2000 Annual Report.pdf

THIS FILING IS (CHECK ONE BOX FOR EACH ITEM)
ltem 1:g An Initial (Original)OR Resubmission No·RECElVED Approved
Submission B No.1902-0021FlLED(pires 11/30/2001)
em 2:An Original Signed Form OR g Conformed Copy 200\JUL 16 PM 2:40
FERC Form No.1:
ANNUAL REPORT OF MAJOR ELECTRIC
UTILITIES,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 other
sanctions as provided by law.The Federal Energy Regulatory Commission does not
consider this report to be of a confidential nature.
Exact Legal Name of Respondent (Company)Year of Report
PacifiCorp Dec.31,2000
FERC FORM No.1 (REV.12-98)
THIS FILING IS (CHECK ONE BOX FOR EACH ITEM)
Item 1:g An Initial (Original)OR Resubmission No.Form Approved
Submission OMB No.1902-0021
(Expires 11/30/2001)
'tem 2:An Original Signed Form OR g Conformed Copy
I
FERC Form No.1:
ANNUAL REPORT OF MAJOR ELECTRIC
UTILITIES,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 other
sanctions as provided by law.The Federal Energy Regulatory Commission does not
consider this report to be of a confidential nature.
Exact Legal Name of Respondent (Company)Year of Report
PacifiCorp Dec.31,2000
FERC FORM No.1 (REV.12-98)
ROBERTR.DAU.EY 825 N.E.Multnomah,Suite 2000
Controller and ChiefAccounting Officer Portland,Oregon 97232
[phone]FAX[phone]
PAciFICORP
January 3,2001
Mr.John Delaware
ChiefAccountant &Deputy Director
Office of Finance,Accounting &Operations
Federal Energy Regulatory Commission
888 First Street,NE
Washington D.C.20426
Reply to:OFAO-DPPD
Docket No.'s:ACOO-20-000and ACOO-20-001
Dear Mr.Delaware:
As we have discussed,PacifiCorp merged with Scottish Powerand became a wholly owned subsidiary.
Scottish Power and PacifiCorp have the same fiscal year endingMarch 31.
We respectfully request for the purpose of meeting the requirementsof filing a Form 1 for its regulated
electric operations,your concurrence with the proposaldescribed below and that you extendthe same
approval grantedlast year in your letter dated April 14,2000 (attached).
1.PacifiCorp will prepare and file by June 30,2001 a Form 1 for its regulatedelectric operations
including all financial and statistical data on a year-endof December31 basis.This data will be
comparablewith previously filed data of PacifiCorp.
2.PacifiCorp will also file by June 30,2001 audited financial statements as of and for the year ended
March 31of its regulatedelectric business.These financial statements will be in the form required by
the Form 1.Audited financial statements for the twelve months ended March 31,2000 were issued
and submitted with the 1999 PacifiCorp Form 1.
This Form 1 extension to June 30 allows Scottish Power to release their final fiscal year-endfinancial data
by the first week in May without having any pre-emptive disclosure made by PacifiCorp (40%of Scottish
Power's operations)prior to that date.
Additionally,we would like to point out that our financial statements for each calendarquarterend are
reviewed by our independentaccountants under standards prescribedby the AICPA for reviews of Interim
Financial Information (SAS 71).This procedureresults in continuing involvement of our auditors in the
financial reporting process and helps insure that key issues are addressed and resolved on a timely basis.
We appreciate you givingthis proposal careful consideration.I would be happy to discuss this with you at
your earliest convenience.
Yours very truly,
Robe R.Dalley
RRD:cw
Enclosures
PACIFIC POWER UTAHPOWER POWERCOR
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INSTRUCTIONSFOR FILING THE
FERC FORM NO.1
GENEEUAL INFOIU47/CION
I.Purpose
This form is a regulatory support requirement (18 CFR 141.1).It is designed to collect financial and
operational information from major electric utilities,Licensees and others subject to the jurisdiction oÉ the
Federal Energy Regulatory Commission.This report is also secondarily considered to be a nonconfidential public use
form supporting a statistical publication (Financial Statistics of Selected Electric Utilities),published by the
Energy Information Administration.
II.Who Must Submit
Each major electric utility,licensee,or other,as classified in the Commission's Uniform System of Accounts
Prescribed for Public Utilities and Licensees Subject to the Provisions of The Federal Power Act (18 CFR 101),must
submit this form.
Note:Major means having,in each of the three previous calendar years,sales or transmission service that
exceeds
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 1A
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 18
C.F.R.385.2011(c)(5).Paragraph (c)(5)of 18 C.F.R.385.2011 requires each respondent submitting data
electronically to file a subscription stating that the paper copies contain the same information as the electronic
filing,that the signer knows the contents of the paper copies and electronic filing,and that the contents as
stated in the copies and electronic filing are true to the best knowledge and belief of the signer.
03)Submit,immediately upon publication,four (4)copies of the Latest annual report to stockholders and any
annual financial or statistical report regularly prepared and distributed to bondholders,security analysts,or
industry associations.(Do not include monthly and quarterly reports.Indicate by checking the appropriate box on
Page 4,List of Schedules,if the reports to stockholders will be submitted or if no annual report to stockholders
is prepared.)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 for
this form,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 with
the Commission's applicable Uniform Systems of Accounts (including applicable notes relating thereto and the Chief
Accountant's published accounting releases),and
(ii)Signed by independent certified public accountants or an independent Licensed public accountant
certified or Licensed by a regulatory authority of a State or other political subdivision of the U.S.(See 18 CFR
41.10-41.12 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
Comparative Balance 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 exmaination 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 Goveraments 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
GENEFGkL 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 Linestransmittingpowertherefromtothepointofjunctionwiththedistributionsystemorwiththeinterconnectedprimarytransmissionsystem,all miscellaneous structures used and useful in connection with said unit or any partthereof,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 orforeigncommerce,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 otherperiodicorspecialreportsastheCommissionmayberulesandregulationsorotherprescribeasnecessaryorappropriatetoassisttheCommissionintheproperadministrationofthisAct.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 shallinclude,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
J1 Exact Legal Name of Respondent 02 Year of Report
PacifiCorp Dec.31,2000
03 Previous Name and Date of Change (if name changed during year)
I l
04 Address of Principal Office at End of Year (Street,City,State,Zip Code)
825 N.E.Multnomah,Ste 2000,Portland,OR 97232
05 Name of Contact Person 06 Title of Contact Person
Henry Lay Accounting Director
07 Address of Contact Person (Street,City,State,Zip Code)
825 N.E.Multnomah,Ste 1900,Portland,OR 97232
08 Telephone of Contact Person,lncluding 09 This Report ls 10 Date of Report
Area Code (1)g An Original (2)A Resubmission (Mo,Da,Yr)
[phone] //
ATTESTATION
The undersigned officer certifies that he/she 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 and
affairs of the above named respondent in respect to each and every matter set forth therein during the period from and including January 1 to
and including December 31 of the year of the report.
01 Name 03 Signature 04 Date Signed
Karen K.Clark (Mo,Da,Yr)
02 Title 06/26/2001
Senior Vice President and CFO
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 any
false,fictitious or fraudulent statements as to any matter within its jurisdiction.
FERC FORM No.1 (ED.12-91)Page 1
Nameof Respondent I his keport is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
LIS I DE buHi-DULES (Electnc U ility)
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)
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 Eamingsfor 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 none
27 Unrecovered Plant and Regulatory Study Costs 230
28 Other Regulatory Assets 232
29 Miscellaneous Deferred Debits 233
30 Accumulated Deferred Income Taxes 234
31 Capital Stock 250-251
32 Cap Stk Sub,Cap Stk Liab for Con,Prem Cap Stk &Inst Recd Cap Stk 252 none
33 Other Paid-in Capital 253 none
34 Discount on Capital Stock 254 none
35 Capital Stock Expense 254
36 Long-Term Debt 256-257
FERC FORMNO.1 (ED.12-96)Page 2
Name of Respondent I his Report is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
Llo i UI-SCHauULES (Electnc 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 Ïitle of $chedule Reference RemarksNo.Page No.
(a)(b)(c)
37 Reconciliation of Reported Net Income with Taxable Inc for Fed Inc Tax 261
38 Taxes Accrued,Prepaid and Charged During the Year 262-263
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 Ta×es-Other 276-277
44 Other Regulatory Liabilities 278
45 Electric Operating Revenues 300-301
46 Sales of Electricity by Rate Schedules 304
47 Sales for Resale 310-311
48 Electric Operation and Maintenance Expenses 320-323
49 Number of 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 CommissionExpenses 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
'ERC FORM NO.1 (ED.12-96)Page 3
Name of Respondent I his Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000
(2)A Resubmission //
Llo I UE SCHEDULES (Electnc 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 Šchedule Reterence Remarks
No.Page No.
(a)(b)(c)
67 Transmission Lines Added During Year 424-425
68 Substations 426-427
69 Electric Distribution Meters and Line Transformers 429
70 EnvironmentalProtection Facilities 430
71 EnvironmentalProtection Expenses 431
72 FoomoteDab 450
Stockholders'Reports Check appropriate box:
Four copies will be submitted
O No annual report to stockholders is prepared
ERCFORM NO.1 (ED.12-96)Page 4
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)g An Original (Mo,Da,Yr)
(2)A Resubmission j ¡Dec.31,2000
GENERAL INFORMATION
1.Providename and title of officer having custody of the general corporatebooks of account and address ofofficewherethegeneralcorporatebooksarekept,and address of office where any other corporate books of account
are kept,if differentfrom that where the general corporate books are kept.
Karen K.Clark,Sr VP/CFO Corporate books are kept at:
825 N.E.Multnomah,Suite 2000 825 N.E.Multnomah,Suite 2000
Portland,Oregon 97232-4116 Portland,OR 97232-4116
2.Providethe name of the State under the laws of which respondent is incorporated,and date of incorporation.
If incorporatedunder a special law,give referenceto such law.If not incorporated,state that fact and give the type
of organizationand the date organized.
Incorporated on January 9,1989 in the State of Oregon.
3.If at any time duringthe year the property of respondent was held by a receiver or trustee,give (a)name ofreceiverortrustee,(b)date such receiver or trustee took possession,(c)the authority by which the receivershipor
trusteeship was created,and (d)date when possession by receiver or trustee ceased.
Not Applicable
Not Applicable.
4.State the classes or utility and other services furnished by respondentduring the year in each State in which
the respondentoperated.
The Company is an electric utility that conducts a retail electric utilitybusinessthroughPacificPowerandUtahPowerandengagesinpowerproduction
and sales on a wholesale basis under the name PacifiCorp.
The Company furnishes electric service in portions of California,Idaho,Oregon,Utah,Washington,and Wyoming.
5.Haveyou engaged as the principal accountant to audit your financialstatements an accountant who is not
the principal accountant for your previous year's certified financial statements?
(1)Yes...Enter the date when such independentaccountant was initially engaged:
(2)g No
FERC FORM No.1 (ED.12-87}PAGE 101
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)g An Original (Mo,Da,Yr)
(2)A Resubmission ¡¡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.
ScottishPower plc
ScottishPower NA 1 Limited
ScottishPower NA 2 Limited
NA General Partnership
PacifiCorp (100%controlled)
FERC FORM NO.1 (ED.12-96)Page 102
Name of Respondent I his Report is:Date ot Report Year of Repod I
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000
(2)A Resubmission //
GUMPURAl lUNb GUN I RULLED BYR .bHUNul-N I
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 Ëootnote
No.Stock Owned Ref.(a)(b)(c)(d)
1 Centralia Mining Company mining 100
2 Demand Side Receivables,Inc.100
3 Energy West Mining Company mining 100
4 Glenrock Coal Company mining 100
5 Interwest Mining Company mining 100
6 Pacific Klamath Energy,Inc.Klamath Falls Co-Gen Project 100
7 Pacific Minerals,Inc.mining 100
8 Bridger Coal Company mining 100
9 PacifiCorp Environmental Remediation Co environmental services 100
10 PacifiCorp Future Generations,Inc.rain forest carbon credits 100
11 PacifiCorp Group Holdings Company holding company 100
12 PacifiCorp Financial Services,Inc.financial services 100
13 PacifiCorp International Group Holdings Co int'l holding company 100
14 PacifiCorp investment Management,Inc management services for PERCO 100
15 PPW Repurchase LLC 100
16 PacifiCorp Power Marketing,Inc.wholesale power marketing 100
17
18
19
20
21
22
23
24
25
26
27
FERC FORM NO.1 (ED.12-96)Page 103
Name of Respondent I his Report is:lJate of Report Ÿear of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000
(2)A Resubmission //
1.Report below the name,title and salary for each executive officer whose salary is $50,000 or more.An "executive officer"of a
respondent includes its president,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 previous
incumbent,and the date the change in incumbency was made.
Line iltle Nan'le ót Uttibér balaryforYearNo.(a)(b)(c)
1
2 President and Chief Executive Officer Alan V.Richardson 589,015
3
4 Senior Vice President Paul G.Lorenzini 1,295,262
5
6 Senior Vice President Terry F.Hudgens 277,593
7
8 Senior Vice President Andrew N.MacRitchie 289,156
9
10 President and Chief Operating Officer Richard T.O'Brien 1,791,120
11
12 Executive Vice President Henry H.Hewitt 143,506
13
14 Executive Vice President William D.Landels 417,192
15
16 Executive Vice President Judith A.Johansen 2,545
17
18 Vice President Thomas J.Imeson 783,780
19
20 Corporate Secretary Lenore M.Martin 201,555
21
22 Senior Vice President Michael J.Pittman 346,102
23
24 Vice President Ernest E.Wessman 206,754
25
26 Vice President Richard D.Westerberg 587,128
27
28 Vice President and Treasurer William E.Peressini 1,042,408
29
30 Vice President Anne E.Eakin 144,119
31
32 Vice President Donald N.Furman 197,416
33
34 Senior Vice President Timothy E.Meier 306,491
35
36 Vice President Brian D.Sickels 389,512
37
38 Vice President Richard Walje 260,613
39
40 Controller Robert R.Dalley 263,631
41
42 Vice President Craig N.Longfield 255,758
43
44 Vice President Barry G.Cunningham 279,326
FERC FORMNO.1 (ED.12-96)Page 104
Name of Respondent I his Report is:lJate of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
1.Report below the name,title and salary for each executive officer whose salary is $50,000 or more.An "executive officer"of a
respondent includes its president,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 previous
incumbent,and the date the change in incumbency was made.
une litle Wame of Uthcer bálaryforYearNo(a)(b)(c)
1
2 Vice President C.Alex Miller 301,690
3
4 Senior Vice President and Chief Financial Officer Karen K.Clark 396,389
5
6 Treasurer Bruce N.Williams 166,541
7
8 Vice President Robert A.Moir 212,194
9
10 Vice President Matthew R.Wright 179,140
11
12 General Counsel and Corporate Secretary Andrew P.Haller 18,344
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 FORMNO.1 (ED.12-96)Page 104.1
Name of Respondent I his Report is:Date ot Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000
(2)A Resubmission //
DIRECluRS
1.Report below the information called for conceming each director of the respondent who held office at any time during the year.Include in column (a),abbreyiated
titles of the directors who are officers of the respondent.
2.Designate members of the Executive Committee by a triple asterisk and the Chairman of the Executive Committee by a double asterisk.Lille Name (and lille)of Utrector Pnncipal Business AddressNo-(a)(b)
1 PacifiCorp Board of Directors:
2
3 **Sir Ian Robinson 1 Atlantic Quay
4 Glasgow,Scotland G2 8SP UK
5
6 Keith R.McKennon 1540 SW Vista Ave #3000
7 Portland,OR 97201
8
9 Richard T.O'Brien (President and COO)825 NE Multnomah
10 Portland,Oregon 97232
11
12 ***Alan V.Richardson (President and CEO)825 NE Multnomah
13 Portland,Oregon 97232
14
15 Nolan E.Karras 4695 South 1900 West #3
16 Roy,Utah 84067
17
18 ***William D.Landels (Executive V.P.)201 South Main,Ste 2300
19 Salt Lake City,UT 84140
20
21 ***lan M.Russell 1 Atlantic Quay
22 Glasgow,Scotland G2 8SP UK
23
24 ***Kenneth L.Vowles 1 Atlantic Quay
25 Glasgow,Scotland G2 8SP UK
26
27 Robert G.Miller 0305 SW Montgomery#F508
28 Portland,Oregon 97201
29
30 Don M.Wheeler 4901 West 2100 South
31 Salt Lake City,Utah 84120
32
33 Henry H.Hewitt 825 NE Multnomah
34 Portland,Oregon 97232
35
36 "*Karen K.Clark (Senior V.P.and CFO)825 NE Multnomah
37 Portland,Oregon 97232
38
39 ***Andrew N.MacRitchie (Senior V.P.)825 NE Multnomah
40 Portland,Oregon 97232
41
42 ***Timothy E.Meier (Senior V.P.)825 NE Multnomah
43 Portland,Oregon 97232
44
45 **Michael J.Pittman (Senior V.P.)825 NE Multnomah
46 Portland,Oregon 97232
47
48 ***Terry F.Hudgens (Senior V.P.)825 NE Multnomah
FERC FORM NO.1 (ED.12-95)Page 105
Name of Respondent I his Report is:Date ot Report Year ot Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000
(2)A Resubmission //
DIRL-UlURb
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),abbreviated
titles of the directors who are officers of the respondent.
2.Designate members of the Executive Committee by a triple asterisk and the Chairman of the Executive Committee by a double asterisk.Lille Name (and I itle)of IJirector Principal business AddressNo·(a)(b)
1 Portland,Oregon 97232
2
3 "*Judith A.Johansen (Executive V.P.)825 NE Multnomah
4 Portland,Oregon 97232
5
6 Pacific Board:
7
8 Nancy Wilgenbusch Marylhurst University
9 Marylhurst,OR 97036
10
11 William D.Landels (Executive V.P.)201 South Main,Ste 2300
12 Salt Lake City,UT 84140
13
14 William B.Douglas P.O.Box 430
15 Yakima,Washington 98907
16
17 Michael D.Naumes P.O.Box 996
18 Medford,Oregon 97501
19
20 Linda Shelk 37 PokegamaDrive
21 Powell Butte,Oregon 97753
22
23 Ethel Simon-McWilliams 600 S.E.Marion #501
24 Portland,Oregon 97202
25
26 Utah Board:
27
28 Nolan E.Karras 4695 South 1900 West #3
29 Roy,Utah 84067
30
31 William D.Landels (Executive V.P.)201 South Main,Ste 2300
32 Salt Lake City,UT 84140
33
34 Dr.Chase N.Peterson 66 Thaynes Canyon Drive
35 Park City,Utah 84060-6711
36
37 Steven D.Bennion 351 West Center
38 Cedar City,Utah 84720
39
40 Peggy A.Stock 1840 South 1300 East
41 Salt Lake City,Utah 84105
42
43 E.J."Jake"Garn 201 South Main,Ste 700
44 Salt Lake City,UT 84111
45
46 Kent H.Cannon 36 South State Street
47 Salt Lake City,UT 84136
48
FERC FORMNO.1 (ED.12-95)Page 105.1
Name of Respondent I his Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000
(2)A Resubmission //
1.Report below the information called for conceming each director of the respondent who held office at any time during the year.Include in column (a),abbreviated
titles Jf the directors who are officers of the respondent.
2.Designate members of the Executive Committee by a triple asterisk and the Chairman of the Executive Committee by a double asterisk.
Liub Name (ano I itle)of Director Principal business AddressNo.(a)(b)
1 Wyoming Board:
2
3 Deborah Healy Hammonds 100 Country Drive
4 Worland,Wyoming 82401
5
6 John W.Hay ll!Box 880
7 Rock Springs,Wyoming 82902
8
9 Brent R.Kunz P.O.Box 1208
10 Cheyenne,Wyoming 82003-1208
11
12 Margaret Maier Murdock 125 Conye Drive
13 Casper,Wyoming 82601
14
15 Peter I.Wold 139 West Second Street,P.O.Box 114
16 Casper,Wyoming 82602
17
18 William D.Landels (Executive V.P.)201 South Main,Ste 2300
19 Salt Lake City,UT 84140
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.12-95)Page 105.2
BLANK PAGE
(Next Page is:106)
Nameof Respondent I his Report Is:Date of keport Year of Report(1)An Original (Mo,Da,Yr)PacifiCorp Dec.31 2000(2)A Resubmission //
bbURll y HULUbHB ANU VUIINGPUvvEks
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)conceming 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.Fumish particulars (details)conceming 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 andbookpriortoendofyear,and state the purpose latest general meeting prior to end of year place of such meetingofsuchclosing:for election of directors of the respondent and May 15,2000November16,2000 for the determination of number of such votes cast by proxy
stockholders of record for payment of dividends-Total:297,324,604 Reelected by resolution
By Proxy:
VUllNGSECURllii-8LineName(Title)and Address of Security
No.Number of Votes as of (date):05/15/2000HolderTotalCommon Preferred Other
Votes Stock Stock
(a)(b)(c)(d)(e)
4 TOTAL votes of all voting securities
5 TOTAL number of security holders
6 TOTAL votes of security holders listed below
7
8 ScottishPower plc 297,324,604 297,324,604
9 1 Atlantic Quay
10 Glasgow,Scotland G2 8SP UK
11
12 Cedefast 2,080,923 2,080,645
13
14 Atomic Investments 2,000 2,000
15
16 John &Lois Hunting 2,000 2,000
17
18 Robert F.Hallwyler 1,411 1,411
FERCFORM NO.1 (ED.12-96)Page 106
Name of Respondent I his Report Is:Date of Report Year of Report(1)An Original (Mo,Da,Yr)PacifiCorp (2)A Resubmission //Dec.31,2000
SE URI ly HULUt-Rb ANU vu I ING Puvvt-ko (continued)
Line Name (Title)and Address of Security Total Common Preferred Other
No.Holder Votes Stock Stock
(a)(b)(c)(d)(e)
19
20 Mapleton Grain Co.917 917
21
22 Thelma Vemice Wolff Trustee
23 FBO ThelmaV.Wolff Living Trust 816 816
24
25 ElmerM.&Lillian E.Schuff 681 681
26
27 Agatha D.Nemish 678 678
28
29 ElmerM.Black &Helen L.Black TR U/A 629 629
30
31 Dale Kris &Neil Hansen Partnership 600 600
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46
47
48
49
50
51
52
53
FERC FORM NO.1 (ED.12-96)Page 107
Name of Respondent I his Report Is:Date of Report Y ear of Report
PacifiCorp (1)An Original Dec.31,2000
(2)A Resubmission
llvPUNIANI CHANut-8UURING IHt-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 given elsewhere 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 joumal 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 Reportis:Date of Report Year of Report
(1)X An Original (Mo,Da,Yr)
PacifiCorp (2)A Resubrnission //Dec 31,2000
IMPORTANTCHANGESDURING THEYEAR (Continued)
1.The following PacifiCorp franchiseagreements were renewedor newly adoptedin 2000:
Renewal Date Expiration Date Fee %
California
None
Idaho
Firth,ID 2000 03 14 2035 01 01
Oregon
Gold Hill,OR 2000 03 08 2005 03 08 3.5%Franchise
+3 successive 5 year terms
Phoenix,OR 2000 01 17 2020 01 17 3.5%Franchise
Prineville,OR 2000 03 14 2005 03 14 5.0%Franchise
Sweet Home,OR 2000 06 27 2005 08 01 5.0%Franchise
*Utah
Layton,UT 2000 10 05 2005 10 01 4.0%MST
Saratoga Springs,UT 2000 05 11 2030 05 11
Snowville,UT 2000 09 12 2025 10 01
Washington
Zillah,WA 2000 07 03 2005 07 03 6.0%B&O
+1 successive 5 year term
Wyoming
Buffalo,WY 2000 04 04 2015 04 04 4.0%Franchise
Byron,WY 2000 12 15 2025 12 15 2.0%Franchise
Douglas,WY 2000 02 23 2015 02 23 3.0%Franchise
East Thermopolis,WY 2000 08 01 2025 08 01 3.5%Franchise
GreenRiver,WY 2000 02 01 2015 02 01 2.0%Franchise
Midwest,WY 2000 12 13 2025 12 13 2.0%Franchise
Pinedale,WY 2000 10 16 2010 10 16 2.0%Franchise
Thermopolis,WY 2000 04 04 2025 04 04 3.5%Franchise
2.none
3.On September 6,2000,PacifiCorp completed the sale of its indirect ownershipof Powercor pursuant to the August 2,
2000 agreementto sell Powercor and PacifiCorp's 19.9%interest in Hazelwood.On November 17,2000,PacifiCorp
completed the sale of Hazelwood to National Power Australia Holdings Pty Ltd,a wholly owned indirect subsidiaryof
International Power plc,pursuantto the partnership'spre-emptiverights process.
On May 4,2000,the utility partners (including PacifiCorp)who ownedthe 1,340 MW coal-fired Centralia Power Plant
sold the plant and the adjacent coal mine,wholly owned and operatedby PacifiCorp,to Transalta.Commission
authorization was given on Docket No.ECOO-17-000 dated January13,2000.
FERC FORM NO.1 (ED.12-96)Page 109
Name of Respondent This Report is:Date of Report Year of Report
(1)X_An Original (Mo,Da,Yr)
PacifiCorp (2)_A Resubmission //Dec 31,2000
IMPORTANTCHANGES DURINGTHE YEAR (Continued)
4.none
5.none
6.none
7.none
8.During 2000,wage increases went into effect with the International Brotherhood of Electrical Workers,Local 57,
Local 125,Local 659 and Local 415 of 3.0%.Wage increases went into effect with the Utility Workers Union of
America,Local 127 and Local 197 of 3.0%.
9.PacifiCorp and its subsidiaries are parties to various legal claims,actions and complaints,certain of which involve
material amounts.Although PacifiCorp is unable to predict with certainty whether or not it will ultimately be successful
in these proceedingsor,if not,what the impact might be,managementcurrently believes that disposition of these matters
will not have a materially adverse effect on PacifiCorp's consolidated financial statements.
Theparties have settled the litigationof Sierra Club v.Tri-State Generation and Transmission Association,Inc.,Public
Service Companyof Colorado,Inc.,Salt River Project AgriculturalImprovement and Power District,PacifiCorp and
Platte River PowerAuthority,Civil Action No.96-B2368,US District Court for the District of Colorado.
10.PacifiCorp had $10 million and $5 million as of December31,2000 and March 31,2000,respectively,of accrued
liabilities payable for ScottishPoweremployees employed as PacifiCorp managementand ScottishPower employees
temporarily working for PacifiCorp on its Transition Plan.In addition,at December 31,2000,PacifiCorp had a $404
million note and related interest receivable from ScottishPower.Interest income was $8 million for the year ended
December31,2000.
FERC FORM NO.1 (ED.12-96)Page 109.1
BLANK PAGE
(Next Page is:110)
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)g An Original (Mo,Da,Yr)
(2)A Resubrnission //Dec.31,2000
COMPARATIVE BALANCE SHEET (ASSETE AND OTHER DEBITS)
Ref.Balance at Balance atLineTitleofAccountPageNo.Beginning of Year End of YearNo.(a)(b)(c)(d)
1 UTILITY PLANT
2 Utility Plant (101-106,114)200-201 12,255,386,236 12,049,689,943
3 Construction Work in Progress (107)200-201 283,919,388 265,681,606
4 TOTAL Utility Plant (Enter Total of lines 2 and 3)12,539,305,624 12,315,371,549
5 (Less)Accum.Prov.for Depr.Amort.Depl.(108,111,115)200-201 4,607,397,151 4,674,742,315
6 Net Utility Plant (Enter Total of line 4 less 5)7,931,908,473 7,640,629,234
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)7,931,908,473 7,640,629,234
11 Utility Plant Adjustments (116)122 0 0
12 Gas Stored Underground -Noncurrent (117)0 0
13 OTHER PROPERTYAND INVESTMENTS
14 Nonutility Property (121)221 85,182,863 12,815,250
15 (Less)Accum.Prov.for Depr.and Amort.(122)44,024,208 5,478,431
16 Investments in Associated Companies (123)6,107,928 7,395,158
17 investment in Subsidiary Companies (123.1)224-225 1,054,708,537 575,253,560
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)71,569,195 88,674,526
21 Special Funds (125-128)2,997,150 2,566,973
22 TOTAL Other Property and investments (Total of lines 14-17,19-21)1,176,541,465 681,227,036
23 CURRENT AND ACCRUED ASSETS
24 Cash (131)-24,834,331 -12,444,561
25 Special Deposits (132-134)-7,281,344 -6,885,091
26 Working Fund (135)785,618 -1,747,749
27 Temporary Cash Investments (136)19,651,150 55,417,301
28 Notes Receivable (141)564,076 452,523
29 Customer Accounts Receivable (142)233,684,732 553,622,283
30 Other Accounts Receivable (143)19,404,868 21,139,851
31 (Less)Accum.Prov.for Uncollectible Acct.-Credit (144)19,677,546 14,568,873
32 Notes Receivable from Associated Companies (145)-344 130,282
33 Accounts Receivable from Assoc.Companies (146)59,619,349 59,952,512
34 Fuel Stock (151)227 51,809,164 53,541,066
35 Fuel Stock Expenses Undistributed (152)227 0 0
36 Residuals (Elec)and Extracted Products (153)227 0 0
37 Plant Materials and Operating Supplies (154)227 104,636,772 93,359,223
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 O 0
43 Stores E×pense Undistributed (163)227 0 0
44 Gas Stored Underground -Current (164.1)O 0
45 Liquefied Natural Gas Stored and Held for Processing (164.2-164.3)O 0
46 Prepayments (165)25,161,022 21,596,134
47 Advances for Gas (166-167)0 0
48 Interest and Dividends Receivable (171)1,060,202 254,323
49 Rents Receivable (172)413,403 55,623
50 Accrued Utility Revenues (173)142,610,622 145,087,713
51 Miscellaneous Current and Accrued Assets (174)0 -82,577
52 TOTAL Current and Accrued Assets (Enter Total of lines 24 thru 51)607,607,413 968,879,983
FERC FORM NO.1 (ED.12-94)Page 110
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)g An Original (Mo,Da,Yr)
(2)A Resubmission //Dec.31,2000
COMPARATIVE BALANCE SHEET (ASSETS AND OTHEF:DEBITS)continued)
Ref.Balance at Balance atLineTitleofAccount
No.(a)Page No.Beginning of Year End of Year
(b)(c)(d)
53 DEFERRED DEBlTS
54 Unamortized Debt Expenses (181)47,035,217 37,197,114
55 Extraordinary Property Losses (182.1)230 0 0
56 Unrecovered Plant and Regulatory Study Costs (182.2)230 21,031,086 19,175,216
57 Other Regulatory Assets (182.3)232 742,318,694 887,390,222
58 Prelim.Survey and Investigation Charges (Electric)(183)890,191 768,817
59 Prelim.Sur.and Invest.Charges (Gas)(183.1,183.2)0 0
60 Clearing Accounts (184)-28,447 186,516
61 Temporary Facilities (185)59,262 84,520
62 Miscellaneous Deferred Debits (186)233 93,461,703 91,322,557
63 Def.Losses from Disposition of Utility Pit.(187)0 0
64 Research,Devel.and Demonstration E×pend.(188)352-353 0 0
65 Unamortized Loss on Reaquired Debt (189)46,939,953 46,560,934
66 Accumulated Deferred income Taxes (190)234 214,980,898 218,331,387
67 Unrecovered Purchased Gas Costs (191)0 0
68 TOTAL Deferred Debits (Enter Total of lines 54 thru 67)1,166,688,557 1,301,017,283
69 TOTAL Assets and Other Debits (Enter Total of lines 10,11,12,22,52,68)10,882,745,908 10,591,753,536
FERC FORM NO.1 (ED.12-94)Page 111
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)Q An Original (Mo,Da,Yr)
(2)A Resubrnission //Dec.31,2000
COMPARATIVEBALANCE SHEET(LIABILITIESAND OTHER CREDITS)
Ref.Balance at Balance atLineTitleofAccountPageNo.Beginningof Year End of YearNo.(a)(b)(c)(d)
1 PROPRIETARY CAPITAL
2 Common Stock Issued (201)250-251 3,350,185,742 3,350,Ä5,742
3 Preferred Stock Issued (204)250-251 216,493,200 216,463,300
4 Capital Stock Subscribed (202,205)252 0 0
5 Stock Liability for Conversion (203,206)252 0 0
6 Premiumon Capital Stock (207)252 0 0
7 Other Paid-In Capital(208-211)253 0 0
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 44,258,749 43,799,002
11 Retained Earnings (215,215.1,216)118-119 824,537,881 908,060,106
12 Unappropriated Undistributed Subsidiary Earnings (216.1)118-119 -313,011,350 -807,521,350
13 (Less)Reaquired Capital Stock (217)250-251 515,475 0
14 TOTAL Proprietary Capital (Enter Total of lines 2 thru 13)4,033,431,249 3,623,388,796
15 LONG-TERM DEBT
16 Bonds (221)256-257 3,173,477,115 3,008,197,120
17 (Less)Reaquired Bonds (222)256-257 0 0
18 Advances from Associated Companies (223)256-257 381,503,100 379,054,473
19 Other Long-Term Debt (224)256-257 175,825,925 0
20 Unamortized Premiumon Long-Term Debt (225)558,177 60,026
21 (Less)Unamortized Discount on Long-Term Debt-Debit (226)3,367,515 2,996,143
22 TOTAL Long-Term Debt (Enter Total of lines 16 thru 21)3,727,996,802 3,384,315,476
23 OTHER NONCURRENTLIABILITIES
24 Obligations Under Capital Leases -Noncurrent (227)27,208,363 27,273,739
25 Accumulated Provision for Property insurance (228.1)10,162,161 10,891,473
26 Accumulated Provision for Injuries and Damages (228.2)4,971,50 73,975,588
27 Accumulated Provision for Pensions and Benefits (228.3)81,323,551 177,480,459
28 Accumulated Miscellaneous Operating Provisions (228.4)10,966,34 12,923,148
29 Accumulated Provision for Rate Refunds (229)746,28 0
30 TOTAL OTHERNoncurrent Liabilities (Enter Total of lines 24 thru 29)135,378,214 302,544,407
31 CURRENTAND ACCRUED LIABILITIES
32 Notes Payable (231)138,557,988 263,259,772
33 Accounts Payable (232)314,822,266 659,652,623
34 Notes Payable to Associated Companies (233)254,083,722 71,353,702
35 Accounts Payable to Associated Companies(234)21,346,93 16,060,693
36 Customer Deposits (235)6,429,21 6,940,774
37 Taxes Accrued (236)262-263 115,178,14 139,540,035
38 interest Accrued (237)78,414,38 76,678,488
39 Dividends Declared (238)6,274,25 84,443,774
40 Matured Long-Term Debt (239)0
41 Matured Interest (240)0
42 Tax Collections Payable (241)4,274,94 10,829,906
43 Miscellaneous Current and Accrued Liabilities (242)87,178,86 85,738,612
44 Obligations Under Capital Leases-Current (243)-137,44 -65,374
45 TOTAL Current &Accrued Liabilities (Enter Total of lines 32 thru 44)1,026,423,28 1,414,433,005
FERC FORM NO.1 (ED.12-89)Page 112
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)g An Original (Mo,Da,Yr)
(2)A Resubrnission //Dec.31,2000
COMPARATIVEBALANCE SHEET (LIABILITIESAND OTHER CREDITS)(Continued)
Ref.Balance at Balance atLineTitleofAccountPageNo.Beginning of Year End of YearNo.(a)(b)(c)(d)
46 DEFERREDCREDITS
47 Customer Advances for Construction (252)15,777,058 14,639,806
48 Accumulated Deferred Investment Tax Credits (255)266-267 117,226,317 109,226,949
49 Deferred Gains from Disposition of Utility Plant (256)O 0
50 Other Deferred Credits (253)269 146,145,379 117,912,368
51 Other Regulatory Liabilities (254)278 47,646,876 72,847,601
52 Unamortized Gain on Reaquired Debt (257)1,152,031 814,643
53 Accumulated Deferred Income Taxes (281-283)272-277 1,631,568,697 1,551,630,485
54 TOTAL Deferred Credits (Enter Total of lines 47 thru 53)1,959,516,358 1,867,071,852
55 0 0
56 0 0
57 0 0
58 0 0
59 0 0
60 0 0
61 0 0
62 0 0
63 0 0
64 0 0
65 0 0
66 0 0
67 0 0
68 TOTAL Liab and Other Credits (Enter Total of lines 14,22,30,45,54)10,882,745,908 10,591,753,536
FERC FORM NO.1 (ED.12-89)Page 113
Name of Respondent I his Report is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
blAIEMENI UE INGUME EUR IHE yEAR
1.Report amounts for accounts 412 and 413,Revenue and Expenses from Utility Plant Leased to Others,in another Utility colurnn (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
2 Operating Revenues (400)300-301 4,108,770,69 3,230,019,004
3 Operating Expenses
4 Operation Expenses (401)320-323 2,972,684,38 2,003,532,314
5 Maintenance Expenses (402)320-323 163,203,33 161,697,805
6 Depreciation Expense (403)336-337 338,754,59 323,476,640
7 Amort.&Depl.of Utility Plant (404-405)336-337 40,386,58 42,457,860
8 Amort.of Utility Plant Acq.Adj.(406)336-337 5,857,361 5,860,179
9 Amort.Property Losses,Unrecov Plant and Regulatory Study Costs (407)
10 Amort.of Conversion Expenses (407)-23,961
11 Regulatory Debits (407.3)1,951,714 1,225,177
12 (Less)Regulatory Credits (407.4)
13 Taxes Other Than Income Taxes (408.1)262-263 121,451,546 117,326,353
14 Income Taxes -Federal (409.1)262-263 140,505,147 54,064,212
15 -Other (409.1)262-263 13,631,972 6,027,789
16 Provision for Deferred Income Taxes (410.1)234,272-277 227,108,183 236,272,497
17 (Less)Provision for Deferred income Taxes-Cr.(411.1)234,272-277 274,140,674 155,407,983
18 investment Tax Credit Adj.-Net (411.4)266 -5,934,108 -5,952,396
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)10,598,784 463,315
22 Losses from Disposition of Allowances (411.9)
23 TOTAL Utility Operating Expenses (Enter Total of lines 4 thru 22)3,734,861,264 2,790,093,171
24 Net Util Oper Inc (Enter Tot line 2 less 23)Carry fwd to P117,line25 373,909,434 439,925,833
FERC FORM NO.1 (ED.12-96)Page 114
Name of Respondent I his Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
bl A I EMbl¾\UE INuuMt-EUR I HE.mAN (uontinued)
resulting from settlement of any rate proceeding affecting revenues received or costs incurred for power or gas purchases,and a
summary of the adjustments made to balance sheet,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 on
pages 122-123.
B.Enter on pages 122-123 a concise explanation of only those changes in accounting methods made during the year which had an
effect on net income,including the basis of allocations and apportionments from those used in the preceding year.Also give the
approximate dollar effect of such changes.
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,and
report the information in the blank space on pages.122-123 or in a footnote.
ELECTRIC UTILITY GAS UTILITY OTHER UTILITY Line
current Year Previous Year current year Previous Year Gurrent Year Previous Year No.
(e)(f)(g)(h)(i)(j)
4,108,770,698 3,230,019,004 2
2,972,684,389 2,003,532,314 4
163,203,337 161,697,805 5
338,754,599 323,476,640 6
40,386,582 42,457,860 7
5,857,361 5,860,179 8
9
-23,961 10
1,951,714 1,225,177 11
12
121,451,546 117,326,353 13
140,505,147 54,064,212 14
13,631,972 6,027,789 15
227,108,183 236,272,497 16
274,140,674 155,407,983 17
-5,934,108 -5,952,396 18
19
20
10,598,784 463,315 21
22
3,734,861,264 2,790,093,171 23
373,909,434 439,925,833 24
FERC FORM NO.1 (ED.12-96)Page 115
Name ot Respondent I his Report Is:Date of keport Year of keport(1)An Original (Mo,Da,Yr)PacifiCorp Dec.31 2000(2)A Resubmission //
a l a i EMi-N I UE INuulvle Euk i HE y dAk (Gontinued)
Line OTHER UTILITY OTHER UTILITY OTHER UTILITY
No Current Year Previous Year Current Year Previous Year Gurrent Year Previous Year
(k)(I)(m)(n)(o)(p)
2
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
FERC FORM NO.1 (ED.12-96)Page 116
Name ot Respondent I his Report is:Date of Report Year of Report(1)An Original (Mo,Da,Yr)PacifiCom (2)A Resubrnission //Dec.31,2000
o I A I blvli-N I Ul-INGUlvlb I-UR I Hb y l-AR (Gontinued)
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)373,909,434 439,925,833
26 Other income and Deductions
27 Other Income
28 Nonutilty Operating Income
29 Revenues From Merchandising,Jobbing and Contract Work (415)9,654,080 11,951,014
30 (Less)Costs and Exp.of Merchandising,Job.&Contract Work (416)2,772,899 5,531,366
31 Revenues From Nonutility Operations (417)21,998,518 54,426,508
32 (Less)Expenses of NonutilityOperations (417.1)18,815,598 49,899,163
33 Nonoperating Rental Income (418)602,132 393
34 Equity in Earnings of Subsidiary Companies (418.1)119 -145,756,923 40,905,924
35 Interest and Dividend Income (419)9,666,462 10,350,329
36 Allowance for Other Funds Used During Construction (419.1)4,356,322 11,179,107
37 Miscellaneous Nonoperating Income (421)4,900,162 -1,775,267
38 Gain on Disposition of Property (421.1)1,947,186 7,263,562
39 TOTAL Other Income (Enter Total of lines 29 thru 38)-114,220,558 78,871,041
40 Other Income Deductions
41 Loss on Disposition of Property (421.2)14,076,787 1,066,855
42 Miscellaneous Amortization (425)340 44,068 128,074
43 Miscellaneous Income Deductions (426.1-426.5)340 -29,267,090 151,988,918
44 TOTAL Other Income Deductions (Total of lines 41 thru 43)-15,146,235 153,183,847
45 Taxes Applic.to Other Income and Deductions
46 Taxes Other Than Income Taxes (408.2)262-263 160,500 164,728
47 Income Taxes-Federal (409.2)262-263 4,993,000 -1,424,000
48 Income Taxes-Other (409.2)262-263 663,000
49 Provision for Deferred inc.Taxes (410.2)234,272-277 131,024 251,199
50 (Less)Provision for Deferred Income Taxes-Cr.(411.2)234,272-277 2,506,502 1,415,551
51 Investment Tax Credit Adj.-Net (411.5)-2,065,260 -2,065,260
52 (Less)Investment Tax Credits (420)
53 TOTAL Taxes on Other Income and Deduct.(Total of 46 thru 52)1,375,762 -4,488,884
54 Net Other income and Deductions (Enter Total lines 39,44,53)-100,450,085 -69,823,922
55 Interest Charges
56 interest on Long-Term Debt (427)212,636,944 4SŸ,154
57 Amort.of Debt Disc.and Expense (428)4,369,274 4,254,002
58 Amortization of Loss on Reaquired Debt (428.1)6,219,217 6,160,148
59 (Less)Amort.of Premiumon Debt-Credit (429)498,151 1,984,449
60 (Less)Amortization of Gain on Reaquired Debt-Credit (429.1)337,388
61 Interest on Debt to Assoc.Companies (430)340 41,136,700 35,060,335
62 Other Interest Expense (431)340 24,239,520 31,291,339
63 (Less)Allowance for Borrowed Funds Used During Construction-Cr.(432)9,209,549 9,300,699
64 Net Interest Charges (Enter Total of lines 56 thru 63)278,556,567 290,087,830
65 income Before Extraordinary Items (Total of lines 25,54 and 64)-5,097,218 80,014,081
66 Extraordinary Items
67 Extraordinary Income (434)
68 (Less)Extraordinary Deductions (435)
69 Net Extraordinary Items (Enter Total of line 67 less line 68)
70 Income Taxes-Federal and Other (409.3)262-263
71 Extraordinary Items After Taxes (Enter Total of line 69 less line 70)
72 Net income (Enter Total of lines 65 and 71)-5,097,218 80,014,081
ERC FORM NO.1 (ED.12-96)Page 117
Name of Hespondent I his Report Is:L)ate of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000
(2)A Resubmission //
SIAl EMENI UF REIAINED bANNINGS I-UN I Hb 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 bontia Primary Art ountNo.Item Account Affected(a)(b)(c)
UNAPPROPRIATEDRETAINED EARNINGS(Account 216)
1 Balance-Beginning of Year 820,962,070
2 Changes
3 Adjustments to Retained Eamings (Account 439)
4 Dividends from subsidiaries 216.1 348,753,077
5
6
7
8
9 TOTAL Credits to Retained Eamings (Acct.439)348,753,077
10 214 -451,485
11
12
13
14
15 TOTAL Debits to Retained Eamings (Acct.439)-451,485
16 Balance Transferred from Income (Account 433 less Account 418.1)140,659,705
17 Appropriations of Retained Earnings (Acct.436)
18
19
20
21
22 TOTAL Appropriations of Retained Eamings (Acct.436)
23 Dividends Declared-Preferred Stock (Account 437)
24 Various series and rates 238 -15,393,790
25
26
27
28
29 TOTAL Dividends Declared-Preferred Stock (Acct.437)-15,393,790
30 Dividends Declared-CommonStock (Account 438)
31 Commonstock 238 -390,045,282
32
33
34
35
36 TOTAL Dividends Declared-CommonStock (Acct.438)-390,045,282
37 Transfers from Acct 216.1,Unapprop.Undistrib.Subsidiary Earnings
38 Balance -End of Year (Total 1,9,15,16,22,29,36,37)904,484,295
FERC FORM NO.1 (ED.12-96)Page 118
Nameof Respondent I his Report is:Date ot Report Ýear ot Repod(1)An Original (Mo,Da,Yr)2000PacifiCorpDec.31,(2)A Resubmission //
6 I A I EMENI UI-Kb I AINi-U EARNINGS I-UR I Mb Y EAR
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.
Lille LOillra Pillriary ArtrouritNo.Item Account Affected(a)(b)(c)
APPROPRIATEDRETAINED EARNINGS (Account 215)
39
40
41
42
43
44
45 TOTAL Appropriated Retained Earnings (Account 215)
APPROP.RETAINEDEARNINGS-AMORT.Reserve,Federal (Account 215.1)
46 TOTAL Approp.Retained Earnings-Amort.Reserve,Federal (Acct.215.1)3,575,811
47 TOTAL Approp.Retained Earnings (Acct.215,215.1)(Total 45,46)3,575,811
48 TOTAL Retained Earnings (Account 215,215.1,216)(Total 38,47)908,060,106
UNAPPROPRIATEDUNDISTRIBUTEDSUBSIDIARY EARNINGS(Account 216.1)
49 Balance-Beginning of Year (Debit or Credit)-313,011,350
50 Equity in Earnings for Year (Credit)(Account 418.1)-145,756,923
51 (Less)Dividends Received (Debit)348,753,077
52
53 Balance-End of Year (Total lines 49 thru 52)-807,521,350
ERC FORM NO.1 (ED.12-96)Page 119
Name of Respondent I his Report is:Date of Report Year ot Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
blAIEMENI UI-UAbH I-Luvvb
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 Uesenpuun toee lustrucuan Wo.o lor exµ\anation of bodes)Amounts
No.(a)(b)
2 Net Income -5,097,218
3 Noncash Charges (Credits)to income:
4 Depreciation and Depletion 338,754,599
5 Amortization of 49.593.296
6
7
8 Deferred income Taxes (Net)-49,407,969
9 Investment Tax Credit Adjustment (Net)-7,999,368
10 Net (Increase)Decrease in Receivables -316,216,154
11 Net (Increase)Decrease in Inventory -9,235,030
12 Net (Increase)Decrease in Allowances inventory
13 Net Increase (Decrease)in Payables and Accrued Expenses 423,427,628
14 Net (Increase)Decrease in Other Regulatory Assets 68,162,758
15 Net Increase (Decrease)in Other Regulatory Liabilities -40,228,734
16 (Less)Allowance for Other Funds Used During Construction 4,356,322
17 (Less)Undistributed Eamings from Subsidiary Companies -494,510,000
18 Other:-127,714,993
19
20
21
22 Net Cash Provided by (Used in)Operating Activities (Total 2 thru 21)814,192,493
23
24 Cash Flows frorn Investment Activities:
25 Construction and Acquisition of Plant (including land):
26 Gross Additions to Utility Plant (less nuclear fuel)-355,702,584
27 Gross Additions to Nuclear Fuel
28 Gross Additions to Common Utility Plant
29 Gross Additions to Nonutility Plant
30 (Less)Allowanœ for Other Funds Used During Construction
31 Other:
32
33
34 Cash Outflows for Plant (Total of lines 26 thru 33)-355,702,584
35
36 Acquisition of Other Noncurrent Assets (d)
37 Proceeds from Disposal of Noncurrent Assets (d)313,328,337
38
39 Investments in and Advances to Assoc.and Subsidiary Companies 23,841
40 Contributions and Advanœs from Assoc.and Subsidiary Companies
41 Disposition of Investments in (and Advances to)
42 Associated and Subsidiary Companies
43
44 Purchase of Investment Securities (a)
45 Proceeds from Sales of Investment Securities (a)
ERC FORM NO.1 (ED.12-96)Page 120
Name of Respondent I his Report is:Date ot Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
S I A I EMt-NI Ul-CASH t-LUvvb
4.Investing Activities include at Other (line 31)net cash outflow to acquire other companies.Provide a reconciliation of assets acquired with liabilities
assumed on pages 122-123.Do not include on this statement the dollar amount of Leases capitalized per US of A General Instruction 20;instead
provide a reconciliation of the dollar amountof Leases capitalized with the plant cost on pages 122-123.
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.
urie Descriptiori aee Iristrucuon Wu.a for Exµlanation oi e odes)Amounts
No.(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 2,854,590
54
55
56 Net Cash Provided by (Used in)Investing Activities
57 Total of lines 34 thru 55)-39,495,816
58
59 Cash Flows from Financing Activities:
60 Proceeds from Issuance of:
61 Long-Term Debt (b)3,052,036
62 Preferred Stock
63 Common Stock
64 Other:
65
66 Net Increase in Short-Term Debt (c)
67 Other:
68
69
70 Cash Provided by Outside Sources (Total 61 thru 69)3,052,036
71
72 Paymentsfor Retirement of:
73 Long-term Debt (b)-343,977,591
74 Preferred Stock -5,550
75 Common Stock
76 Other:-185,178,992
77
78 Net Decrease in Short-Term Debt (c)124,701,785
79
80 Dividends on Preferred Stock -15,394,171
81 Dividends on Common Stock -311,875,385
82 Net Cash Provided by (Used in)Financing Activities
83 (Total of lines 70 thru 81)-728,677,868
84
85 Net Increase (Decrease)in Cash and Cash Equivalents
86 (Total of lines 22,57 and 83)46,018,809
87
88 Cash and Cash Equivalents at Beginning of Year -11,678,907
89
90 Cash and Cash Equivalents at End of Year 34,339,902
FERC FORM NO.1 (ED.12-96)Page 121
Name of Respondent I his Report ls:Date of Report Y ear of Report
PacifiCorp (1)An Original Dec.31,2000
(2)A Resubmission
NUlbb lUl-INANGIALblAlbMENlb
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.Fumish 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 involving possible 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 INTENTIONALLYLEFT BLANK
SEE PAGE 123 FOR REQUIRED INFORMATION.
FERC FORM NO.1 (ED.12-96)Page 122
Name of Respondent This Report is:Date of Report Year of Report
(1)X An Original (Mo,Da,Yr)
PacifiCorp (2)_A Resubmission //Dec 31,2000
NOTESTO FINANCIALSTATEMENTS (Continued)
See Supplemental Filing
FERC FORM NO.1 (ED.12-88)Page 123
Name of Respondent I his Report is:Date of Report Ÿear of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
SUMMARY UI-U I ILI lY PLAN l AND AGUUMULAl EU PKUVISIONS
FOR DEPRECIATION.AMORTI7.ATIONAND DEPLETION
Line Classification Total Electric
No.(a)(b)(c)
1 Utility Plant
3 Plant in Service (Classified)12,061,980,711 12,061,980,711
4 Property Under Capital Leases 27,208,365 27,208,365
5 Plant Purchased or Sold -151,184,605 -151,184,605
6 CompletedConstruction not Classified
7 Experimental Plant Unclassified
8 Total (3 thru 7)11,938,004,471 11,938,004,471
9 Leased to Others
10 Held for Future Use 2,831,111 2,831,111
11 Construction Work in Progress 265,681,606 265,681,606
12 Acquisition Adjustments 108,854,361 108,854,361
13 Total Utility Plant (8 thru 12)12,315,371,549 12,315,371,549
14 Accum Prov for Depr,Amort,&Depl 4,674,742,315 4,674,742,315
15 Net Utility Plant (13 less 14)7,640,629,234 7,640,629,234
16 Detail of Accum Prov for Depr,Amort &Depl
17 In Service:
18 Depreciation 4,490,133,529 4,490,133,529
19 Amort &Depi of Producing Nat Gas Land/Land Right
20 Amort of Underground Storage Land/Land Rights
21 Amort of Other Utility Plant 184,451,661 184,451,661
22 Total in Service (18 thru 21)4,674,585,190 4,674,585,190
23 Leased to Others
24 Depreciation
o I
Fut
roO eprs(2o4n
&25)
28 Depreciation 157,125 157,125
29 Amortization
30 Total Held for Future Use (28 &29)157,125 157,125
31 Abandonmentof Leases (Natural Gas)
32 Amort of Plant Acquisition Adj
33 Total Accum Prov (equals 14)(22,26,30,31,32)4,674,742,315 4,674,742,315
FERC FORM NO.1 (ED.12-89)Page 200
Name of Respondent I his Report is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
tiUMMAK Ul-U I ILI \Y PLAN \AND ACCUMULAlED PNOVISIONS
FOR DEPRECIATION.AMORTIZATIONAND DEPLETION
Gas Other (Specify)Other (Specify)Other (Specify)Common Line
(d)(e)(f)(g)(h)No.
1
3
4
5
6
7
8
9
10
11
12
13
14
15
17
18
19
21
22
24
25
26
27
28
29
30
32
33
FERC FORMNO.1 (ED.12-89)Page 201
Name of Respondent Ihis Report is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
ELEUI Klu PLAN I IN bEkvlui-(Account IU'l,U2,1Ud 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 Plantin Service (Classified),this page and the next include Account 102,Electric Plant Purchased or Sold;
Account 103,Experimental Electric Plant Unciassified;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 necessanj,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 unciassified 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 Balande Additions
No Beginning of Year
(a)(b)(c)
1 1.INTANGIBLE PLANT
2 (301)Organization 26,289,044 -881
3 (302)Franchises and Consents 12,716,060 161,576
4 (303)Miscellaneous Intangible Plant 357,215,239 41,159,730
5 TOTAL Intangible Plant (Enter Total of lines 2,3,and 4)396,220,343 41,320,425
6 2.PRODUCTION PLANT
7 A.Steam Production Plant
8 (310)Land and Land Rights Ë0,906,651 2,246
9 (311)Structures and improvements 769,132,393 2,098,134
10 (312)Boiler Plant Equipment 2,433,549,977 28,300,086
11 (313)Engines and Engine-Driven Generators
12 (314)Turbogenerator Units 683,983,307 12,973,059
13 (315)Accessory Electric Equipment 322,209,141 435,155
14 (316)Misc.Power Plant Equipment 31,137,931 72,838
15 TOTAL Steam Production Plant (Enter Total of lines 8 thru 14)4,320,919,400 43,881,518
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 17,551,086
26 (331)Structures and Improvements 71,370,581 105,776
27 (332)Reservoirs,Dams,and Waterways 250,653,624 3,206,906
28 (333)Water Wheels,Turbines,and Generators 70,227,579 2,670,427
29 (334)Accessonj Electric Equipment 26,814,072 785,013
30 (335)Misc.Power PLant Equipment 3,083,995 551,280
31 (336)Roads,Railroads,and Bridges 10,859,671 188,677
32 TOTAL Hydraulic Production Plant (Enter Total of lines 25 thru 31)450,560,608 7,508,079
33 D.Other Production Plant
34 (340)Land and Land Rights 842,880
35 (341)Structures and Improvements 11,224,005
36 (342)Fuel Holders,Products,and Accessories 3,210,083
37 (343)Prime Movers 94,719,851
38 (344)Generators 80,351,537 -83,325
39 (345)Accessory Electric Equipment 9,274,455
FERC FORM NO.1 (ED.12-95)Page 204
Name of Respondent I his Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
ELEC I RIC PLAN I IN SERVICE(Account 101,102,1 J3 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 of
year.
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 amounts initially recorded in Account 102,include in column (e)the amounts with respect to accumulated
provision for depreciation,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 amount submit a supplementary statement showing
subaccount classification of such plant conforming to the requirement of these pages.
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 joumal entries have been filed with the Commissionas required by the Uniform System of Accounts,give also date
of such filing.
Retirements Adjustments I ransfers balance at Line
(d)(e)(f)End f Year No.
1
26,288,163 2
12,877,636 3
29,601,619 -23,058 -889,718 367,860,574 4
222,324 -741,546 79,945,027 8
19,382,735 -6,639,492 745,208,300 9
115,669,906 424 128,257 2,346,308,838 10
11
59,852,931 275,540 637,378,975 12
8,251,821 -204,967 314,187,508 13
688,896 -96,137 30,425,736 14
204,068,613 424 -7,278,345 4,153,454,384 15
16
17
18
19
20
21
22
23
24
9,443 755,081 18,296,724 25
947,476 72,423,833 26
5,117,403 258,977,933 27
72,898,006 28
27,599,085 29
3,635,275 30
199,204 11,247,552 31
9,443 7,019,164 465,078,408 32
33
842,880 34
11,224,005 35
3,210,083 36
94,719,851 37
80,268,212 38
9,274,455 39
FERC FORM NO.1 (ED.12-95)Page 205
Name of Respondent I his Report is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
ELECl RIC PLAN I IN SERVIUb (Account 101,1U2,1 )3 and 10ti)(Continued)
Line ACóóunt Balàñóe Additioñá
No.Beginning of Year
(a)(b)(c)
40 (346)Misc.Power Plant Equipment 534,784
41 TOTAL Other Prod.Plant (Enter Total of lines 34 thru 40)200,157,595 -83,325
42 TOTAL Prod.Plant (Enter Total of lines 15,23,32,and 41)4,971,637,603 51,306,272
43 3.TRANSMISSIONPLANT
44 (350)Land and Land Rights 87,002,28 146,414
45 (352)Structures and Improvements 48,365,430 635,793
46 (353)Station Equipment 717,836,959 11,447,589
47 (354)Towers and Fixtures 340,627,640 497,921
48 (355)Poles and Fixtures 378,617,957 17,459,843
49 (356)Overhead Conductors and Devices 548,254,257 14,120,455
50 (357)Underground Conduit 2,012,226 2,416
51 (358)Underground Conductors and Devices 2,309,754 6,461
52 (359)Roads and Trails 10,913,118 56,196
53 TOTAL Transmission Plant (Enter Total of lines 44 thru 52)2,135,939,626 44,373,088
54 4.DISTRIBUTIONPLANT
55 (360)Land and Land Rights 27,677,443 709,423
56 (361)Structures and Improvements 30,089,936 729,436
57 (362)Station Equipment 471,953,874 12,653,450
58 (363)Storage Battery Equipment
59 (364)Poles,Towers,and Fixtures 623,953,955 34,069,598
60 (365)Overhead Conductors and Devices 487,097,597 18,870,389
61 (366)Underground Conduit 192,703,306 11,027,072
62 (367)Underground Conductors and Devices 424,131,729 27,122,748
63 (368)Line Transformers 703,837,976 39,283,091
64 (369)Services 249,048,659 33,103,227
65 (370)Meters 175,795,400 4,119,196
66 (371)Installations on Customer Premises 8,742,130 343,896
67 (372)Leased Property on Customer Premises 49,658
68 (373)Street Lighting and Signal Systems 43,677,883 3,907,238
69 TOTAL Distribution Plant (Enter Total of lines 55 thru 68)3,438,759,546 185,938,764
70 5.GENERALPLANT
71 (389)Land and Land Rights 14,510,483
72 (390)Structures and Improvements 189,750,458 5,539,729
73 (391)Office Fumiture and Equipment 104,998,964 9,150,526
74 (392)Transportation Equipment 65,055,373 5,426,188
75 (393)Stores Equipment 9,252,382 90,971
76 (394)Tools,Shop and Garage Equipment 42,266,972 1,731,546
77 (395)Laboratory Equipment 31,221,919 808,342
78 (396)Power Operated Equipment 89,677,696 9,992,133
79 (397)CommunicationEquipment 178,841,872 4,604,082
80 (398)Miscellaneous Equipment 4,755,494 -749,580
81 SUBTOTAL(Enter Total of lines 71 thru 80)730,331,613 36,593,937
82 (399)Other Tangible Property 437,898,638 5,524,114
83 TOTAL General Plant (Enter Total of lines 81 and 82)1,168,230,251 42,118,051
84 TOTAL (Accounts 101 and 106)12,110,787,369 365,056,600
85 (102)Electric Plant Purchased (See instr.8)
86 (Less)(102)Electric Plant Sold (See Instr.8)-22,291,085
87 (103)Experimental Plant Unclassified
88 TOTAL Electric Plantin Service (Enter Total of lines 84 thru 87)12,110,787,369 387,347,685
FERC FORMNO.1 (ED.12-95)Page 206
Name ot Respondent I his Report is LJate of Report Year of Report
PacifiCorp (1)An O iginal (Mo,Da,Yr)Dec.31,2000(2)A Reiubmission //
ELECl RIC PLAN I IN SbkVICE (Account 101,102,1 33 and 106)(Continued)
Retirements Adjustments I ransfers Balance at Line
(d)(e)(f)End f Year No.
534,784 40
200,074,270 41
204,078,056 424 -259,181 4,818,607,062 42
43
284,869 359,991 87,223,821 44
2,622 -5,469,523 43,529,078 45
6,462,070 6,720,906 729,543,384 46
158,757 -3,823 340,962,981 47
1,793,794 394,284,006 48
748,821 561,625,891 49
2,014,642 50
2,316,215 51
10,969,314 52
9,450,933 1,607,551 2,172,469,332 53
54
17,929 -2,259,980 26,108,957 55
49,643 612,590 31,382,319 56
4,985,655 1,000,000 108,455 480,730,124 57
58
10,959,663 647,063,890 59
11,378,750 494,589,236 60
256,005 203,474,373 61
1,314,246 449,940,231 62
8,403,722 -476 734,716,869 63
1,091,724 281,060,162 64
6,591,469 -9,983 173,313,144 65
254,156 8,831,870 66
49,658 67
692,011 46,893,110 68
45,994,973 989,541 -1,538,935 3,578,153,943 69
70
-4,447 14,506,036 71
709,878 194,580,309 72
13,214,500 -122,541 -6,617 100,805,832 73
3,854,892 15,417 66,642,086 74
131,435 9,211,918 75
630,601 -1,232 38,329 43,405,014 76
135,725 -611 31,893,925 77
9,494,093 -1,930 90,173,806 78
1,158,000 -457,392 169,494 182,000,056 79
96,859 903,886 4,812,941 80
29,425,983 -581,165 1,113,521 738,031,923 81
95,728,394 -2,280 347,692,078 82
125,154,377 -583,445 1,113,521 1,085,724,001 83
414,279,958 383,462 33,238 12,061,980,711 84
85
-173,475,690 151,184,605 86
87
587,755,648 383,462 33,238 11,910,796,106 88
FERC FORM NO.1 (ED.12-95)Page 207
Name of Respondent I hrs Report is:Date of Report Year of Report(1)An Original (Mo,Da,Yr)PacifiCorp (2)A Resubmission //Dec.31,2000
ELECl RIG PLAN I HELD FUN I-U l UNE Ubb (Account 10b)
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 Unginally includea Date spected to be used balance atNo.Of Prooerty in This Account in Utility Service End of Year(a)(b)(c)(d)
2
3 NORTH HORNMOUNTAIN COAL PROPERTIES 010175 925,014
4 SOUTHEASTSUBSTATION 010175 273,612
5
6
7
8
9 MISCELLANEOUS,EACH UNDER $250,000 1,142,932
10
11
12
13
14
15
16
17
18
19
20
21 Other Property:
22
23 EASEMENTS-SWIFT/TROUTDALE L17 010171 341,349
24
25 MISCELLANEOUS,EACH UNDER $250,000 148,204
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46
47 Total 2,831,111
FERCFORM NO.1 (ED.12-96)Page 214
Nameof Respondent I his Report is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
GUNS I RUG l luN WORK IN PRUL,REbd --ELEu i NIC Account 101)
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 bescription of Project Construction work in progress -
No.Electric (Account 107)(a)(b)
1 Distribution:
2 Oguirrh #2:New 138-12.5kV Xfmr (30 MVA)1,624,804
3 A.F.-NEW SUB-138/12.5KV-138KV 30MVA 1,138,625
4 Summit Crk Sub:Build New 138-12.5KV Sub 1,329,361
5 SO Mtn Sub:Install new 138-12.5KV,30 M 1,679,889
6 Parkway Sub:Install 2ND 138 12.5KV XFMR 1,460,732
7 Willowridge:Install 46/12.5KV,14 MVA X 1,003,653
8
9 Intangible:
10 Legal costs for Hydro Re-licensing 1,058,537
11 Yale Relicensing 4,718,470
12 LR-Merwin License Contract-Billable 1,269,782
13 nc LR Relicensing-Lands Purchase 2,070,601
14 North Umpqua Relicensing 34,228,540
15 Powerdale Relicensing 2,363,116
16
17 Production:
18 Blundell Purchase Steam Path 1,187,688
19 Cholla Betterments Common 1,253,021
20 Cholla common-Coal Handling/RR Redesign 2,824,812
21
22 Transmission:
23 Klamath Co-Gen:500kV Line Protection 1,199,103
24 Tri Cities-American Fork 138/46 KV LINE 1,585,683
25 Tri City -New 138KV Switchrack 1,331,865
26 Lone Pine Sub-Install New 230KV Line POS 2,189,523
27 A/B Ln Rebid:RoseparkTap N to Riverdale 6,770,084
28 Grace-Goshen 161 Ln Collect ROW Funds 1,138,631
29 PR McFadden-Blackhawk 138KV Line 1,217,025
30 Alpowa 230kV Ln -Pole Replacements 1,091,603
31
32 Miscellaneous Projects each under $1,000,000 189,946,458
33
34
35
36
37
38
39
40
41
42
43 TOTAL 265,681,606
FERC FORM NO.1 (ED.12-87)Page 216
Name of Respondent I nis Report Is:Date of Report Year of Report(1)Q An Original (Mo,Da,Yr)Pacifi Corp (2)A Resubmission //Dec.31,2000
uuWS\kUUlluNuvERHEADS-ELEUlRIU
1.List n 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 ca >italizedshould be shown as separate items.2.On Page 218 fumish information conceming construction overheads.3.A respondent should not report "none"to the páge if no
overhead apportionments are made,but rather should explain on Page 218 the accounting procedures,employed and the amounts of engineering,supervision and administrative costs,
etc.wl ich are directly charged to construction.4.Enter on this page engineering,supervision,administrative,and allowanœfor 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 Allowance for funds used during construction 13,565,871
2
3 Construction Overheads 32,929,349
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 46,495,220
FERC FORMNO.1 (ED.12-89)Page 217
Name ot Respondent I his Report is:Date of Report Year ot keport
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
GENERALUb5CRIP I lUN UE GUNSI RUG l lUN UVbKHEAU PROUbUUNE
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 theoverheadisdirectlyorindirectlyassigned.
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.
General Administration:
Represents salaries and expenses of a general administrative nature chargable to capital expenditures.
These expenses are accumulated in specific cost centers related to business areas and are distributed on a pro
rata basis to construction jobs.
COMPUTATIONOF 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.Componentsof Formula (Derived from actual book balances and actual cost rates):
Line Title Amount Capitalization Cost RateNo.Ratio(Percent)Percentage
(a)(b)(c)(d)
1 Average Short-Term Debt &S 193,034,308
Computationof Allowance text
2 Short-term interest s 6.17
3 Long-Term Debt D 3,727,996,803 48.03 d 7.14
4 Preferred Stock P 216,493,200 2.79 p 6.06
5 Common Equity C 3,816,938,049 49.18 c 11.08
6 Total Capitalization 7,761,428,052 100.00 100%
7 Average Construction Work in W 295,460,895
Progress Balance
2.Gross Rate for Borrowed Funds S D S
s (_)+d(__._)(1 -_)5.22WD+P+C W
3.Rate for Other Funds
[1 -][p()+c (
C )]1.95
W D+P+C D+P+C
4.Weighted Average Rate Actually Used for the Year:
a.Rate for Borrowed Funds -5.22
b.Rate for Other Funds -1.95
FERC FORM NO.1 (ED.12-88)Page 218
Name of Respondent I his Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
AUGUMULAI BU PRUVlòlUN 1-UR UbPHbclAI lUN OF bLED I RIC Ul ILI lY PLAN I (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 tentativelyfunctionalize 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 (hanges During Year
Line lleill latal Eleoliiu Plant in Eleullic Fielil Held Elecuiu PianL
N (c+o+e)Service for Future Use Leased to Others
(a)(b)(c)(d)(e)
1 Balance Beginning of Year 4,434,372,449 4,434,218,640 153,80E
2 Depreciation Provisions for Year,Charged to
3 (403)Depreciation Expense 349,605,656 349,602,340 3,316
4 (413)Exp.of Elec.PIt.Leas.to Others
5 Transportation Expenses-Clearing
6 Other Clearing Accounts
7 Other Accounts (Specify):1,054,327 1,054,327
8 Account 151 -Fuel Stock 17,955,830 17,955,830
9 TOTAL Deprec.Prov for Year (Enter Total of 368,615,813 368,612,497 3,316
lines 3 thru 8)
10 Net Charges for Plant Retired:
11 Book Cost of Plant Retired 382,287,230 382,287,230
12 Cost of Removal 13,553,553 13,553,553
13 Salvage (Credit)5,252,618 5,252,618
14 TOTAL Net Chrgs.for Plant Ret.(Enter Total 390,588,165 390,588,165
of lines 11 thru 13)
15 Other Debit or Cr.Items (Describe):77,890,558 77,890,558
16
17 Balance End of Year (Enter Totals of lines 1,4,490,290,655 4,490,133,530 157,125
9,14,15,and 16)
Section E .Balances at End of Yet r According to Functional Classification
18 Steam Production 1,867,577,742 1,867,577,742
19 Nuclear Production
20 Hydraulic Production-Conventional 188,101,080 188,101,080
21 Hydraulic Production-PumpedStorage
22 Other Production 26,004,587 26,004,587
23 Transmission 765,941,899 765,784,774 157,125
24 Distribution 1,197,444,801 1,197,444,801
25 General 445,220,545 445,220,545
26 TOTAL (Enter Total of lines 18 thru 25)4,490,290,654 4,490,133,529 157,12E
FERC FORM NO.1 (ED.12-88)Page 219
Name of Respondent I his Report Is:Date of Report Year of Report(1)An Original (Mo,Da,Yr)PacifiCorp (2)A Resubmission //Dec.31,2000
NUNUi ILI lY PRUPI-R I Y (ACCOUni 1¿1)
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.Fumish 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 devoted
to public service (Line 44),or (2)other Nonutility property (Line 45).
Line Description and Location balance of Begining Purchases,Sales,Balance at Gnd
No.of Year Transfers,etc.of Year(a)(b)(c)(d)
1 NAUGHTONNO 4 STEAM ELECTRIC STATION 930,908 930,908
2 HUNTERNO 1 STEAM ELECTRICSTATION 783,042 783,042
3 AXTELL PROJECT 265,000 265,000
4 WELLINGTONPROJECT 712,583 712,583
5 DELTA-FILLMORERAILROAD RIGHT OF WAY 157,000 157,000
6 FUTURELAKE DISTRICT SERVICE CENTER SITE 150,000 150,000
7 GARFIELDCOAL PROPERTIES 191,074 -191,074
8 TIMP DISTRICTSERVICECENTER AND OFFICE 688,650 688,650
9 REED RANCH 282,937 282,937
10 COOS BAY DISTRICTOFFICE 301,380 301,380
11 ALBANY OFFICE -N.C.S.T.116,985 116,985
12 JUNCTION CITY DISTRICT 166,076 166,076
13 NORTH CANAL PROJECT 226,320 226,320
14 SIMPLE CHOICE LICENSINGFEE 4,277,946 4,277,946
15 MADRAS DISTRICTOFFICE 345,542 345,542
16 LAND -DRY CREEK SITE 408,205 408,205
17 ROSEBURGDISTRICTOFFICE 156,960 -156,960
18 CENTRALIACOAL MINE -NON-RATE BASE 62,965,416 -62,965,416
19 CENTRALIACOAL MINE (DRAGLINE)6,448,412 -6,448,412
20 CENTRALIAMINE (WIDCO PURCHASE)2,561,474 -2,561,474
21 LAND -DECKERPROJECTWYOMING 314,390 314,390
22 COPCO#1 HYDRO NONUTILITY 960,377 960,377
23 CHERRYWOODSUB NONUTILITY 202,096 202,096
24
25
26
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 756,220 -24,620 731,600
45 Minor Items-Other Nonutility Property 813,870 -19,657 794,213
46 TOTAL 85,182,863 -72,367,613 12,815,250
ERC FORM NO.1 (ED.12-95)Page 221
Name of Respondent I his Report is:Date of Report Year ot Report
PacifiCorp R su
malssion (Mo,Da,Yr)Dec.31,2000
INVESI M :N I S IN SUtdSIDIARY 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)InvestmentAdvances -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 eamings since acquisition.The TOTAL in column (e)should equal the amount entered for
Account 418.1.
Line Uescnption of Investment Date Acquired Date Ut Amount of lovestment át
No (a)(b)Mat rity Begin g of Year
1
2 PACIFICORP GROUP HOLDINGS COMPANY
3 Common Stock 99,483,436
4 Capital Contributions 2,919,883
5 Equity in Earnings 894,944,150
6 SUBTOTAL 997,347,469
7
8 PACIFIC POWER&LIGHT COMPANY
9 Common Stock 100
10 SUBTOTAL 100
11
12 CENTRALIA MININGCOMPANY
13 Capital Contributions 1,000
14 SUBTOTAL 1,000
15
16 ENERGY WEST
17 Capital Contributions 1,000
18 SUBTOTAL 1,000
19
20 PMI-BRIDGER COAL
21 Common Stock 1
22 Capital Contribution 43,873,920
23 SUBTOTAL 43,873,921
24
25 GLENROCK COAL
26 Common Stock 1
27 SUBTOTAL 1
28
29 PACIFICORP POWER MARKETING
30 Capital Contributions
31 Equity in Earnings
32 SUBTOTAL
33
34 INTERWEST MINING
35 Common Stock 1,000
36 SUBTOTAL 1,000
37
38 PACIFIC KLAMATH ENERGY
39 Capital Contributions
40 Equity in Earnings
41 SUBTOTAL
42 otal Cost of Account 123.1 $lU I AL 1,054,708,537
FER(:FORM NO.1 (ED.12-89)Page 224
Name ot Respondent I his Report Is:Date of Report Year ot Report
PacifiCorp
)R u
malssion (Mo,Da,Yr)
Dec.31,2000
INVt-S I MEN I S IN SUdblUIARY CUMPANit-8 (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 pledgee
and purpose of the pledge.
5.If Commissionapproval 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 bubstolary Revenues for Y ear Amount of investment at L,ain or Loss from investment LineEarninsofYearEndfYearDispsedofNo.
1
2
99,483,436 3
2,919,883 4
-153,126,756 -350,033,626 391,783,768 5
-153,126,756 -350,033,626 494,187,087 6
7
8
100 9
100 10
11
12
-1,000 13
-1,000 14
15
16
1,000 17
1,000 18
19
20
1 21
15,932,314 59,806,234 22
15,932,314 59,806,235 23
24
25
1 26
1 27
28
29
-3,728,721 -3,728,721 30
5,219,740 5,219,740 31
5,219,740 -3,728,721 1,491,019 32
33
34
1,000 35
1,000 36
37
38
5,009,270 5,009,270 39
-137,805 -137,805 40
-137,805 5,009,270 4,871,465 41
-145,756,922 -333,698,055 575,253,560 42
FERC FORM NO.1 (ED.12-89)Page 225
Name of Respondent I his Report is:Date ot keport Year of Report(1)An Original (Mo,Da,Yr)PacifiCorp (2)A Resubmission //Dec.31,2000
INVbb i MbN I S IN SUBSIDIARY COMPANibb Account 123.1)
1.Report below investments in Accounts 123.1,investments in Subsidianj 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 eamings since acquisition.The TOTAL in column (e)should equal the amount entered for
Account 418.1.
une description of Investment Date Acquired Date Ut Amount of investmeñt et
Matunty Beginning of YearNo(a)(b)(c)(d)
1
2 PACIFICORPCAPITAL l
3 Capital Contributions 6,712,000
4 Equity in Earnings
5 SUBTOTAL 6,712,000
6
7 PACIFICORPCAPITALII
8 Capital Contributions 4,176,000
9 Equity in Earnings
10 SUBTOTAL 4,176,000
11
12 PACIFICORP INVESTMENTMANAGEMENTINC.
13 Capital Contributions 100,000
14 Equity in Earnings 17,313
15 SUBTOTAL 117,313
16
17 PACIFICORP ENVIRONMENTALREMEDIATIONCOMPANY
18 Capital Contributions 900,000
19 Equity in Earnings 1,577,733
20 SUBTOTAL 2,477,733
21
22 PFS ACQUISITION CORP.
23 Common Stock 1,000
24 SUBTOTAL 1,000
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42 l otal Cost of Account 123.1 $U \0 \AL 1,054,708,537
FEROFORM NO.1 (ED.12-89)Page 224.1
Nameot Respondent I his Report Is:Date ot Report Vear of Report
PacifiCorp R u
malssion (Mo/,Da,Yr)
Dec.31,2000
1NVbb I MbN I J IN SUBSIDIARY CUMPANik-8 (Account 1D.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 pledgee
and purpose of the pledge.
5.If Commissionapproval 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 adjustment
includible in column (f).
8.Report on Line 42,column (a)the TOTAL cost of Account 123.1
equity in buosidiary Nevenues for y ear Amount of investment at eam or Loss from Investment LineEaminsofYearEndfYearDispsedofNo.
1
2
6,712,000 3
553,740 -553,740 4
553,740 -553,740 6,712,000 5
6
7
4,176,000 8
321,552 -321,552 9
321,552 -321,552 4,176,000 10
11
12
100,000 13
4,166 21,479 14
4,166 121,479 15
16
17
900,000 18
1,408,441 2,986,174 19
1,408,441 3,886,174 20
21
22
-1,000 23
-1,000 24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
-145,756,922 -333,698,055 575,253,560 42
FERC FORM NO.1 (ED.12-89)Page 225.1
Name of Respondent I his Report is:Date of Report Year of Report
PacifiCorp R su
malssion (Mo,Da,Yr)
Dec.31,2000
MATERIALSAND 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 materialand 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)51,809,164 53,541,066 Electric
2 Fuel Stock Expenses Undistributed (Account 152)
3 Residuals and Extracted Products (Account 153)
4 Plant Materials and Operating Supplies (Account 154)
5 Assigned to -Construction (Estimated)33,250,372 30,568,693 Electric
6 Assigned to -Operations and Maintenance
7 Production Plant (Estimated)45,559,695 43,530,193 Electric
8 Transmission Plant (Estimated)2,128,852 2,404,930 Electric
9 Distribution Plant (Estimated)9,687,700 10,621,715 Electric
10 Assigned to -Other 14,010,153 6,233,692 Electric
11 TOTAL Account 154 (Enter Total of lines 5 thru 10)104,636,772 93,359,223
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)
16
17
18
19
20 TOTAL Materials and Supplies (Per Balance Sheet)156,445,936 146,900,289
FERC FORM NO.1 (ED.12-96)Page 227
BLANK PAGE
(Next Page is:228)
Name of Respondent I his Report is:Date ot keport Year of Report
PacifiCorp R su
malssion (Mo/,Da,Yr)
Dec.31,2000
Allowances (Accounts 158.1 and 158.2)
1.Report below the particulars (details)called for concerning allowances.
2.Report all acquisitions of allowances at cost.
3.Report allowances in accordance with a weighted average cost allocation method and other accounting as prescribed by General
Instruction No.21 in the Uniform System of Accounts.
4.Report the allowances transactions by the period they are first eligible for use:the current year's allowances in columns (b)-(c),
allowances for the three succeeding years in columns (d)-(i),starting with the following year,and allowances for the remaining
succeeding years in columns (j)-(k).
5.Report on line 4 the Environmental Protection Agency (EPA)issued allowances.Report withheld portions Lines 36-40.
Line Allowances Inventory Current Year 2001
No.(Account 158.1)No.AmL No.AmL(a)(b)(c)(d)(e)
194,636.00 170,231.00
4 Issued (Less Withheld Allow)121.00 121.00
5 Returned by EPA
6
8 Purchases/Transfers:
9 APS 5,000.00
10
11
12
13
14
15 Total 5,000.00
16
18 Charges to Account 509 91,701.00
19 Other:
20
21 Cost of Sales/Transfers:
22 Centralia 32,478.0 18,718.00
23 Koch Carbon 15,000.0
24 PSE&G 15,000.0
25 AEP 26,476.0
26 Aquila 5,000.0
27 APS
28 Total 93,954.0 18,718.00
29 Balance-End of Year 14,102.0 151,634.00
30
32 Net Sales Proceeds(Assoc.Co.)
33 Net Sales Proceeds (Other)93,954.00 18,718.00
34 Gains 93,954.00 18,718.00
35 Losses
Allowances Withheld (Acct 158.2)
36 Balance-Beginning of Year 2,546.00 2,546.00
37 Add:Withheld by EPA
38 Deduct:Retumed by EPA
39 Cost of Sales 2,546.00 288.00
40 Balance-End of Year 2,258.00
41
43 Net Sales Proceeds (Assoc.Co.)
44 Net Sales Proceeds (Other)2,546.00 288.00
45 Gains 2,546.00 288.00
46 Losses
"ERC FORM NO.1 (ED.12-95)Page 228
me o espon 90 ear o ep
PacifiCorp (1)An Original (Mo,Da,Yr)
(2)A Resubmission //Dec.31,2000
Allowances (Accounts 158.1 and 158.2)(Continued)
6.Report on Lines 5 allowances returned by the EPA.Report on Line 39 the EPA's sales of the withheld allowances.Report on -Lines
43-46 the net sales proceeds and gains/losses resulting from the EPA's sale or auction of the withheld allowances.
7.Report on Lines 8-14 the names of vendors/transferors of allowances acquire and identify associated companies (See "associated
company"under "Definitions"in the Uniform System of Accounts).
8.Report on Lines 22 -27 the name of purchasers/transferees of allowances disposed of an identify associated companies.
9.Report the net costs and benefits of hedging transactions on a separate line under purchases/transfers and sales/transfers.
10.Report on Lines 32-35 and 43-46 the net sales proceeds and gains or losses from allowance sales.
2002 2003 FutureYears Totals Line
No.
(f)(g)(h)(i)(j)(k).(I)(m)
46
FERC FORM NO.1 (ED.12-95)Page 229
Nameof Respondent I his keport Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
EX I RAORDINARY PROPERI Y LOSJES (Account 182.1)
oe [InDcudc the deEs
t th a es
A R Losses WRITTEN OFF DURINGYEAR Balance at
aCndm oo r aaton
(o yer oc o Losns Duen
g
eeadr Den 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
Nameot Respondent I his Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
UN RECOVEREDPLAN I AND RI-GULATO (YS I UDY COS I S (182.2)
Line Description of Unrecovered Plant Total Costs WRITTEN OFF DURING YEAR BalanceatNo.and Regulatory Study Costs [Include Amount 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 Unrecovered plant:Trojan Nuclear 21,031,086 1,717,019 407 3,572,889 19,175,216
22 Plant located near Portland,OR
23 Date of retirement:12/31/92
24 Date of Commission Authorization:
25 4/20/1993
26 Amortization period:1/93 through
27 1/2011
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46
47
48
49 TOTAL 21,031,086 1,717,019 3,572,889 19,175,216
FERC FORM NO.1 (ED.12-88)Page 230b
Name of Respondent I his Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000
(2)A Resubmission //
U HERREUULAIURY AbbeIb(Account \62.3)
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.IVinor 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 YearCharged
(a).(b)(c)(d)(e)
1 DEMAND SIDE RESOURCES:
2 STATE OF OREGON:
3 Weatherization Amort 0%(10)177,588 124,734
4 Weatherization Amort 0%(30)9,756 278,802 142,654
5 Weatherization Amod 0%(5)83,885 19,222
6 Irrigation Ditch to Pipe (15)3,592 1,796
7 Irrigation (15)282,182 141,091
8 Irrigation (5)2,764 1,446
9 Energy Efficient Showerheads (10)414 620
10 Energy Efficient Showerheads (12)3,059,218 1,529,609
11 Energy Efficient Showerheads (5)333,160 164,113
12 DSM R&D Technology (16)1,262 631
13 Water Heater Solar (16)173 87
14 Weatherization Amort 6.5%(10)3 384,408 242,742
15 Weatherization Amori 6%(30)246,115 123,058
16 Weatherization Amort 6%(5)49,253 39,475
17 Green Lights (16)3,076 1,538
18 Major Customer Accounts (15)38,897 19,449
19 Major Customer Accounts (5)28,047 18,346
20 Meter Info -Service Pilot (16)4,727 2,364
21 Market Transformation (16)63,734 31,785
22 Market Transformation (5)7,338 3,669
23 Small Retrofit (16)456,627 568,478 586,660
24 Small Retrofit (5)293,262 251,502
25 Energy Finanswer Operation Service (16)11,844 5,922
26
27 Northwest Energy Efficiency Alliance 763,133 763,128
28 Commercial Codes (16)100,499 50,249
29
30 Energy Excellence (10)74,866
31 School Efficiency Partner (10)3,661
32 Energy Finanswer Schools (16)1,829 914
33 Industrial Partners (10)252,737 4,374
34 Low income (10)362,971 242,231
35 Low Income (30)596,824 298,412
36 Low Income (5)298,453 249,133
37 Manufactured Housing (10)224,517 326,672
38 Manufactured Housing (50)4,574,965 2,287,482
39 Manufactured Housing (5)7,585 3,793
40 ResidentialAppliances (10)39,713
41 Commercial Lost Opportunities (10)2
42 Commercial Lighting Demo (10)37,294
43 Pacific Environments (15)1,404 702
44 TOTAL 262,282,142 137,133,615 887,390,222
-ERC FORM NO.1 (ED.12-94)Page 232
Name of kespondent I his Report is:IJate of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
U HERktbULAIURYAbbblb(Account IBÄ.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.F3r regulatory assets being amortized,show period of amortization in column (a)
3.W inor 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 OREDITS Balanæ at
No.Other Regulatory Assets Account Amount End of YearCharged
(a)(b)(c)(d)(e)
1 DEMAND SIDE RESOURCES:(cont'd)
2 STATEOF OREGON (cont'd)
3 Pacific Environments (15)288,195 871,628
4 Home Comfort (15)69,151 202,856
5 Home Comfort (30)18,960 9,480
6 Technology Monitoring &Analysis (10)4,890 4,135
7 Technology Monitoring &Analysis (16)15,855 7,927
8 Hasslefree Efficiency Acquisition (10)96,963 48,482
9 Hasslefree Efficiency Acquisition (15)130,858 104,546
10 Hasslefree Efficiency Acquisition (5)74,559 67,910
11 Self Audit -1999-2000 (1)4,823 658 5,079
12 Energy Finanswer (5)448,894 85,607
13 Energy Finanswer (16)2,312,752 1,022,381
14 Competitive Bidding (10)7,801 6,882
15 Low Income Competitive Bidding (10)8,979 13,469
16 Residential Building Codes (50)16,610 8,305
17 Residential Building Codes (10)10,469 9,975
18 RFP Low Income (30)3,019,150 731,274
19 RFP Low Income (5)266,680 206,970
20 Energy Partners (15)28,237 84,712
21 Industrial Finanswer 1992-99 (15)179,860 648,809
22 Industrial Finanswer 1993-1999 (15)1,495,530 676,625
23 Industrial Finanswer 1996-1998 (5)309,080 253,493
24 Technology Assessment 608 304
25 NehemiahWeatherization (10)1,686,792 3,742
26 Large Commercial Bldg Retrofit (10)324,829 186,973
27 Large Commercial Bldg Retrofit (5)16,716 11,729
28 Large Commercial Bldg Retrofit (16)1,971 792,499 397,156
29 DSM Other Programs (16)175,705 87,853
30 DSM Other Programs (5)19,625 10,891
31 Energy Finanswer 12,000 (10)69,335 86,813
32 Energy Finanswer 12,000 (16)227,764 113,882
33 Econs (5)5
34 RFP General (5)292 144
35
36 E.Rated Appliance (5)920 460
37 Home Comfort (5)5 567
38 Conservation for Wholesale (10)4,931 4,931
39 Manufactured Acquisition (10)195,371 195,371
40 Home Comfort Analysis (10)5,362 5,362
41 ESC Loans in GAWL (10)3,423 3,423
42 Super Efficient Refrigerator (10)2,267 1,621
43 Super Efficient Refrigerator (15)53,621 20,743
44 TOTAL 262,282,142 137,133,615 887,390,222
ERC °ORM NO.1 (ED.12-94)Page 232.1
Nameof Respondent lhis Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000
(2)A Resubmission //
U HERRabULA I URY Abbi-I b (Account 16A.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 OREDITS Balance at
No.Other Regulatory Assets Account Amount End of YearCharged
(a)(b)(c)(d)(e)
1 DEMANDSIDERESOURCES:(cont'd)
2 STATEOF OREGON(cont'd)
3 Super Efficient Refrigerator (5)2,514 1,482
4 Regional Energy Management (16)921 461
5 Program Development &Support (16)2,096 1,048
6 Load Studies (10)2,245 3,368
7 Load Studies (16)17,074 8,537
8 Super Good Cents (10)3,347,249 2,251,820
9 Super Good Cents (5)179,501 154,600
10 Super Good Cents (50)4,874,241 2,434,779
11 H-Pro Energy Efficiency (10)41,337 62,005
12 H-Pro Energy Efficiency (5)13,968 6,984
13 H-Pro Energy Efficiency (15)432,983 216,491
14 New Construction Super Good Cents (10)72,273 108,409
15 New Construction Super Good Cents (50)18,686 9,343
16 Energy Finanswer Light Pro Network (10)5
17 Energy Finanswer Light Pro Network (16)2,454 1,227
18 Irrigation (10)3,644 5,465
19 Irrigation (15)2,045 1,023
20 Super Good Cents Home Improvement (30)15,346 7,673
21 NW Compfl Bulb,OR 1995 (15)29,377 11,964
22 NW Compfl Bulb,OR 1995 (5)2,724 1,743 872
23 HIP Supplementary Measures (30)42,999 21,499
24 HIP Rebate Weatherization (30)648,948 570,882
25 HIP Rebate Weatherization (5)225,090 601,927 282,182
26 DSR Carrying Charges 891,973 16,086,775 -13,472,097
27 DSR Deferred Amortization 18,079,771 58,785 42,634,630
28
29
30 DSR Oregon DSM Expense-Deferred 420,914
31 Merger Stipulation 147,278 49,028 147,278
32
33
34
35
36
37
38
39
40
41
42
43
44 TOTAL 262,282,142 137,133,615 887,390,222
¯ERC FORMNO.1 (ED.12-94)Page 232.2
Name of Respondent I his Report is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
U HER RI-bULA I URY Abbt lb (Account 162.3)
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.F3r regulatory assets being amortized,show period of amortization in column (a)
3.IV inor 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 YearCharged
(a).(b)(c)(d)(e)
1 DEMANDSIDE RESOURCES:(cont'd)
2 STATE OF IDAHO
3 Idaho Weatherization 631 2,841
4 Super Good Cents 256,556 1,154,559
5 Weatherization 158,591 713,661
6 Low Income Program 33,590 41,431 223,637
7 Cash Grant 54,791 246,560
8 Weather Loans 99 578
9 Early Loan Payoff Program 115,873 521,428
10 Irrigation Rebate 1,171 5,268
11 Regional Mobile Home (MAP)16,261 226,202 944,736
12 Technology Monitoring 886 3,986
13 Hasslefree Efficiency Acquisition 3,089 5,669 30,684
14 Energy Finanswer 6,251 46,056 214,479
15 Major Customer 389 1,749
16 Industrial Finanswer 7,566 5,504 33,653
17 CommercialRetrofit 196 629
18 Energy Finanswer 12,000 2,607 11,732
19 Consentation for Wholesale 723 3,252
20 Manufactured Acquisition 10,155 45,697
21 Home Comfort Analysis 696 3,132
22 Super Efficient Refrigerator 33,497 163,791
23 Regional Energy Management 104 467
24 Program Development &Support 207 930
25 Load Studies 2,033 9,151
26 Interest Bearing Variable 8 36
27 Energy Finanswer Light Pro Network 3 11
28 Irrigation 3,723 16,753
29 Self Audit -1998 763 24 991
30 DSM Other Programs 2,316 10,422
31 DSR Market Research 2,623 11,802
32 Northwest Energy Efficiency Alliance 13,069 58,809
33 DSR Deferred Net Lost Revenue 557,593 2,509,167
34 Low income Bid 313,873 32,215 668,243
35
36
37
38
39
40
41
42
43
44 TOTAL 262,282,142 137,133,615 887,390,222
FERC FORM NO.1 (ED.12-94)Page 232.3
Name of Respondent I his Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000
(2)A Resubmission //
U HER RebULA I URY AbbE I b (Account 182.3)
1.Raport 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.Ivinor 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 YearCharged
(a)-(b)(c)(d)(e)
1 DEMAND SIDE RESOURCES:(cont'd)
2 STATE OF CALIFORNIA
3 Super Good Cents -Mobile Home (10)17,880 17,880
4 Weatherization Amort 0%(10)5,452 4,100
5 Weatherization Amort Cash Rebate (10)1,954
6 Weatherization Amort Winter Saver (10)1 41,308
7 Low Income Direct Weather (10)153,843 203,059
8
9 Hasslefree Efficiency Acquisition (10)10,121 11,499
10 Energy Finanswer (10)20,414 22,298
11 ESC Loans in GAWL (10)330 330
12 Industrial Finanswer (10)194 290
13 Energy Finanswer 12,000 (10)151 151
14 Water Heater Rebate (10)3,666 884
15 Heat Pump Water Heater Rebate (10)31
16 Regional Mobile Home (MAP)(10)89,194 162,428
17 Crescent City Hydronic Eval (10)6,493
18 Home Comfort Analysis (10)57,522 99,466
19 Manufactured Homes -HUD (10)21,452 17,704
20 Home Comfort (10)1,720 860
21 Irrigation (10)60,278 87,823
22 Super Efficient Refrigerator (10)96 96
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44 TOTAL 262,282,142 137,133,615 887,390,222
ERCFORM NO.1 (ED.12-94)Page 232.4
Name of Respondent I his Heport Is:Date ot Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
U HERkt-bULAIURY AbbEIb (Account la2.d)
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 I Balanœ at
No.Other Regulatory Assets Account Amount End of YearCharged(a)-(b)(c)(d)(e)
1 DEMAND SIDE RESOURCES:(cont'd)
2 STATE OF UTAH
3 Super Good Cents (10)41,261 37,678
4 Energy Partners (15)16,235 48,706
5 Industrial Finanswer (15)155,825 709,910
6 Existing Commercial Buildings (15)12,077 39,421
7 Commercial Retrofit (15)4,918 23,094
8 Low Income Weatherization (10)118,996 220,959
9 RFP Resource Acquisition (10)16,229 16,229
10 RFP CES/WAY (10)171,584 455,350
11 Green Lights (10)492
12 Major Customer Accounts (10)59,899 138,776
13 DSR Commercial Codes (10)1,116 2,492
14 Utah Schedule 5 (10)13,434 27,159
15 RFP Low income (10)1,805 5,414
16 RFP General (10)673 336
17 Technology Monitoring (10)13,542 20,314
18 Energy Finanswer (15)461,002 2,035,343
19 Energy Efficient Showerheads (10)4,048 4,986
20 Commercial Competitive Bidding (15)39,218 156,873
21 Commercial Retrofit (15)1,571 6,284
22 Energy Finanswer 12,000 (15)39,765 154,054
23 Conservation for Wholesale (15)3,815 13,352
24 Home Comfort Analysis (10)5,666 5,666
25 Energy Finanswer Schools,IJT (10)341 854
26 Super Efficient Refrigerator (10)33,403 65,242
27 Regional Energy Management (10)755 1,132
28 Program Development &Support (10)1,499 2,248
29 Load Studies (10)14,749 22,124
30 Market Research,UT (10)2,348 5,870
31 Energy Finanswer Light Pro Network (10)1,932 2,897
32 Heat Pump (H Pro)(10)2,018 5,032
33 DSM Other Programs (10)14,530 35,263
34 ECONS (10)572,419 1,158,896
35 RFP EUA Onsite (10)431,478 1,124,369
36 DSR Carrying Charges 7,087 29,843 64,334
37 DSR Deferred Net Lost Revenue 392,116 1,455,353
38
39
40
41
42
43
44 TOTAL 262,282,142 137,133,615 887,390,222
ERC FORM NO.1 (ED.12-94)Page 232.5
Name ot Respondent I his Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000
(2)A Resubmission //
U HERRt-bULAl URY Abbe I b (Account 182.3)
1.Raport 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.Winor 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 Arnount End of YearCharged
(a).(b)(c)(d)(e)
1 DEMANDSIDERESOURCES:(cont'd)
2 STATEOF WYOMING -PPL
3 Super Good Cents (10)119,541 287,782
4 Major Customer Accounts (10)8,632 22,749
5 Energy Finanswer (10)8,310 57,591 154,206
6 MAP WY-P (10)1,390 -4,169
7
8 Industrial Finanswer (10)25,447 8,063 63,607
9 Market Transformation 1
10 Commercial Retrofit (10)279 616 850
11 Energy Finanswer 12,000 (10)8,949 11,590
12 Super Efficient Refrigerator (10)3,620 7,269
13 Self Audit (10)1,154 108 1,154
14
15 STATE OF WYOMING -UPL
16 Super Good Cents (10)4,914 8,982
17 Major Customer Accounts (10)10,562 20,273
18 RFP General (10)3
19 Super Efficient Refrigerator (10)491 762
20 Energy Finanswer (10)4,118 8,514
21 Industrial Finanswer (10)28,848 100,574
22 Energy Finanswer 12,000 (10)900 900
23 DSR Deferred Net Lost Revenue 118,709 551,442
24
25
26
27
28 STATE OF WASHINGTON
29 Energy Finanswer 9,324 9,324
30 Industrial Finanswer 52,495 52,495
31 Low income 51,282 51,282
32 Self Audit 302 302
33 CommercialSmall Retrofit 954 954
34 CommercialRetrofit Lighting 954 954
35 NEEA 112,464 112,464
36 Hasslefree 1,660 1,660
37
38
39
40
41
42
43
44 TOTAL 262,282,142 137,133,615 887,390,222
¯ERC FORM NO.1 (ED.12-94)Page 232.6
Name of Respondent I his Report Is:lJate of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000
(2)A Resubmission //
U HL-R REGULAl URY Abbt-I b (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.F3r regulatory assets being amortized,show period of amortization in column (a)
3.IV inor 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 YearCharged(a).(b)(c)(d)(e)
1 OTHER REGULATORYASSETS -COST-OTHER:
2
3 FAS 106 Regulatory Asset Deferrals
4 Wyoming PP&L 1,144,788 2,281,694
5 Wyoming UP&L 361,512 730,956
6
7 FAS 109 income Tax Regulatory Assets 282 37,037,732 594,232,960
8
9 FAS 88/89 Deferred Pension Costs 88,919,308
10 FAS 88/89 Deferred Pension Costs -CA GEN -1,185,677
11 FAS 88/89 Deferred Pension Costs -MT GEN -846,635
12 FAS 88/89 Deferred Pension Costs Write Down -86,886,996
13
14 EnvironmentalCost under Amortization 2,147,529 925 4,863,553 15,946,608
15
16 Oregon Direct Access 423,141 397,643 267,543
17
18 IDAl Costs -No Calif -Direct Access 569 569 1,665,523
19
20 Non-cost -California Generation 24,934 1,918 -381,676
21 Non-cost -Montana Generation 22,997 1,769 -351,956
22 FAS 109 Inc Tax Regulatory Asset -CA Gen -10,252,815
23 FAS 109 Inc Tax Regulatory Asset -MT Gen -9,589,686
24
25 Pittsburgh &Midway Arbitration 56,427 923 733,554
26
27
28 OTHER REGULATORYASSETS -NON-COSTS-
29 Provision for Disallowed Colstrip 3 -Washington 4,349 456 56,537 1,048,139
30
31 Cholla Plant Transaction 93,535 557 1,215,960 18,613,550
32 Cholla Contract Review 16,548 923 215,120 397,144
33
34 Retail Access Project 4,342,493 749,593 3,592,900
35 Transition Costs -Retirement&Displacement 174,494,026 26,754,584 147,739,442
36 Glenrock Mine Reclamation97 -UT 5,943,700 921 1,342,126 4,601,574
37 Y2K Expense 98-00 -UT 2,277,986 921 1,237,936 1,040,050
38 ComputerMainframe Writedown 97 -UT 2,178,458 921 491,910 1,686,548
39 Early Retirement98 -UT 9,453,085 921 2,087,045 7,366,040
40 FAS 87/88 Pension -UT 23,166,103 930.2 1,053,005 22,113,098
41 Y2K Expense 98-00 -OR 1,141,801 930.2 67,165 1,074,636
42 Deferred Excess Net Power Costs -WY 16,019,933 557 16,019,933
43
44 TOTAL 262,282,142 137,133,615 887,390,222
FERC FORM NO.1 (ED.12-94)Page 232.7
Name of Respondent I his Report Is:Date of keport Year ot Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
M SUELLANt-UUd DEFFERED Ubbi lo (Account 16b)
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 wu Amount End of Year
(a)(b)(c)((e)(f)
1 Bonneville Power Administration
2 Balancing Account 1,635,209 17,418,664 18,720,537 333,336
3
4 Water assessment payment to
5 Emery Water Conservancy
6 District (Amortization Period
7 12 months)290,489 160,627 129,862
8
9 Mill Fork tract mine rights
10 lease payments 25,216,689 25,216,689
11
12 California property taxes
13 (amortized over 6 months)932,403 864,389 932,919 863,873
14
15 Joseph Hydro Buyout 2,472,854 125,932 2,346,922
16
17 Idaho Customer Balancing
18 Account -920,802 6,304,806 5,616,949 -232,945
19
20 Cove Hydro Projects -Amortized
21 through 12-18-2001 10,307 416 5,104 5,619
22
23 Firth Cogeneration Buyout 2,563,732 55,194 482,486 2,136,440
24
25 Lacomb Irrigation 1,005,840 41,910 963,930
26
27 Option purchases 193,400 252,200 -58,800
28
29 Property damage repairs -
30 insurance losses 237,019 941,236 1,245,391 -67,136
31
32 Sales of Electric Utility
33 Facilities and Properties 1,019,891 2,934,651 2,979,506 975,036
34
35 Bogus Creek 1,651,200 37,840 1,613,360
36 Bogus Creek settlement -708,000 118,000 -590,000
37
38 Halsey MillCogeneration Option 347,846 26,061 224,889 149,018
39
40 Intangible Pension Asset:
41 SERP Plan 2,472,096 992,904 3,465,000
42 Prepaid CMC Pension
43
44 Marathon Oil -Elec/Gas swap -905,245 7,533,504 6,628,259
45
46 Business Energy Tax Credit:
47 Misc.Work in Progress
48 Deterred Reguletóry Gótnin.
Expenses (See pages 350 -351)
49 TOTAL 93,461,703 91,322,557
FERC FORM NO.1 (ED.12-94)Page 233
Name of Respondent I his Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
M bubLLANeuUS DEhebkED DEsl I s (Account 166)
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 u Amount End of Year
(a)(b)(c)(d (e)(f)
1 Super Good Cents 46,069 38,820 7,249
2 Weatherization Loan Program 9,942 8,232 4,908 13,266
3 Loan Program 577 528 49
4 Energy Finanswer 44,647 39,660 4,987
5 Industrial Finanswer 36,641 26,988 9,653
6 Finanswer 4,403 4,405 -2
7 Cash Rebate/Incentive 250,494 247,127 105,420 392,201
8 Commercial Retrofit 108,990 99,276 9,714
9 Low income Weatherization 8,645 4,320 4,325
10
11 Deferred Coal Mine Costs:
12 Centralia Mining Company
13 Centralia Deferred Stripping 8,338,579 104,077 8,442,656
14 Dave Johnston Mine/Glenrock
15 Coal Company -deferred
16 stripping costs 1,708,914 412,116 2,218,584 -97,554
17 Trail Mountain Exploration
18 costs 1,263,034 1,263,034
19
20 Centralia Mining Company/
21 Energy West Management
22 Labor 10,336 142,020 146,553 5,803
23
24 Centralia Deferred Box Cut -
25 Kopiah 3,068,347 30,405 3,098,752
26
27 Tri-State Firm Wheeling 5,120,820 971,190 4,149,630
28
29 Mead Phoenix Availability
30 &Trans Charge 17,880,640 346,280 17,534,360
31
32 Financing Costs Deferred 962,618 26,056 403,655 585,019
33
34 Environmental Deferred -26,854 26,854
35
36 Clark Firm Transmission 3,574,718 2,069,574 1,505,144
37
38 Garfield Negotiations 1,046,345 5,175,917 6,222,262
39
40 Biomass COD Prepayment 1,015,471 21,606 485,552 551,525
41
42 Buffalo Buyout 218,353 41,412 176,941
43
44 Lakeview Buyout 393,125 3,607 46,887 349,845
45
46 TGS Buyout 297,606 624 14,166 284,064
47 Misc.Work in Progress
48 Deterred Regulatory bomm.
Expenses (See pages 350 -351)
49 TOTAL 93,461,703 91,322,557
FERC FORM NO.1 (ED.12-94)Page 233.1
Nameof Respondent I his Report is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
Ivl subLLANEUUb DabeëK D DEbl I b (Account 16b)
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 ea""Amount End of Year
(a)(b)(c)(Ë (e)(f)
1
2 Hermiston Swap 8,947,913 44,965 584,537 8,408,341
3
4 Hydrologic Assessment 72,533 72,533
5
6 Deferred Longwall Costs 213,546 1,938,261 1,491,532 660,275
7
8 Transition Costs -Washington 16,684,641 1,129,013 15,555,628
9
10 Hayden Settlement 2,140,401 496,264 1,644,137
11
12 BETC Retrofit 145,561 145,561
13
14 Northwest Power Pool 20,736 1,910,919 1,843,436 88,219
15
16 Other Deferred Debits with
17 Amounts less than $50,000 131,934 2,132,986 1,516,514 748,406
18
19 Miscellaneous deferred charges 1,468,142 138,811 1,606,953
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41 Misc.Work In Progress
42 DEFERRED REGULATORYCOMM.
43
44
45
46
47 Misc.Work in Progress
48 Ueterred Regulatory Comm.
Expenses (See pages 350 -351)
FERC FORMNO.1 (ED.12-94)Page 233.2
Name of Respondent I his Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
AGUUlvibLAl EU UEH-kkt-U INuulvlE I AAt-o (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 Desenption and Location balance of begining balance at end
No of Year of Year(a)(b)(c)
2 Bond Refinancing 1,273,719 299,103
3 Deferred Compensation 7,205,493 305,913
4 Bad Debt 6,914,085 2,993,526
5 Obsolete Parts 7,738,031 3,323,048
6 Cholla/GEContract Amortization 18,504,712 20,603,144
7 Other 160,468,969 178,386,675
8|TOTAL Electric (Enter Total of lines 2 thru 7)202,105,009 205,911,409
10
11
12
13
14
15 Other
16 TOTAL Gas (Enter Total of lines 10 thru 15
17 Other (Specify)12,875,889 12,419,978
18 TOTAL (Acct 190)(Total of lines 8,16 and 17)214,980,898 218,331,387
Notes
FERC FORMNO.1 (ED.12-88)Page 234
Name of Respondent I his Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
UAPI \AL S I UUKb (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 Ôlass and Šeries of Štock and Number of shares Par or Štated Öall Price at
No.Name of Stock Series Authorized by Charter Value per share End of Year
(a)(b)(c)(d)
1 Common Stock (Account 201)750,000,000
2 (PacifiCorp is a fully owned subsidiary of
3 ScottishPower)
4
5
6 TOTAL_COMMONSTOCK 750,000,000
7
8
9 Preferred Stock (Account 204):
10 5%Cumulative Preferred (American Stock Exch.)126,533 100.00 110.00
11 Serial Preferred,Cumulative:3,500,000
12 4.52%Series 100.00 103.50
13 7.00%Series 100.00
14 6.00%Series 100.00
15 5.00%Series 100.00 100.00
16 5.40%Series 100.00 101.00
17 4.72%Series 100.00 103.50
18 4.56%Series 100.00 102.34
19
20 No Par Serial Preferred,Cumulative:16,000,000
21 $7.70 Series 100.00
22 $7.48 Series 100.00
23
24 TOTAL_PREFERREDSTOCK 19,626,533
25
26
27
28
29
30
31
32
33
34
35 Authorized and unissued Capital Stock
36
37
38
39
40
41
42
FERCFORM NO.1 (ED.12-91)Page 250
Name of Respondent I his Report is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
GAPI I AL bl UUKb (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 commission
which have not yet been issued.
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 which
is pledged,stating name of pledgee and purposes of pledge.
OU I S iANDING PER BALANCE SHEl-)HL-LD BY RE-E PONDEN I Line(Total amount outstanding without reduction
for amounts held by respondent)AS REACQUIRED STOCK(Account 217)IN SINKING AND OTHERFUNDS No.
bnares Amount chares bost bnares Amount(e)(f)(g)(h)(i)(j)
297,324,604 3,350,185,742 1
2
3
4
5
297,324,604 3,350,185,742 6
7
8
9
126,243 12,624,300 10
11
2,065 206,500 12
18,046 1,804,600 13
5,930 593,000 14
41,908 4,190,800 15
65,959 6,595,900 16
69,890 6,989,000 17
84,592 8,459,200 18
19
20
1,000,000 100,000,000 21
750,000 75,000,000 22
23
2,164,633 216,463,300 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 I his Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000
(2)A Resubmission //
UldCOUNI UN UAPI I AL blUUK (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 Glass and benOS Ol LOCK balance at end ol i ear
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
Name of Respondent I his Report is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
JAPI I AL bluuK APENSE (Accoun ¿14)
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-off of capital stock expense and specify the account charged.
une Glass arid series el atocK Balarice at brid of year
No.(a)(b)
1 Common Stock 41,093,938
2
3 Preferred Stock:
4 5.00%Serial 98,049
5 4.52%Serial 9,676
6 4.72%Serial 30,349
7 4.56%Serial 49,071
8 $7.70 Serial 911,507
9 $1.98 Serial 765,979
10 $7.48 Serial 840,433
11
12
13
14
15
16
17
18
19
20
21
22 TOTAL 43,799,002
FERC FORM NO.1 (ED.12-87)Page 254b
Name of Respondent I his Report is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
LONb-I ERM ubb I (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,cedificates,show in column (a)the name of the court -and date of court order under which such certificates wereissued.
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,Óoupon Rate Principal Amount Total expense,
No.(For new issue,give commission Authorization numbers and dates)Of Debt issued Premium or Discount
(a)(b)(c)
1 Bonds (Account 221):
2 First Mortgage Bonds:
3 6-3/4%Series due April 1,2005 150,000,000 1,177,203
4 196,500 D
5 5.650%Series due November 1,2006 200,000,000 6,185,966
6 670,000 D
7 8.271%Series due October 1,2010 48,972,000
8 7.978%Series due October 1,2011 4,422,000
9 8.493%Series due October 1,2012 19,772,000
10 8.797%Series due October 1,2013 16,203,000
11 8.734%Series due October 1,2014 28,218,000
12 8.294%Series due October 1,2015 46,946,000
13 8.635%Series due October 1,2016 18,750,000
14 8.470%Series due October 1,2017 19,609,000
15
16 First Mortgage and Collateral Trust Bonds:
17 7.21%Series E Medium-TermNotes due Jan.19,2000 25,000,000 152,068
18 7.11%Series E Medium-TermNotes due Jan.20,2000 10,000,000 60,827
19 7.13%Series E Medium-TermNotes due Jan.20,2000 10,000,000 60,827
20 7.07%Series E Medium-TermNotes due Jan.25,2000 10,500,000 63,869
21 6.99%Series E Medium-TermNotes due Jan.25,2000 10,000,000 60,827
22 6.97%Series E Medium-TermNotes due Jan.28,2000 1,000,000 6,083
23 5.85%Series F Medium-TermNotes due Apr.17,2000 3,000,000 21,442
24 5.85%Series F Medium-TermNotes due Apr.17,2000 3,000,000 21,442
25 5.85%Series F Medium-TermNotes due Apr.17,2000 5,000,000 35,737
26 5.85%Series F Medium-TermNotes due Apr.17,2000 5,000,000 35,737
27 6.05%Series F Medium-TermNotes due Apr.17,2000 15,000,000 107,211
28 6.05%Series F Medium-TermNotes due Apr.17,2000 15,000,000 107,211
29 6.05%Series F Medium-TermNotes due Apr.17,2000 25,000,000 178,686
30 6.05%Series F Medium-TermNotes due Apr.17,2000 5,000,000 35,737
31 6.86%Series E Medium-TermNotes due Sept.11,2000 10,000,000 72,648
32 6.55%Series E Medium-TermNotes due Sept.15,2000 5,000,000 36,324
33 TOTAL 3,794,425,925 62,200,628
FERCFORM NO.1 (ED.12-96)Page 256
Name of Respondent I his Report is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
LUNU-I ERM ul-8 I (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,Premium
on Debt -Credit.
12.In a footnote,give explanatory (details)for Accounts 223 and 224 of net changes during the year.With respect to long-term
advances,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 pledgee
and purpose of the pledge.
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 interest
expense in column (i).Explain in a footnote any difference between the total of column (i)and the total of Account 427,interest on
Long-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.
Afv10RTIZATION PEklOD Ouladtidlig--LineNominalDateDateof(Total amount outstandmhewithout Interest for Year
of Issue Maturity Date From Date To reductionr srpamoenn Id by Amount No.
(d)(e)(f)(g)Îhnd
1
2
040193 040105 040193 040105 150,000,000 10,125,000 3
4
110698 110106 110698 110106 200,000,000 11,300,000 5
6
041592 100110 041592 100110 34,118,000 2,955,084 7
041592 100111 041592 100111 3,164,000 262,955 8
041592 100112 041592 100112 14,887,000 1,309,069 9
041592 100113 041592 100113 12,642,000 1,145,963 10
041592 100114 041592 100114 22,551,000 2,022,794 11
041592 100115 041592 100115 38,010,000 3,231,114 12
041592 100116 041592 100116 15,587,000 1,374,951 13
041592 100117 041592 100117 16,533,000 1,427,788 14
15
16
011993 011900 011993 011900 90,125 17
012093 012000 012093 012000 37,525 18
012093 012000 012093 012000 37,631 19
012293 012500 012293 012500 49,490 20
012593 012500 012593 012500 46,600 21
012893 012800 012893 012800 5,228 22
080293 041700 080293 041700 51,675 23
080293 041700 080293 041700 51,675 24
080293 041700 080293 041700 86,125 25
080293 041700 080293 041700 86,125 26
081393 041700 081393 041700 267,208 27
081393 041700 081393 041700 267,208 28
081393 041700 081393 041700 445,347 29
081393 041700 081393 041700 89,069 30
091092 091100 091092 091100 476,389 31
091692 091500 091692 091500 231,069 32
3,387,251,593 242,798,222 33
FERC FORM NO.1 (ED.12-96)Page 257
Name of Respondent I his Report is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
L JNU-I ERM Ubb i (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 Þrincipal Amount Total expense,
No.(For new issue,give commissionAuthorization numbers and dates)Of Debt issued Premiumor Discount
(a)(b)(c)
1 8.90%Series B Medium-Term Notes due Feb.15,2001 20,000,000 174,297
2 8.90%Series B Medium-Term Notes due Feb.15,2001 20,000,000 174,297
3 8.88%Series B Medium-Term Notes due Feb.15,2001 20,000,000 174,297
4 8.90%Series B Medium-Term Notes due Feb.15,2001 20,000,000 169,297
5 9.10%Series A Medium-Term Notes due March 1,2001 5,000,000 30,114
6 6.02%Series F Medium-TermNotes due May 15,2001 4,500,000 34,413
7 9.12%Series C Medium-TermNotes due July 5,2001 5,000,000 40,830
8 9.12%Series C Medium-TermNotes due July 5,2001 10,000,000 81,659
9 9.06%Series B Medium-Term Notes due July 9,2001 1,000,000 6,018
10 9.15%Series C Medium-TermNotes due July 16,2001 3,000,000 24,498
11 9.17%Series B Medium-Term Notes due July 17,2001 1,000,000 6,268
12 9.06%Series C Medium-TermNotes due July 23,2001 1,000,000 8,166
13 9.09%Series C Medium-TermNotes due July 24,2001 1,000,000 8,166
14 9.10%Series C Medium-TermNotes due July 30,2001 5,000,000 40,830
15 7.50%Series E Medium-TermNotes due Aug.1,2001 2,000,000 12,598
16 8.99%Series C Medium-TermNotes due Aug.7,2001 3,000,000 24,498
17 9.00%Series C Medium-TermNotes due Aug.8,2001 500,000 4,083
18 9.00%Series B Medium-TermNotes due Aug.8,2001 2,500,000 15,669
19 7.20%Series D Medium-TermNotes due Aug.15,2002 12,000,000 76,552
20 7.20%Series D Medium-TermNotes due Aug.15,2002 6,500,000 41,466
21 7.20%Series D Medium-TermNotes due Aug.15,2002 10,000,000 63,793
22 7.20%Series D Medium-Term Notes due Aug.15,2002 6,000,000 38,276
23 7.18%Series D Medium-Term Notes due Aug.15,2002 10,000,000 63,793
24 7.18%Series D Medium-Term Notes due Aug.15,2002 3,500,000 22,328
25 7.12%Series D Medium-Term Notes due Aug.15,2002 4,000,000 25,517
26 7.25%Series E Medium-TermNotes due Sept.9,2002 20,000,000 150,295
27 7.25%Series E Medium-TermNotes due Sept.9,2002 20,000,000 150,295
28 7.21%Series E Medium-TermNotes due Sept.9,2002 10,000,000 75,148
29 7.14%Series E Medium-TermNotes due Sept.10,2002 1,500,000 11,272
30 6.98%Series E Medium-TermNotes due Sept.16,2002 10,000,000 75,148
31 6.97%Series E Medium-TermNotes due Sept.16,2002 2,000,000 15,030
32 6.95%Series E Medium-TermNotes due Sept.16,2002 10,000,000 75,148
33 TOTAL 3,794,425,925 62,200,628
FERCFORM NO.1 (ED.12-96)Page 256.1
Nanvaotkespondent Irvskepodls:Dateotkepod YearotRepod
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
LUNG-1 ERM DES I (Account 221,222,223 and 224)(Gontinued)
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 Account429,Premium
on Debt-Credit.
12.In a footnote,give explanatory (details)for Accounts 223 and 224 of net changes during the year.With respect to long-terrn
advances,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 pledgee
and purpose ofthe pledge.
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 interest
expense in column (i).Explain in a footnote any difference between the total of column (i)and the total of Account 427,interest on
Long-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.
AMORllZAi lON Pl-RIOD QUtolaliuillM--LineNominalDateDateof(Total arnount outstanainhewithout Interest for Year
of Issue Maturity Date From Date To reductionr srpao eunts Id by Amount No.
(d)(e)(0 (g)(h)(i)
021291 021501 021291 021501 20,000,DOO 1,780,000 1
021291 021501 021291 021501 20,000,000 1,780,000 2
021291 021501 021291 021501 20,000;DOO 1,776,000 3
021391 021501 021391 021501 20,000,000 1,780,000 4
062591 030101 062591 030101 5,000,DOO 455,000 5
072793 051501 072793 051501 4,500,000 270,900 6
070591 070501 070591 070501 5,000,000 456,000 7
070591 070501 070591 070501 10,000,000 912,000 8
070991 070901 070991 070901 1,000,000 90,600 9
071691 071601 071691 071601 3,000,000 274,500 10
071791 071701 071791 071701 1,000,000 91,700 11
072391 072301 072391 072301 1,000,000 90,600 12
072491 072401 072491 072401 1,000,000 90,900 13
073091 073001 073091 073001 5,000,000 455,DOO 14
110692 080101 110692 080101 2,000,000 150,DOO 15
080791 080701 080791 080701 3,000,000 269,700 16
080891 080801 080891 080801 500,000 45,000 17
080891 080801 080891 080801 2,500,000 225,000 18
081492 081502 081492 081502 12,000,000 BEA,000 19
081492 081502 081492 081502 6,500,000 468,000 20
081492 081502 081492 081502 10,000,000 720,000 21
081492 081502 081492 081502 6,000,000 432,000 22
081492 081502 081492 081502 10,000,000 718,000 23
081492 081502 081492 081502 3,500,000 251,300 24
081492 081502 081492 081502 4,000,000 284,800 25
090892 090902 090892 090902 20,000,000 1,450,000 26
090492 090902 090492 090902 20,000,000 1,450,000 27
090992 090902 090992 090902 10,000,000 721,000 28
091092 091002 091092 091002 1,500,000 107,100 29
091592 091602 091592 091602 10,000,000 698,000 30
091592 091602 091592 091602 2,000,000 139,400 31
091692 091602 091692 091602 1CI,000,000 695,000 32
3,387,251,593 242,798,222 33
FERC FORMNO.1 (ED.12-96)Page 257.1
Name of Respondent I his Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
L JNU-l ERM DEBi (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 Ólass and Šeries of Obligation,Coupon Rate PrincipalAmount Yotal expense,
No.(For new issue,give commission Authorization numbers and dates)Of Debt issued Premiumor Discount
(a)(b)(c)
1 7.00%Series E Medium-Term Notes due Sept.17,2002 1,000,000 7,515
2 6.97%Series E Medium-Term Notes due Sept.23,2002 1,500,000 11,272
3 7.40%Series E Medium-Term Notes due Jan.22,2003 1,000,000 6,333
4 7.36%Series E Medium-Term Notes due Jan.27,2003 3,000,000 18,998
5 6.34%Series F Medium-Term Notes due July 28,2003 19,000,000 150,051
6 6.34%Series F Medium-Term Notes due July 28,2003 4,000,000 31,590
7 6.34%Series F Medium-Term Notes due July 28,2003 2,000,000 15,795
8 6.34%Series F Medium-Term Notes due July 28,2003 2,000,000 15,795
9 6.34%Series F Medium-Term Notes due July 28,2003 10,000,000 78,974
10 6.31%Series F Medium-Term Notes due July 28,2003 6,000,000 47,385
11 6.31%Series F Medium-Term Notes due July 28,2003 18,000,000 142,154
12 6.31%Series F Medium-Term Notes due July 28,2003 18,000,000 142,154
13 6.31%Series F Medium-Term Notes due July 28,2003 1,000,000 7,897
14 9.00%Series C Medium-Term Notes due Sept.1,2003 55,226,000 63,366
15 7.03%Series E Medium-Term Notes due Oct.15,2003 5,000,000 33,788
16 7.27%Series E Medium-Term Notes due Oct.21,2003 2,000,000 13,515
17 7.39%Series E Medium-Term Notes due Oct.21,2003 5,000,000 33,788
18 7.30%Series E Medium-Term Notes due Oct.22,2003 2,000,000 13,515
19 7.86%Series D Medium-Term Notes due Feb.16,2004 2,500,000 21,110
20 7.81%Series D Medium-Term Notes due Feb.16,2004 20,000,000 168,880
21 7.79%Series D Medium-Term Notes due Feb.16,2004 6,000,000 50,664
22 7.75%Series D Medium-Term Notes due Feb.16,2004 3,000,000 25,332
23 6.75%Series H Medium-Term Notes due Jul.15,2004 175,000,000 2,680,166
24 500,500 D
25 7.32%Series E Medium-Term Notes due Sept.3,2004 7,500,000 56,361
26 7.11%Series E Medium-Term Notes due Sept.24,2004 6,500,000 48,846
27 7.30%Series E Medium-Term Notes due Oct.22,2004 10,000,000 67,576
28 7.30%Series E Medium-Term Notes due Oct.22,2004 10,000,000 67,576
29 7.66%Series E Medium-Term Notes due Oct.22,2004 5,000,000 32,745
30 7.53%Series E Medium-Term Notes due Oct.26,2004 750,000 5,068
31 7.71%Series E Medium-Term Notes due Oct.27,2004 3,000,000 20,273
32 7.71%Series E Medium-Term Notes due Oct.27,2004 3,250,000 21,962
33 TOTAL 3,794,425,925 62,200,628
FERC FORMNO.1 (ED.12-96)Page 256.2
NanseotRespondent Ilmskepodis:Dateotkepon Yearotkepod
PacifCorça (1)An Onginal (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
LUNo-ll-RMUEBl(Account221,222,223and224)(Gontinued)
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,Premium
on Debt-Credit.
12.In a footnote,give explanatory (details)for Accounts 223 and 224 of net changes during the year.With respect to long-term
advances,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 pledgee
and purpose ofthe pledge.
14.If the respondent has any long-term debt securities which have been nominally issued and are nominally outstanding at end of
year,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 interest
expense in column (i).Explain in a footnote any difference between the total of column (i)and the total of Account 427,interest on
Long-Term Debt and Account430,Interest on Debt to Associated Companies.
16.Give particulars (details)concerning any long-term debt authorized by a regulatory commission but not yet issued.
AMORil/ATIONPERIOD ÙUlbidildilig·-LineNominalDateDateof(Total amount outstanaing without Interest for Year
of Issue Maturity Date From Date To reductionr sr amoenn held by Amount No.
(d)(e)(1)(g)
ind
091792 091702 091792 091702 1,000,000 70,000 1
092192 092302 092192 092302 1,500,000 104,550 2
012293 012203 012293 012203 1,000,000 74,000 3
012693 012703 012693 012703 3,000,000 220,800 4
072893 072803 072893 072803 19,000,000 1,204,600 5
072893 072803 072893 072803 4,000,000 253,600 6
072893 072803 072893 072803 2,000,000 126,800 7
072893 072803 072893 072803 2,000,000 126,800 8
072193 072803 072193 072803 10,000,000 634,000 9
072893 072803 072893 072803 6,000,000 378,600 10
072893 072803 072893 072803 18,000,000 1,135,800 11
072893 072803 072893 072803 18,000,000 1,135,800 12
072893 072803 072893 072803 1,000,000 63,100 13
061091 090103 061091 090103 12,861,733 1,312,398 14
101592 101503 101592 101503 5,000,000 351,500 15
102192 102103 102192 102103 2,000,000 145,400 16
102192 102103 102192 102103 5,000,000 369,500 17
102292 102203 102292 102203 2,000,000 146,000 18
021492 021604 021492 021604 2,500,000 196,500 19
021492 021604 021492 021604 20,000,000 1,562,000 20
021492 021604 021492 021604 6,000,000 467,400 21
021492 021604 021492 021604 3,000,000 232,500 22
071597 071504 071597 071504 175,DOO,000 11,812,500 23
24
090492 090304 090492 090304 7,500,000 549,000 25
092492 092404 092492 092404 6,500,000 462,150 26
102292 102204 102292 102204 10,000,000 730,000 27
102292 102204 102292 102204 10,000,000 730,000 28
110692 102204 110692 102204 5,000,000 383,000 29
102692 102604 102692 102604 750,000 56,475 30
102792 102704 102792 102704 3,000,000 231,300 31
102792 102704 102792 102704 3,250,000 250,575 32
3,387,251,593 242,798,222 33
FERC FORM NO.1 (ED.12-96)Page 257.2
Name of Respondent lhis Report is:Date of Report Year ot keport
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
LUNU-I ERM IJEBI (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 Ölass and Series of Obligation,Óoupon Rate Principal Amount Total expense,
No.(For new issue,give commission Authorization numbers and dates)Of Debt issued Premiumor Discount
(a)(b)(c)
1 7.60%Series E Medium-TermNotes due Nov.1,2004 1,000,000 6,549
2 7.72%Series E Medium-TermNotes due Nov.2,2004 1,500,000 9,824
3 7.43%Series E Medium-TermNotes due Jan.24,2005 1,000,000 6,333
4 7.43%Series E Medium-TermNotes due Jan.24,2005 2,500,000 15,832
5 7.34%Series E Medium-TermNotes due Oct.17,2005 5,000,000 33,788
6 7.36%Series E Medium-TermNotes due Oct.17,2005 5,000,000 33,788
7 6.12%Series G Medium-TermNotes due Jan.15,2006 100,000,000 679,467
8 7.67%Series C Medium-TermNotes due Jan.10,2007 5,724,000 36,625
9 6.625%Series G Medium-TermNotes due June 1,2007 100,000,000 1,267,428
10 630,000 D
11 7.43%Series E Medium-TermNotes due Sept.11,2007 2,000,000 15,530
12 7.22%Series E Medium-TermNotes due Sept.18,2007 2,500,000 19,412
13 7.27%Series E Medium-TermNotes due Sept.24,2007 4,000,000 31,059
14 6.375%Series H Medium-TermNotes due May 15,2008 200,000,000 1,416,179
15 644,000 D
16 7.00%Series H Medium-TermNotes due Jul.15,2009 125,000,000 1,976,904
17 451,250 D
18 9.15%Series C Medium-TermNotes due Aug.9,2011 8,000,000 75,327
19 8.95%Series C Medium-TermNotes due Sept.1,2011 25,000,000 175,398
20 8.95%Series C Medium-TermNotes due Sept.1,2011 20,000,000 132,118
21 8.92%Series C Medium-TermNotes due Sept.1,2011 20,000,000 188,318
22 8.29%Series C Medium-TermNotes due Dec.30,2011 3,000,000 23,040
23 8.26%Series C Medium-TermNotes due Jan.10,2012 1,000,000 7,649
24 8.28%Series C Medium-TermNotes due Jan.10,2012 2,000,000 13,297
25 8.25%Series C Medium-Term Notes due Feb.1,2012 3,000,000 22,946
26 8.13%Series E Medium-TermNotes due Jan.22,2013 10,000,000 75,827
27 7.25%Series F Medium-TermNotes due Aug.1,2013 10,000,000 91,474
28 7.25%Series F Medium-TermNotes due Aug.1,2013 10,000,000 91,474
29 7.25%Series F Medium-TermNotes due Aug.1,2013 10,000,000 91,474
30 7.25%Series F Medium-TermNotes due Aug.1,2013 10,000,000 91,474
31 8.53%Series C Medium-TermNotes due Dec.16,2021 15,000,000 115,202
32 8.375%Series C Medium-TermNotes due Dec.31,2021 5,000,000 38,400
33 TOTAL 3,794,425,925 62,200,628
FERC FORM NO.1 (ED.12-96)Page 256.3
Name of Respondent I his Report Is:Date of Report Ÿear of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
LUN 3-|k-RIVI Ubb I (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,Premium
on Debt -Credit.
12.In a footnote,give explanatory (details)for Accounts 223 and 224 of net changes during the year.With respect to long-term
advances,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 pledgee
and purpose of the pledge.
14.If the respondent has any long-term debt securities which have been nominally issued and are nominally outstanding at end of
year,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 interest
expense in column (i).Explain in a footnote any difference between the total of column (i)and the total of Account 427,interest on
Long-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.
AlvlOR1|ZAl ION PERIOD bl616IlullIG.LineNominalDateDateof(Total amountoutstanainhewithout Interest for Year
of Issue Maturity Date From Date To reductionr srpamoennts Id by Amount No.
(d)(e)(f)(g)Îhnd
110692 110104 110692 110104 1,000,000 76,000 1
110292 110204 110292 110204 1,500,000 115,800 2
012293 012405 012293 012405 1,000,000 74,300 3
012293 012405 012293 012405 2,500,000 185,750 4
101592 101705 101592 101705 5,000,000 367,000 5
101592 101705 101592 101705 5,000,000 368,000 6
012296 011506 012296 011506 100,000,000 6,120,000 7
011092 011007 011092 011007 5,724,000 439,031 8
060995 060107 060995 060107 100,000,000 6,625,000 9
10
091192 091107 091192 091107 2,000,000 148,600 11
091892 091807 091892 091807 2,500,000 180,500 12
092292 092407 092292 092407 4,000,000 290,800 13
051298 051508 051298 051208 200,000,000 12,750,000 14
15
071597 071509 071597 071509 125,000,000 8,750,000 16
17
080991 080911 080991 080911 8,000,000 732,000 18
081691 090111 081691 090111 25,000,000 2,237,500 19
081691 090111 081691 090111 20,000,000 1,790,000 20
081691 090111 081691 090111 20,000,000 1,784,000 21
123191 123011 123191 123011 3,000,000 248,700 22
010992 011012 010992 011012 1,000,000 82,600 23
011092 011012 011092 011012 2,000,000 165,600 24
011592 020112 011592 020112 3,000,000 247,500 25
012093 012213 012093 012213 10,000,000 813,000 26
072893 080113 072893 080113 10,000,000 725,000 27
072893 080113 072893 080113 10,000,000 725,000 28
072893 080113 072893 080113 10,000,000 725,000 29
072893 080113 072893 080113 10,000,000 725,000 30
121691 121621 121691 121621 15,000,000 1,279,500 31
123191 123121 123191 123121 5,000,000 418,750 32
3,387,251,593 242,798,222 33
FERC FORM NO.1 (ED.12-96)Page 257.3
Nameof Respondent Ihis Report Is:Date of keport Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
LONU-I ERM DESI (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 Pnncipal Amount I otal expense,
No.(For new issue,give commission Authorization numbers and dates)Of Debt issued Premium or Discount
(a)(b)(c)
1 8.26%Series C Medium-Term Notes due Jan.7,2022 5,000,000 33,243
2 8.27%Series C Medium-Term Notes due Jan.10,2022 4,000,000 30,594
3 8.05%Series E Medium-Term Notes due Sept.1,2022 15,000,000 131,471
4 8.07%Series E Medium-Term Notes due Sept.9,2022 8,000,000 70,118
5 8.12%Series E Medium-Term Notes due Sept.9,2022 50,000,000 438,238
6 8.11%Series E Medium-Term Notes due Sept.9,2022 12,000,000 105,177
7 8.05%Series E Medium-Term Notes due Sept.14,2022 10,000,000 87,648
8 8.08%Series E Medium-Term Notes due Oct.14,2022 26,000,000 208,198
9 8.08%Series E Medium-Term Notes due Oct.14,2022 25,000,000 200,190
10 8.23%Series E Medium-Term Notes due Jan.20,2023 5,000,000 37,914
11 8.23%Series E Medium-Term Notes due Jan.20,2023 4,000,000 30,331
12 -81,560 P
13 7.26%Series F Medium-Term Notes due July 21,2023 27,000,000 246,981
14 7.26%Series F Medium-Term Notes due July 21,2023 11,000,000 100,622
15 7.40%Series F Medium-Term Notes due July 28,2023 2,000,000 18,295
16 7.37%Series F Medium-Term Notes due Aug.11,2023 15,500,000 141,785
17 7.23%Series F Medium-Term Notes due Aug.16,2023 15,000,000 137,211
18 7.24%Series F Medium-Term Notes due Aug.16,2023 30,000,000 274,423
19 6.75%Series F Medium-Term Notes due Sept.14,2023 5,000,000 38,250
20 6.75%Series F Medium-Term Notes due Sept.14,2023 2,000,000 15,300
21 6.72%Series F Medium-Term Notes due Sept.14,2023 2,000,000 15,300
22 6.75%Series F Medium-Term Notes due Oct.26,2023 20,000,000 152,326
23 6.75%Series F Medium-Term Notes due Oct.26,2023 16,000,000 121,861
24 6.75%Series F Medium-Term Notes due Oct.26,2023 12,000,000 91,396
25 8.625%Series F Medium-Term Notes due Dec.13,2024 20,000,000 151,025
26 498,600 D
27 6.71%Series G Medium-Term Notes due Jan.15,2026 100,000,000 904,467
28
29
30 Pollution Control Obligations-Secured by Pledged First Mortgage Bonds:
31 Daily Adj.Rate Poll Ctrl Revenue Refunding Bonds,Moffat County,CO,Series 1994 40,655,000 874,159
32 5-5/8%Lincoln County,WY,Series due Nov.1,2021 8,300,000 228,980
33 TOTAL 3,794,425,925 62,200,628
FERC FORM NO.1 (ED.12-96)Page 256.4
Name of kespondent I his Report is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
LUN I ERM UEBl (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,Premium
on Debt -Credit.
12.In a footnote,give explanatory (details)for Accounts 223 and 224 of net changes during the year.With respect to long-term
advances,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 pledgee
and purpose of the pledge.
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 interest
expense in column (i).Explain in a footnote any difference between the total of column (i)and the total of Account 427,interest on
Long-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.
AMOR I IZA I lON PERIOD Oubmilullig-LineNominalDateDateof(Total amount outstanarnhewithout Interest for Year
of Issue Maturity Date From Date To reductionr srpa oennts Id by Amount No.
(d)(e)(f)(g)(h)(i)
010892 010722 010892 010722 5,000,000 413,000 1
010992 011022 010992 011022 4,000,000 330,800 2
091892 090122 091892 090122 15,000,000 1,207,500 3
090992 090922 090992 090922 8,000,000 645,600 4
091192 090922 091192 090922 50,000,000 4,060,000 5
091192 090922 091192 090922 12,000,000 973,200 6
091492 091422 091492 091422 10,000,000 805,000 7
101592 101422 101592 101422 26,000,000 2,100,800 8
101592 101422 101592 101422 25,000,000 2,020,000 9
012093 012023 012093 012023 5,000,000 411,500 10
012993 012023 012993 012023 4,000,000 329,200 11
12
072293 072123 072293 072123 27,000,000 1,960,200 13
072293 072123 072293 072123 11,000,000 798,600 14
072893 072823 072893 072823 2,000,000 148,000 15
081193 081123 081193 081123 15,500,000 1,142,350 16
081693 081623 081693 081623 15,000,000 1,084,500 17
081693 081623 081693 081623 30,000,000 2,172,000 18
091493 091423 091493 091423 5,000,000 337,500 19
091493 091423 091493 091423 2,000,000 135,000 20
091493 091423 091493 091423 2,000,000 134,400 21
102693 102623 102693 102623 20,000,000 1,350,000 22
102693 102623 102693 102623 16,000,000 1,080,000 23
102693 102623 102693 102623 12,000,000 810,000 24
121394 121324 121394 121324 20,000,000 1,725,000 25
26
012396 011526 012396 011526 100,000,000 6,710,000 27
28
29
30
111794 050113 111794 050113 40,655,000 1,833,323 31
111593 110121 111593 110121 8,300,000 466,875 32
3,387,251,593 242,798,222 33
FERC FORM NO.1 (ED.12-96)Page 257.4
Name of Respondent I his Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
L JNU-I t-RM Uh-B I (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 Öbligation,Coupon Rate Principal Amount Total expense,
No.(For new issue,give commission Authorization numbers and dates)Of Debt issued Premiumor Discount
(a)(b)(c)
1 197,125 D
2 5.65%Emery County,Utah,Series due Nov.1,2023 46,500,000 1,624,793
3 5-5/8%Emery County,Utah,Series due Nov.1,2023 16,400,000 625,551
4 389,500 D
5 Daily Adj.Rate Poll Ctrl Rev Refunding Bonds,Sweetwater County,WY,Series 1994 21,260,000 510,479
6 Daily Adj.Rate Poll Ctrl Rev Refunding Bonds,Converse County,WY,Series 1994 8,190,000 209,777
7 Daily Adj.Rate Poll Ctrl Rev Refunding Bonds,Emery County,UT,Series 1994 121,940,000 3,274,246
8 Daily Adj.Rate Poll Ctrl Rev Refunding Bonds,Carbon County,UT,Series 1994 9,365,000 206,519
9 Daily Adj.Rate Poll Ctrl Rev Refunding Bonds,Lincoln County,WY,Series 1994 15,060,000 422,858
10
11 Pollution Control Revenue Bonds:
12 Customized Purchase Poll Ctrl Rev Refndng Bonds,Sweetwater Cnty,WY,Ser.1992A 9,335,000 147,642
13 Customized Purchase Poll Ctrl Rev Refndng Bonds,Sweetwater Cnty,WY,Ser.1992B 6,305,000 138,478
14 Customized PurchasePoll Ctrl Rev Refndng Bonds,Converse County,WY,Series 1992 22,485,000 194,271
15 Customized Purchase Poll Ctrl Rev Refndng Bonds,Sweetwater Cnty,WY,Ser.19888 11,500,000 84,822
16 Customized Purchase Poll Ctrl Rev Refndng Bonds,Converse County,WY,Series 1988 17,000,000 155,970
17 Daily Adjustable Rate Poll Ctrl Revenue Bonds,Sweetwater County,WY,Series 1984 15,000,000 122,887
18 105,000 D
19 Weekly Adj.Rate Poll Ctrl Rev Refndng Bonds,Sweetwater County,WY,Ser.1990A 70,000,000 660,750
20 Customized Purchase Poll Ctrl Rev Refunding Bonds,Emery County,UT,Series 1991 45,000,000 872,505
21 Customized Purchase Poll Ctrl Rev Refunding Bonds,Lincoln Cnty,WY,Series 1991 45,000,000 771,836
22 Flexible Rate Demand Poll Ctrl Revenue Bonds,City of Forsyth,MT,Series 1986 8,500,000 304,824
23 Customized Purchase Poll Ctrl Rev Refndng Bonds,Sweetwater Cnty,WY,Ser.1988A 50,000,000 422,443
24 Customized Purchase Poll Ctrl Rev Refndng Bonds,City of Forsyth,MT,Series 1988 45,000,000 380,198
25 Customized Purchase Poll Ctrl Rev Refndng Bonds,City of Gillette,WY,Ser.1988 41,200,000 351,905
26 Daily Adj.Rate Environ.ImpntmntRev Bonds,Converse County,WY,Series 1995 5,300,000 132,043
27 Daily Adj.Rate Environ.ImprvmntRev Bonds,Lincoln County,WY,Series 1995 22,000,000 404,262
28 Daily Adj.Rate Environ.ImprvmntRev Bonds,Sweetwater County,WY,Series 1995 24,400,000 225,000
29 6.15%Emery County,Utah,Series due September 1,2030 12,675,000 556,549
30 178,464 D
31
32 Less:Funds held by Trustee
33 TOTAL 3,794,425,925 62,200,628
FERCFORM NO.1 (ED.12-96)Page 256.5
Name of Respondent I his keport Is:Date ot keport Year ot keport
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
LUNG-I ekM Ut-8 i (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,Premium
on Debt -Credit.
12.In a footnote,give explanatory (details)for Accounts 223 and 224 of net changes during the year.With respect to long-term
advances,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 pledgee
and purpose of the pledge.
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 interest
expense in column (i).Explain in a footnote any difference between the total of column (i)and the total of Account 427,interest on
Long-Term Debt and Account430,Interest on Debt to Associated Companies.
16.Give particulars (details)concerning any long-term debt authorized by a regulatory commission but not yet issued.
AMOR I IZA I lON PERIOD Uloidilull W LineNominalDateDateof(Total amount outstanainhewithout Interest for YearofIssueMaturityDateFromDateToreductionrsrpamdenntsIdbyAmount No.
(d)(e)(f)(g)Îhn
1
111593 110123 111593 110123 46,500,000 2,627,250 2
111593 110123 111593 110123 16,400,000 922,500 3
4
111794 110124 111794 110124 21,260,000 959,433 5
111794 110124 111794 110124 8,190,000 369,594 6
111794 110124 111794 110124 121,940,000 5,520,662 7
111794 110124 111794 110124 9,365,000 422,315 8
111794 110124 111794 110124 15,060,000 679,622 9
10
11
092992 040105 092992 040105 9,335,000 441,274 12
092992 120105 092992 120105 6,305,000 298,043 13
092992 070106 092992 070106 22,485,000 1,062,888 14
010188 010114 011488 010114 11,500,000 515,572 15
010188 010114 011488 010114 17,000,000 784,401 16
120184 120114 120184 120114 15,000,000 629,283 17
18
072590 070115 072590 070115 70,000,000 3,168,578 19
052391 070115 052391 070115 45,000,000 2,048,254 20
011791 010116 011791 010116 45,000,000 2,131,925 21
120186 120116 120186 120116 8,500,000 356,930 22
010188 010117 011488 010117 50,000,000 2,213,762 23
010188 010118 011488 010118 45,000,000 2,017,455 24
010188 010118 011488 010118 41,200,000 1,902,763 25
111795 110125 111795 110125 5,300,000 230,984 26
111795 110125 111795 110125 22,000,000 958,803 27
121495 110125 121495 110125 24,400,000 1,063,400 28
092496 090130 092496 090130 12,675,000 779,513 29
30
31
-2,250,613 32
3,387,251,593 242,798,222 33
FERC FORM NO.1 (ED.12-96)Page 257.5
Name of Respondent I his Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
L JNU-I ERM DEB\(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.Fumish 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 Ölass and Šeries of Öbligation,Ôoupon Rate Principal Amount Ïotal expense,
No.(For new issue,give commission Authorization numbers and dates)Of Debt issued Premium or Discount
(a)(b)(c)
1
2 SUBTOTALACCOUNT 221 3,255,712,000 43,281,974
3
4
5
6 Reacquired Bonds (Account 222)
7
8
9
10
11 Advances from Associated Companies (Account223)
12 Advance from Pacific Minerals,Inc.(PMI)
13 Advance from DemandSide Receivable,Inc.(DSR)
14 8-1/4%Debentures Series C payable to PacifiCorp Capital I 223,712,000 7,487,809
15 7.70%Debentures Series D payable to PacifiCorp Capital 11 139,176,000 4,586,685
16
17 SUBTOTAL ACCOUNT 223 362,888,000 12,074,494
18
19
20 Other Long-Term Debt (Account 224)
21 8.55%Quarterly Income Debt Securities (QUIDS)(Junior Subordinated
22 Deferrable interest Debentures,Series B)55,825,925 2,520,556
23 8.375%Quarterly Income Debt Securities (QUIDS)(Junior Subordinated
24 Deferrable Interest Debentures,Series A)120,000,000 4,323,604
25
26 SUBTOTAL ACCOUNT 224 175,825,925 6,844,160
27
28
29
30
31
32 Long-Term Debt Authorized but Unissued
33 TOTAL 3,794,425,925 62,200,628
FERC FORM NO.1 (ED.12-96)Page 256.6
Name of Respondent I his Report is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
LUNU-I t-RM DEBl (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,Premium
on Debt -Credit.
12.In a footnote,give explanatonj (details)for Accounts 223 and 224 of net changes during the year.With respect to long-terin
advances,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 pledgee
and purpose of the pledge.
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 interest
expense in column (i).Explain in a footnote any difference between the total of column (i)and the total of Account 427,interest on
Long-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.
AMORTIZATIONPERIOD ÛUddlidllid .LineNominalDateDateof(Total amount outstana nhewithout Interest for YearofIssueMaturityDateFromDateToreductionrsrpamoennIdbyAmount No.
(d)(e)(f)(g)Îhnd
1
3,008,197,120 199,460,838 2
3
4
5
6
7
8
9
10
11
16,166,473 988,488 12
13
061196 063036 061196 063036 223,712,000 18,456,240 14
080497 093037 080497 093037 139,176,000 10,716,552 15
16
379,054,473 30,161.280 17
18
19
20
21
100595 123125 100595 123125 4,242,771 22
23
053195 063035 053195 063035 8,933,333 24
25
13,176,104 26
27
28
29
30
31
32
3,387,251,593 242,798,222 33
FERC FORM NO.1 (ED.12-96)Page 257.6
Name ot Respondent I his keport Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
MbUUNCILIAl ION UI-MbHURI EU Nb I INGUMb WI I H I AXABLE INGUMb FUM I-bUbHAL INGUME I AXES
1.Report the reconciliation of reported net income for the year with taxable income used in computing Federal income tax accruals and show
computation of such tax accruals.Include in the reconciliation,as far as practicable,the same detail as furnished on Schedule M-1 of the tax retum for
the year.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 memberof a group which files a consolidated Federal tax return,reconcile reported net income with taxable net income as if a
separate retum were to be field,indicating,however,intercompany amounts to be eliminated in such a consolidated return.State names of group
member,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 meeta particular need of a company,may be used as Long as the data is consistent and meets the requirements of
the above instructions.For electronic reporting purposes complete Line 27 and provide the substitute Page in the context of a footnote.
Line Particulare (Details)Amount
No.(a)(b)
1 Net Income for the Year (Page 117)-5,097,218
2
3
4 Taxable income Not Reported on Books
5 Contributions in aid of Construction 14,292,000
6 Gain/Loss on Property disposition 57,989,018
7 Misc Items on return unaccrued 875,292
8 Cholla APS Safe Harbor Lease (Disc)130,335
9 Deductions Recorded on Books Not Deducted for Retum
10 Federal Incom Tax 145,498,147
11 Equity in Eamings of Subsidiary companies 145,756,923
12 Merger Credits/CentraliaGiveback 147,778,754
13 Other Items 130,255,673
14 Income Recorded on Books Not included in Retum
15 Allowance for Funds Used During Construction 10,683,000
16 Deferred Income Tax 57,407,337
17 Redding Contract 6,949,992
18 Other Items 8,716,711
19 Deductions on Retum Not Charged Against Book income
20 Removal Costs 12,750,751
21 Final Reclamation 12,534,923
22 Pension /RetirementAccrued 38,289,883
23 Merger Transaction Costs 27,452,762
24 Utility Asset Writedown 24,146,665
25 ADR Repair Allowance 13,196,750
26 Other Items 48,793,871
27 Federal Tax Net Income 376,556,279
28 Show Computationof Tax:
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
Ekt EUkM NU.1 (bU.12-9b)Page 261
BLANK PAGE
(Next Page is:262)
Name of Respondent I his Repon Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
IALES ACURUbu,PREPAID AND CHARGbU DURING YEAN
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 l ax BALANut-Al Bi-blNNING UV Y t-Ak arŠÊd .Adjust-No.(See instruction 5)I axes Acorueo Prepaid I axes nn nng ts(Account 236)(include in Account 165)ear ear men
(a)(b)(c)(d)(e)(f)
1 Federal:
2 Income 63,436,284 145,498,147 114,115,139 -154,575
3 FICA -1,191,121 25,966,844 28,506,889 3,999.389
4 Unemployment 35,679 2,249,793 1,727,499 -165,494
5 Highway Motor Vehicle
6 Diesel Fuel 72,608 159,235 81,911
7 Excise Tax -Coal 361,364 9,122,950 10,333,662 985.796
8 Excise Tax -Superfund
9 SUBTOTAL 62,714,814 182,996,969 154,765,100 4,665,116
10
11
12
13 Arizona:
14 Property 1,354,562 2,774,144 2,741,634
15 Income Tax 552,179 212,758 258,758
16 Road Use
17 Unemployment
18 SUBTOTAL 1,906,741 2,986,902 3,000,392
19
20
21
22 Califomia:
23 Property 931,347 1,749,175 1,817,167
24 Unemployment
25 EmployeeTraining Fund
26 Bank/Corp.Franchise 939,333 407,888 357,888
27 PUC Use Tax 93,485 93,485
28 Sales and Use Tax 230 44,552 51,975
29 Motor Vehicle 70,477 70,477
30 Local Franchise Tax 582,017 555,412 557,026
31 SUBTOTAL 2,452,927 2,876,437 2,940,595 51,975
32
33
34
35 Colorado
36 Property 3,100,100 2,805,341 2,952,721
37 Income 322,219 -314,894
38 SUBTOTAL 3,422,319 2,805,341 2,637,827
39
40
41 TOTAL 115,178,147 10,407,356 301,871,723 276,892,625 80,559
FERCFORM NO.1 (ED.12-96)Page 262
Name of Respondent I his Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
IAXI-8 ACURUE-D,PREPAID AND CHARGbU 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 (!)how the taxes were distributed.Report in column (1)only the amounts charged to Accounts 408.1 and 409.1
pertaining to electric operations.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.
BALANCEAl -NU UF YEAN DIS I MlldU I ION OF \AXb5 CHANGi-D Line(Taxes accrued Prepaid laxes Electric Extraordinary Items Adjustments to ket.Oth r No.Account 236)(Incl.in Account 165)(Account 408.1,409.1)(Account 409.3)Eamings (Account 439)e
(g)(h)(i)(j)(k)(l)
1
94,664,717 140,505,147 4,993,000 2
268,223 25,236,157 730,687 3
392,479 2,136,995 112,798 4
5
149,932 159,235 6
136,448 9,122,950 7
8
95,611,799 167,878,299 15,118,670 9
10
11
12
13
1,387,072 2,774,144 14
506,179 202,890 9,868 15
16
17
1,893,251 2,977,034 9,868 18
19
20
21
22
863,356 1,714,379 34,796 23
24
25
989,333 388,970 18,918 26
93,485 27
7,653 28
70,477 29
580,403 555,412 30
2,440,745 2,658,761 217.676 31
32
33
34
35
2,952,720 2,804,297 1,044 36
637,113 37
3,589,833 2,804,297 1.044 38
39
40
139,540,035 9,709,586 275,600,360 26,271,364 41
FERC FORM NO.1 (ED.12-96)Page 263
Name of Respondent I his Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
IALES AGURUbU,PRt-PAIDAND CHARGEU UURING YBAR
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 bALANGE AI bb3\NNING UF yRAR guarŠd aig Adjust-No.(See instruction 5)I axes Accrued Prepaid I axes Dunng During ments(Account 236)(include in Account 165)Year Year(a)(b)(c)(d)(e)(f)
1 Idaho:
2 Property 1,718,438 3,025,489 3,069,793 -585,499
3 Income 1,948,245 587,012 622,012
4 KWH 24,924 2,733 27,384
5 Unemployment
6 Regulatory Commission 147,421 312,454 330,067
7 Diesel Fuel
8 MotorVehicle 8,165 8,165
9 Road Use
10 Local Franchise Tax
11 SUBTOTAL 3,691,607 147,421 3,935,853 4,057,421 -585,499
12
13
14 Montana:
15 Property 2,267,034 1,574,142 2,709,043 585.499
16 Unemployment
17 Corporate License 1,415,119 215,085 145,085
18 Local Franchise Tax
19 Consumer Council
20 Motor Vehicle
21 Regulatory Commission
22 Montana Old Fund Ta×
23 SUBTOTAL 3,682,153 1,789,227 2,854,128 585,499
24
25 Nevada
26 Property
27 Unemployment
28 CEP
29 Employee Business Tax
30 SUBTOTAL
31
32 New Mexico:
33 Property 4,846 7,949 8,820
34 Income -33,125 45,308 39,308
35 SUBTOTAL -28,279 53,257 48,128
36
37 Oregon:
38 Property 37,446 7,982,713 15,192,944 14,551,083
39 Unemployment
40 Other
41 TOTAL 115,178,147 10,407,356 301,871,723 276,892,625 80,559
FERC FORMNO.1 (ED.12-96)Page 262.1
Name of Respondent I his Report Is:Date of keport Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
I AXES AGURUbu,PRt-PAID AND CHANGED DURING Yt-AM (Continued)
5.If any tax (exclude Federal and State income taxes)-covers more then one year,show the required information separately for each ta× 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 (1)how the taxes were distributed.Report in column (I)only the amounts charged to Accounts 408.1 and 409.1pertainingtoelectricoperations.Report in column (I)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.
E3ALANCE A I ENU UI-YBAR Ulb I MlldU I ION Ul-IAXES CHARGbU Line(Taxes accrued Prepaid laxes E-lectric extraordinary Items Adjustments la Ret.Other NoAccount236)(incl.in Account 165)(Account 408.1,409.1)(Account 409.3)Earnings (Account 439)
(g)(h)(i)(j)(k)(!)
1
1,088,635 3,023,389 2,100 2
1,913,245 559,786 27,226 3
273 2,733 4
5
165,034 312,454 6
7
8,165 8
9
10
3,002,153 165,034 3,585,908 349,945 11
12
13
14
1,717,632 1,573,902 240 15
16
1,485,119 205,109 9,976 17
18
19
20
21
22
3,202,751 1,779,011 10,216 23
24
25
26
27
28
29
30
31
32
3,975 7,949 33
-27,125 43,207 2,101 34
-23,150 51,156 2,101 35
36
37
6,601 7,310,007 14,877,600 315,344 38
39
540,484 -540,484 40
139,540,035 9,709,586 275,600,360 26,271,364 41
FERC FORM NO.1 (ED.12-96)Page 263.1
Name of Respondent I his Report Is:Date of keport Year ot Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
IAxb5 ACURUbu,PREPAIDAND CHARGbU UURING YEAN
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 BALANub Ai stälNNING UN Y EAR dArŠd a^¡¶Adjust-No.(See instruction 5)I axes Accrued Frepaid I axes Dunng During ments(Account 236)(Include in Account 165)Year Year(a)(b)(c)(d)(e)(f)
1 Regulatory Commission 626,358 2,496,773 2,493,884
2 Excise Tax 7,780,107 6,828,544 5,857,075
3 City of Portland 39,141 50,689 -9,802
4 Motor Vehicle 169,417 169,417
5 Tri Met
6 Lane County
7 Local Franchise Tax 248,132 15,594,773 15,590,643
8 SUBTOTAL 8,104,826 8,609,071 40,333,140 38,652,300
9
10 Utah:
11 Property 1,386,745 29,458,494 30,562,125
12 Income 5,841,211 5,738,751 5,152,689
13 Unemployment
14 Regulatory Commission 1,230,870 2,440,837 2,419,933
15 Special Fuel
16 Motor Vehicle 360,167 360,167
17 Road Use
18 Misc.Municipal
19 Environmental
20 Local Franchise Tax
21 Gross Receipts Tax 1,440,480 2,359,929 2,359,929
22 SUBTOTAL 8,668,436 1,230,870 40,358,178 40,854,843
23
24 Washington:
25 Property 7,333,981 4,358,679 6,473,567
26 Unemployment
27 Business 83,668 617,652 687,912
28 Public Utility Tax (Rev.)1,117,022 7,013,889 7,087,582
29 Regulatory Commission 94,770 383,053 384,376
30 Compensating 979,343 565,337 1,539,511
31 Environmental
32 Local Franchise Tax 8,707 249,091 236,734
33 Centralia Production Tax 985,796 -985,796
34 Motor Vehicle 144,756 144,756
35 SUBTOTAL 10,508,517 94,770 13,332,457 16,554,438 -985,796
36
37 Washington D.C.:
38 Unemployment
39 Franchise 2,697
40 SUBTOTAL 2,697
41 TOTAL 115,178,147 10,407,356 301,871,723 276,892,625 80,559
FERC FORMNO.1 (ED.12-96)Page 262.2
Name of Respondent I his Report is:Date of Report Year of Report |
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
IAXES AGURUbu,PNEPAID AND CHARGbD DURING YbAN (Contmued)
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 ta×es collected through payroll deductions or otherwise pendingtransmittalofsuchtâxestothetaxingauthority.
8.Report in columns (i)through (I)how the taxes were distributed.Report in column (I)only the amounts charged to Accounts 408.1 and 409.1pertainingtoelectricoperations.Report in column (l)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.
BALANutA i bNu us y dAR IJIb I MlbU \IUN UP I AAbd UHAKUbU Line(Taxes accrued Prepaid laxes Electric Extraordinary Items Adjustments to Net.Oth r NoAccount236)(Incl.in Account 165)(Account 408.1,409.1)(Account 409.3)Earnings (Account 439)e .
(g)(h)(i)(j)(k)(1)
623,469 2,496,773 1
8,751,576 6,511,837 316,707 2
99,632 257,275 -206,586 3
169,417 4
5
6
252,262 15,594,773 7
9,110,071 7,933,476 37,781,969 2,551.171 8
9
10
283,114 27,596,968 1,861,526 11
6,427,273 5,472,588 266,163 12
13
1,209,966 2,440,837 14
15
360,167 16
17
18
19
20
1,440,480 2,359,929 21
8,150,867 1,209,966 35,429,485 4,928,693 22
23
24
5,219,093 4,273,582 85,097 25
26
13,408 617,652 27
1,043,329 7,013,889 28
96,093 383,053 29
5,169 565,337 30
31
21,064 249,091 32
33
144,756 34
6,302,063 96,093 11,536,562 1,795,895 35
36
37
38
2,697 39
2,697 40
139,540,035 9,709,586 275,600,360 26,271,364 41
FERC FORM NO.1 (ED.12-96)Page 263.2
Name of Respondent I his Report is:Date ot Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
lA;b5 AGURULU,PREPAIDAND CHARGE.D UURING 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 lax baLANGE Al abblNNINO UF YEAk arŠd a^¡Adjust-No.(See instruction 5)I axes Accrued Frepaid I axes nng nn ts(Account 236)(include in Account 165)ear ear9 men
(a)(b)(c)(d)(e)(f)
1
2
3 Wyoming:
4 Property 3,591,159 7,177,592 7,476,053 218,614
5 Unemployment
6 Regulatory Commission 325,224 630,241 610,034
7 Glenrock Production Tax 597,617 419,717 245,402 -64,276
8 Local Franchise Tax 25,102 877,309 894,757
9 Sales and Use Tax 356,855 69,620 -20.600
10 Motor Vehicle
11 Special Fuel
12 Environmental
13 SUBTOTAL 4,570,733 325,224 9,104,859 9,295,866 133,738
14
15 Goshute Possessory 7,421 7,421
16 Sho-Ban Possessory 132,862 132,862
17 Navajo Business Activity 15,358 15,358
18 Navajo Possessory Interest 41,705 85,631 84,520
19 Ute Possessory Interest 2,279 2,279
20 Crow Utility Tax 18,184 36,369 18,185
21 Umatilla 39,442 39,442
22 Franchise Taxes Assoc.
23 with Unbilled Revenues 1,636,293 979,741 931,520
24
25 Franchise/License Taxes 3,784,474 -3,784,474
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41 TOTAL 115,178,147 10,407,356 301,871,723 276,892,625 80,559
FERCFORM NO.1 (ED.12-96)Page 262.3
Name of Respondent I his Report is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
IAXES ACCRUt-D,PREPAIDAND CHARGEDDURINGYEAR (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 409.1
pertaining to electric operations.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.
BALANUb A I ENU Ul-YEAR DIS I MIBUI ION Uf-I AXt-S CHANGl-D Line(Taxes accrued Prepaid I axes Electric Extraordinary Items Adjustments lo ket'Other NoAccount236)(incl.in Account 165)(Account 408.1,409.1)(Account 409.3)Earnings (Account 439)
(g)(h)(i)(j)(k)(I)
1
2
3
3,511,312 6,941,466 236,127 4
5
305,017 630,241 6
707,656 419,717 7
7,654 877,309 8
266,635 9
10
11
12
4,493,257 305,017 7,818,775 1,286,085 13
14
7,421 15
132,862 16
15,358 17
42,816 85,631 18
2,279 19
36,368 36,369 20
39,442 21
22
1,684,514 979,741 23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
139,540,035 9,709,586 275,600,360 26,271,364 41
FERC FORM NO.1 (ED.12-96)Page 263.3
Name of Respondent I his Report Is:L)ate of keport Year ot Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000
(2)A Resubmission //
AGUUMULAl EU Uhl-ERRbU INVESI MENI I AX UREDII 5 (ACCount 2bb)
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 colurnn (i)
the average period over which the tax credits are amortized.
Line Account balance at beginning alluodliolla le
No.Subd ions of Year Deferred for Year Current Year's Income Adjustments
a (b)Account No.i Aliiuunt Accuunt No.I amount(c)(d)(e)(f)(9)
1 Electric LJtility
2 3%97,537 411.4 79,25
3 4%2,763,772 411.4 324,81
4 7%
5 10%107,708,799 411.4,420 7,089,05
6
7 Idaho 1,366,817 411.4 65,43
8 TOTAL 111,936,925 7,558,56
9 Other (List separately
and show 3%,4%,7%,
10%and TOTAL)
10
11 Nonutility
12 10%5,289,392 420 440,80
13
14 Total Nonutility 5,289,392 440,80
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
ERC FORM NO.1 (ED.12-(9)Page 266
Name of Respondent I his Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
ACCUMULAI EU D ±bHRE-D INVESI MENT l AX URt-D I S (Account 2bb)(continued)
BalanceeaarEnd A rAa e rinod ADJUSTMENT EXPLANATION Line
to Income(h)(i)
1
18,284 35 2
2,438,960 35 3
4
100,619,740 30,35 5
6
10
11
4,848,584 12
13
4,848,584 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 ot Respondent I his Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
U Hi-R UEFFERab UREDI lb (Account 2bd)
1.Report below the particulars (details)callet for conceming other deferred credits.
2.F<r any deferred credit being amortized,stow the period of amchization.
3.Minor items (5%of the Balance End of YeE r for Account 253 or amounts less than $10,000,whichever is greater)may be grouped by classes.
Line Description and Öther Balance at OËBITŠ Balance at
No.Deferred Credits Beginning of Year Contra Amount Credits End of Year
Account(a)(b)(c)(d)(e)(f)
1 Cogeneration bonds 413,417 413,417
2
3 Working capital deposit from
4 Deseret Generation &Transmission
5 Cooperative 1,109,000 143 163,000 946,000
6
7 Working capital and coal pile
8 deposits from Provo City 273,000 143 273,000
9
10 Working capital deposit from UAMPS 644,000 143 105,000 539,000
11
12 Reclamation costs -Dave Johnston
13 Coal Mine 46,873,612 151 15,682,437 6,338,343 37,529,518
14
15 Reclamation costs -Centralia Coal
16 Mine 36,551,589 151 111,174,468 85,615,637 10,992,758
17
18 Reclamation costs -Trapper Mine 151 106,353 2,101,939 1,995,586
19
20 Reclamation liabilities -Federal 885,782 151 1,066,404 180,622
21
22 Reclamation costs -Deer Creek
23 Mine 1,037,494 151 261,400 395,232 1,171,326
24
25 Reclamation costs -Deseret Mine 1,514,566 151 107,668 1,406,898
26
27 Reclamation costs -Cottonwood
28 Mine 942,863 151 3 166,923 1,109,783
29
30 Deferred Compensation -673,784 131 6,252,244 18,669,426 11,743,398
31
32 401(k)Plan administrative costs -106,139 131 1,234,927 1,606,173 265,107
33
34 Long Term Incentive Plan 143,991 217 275,172 643,381 512,200
35
36 Building rent revenues -Portland 3,626 931 19,421 12,693 -3,102
37
38 Centralia Mine coal cost refund -877,197 various 5,516,461 6,602,482 208,824
39
40 Mill Fork Tract Lease Bonus Paymnt 20,160,000 131 5,040,000 15,120,000
41
42 SkookumchuckTimber Harvest Contrt 545,804 various 545,804
43
44 Pension administrative costs -227,936 131 1,080,326 1,231,589 -76,673
45
46 Transmission Service Deposit 40,500 142 1,050,975 4,932,900 3,922,425
47 TOTAL 146,145,379 182,833,105 154,600,094 117,912,368
FERCFORM NO.1 (ED.12-94)Page 269
Name ot Respondent I his Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
U HER UH-H-RED UkEul I b (Account 2bd)
1.Raport below the particulars (details)called for concerning other deferred credits.
2.For any deferred credit being amortized,stow the period of amcrtization.
3.M nor items (5%of the Balance End of Year for Account 253 or amounts less than $10,000,whichever in greater)may be grouped by classes.
Line bescription and Öther Balance at DË$lIŠ Balance at
No.Deferred Credits Beginningof Year Contra Amount Credits End of Year
Account(a)(b)(c)(d)(e)(f)
1
2 Other deferred credits 4,661,738 456 863,737 2,850,500 6,648,501
3
4
5 MCl F.O.G.wire lease 560,932 454 7,291,411 7,291,237 560,758
6
7 Firth Cogeneration Buyout 2,094,480 131 349,080 1,745,400
8
9 Monsanto Contract 6,666,660 456 3,611,114 277,778 3,333,324
10
11 Redding Contract 14,620,866 447 6,370,826 8,250,040
12
13 Footcreek Contract 153,183 2,097,245 1,944,062
14
15 B.P.A.Residential Purchase and
16 Sales agreement -492,643 440 273 195 -492,721
17
18 Hermiston breakage fee 7,557,418 431 7,557,418
19
20 University of Wyoming electric
21 prepayment 891,740 445 1,784,004 3,531,712 2,639,448
22
23 Lakeview Buyout 330,000 131 55,000 275,000
24
25 Environmental Liabilities -
26 Non Current 5,114,996 10,054,087 4,939,091
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46
47 TOTAL 146,145,379 182,833,105 154,600,094 117,912,368
FERC FORMNO.1 (ED.12-94)Page 269.1
Nameof Respondent Ihis Report is:lJate of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
AUGUMULAI BU Ubi-bkMbL INGUME I AXbb -AGUbLENAl i-D /,MUK I IZA I lUN 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.
ÔHANÔEŠ DURINÓYEARLineAccountBalanceat
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)
3 Defense Facilities 2,640,146 334,272
4 Pollution Control Facilities
5 Other
6
7
8 TOTAL Electric (Enter Total of lines 3 thru 7)2,640,146 334,272
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)2,640,146 334,272
19 Federal Income Tax 2,324,302 294,287
20 State income Tax 315,844 39,985
21 Local income Tax
NOTEE
ERC FORM NO.1 (ED.12-96)Page 272
Name of Respondent I his Report Is:Date of Report Year ot keport I
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
AUGUMULA1 EU Ubi-bHRbU INGUlv b I AXES _ACCELt-KAI EU AMUN I Z.A l ION PRUPt-N I Y (Account 281)(Continued)
3.Use footnotes as required.
ÓHANGES DURINGYEAR AUJUS I MENI b
Amounts bebited Amounts Credited bebits 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)(¡¡0)(k)
1
2,305,874 3
4
5
6
7
2,305,874 8
10
11
12
13
14
15
16
2,305,874 17
18
2,030,015 19
275,859 20
21
NOTES(Continued)
ERC FORM NO.1 (ED.12-96)Page 273
Nameof Respondent I his Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission I /
AGUUMULAI b )DEf-i-bHED INGUME I AXES -U I t EN PRUPERI Y (ACCOUnt ¿82)
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.
ÓHANÓESDURINÓYEARLineAccountBalanceat
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 1,002,407,833 61,508,937 95,839,255
3 Gas
4 FAS 109 576,317,878
5 TOTAL (Enter Total of lines 2 thru 4)1,578,725,711 61,508,937 95,839,255
6 Nonutility 10,523,712
7
8
9 TOTAL Account 282 (Enter Total of lines 5 thru 1,589,249,423 61,508,937 95,839,255
10 Classification of TOTAL
11 Federal Income Tax 1,523,284,198 57,104,586 86,337,641
12 State income Tax 65,965,225 4,404,351 9,501,614
13 Local Income Tax
NOTES
FERC FORM NO.1 (ED.12-96)Page 274
Name of Respondent I his Report is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
ACCUMULAl EU UEFERRED INGUtv b i AXb5 -U I HbH PRUPER I Y (ACCOUnt 262)(Continued)
3.Use footnotes as required.
ÓHANÓESDURINÓYEAR ADJUSI MEN lb
Amounts Debited Amounts Öredited 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)
190 1,939,41€190,283 2,093,357 968,231,462 2
3
182 37,037,732254 3,157,00C 542,437,14€4
38,977,142 5,250,357 1,510,668,60E 5
10,84E 882,564 190 883,254 190 10,99E 8,779,741 6
7
8
10,84E 882,564 39,860,39E 5,261,35€1,519,448,34E 9
10,846 882,564 39,794,94E 5,161,93$1,458,546,418 11
65,44E 99,41/60,901,931 12
13
NOTES(Continued)
FERC FORM NO.1 (ED.12-96)Page 275
Name of Respondent I his Report Is:Date of Report Ÿear of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
AGUUMUL\I EU Ul-1-1-ENED INGUME I AXb5 -U I HbH (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.
CHANGEŠ DURINGYEARLineAccountBalanceatAmountsveDiteoAmounts creaitea
No.(a)
Beginning of Year to Acc t 410.1 to Acc t 411.1
1 Account 283
3 UPL/PPL Merger Amortization 5,073,078
4 Loss on Reacquired Debt 16,244,187 128,044 1,420,646
5 Expense of Pollution Control
Property Taxes (California and -168,156 6,110,154 441,096
7
8 Other 18,525,551 16,423,182 23,822,209
9 TOTAL Electric (Total of lines 3 thru 8)39,674,660 22,661,380 25,683,951
10 Gas
11
12
1Š
14
15
16
17 TOTAL Gas (Total of lines 11 thru 16)
18 Nonutility -Investments 4,468
10 TOTAL (Acct 283)(Enter Total of lines 9,17 and 18)39,679,128 22,661,38 25,683,951
20 Classification of TOTAL
21 Federal Income Tax 36,929,757 20,256,25 22,890,261
State Income Tax 2,749,371 2,405,12 2,793,690
2 Local Income Tax
NOTES
ERCFORM NO.1 (ED.12-96)Page 276
Name of Respondent I his Report is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
AUGUMULAI EU Ubt-bHNbU INCOME I AXEb -U I HER (Account 283)(Continuec)
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.
CHANGE$DURINÓ YEAR AUJUSl MENI S
Amounts Debited Amounts credited Debits Uredits Balance at Line
to Account 410.2 to Account 411.2 A couent Amount A ul AniounL End of Year No.
(e)(f)ig (h)(i)(j)(k)
1
282 1,137,447 3,935,631 3
190 1,735,853 190 803,866 14,019,598 4
5
5,500,902 6
7
190 4,710,861 190 6,415,663 8
7,584,161 803,866 29,871,794 9
11
12
13
14
15
16
17
4,466 18
7,584,161 803,866 29,876,262 19
7,081,578 27,214,170 21
502,583 803,866 2,662,092 22
23
NOTES (Continued)
FERC FORMNO.1 (ED.12-96)Page 277
Nameof Respondent I his Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
U \HER MbbULA I URY LIABILI i II-b (Account 254)
1.Reporting below the particulars (Details)called for concerning other regulatory liabilities which are created through the rate-making
actions of regulatory agencies (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 grouped
by classes.
Line bescription and Purpose of DÊBlÏS Balance at
No.Other Regulatory Liabilities Account Amount Credits End of Year
Credited(a)(b)(c)(d)(e)
1 1996 Depreciation Study 403 11,582,692 29,219,449 17,636,757
2
3 FAS 109 income Tax Regulatory Liab 182.3 3,157,000 44,489,876
4
5 Centralia Gain Giveback 456 3,191,002 13,911,970 10,720,968
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 TOTAL 17,930,694 43,131,419 72,847,601
FERC FORM NO.1 (ED.12-94)Page 278
BLANK PAGE
(Next Page is:300)
Name ot Respondent I his Report is:Date of Weport Year ot keport
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
E.EU\RIC UPERAI ING RbvbNUbb (Account400)
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 REVENUÊS
No Amount for Year |Amount for Previous Year(a)(b)(c)
1 Sales of Electricity
2 (440)Residential Sales 834,996,675 799,573,731
3 (442)Commercialand Industrial Sales
4 Small (or Comm.)(See Instr.4)700,213,182 663,011,960
5 Large (or Ind.)(See Instr.4)714,220,302 679,654,408
6 (444)Public Street and Highway Lighting 13,990,710 13,019,154
7 (445)Other Sales to Public Authorities 17,873,190 17,296,445
8 (446)Sales to Railroads and Railways
9 (448)Interdepartmental Sales
10 TOTAL Sales to Ultimate Consumers 2,281,294,059 2,172,555,698
11 (447)Sales for Resale 1,736,151,126 1,051,884,816
12 TOTAL Sales of Electricity 4,017,445,185 3,224,440,514
13 (Less)(449.1)Provision for Rate Refunds 1,503,068 2,566,493
14 TOTAL Revenues Net of Prov.for Refunds 4,015,942,117 3,221,874,021
15 Other Operating Revenues
16 (450)Forfeited Discounts 4,015,689 4,298,579
17 (451)Miscellaneous Service Revenues 7,126,746 7,629,483
18 (453)Sales of Water and Water Power
19 (454)Rent from Electric Property 12,237,674 12,369,824
20 (455)Interdepartmental Rents
21 (456)Other Electric Revenues 69,448,472 -16,152,903
22
23
24
25
26 TOTAL Other Operating Revenues 92,828,581 8,144,983
27 TOTAL Electric Operating Revenues 4,108,770,698 3,230,019,004
FERC FORM NO.1 (ED.12-96)Page 300
Name ot kespondent I his Report is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission I /
E .EU l klU UPERA I ING RavbNUbb (Account 400)
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 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.
MEGAWAl I HOURS SOLD AVG.NO.CUSTOMERS PER MON I H Line
Amount for Year Amount for Previous Year Number for Year Numberfor Previous Year No.
(d)(e)(f)(g)
1
13,375,862 13,032,079 1,262,293 1,243,897 2
3
13,471,314 12,676,070 175,420 171,295 4
20,749,637 20,248,263 35,004 35,289 5
138,347 126,535 4,218 4,562 6
565,313 522,206 28 28 7
8
9
48,300,473 46,605,153 1,476,963 1,455,071 10
29,953,491 36,315,498 119 149 11
78,253,964 82,920,651 1,477,082 1,455,220 12
13
78,253,964 82,920,651 1,477,082 1,455,220 14
Line 12,column (b)includes $2,477,091 of unbilled revenues.
Line 12,column (d)includes -57,091 MWH relating to unbilled revenues
FERC FORM NO.1 (ED.12-96)Page 301
Narne otkespondent lhis kepod is:Dateotkepod Yearotkepod
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000
(2)A Resubmission //
bALES UE ELt-U l RIGI I ysy RA l a SCHEUULab
1.Raport 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.P ovide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues,"Page
300-301.If the sales under any rate schedule are classified in more than one revenue account,List the rate schedule and sales data under each
applicabkarevenueaccountsubheadinig.
3.V'here 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
custorners.
4.Tle average number of customers should be the numberof bills rendered during the year divided by the number of billing periods during the year (12
if all 3illings are made monthly).
5.For any rate schedule having a fuel adjustment clause state in a footnote the estimeted additional revenue billed pursuant thereto.
6.Repodarnountofunbilled revenue as ofend ofyearforeach applicable revenueaccountsubheading.
Line INullideidild TÍue UÏ Rdie bulledure Iv!Wli Sold Reveliue Avelaye luulliber kWII ut õeles e el
No-(a)(b)(c)"(somers Per stomer
1 ResidentialSales(Account440):
2 Sch.
3 1 Residential Service -UT 4,939,315 304,599,949 579,604 8,522 0.0617
4 2 ResidentialOptional
5 Time-of-Day-UT 88 6,535 7 12,571 0.0743
6 3 Lifeline Program-UT 771 48,933 134 5,754 0.0635
7 7 SecudgArea Lighting-UT 3,363 &¾L804 3,911 860 0.1911
8 12SecurigPostTop Lightng-U 257 19,248 84 3,060 0.0749
9 14 TempSenrice Connection -UT 1,493
10 25 Mobile Home Serviœ
11 Existing Customers -UT 11,414 573,928 11 1,037,636 0.0503
12 BlueskyEnertyy-UT 22,004 404
13 Less-Multiple-Billings -7,379
14 Annual Guaranteed Adj -UT 64,944
15 Unbilled Revenue -UT -43,511 -2,173,667 0.0500
16
17 2 FassidentialServiceVVY-UPL 439 27,440 60 7,317 0.0625
18 3 ResidentialSenrice
19 OptionalVVY-UPL 44 2,331 2 22,000 0.0530
20 201 Residential Service WY-UPL 55,923 4,896,388 8,286 6,749 0.0876
21 205ResidentialSenrice
22 Optional-VVY-UPL 39,544 2,696,828 2,201 17,966 0.0682
23 207 SecuntyArea Lighting VVY-UPL 90 23,412 107 841 0.2601
24 Bluesky Energy-VVY-UPL 301 7
25 Renton ElecPropedy\¾Y-UPL 15 1
26 Centralia Refund -WY-UPL -33,186
27 Annual Guarantee Adj WY-UPL 7,670
28 Less Multiple Billings -154
29 UnbilledRevenue\¾Y-UPL 1,612 122,000 0.0757
30
31 1 Residential ID-UPL 267,237 21,778,760 28,238 9,464 0.0815
32 7 Secunt/Area Lightng ID-UPL 145 38,484 179 810 0.2654
33 36 ResidentialSentice
34 Time-of-Day ID-UPL 296,457 18,764,085 15,834 18,723 0.0633
35 BPA Balance Account ID-UPL 321,967
36 Less-Multiple-Billings -364
37 Annual Guaranteed Adj ID-UPL 11,217
38 Unbilled Revenue-ID-UPL 9,717 889,000 0.0915
39
40
41 lul AL Billed 48,357,56E 2,278,816,968 1,476,966 32,741 0.0471
42 Total Unbilled Rev.(Šee Instr.6)-57,091 Ž,477,091 C C -0.0434
4$TÖTAL 48,300,474 2,281,294,059 1,476,966 32,703 0.0472
FERt:FORM NO.1 (ED.12-95)Page 304
Name ot Respondent I his Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
bALES UI-ELEUI RIGI I Y BY RA I e buHauULeb
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,"Page
300-301.If the sales under any rate schedule are classified in more than one revenue account,List the rate schedule and sales data under each
applicable revenue account subheading.
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 adjt stment clause state in a footnote the estimated additional revenue billed pursuant thereto.
6.Report amount of unbilled revenue as o end of year for each applicable revenue account subheading.
une Isuilibei ano Title of Rate suaeuure ivlWil öuid Freveliue Avetaye Wuliivel Kvvii uf Sales i e ei
No-(a)(b)(c)of Cus omers Per ustomer
1 D Residential Service -CA 317,536 22,437,831 29,160 10,889 0.0707
2 DC-7-A Residential Service
3 Clean Air -CA 30,538 2,247,699 2,182 13,995 0.0736
4 DL-6 Residential Service Low
5 Income Rate Assist-CA 19,261 1,146,365 1,770 10,882 0.0595
6 DM-8 Multi-FamilyResidential
7 Service -CA 1,439 90,447 17 84,647 0.0629
8 DM-9 Multi-Family Residential
9 Service -CA 451 30,248 16 28,188 0.0671
10 OL-15 Outdoor Area Lighting
11 Service -CA 460 76,023 499 922 0.1653
12 Annual Guaranteed Adj -CA 1,193
13 Less Multiple-Billing -951
14 Unbilled Revenue -1,535 -108,000 0.0704
15
16 4 Residential Service -OR 5,196,570 331,442,824 420,197 12,367 0.0638
17 14 Outdoor Area Lighting
18 Domestic and Farm -OR 1 34 2 500 0.0340
19 15 Outdoor Area Lighting
20 New Service -OR 4,060 401,127 3,835 1,059 0.0988
21 Net Metering -OR 25 1,594 3 8,333 0.0638
22 Bluesky Energy -OR 24,409 407
23 BPA Balancing Account -OR 41
24 Less Multiple-Billing -8,722
25 Annual Guaranteed Adj -OR 23,473 8
26 Unbilled Revenue -OR -18,991 225,173 -0.0119
27
28 13 Outdoor Area Lighting
29 Service Domestic &Farm-WA 1,336 144,549 1,436 930 0.1082
30 15 Outdoor Area Lighting
31 Service -WA 10 1,112 11 909 0.1112
32 16 Residential Service -WA 1,495,418 78,487,580 96,831 15,444 0.0525
33 Bluesky Energy -WA 2,707 46
34 BPA Balancing Account -WA 63
35 Less Multiple-Billing -2,236
36 Annual Guaranteed Adj -WA 2,694
37 Unbilled Revenue -WA -18,370 -934,672 0.0509
38
39 2 Residential Service WY-PPL 652,320 40,235,347 82,269 7,929 0.0617
40 3 Residential Service
41 I U I AL Billed 48,357,565 2,278,816,968 1,476,965 32,741 0.0471
42 lotal Unbilled Rev.(See instr.6)-57,091 2,477,091 C (-0.0434
43 10TAL 48,300,474 2,281,294,059 1,476,96E 32,702 0.0472
FER(:FORM NO.1 (ED.12-95)Page 304.1
Nameot kespondent I his Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
bALbb UI-ELeu I Riul I vet RA I E buHEDULES
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,"Page
300-301.If the sales under any rate schedule are classified in more than one revenue account,List the rate schedule and sales data under each
applicable revenue account subheading.
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 estimeted additional revenue billed pursuant thereto.
6.Report amount of unbilled revenue as of end of year for each applicable revenue account subheading.
une Wulliuel allu Tide of Rate sulieuule Ivivvli Suld Reveliue Aveiaye Nuillbei KWh of öales i e Fei
No·(a)(b)(c)of Cus omers Per stomer
1 Optional Service WY-PPL 113,689 5,809,444 5,081 22,375 0.0511
2 15 Outdoor Area Lighting
3 Service WY-PPL 1,377 134,834 1,431 962 0.0979
4 Bluesky Energy -WY-PPL 4,365 83
5 Net Metering -WY-PPL 12 750 1 12,000 0.0625
6 Centralia Refund -WY-PPL -261,376
7 Less Multiple-Billing -2,254
8 Annual Guaranteed Adj WY-PPL 2,050
9 Unbilled Revenue WY-PPL -2,650 -26,136 0.0099
10
11 Total Account 440 13,375,862 834,996,675 1,262,295 10,596 0.0624
12
13
14 Commercial Sales (Account 442):
15 Sch.
16 6 General Service -Distribution
17 Voltage -UT 4,599,185 217,791,516 9,246 497,424 0.0474
18 6A General Service -Distribution
19 Voltage -UT 122,998 7,840,798 1,179 104,324 0.0637
20 6B General Service
21 Time of Day -UT 108,779 4,175,886 26 4,183,808 0.0384
22 7 General Service -Energy
23 Time of Day -UT 10,190 1,535,423 5,308 1,920 0.1507
24 9 General Service -Demand
25 Time of Day -UT 195,148 6,387,472 29 6,729,241 0.0327
26 9A General Service -Demand
27 Time of Day -UT 7,581 276,743 1 7,581,000 0.0365
28 98 General Service -High
29 Voltage -UT 155 13,747 3 51,667 0.0887
30 12 General Service -Demand
31 Time of Day -UT 8,225 551,177 475 17,316 0.0670
32 14 Security Area Lighting -UT 59,038
33 19 Security Area Lighting -UT 20,612 1,557,776 652 31,613 0.0756
34 23 General Service High
35 Voltage -UT 930,715 57,058,508 48,025 19,380 0.0613
36 31 General Service High
37 Voltage -UT 9,376 435,566 1 9,376,000 0.0465
38 Security Post Top Lighting-UT 57 4,203 9 6,333 0.0737
39 Bluesky Energy -UT 114 2
40 Annual Guaranteed Adj -UT 756,777
41 I U I AL Billed 48,357,568 2,278,816,968 1,476,965 32,741 0.0471
42 I otal Unbilled Rev.(See Instr.6)-57,091 2,477,091 (C -0.0434
43 10IAL 48,300,474 2,281,294,059 1,476,965 32,702 0.0472
FERGFORM NO.1 (ED.12-95)Page 304.2
i Name of Respondent I his Report is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
BALl-b UE ELEGI Nici lYBY MA lb bbHEDULeb
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,"Page
300-301.If the sales under any rate schedule are classified in more than one revenue account,List the rate schedule and sales data under each
applicable revenue account subheading.
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 adjt stment clause state in a footnote the estimated additional revenue billed pursuant thereto.
6.Report amount of unbilled revenue as o end of year for each applicable revenue account subheading.
une Nuliivei dild Tiue ui Rate su.ieuule Ivlvvil Solo Reveliue Avelaye Isutilbei Kvvli uf Sales eo
No-(a)(b)(c)of Cus omers Per ustomer
i Less Multiple-Billings -6,044
2 Unbilled Revenue -UT 38,193 2,037,333 0.0533
3
4 25 General Service WY-UPL 83,556 6,595,429 2,006 41,653 0.0789
5 206 General Service Single
6 Meter WY-UPL 642 58,514 34 18,882 0.0911
7 207 Security Area Lighting WY-UPL 300 73,232 145 2,069 0.2441
8 208 Large General Services WY-UPL 12,722 634,332 7 1,817,429 0.0499
9 212 Street Lighting Customer
10 Owned WY-UPL 40 5,249 2 20,000 0.1312
11 Rent of Electric Prop WY-UPL 15 1
12 Centralia Refund -WY-UPL -32,246
13 Annual Guarantee Adj WY-UPL 37,088
14 Less MultipleBillings -145
15 Unbilled Revenue WY-UPL 780 39,000 0.0500
16
17 6 General Service
18 Large Power -ID 159,376 9,319,683 809 197,004 0.0585
19 6A General Service Large Power
20 Residentialand Farm -ID 18,222 1,146,834 182 100,121 0.0629
21 7 Security Area Lighting -ID 265 65,494 207 1,280 0.2471
22 7A Security Area Lighting -ID 11 3,105 16 688 0.2823
23 9 General Service
24 High Voltage -ID 23,539 1,010,789 2 11,769,500 0.0429
25 19 Commercialand Industrial
26 Space Heating -ID 12,312 879,655 344 35,791 0.0714
27 23 General Service
28 Small Power -ID 75,575 6,557,130 4,182 18,071 0.0868
29 23A General Service
30 Small Power -ID 12,295 1,060,452 1,018 12,078 0.0863
31 35 General Service Optional 1,194 49,649 1 1,194,000 0.0416
32 BPA Balancing Account -ID 9,363
33 Annual Guaranteed Adj -ID 96,718
34 Less Multiple-Billings -589
35 Unbilled Revenue -ID 5,512 298,000 0.0541
36
37 A-25 General Servie
38 Less Than 20 KW -CA 780 94,821 67 11,642 0.1216
39 A-31 CommercialWater
40 Heating-CA 346 27,196 41 8,439 0.0786
41 I U I AL Billed 48,357,565 2,278,816,968 1,476,965 32,741 0.0471
42 Total Unbilled Rev.(See Instr.6)-57,091 2,477,091 C C -0.04Š4
43 TOlAL 48,300,474 2,281,294,059 1,476,966 32,703 0.0472
FERO FORM NO.1 (ED.12-95)Page 304.3
Name of Respondent I his Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
bALbb UI-ELEUi RIGI lY BY RA lE buHbuULbb
1.Raport 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.P ovide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues,"Page
300-301.If the sales under any rate schedule are classified in more than one revenue account,List the rate schedule and sales data under each
applicable revenue account subheading.
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.T ie 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 aillings are made monthly).
5.For any rate schedule having a fuel adjt stment clause state in a footnote the estimated additional revenue billed pursuant thereto.
6.Report amount of unbilled revenue as oi end of year for each applicable revenue account subheading.
Lille IAUilldel dilÚ TitÍW UÍ RdtW bGilWOUlW IvivVli ÕUI UVellüW Aveldge ÑUilluti Kvvil UÍ Õd Wh WI
No (a)(b)(c)of Cus omers Per ustomer h
1 A-32 General Service 20 KW
2 and over -CA 122,815 11,359,829 7,120 17,249 0.0925
3 A-36 Large General Service
4 100 KW and over -CA 89,332 6,457,886 228 391,807 0.0723
5 AT-48 Large General Service
6 TOU 500 KW -CA 41,590 2,301,490 8 5,198,750 0.0553
7 OL-15 Outdoor Area Lighting
8 Service -CA 831 138,202 617 1,347 0.1663
9 OL-42 Airway and Athletic Field
10 Lighting Service -CA 226 26,385 39 5,795 0.1167
11 Annual Guaranteed Adj -CA 53,173
12 Less Multiple Billings -1,092
13 Unbilled Revenue -CA -605 -70,000 0.1157
14
15 14 Outdoor Area Lighting
16 Domestic and Farm -OR 20
17 15 Outdoor Area Lighting
18 Domestic and Farm -OR 10,909 997,567 5,079 2,148 0.0914
19 24 General Service Domestic
20 and Farm -OR -31 -2,318 5 -6,200 0.0748
21 25 General Service Domestic
22 and Farm -OR 2,101,789 132,651,307 69,718 30,147 0.0631
23 27 Large General Service -OR 1,730,536 80,367,209 2,247 770,154 0.0464
24 47T Large General Service and
25 Partial Requirements-OR 569 100,108 1 569,000 0.1759
26 48T Large General Service TOU-OR 592,618 25,429,307 78 7,597,667 0.0429
27 54 Recreational Field Lighting
28 Lighting -OR 967 72,642 109 8,872 0.0751
29 Bluesky Energy -OR 40,352 7
30 BPA Balancing Account -OR -5
31 Annual Guaranteed Adj -OR 19 991,658 52.1925
32 Less Multiple Billings -9,720
33 Unbilled Revenue -OR -17,852 -714,000 0.0400
34
35 13 Outdoor Area Lighting Sentice
36 Domestic and Farm -WA 783 84,467 702 1,115 0.1079
37 15 Outdoor Area Lighting
38 Service -WA 1,873 186,063 964 1,943 0.0993
39 24 General Service -WA 426,704 23,550,523 11,886 35,900 0.0552
40 25 General Service Domestic
41 lul AL Billed 48,357,566 2,278,816,968 1,476,96E 32,741 0.0471
42 Total Unbilled Rev.(See Instr.6)-57,091 2,477,091 C C -0.0434
43 TÖTAL 48,300,474 2,281,294,059 1,476,965 32,703 0.0472
FERí:FORM NO.1 (ED.12-95)Page 304.4
Name of Respondent I his Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
bALt-b Ut-ELeu I RIGI lyBy RA I b buHEDULeb
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,"Page
300-301.If the sales under any rate schedule are classified in more than one revenue account,List the rate schedule and sales data under each
applicable revenue account subheading.
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.T 1e 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.F3r any rate schedule having a fuel adjt stment clause state in a footnote the estimoted additional revenue billed pursuant thereto.
6.Report amount of unbilled revenue as o end of year for each applicable revenue account subheading.
Une Isunibui and Title of Rate soliedule MWII 3uld Reveliue Aveiaye Nunibei KWil of 3aies i e ei
No·(a)(b)(c)of Cusd)omers Per stomer d
1 and Farm -WA 53,884 3,109,868 3,277 16,443 0.0577
2 35 Large General Service
3 Less Than 1,000 KW -WA 65,748 2,792,561 75 876,640 0.0425
4 36 Large General Service
5 Less Than 1,000 KW -WA 631,316 26,989,301 753 838,401 0.0428
6 38 Space and Water Heating -WA 370 20,787 11 33,636 0.0562
7 42 ControlledWater
8 Heating Service -WA 564 36,057 135 4,178 0.0639
9 48T Large General Service TOU
10 1,000 KW and over -WA 177,235 6,754,717 25 7,089,400 0.0381
11 54 Recreational Field
12 Lighting -WA 360 23,053 33 10,909 0.0640
13 BPA Balancing Account -WA -10
14 Annual Guaranteed Adj -WA -27 112,119 -4.1526
15 Less Multiple-Billings -2,224
16 Unbilled Revenue -WA -2,922 -103,000 0.0352
17
18 2 ResidentialService WY-PPL 76
19 15 Outdoor Area Lighting
20 Service WY-PPL 4,056 392,029 2,050 1,979 0.0967
21 25 General Service WY-PPL 504,173 27,933,688 18,051 27,930 0.0554
22 43 CommercialWater
23 Heating WY-PPL 9 407 2 4,500 0.0452
24 45 Large General Service WY-PPL 384,610 16,405,374 402 956,741 0.0427
25 46 Large General Service TOU
26 1,000 KW and over WY-PPL 92,899 3,200,742 11 8,445,364 0.0345
27 54 Recreational Field
28 Lighting WY-PPL 532 31,237 54 9,852 0.0587
29 Bluesky Energy -WY-PPL 279 3
30 Centralia Refund -WY-PPL -290,355
31 Annual Guaranteed Adj WY-PPL 441,884
32 Less Multiple-Billings -2,552
33 Unbilled Revenue WY-PPL -3,247 -171,000 0.0527
34
35 Total Commercial (Account 442)13,471,314 700,213,182 175,420 76,795 0.0520
36
37 Industrial Sales (Acct 442):
38 Sch.
39 6 General Service
40 Distribution -UT 1,518,890 71,101,457 1,492 1,018,023 0.0468
41 I U \AL Billed 48,3b/,bbt 2,278,816,968 1,476,96E 32,741 0.0471
42 Total Unbilled Rev.(See instr.6)-5/,091 2,477,091 C C -Ò.Ò434
43 TÖTAL 48,300,474 2,281,294,059 1,476,96E 32,702 0.0472
FERO FORM NO.1 (ED.12-95)Page 304.5
Name of Respondent I his Report is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
BALab UE ELEUIRIGI I Y by RAI E SCHEDULt-b
1.Report below for each rate schedule in effect during the year the MWHof electricity sold,revenue,average number of customer,average Kwh percustomer,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 each
applicable revenue account subheading.
3.Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residentialscheduleandanoffpeakwaterheatingschedule),the entries in column (d)for the special schedule should denote the duplication in number of reportedcustomers.
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 adjustmentclause 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.
LIAS NUrubel allu Tine UÏ Eidte bulledule Ivivvb Sulu EtevellUU Aveldge ikullibui b"vvh UÏ3dies le el
No-(a)(b)(c)of Cus omers Per stomer
1 6A General Service-Energy
2 Time of Day -UT 94,323 4,947,845 145 650,503 0.0525
3 6B General Service-Demand
4 Time of Day -UT 1,661 87,975 3 553,667 0.0530
5 9 General Service -High
6 Voltage -UT 1,571,752 48,836,147 93 16,900,559 0.0311
7 9A General Service-Demand
8 Time of Day -UT 774,267 23,620,053 25 30,970,680 0.0305
9 9B General Service-Demand
10 Time of Day -UT 38,283 1,422,876 1 38,283,000 0.0372
11 10 Irrigation &Soil Drainage
12 Pumping Power -UT 175,659 7,103,120 2,082 84,370 0.0404
13 12 Street Lighting
14 Customer Owned -UT 93 7,615 16 5,813 0.0819
15 19 Commercialand Industrial
16 Space Heating -UT 304 23,538 26 11,692 0.0774
17 21 Electric Fumace Operations
18 Limited Service -UT 3,480 273,474 5 696,000 0.0786
19 23 General Service-Small
20 Commercial/Industrial-UT 62,821 3,959,081 4,212 14,915 0.0630
21 23B General Service-Demand
22 Time of Day -UT 5 408 2 2,500 0.0816
23 30 Large Industrial Service-UT
24 31 Standby Service -UT 729 69,034 1 729,000 0.0947
25 Security Area Lighting -UT 1,922 265,558 667 2,882 0.1382
26 Special Contracts -UT 2,477,873 59,094,998 9 275,319,222 0.0238
27 Less Multiple-Billings -534
28 Annual Guaranteed Adj -UT 560,812 15,214,473 1 560,812,000 0.0271
29 Unbilled Revenue -UT 41,101 1,696,331 0.0413
30
31 206 General Service Single
32 Meter WY-UPL 43,621 2,715,620 399 109,326 0.0623
33 207 Security Area Lighting WY-UPL 11 3,156 6 1,833 0.2869
34 208 Large Service Optional WY 9,995 464,980 2 4,997,500 0.0465
35 209 General Service High Voltage 646 35,367 1 646,000 0.0547
36 210 Irrigation and Soil
37 Drainage WY-UPL 1,029 81,418 16 64,313 0.0791
38 217 Large Power Service WY-UPL 730,342 25,298,606 13 56,180,154 0.0346
39 218 Back-up,Maintenance and 3,109 235,866 1 3,109,000 0.0759
40 Special Contracts WY-UPL 175,147 5,642,493 4 43,786,750 0.0322
41 I Ul AL Hilled 48,357,565 2,278,816,968 1,476,965 32,741 0.0471
42 Total Unbilled Rev.(See Instr.6)-57,091 2,477,091 C C -0.0434
43 TÖTAL 48,300,474 2,281,294,059 1,476,965 32,702 0.0472
FERGFORM NO.1 (ED.12-95)Page 304.6
Name ot Respondent I his keport Is:Date of Report Ÿear of Report |
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
SALebuk ELEUIRIbilY BY RAlb buHEDULES
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,e×cluding 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,"Page
300-301.If the sales under any rate schedule are classified in more than one revenue account,List the rate schedule and sales data under each
applicable revenue account subheading.
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 adjt stment clause state in a footnote the estimated additional revenue billed pursuant thereto.
6.Report amount of unbilled revenue as o end of year for each applicable revenue account subheading.
No-(a)(b)(c)of Cusd)omers Per stomer
1 Centralia Refund -WY-UPL -109,898
2 Annual Guarantee Adj WY-UPL 24,955
3 Less Multiple-Billing -6
4 Unbilled Revenue WY-UPL 16,693 662,000 0.0397
5
6 6 General Service Large Power
7 Residential and Farm ID-UPL 72,255 3,815,557 118 612,331 0.0528
8 6A General Service Large Power
9 Residential and Farm ID-UPL 7,551 411,307 40 188,775 0.0545
10 7 Security Area Lighting ID-UPL 18 4,835 21 857 0.2686
11 7A Security Area Lighting ID-UPL 2 599 3 667 0.2995
12 8 General Service
13 Medium Voltage ID-UPL 2,749 153,701 4 687,250 0.0559
14 9 General Service
15 High Voltage ID-UPL 84,010 3,545,719 12 7,000,833 0.0422
16 10 Irrigation and Soil
17 Drainage Pumping ID-UPL 600,756 25,127,658 4,458 134,759 0.0418
18 12 Street Lighting
19 Customer Owned ID-UPL 25 2,565 3 8,333 0.1026
20 19 Commercial and Industrial
21 Space Heating ID-UPL 274 20,250 8 34,250 0.0739
22 23 General Service
23 Small Power ID-UPL 7,954 686,328 392 20,291 0.0863
24 23A General Service
25 Small Power ID-UPL 2,897 263,237 296 9,787 0.0909
26 BPA Balancing Account ID-UPL 1,744,571
27 Special Contracts ID-UPL 1,466,828 28,889,214 4 366,707,000 0.0197
28 Annual Guaranteed Adj ID-UPL 115,501
29 Less Multiple-Billings -27
30 Unbilled Revenue ID-UPL -15,377 -370,664 0.0241
31
32 A-25 General Service
33 Less Than 20 KW -CA 922 89,908 108 8,537 0.0975
34 A-32 General Service 20 KW
35 and over -CA 1,593 167,419 20 79,650 0.1051
36 A-36 Large General Service
37 100 KW and over -CA 11,746 905,693 24 489,417 0.0771
38 AT-48 Large General Service
39 TOU 500 KW -CA 50,567 2,862,791 7 7,223,857 0.0566
40 OL-15 Outdoor Area Lighting
41 10lAL Billed 48,3b/,b6t 2,278,816,968 1,476,965 32,741 0.0471
42 Total Unbilled Rev.(See Instr.6)-5/,091 2,4//,091 C C -0.0434
4Š TOTAL 48,300,474 2,281,294,059 1,476,965 32,702 0.0472
FERG FORM NO.1 (ED.12-95)Page 304.7
Name of Respondent I his Report Is:Date of Report Year of keport
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
SALbb Ul-ELEUl RIGI I vbY RA lE buHEDULab
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.P ovide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues,"Page
300-401.If the sales under any rate schedule are classified in more than one revenue account,List the rate schedule and sales data under eachappli^able revenue account subheading.
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.T le 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 Jillings 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.Raport amount of unbilled revenue as of end of year for each applicable revenue account subheading.
une Nullibel alid Tille of Race soliedu¡e MWII öu.d Reveliue Aveisye Nulill.ael Kvvli of õeies e er
No-(a)(b)(c)of Cus omers Per stomer
1 Service -CA 22 3,102 9 2,444 0.1410
2 PA-20 Agricultural Pumping
3 Service -CA 62,778 3,996,091 1,287 48,779 0.0637
4 PA-150 Agricultural Pumping
5 Service -CA 30,218 154,137 594 50,872 0.0051
6 Klamath Falls Minimum -CA 26,998
7 Annual Guaranteed Adj -CA 16,848
8 Special Contracts -CA 2,115 75,217 0.0356
9 Less Multiple-Billings -118
10 Unbilled Revenue -CA -1,030 -44,000 0.0427
11
12 15 Outdoor Area Lighting 608 52,097 212 2,868 0.0857
13 New Service -OR
14 25 General Service -OR 97,165 6,399,789 1,957 49,650 0.0659
15 26 Large General Service
16 Less Than 1,000 KW -OR 48 2,464 0.0513
17 27 Large General Service -OR 430,522 20,679,335 400 1,076,305 0.0480
18 33 Klamath Basic Irrigation
19 and Drainage Pumping -OR 54,328 394,845 687 79,080 0.0073
20 35 Klamath Basic Irrigation
21 and Drainage Pumping -OR 55,109 330,653 1,299 42,424 0.0060
22 36 Partial Requirements Service
23 Less Than 1 MW -OR 65 50,022 2 32,500 0.7696
24 41 Agricultural Pumping
25 Service -OR 126,418 7,192,740 6,476 19,521 0.0569
26 47T Large General Service 153,570 6,407,522 4 38,392,500 0.0417
27 Partial -OR
28 48T Large General Service TOU-OR 3,320,205 132,728,256 139 23,886,367 0.0400
29 Special Contracts -OR 183,312 9,085,924 3 61,104,000 0.0496
30 Annual Guaranteed Adj -OR 189,475
31 Less Multiple-Billings -675
32 Unbilled Revenue -OR -9,487 1,743,631 -0.1838
33
34 13 Outdoor Area Lighting Service
35 Domestic and Farm -WA 200 19,145 76 2,632 0.0957
36 24 General Service -WA 23,161 1,277,190 408 56,767 0.0551
37 25 General Service
38 Domestic and Farm -WA 6,585 395,853 170 38,735 0.0601
39 35 Large General Senrice
40 Less Than 1,000 KW -WA 7,350 318,981 11 668,182 0.0434
41 10 \AL Billed 48,357,565 2,278,816,968 1,476,965 32,741 Ò.0471
42 Total Unbilled Rev.(See Instr.6)-57,091 2,477,091 C C -0.0434
43 TÖTAL 48,300,474 2,281,294,059 1,476,966 32,702 0.0472
FERG FORM NO.1 (ED.12-95)Page 304.8
Name of Respondent I his Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
SALE-bub ELECIRlull Y BY RAIEscHeudLEb
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,e×cluding 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 eathapplicablerevenueaccountsubheading.
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 reportedcustomers.
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.
une imuilibel and Title of Rate sulleduie lv!Wil Suld Reveliue Avelaye Nuitivel KWl!uf 3eies eo
No·(a)(b)(c)of Cusd)omers Per stomer d
1 36 Large General Service
2 Less Than 1,000 KW -WA 180,202 7,730,569 156 1,155,141 0.0429
3 40 Agricultural Pumping
4 Service -WA 149,474 7,410,057 5,453 27,411 0.0496
5 42 Controlled Water
6 Heating Service -WA 59 3,373 3 19,667 0.0572
7 48T Large General Service TOU
8 1,000 KW and over -WA 407,685 15,249,790 36 11,324,583 0.0374
9 BPA Balancing Account -WA -12
10 Frost Protection -WA 152
11 Special Contracts -WA 452,468 11,485,650 1 452,468,000 0.0254
12 Direct Access-ESP Revenue 253 6,350 0.0251
13 Annual Guaranteed Adj -WA 80,359
14 Less Multiple-Billings -183
15 Unbilled Revenue -WA -11,742 158,000 -0.0135
16
17 15 Outdoor Area Lighting
18 Service WY-PPL 110 10,075 61 1,803 0.0916
19 25 General Service WY-PPL 81,174 4,150,978 1,655 49,048 0.0511
20 33 Partial Requirements
21 Service WY-PPL 591,165 19,835,602 5 118,233,000 0.0336
22 40 Agricultural Pumping
23 Service WY-PPL 14,676 655,067 514 28,553 0.0446
24 45 Large General Service WY-PPL 165,916 6,744,493 116 1,430,310 0.0407
25 46 Large General Service TOU
26 1,000 KW and over WY-PPL 2,905,992 89,976,416 80 36,324,900 0.0310
27 Special Contracts WY-PPL 697,080 19,380,003 103 6,767,767 0.0278
28 Centralia Refund WY-PPL -961,940
29 Annual Guaranteed Adj WY-PPL 396,553
30 Less Multiple-Billing -111
31 Unbilled Revenue WY-PPL -27,474 -802,283 0.0292
32
33 Total Industrial (Account 442)20,749,638 714,220,302 35,003 592,796 0.0344
34
35 Public Street &Highway Lighting
36 (Account 444):
37 Sch.
38 7 Security Area Lighting -UT 336 49,571 84 4,000 0.1475
39 11 Street Lighting-Company
40 Owned -UT 27,018 4,473,992 1,143 23,638 0.1656
41 lU IAL Billed 48,35/,56t 2,278,816,968 1,476,96E 32,741 0.0471
42 Total Unbilled Rev.(See instr.6)-57,091 2,4//,091 C C -Ò.Ò4Š4
43 TÓTAL 48,300,474 2,281,294,059 1,476,965 32,703 0.0472
FERO FORMNO.1 (ED.12-95)Page 304.9
Name of Respondent I his Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
SALeb UI-ELau l Riul lyBY RA lb bbHEDULab
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,"Page
300-301.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.T ie 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 Jillings are made monthly).
5.F ar 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.
une Wuilibel aiid Titie of Rate soliedule Iv!Wil 3uld Reveliue Aveiage Nunibei KvVli uf ädies e er
No-(a)(b)(c)of Cus omers Per stomer
1 12 Street Lighting-Customer
2 Owned -UT 36,712 2,560,177 2,643 13,890 0.0697
3 13 Decor Customer-Owned -UT 4,417 146,139 12 368,083 0.0331
4 Security Lighting -UT 81 4,201 4 20,250 0.0519
5 Other -UT 1 439 1 1,000 0.4390
6 Annual Guaranteed Adj -UT 4,374
7 Less Multiple Billings -1,122
8 Unbilled Revenue -UT 962 57,000 0.0593
9
10
11 212 Street Lighting Customer
12 Owned WY-UPL 1,543 368,272 114 13,535 0.2387
13 Centralia Refund -WY-UPL -250
14 Less Multiple-Billings -66
15 Unbilled Revenue WY-UPL -2 -1,000 0.5000
16
17 11 Street Lighting Company
18 Owned ID-UPL 136 38,750 29 4,690 0.2849
19 12 Street Lighting Customer
20 Owned ID-UPL 2,086 261,707 176 11,852 0.1255
21 Less Multiple-Billings -55
22 Unbilled Revenue ID-UPL 5
23
24 LS-51 High Pressure Sodium
25 Vapor -CA 739 143,006 81 9,123 0.1935
26 LS-52 Street Lighting Company
27 Owned -CA 2 2,020 5 400 1.0100
28 LS-53 Street Lighting Customer
29 Owned -CA 1,468 126,198 130 11,292 0.0860
30 LS-58 Street Lighting Customer
31 Owned -CA 248 25,058 25 9,920 0.1010
32 OL-15 Outdoor Area Lighting
33 Service -CA 3 451 2 1,500 0.1503
34 Less Multiple-Billings -CA -105
35
36 15 Outdoor Area Lighting
37 New Service -OR 29 3,570 14 2,071 0.1231
38 50 Mercury Vapor Street
39 Lighting -OR 14,370 1,139,949 333 43,153 0.0793
40 51 High Pressure Sodium Vapor
41 lul AL Billed 48,357,565 2,278,816,968 1,476,965 32,741 Ò.Ò471
42 1otal Unbilled Rev.(See Instr.6)-57,091 2,477,091 C C -0.Ò434
43 T OTAL 48,300,474 2,281,294,059 1,476,965 32,702 0.0472
FERO FORM NO.1 (ED.12-95)Page 304.10
Name of Respondent i his Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
SALEb UI-ELEUi Rlui I YBY NA lE SCHEDULab
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,"Page
300-301.If the sales under any rate schedule are classified in more than one revenue account,List the rate schedule and sales data under each
applicable revenue account subheading.
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 amountof unbilled revenue as of end of year for each applicable revenue account subheading.
Line INulilheldild Title UE RdEU bbileau.e IvlWil õeid Reveliue avelaye Nullibei Kvvh of Sales e er
No.(a)(b)(c)of Cus omers Per ustomer
1 Street Lighting -OR 16,026 2,009,056 645 24,847 0.1254
2 52 Street Lighting Company
3 Owned -OR 2,294 218,581 116 19,776 0.0953
4 53 Street Lighting Customer
5 Owned -OR 9,023 419,982 207 43,589 0.0465
6 Less Multiple-Billings -713
7
8 12 Street Lighting -WA 76
9 51 Street Lighting -High
10 Pressure Sodium -WA 2,621 378,831 110 23,827 0.1445
11 52 Street Lighting Company
12 Owned -WA 399 36,709 20 19,950 0.0920
13 53 Street Lighting Customer
14 Owned -WA 3,869 191,670 195 19,841 0.0495
15 57 Street Lighting -Mercury
16 Vapor -WA 2,240 192,738 64 35,000 0.0860
17 Less Multiple-Billings -144
18
19 15 Outdoor Area Lighting WY-PPL 13 1,122 3 4,333 0.0863
20 51 Street Lighting High Pressure
21 Sodium Vapor WY-PPL 4,024 543,060 174 23,126 0.1350
22 53 Street Lighting Mercury
23 Lighting WY-PPL 5,493 433,038 233 23,575 0.0788
24 57 Street Lighting Company
25 Owned WY-PPL 607 89,393 34 17,853 0.1473
26 58 Street Lighting Customer
27 Owned WY-PPL 1,565 73.286 53 29,528 0.0468
28 212 Street Lighting Customer
29 Owned WY-PPL 19 1,248 2 9,500 0.0657
30 Centralia Refund -WY-PPL -1,704
31 Less Multiple-Billings -228
32
33
34 Total Account 444 138,347 13,990,710 4,219 32,791 0.1011
35 Other Sales to Public Authorities
36 Account 445:
37 Sch.
38 6 General Service -Distribution
39 Voltage -UT 54,687 2,304,237 8 6,835,875 0.0421
40 7 Security Area Lighting -UT 22 3,921 6 3,667 0.1782
41 10 I AL Billed 48,357,565 2,278,816,968 1,476,965 32,741 0.0471
42 Total Unbilled Rev.(Šee Instr.6)-57,Ò91 2,477,091 C C -Ò.043A
43 TÖTAL 48,300,474 2,281,294,059 1,476,965 32,703 0.0472
¯ERC FORMNO.1 (ED.12-95)Page 304.11
Name of Respondent I his Report Is:Date ot Report Year ot keport
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
bALbb UF ELbu l RIGI I vby RA I E buHI-UULES
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 sâme 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 estimeted additional revenue billed pursuant thereto.
6.Report amount of unbilled revenue as of end of year for each applicable revenue account subheading.
une I unibel and Tide viRale sulleduie ivlWla öuld Reveilue avelaye lúuinbei KWII of Sales F e ei
No (a)(b)(c)of Cus omers Per stomer
1 9 General Service -High
2 Voltage -UT 444,275 13,721,800 6 74,045,833 0.0309
3 23 General Sentice -Small
4 Commerciallindustrial -UT 150 8,845 9 16,667 0.0590
5 Less Multiple-Billings -1
6 UnbilledRevenues -UT 3,129 68,045 0.0217
7
8 Other Sales -WY-PPL 63,050 1,766,343 0.0280
9
10
11 Total Account 445 565,313 17,873,191 28 20,189,750 0.0316
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 lU I AL Billed 48,357,56E 2,278,816,968 1,476,965 32,741 0.0471
42 Ïotal UnbilledRev.(See Instr.6)-57,091 2,477,091 C C -0.0434
43 TÖTAL 48,300,474 2,281,294,059 1,476,96E 32,703 0.0472
FERt:FORM NO.1 (ED.12-95)Page 304.12
BLANK PAGE
(Next Page is:310)
Name of Respondent I his Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
SALES I-UR kbSALi-(Account 4 /)
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 e×changes 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 thePurchasedPowerschedule(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 anyownershipinterestoraffiliationtherespondenthaswiththepurchaser.
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.,thesupplierincludesprojectedloadforthisserviceinitssystemresourceplanning).In addition,the reliability of requirements service mustbethesameas,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 economicreasonsandisintendedtoremainreliableevenunderadverseconditions(e.g.,the supplier must attempt to buy emergency energyfromthirdpartiestomaintaindeliveriesofLFservice).This category should not be used for Long-term firm service which meets thedefinitionofRQservice.For all transactions identified as LF,provide in a footnote the termination date of the contract defined as theearliestdatethateitherbuyerorsettercanunilaterallygetoutofthecontract.
IF -for intermediate-term firm service.The same as LF service except that "intermediate-term"means longer than one year but Lessthanfiveyears.
SF -for short-term firm service.Use this category for all firm services where the duration of each period of commitment for service isoneyearorless.
LU -for Long-term service from a designated generating unit."Long-term"means five years or Longer.The availability and reliability ofservice,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 Nameof Company or Public Authority Statistical FERCRate Avera e Actual Demand (MW)
No.(Footnote Affiliations)C -Sache Ireber
DMe
a d (MonthÛy N Demant Month y CP emand
(a)(b)(c)(d)(e)(f)
1 RequirementSales:
2 Blanding City RQ T-6 1 1 0.749
3 Brigham City RQ 318 15.9 15.9 14.206
4 Deaver,Town of RQ T-4 0.2 0.2 NA
5 Helper City RQ T-6 0.9 0.9 0.744
6 Helper City Annex RQ T-6 0.6 0.6 0.545
7 Navajo Tribal Utility Authority (Mexica RQ T-6 0.2 0.2 0.134
8 Navajo Tribal Utility Authority (Red Me RQ T-6 0.6 0.6 0.538
9 Portland General Electric Company RQ 147 NA NA NA
10 Price City RQ T-6 11.2 11.2 9.36
11
12
13
14 NonrequirementSales
Subtotal RQ 0 0 0
Subtotal non-RQ 0 0 0
Total 0 0 0
FERCFORMNO.1 (ED.12-90)Page 310
Name of Respondent I his Report is:Date of Report Vear of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
SI.LES EUR RESALE(Account 44/)(Cantinued)
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 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 DemandCharges Energy Öharges Uther arges
(g)(h)(i)(i)(k)
1
6,598 93,240 114,716 417 208,373 Ž
93,639 1,484,513 1,631,188 11,601 3,127,302 Š
869 11,986 15,715 27,701 4
5,097 96,078 90,377 1,625 188,080 5
3,826 53,939 83,596 1,108 138,643 6
855 19,075 14,954 33 34,062 7
3,740 15,690 109,660 284 125,634 8
12,661 644,624 9,295 653,919 9
61,270 1,041,724 1,068,603 8,330 2,118,657 1Ò
11
12
13
14
188,555 2,816,245 3,773,433 32,693 6,622,371
29,764,936 196,899,703 1,534,913,327 -2,284,275 1,729,528,755
29,953,491 199,715,948 1,538,686,760 -2,251,582 1,736,151,126
FERC FORM NO.1 (ED.12-90)Page 311
Name of Respondent Ihls Report is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
SALES FUR kkbALE (Account 44/)
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 PublicAuthority Statistical FERC Rate Avera e Actual Demand (MW)
No.(Footnote Affiliations)C -Sacrihe
u br DMern
d (Month y Deman.Month y CP emand
(a)(b)(c)(d)(e)(f)
1 American Electric Power AD T-3 NA NA NA
2 American Electric Power OS T-3 NA NA NA
3 American Electric Power OS WSPP NA NA NA
4 American Electric Power SF T-3 NA NA NA
5 American Electric Power SF WSPP NA NA NA
6 Anaheim,City of OS WSPP NA NA NA
7 Anaheim,City of SF WSPP NA NA NA
8 Aquila Power Corporation OS WSPP NA NA NA
9 Aquila Power Corporation SF T-3 NA NA NA
10 Aquila Power Corporation SF WSPP NA NA NA
11 Arizona Electric Power Cooperative IF T-12 44 44 44
12 Arizona Public Service Company OS T-3 NA NA NA
13 Arizona Public Service Company OS WSPP NA NA NA
14 Arizona Public Service Company SF T-3 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 I his Report is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
bALES I-UR RESALE (Account 44/)(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 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 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 Ënergy Öharges Other Charges Total ($)Line
($)($)($)(h+i+j)No.
(9)(h)(i)(j)(k)
16,900 16,900 1
120 3,600 3,600 2
100 5,375 5,375 Š
45 630 630 4
575,185 42,175,395 42,175,395 5
118 9,350 9,350 6
44,340 6,712,650 6,712,650 7
310 67,500 67,500 8
140 24,150 24,150 9
465,226 33,133,367 33,133,367 10
114,146 3,836,160 1,851,448 5,687,608 11
100 2,350 2,350 12
15,994 726,068 726,068 13
575 15,350 15,350 14
188,555 2,816,245 3,773,433 32,693 6,622,371
29,764,936 196,899,703 1,534,913,327 -2,284,275 1,729,528,755
29,953,491 199,715,948 1,538,686,760 -2,251,582 1,736,151,126
FERC FORM NO.1 (ED.12-90)Page 311.1
Name of Respondent I his Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
SALES FUR REbALE (Account 44/)
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 thePurchasedPowerschedule(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 anyownershipinterestoraffiliationtherespondenthaswiththepurchaser.
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.,thesupplierincludesprojectedloadforthisserviceinitssystemresourceplanning).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 economicreasonsandisintendedtoremainreliableevenunderadverseconditions(e.g.,the supplier must attempt to buy emergency energyfromthirdpartiestomaintaindeliveriesofLFservice).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 Lessthanfiveyears.
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"meansLongerthanoneyearbutLessthanfiveyears.
Line Name of Company or Public Authority Statistical FERC Rate Avera e Actual Demand (MW)
No.(Footnote Affiliations)C s -Sa ur$ber
DMe
a d (Month yS$Demant Month yœCP Demand
(a)(b)(c)(d)(e)(f)
1 Arizona Public Senrice Company SF WSPP NA NA NA
2 Avista Corporation AD T-12 NA NA NA
3 Avista Corporation AD WSPP NA NA NA
4 Avista Corporation OS WSPP NA NA NA
5 Avista Corporation SF T-12 2 17 0
6 Avista Corporatio;SF T-3 NA NA NA
7 Avista Corporation SF WSPP NA NA NA
8 Avista Energy,Inc.AD WSPP NA NA NA
9 Avista Energy,Inc.OS WSPP NA NA NA
10 Avista Energy,Inc.OS WSPP NA NA NA
11 Avista Energy,Inc.SF WSPP NA NA NA
12 Azusa Light &Water Department SF T-3 NA NA NA
13 Azusa Light &Water Department SF WSPP NA NA NA
14 Black Hills Power &Light Company AD T-12 NA NA NA
Subtotal RQ 0 0 0
Subtotal non-RQ 0 0 0
Total 0 0 0
FERCFORMNO.1 (ED.12-90)Page 310.2
Name of Respondent I his Report is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
SI.LES EUR RbbALb (Account 44/)(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 riature
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 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-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 on
the Last -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 harges Energy Charges Uther arges
(9)(h)(i)(j)(k)
693,940 52,360,341 52,360,341 1
-2,100 -2,100 Ž
400 10,060 10,060 3
150 7,600 7,600 4
61 3,000 2,684 5,684 5
75 2,025 2,025 6
107,422 6,920,484 6,920,484 7
-650 -54,280 -54,280 8
594 105,450 105,450 9
325 325 10
345,980 17,820,067 17,820,067 11
160 10,320 10,320 12
248 9,392 9,392 13
-10 -300 -300 14
188,555 2,816,245 3,773,433 32,693 6,622,371
29,764,936 196,899,703 1,534,913,327 -2,284,275 1,729,528,755
29,953,491 199,715,948 1,538,686,760 -2,251,582 1,736,151,126
FERC FORM NO.1 (ED.12-90)Page 311.2
Name of Respondent I his Report is:Date ot keport Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
SALE-8 I-UR RESALE(Account 4,/)
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 creditsforenergy,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 provideon 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 FERCRate Avera e Actual Demand (MW)
No.(Footnote Affiliations)C s -Sac Irenb
r
DMe rd (Month I Demant Month y
CmP emand
(a)(b)(c)(d)(e)(f)
1 Black Hills Power &Light Company LF 236 70 70 68
2 Black Hills Power &Light Company LF 246 NA NA NA
3 Black Hills Power &Light Company LF 424 30 30 4
4 Black Hills Power &Light Company OS T-12 NA NA NA
5 Black Hills Power &Light Company OS T-3 NA NA NA
6 Black Hills Power &Light Company SF T-12 NA NA NA
7 Black Hills Power &Light Company SF T-3 NA NA NA
8 Bonneville Power Administration AD T-12 NA NA NA
9 Bonneville Power Administration LU T-12 NA NA NA
10 Bonneville Power Administration SF T-3 NA NA NA
11 Bonneville Power Administration SF WSPP NA NA NA
12 BP Energy Company SF WSPP NA NA NA
13 British Columbia Hydro Power Authority OS WSPP NA NA NA
14 British Columbia Hydro Power Authority 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 310.3
Nameof Respondent I his Report is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
S/,Li-8 FUM MbbALE (Account 44/)(continued)
OS -for other serlice.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 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 (\).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 Uther Charges Total ($)Line
($)($)($)(h+i+j)No.
(9)(h)(i)(j)(k)
505,621 9,762,778 4,857,844 14,620,622 1
68 1,295 1,295 Ž
2,380 450,000 342,839 792,839 3
19,750 656,595 656,595 4
10 270 270 5
14,720 823,175 823,175 6
110 27,100 27,100 7
228,582 228,582 8
42,345 2,858,568 2,858,568 9
250 46,250 46,250 10
170,421 17,370,980 17,370,980 11
51,400 5,693,900 5,693,900 12
104 2,704 2,704 13
307,410 26,336,361 26,336,361 14
188,555 2,816,245 3,773,433 32,693 6,622,371
29,764,936 196,899,703 1,534,913,327 -2,284,275 1,729,528,755
29,953,491 199,715,948 1,538,686,760 -2,251,582 1,736,151,126
FERCFORM NO.1 (ED.12-90)Page 311.3
Name of Respondent I his Report is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
bALES l-Uk kbbALE (Account 4</)
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 anyownershipinterestoraffiliationtherespondenthaswiththepurchaser.
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 Lessthanfiveyears.
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 -Sachne Irenber DMeorahr
d (MonthÛy N Demant Month yeCP emand
(a)(b)(c)(d)(e)(f)
1 Burbank,City of OS WSPP NA NA NA
2 Burbank,City of SF WSPP NA NA NA
3 California ISO AD T-12 NA NA NA
4 Califomia ISO SF T-12 NA NA NA
5 Califomia Power Exchange AD T-12 NA NA NA
6 Califomia Power Exchange AD WSPP NA NA NA
7 Califomia Power Exchange SF T-12 NA NA NA
8 Califomia Power Exchange SF WSPP NA NA NA
9 Cargill-Alliant,LLC AD T-3 NA NA NA
10 Cargill-Alliant,LLC OS WSPP NA NA NA
11 Cargill-Alliant,LLC SF WSPP NA NA NA
12 Cheyenne Light,Fuel and Power Company IF 421 135 135 135
13 Cinergy Senrices Inc.SF WSPP NA NA NA
14 Clark Public Utilities AD T-12 NA NA NA
Subtotal RQ 0 0 0
Subtotal non-RQ 0 0 0
Total 0 0 0
FERC FORMNO.1 (ED.12-90)Page 310.4
Name of Respondent I his Report is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
SLü-8 FUR RE-bALl-(Account44/)(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 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 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 Page
401,iine 24.
10.Footnote entries as required and provide explanations following all required data.
MegaWattHours REVENUE
Sold Demand Charges Ênergy Óharges Other Charges Total ($)Line
($)($)($)(h+i+j)No.
(9)(h)(i)(i)(k)
415 35,564 35,564 1
160 3,680 3,680 2
-534,487 -534,487 3
692,595 76,634,156 76,634,156 4
-512,975 757,024 757,024 5
512,975 -13,171 -13,171 6
1,192,743 87,406,442 87,406,442 7
6,041 31,375,029 31,375,029 8
-9,800 -9,800 9
567 34,071 34,071 1Ò
30,088 2,347,398 2,347,398 11
971,242 8,348,583 18,307,912 26,656,495 12
73,200 4,350,200 4,350,200 13
-6 226,352 226,352 14
188,555 2,816,245 3,773,433 32,693 6,622,371
29,764,936 196,899,703 1,534,913,327 -2,284,275 1,729,528,755
29,953,491 199,715,948 1,538,686,760 -2,251,582 1,736,151,126
FERC FORM NO.1 (ED.12-90)Page 311.4
Name of Respondent I nis Report Is:Date of Report Year ot Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
SALbb Fuk RESALE(Account49/)
1.Report all sales for resale (i.e.,sales to purchasers other than ultimate consumers)transacted on a settlement basis other thanpowerexchangesduringtheyear.Do not report exchanges of electricity (i.e.,transactions involving a balancing of debits and creditsforenergy,capacity,etc.)and any settlements for imbalanced exchanges on this schedule.Power exchanges must be reported on thePurchasedPowerschedule(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 anyownershipinterestoraffiliationtherespondenthaswiththepurchaser.
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.,thesupplierincludesprojectedloadforthisserviceinitssystemresourceplanning).In addition,the reliability of requirements service mustbethesameas,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 economicreasonsandisintendedtoremainreliableevenunderadverseconditions(e.g.,the supplier must attempt to buy emergency energyfromthirdpartiestomaintaindeliveriesofLFservice).This category should not be used for Long-term firm service which meets thedefinitionofRQservice.For all transactions identified as LF,provide in a footnote the termination date of the contract defined as theearliestdatethateitherbuyerorsettercanunilaterallygetoutofthecontract.
IF -for intermediate-term firm service.The same as LF service except that "intermediate-term"means longer than one year but Lessthanfiveyears.
SF -for short-term firm service.Use this category for all firm services where the duration of each period of commitment for service isoneyearorless.
LU -for Long-term service from a designated generating unit."Long-term"means five years or Longer.The availability and reliability ofservice,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"meansLongerthanoneyearbutLessthanfiveyears.
Line Name of Company or Public Authority Statistical FERC Rate Avera e Actual Demand (MW)
No.(Footnote Affiliations)C s -Sach uu br DMerMahr
d (Month Demant Month y P emand
(a)(b)(c)(d)(e)(f)
1 Clark Public Utilities LF 428 250 250 229
2 Clark Public Utilities LF T-12 NA NA NA
3 CNG Power Services Corp.AD WSPP NA NA NA
4 Coastal Merchant Energy,L.P.SF WSPP NA NA NA
5 Colorado Springs Utilities OS WSPP NA NA NA
6 Colorado Springs Utilities SF WSPP NA NA NA
7 ConAgra Energy Services,Inc.SF WSPP NA NA NA
8 Constellation Power Source,Inc.AD WSPP NA NA NA
9 Constellation Power Source,Inc.SF WSPP NA NA NA
10 Coral Power,L.L.C.OS WSPP NA NA NA
11 Coral Power,L.L.C.SF WSPP NA NA NA
12 Cowlitz County Public Utility District LF T-12 10 10 10
13 Deseret Generation &Trans.Co-Op.AD 462 NA NA NA
14 Deseret Generation &Trans.Co-Op.LF 462 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 I his Report Is.Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
SALES I-URREbALE (Account 44/)(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 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 the
average monthly billing demand in column (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-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 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 Total ($)Line
Sold Deman Charges Energy Öharges Uther arges (h+i+j)No.
(g)(h)(i)(j)(k)
1,424,296 8,253,750 23,327,457 31,581,207 1
68,135 1,795,576 1,795,576
-6 -50 -50 Š
43,400 3,045,000 3,045,000 4
80 2,960 2,960 5
2,481 270,153 270,153 6
37,946 967,439 967,439 7
55 1,705 1,705 8
176,822 10,372,535 10,372,535 $
15 450 450 10
28,614 4,148,643 4,148,643 11
67,184 116,468 1,071,407 1,187,875 12
13,175 255,957 255,957 13
577,250 31,778,384 31,778,384 14
188,555 2,816,245 3,773,433 32,693 6,622,371
29,764,936 196,899,703 1,534,913,327 -2,284,275 1,729,528,755
29,953,491 199,715,948 1,538,686,760 -2,251,582 1,736,151,126
FERC FORM NO.1 (ED.12-90)Page 311.5
Name ot Respondent I his keport Is:Date of Repod Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
SALbb I-UR REbALE (Account49/)
1.Report all sales for resale (i.e.,sales to purchasers other than ultimate consumers)transacted on a settlement basis other thanpowerexchangesduringtheyear.Do not report exchanges of electricity (i.e.,transactions involvinga balancing of debits and creditsforenergy,capacity,etc.)and any settlements for imbalanced exchanges on this schedule.Power exchanges must be reported on thePurchasedPowerschedule(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 anyownershipinterestoraffiliationtherespondenthaswiththepurchaser.
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 provideon an ongoing basis (i.e.,thesupplierincludesprojectedloadforthisserviceinitssystemresourceplanning).In addition,the reliability of requirements service mustbethesameas,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 economicreasonsandisintendedtoremainreliableevenunderadverseconditions(e.g.,the supplier must attempt to buy emergency energyfromthirdpartiestomaintaindeliveriesofLFservice).This category should not be used for Long-term firm service which meets thedefinitionofRQservice.For all transactions identified as LF,provide in a footnote the termination date of the contract defined as theearliestdatethateitherbuyerorsettercanunilaterallygetoutofthecontract.
IF -for intermediate-term firm service.The same as LF service except that "intermediate-term"means longer than one year but Lessthanfiveyears.
SF -for short-term firm service.Use this category for all firm services where the duration of each period of commitment for service isoneyearorless.
LU -for Long-term service from a designated generating unit."Long-term"means five years or Longer.The availability and reliability ofservice,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"meansLongerthanoneyearbutLessthanfiveyears.
Line Name of CompanyAorPlic Authority SCtatiical
Sanff
u ber
DMe
r Month e
aDnodnth
y P emand
(a)(b)(c)(d)(e)(f)
1 Duke Energy Trading And Marketing,L.L.SF T-3 NA NA NA
2 Duke Energy Trading And Marketing,L.L.SF WSPP NA NA NA
3 Dynegy Power Marketing,Inc.AD T-3 NA NA NA
4 Dynegy Power Marketing,Inc.AD WSPP NA NA NA
5 Dynegy Power Marketing,Inc.SF T-3 NA NA NA
6 Dynegy Power Marketing,Inc.SF WSPP NA NA NA
7 Edison Mission Marketing &Trading,Inc IF T-12 NA NA NA
8 Edison Mission Marketing &Trading,Inc SF T-3 NA NA NA
9 El Paso Energy Marketing Company OS WSPP NA NA NA
10 El Paso Energy Marketing Company SF WSPP NA NA NA
11 Electrical District of Pinal County IF T-12 9 9 9
12 Energy Northwest inc.LF T-12 NA NA NA
13 Enron Power Marketing,Inc.AD T-3 NA NA NA
14 Enron Power Marketing,Inc.OS T-3 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
Nameof Respondent i his Report is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
b)LES I-UR RESALE(Account 44/)(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 Ënergy Öharges Uther Charges Total ($)Line
($)($)($)(h+i+j)No.
(9)(h)(i)(j)(k)
86 4,090 4,090 1
336,109 24,051,318 24,051,318 2
3,205 3,205 3
-830 -299,466 -299,466 4
50 1,600 1,600 5
313,132 23,197,920 23,197,920 6
134,904 4,110,224 4,110,224 7
50 1,173 1,173 8
175 9,425 9,425 9
357,090 28,472,998 28,472,998 10
36,978 1,287,360 651,922 1,939,282 11
122,976 2,932,978 2,932,978 12
36 936 936 13
656 46,450 46,450 14
188,555 2,816,245 3,773,433 32,693 6,622,371
29,764,936 196,899,703 1,534,913,327 -2,284,275 1,729,528,755
29,953,491 199,715,948 1,538,686,760 -2,251,582 1,736,151,126
FERC FORM NO.1 (ED.12-90)Page 311.6
Name of kespondent I his Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
SALES FUR RESALE (Account 44/)
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 energyfromthirdpartiestomaintaindeliveriesofLFservice).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 Companyor Public Authority Statistical FERC Rate Avera e Actual Demand (MW)
No.(Footnote Affiliations)C s -Sacrihe Irenb
r
DMerahr
d (Month y IV Demant Month y
CmP emand
(a)(b)(c)(d)(e)(f)
1 Enron Power Marketing,Inc.OS WSPP NA NA NA
2 Enron Power Marketing,Inc.OS WSPP NA NA NA
3 Enron Power Marketing,Inc.SF T-3 NA NA NA
4 Enron Power Marketing,Inc.SF WSPP NA NA NA
5 Eugene Water &Electric Board AD 419 NA NA NA
6 Eugene Water &Electric Board AD WSPP NA NA NA
7 Eugene Water &Electric Board LF 419 50 50 50
8 Eugene Water &Electric Board SF WSPP NA NA NA
9 Fiberweb IF T-12 10 10 9
10 Flathead Electric Coop LF T-12 NA NA NA
11 Flathead Electric Coop SF T-12 NA NA NA
12 Glendale,City of SF T-3 NA NA NA
13 Glendale,City of SF WSPP NA NA NA
14 Green Mountain Energy Resources,LIc AD T-3 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 I his Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
bl LEb EURRESALE(Account 44/)(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 the
average monthly billing demand in column (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 DemandCharges Energy Charges Uther Charges Total ($)Line
($)($)($)(h+i+j)No.
(9)(h)(i)(j)(k)
3,145 433,866 433,866 1
42,125 42,125
324 25,549 25,549 3
2,419,733 233,325,528 233,325,528 4
40 831 831 5
-40 -840 -840 6
238,365 1,155,000 4,953,225 6,108,225 7
74,665 1,599,995 1,599,995 8
54,935 97,563 817,984 915,547 9
491,904 11,731,910 11,731,910 10
12,705 1,707,887 1,707,887 11
91 2,730 2,730 12
514 14,196 14,196 13
1,766 172,273 172,273 14
188,555 2,816,245 3,773,433 32,693 6,622,371
29,764,936 196,899,703 1,534,913,327 -2,284,275 1,729,528,755
29,953,491 199,715,948 1,538,686,760 -2,251,582 1,736,151,126
FERC FORM NO.1 (ED.12-90)Page 311.7
blame of Respondent I his Report is:Date of Report Year ot Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission I /
SALES l-UR RESALE (Account 4,/)
1.Report all sales for resale (i.e.,sales to purchasers other than ultimate consumers)transacted on a settlement basis other thanpowerexchangesduringtheyear.Do not report exchanges of electricity (i.e.,transactions involving a balancing of debits and creditsforenergy,capacity,etc.)and any settlements for imbalanced exchanges on this schedule.Power exchanges must be reported on thePurchasedPowerschedule(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 anyownershipinterestoraffiliationtherespondenthaswiththepurchaser.
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.,thesupplierincludesprojectedloadforthisserviceinitssystemresourceplanning).In addition,the reliability of requirements service mustbethesameas,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 economicreasonsandisintendedtoremainreliableevenunderadverseconditions(e.g.,the supplier must attempt to buy emergency energyfromthirdpartiestomaintaindeliveriesofLFservice).This category should not be used for Long-term firm service which meets thedefinitionofRQservice.For all transactions identified as LF,provide in a footnote the termination date of the contract defined as theearliestdatethateitherbuyerorsettercanunilaterallygetoutofthecontract.
IF -for intermediate-term firm service.The same as LF service except that "intermediate-term"means longer than one year but Lessthanfiveyears.
SF -for short-term firm service.Use this category for all firm services where the duration of each period of commitment for service isoneyearorless.
LU -for Long-term service from a designated generating unit."Long-term"means five years or Longer.The availability and reliability ofservice,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"meansLongerthanoneyearbutLessthanfiveyears.
Line Name of Company or PublicAuthority Statistical FERCRate Avera e Actual Demand(MW)
No.(Footnote Affiliations)C s -SaÎi urib r
DMer
a d (MonthÛy N Deman*Month y CP emand
(a)(b)(c)(d)(e)(f)
1 Green Mountain Energy Resources,LIc LF T-3 NA NA NA
2 Hinson Power Company AD T-12 NA NA NA
3 Hinson Power Company IF T-12 NA NA NA
4 Hurricane,City of LF T-12 NA NA NA
5 Idaho Power Company AD WSPP NA NA NA
6 Idaho Power Company AD WSPP NA NA NA
7 Idaho Power Company OS T-3 NA NA NA
8 Idaho Power Company OS WSPP NA NA NA
9 Idaho Power Company OS WSPP NA NA NA
10 Idaho Power Company SF WSPP NA NA NA
11 Illinova Power Marketing,Inc.AD WSPP NA NA NA
12 Illinova Power Marketing,Inc.SF WSPP NA NA NA
13 Koch Power Services,Inc.SF WSPP NA NA NA
14 Los Angeles Dept.of Water &Power AD 301 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 ot Respondent I his Report is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
St.Lab I-UR Rb.SALi-(Account 44/)(Contmued)
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 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 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 Charges Energy Ôharges Uther Charges Total ($)Line
($)($)($)(h+i+j)No.
(9)(h)(i)(j)(k)
181,905 30,838,273 30,838,273 1
-614 -7.725 -7,725 Ž
512,715 13,474,686 13,474,686 3
7,852 219,856 219,856 4
-50 -1,100 -1,100 5
25 6
100 7,500 7,500 7
7,976 447,125 447,125 8
220 220 9
562,969 52,541,552 52,541,552 10
-36 -936 -936 11
35,777 818,143 818,143 12
78,000 5,310,000 5,310,000 13
1,725 -549 -549 14
188,555 2,816,245 3,773,433 32,693 6,622,371
29,764,936 196,899,703 1,534,913,327 -2,284,275 1,729,528,755
29,953,491 199,715,948 1,538,686,760 -2,251,582 1,736,151,126
FERC FORM NO.1 (ED.12-90)Page 311.8
Nameof Respondent I nis Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
SALES I-UR REbALE (Account 44/)
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 creditsforenergy,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 theearliestdatethateitherbuyerorsettercanunilaterallygetoutofthecontract.
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 Nameof Company or PublicAuthority Statistical FERC Rate Average Actual De nand (MW)
Classifi-Schedule or Monthly Billing hvadye AverageNo.(Footnote Affiliations)cation Tariff Number Demand (MW)Monthly NCP Demant Monthly CP Demand
(a)(b)(c)(d)(e)(f)
1 Los Angeles Dept.of Water &Power LU 301 64 64 64
2 Los Angeles Dept.of Water &Power OS T-3 NA NA NA
3 Los Angeles Dept.of Water &Power OS WSPP NA NA NA
4 Los Angeles Dept.of Water &Power SF WSPP NA NA NA
5 Merchant Energy Group of The Americas,SF WSPP NA NA NA
6 Merrill Lynch Capital Services SF WSPP NA NA NA
7 Mesa,City of IF T-12 20 20 20
8 MirantAmericas Energy Marketing,L.P.SF WSPP NA NA NA
9 Modesto Irrigation SF WSPP NA NA NA
10 Morgan Stanley Capital SF WSPP NA NA NA
11 Municipal Energy Agency of Nebraska OS T-3 NA NA NA
12 Municipal Energy Agency of Nebraska OS WSPP NA NA NA
13 NevadaPowerCompany AD 312 NA NA NA
14 Nevada Power Company AD 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 I his Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
Si,LES l-UR RI-SALE (Account 44/)(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 the
average monthly billing demand in column (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-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.Repod 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 Ënergy Charges Other Charges Total ($)Line
($)($)($)(h+i+j)No.
(9)(h)(i)(j)(k)
531,194 8,728,000 14,457,912 23,185,912 1
138 7,780 7,780 Ž
22,471 1,399,919 1,399,919 3
12,460 865,413 865,413 4
51,200 1,690,760 1,690,760 5
81,200 8,403,700 8,403,700 6
41,984 1,788,000 748,575 2,536,575 7
531,081 43,237,998 43,237,998 8
24,130 1,035,037 1,035,037 $
51,400 5,113,400 5,113,400 10
245 15,925 15,925 11
938 52,126 52,126 12
-44,887 -44,887 13
-200 -200 14
188,555 2,816,245 3,773,433 32,693 6,622,371
29,764,936 196,899,703 1,534,913,327 -2,284,275 1,729,528,755
29,953,491 199,715,948 1,538,686,760 -2,251,582 1,736,151,126
FERCFORM NO.1 (ED.12-90)Page 311.9
Name of Respondent I his Report is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
SALES I-UR MbbALE (Account 44/)
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 creditsforenergy,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.,thesupplierincludesprojectedloadforthisserviceinitssystemresourceplanning).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 energyfromthirdpartiestomaintaindeliveriesofLFservice).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 Nameof Company or Public Authority Statistical FERCRate Avera e Actual Demand (MW)
No.(Footnote Affiliations)C s -SaÊÛu ber
DMeahr
d (Month Demant Month yC emand
(a)(b)(c)(d)(e)(f)
1 Nevada Power Company AD WSPP NA NA NA
2 Nevada Power Company OS T-3 NA NA NA
3 Nevada Power Company OS WSPP NA NA NA
4 Nevada Power Company SF T-3 NA NA NA
5 Nevada Power Company SF WSPP NA NA NA
6 Northem California Power Agency SF WSPP NA NA NA
7 Pacific Gas &Electric Company AD T-3 NA NA NA
8 Pacific Northwest Generating Cooperativ IF 429 58 58 58
9 PECO Energy Power Co.AD WSPP NA NA NA
10 PECO Energy Power Co.SF WSPP NA NA NA
11 PG&E Energy Trading -Power L.P.SF T-3 NA NA NA
12 PG&E Energy Trading -Power L.P.SF WSPP NA NA NA
13 Plains Electric G &T Cooperative OS T-3 NA NA NA
14 Plains Electric G &T Cooperative :SF T-3 67 67 59
Subtotal RQ 0 0 0
Subtotal non-RQ 0 0 0
Total 0 0 0
FERC FORM NO.1 (ED.12-90)Page 310.10
Name of Respondent i his Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
Si,Li-S 1-UR RbbALE (Account 44/)(Continued)
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 riature
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 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 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 Uther arges
(g)(h)(i)(j)(k)
-91 -91 1
576 29,510 29,510 2
57,009 3,017,338 3,017,338 3
175 39,375 39,375 4
433,712 26,439,547 26,439,547 5
400 10,000 10,000 $
-23,130 -23,130 7
371,965 650,000 5,720,822 6,370,822 8
89,900 89,900 $
7,200 930,000 930,000 10
2,400 192,000 192,000 11
543,200 41,672,170 41,672,170 12
25 500 500 13
237,241 557,410 4,165,928 4,723,338 14
188,555 2,816,245 3,773,433 32,693 6,622,371
29,764,936 196,899,703 1,534,913,327 -2,284,275 1,729,528,755
29,953,491 199,715,948 1,538,686,760 -2,251,582 1,736,151,126
FERC FORM NO.1 (ED.12-90)Page 311.10
Name of Respondent I his Report is:Date of keport Year ot keport
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
SALES FUR kESALE (Account A/)
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 thePurchasedPowerschedule(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.,thesupplierincludesprojectedloadforthisserviceinitssystemresourceplanning).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 economicreasonsandisintendedtoremainreliableevenunderadverseconditions(e.g.,the supplier must attempt to buy emergency energyfromthirdpartiestomaintaindeliveriesofLFservice).This category should not be used for Long-term firm service which meets thedefinitionofRQservice.For all transactions identified as LF,provide in a footnote the termination date of the contract defined as theearliestdatethateitherbuyerorsettercanunilaterallygetoutofthecontract.
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 isoneyearorless.
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"meansLongerthanoneyearbutLessthanfiveyears.
Line Name of Company or PublicAuthority Statistical FERC Rate Avera e Actual Demand (MW)
No.(Footnote Affiliations)C -Sa
u ber
DMeonnyd
(Month Demant Month y CP emand
(a)(b)(c)(d)(e)(f)
1 Platte River Power SF WSPP NA NA NA
2 Portland General Electric Company AD T-3 NA NA NA
3 Portland General Electric Company OS T-3 NA NA NA
4 Portland General Electric Company OS WSPP NA NA NA
5 Portland General Electric Company OS WSPP NA NA NA
6 Portland General Electric Company SF T-3 NA NA NA
7 Portland General Electric Company SF WSPP NA NA NA
8 PPL Montana,LLC OS WSPP NA NA NA
9 PPL Montana,LLC OS WSPP NA NA NA
10 PPL Montana,LLC SF WSPP NA NA NA
11 PublicService Company of Colorado AD 320 NA NA NA
12 PublicService Company of Colorado LF 320 176 176 174
13 PublicService Company of Colorado OS WSPP NA NA NA
14 PublicService Company of Colorado SF T-3 NA NA NA
Subtotal RQ 0 0 0
Subtotal non-RQ 0 0 0
Total 0 0 0
FERCFORM NO.1 (ED.12-90)Page 310.11
Name of Respondent i nis Report is:Date ot Report Year ot keport
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
bhLES FUR RbbALE (Account 44/)(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 Deman Charges Ënergy Öharges Uther arges
(g)(h)(i)(j)(k)
78 18,888 18,888 1
2,505 2,505
62 1,395 1,395 3
22,325 537,193 537,193 4
505 505 5
558 14,705 14,705 6
158,834 12,899,748 12,899,748 7
3,225 222,645 222,645 8
1,650 1,650 $
6,145 636,105 636,105 10
33 -1,750,838 -1,750,838 11
1,157,423 30,792,960 18,240,073 49,033,033 12
15,792 933,245 933,245 13
225 7,445 7,445 14
188,555 2,816,245 3,773,433 32,693 6,622,371
29,764,936 196,899,703 1,534,913,327 -2,284,275 1,729,528,755
29,953,491 199,715,948 1,538,686,760 -2,251,582 1,736,151,126
FERC FORM NO.1 (ED.12-90)Page 311.11
Name ot Respondent ihis Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
bALEb I-UR khsAu-(Account 4,/)
1.Report all sales for resale (i.e.,sales to purchasers other than ultimate consumers)transacted on a settlement basis other thanpowerexchangesduringtheyear.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 anyownershipinterestoraffiliationtherespondenthaswiththepurchaser.
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.,thesupplierincludesprojectedloadforthisserviceinitssystemresourceplanning).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 energyfromthirdpartiestomaintaindeliveriesofLFservice).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 isoneyearorless.
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"meansLongerthanoneyearbutLessthanfiveyears.
Line Name of Company or Public Authority Statistical FERC Rate Avera e Actual Demand (MW)
No.(Footnote Affiliations)C s -Sa
u br DMe
a d (Month y Demari Month yœCmP emand
(a)(b)(c)(d)(e)(f)
1 Public Service Company of Colorado SF WSPP NA NA NA
2 Public Service Company of New Mexico OS T-3 NA NA NA
3 Public Service Company of New Mexico OS WSPP NA NA NA
4 Public Service Company of New Mexico OS WSPP NA NA NA
5 Public Service Company of New Mexico SF T-3 NA NA NA
6 Public Service Company of New Mexico SF WSPP NA NA NA
7 Public Utility District #1 of Okanogan LF T-12 NA NA NA
8 Public Utility District No.1 of Chelan SF WSPP NA NA NA
9 Public Utility District No.2 of Grant SF WSPP NA NA NA
10 Puget Sound Power &Light Company AD WSPP NA NA NA
11 Puget Sound Power &Light Company AD WSPP NA NA NA
12 Puget Sound Power &Light Company LF 254 200 200 200
13 Puget Sound Power &Light Company OS WSPP NA NA NA
14 Puget Sound Power &Light Company 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 310.12
Name of Respondent I his Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
bl.LES EUR RbbALE (Account44/)(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 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-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 Ënergy Öharges Uther Charges Total ($)Line
($)($)($)(h+i+j)No.
(9)(h)(i)(j)(k)
164,473 12,560,962 12,560,962 1
155 19,175 19,175
22,573 1,145,212 1,145,212 3
88,045 88,045 4
87 5,734 5,734 5
242,960 13,075,351 13,075,351 6
46,692 706,952 706,952 7
1,000 29,200 29,200 8
25,285 2,267,670 2,267,670 9
-1,156 10
1,498 9.728 9,728 11
1,051,200 29,784,000 18,232,288 48,016,288 12
2,787 30,626 30,626 13
1,115 1,115 14
188,555 2,816,245 3,773,433 32,693 6,622,371
29,764,936 196,899,703 1,534,913,327 -2,284,275 1,729,528,755
29,953,491 199,715,948 1,538,686,760 -2,251,582 1,736,151,126
FERC FORM NO.1 (ED.12-90)Page 311.12
Name of Respondent I nis Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
SALES FUR RbbALE (Account 4,i;
1.Report all sales for resale (i.e.,sales to purchasers other than ultimate consumers)transacted on a settlement basis other thanpowerexchangesduringtheyear.Do not report exchanges of electricity (i.e.,transactions involving a balancing of debits and creditsforenergy,capacity,etc.)and any settlements for imbalanced exchanges on this schedule.Power exchanges must be reported on thePurchasedPowerschedule(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 anyownershipinterestoraffiliationtherespondenthaswiththepurchaser.
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.,thesupplierincludesprojectedloadforthisserviceinitssystemresourceplanning).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 economicreasonsandisintendedtoremainreliableevenunderadverseconditions(e.g.,the supplier must attempt to buy emergency energyfromthirdpartiestomaintaindeliveriesofLFservice).This category should not be used for Long-term firm service which meets thedefinitionofRQservice.For all transactions identified as LF,provide in a footnote the termination date of the contract defined as theearliestdatethateitherbuyerorsettercanunilaterallygetoutofthecontract.
IF -for intermediate-term firm service.The same as LF service except that "intermediate-term"means longer than one year but Lessthanfiveyears.
SF -for short-term firm service.Use this category for all firm services where the duration of each period of commitment for service isoneyearorless.
LU -for Long-term service from a designated generating unit."Long-term"means five years or Longer.The availability and reliability ofservice,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"meansLongerthanoneyearbutLessthanfiveyears.
Line Name of Company or PublicAuthority Statistical FERCRate Avera e Actual Demand (MW)
No.(Footnote Affiliations)C s -Saci
u br DMe
d (Month Demant Month y
CmP emand
(a)(b)(c)(d)(e)(f)
1 Puget Sound Power &Light Company SF T-3 NA NA NA
2 Puget Sound Power &Light Company SF WSPP NA NA NA
3 Redding,City of AD 364 NA NA NA
4 Redding,City of AD 364 NA NA NA
5 Redding,City of IF 364 50 50 50
6 Redding,City of LF 364 50 50 50
7 Redding,City of SF T-3 NA NA NA
8 Redding,City of SF WSPP NA NA NA
9 Reliant Energy Service OS WSPP NA NA NA
10 Reliant Energy Service SF WSPP NA NA NA
11 Riverside,City of OS WSPP NA NA NA
12 Riverside,City of SF WSPP NA NA NA
13 Sacramento Municipal Utility District AD 250 NA NA NA
14 Sacramento Municipal Utility District LF 250 NA NA NA
Subtotal RQ 0 0 0
Subtotal non-RQ 0 0 0
Total 0 0 0
FERC FORMNO.1 (ED.12-90)Page 310.13
Name of Respondent I his Report is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
bi,LES I-UR REbALt-(Account 44/)(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-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,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 I-nergy Charges Uther Charges Total ($)Line
($)($)($)(h+i+j)No.
(9)(h)(i)(j)(k)
21 378 378 1
244,240 24,836,688 24,836,688 2
-607,175 -607,175 3
1 1,418,447 1,418,447 4
337,380 550,000 4,757,058 5,307,058 5
337,380 8,348,500 10,989,606 19,338,106 6
190 4,750 4,750 7
2,430 80,986 80,986 8
150 90,000 90,000 9
91,125 16,282,975 16,282,975 10
4,813 202,232 202,232 11
12,493 951,068 951,068 12
332,956 332,956 13
569,825 8,296,692 8,296,692 14
188,555 2,816,245 3,773,433 32,693 6,622,371
29,764,936 196,899,703 1,534,913,327 -2,284,275 1,729,528,755
29,953,491 199,715,948 1,538,686,760 -2,251,582 1,736,151,126
FERC FORM NO.1 (ED.12-90)Page 311.13
Name ot Respondent I his Report is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
SALES EUR Rh-SALE (Account 49/)
1.Report all sales for resale (i.e.,sales to purchasers other than ultimate consumers)transacted on a settlement basis other thanpowerexchangesduringtheyear.Do not report exchanges of electricity (i.e.,transactions involving a balancing of debits and creditsforenergy,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 anyownershipinterestoraffiliationtherespondenthaswiththepurchaser.
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.,thesupplierincludesprojectedloadforthisserviceinitssystemresourceplanning).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 economicreasonsandisintendedtoremainreliableevenunderadverseconditions(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 Lessthanfiveyears.
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"meansLongerthanoneyearbutLessthanfiveyears.
Line Name of Company or Public Authority Statistical FERC Rate Avera e Actual Demand (MW)
No.(Footnote Affiliations)C s -Sacrihe Irenb
r
DMe
d (Month Demant Month y CP emand
(a)(b)(c)(d)(e)(f)
1 Sacramento Municipal Utility District OS WSPP NA NA NA
2 Sacramento Municipal Utility District SF WSPP NA NA NA
3 Sacramento Municipal Utility District SF WSPP NA NA NA
4 Salt River Project OS WSPP NA NA NA
5 Salt River Project SF WSPP NA NA NA
6 San Diego Gas &Electric Company SF WSPP NA NA NA
7 Santa Clara,City of SF WSPP NA NA NA
8 Seattle City Light OS WSPP NA NA NA
9 Seattle City Light SF WSPP NA NA NA
10 Sempra Energy Trading Corporation OS WSPP NA NA NA
11 Sempra Energy Trading Corporation SF WSPP NA NA NA
12 Sierra Pacific Power Company AD 258 NA NA NA
13 Sierra Pacific Power Company AD 267 NA NA NA
14 Sierra Pacific Power Company |AD 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 310.14
Name of Respondent I his Report is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
bl.LES EUR RbbALE (Account 44/)(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 repertingyears.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-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 on
the Last -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.
MegaWattHours REVENUE
Sold DemandCharges Energy Charges Uther Charges Total ($)Line
($)($)($)(h+i+j)No.
(9)(h)(i)(j)(k)
5,087 135,932 135,932 1
252,965 6,283,923 6,283,923 2
8,717,195 8,717,195 3
47,215 2,135,046 2,135,046 4
49,874 3,411,545 3,411,545 5
887,652 15,595,337 15,595,337 6
23,287 1,382,909 1,382,909 7
1,200 1,200 8
36,866 2,272,915 2,272,915 9
1,065 113,295 113,295 1Ò
162,772 11,703,057 11,703,057 11
16.195 16,195 12
411.206 411,206 13
-310 -310 14
188,555 2,816,245 3,773,433 32,693 6,622,371
29,764,936 196,899,703 1,534,913,327 -2,284,275 1,729,528,755
29,953,491 199,715,948 1,538,686,760 -2,251,582 1,736,151,126
FERC FORM NO.1 (ED.12-90)Page 311.14
Name of Respondent I his Repod Is.Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
SALbb I-UR REbALt-(Account VI)
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 creditsforenergy,capacity,etc.)and any settlements for imbalanced exchanges on this schedule.Power exchanges must be reported on thePurchasedPowerschedule(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 anyownershipinterestoraffiliationtherespondenthaswiththepurchaser.
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.,thesupplierincludesprojectedloadforthisserviceinitssystemresourceplanning).In addition,the reliability of requirements service mustbethesameas,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 economicreasonsandisintendedtoremainreliableevenunderadverseconditions(e.g.,the supplier must attempt to buy emergency energyfromthirdpartiestomaintaindeliveriesofLFservice).This category should not be used for Long-term firm service which meets thedefinitionofRQservice.For all transactions identified as LF,provide in a footnote the termination date of the contract defined as theearliestdatethateitherbuyerorsettercanunilaterallygetoutofthecontract.
IF -for intermediate-term firm service.The same as LF service except that "intermediate-term"means longer than one year but Lessthanfiveyears.
SF -for short-term firm service.Use this category for all firm services where the duration of each period of commitment for service isoneyearorless.
LU -for Long-term service from a designated generating unit."Long-term"means five years or Longer.The availability and reliability ofservice,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"meansLongerthanoneyearbutLessthanfiveyears.
Line Name of Company or Public Authority Statistical FERC Rate Average Actual Demand (MW)
No.(Footnote Affiliations)Classifi-Schedule or Monthly Billing ^*e e AveracationTariffNumberDemand(MW)Monthly NC Demant Monthly CP emand
(a)(b)(c)(d)(e)(f)
1 Sierra Pacific Power Company LF 258 75 75 75
2 Sierra Pacific Power Company LF 267 75 75 75
3 Sierra Pacific Power Company OS WSPP NA NA NA
4 Sierra Pacific Power Company SF T-3 NA NA NA
5 Sierra Pacific Power Company SF WSPP NA NA NA
6 Snohomish County Pud No.1 OS WSPP NA NA NA
7 Snohomish County Pud No.1 SF T-3 NA NA NA
8 Snohomish County Pud No.1 SF WSPP NA NA NA
9 Southem Califomia Edison Company AD 248 NA NA NA
10 Southem Califomia Edison Company LF 248 200 200 183
11 Springfield Utility Board LF 423 42 42 36
12 Springfield Utility Board SF T-3 NA NA NA
13 State of Califomia AD 311 NA NA NA
14 State of Califomia LF 311 100 100 100
Subtotal RQ 0 0 0
Subtotal non-RQ 0 0 0
Total 0 0 0
FERC FORM NO.1 (ED.12-90)Page 310.15
Name of Respondent I his Report Is:Date of Report Year of keport
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
Si,LES FOR kabALE (Account44/)(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 e×planation 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 Ënergy Õharges Uther Charges Total ($)Line
($)($)($)(h+i+j)No.
(9)(h)(i)(j)(k)
461,164 15,156,000 6,018,190 21,174,190 1
216,383 3,081,000 2,869,596 5,950,596 2
2,660 164,850 164,850 3
1,138 93,290 93,290 4
352,398 19,507,097 19,507,097 5
25 5,000 5,000 6
25 1,445 1,445 7
7,095 320,685 320,685 8
-117,050 -117,050 à
1,230,672 24,072,000 34,560,593 58,632,593 1Ò
231,855 1,713,680 6,169,458 7,883,138 11
145,200 2,722,452 2,722,452 12
-627,069 -627,069 13
613,033 21,264,000 10,482,864 31,746,864 14
188,555 2,816,245 3,773,433 32,693 6,622,371
29,764,936 196,899,703 1,534,913,327 -2,284,275 1,729,528,755
29,953,491 199,715,948 1,538,686,760 -2,251,582 1,736,151,126
FERC FORM NO.1 (ED.12-90)Page 311.15
Name of Respondent I his Report is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
SALES I-UR RESALE (Account 40/)
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 economicreasonsandisintendedtoremainreliableevenunderadverseconditions(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 thedefinitionofRQservice.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 fiveyears or Longer.The availability and reliability ofservice,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"meansLongerthanoneyearbutLessthanfiveyears.
Line Name of Company or Public Authority Statistical FERC Rate Avera e Actual Demand (MW)
No.(Footnote Affiliations)C s -Sache
u ber
DMe
d (Month Demant Month y
CmP emand
(a)(b)(c)(d)(e)(f)
1 State of Califomia SF WSPP NA NA NA
2 Statoil Energy,Inc.SF WSPP NA NA NA
3 Tacoma,City of SF T-3 NA NA NA
4 Tacoma,City of SF WSPP NA NA NA
5 Texas-New Me×ico Power Company OS WSPP NA NA NA
6 Texas-New Mexico Power Company SF WSPP NA NA NA
7 Tillamook Public Utility District SF T-3 NA NA NA
8 Tractebel Energy Marketing,Inc.SF WSPP NA NA NA
9 TransAlta Energy Marketing Corp.OS WSPP NA NA NA
10 TransAlta Energy Marketing Corp.SF WSPP NA NA NA
11 Tri-State Gen.&Trans.Association AD WSPP NA NA NA
12 Tri-State Gen.&Trans.Association OS T-3 NA NA NA
13 Tri-State Gen.&Trans.Association OS WSPP NA NA NA
14 Tri-State Gen.&Trans.Association SF WSPP NA NA NA
Subtotal RQ 0 0 0
Subtotal non-RQ 0 0 0
Total 0 0 0
FERCFORM NO.1 (ED.12-90)Page 310.16
Name of Respondent I nas Report is:Date ot keport Year ot keport
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
Si,LES 1-UR MbbALE (Account 44/)(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 riature
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 involvingdemand 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)
3,949 439,905 439,905 1
10,000 295,000 295,000 2
40 2,160 2,160 3
2,200 175,497 175,497 4
23 4,660 4,660 5
2,553 142,980 142,980 6
25,555 401,214 401,214 7
61,425 6,319,363 6,319,363 8
25 650 650 9
122,033 16,044,469 16,044,469 10
79 8,234 8,234 11
50 6,750 6,750 12
15,781 1,029,630 1,029,630 13
160,950 11,211,952 11,211,952 14
188,555 2,816,245 3,773,433 32,693 6,622,371
29,764,936 196,899,703 1,534,913,327 -2,284,275 1,729,528,755
29,953,491 199,715,948 1,538,686,760 -2,251,582 1,736,151,126
FERC FORM NO.1 (ED.12-90)Page 311.16
Name of Respondent I his Report Is:Date of Report Year ot Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
bALbb EURkbbALE (Account 44/)
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 Nameof Company or Public Authority Statistical FERCRate Avera e Actual Demand(MW)
No.(Footnote Affiliations)C s -Sachff
u br DMeahr
d (Month Demant Month y CP emand
(a)(b)(c)(d)(e)(f)
1 Tucson Electric Power Company OS T-3 NA NA NA
2 Tucson Electric Power Company OS WSPP NA NA NA
3 Tucson Electric Power Company SF T-3 NA NA NA
4 Tucson Electric Power Company SF WSPP NA NA NA
5 Utah Associated Municipal Power Systems AD T-3 NA NA NA
6 Utah Associated Municipal Power Systems AD WSPP NA NA NA
7 Utah Associated Municipal Power Systems OS T-3 NA NA NA
8 Utah Associated Municipal Power Systems OS WSPP NA NA NA
9 Utah Associated Municipal Power Systems SF T-3 NA NA NA
10 Utah Associated Municipal Power Systems SF WSPP NA NA NA
11 Utah Municipal Power Agency AD 433 NA NA NA
12 Utah Municipal Power Agency LF 433 8 8 7
13 Utah Municipal Power Agency LF 433 43 43 43
14 Utah Municipal Power Agency OS T-3 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 310.17
Name of Respondent I his Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
b),LES I-UR Ml-bALE (Account44/)(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 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 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 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 Page
401,iine 24.
10.Footnote entries as required and provide explanations following all required data.
MegaWattHours REVENUE Total ($)Line
Sold Demand harges Energy Charges other arges (h+i+j)No.
(g)(h)(i)(j)(k)
94 2,068 2,068 1
14,981 993,882 993,882 Ž
25 626 626 Š
131,557 8,032,458 8,032,458 4
30 750 750 5
25 700 700 6
605 78,450 78,450 7
14,375 1,331,045 1,331,045 8
65 10,825 10,825 9
10,945 1,852,870 1,852,870 10
-8 -173 -173 11
44,006 1,440,000 937,685 2,377,685 12
141,212 620,950 3,071,361 3,692,311 13
27 1,639 1,639 14
188,555 2,816,245 3,773,433 32,693 6,622,371
29,764,936 196,899,703 1,534,913,327 -2,284,275 1,729,528,755
29,953,491 199,715,948 1,538,686,760 -2,251,582 1,736,151,126
FERC FORM NO.1 (ED.12-90)Page 311.17
Name of Respondent I his Report is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
bALES FUR RbbALi-(Account 44/)
1.Report all sales for resale (i.e.,sales to purchasers other than ultimate consumers)transacted on a settlement basis other thanpowerexchangesduringtheyear.Do not report exchanges of electricity (i.e.,transactions involving a balancing of debits and creditsforenergy,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 anyownershipinterestoraffiliationtherespondenthaswiththepurchaser.
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 economicreasonsandisintendedtoremainreliableevenunderadverseconditions(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 theearliestdatethateitherbuyerorsettercanunilaterallygetoutofthecontract.
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 -Sa urenb
r
DMeahr
d (Month Demant Month y
CæP emand
(a)(b)(c)(d)(e)(f)
1 Utah Municipal Power Agency OS WSPP NA NA NA
2 Utah Municipal Power Agency SF T-3 NA NA NA
3 Utah Municipal Power Agency SF WSPP NA NA NA
4 Wafertech LF T-12 10 10 10
5 Western Area Power Administration AD 313 NA NA NA
6 Western Area Power Administration AD 328 NA NA NA
7 Westem Area Power Administration AD T-3 NA NA NA
8 Westem Area Power Administration AD WSPP NA NA NA
9 Westem Area Power Administration LF 313 60 60 58
10 Western Area Power Administration LF 328 75 77 69
11 Westem Area Power Administration OS WSPP NA NA NA
12 Westem Area Power Administration OS WSPP NA NA NA
13 Westem Area Power Administration SF WSPP NA NA NA
14 Williams Energy Services Co.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 310.18
Name of Respondent ihis Report is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
SALt-8 I-UR RESALt-(Account 44/)(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 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 Page
401,iine 24.
10.Footnote entries as required and provide explanations following all required data.
MegaWatt Hours REVENUE L
Sold Demand harges EnergyæCharges Uther arges o a
(g)(h)(i)(j)(k)
1,615 72,903 72,903 1
23 4,642 4,642 2
579 149,610 149,610 3
87,840 132,000 1,300,032 1,432,032 4
20 20 5
1,206 22,836 22,836 Ú
30.800 30,800 7
-4,040 -4,040 8
468,724 1,228,561 16,379,955 17,608,516 9
554,058 13,681,980 9,169,979 22,851,959 10
56,975 2,765,580 2,765,580 11
10,000 10,000 12
130,237 10,002,587 10,002,587 13
800 40,000 40,000 14
188,555 2,816,245 3,773,433 32,693 6,622,371
29,764,936 196,899,703 1,534,913,327 -2,284,275 1,729,528,755
29,953,491 199,715,948 1,538,686,760 -2,251,582 1,736,151,126
FERC FORMNO.1 (ED.12-90)Page 311.18
Name of Respondent I nis Report is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
SALES I-Uk REbALE (Account A/)
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 thePurchasedPowerschedule(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 anyownershipinterestoraffiliationtherespondenthaswiththepurchaser.
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.,thesupplierincludesprojectedloadforthisserviceinitssystemresourceplanning).In addition,the reliability of requirements service mustbethesameas,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 economicreasonsandisintendedtoremainreliableevenunderadverseconditions(e.g.,the supplier must attempt to buy emergency energyfromthirdpartiestomaintaindeliveriesofLFservice).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 theearliestdatethateitherbuyerorsettercanunilaterallygetoutofthecontract.
IF -for intermediate-term firm service.The same as LF service except that "intermediate-term"means longer than one year but Lessthanfiveyears.
SF -for short-term firm service.Use this category for all firm services where the duration of each period of commitment for service isoneyearorless.
LU -for Long-term service from a designated generating unit."Long-term"means five years or Longer.The availability and reliability ofservice,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"meansLongerthanoneyearbutLessthanfiveyears.
Line Name of Company or Public Authority Statistical FERC Rate Avera e Actual Deviand (MW)
No.(Footnote Affiliations)C s -Sa
u br DMer
a d (Month yS$bDemant
Month y
CmPŸemand
(a)(b)(c)(d)(e)(f)
1 Williams Energy Services Co.SF WSPP NA NA NA
2 Accrual adjustment NA NA NA NA
3
4
5
6
7
8
9
10
11
12
13
14
Subtotal RQ 0 0 0
Subtotal non-RQ 0 0 0
Total 0 0 0
FERCFORM NO.1 (ED.12-90)Page 310.19
Name of Respondent I his Report is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
b/J..bb FOR RESALE (Account 44/)(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 the
average monthly billing demand in column (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,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 RQlNon-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 Deman Charges Ênergy Charges other arges o a (
(9)(h)(i)(j)(k)
580,085 40,498,225 40,498,225 1
-6,638 -2,202.610 -2,202,610 2
4
5
6
7
8
10
11
1Ž
13
14
188,555 2,816,245 3,773,433 32,693 6,622,371
29,764,936 196,899,703 1,534,913,327 -2,284,275 1,729,528,755
29,953,491 199,715,948 1,538,686,760 -2,251,582 1,736,151,126
FERC FORM NO.1 (ED.12-90)Page 311.19
Nameof Respondent I his keport is:Date of Report Year of keport
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
ELEGI RIC UPERAI ION AND MAINI ENANCE EXPENSES
If the amount for previous year is not derived from previously reported figures,e::plain in footnote.
Line Account Amount for Am.ount forCurrentYearPreviousYearNo(a)(b)(c)
1 1.POWER PRODUCTIONEXPENSES
4 (500)Operation Supervision and Engineering 10,206,932 4,547,387
5 (501)Fuel 456,031,590 457,833,389
6 (502)Steam Expenses 14,925,133 13,186,499
7 (503)Steam from Other Sources 9,520,966 9,362,235
8 (Less)(504)Steam Transferred-Cr.
9 (505)Electric Expenses 1,409,243 1,643,540
10 (506)Miscellaneous Steam Power Expenses 55,839,085 80,092,583
11 (507)Rents 188,519 476,872
12 (509)Allowances 2,862
13 TOTAL Operation (Enter Total of Lines 4 thru 12)548,121,468 567,145,367
14 Maintenance
15 (510)Maintenance Supervision and Engineering 2,309,168 2,046,737
16 (511)Maintenanæ of Structures 912,799 705,638
17 (512)Maintenanœof Boiler Plant 53,468,303 31,270,584
18 (513)Maintenance of Electric Plant 11,844,444 11,036,918
19 (514)Maintenance of Miscellaneous Steam Plant 25,425,849 42,197,361
20 TOTAL Maintenance (Enter Total of Lines 15 thru 19)93,960,563 87,257,238
21 TOTAL Power Production Expenses-Steam Power (Entr Tot lines 13 &20)642,082,031 654,402,605
22 B.Nuclear Power Generation
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)Maintenanœ of Miscellaneous 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
44 (535)Operation Supervision and Engineering 5,981,419 4,589,198
45 (536)Water for Power
46 (537)Hydraulic Expenses 1,637,098 1,492,730
47 (538)Electric Expenses
48 (539)Miscellaneous Hydraulic Power Generation Expenses 12,859,831 8,450,220
49 (540)Rents 490,781 282,901
50 TOTAL Operation (Enter Total of Lines 44 thru 49)20,969,129 14,815,049
FERC FORM NO.1 (ED.12-93)Page 320
Name of Respondent I his Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
ELi-CI RIC OPERAIION ANI.)MAINI t-NANUb bAPENSbb (Continued)
If the amount for previous year is not derived from previously reported figures,explain in footnote.
Line Account Amount for Am.ount forCurrentYearPreviousYearNo(a)(b)(c)
51 C.Hydraulic Power Generation (Continued)
52 Maintenance
53 (541)Mainentance Supervision and Engineering 612,13 738,138
54 (542)Maintenance of Structures
55 (543)Maintenance of Reservoirs,Dams,and Waterways
56 (544)Maintenance of Electric Plant 371,495 1,517,422
57 (545)Maintenance of Miscellaneous Hydraulic Plant 2,103,235 3,128,088
58 TOTAL Maintenance (Enter Total of lines 53 thru 57)3,086,860 5,383,648
59 TOTAL Power Production Expenses-Hydraulic Power (tot of lines 50 &58)24,055,989 20,198,697
60 D.Other Power Generation
62 (546)Operation Supervision and Engineering
63 (547)Fuel 41,677,406 37,837,817
64 (548)Generation Expenses 7,338,874 4,719,500
65 (549)Miscellaneous Other Power Generation Expenses 1,571,747 1,080,243
66 (550)Rents 291,156
67 TOTAL Operation (Enter Total of lines 62 thru 66)50,879,183 43,637,560
68 Maintenance
69 (551)Maintenance Supervision and Engineering
70 (552)Maintenance of Structures
71 (553)Maintenance of Generating and Electric Plant
72 (554)Maintenance of Miscellaneous Other Power Generation Plant
73 TOTAL Maintenance (Enter Total of lines 69 thru 72)
74 TOTAL Power Production Expenses-Other Power (Enter Tot of 67 &73)50,879,183 43,637,560
75 E.Other Power Supply Expenses
76 (555)Purchased Power 1,942,486,285 885,545,286
77 (556)System Control and Load Dispatching 499,559 2,306,833
78 (557)Other Expenses 32,694,308 12,168,841
79 TOTAL Other Power Supply Exp (Enter Total of lines 76 thru 78)1,975,680,152 900,020,960
80 TOTAL Power Production Expenses (Total of lines 21,41,59,74 &79)2,692,697.355 1,618,259,822
81 2.TRANSMISSIONEXPENSES
83 (560)Operation Supervision and Engineering 6,931,029 1,337,275
84 (561)Load Dispatching 3,546,270 2,115,234
85 (562)Station Expenses 3,615,734 1,454,958
86 (563)Overhead Lines Expenses 985,181 217,674
87 (564)Underground Lines Expenses
88 (565)Transmission of Electricity by Others 78,404,520 71,336,469
89 (566)Miscellaneous Transmission Expenses 1,394,904 761,894
90 (567)Rents 861,040 553,016
91 TOTAL Operation (Enter Total of lines 83 thru 90)95,738,678 77,776,520
92 Maintenance
93 (568)Maintenance Supervision and Engineering 1,964 -316
94 (569)Maintenance of Structures 203,072 106,231
95 (570)Maintenance of Station Equipment 2,354,254 3,688,809
96 (571)Maintenance of Overhead Lines 5,580,227 1,770,377
97 (572)Maintenance of Underground Lines 1,637 584
98 (573)Maintenance of Miscellaneous Transmission Plant 87,995 532,069
99 TOTAL Maintenance (Enter Total of lines 93 thru 98)8,229,149 6,097,754
100 TOTAL Transmission Expenses (Enter Total of lines 91 and 99)103,967,827 83,874,274
101 3.DISTRIBUTIONEXPENSES
103 (580)Operation Supervision and Engineering 45,137,742 33,190,259
FERCFORMNO.1 (ED.12-93)Page 321
Name of Respondent I his Report is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
ELECI RIC UPERAI ION AND MAIN I ENANCE EXPi-NSES (Continued)
If the amount for previous year is not derived from previously reported figures,explain in footnote.
Line Account Amount for Arnount forCurrentYearPreviousYearNo.(a)(b)(c)
104 3.DISTRIBUTIONExpenses (Continued)
105 (581)Load Dispatching 4,769,203 4,623,986
106 (582)Station Expenses
107 (583)Overhead Line Expenses 23,846,500 37,664,281
108 (584)Underground Line Expenses 780
109 (585)Street Lighting and Signal System Expenses
110 (586)Meter Expenses
111 (587)Customer Installations Expenses 378,297 751,212
112 (588)Miscellaneous Expenses 11,888
113 (589)Rents 399,255 2,113,983
114 TOTAL Operation (Enter Total of lines 103 thru 113)74,542,885 78,344,501
115 Maintenance
116 (590)Maintenance Supervision and Engineering
117 (591)Maintenance of Structures
118 (592)Maintenance of Station Equipment 1,498,598 4,869,731
119 (593)Maintenance of Overhead Lines 44,988,646 43,851,012
120 (594)Maintenance of Underground Lines 7,121,371 5,273,571
121 (595)Maintenance of Line Transformers
122 (596)Maintenance of Street Lighting and Signal Systems 1,113,495 1,418,776
123 (597)Maintenance of Meters 2,379,893 3,839,455
124 (598)Maintenance of Miscellaneous Distribution Plant 401,838 3,706,620
125 TOTAL Maintenance (Enter Total of lines 116 thru 124)57,503,841 62,959,165
126 TOTAL Distribution Exp (Enter Total of lines 114 and 125)132,046,726 141,303,666
127 4.CUSTOMERACCOUNTS EXPENSES
129 (901)Supervision 21,075,149 23,650,769
130 (902)Meter Reading Expenses 19,043,633 14,227,006
131 (903)Customer Records and Collection Expenses 24,764,926 24,518,751
132 (904)Uncollectible Accounts 8,163,666 19,294,336133(905)Miscellaneous Customer Accounts Expenses 905,966 2,649,192134TOTALCustomerAccountsExpenses(Total of lines 129 thru 133)73,953,340 84,340,054
135 5.CUSTOMERSERVICEAND INFORMATIONAL EXPENSES
137 (907)Supervision
138 (908)Customer Assistance Expenses 26,632,425 19,318,915
139 (909)Informational and Instructional Expenses 43,410 13,562
140 (910)Miscellaneous Customer Senrice and Informational Expenses 1,032,532 8,377,985
141 TOTAL Cust.Service and information.Exp.(Total lines 137 thru 140)27,708,367 27,710,462
142 6.SALES EXPENSES
144 (911)Supervision 197,315
145 (912)Demonstrating and Selling Expenses 2,912,712 12
146 (913)Advertising Expenses 719
147 (916)Miscellaneous Sales Expenses 2,043,660 32,159
148 TOTAL Sales Expenses (Enter Total of lines 144 thru 147)5,154,406 32,171
149 7.ADMINISTRATIVEAND GENERAL EXPENSES
151 i (920)Administrative and General Salaries 84,941,723|107,922,565
152 (921)Office Supplies and Expenses 251,668 55,945,951
153 (Less)(922)Administrative Expenses Transferred-Credit 10,709,386 66,668,074
FERC FORMNO.1 (ED.12-93)Page 322
Name of Respondent I his Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
ELi-C I NIC UPI-RA I ION ANU MAIN I ENANUb I-XEtNSbb (COntinued)
If the amount for previous year is not derived from previously reported figures,explain in footnote.
Line Account Amount for Arrtount frCurrentYearPreviousearNo·(a)(b)(c)
154 7.ADMINISTRATIVEAND GENERAL EXPENSES (Continued)
155 (923)Outside Services Employed 39,145,149 36,813,971
156 (924)Property Insurance 7,943,105 10,806,849
157 (925)Injuries and Damages 8,137,061 7,828,018
158 (926)Employee Pensions and Benefits -1,930,073 35,705,131
159 (927)Franchise Requirements 45
160 (928)Regulatory Commission Expenses 8,517,445 13,381,194
161 (929)(Less)Duplicate Charges-Cr.2,329,943 225,861
162 (930.1)General Advertising Expenses 2,678,307 2,048,413
163 (930.2)Miscellaneous General Expenses -40,519,532 -1,319,039
164 (931)Rents 3,811,25 7,470,507
165 TOTAL Operation (Enter Total of lines 151 thru 164)99,936,77 209,709,670
166 Maintenance
167 (935)Maintenance of General Plant 422,92
168 TOTAL Admin &General Expenses (Total of lines 165 thru 167)100,359,705 209,709,670
169 TOTAL Elec Op and Maint Expn (Tot 80,100,126,134,141,148,168)3,135,887,726 2,165,230,119
NUMBEROF ELECTRIC DEPARTMENT EMPLOYEES
1.The data on numberof employees should be reported constructión 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'spayroll 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 equivalentemployees
employes on line 3,and show the numberof such special attributed to the electric departmentfrom joint functions.
1.Payroll Period Ended (Date)12/25/2000
2.Total Regular Full-TimeEmployees 6,557
3.Total Part-Timeand Temporary Employees 564
4.Total Employees 7,121
FERC FORM NO.1 (ED.12-93)Page 323
Name of Respondent I his Report is:Date of Report Year ot keport
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000
(2)A Resubmission //
PURCHAM-D PUWER (Account bbb)(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-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
2 Power Purchases
3 American Electric Power OS NA NA NA
4 American Electric Power SF NA NA NA
5 Anaheim,City of OS NA NA NA
6 Anaheim,City of SF NA NA NA
7 Aquila Power Corp.OS NA NA NA
8 Aquila Power Corp.SF NA NA NA
9 Arizona Public Service Company LF NA NA NA
10 Arizona Public Service Company LF NA NA NA
11 Arizona Public Service Company OS NA NA NA
12 Arizona Public Service Company SF NA NA NA
13 Avista Corp.OS NA NA NA
14 Avista Corp.LF 150 150 150
Total
FERCFORM NO.1 (ED.12-90)Page 326
Name of Respondent I nis Report is:\Jate of Report Ÿear of Report i
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
PU ibHAerl)FUvvi-ktAccount bba)Nonlinueu)(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 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 (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.
PUvvER BACHANbbb Cua ubt I l LElvil-NI UE PuvvERMegaWattHours Line
Purchased MegaWatt Hours Megavvatt Hours Demand Charges Energy Charges Other Charges lotal (J+k+1)No.Received Delivered ($)($)($)of Settlement (S)
(g)(h)(i)(j)(k)(1)(m)
1
1,415 164,612 164,612 3
730,162 50,036,002 -849 50,035,153 4
13,60C 1,441,60C 1,441,600 5
20,00C 2,600,00C 2,600,000 6
43C 29,30C 29,300 7
725,18E 67,756,18E 67,756,188 8
292,88C 10,420,457 10,420,457 $
175,29E 9,800,000 9,800,000 10
145,04E 12,526,842 12,526,842 11
655,652 48,486,470 48,486,470 12
39,625 733,366 283,548 1,016,914 13
82,80C 1,881,000 5,216,91€7,097,916 14
28,098,219 6,946,122 6,448,750 162,146,768 1,756,314,610 24,024,907 1,942,486,285
FERC FORM NO.1 (ED.12-90)Page 327
Name of Respondent I nis Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
PURCHAbl-D PUWER (Account bbb)(Includmg power excnanges)
1.Report all power purchases made during the year.Also report exchanges of electricity (i.e.,transactions involving a balancing ofdebitsandcreditsforenergy,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 useacronyms.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.,thesupplierincludesprojectsloadforthisserviceinitssystemresourceplanning).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 emergencyenergyfromthirdpartiestomaintaindeliveriesofLFservice).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 oneyearorless.
LU -for long-term service from a designated generating unit."Long-term"means five years or longer.The availability and reliability ofservice,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 allnon-firm service regardless of the Length of the contract and senrice 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 FERCRate Average Actual Demand (MW)Classifi-Schedule or Monthly Billing Averáge AverageNo.(Footnote Affiliations)cation Tariff Number Demand(MW)Monthly NCP Demant Monthly CP Demand(a)(b)(c)(d)(e)(f)
1 Avista Corp.SF NA NA NA
2 Avista Energy,Inc.OS NA NA NA
3 Avista Energy,Inc.SF NA NA NA
4 Beaver City LF NA NA NA
5 Bell Mountain Power LU 0.2 0.3 0.2
6 Biomass One,Limited Partnership LU 22.5 17 10.6
7 Birch Creek Hydro LU 2.1 2.4 2.1
8 Black Hills Power &Light Company LF NA NA NA
9 Black Hills Power &Light Company LU NA 22.7 NA
10 Bogus Creek LU NA NA NA
11 Boise Cascade Corporation OS NA NA NA
12 Bonneville Power Administration IF 1100 1100 1012.5
13 Bonneville Power Administration LF 9.7 8.5 8.5
14 Bonneville Power Administration LU NA NA NA
Total
FERCFORM NO.1 (ED.12-90)Page 326.1
Name of Respondent I ms Report Is:Date of Report Year ot keport
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
FU tuHA VµvvEk(Accoügt Doo)tuonunued)ncluding power excnanges)
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 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.Repon 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 (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 explanatoryfootnote.
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.
PUvvER EACHANUES I Gud l ysk I l LEMENl UI-PUvvEkMegaWattHours Line
Purchased MegaWatt Hours MegaWatt Hours Demand Charges Energy Charges Uther Charges lotal (j+k+l)No.Received Delivered ($)($)(S)of Settlement ($)
(g)(h)(i)(j)(k)(I)(rn)
280,672 14,078,13E 14,078,138 1
416 11,224 11,224 Ž
546,082 28,598,11E 28,598,118 3
64 4,522 4,523 4
1,985 75,385 27,787 103,172 5
125,257 2,111,400 14,902,10E 17,013,508 6
18,78E 758,774 263,037 1,021,811 7
187,955 16,182,692 16,182,693 8
3,564 600,000 949,766 1,549,766 9
1,244 34,024 34,024 10
4,08C 1,358,77E 1,358,778 11
68,040,000 68,040,000 12
53,298 53,298 13
2,82C 101,52C 101,520 14
28,098,219 6,946,122 6,448,750 162,146,768 1,756,314,610 24,024,907 1,942,486,286
FERC FORMNO.1 (ED.12-90)Page 327.1
Name of Respondent i his Report is:I.>ate ot keport Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
PURCHAbED PUWI-R (Account bbb)(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.,thesupplierincludesprojectsloadforthisserviceinitssystemresourceplanning).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 emergencyenergyfromthirdpartiestomaintaindeliveriesofLFservice).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 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 involvinga 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 Nameof Company or Public Authority Statistical FERC Rate Average Actual Demand (MW)
Classifi-Schedule or Monthly Billing Averáge AverageNo.(Footnote Affiliations)cation Tariff Number Demand (MW)Monthly NCP Demant Monthly CP Demand
(a)(b)(c)(d)(e)(f)
1 Bonneville Power Administration OS NA NA NA
2 Bonneville Power Administration SF NA NA NA
3 Boston Power LU 0.08 0.05 0.05
4 Boyd,James LU 0.3 0.5 0.2
5 BP Energy Company LU NA NA NA
6 BPEnergyCompany SF NA NA NA
7 Burbank,City of SF NA NA NA
8 California Department of Water Resourc SF NA NA NA
9 Califomia Independent System Operator OS NA NA NA
10 Califomia Independent System Operator SF NA NA NA
11 Califomia Power Exchange OS NA NA NA
12 Califomia Power Exchange SF NA NA NA
13 Cargill-Alliant,LLC OS NA NA NA
14 Cargill-Alliant,LLC SF NA NA NA
Total
FERCFORM NO.1 (ED.12-90)Page 326.2
Name of Respondent I his Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
PU sbna PUvvEktAccount bob;tuonunued)uding 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.MonthlyCP 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 (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.
Puvvbk ExuHANbbe i UUo liot-I I LEMENI UF PUvvERMegaWattHoursi Line
Purchased MegaWatt Hours MegaWatt Hours L)emand Charges t-nergy Charges Uther Charges lotal 0+k+l)No.Received Delivered ($)($)($)of Settlement($)
(g)(h)(i)(j)(k)(I)(m)
4,74E 348,32E 348,328 1
692,912 31,671,502 151,400 31,822,903 2
462 5,319 32,026 37,344 3
2,122 20,098 144,34C 164,438 4
28,372 4,424,160 4,424,160 5
51,60C 5,384,100 5,384,100 6
475 66,646 66,645 7
19,95C 618,65C 618,650 8
1,766 12,81E 12,819 $
55,28E 1,999,355 1,999,355 10
468,06E 468,069 11
614,932 105,019,994 49,353 105,069,347 1Ž
3,02E 76,814 76,814 13
80,22E 6,334,50C 6,334,500 14
28,098,219 6,946,122 6,448,750 162,146,768 1,756,314,610 24,024,907 1,942,486,285
FERC FORMNO.1 (ED.12-90)Page 327.2
Name of Respondent I nis Report is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
PURCHAbEU PUWl-R (Account bbb)(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 oneyearorless.
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 Nameof Company or Public Authority Statistical FERCRate 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 CDM Hydro LU 2.9 3.8 2.8
2 Central Oregon Irrigation District LU 5.9 4.6 3.6
3 Chelan County Public Utility District LU NA NA NA
4 Chelan County Public Utility District OS NA NA NA
5 Chelan County Public Utility District SF NA NA NA
6 Cinergy Services Inc.SF NA NA NA
7 City of Buffalo LU 0.2 0.2 0.2
8 Coastal Merchant Energy SF NA NA NA
9 Colorado Springs Utilities OS NA NA NA
10 Colorado Springs Utilities SF NA NA NA
11 Columbia Storage Power Exchange LF NA NA NA
12 Commercial Energy Management LU 0.2 0.5 0.3
13 Conagra Energy Services SF NA NA NA
14 Constellation Power Source Inc.OS NA NA NA
Total
FERC FORM NO.1 (ED.12-90)Page 326.3
Name ot Respondent i nis Report is:l.Jate of Report Year of Report
PacifiCorp (1)g An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
PUK rise Uvvektaccount ooo;(Lonunueu;(I ing 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 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 (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
POWEREACHANbbb GUb ||5E I l LblvibN I UN POVVERMegaWattHours Line
Purchased MegaWatt Hours MegaWatt Hours L)emand Charges Energy Charges Uther Charges lotal (j+k+l)No.Received Delivered ($)($)($)of Settlement ($)
(g)(h)(i)(j)(k)(I)(m)
25,352 1,018,230 354,94E 1,373,179 1
34,372 608,597 2,585,134 3,193,731 Ž
371,196 3,100,971 3,100,971 $
73,175 73,175 4
61,45C 5,322,65C 5,322,650 5
116,80C 6,642,58C 6,642,580 6
1,901 18,422 43,00E 61,428 7
3,40C 244,60C 244,600 8
72C 54,275 54,275 9
1,621 191,395 191,395 10
84,761 11
2,114 18,564 89,79E 108,362 1Ž
12,825 749,35C 749,350 13
25 375 375 14
28,098,219 6,946,122 6,448,750 162,146,768 1,756,314,610 24,024,907 1,942,486,286
FERC FORM NO.1 (ED.12-90)Page 327.3
Nameof Respondent I his Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
PURCHAkibU PUvvbR (Account boo)(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-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 Constellation Power Source Inc.SF NA NA NA
2 Coral Power SF NA NA NA
3 Curtiss Livestock LU NA NA NA
4 Davis Company Waste Management LU NA NA NA
5 Deschutes Valley Water District LU 4.5 3.5 3.1
6 Deseret Generation &Transmission Coop LF NA NA NA
7 Deseret Generation &Transmission Coop LF NA NA NA
8 Deseret Generation &Transmission Coop SF NA NA NA
9 Douglas County Public Utility District LU NA NA NA
10 Douglas County Public Utility District OS NA NA NA
11 Douglas County Public Utility District SF NA NA NA
12 DR Johnson Lumber Company LU 8.6 8.8 7
13 Duke Energy Trading OS NA NA NA
14 Duke Energy Trading SF NA NA NA
Total
FERC FORMNO.1 (ED.12-90)Page 326.4
Name of Respondent I nis Report Is:Date of Report Year of Report
PacifiCor (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
Pu sbHA PUvvbktAccounl boo)6.,onlinued)uding 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 PUWbk EXCHANebs Gud libb I I LHvlEÑ l UI-PUWERMegaWattHours|Line
Purchased IviegaWatt Hours ivlegaWatt Hours Demand unarges t-nergy Charges Other Uharges lotal U+k+1)No.Received Delivered ($)($)($)of Settlement ($)(g)(h)(i)(j)(k)(I)(m)
414,77C 24,797,93E 24,797,939 1
64,556 5,404,927 5,404,927 2
211 12,367 12,367 3
3,102 50,44E 50,448 4
26,877 441,373 2,273,802 2,715,175 5
784,123 784,123 6
574,471 18,242,586 -1.733,873 16,508,716 7
53,63E 6,691,787 6,691,787 8
279,12C 2,053,975 2,053,975 0
89,68E 1,201,894 1,201,894 10
14,294 829,09E 829,096 11
64,952 783,495 5,449,535 6,233,030 12
6,02C 173,32C 173,320 13
687,61E 52,655,112 52,655,112 14
28,098,219 6,946,122 6,448,750 162,146,768 1,756,314,610 24,024,907 1,942,486,285
FERC FORM NO.1 (ED.12-90).Page 327.4
Name of Respondent I nis Report is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
PURCHASEDPUWER (Account bbb)(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
senrice,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 Companyor 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 Dynegy Power Marketing,Inc.OS NA NA NA
2 Dynegy Power Marketing,Inc.SF NA NA NA
3 Eagle Point Irrigation LU 0.4 0.5 0.4
4 El Paso Energy Marketing OS NA NA NA
5 El Paso Energy Marketing SF NA NA NA
6 Enron Power Marketing,Inc.OS NA NA NA
7 Enron Power Marketing,Inc.SF NA NA NA
8 Eugene Water &Electric Board OS NA NA NA
9 Eugene Water &Electric Board SF NA NA NA
10 Falls Creek LU 2.3 1.3 0.6
11 Farmers Irrigation #2 LU 4.1 3.2 2.5
12 Fery,Loyd LU NA NA NA
13 Fillmore City LF NA NA NA
14 Flathead Electric Cooperative,Inc.LF NA NA NA
Total
FERC FORM NO.1 (ED.12-90)Page 326.5
Name of Respondent I nis Report is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
RJ mr1Ao UvvEktaccounl oco)(Lonlinued)(I ing 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 (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 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.
PUvvEk EACHANGEd GUd Imb ll LblvlbN I UI-PUVVERMegaWattHours Line
Purchased tvlegavvatt Hours Ivlegavvatt Hours Uemand Unarges t-nergy unarges utner Charges lotal (J+k+l)No.Received Delivered ($)($)($)of Settlement ($)(g)(h)(i)(j)(k)(!)(m)
29,941 640,735 640,735 1
421,201 33,451,804 33,451,804 Ž
3,38E 43,870 299,592 343,463 3
10,40C 361,80C 361,800 4
483,34:49,591,207 49,591,207 5
107,661 6,785,67E 6,785,676 6
3,033,007 268,486,132 268,486,132 7
41C 12,52C 12,520 8
35,557 2,744,16E 2,744,169 9
15,254 198,580 1,228,141 1,426,721 10
23,09C 351,548 1,877,077 2,228,625 11
262 15,417 15,417 1Ž
13C 14,07€14,076 13
1,360 5,601 5,601 14
28,098,219 6,946,122 6,448,750 162,146,768 1,756,314,610 24,024,907 1,942,486,285
FERC FORM NO.1 (ED.12-90)Page 327.5
Nameot Respondent I his Report Is:Date ot keport Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
PUkcHASED PUWER (Account ebb)(including power exchanges)
1.Report all power purchases made during the year.Also report exchanges of electricity (i.e.,transactions involving a balancing ofdebitsandcreditsforenergy,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 oneyearorless.
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 Nameof Company or Public Authority Statistical FERC Rate Average Actual Demand (MW)
Classifi-Schedule or Monthly Billing Averáge AverageNo.(Footnote Affiliations)cation Tariff Number Demand (MW)Monthly NCPDemara Monthly CP Demand
(a)(b)(c)(d)(e)(f)
1 Galesville Dam LU 0.7 0.9 0.8
2 Garland Canal LU 1.5 1.4 1.2
3 General ChemicalCompany OS NA NA NA
4 Georgetown Power LU 0.3 0.3 0.3
5 Glendale,City of SF NA NA NA
6 Grand Valley Rural Power LF NA NA NA
7 Grant County Public Utility District N LF NA NA NA
8 Grant County Public Utility District N LU NA NA NA
9 Grant County Public Utility District N LU NA NA NA
10 Grant County Public Utility District N OS NA NA NA
11 Grant County Public Utility District N SF NA NA NA
12 Great Salt Lake Minerals LU NA NA NA
13 Green Mountain.com SF NA NA NA
14 Heber Light &Power LF NA NA NA
Total
FERC FORM NO.1 (ED.12-90)Page 326.6
Name of Respondent i his Report is:Date ot Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
HJ <bHA PUvvER(Account bbo)(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 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 (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 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.
PUvvENBACHANGES bus116EI ILbMENI UE PUvvbRMegaWattHours Line
Purchased MégaWatt Hours MegaWatt Hours Demand Charges Energy Charges Other Charges lotal (j+k+l)No.Received Delivered ($)($)($)of Settlement ($)(g)(h)(i)(j)(k)(I)(m)
5,38E 70,991 508,62E 579,619 1
9,834 98,152 295,894 394,046 Ž
3,486 51,941 51,941 3
2,217 87,249 31,032 118,282 4
45,65E 1,083,841 1,083,841 5
7E 6,85C 6,850 6
87,60C 3,066,00C 3,066,000 7
843,75E 6,175,350 6,175,350 8
626,927 3,695,682 3,695,682 9
15C 4,05C 9,035 13,085 10
183,97E 13,465,781 -615 13,465,166 11
19,915 400,487 41,095 441,582 12
17 32,44E 32,446 13
2,665 157,405 157,405 14
28,098,219 6,946,122 6,448,750 162,146,768 1,756,314,610 24,024,907 1,942,486,285
FERC FORM NO.1 (ED.12-90)Page 327.6
Nameof Respondent I his Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
PURCHAt;IEUPUWER (Account bbb)(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 Authordy Statistical FERC Rate Average Actual Demand (MW)Classifi-Schedule or Monthly Billing Average AverageNo.(Footnote Affiliations)cation Tariff Number Demand (MW)Monthly NCPDemant Monthly CP Demand
(a)(b)(c)(d)(e)(f)
1 Hermiston Generating Company,L.P.LU 280 321.4 238
2 Hinson Power Company,Inc.IF NA NA NA
3 Hinson Power Company,Inc.OS NA NA NA
4 Hurricane,City of LF NA NA NA
5 Idaho Falls,City of LU NA NA NA
6 Idaho Power Company OS NA NA NA
7 Idaho Power Company SF NA NA NA
8 Ingram Warm Springs Ranch LU 0.3 0.4 0.3
9 Intermountain Power Project LU 64 64 64
10 Kennecott LU NA NA NA
11 Koch Power Services,Inc.SF NA NA NA
12 Lacomb Irrigation LU NA NA NA
13 Lake Siskiyou LU 3.4 4 2.7
14 Los Angeles,City of OS NA NA NA
Total
FERC FORM NO.1 (ED.12-90)Page 326.7
Name of Respondent i his Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
FU LHA PUvvEk(Accoupl oco)(Continued;ncluding power excnanges)
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).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 (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.
PUvvER EACHANebb Guo libE I i LalvlEN I Ul-PUUUbkMegaWattHours Line
Purchased MegaWatt Hours MegaWatt Hours Demand Charges knergy Charges Uther Charges I otal (J+k+l)No.Received Delivered ($)($)($)of Settlement ($)
(g)(h)(i)(j)(k)(I)(m)
1,940,77C 39,437,572 34,367,62E 251,973 74,057,174 1
4,357 4,361,157 4,361,157
38,855 6,272,905 6,272,905 3
89E 28,735 28,735 4
54,88E 2,565,101 2,565,101 5
7,352 523,60C 50,145 573,745 6
705,427 59,057,767 59,057,767 7
2,47C 100,021 34,584 134,605 8
532,91E 8,728,000 14,457,912 -549 23,185,363 9
20E 1,792,454 1,792,454 10
61,60C 3,046,60C 3,046,600 11
3,617 257,247 257,247 12
24,882 373,871 2,151,702 2,525,574 13
17,05E 2,361,831 2,361,831 14
28,098,219 6,946,122 6,448,750 162,146,768 1,756,314,610 24,024,907 1,942,486,285
FERC FORMNO.1 (ED.12-90)Page 327.7
Name ot Respondent I his Report is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
PURCHAbi-U PUWER (Account bbb)(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 Companyor 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 Demari Monthly CP Demand
(a)(b)(c)(d)(e)(f)
1 Los Angeles,City of SF NA NA NA
2 Luckey,Paul LU NA NA NA
3 Marsh Valley Hydro Electric Company LU 0.6 1 0.6
4 Merchant Energy Group of the Americas SF NA NA NA
5 Merrill Lynch Capital Services OS NA NA NA
6 Merrill Lynch Capital Services SF NA NA NA
7 Middlefork Irrigation District LU 2.6 2.2 2.1
8 Mink Creek Hydro LU 0.9 1.1 0.9
9 Modesto Irrigation District OS NA NA NA
10 Modesto Irrigation District SF NA NA NA
11 Monsanto OS NA NA NA
12 Morgan City LF NA NA NA
13 Morgan Stanley Capitol Group inc.SF NA NA NA
14 Municipal Energy Agency of Nebraska OS NA NA NA
Total
FERC FORM NO.1 (ED.12-90)Page 326.8
Name of Respondent i his Report is:Date of Report Year ot keport
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
PtJ a,HA FuvvEktAccoupt aca)(Dontinued;ncluding power excnanges)
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).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 (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 (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 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.
Puvvbb EACHANubo Cub liëE I I LulvleN I ul-PuvvesMegaWattHours Line
Purchased tvlegavvatt Hours Ivlegavvatt Hours Demand Charges energy Charges utner Charges lotal U+k+I)No.Received Delivered ($)($)($)of Settlement ($)(g)(h)(i)(j)(k)(I)(m)
54,295 4,303,996 430,056 4,734,055 1
322 23,596 23,599 Ž
5,44€220,521 76,246 296,769 3
70,40C 2,022,84C 2,022,840 4
10,00C 1,400,00C 1,400,000 5
128,976 11,228,21C 11,228,210 $
19,68C 158,656 1,467,622 1,626,278 7
7,75E 296,508 108,62E 405,134 8
6,17E 168,342 168,342 9
20,522 1,385,611 1,385,611 10
1,257,500 1,257,500 11
31 784 784 1Ž
228,426 17,920,66C 17,920,660 13
6,49C 1,031,17C 1,031,170 14
28,098,219 6,946,122 6,448,750 162,146,768 1,756,314,610 24,024,907 1,942,486,286
FERC FORM NO.1 (ED.12-90)Page 327.8
Name of Respondent i nis Report is:Date of Report Vear of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
PUkuHAbED PUVvbR (Account bbb)(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 Nameof 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 NCPDemant Monthly CP Demand
(a)(b)(c)(d)(e)(f)
1 Municipal Energy Agency of Nebraska SF NA NA NA
2 Murray City LF NA NA NA
3 Nephi City LF NA NA NA
4 Nevada Power Company OS NA NA NA
5 Nevada Power Company SF NA NA NA
6 Nicholson Sunnybar Ranch LU 0.3 0.3 0.3
7 North Fork Sprague LU 0.5 0.6 0.3
8 Northem Califomia Power Agency OS NA NA NA
9 Northem California Power Agency SF NA NA NA
10 Nucor Corporation SF NA NA NA
11 O.J.Power Company LLI 0.08 0.11 0.09
12 Odell Creek LU 0.07 0.07 0.05
13 Pacific Gas &Electric Company AD NA NA NA
14 Pacific Gas &Electric Company AD NA NA NA
Total
FERCFORM NO.1 (ED.12-90)Page 326.9
Name of Respondent i nis Report is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
Pu summo Uvvt-ktaccount bbo)tuonttriued)(I ing 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.Repod 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 (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.
Huvvek EAUHANees uus I JsE I l LblvibN I UI-FUvvEkMegaWattHours Line
Purchased MegaWatt Hours MegaWatt Hours Demand Charges Energy Charges Other Charges lotal (j+k+l)No.Received Delivered ($)($)($)of Settlement ($)
(g)(h)(i)(j)(k)(I)(m)
24,885 2,699,39:2,699,395 1
6C 3,111 3,111 2
1E 1,70C 1,700 3
55,701 5,854,912 5,854,912 4
109,795 8,122,415 8,122,415 5
2,44C 96,784 34,15E 130,943 6
1,967 48,596 172,10E 220,702 7
1,165 251,500 251,500 8
1,561 315,091 315,091 $
812,000 812,000 1Ò
683 24,010 9,55E 33,568 11
39C 6,032 28,30E 34,337 12
-27,813 -27,813 13
397,413 397,413 14
28,098,219 6,946,122 6,448,750 162,146,768 1,756,314,610 24,024,907 1,942,486,285
FERCFORM NO.1 (ED.12-90)Page 327.9
Name ot Respondent i nis Report is:Date of Neport Year ot keport
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)O A Resubmission //
PURCHASEDPUvvbk (Account bbb)(Incluaing power excnanges)
1.Report all power purchases made during the year.Also report exchanges of electricity (i.e.,transactions involving a balancing-ofdebitsandcreditsforenergy,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 useacronyms.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.,thesupplierincludesprojectsloadforthisserviceinitssystemresourceplanning).In addition,the reliability of requirement service mustbethesameas,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 emergencyenergyfromthirdpartiestomaintaindeliveriesofLFservice).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 lessthanfiveyears.
SF -for short-term service.Use this category for all firm services,where the duration of each period of commitment for service is oneyearorless.
LU -for long-term service from a designated generating unit."Long-term"means five years or longer.The availability and reliability ofservice,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 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 for each adjustment.
Line Narne of Company or PublicAuthority Statistical FERC Rate Average Actual Demand (MW)Classifi-Schedule or Monthly Billing Average AverageNo.(Footnote Affiliations)cation Tariff Number Demand (MW)Monthly NCP Demanti Monthly CP Demand
(a)(b)(c)(d)(e)(f)
1 Pacific Gas &Electric Energy Trading OS NA NA NA
2 Pacific Gas &Electric Energy Trading SF NA NA NA
3 PacifiCorp Power Marketing OS NA NA NA
4 Pancheri,Inc.LU 0.02 0.02 0.02
5 Payson City Corp.LF NA NA NA
6 PECO Energy OS NA NA NA
7 PECOEnergy SF NA NA NA
8 Plains Electric Gen.&Transmission Co SF NA NA NA
9 Platte River Power Authority OS NA NA NA
10 Platte River Power Authority SF NA NA NA
11 Portland General Electric Company LF NA NA NA
12 Portland General Electric Company OS NA NA NA
13 Portland General Electric Company AD NA NA NA
14 Portland General Electric Company SF NA NA NA
Total
FERC FORM NO.1 (ED.12-90)Page 326.10
Name of Respondent I his Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
FUNGHA QvvElyAucount bba;6.,antinued;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,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 (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 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.
MegaWatt Hours PUWER EACHANubb Uub i /bb i i Leivleid i ut-FUWEN Line
Purchased MegaWatt Hours MegaWatt Hours IJemand Charges Energy Charges Uther Charges I otal (j+k+l)No.Received Delivered ($)($)($)of Settlement($)
(g)(h)(i)(j)(k)(I)(m)
60C 40,37:40,375 1
544,272 42,603,97C 42,603,970
3,515 175,78C 175,780 3
195 6,505 2,731 9,236 4
12 1,341 1,341 5
17,021 603,73C 603,730 6
95,085 6,634,93E 6,634,938 7
51 1,02C 1,020 8
16,10C 944,06E 944,069 $
7,367 334,751 334,751 10
24,084 231,718 231,718 11
19,22E 396,317 900 397,217 1Ž
159,263 159,263 13
607,076 36,387,731 36,387,731 14
28,098,219 6,946,122 6,448,750 162,146,768 1,756,314,610 24,024,907 1,942,486,286
FERC FORM NO.1 (ED.12-90)Page 327.10
Name of Respondent I his Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
PUkcHAbbD PUvak (Accou t bbb)(Including power excnange
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 FERCRate Average Actual Demand (MW)
Classifi-Schedule or Monthly Billing Averagé AverageNo.(Footnote Affiliations)cation Tariff Number Demand(MW)Monthly NCP Demant Monthly CP Demand
(a)(b)(c)(d)(e)(f)
1 Powerex OS NA NA NA
2 Powerex SF NA NA NA
3 PPLMontana,LLC OS NA NA NA
4 PPLMontana,LLC SF NA NA NA
5 Preston City Hydro LU 0.3 0.3 0.3
6 Provo City LF NA NA NA
7 Public Service Company of Colorado OS NA NA NA
8 Public Service Company of Colorado SF NA NA NA
9 Public Service Company of New Mexico OS NA NA NA
10 Public Service Company of New Mexico SF NA NA NA
11 Puget Sound Energy OS NA NA NA
12 Puget Sound Energy SF NA NA NA
13 Ralphs Ranches Inc.LU NA NA NA
14 Redding,City of LF 50 50 50
Total
FERCFORMNO.1 (ED.12-90)Page 326.11
Name of Respondent inis Report is:Date ot keport Year ot Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
HJ LMAbt-D MUvvektAccount boo)(t.,anunued)(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 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.
PUvvbH EACHANGEb UUb list I I Lelvt N I uw PovvENMegaWattHours Line
Purchased IVlegavvatt Hours Ivlegavvatt Hours Uemana Charges energy unarges Uther Charges lotal U+k+l)No.Received Delivered ($)($)($)of Settlement ($)
(g)(h)(i)(j)(k)(I)(m)
3,37E 140,674 140,674 1
363,976 49,385,822 49,385,822 Ž
1,93E 231,225 231,225 $
45,95C 3,571,90E 3,571,908 4
2,82C 99,631 39,482 139,114 5
8E 10,89E 10,899 6
35,132 2,557,26E 2,557,266 7
245,687 22,943,760 22,943,760 8
198,85E 14,399,455 14,399,455 9
173,297 8,317,88C 8,317,880 10
86,69C 2,163,405 16,500 2,179,909 11
533,142 32,704,61E 32,704,618 12
35E 25,694 25,694 13
337,38C 8,348,500 5,122,936 1,418.447 14,889,883 14
28,098,219 6,946,122 6,448,750 162,146,768 1,756,314,610 24,024,907 1,942,486,285
FERC FORM NO.1 (ED.12-90)Page 327.11
Name of Respondent I nis Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
PURCHAbEU POWh-R (Account bbb)(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 oneyearorless.
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 FERCRate Average Actual Demand (MW)
Classifi-Schedule or Monthly Billing Average AverageNo.(Footnote Affiliations)cation Tariff Number Demand (MW)Monthly NCP Demara Monthly CP Demand
(a)(b)(c)(d)(e)(f)
1 Redding,City of OS NA NA NA
2 Redding,City of SF NA NA NA
3 Reliant Energy Services,Inc.OS NA NA NA
4 Reliant Energy Services,Inc.SF NA NA NA
5 Riverside,City of OS NA NA NA
6 Riverside,City of SF NA NA NA
7 Rocky Mountain Generation Cooperative OS NA NA NA
8 Rocky Mountain Generation Cooperative SF NA NA NA
9 Roseburg Forest Products LU NA NA NA
10 Roush,Neil LU NA NA NA
11 Sacramento Municipal Utility District LF NA NA NA
12 Sacramento Municipal Utility District OS NA NA NA
13 Sacramento Municipal Utility District SF NA NA NA
14 Salt River Project OS NA NA NA
Total
FERCFORM NO.1 (ED.12-90)Page 326.12
Name of Respondent I nas Report is:Date ot Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
PUttbHao epvvEk(AccotJut boo;(bolitinued)(i uding 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 (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 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.
PUvvak EACHANubb Uub ubb ll LalvlbN I ut-PuvvERMegaWattHours Line
Purchased MegaWatt Hours Megavvatt Hours DemandCharges Energy Charges Uther Charges lotal (j+k+l)No.Received Delivered ($)($)($)of Settlement ($)
(g)(h)(i)(j)(k)(1)(m)
2,556 203,116 203,115 1
2,78E 244,616 244,615 Ž
30,80C 913,24C -58,800 854,440 Š
207,065 18,388,804 18,388,804 4
2,51E 174,20C 174,200 5
16,75C 1,122,345 1,122,345 Š
35,135 1,159,672 1,159,672 7
5,49E 225,77E 225,779 8
7,795 2,306,50C 2,306,500 $
422 24,74E 24,748 10
178,102 1,791,706 1,791,706 11
10,897 706,99C 706,990 12
26,264 2,229,40C 2,229,400 13
159,70E 12,921,936 12,921,935 14
28,098,219 6,946,122 6,448,750 162,146,768 1,756,314,610 24,024,907 1,942,486,285
FERC FORM NO.1 (ED.12-90)Page 327.12
Name of Respondent I nis Report is:Date of keport Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
PURCHAbt·D PUWER (Account bbb)(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.,thesupplierincludesprojectsloadforthisserviceinitssystemresourceplanning).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 emergencyenergyfromthirdpartiestomaintaindeliveriesofLFservice).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 lessthanfiveyears.
SF -for short-term service.Use this category for all firm services,where the duration of each period of commitment for service is oneyearorless.
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 natureoftheserviceinafootnoteforeachadjustment.
Line Name of Company or Public Authority Statistical FERCRate Average Actual Demand (MW)Classifi-Schedule or Monthly Billing Average AverageNo.(Footnote Affiliations)cation Tariff Number Demand (MW)Monthly NCP Dernary Monthly CP Demand(a)(b)(c)(d)(e)(f)
1 Salt River Project SF NA NA NA
2 San Diego Gas &Electric OS NA NA NA
3 San Diego Gas &Electric SF NA NA NA
4 Santa Clara,City of OS NA NA NA
5 Santa Clara,City of SF NA NA NA
6 Santiam Water Control District LU 0.2 0.2 0.2
7 Seattle City Light OS NA NA NA
8 Seattle City Light SF NA NA NA
9 Sempra Energy Trading Corp.OS NA NA NA
10 Sempra Energy Trading Corp.SF NA NA NA
11 SF Phosphates LU NA NA NA
12 Sierra Pacific Power Company OS NA NA NA
13 Sierra Pacific Power Company SF NA NA NA
14 Slate Creek LU 1.8 2 1.6
Total
FERC FORMNO.1 (ED.12-90)Page 326.13
Name of Respondent I his Report Is:Date of Report Ÿear of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
Pu <bHARU PuvvEktAccourit bob)tuontinued)(Including power excnanges)
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 (!).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 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.
PUWER bAUHANei-8 Gus libb I I LElvil-IN I Ul-PUWERMegaWattHours Line
Purchased lvlegaWatt Hours Megawatt Hours uemana Unarges energy unarges Uther Charges lotal U+k+0 No.Received Delivered ($)($)($)of Settlement($)
(g)(h)(i)(j)(k)(I)(m)
108,396 6,614,27E 6,614,276 1
88E 11,171 11,171 2
14,957 806,482 806,483 3
1,12C 28,98C -158,458 -129,478 4
123,392 7,669,677 -681,200 6,988,477 5
1,445 14,317 100,584 114,901 6
121 6,151 6,151 7
43,827 2,698,07C 1,350 2,699,420 8
5C 1,15C 1,150 9
262,16C 26,423,41E 26,423,419 10
66E 9,935 9,935 11
12,53E 564,09C 564,090 12
162,10E 11,126,092 11,126,092 13
12.832 162,708 954,67E 1,117,386 14
28,098,219 6,946,122 6,448,750 162,146,768 1,756,314,610 24,024,907 1,942,486,286
FERC FORM NO.1 (ED.12-90)Page 327.13
Name of Respondent I his Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000
(2)A Resubmission //
PURCHAbbD PUWi-R (Account bbb)(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 Nameof Company or Public Authordy 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 Snohomish Public Utility District SF NA NA NA
2 Southem Califomia Edison Company LF 422 NA NA
3 Southem Califomia Edison Company SF NA NA NA
4 Southern Energy Marketing Company SF NA NA NA
5 Southern Energy Marketing Company OS NA NA NA
6 Spanish Fork City LF NA NA NA
7 Springville City LF NA NA NA
8 Statoil Energy,Inc.SF NA NA NA
9 Stauffer Dry Creek LU 1 1.6 1
10 Strawberry Electric Service District OS NA NA NA
11 Sunnyside LU 46.4 52.6 49.4
12 Tacoma City Light OS NA NA NA
13 Tacoma City Light SF NA NA NA
14 Te×as-New Mexico Power Company SF NA NA NA
Total
FERCFORM NO.1 (ED.12-90)Page 326.14
Name ot Respondent I his Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
FU u.,HA PUvvEK(Account boo)(Lonunued)uding 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,enterthemonthlyaveragebillingdemandincolumn(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 (l).Explain in a footnote all components of the amount shown in column (!).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 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.
PUvvER EACHANUES UUb Use I i LeMEN I UI-PUvvEkMegaWattHours Line
Purchased Ivlegavvatt Hours lvlegavvatt Hours Demand Charges energy Charges Uther Charges lotal U+k+l)No.Received Delivered ($)($)($)of Settlement($)
(g)(h)(i)(j)(k)(I)(m)
28,65C 2,538,50C 2,538,500 1
164,62C 8,176,250 28,727,27E -13,428 36,890,098 Ž
1,452 27,68C 27,680 3
814,704 69,698,602 69,698,603 4
25 625 625 5
47 3,831 3,831 6
41 3,652 3,652 7
40,80C 977,00C 977,000 8
8,857 319,005 123,99C 442,995 9
17 1,334 1,334 10
407,475 10,184,140 12,049,454 22,233,594 11
385 9,48C 72 9,552 12
4,563 393,05C 393,050 13
30C 50,596 50.595 14
28,098,219 6,946,122 6,448,750 162,146,768 1,756,314,610 24,024,907 1,942,486,285
FERC FORM NO.1 (ED.12-90)Page 327.14
Name of Respondent I his Report is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
PURCHAbbu POWER (Account bbb)(Including power excnanges)
1.Report all power purchases made during the year.Also report exchanges of electricity (i.e.,transactions involving a balancingof
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 provideon 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 Nameof Company or PublicAuthority 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 Thayn Ranch Hydro LU 0.2 0.3 0.2
2 The Energy Authority OS NA NA NA
3 Tractebel Energy Marketing,Inc.SF NA NA NA
4 TransAlta Energy Marketing Corp.OS NA NA NA
5 TransAlta Energy Marketing Corp.LF NA NA NA
6 TransAlta Energy Marketing Corp.SF NA NA NA
7 Tri-State Generation &Transmission LF 50 46.9 47.3
8 Tri-State Generation &Transmission OS NA NA NA
9 Tri-State Generation &Transmission SF NA NA NA
10 Tucson Electric Power OS NA NA NA
11 Tucson Electric Power SF NA NA NA
12 United States Bureau of Reclamation LU NA NA NA
13 Utah Associated Municipal Power System OS NA NA NA
14 Utah MunicipalPower Agency OS NA NA NA
Total
FERC FORM NO.1 (ED.12-90)Page 326.15
Name of Respondent I nis Report is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
PtJ suHAo µvvl-ktAccoutitboo)(bolitinued)
(I ing power excnanges)
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 (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 (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.
HuvvEN BACHANUES Uub libe I I LbMbÑ \UP PUVVENMegaWattHours Line
Purchased MegaWatt Hours MegaWattHours Demand Charges Energy Charges Uther Charges I otal ()+k+l)No.Received Delivered ($)($)($)of Settlement ($)
(g)(h)(i)(j)(k)(I)(m)
1,97E 22,351 69,762 92,114 1
20C 4,40C 4,400 Ž
134,46E 11,904,60E 11,904,608 3
5C 1,276 1,275 4
1,308,996 57,839,257 57,839,257 5
171,79E 22,760,634 22,760,634 6
284,955 5,784,000 4,610,572 10,394,572 7
148,74E 8,753,271 8,753,271 $
22,535 1,641,774 1,641,774 $
41,992 3,410,982 3,410,982 10
31,132 2,480,28E 2,480,288 11
59,82C 788,541 788,541 12
1,575 44,23C 44,230 13
764 25,164 25,164 14
28,098,219 6,946,122 6,448,750 162,146,768 1,756,314,610 24,024,907 1,942,486,285
FERC FORM NO.1 (ED.12-90)Page 327.15
Nameof Respondent inis Report is:Date ot keport Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
PURCHAbbu PUvvbk (Account bbb)(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 Utah Municipal Power Agency SF NA NA NA
2 Walla Walla,City of LU 2 1.9 1.9
3 Warm Springs Forest Products LU NA NA NA
4 Warm Springs Power Enterprises LU 19.6 15 7
5 Washington City LF NA NA NA
6 Western Area Power Administration OS NA NA NA
7 Westem Area Power Administration SF NA NA NA
8 Whitmore Oxygen OS NA NA NA
9 Whitney,A.C.LU NA NA NA
10 Wiggins,Duane LU NA NA NA
11 Williams Energy Services Company OS NA NA NA
12 Williams Energy Services Company SF NA NA NA
13 Yakima Tieton LU 1.0 .4 .4
14 Accrual Adjustment
Total
FERC FORM NO.1 (ED.12-90)Page 326.16
Name of Respondent I his Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
PtJ wnAa UvvEktAccount aab;(botibuued)0 ing 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,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 (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 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.
PUWER EXCHANGES Uus libe i l Ll-MEN I UF PUWhMMegaWattHours Line
Purchased MegaWatt Hours MegaWatt Hours L)emand Charges Energy Charges Other Charges Total (j+k+l)No.Received Delivered ($)($)($)of Settlement ($)(g)(h)(i)(j)(k)(I)(m)
24E 7,52C 7,520 1
16.037 140,748 1,650,806 1,791,553 2
2E 606 605 Š
83,706 2,048,592 5,695,070 7,743,667 4
3E 1,97C 1,970 5
29,47E 1,816,46E 1,816,469 6
41,826 3,731,896 3,731,895 7
202 203 8
1 71 71 9
47 2,754 2,754 10
75 1,626 79,000 80,625 11
689,154 48,764,644 48,764,644 12
7,534 65,105 729,29C 794,395 13
-18,164,361 -18,164,361 14
28,098,219 6,946,122 6,448,750 162,146,768 1,756,314,610 24,024,907 1,942,486,286
FERC FORMNO.1 (ED.12-90)Page 327.16
Name of Respondent I his Report Is:Date of Repori Year of keport
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
PURCHA¾EUPUVvt-R (Account bbb)(including power excnanges)
1.Report all power purchases made during the year.Also report exchanges of electricity (i.e.,transactions involving a balancing ofdebitsandcreditsforenergy,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 emergencyenergyfromthirdpartiestomaintaindeliveriesofLFservice).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 lessthanfiveyears.
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 AverageNo.(Footnote Affiliations)cation Tariff Number Demand (MW)Monthly NCP Demano Monthly CP Demand
(a)(b)(c)(d)(e)(f)
1
2 Arizona PublicService Company EX 306 NA NA NA
3 Ashland,City of EX 353 NA NA NA
4 Avista Corp.EX 366 NA NA NA
5 Avista Corp.EX 160 NA NA NA
6 Black Hills Power &Light Company EX 246 NA NA NA
7 Black Hills Power &Light Company EX 424 NA NA NA
8 Bonneville Power Administration EX 160 NA NA NA
9 Bonneville Power Administration EX 368 NA NA NA
10 Bonneville Power Administration EX 237 NA NA NA
11 Bonneville Power Administration EX 256 NA NA NA
12 Bonneville Power Administration EX NA NA NA
13 Bonneville Power Administration EX OV-12 NA NA NA
14 Bonneville Power Administration EX 347 NA NA NA
Total
FERC FORM NO.1 (ED.12-90)Page 326.17
Nameot Respondent I his Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
PlJ <GHA PUvvt-ktAccounl bob)(borilinued)ncluding power e×changes)
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,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 (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 (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.
PUvvEk EACHANUES 005 libb ll Leivil-N I UI-PUvuERMegaWattHours Line
Purchased Ivlegavvatt Hours Megavvatt Hours uemand Charges Energy unarges utner Charges lotal U+k+l)No.Received Delivered ($)($)($)of Settlement($)(g)(h)(i)(j)(k)(I)(m)
1
395,269 396,094 -6,562,103 -6,562,103
2,222 127 75,431 75,431 Š
27,900 31,025 1,305,600 1,305,600 4
7,579 5,561 5
250 6
6,525 -97,875 -97,875 7
199,194 177,631 -1.846.850 -1,846,850 8
174,360 174,200 13.920 13,920 9
97 97 10
20,639 10,714 35,482 35,482 11
1,130,953 1,130,953 -6,448,126 -6,448,126 12
78,216 75,069 1,210,178 1,210,178 13
3,210,400 3,224,092 930,000 930,000 14
28,098,219 6,946,122 6,448,750 162,146,768 1,756,314,610 24,024,907 1,942,486,28E
FERCFORM NO.1 (ED.12-90)Page 327.17
Nameof Respondent I his Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
PURCHAbED Puvvi-R (Account bbb)(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 oneyearorless.
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 FERCRate 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 Califomia ISO EX OV-12 NA NA NA
2 Chelan County Public Utility Dist.No.EX 160 NA NA NA
3 Clark County Public Utility District EX 417 NA NA NA
4 Colockum Transmission Company EX 160 NA NA NA
5 Colorado Public Service Company EX OV-12 NA NA NA
6 Colorado PublicService Company EX 319 NA NA NA
7 Cowlitz County PublicUtility Dist.No EX 160 NA NA NA
8 Douglas County Public Utility Dist.No EX 160 NA NA NA
9 Emerald Peoples Utility District EX 351 NA NA NA
10 Enron Power Marketing Inc.EX OV-11 NA NA NA
11 Eugene Water &Electric Board EX OV-12 NA NA NA
12 Flathead Electric Cooperative EX OV-11 NA NA NA
13 Grant County Public Utility Dist.No.EX 160 NA NA NA
14 Idaho Power Company EX 380 NA NA NA
Total
FERC FORM NO.1 (ED.12-90)Page 326.18
Name ot Respondent I nis Report Is:Date ot keport Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
FU n.,mAbt U PUvvENIAccounl obb)(Lonlinued)(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 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 (1).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 (!)
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.
PUuvER EACHANGES I Gud liëE I I LE.Mt-N I ul-PuvvERMegaWattHours|Line
Purchased lviegavvatt Hours Megavvatt Hours Demand Charges t-nergy uharges other Unarges lotal U+k+1)No.Received Delivered ($)($)($)of Settlement ($)
(g)(h)(i)(j)(k)(I)(m)
12,803 6,578 -12,150 -12,150 1
636 14,591
416,048 10,540,329 10,540,329 3
6,527 189,298 -39,726 -39,726 4
73,535 63,357 1.039.694 1,039,694 5
6,150 6
209,788 201,536 7
3,133 8
75 -1,883 -1,883 9
160 79 -1,545 -1,545 1Ò
20,448 25,503 -87,195 -87,195 11
1,955 1,176 -90,860 -90,860 12
9,726 58,489 13
359,002 260,251 14
28,098,219 6,946,122 6,448,750 162,146,768 1,756,314,610 24,024,907 1,942,486,286
FERCFORM NO.1 (ED.12-90)Page 327.18
Name of Respondent I nas Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
PURCHA I-D Puv\/bR (Account bbb)(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 senrice.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 Nameof 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 160 NA NA NA
2 Nevada Power Company EX WSPP NA NA NA
3 Portland General Electric Company EX 160 NA NA NA
4 Redding,City of EX 364 NA NA NA
5 Southern Califomia Edison EX 248 NA NA NA
6 Tri-State Generation &Transmission EX 319 NA NA NA
7 United States Bureau of Reclamation EX 67 NA NA NA
8 Westem Area Power Administration EX OV-12 NA NA NA
9
10 System Deviation NA NA NA
11
12
13
14
Total
FERCFORM NO.1 (ED.12-90)Page 326.19
Name of Respondent I nis Report Is:Date of Report Ýear of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
PUmbHA QvvEN(Accourit boo)(Lonullued)ing power exchanges)
AD -for out-of-period adjustment.Use this code forany 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 (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 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 PUvvbH BACHANUES uus liëE I l LbivlbN I UI-PUV ERMegaWattHours|Line
Purchased tviegavvatt Hours Megavvatt Hours Demand charges l-nergy unarges Uther Charges Iotal U+k+l)
Received Delivered ($)($)($)of Settlement($)
(g)(h)(i)(j)(k)(1)(m)
5,215 1
92,400 92,400 -388,080 -388,080 2
143,195 142,027 3
151,202 5,033,506 5,033,506 4
42,330 5
148,014 153,251 3,622,042 3,622,042 6
5,000 7
6 15 8
9
-954 10
11
12
1$
14
28,098,219 6,946,122 6,448,750 162,146,768 1,756,314,610 24,024,907 1,942,486,285
FERC FORM NO.1 (ED.12-90)Page 327.19
Name of Respondent I his Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
I NAlmalvilauluiN UF t-u-o i NILI I Y I-UN U i I-tt-r<a (Account «oo;(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 American Electric Power OS
2 Aquila Power Corporation OS
3 Arizona Public Service Company OS
4 Arizona Public Service Company Idaho Power Company ŠE
5 Black Hills Power &Light Company PacifiCorp Merchant Montana-Dakota Utilities Company LF
6 Black Hills Power &Light Company PacifiCorp Merchant Black Hills Power &Light Company LE
7 Black Hills Power &Light Company $F
8 Bonneville Power Administration Bonneville Power Administration Bonneville Power Administration LË
9 Bonneville Power Administration Bonneville Power Administration Bonneville Power Administration LE
10 Bonneville Power Administration Bonneville Power Administration Bonneville Power Administration LP
11 Bonneville Power Administration Bonneville Power Administration Bonneville Power Administration LE
12 Bonneville Power Administration OS
13 Bonneville Power Administration Bonneville Power Administration Idaho Power Company 89
14 Cargill-Alliant 08
15 Constellation Power Source,Inc.OS
16 Deseret Generation &Tran.Coop Deseret Generation &Tran.Coop Deseret Generation &Tran.Coop LË
17 Duke Energy Trading Montana Power Company 08
TOTAL
FERC FORM NO.1 (ED.12-90)Page 328
Name ot Respondent I his Report is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
I KAiyalvilablUIN Ut bLEDI Kibi I Y PUN Ut I-IbNo (Account 400)(Gonunuea)(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 all
nonfirm 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.
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.
5.In column (e),identify the FERC Rate Schedule or Tariff Number,On separate lines,list all FERC rate schedules or contract
designations under which service,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 the
designation for the substation,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 the
contract.
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 tvlegavvait hourS Megavvatt Hours No.TariffNumber Designation)Designation)(MW)Received Delivered(e)(f)(g)(h)(i)(j)
OV-11 Various Various 213 212 1
OV-11 Various Various 157,396 157,39E 2
OV-11 Various Various 22,796 22,796 3
OV-11 Various Various 66,200 66,20C 4
42 Various Sheridan 5
236 Various Wyodak 42 6
OV-11 Various Various 48,480 48,48C 7
324 Lost Creek Project Reston Substation 298,496 298,496 8
299 Bingham,Idaho Various 200 1,159,177 1,159,177 9
237 Various Various 285 10
256 Various Various 317 11
OV-11 Various Various 13,634 13,634 12
OV-11 Various Various 174,840 174,84(13
OV-11 Various Various 130,028 130,026 14
OV-11 Mona,Utah Various 106,704 106,701 15
280 Various Various 50 54,068 54,06E 16
OV-11 Various Four Corners 1,200 1,20C 17
1,763 13,553,792 13,553,792
FERC FORM NO.1 (ED.12-90)Page 329
Name of Respondent t his Report is:Date of Report Year ot Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
I KAINolvilobiull UP t.L.EU I r<lui lY I-UK Ui Mt-No (Account 400)(continuea)(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 (1),provide revenues from energy charges related to theamountofenergytransferred.In column (m),provide the total revenues from all other charges on bills or vouchers rendered,includingoutofperiodadjustments.Explain in a footnote all components of the amount shown in column (m).Report in column (n)the totalchargeshownonbillsrenderedtotheentityListedincolumn(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 FRÓM TRANSMISSION ÓF ELECTRIÖlTY FÓROTHERŠ
Oemand Õharges Ënergy Charges (Óther Charges)Total Revenues ($)Lilie
($)($)($)(k+I+m)No.(k)(I)(m)(n)
1,244 1,244 1
569,394 569,394 2
100,106 100,106 3
246,225 246,225 4
786,725 786,725 5
899,100 899,100 6
189,240 189,240 7
312,276 312,276 8
1,474,994 244,008 (1,719,002 9
2,648,694 74,124 i 2,722,818 10
4,398,029 4,398,029 11
79,209 79,209 12
475,875 475,875 13
437,849 437,849 14
329,924 -12,600 317,324 15
1,134,199 1,134,199 16
1,800 1,800 17
22,008,294 25,207,716 2,478,013 49,694,023
FERCFORM NO.1 (ED.12-90)Page 330
BLANK PAGE
(Next Page is:328.1)
Name of Respondent I his Report Is:Date of Report Year of Report
PacifiCorp (1)g An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission I /
\NAlsalviloalulN Ur t-l-t-o i Klot i Y rus u i l-ler<a (Account 400)(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 interruptedforeconomicreasonsandisintendedtoremainreliableevenunderadverseconditions.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 thecontract.
SF -for short-term firm transmission service.Use this category for all firm services,where the duration of each period of commitmentforserviceislessthanoneyear.
Line Payment By Energy Received From Energy Delivered To Statistical
No (Companyof Public Authority)(Company of Public Authority)(Company of Public Authority)Classifi-(Footnote Affiliation)(Footnote Affiliation)(Footnote Affiliation)cation(a)(b)(c)(d)
1 Dynergy Power Marketing,Inc.OS
2 Enron Power Marketing,Inc.ÖŠ
3 Enron Power Marketing,Inc.SË
4 Fall River Rural Electric Coop Fall River Rural Electric Coop Idaho Power Company LF
5 Flathead Electric Coop Deseret Generation &Transmission Flathead Electric Coop LF
6 Idaho Power Company Idaho Power Company Idaho Power Company LP
7 Idaho Power Company $F
8 Idaho Power Company OS
9 Montana Power Company Westem Area Power Administration Ô$
10 Morgan Stanley Capital Group inc.$Ë
11 Moon Lake Electric Association Moon Lake Electric Association Moon Lake Electric Association LF
12 PPL Montana Westem Area Power Administration 0$
13 PacifiCorp Power Marketing OS
14 Powerex Õ$
15 Powerex SF
16 Powerex Powerex Powerex LE
17 Public Service Company of Colorado ŠF
TOTAL
FERC FORM NO.1 (ED.12-90)Page 328.1
Name ot Respondent I his Report is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
I KAINbMibblUIS Ut tLEU I NICI lY I-UN U i McNo (AccounI 4bb)(COnlinUSG)(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 all
nonfirm 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.
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.
5.In column (e),identify the FERC Rate Schedule or Tariff Number,On separate lines,list all FERC rate schedules or contract
designations under which service,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 the
designation for the substation,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 the
contract.
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 Pointof Delivery Billing TRANSFER OF ENERGY LineScheduleof(Subsatation or Other (Substation or Other Demand Ivlegavvar nours tviegavvar hours No.Tariff Number Designation)Designation)(MW)Received Delivered(e)(f)(g)(h)(i)()
OV-11 Mona,Utah Yellowtail,Wyoming 600 60C 1
WSPP Various Various 19,603 19,602 2
WSPP Various Various 22,550 22,55C 3
322 Fall River Interconn Goshen Substation 9 4
OV-11 Mona,Utah Flathead,Montana 5
OV-11 Mona,Utah Harry Allen,Nevada 35 6
OV-11 Various Various 1,955,990 1,955,99C 7
OV-11 Various Various 1,820,757 1,820,757 8
OV-11 Yellowtail,Wyoming Bridger,Wyoming 35,970 35,97C 9
OV-11 Main Main 2,400 2,40C 10
302 Duchesne,Utah Duchesne,Utah 2 11
OV-11 Various Yellowtail,Wyoming 75,922 75,922 12
OV-11 Yellowtail,Wyoming Various 37,528 37,52E 13
OV-11 Various Various 116,691 116,691 14
OV-11 Various Various 88,800 88,80C 15
OV-11 Various Cal ISO,California 80 16
OV-11 Various Various 657,539 657,53E 17
1,763 13,553,792 13,553,792
FERC FORM NO.1 (ED.12-90)Page 329.1
Name ot Respondent I his Report is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
i NAlvolvilabiuW ut t-l..EU i NIGI i Y I-UK U I rit-ko (Account 400)(Dontinuea)(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 e×plaining 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 FROMTRANSMIS$IÓN OF ELEÓTRIClfY FOR OTHERŠ
Demand Charges Energy Charges (Other Charges)Iotal Revenues ($)Line
($)($)($)(k+l+m)No.
(k)(I)(m)(n)
2,325 2,325 1
110,431 110,431 2
80,060 80,060 3
151,308 151,308 4
569,827 569,827 5
425,250 425,250 6
5,524,607 5,524,607 7
4,923,775 -135 4,923,640 8
113,676 113,676 9
9,300 9,300 10
19,452 19,452 11
310,905 310,905 12
119,144 119,144 13
409,135 409,135 14
247,260 96,648 343,908 15
1,782,000 1,782,000 16
1,830,058 1,830,058 17
22,008,294 25,207,716 2,478,013 49,694,023
FERC FORM NO.1 (ED.12-90)Page 330.1
BLANK PAGE
(Next Page is:328.2)
Nameof Respondent I his Report is:Date of Report Year ot keport
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
I KANbMIOblUN U tLub I Klbl I Y I-UK U I MUNb (ACCOUDI 400)(Including transactions referred to as 'wheeling')
1.Repoit 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 PaymentBy Energy Received From Energy Delivered To Statistical
No (Company of PublicAuthority)(Company of Public Authority)(Company of Public Authority)Classifi-
(Footnote Affiliation)(Footnote Affiliation)(Footnote Affiliation)cation(a)(b)(c)(d)
1 Public Senrice Company of Colorado ÕS
2 Public Service Co.of New Mexico Idaho Power Company Ö$
3 Puget Sound Power &Light Co.Idaho Power Company Ó$
4 Reliant Energy Services,Inc.OS
5 Seawest Windpower,Inc.PacifiCorp Merchant LE
6 Sempra Energy Trading Corp.Los Angeles Dept.of Water &Powr Sierra Pacific Power ÓŠ
7 Sierra Pacific Power Company OS
8 Sierra Pacific Power Company SE
9 Snake River Valley Electric Assoc.Snake River Valley Electric Assc.Enron Power Marketing Inc.ÔŠ
10 Southem Energy Marketing Company ÒŠ
11 State of South Dakota State of South Dakota State of South Dakota LF
12 TransAlta Energy Marketing Corp.ÖS
13 Tri-State Gen.&Trans.Association Tri-State Gen.&Trans.Assn.Tri-State Gen.&Trans.Assn.LE
14 United States Bureau of Reclamation United States Bureau of Reclamat United States Bureau of Reclamat LF
15 Utah Associated Municipal Power Idaho Power Company Utah Associated Municipal Power LE
16 Utah Municipal Power Agency Utah Municipal Power Agency Utah Municipal Power Agency LF
17 Utah Municipal Power Agency ÒŠ
TOTAL
FERC FORMNO.1 (ED.12-90)Page 328.2
Name of Respondent I his Report is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
i NAivalviibbiuiu ut t-LED I Nit.,l ¡Y I-UN U I
Mt·Kb (Account 400XLontinuea)(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 reporting
years.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 contract
designations under which service,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 the
designation for the substation,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 the
contract.
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.
FERCRate Point of Receipt Point of Delivery Billing TRANSFEROF ENERGY LineScheduleof(Subsatation or Other (Substation or Other Demand tvlegavvalt mours Ivlegavvalt mours No.TariffNumber Designation)Designation)(MW)Received Delivered(e)(f)(g)(h)(i)(j)
OV-11 Various Various 2,036,729 2,036,72E 1
OV-11 Various Four Comers 700 70C 2
OV-11 Four Corners Various 1,325 1,325 3
OV-11 Yellowtail,Wyoming Four Corners 130 13C 4
OV-11 Various Various 25 5
OV-11 Various Various 234 234 6
OV-11 Various Various 163,932 163,932 7
OV-11 Various Various 459,600 459,60C 8
OV-11 Various Various 9
OV-11 Various Various 204,531 204,531 10
OV-11 Yellowtail,Wyoming Wyodak,Wyoming 4 11
OV-11 Various Various 4,125 4,125 12
123 Various Various 25 12,252 12,252 13
67 Redmond,Oregon Various 3 5,000 5,00C 14
297 Various Various 247 1,182,038 1,182,03E 15
279 Various Various 50 290,459 290,45E 16
OV-11 Various Mona,Utah 19,767 19,767 17
1,763 13,553,792 13,553,792
FERC FORMNO.1 (ED.12-90)Page 329.2
Name of Respondent I his Report is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
I KAINbMlbblUll UI-bLEU i Nibi I Y tuN U i Heko (Account 400)(Dontinueo)(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.
REVENUEFROMTRANŠMlŠŠlÓN ÖF ELEÓTRIÓlTYFOR OTHERŠ
bemand Charges 1-nergy Charges (Other Charges)I otal Revenues ($)Lme
($)($)($)(k+l+m)No.(k)(!)(m)(n)
6,152,945 6,152,945 1
1,460 1,460 2
5,247 5,247 3
759 759 4
766,836 766,836 5
702 702 6
682,645 58 682,703 7
1,265,625 1,265,625 8
-2,363 -2,363 9
631,197 631,197 10
56,700 56,700 11
22,177 22,177 12
44,027 12,252 2,793 59,072 13
8,456 1,000 581 10,037 14
3,836,677 259,080 4,095,757 15
956,275 107,340 1,063,615 16
74,530 74,530 17
22,008,294 25,207,716 2,478,013 49,694,023
FERC FORM NO.1 (ED.12-90)Page 330.2
BLANK PAGE
(Next Page is:328.3)
Name of Respondent I his Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
I KANoivilottuNUI-t Lt-o i NIUi i y t-UN U i MbNs (Account 400)(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(Company of Public Authority)(Company of Public Authority)(Company of Public Authority)Classifi-No.(Footnote Affiliation)(Footnote Affiliation)(Footnote Affiliation)cation
(a)(b)(c)(d)
1 Westem Area Power Administration Westem Area Power Administration Westem Area Power Administration LF
2 Western Area Power Administration Western Area Power Administration Westem Area Power Administration LF
3 Western Area Power Administration Westem Area Power Administration Westem Area Power Administration LF
4 Western Area Power Administration Westem Area Power Administration Westem Area Power Administration LÊ
5 Westem Area Power Administration Western Area Power Administration LF
6 Westem Area Power Administration ÕŠ
7 Western Area Power Administration Western Area Power Administration Weber Basin LF
8
9
10
11
12
13
14
15
16
17
TOTAL
FERC FORM NO.1 (ED.12-90)Page 328.3
Name of Respondent I his Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission I /
1 MANolVilboluis UI-t-LED I NIGI lY PUN Ut MtKo (Account 4co)(Lontinuea)(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 all
nonfirm 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.
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.
5.In column (e),identify the FERC Rate Schedule or Tariff Number,On separate lines,list all FERC rate schedules or contract
designations under which service,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 the
designation for the substation,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 the
contract.
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 Pointof Receipt Point of Delivery Billing TRANSFER OF ENERGY LineScheduleof(Subsatation or Other (Substation or Other Demand Iviegavvalt t1ours tviegavvalt riours No.TariffNumber Designation)Designation)(MW)Received Delivered(e)(f)(g)(h)(i)(j)
45 Various Various 33,992 33,992 1
262 Various Various 329 2,047,931 2,047,931 2
263 Various Various 10 3
OV-11 Yellowtail,Wyoming Dave Johnston,WY 50 4
OV-11 Various Various 5
OV-11 Dave Johnston,WY Yellowtail,Wyoming 100 10C 6
286 Various Various 23,365 23,360 7
8
9
10
11
12
13
14
15
16
17
1,763 13,553,792 13,553,792
FERC FORM NO.1 (ED.12-90)Page 329.3
Name of Respondent I his Report Is:IJate of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
1 NAINolvliablul l ul-t-Lt-U I KILI I Y I-UN U i tit-Ka (Account 400)(Dontinueo)(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 FRÓMTRANSMISŠlÓN ÓF ELECTRIÓlTYFÓR ÓTHERG
bemand Charges É.nergy Charges (Other Charges)I otal Revenues ($)Line
($)($)($)(k+l+m)No.(k)(I)(m)(n)
221,686 10,108 231,794 1
2,639,216 2,639,216 2
58,331 58,331 3
708,750 708,750 4
29,543 29,543 5
584 584 6
23,365 23,365 7
8
9
10
11
12
13
14
15
16
17
22,008,294 25,207,716 2,478,013 49,694,023
FERC FORM NO.1 (ED.12-90)Page 330.3
BLANK PAGE
(Next Page is:332)
Name of Respondent I his Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
I RANSDv ISSIONOF BLEG I RIGI lY BY U I HbHS (ACCOUnt b6b)(Including transactions referred to as "wheeling")
1.Report all transmission,i.e.,wheeling of electricity provided to respondent by other electric utilities,cooperatives,municipalities,orotherpublicauthoritiesduringtheyear.
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 thetransmissionserviceprovider.
3.Provide in column (a)subheadings and classify transmission service purchased form other utilities as:"Delivered Power toWheeler"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),providedemandcharges.In column (e),provide energy charges related to the amount of energy transferred.In column (f),provide the total ofallotherchargesonbillsorvouchersrenderedtotherespondent,including any out of period adjustments.Explain in a footnote allcomponentsoftheamountshownincolumn(f).Report in column (9)the total charge shown on bills rendered to the respondent.If nomonetarysettlementwasmade,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 bytherespondentforthewheeler's transmission tosses should be reported on the Electric Energy Account,Page 401.If the respondentreceivedpowerfromthewheeler,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 TRANSFEROF ENERGY EXPENSES FOR TRANSMISSION OF ELECTRICITY BY OTHERS
No.Authority (Footnote Attillations)Iviagawatt-Mayawall-Der Hand Enelyy Ollier lotal Cost ofhou.rs hours Charges Charges Charges Tran ssionReceivedDelivered($)($)($)(a)(b)(c)(d)(e)(f)
1 Arizona Pub Serv Co 400,667 400,667 2,072,000 1,013,425 370,178 3,455,603
2 Avista Corp 135,833 133,805 242,017 242,156 29,510 513,683
3 Big Hom Rurl Elec Coop 36,358 36,358
4 Blanding City 2,209 2,209 13,256 13,256
5 Bonneville Power Admin 6,752,356 6,705,512 42,090,803 1,462,081 288,430 43,841,314
6 Deseret Gen &Tran Coop 4,633 4,633 14,797 14,797
7 Flowell Electric Assoc.146 146 311 311
8 Hermiston Gen Co,L.P.137,052 137,052
9 Idaho Power Company 369,340 237,668 654,939 6,896,839 9,551,778
10 Los Angeles,City of 331,100 331,100 755,052 567,996 1,323,048
11 Mid Area Cont Pwr Pool 23,082 23,082
12 Montana Power Company 80,223 73,908 289,456 812,113 1,101,569
13 Moon Lake Electric Assn 72,517 72,517
14 Navajo Tribal Util Auth 1.659 1,659
15 Nevada Power Company 3,400 3,400 6,935 25,156 32,091
16 Portland General Elec 690,710 689,544 143.395 143,395
TOTAL 10,091,842 9,842,986 55,905,202 4,899,052 17,595,749 78,400,003
FERC FORM NO.1 (ED.12-90)Page 332
Nameot Respondent I his Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubrnission //
\RANbiv IssiuN ul-ELEU l RIGI lybyul HEks (Account bbb)(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 providerof 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 FORTRANSMISSION OF ELECTRICITY BY OTHERS
No.Authority (Footnote Affiliations)¯MâgaWatt-Mayawall-Deinalid Eliergy Olher Total Cost ofhourshoursChargesChargesChargesTransissionReceivedDelivered($)($)($)(a)(b)(c)(d)(e)(f)g
1 Public Serv Co of Col 201,856 195,736 743,485 743,485
2 Puget Sound Energy 403 403 403 36 439
3 Salt River Project 387 387
4 Sierra Pacific Power Co 5,505 5,505 26,348 905 27,253
5 Snohomish PUD 8,964 8,964 16,744 2,291 19,035
6 Southern Ca Edison Co 511,464 469,277 3,744,000 35,520 3,779,520
7 Springfield Util Board 332,986 332,986
8 Surprise Valley Elec 8,861 8,861
9 Tri-State Gen &Trans 262,286 249,762 743,485 28,731 1,060,989 1,833,205
10 Utah Associated Mun.Pw 930 930
11 Westem Area Pwr Admin 330,747 330,747 5,863,211 374,729 229.691 6,467,631
12 Accrual Adjustment 4.924.758 4,924,758
13 Total 10,091,842 9,842,986 55,905,202 4,899,052 17,595,749 78,400,003
14
15
16
TOTAL 10,091,842 9,842,986 55,905,202 4,899,052 17,595,749 78,400,003
FERC FORM NO.1 (ED.12-90)Page 332.1
Name of Respondent I his Report Is:Date of Report Year of Report
PacifiCorp (1)X An Original (Mo,Da,Yr)Dec.31 2000(2)A Resubmission //'
MISUELLABbUUS UbNERAL EXPt-NSES (Account 930.2)(bLtU\MlU)
Line Òescription Amount
No.(a)(b)
1 Industry Association Dues 439,696
2 Nuclear Power Research Expenses
3 Other Experimental and General Research Expenses
4 Pub &Dist Info to Stkhldrs...expn servicing outstanding Securities 709,012
5 Oth Expn >=5,000 show purpose,recipient,amount.Group if <$5,000
6
7 Directors Fees and Expenses 206,903
8
9 Corporate Memberships and Subscriptions:
10 Nature Conservancy 61,000
11 Harvard University 50,000
12 Research Services 37,500
13 PNUCC (Pacific Northwest Utilities Conference Comm)37,252
14 Oswego Lake Country Club 17,500
15 Utah Taxpayers Association 9,000
16 Wyoming Taxpayers Association 8,121
17 Salt Lake Area Chamber 15,127
18 Utah Partners in Education 7,000
19 Utah Manufacturers Association 5,964
20 Arlington Club 5,175
21 American Legislative Exchange 5,000
22 Oregon Business Council 7,516
23 Friends of Trees 5,000
24 Other 87,549
25
26 Economic and Community Development:
27 Center For Community Service 10,000
28 CCD Business Development Corp 5,000
29 City of Pendleton 5,000
30 Converse Area New Development 5,000
31 Corvallis Benton County 5,000
32 Eastern ID Econ Dev 5,000
33 Economic Development Corp of Utah 35,000
34 Laramie Economic Development 5,000
35 New Vision YCDA 5,000
36 Northwest Business Association 5,000
37 Portland Development Commission 7,500
38 South Coast Development Council 10,000
39 South Fremont Econ Dev 7,000
40 Southem Oregon Regional Econ Dev 5,000
41 Taylorsville Economic Development 5,000
42 Team Walla Walla 5,000
43 Sunnyside Inc 5,000
44 Cottage Grove Area Chamber 5,000
45 Redmond Economic Development 5,000
46 TOTAL -40,519,532
FERCFORM NO.1 (ED.12-94)Page 335
Name of Respondent i his Report Is:Date of Report Year of Report
PacifiCorp (1)OX An Original (Mo,Da,Yr)Dec.31 2000(2)O A Resubmission //'
IvilouELLAl EUU UENEkAL EAPEN Eb (Account 93U.2)(ELEUI Mlb)
Line Description AmountNo.(a)(b)
6 Portland Property Access Project 5,000
7 Ad-Portland Book -5,994
8 Other 43,600
9
10 US Bank 303,937
11 Wachovia Bank 29,972
12 Bank of New York 71,357
13 Hunton and Williams 30,000
14 E×penses moved to capital -3,221,056
15 UT Writeback and Amort -Defrrd Pen Regulatory Asset -22,113,098
16 Early Retirment-UT Writeback and related Amort -7,366,040
17 Glenrock Mn Recimtion -UT Writeback and related Amt -4,601,574
18 Comp Mainfrm Writedown -UT Writeback and related Am -1,686,548
19 Y2K Expense-UT Writeback and related Amort -1,040,050
20 Lloyd Center Tower operations 528,644
21 PacifiCorp Trans,Inc.-Indirect airplane costs 2,069,511
22 CWIP reserve -3,400,000
23 Oregon Asset Write-back -1,119,412
24 Intercompany Transfers In/(Out)-870,329
25
26
27 Other -43,255
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46 TOTAL -40,519,532
FERC FORM NO.1 (ED.12-94)Page 335.1
Name of Respondent I his Report is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
l.>t-PRt-CIAI lUN AND AMORI IZA I ION Ul-t-Ll-C I RIC PLAN I (ACCount 4U3,404,4Ub)
(Except 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.Identifyat 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
une Deureulatlun Aniollizalluri uf Arnorllradun of
N 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 36,592,010 1,758,797 38,350,807
2 Steam Production Plant 109,850,826 109,850,826
3 Nuclear Production Plant
4 Hydraulic Production Plant-Conventional 10,710,039 13,760 10,723,799
5 Hydraulic Production Plant-PumpedStorage
6 Other Production Plant 3,335,468 3,335,468
7 Transmission Plant 45,091,215 45,091,215
8 Distribution Plant 129,833,097 129,833,097
9 General Plant 39,933,954 2,022,015 41,955,969
10 Common Plant-Electric
11 TOTAL 338,754,599 38,627,785 1,758,797 379,141,181
B.Basis for Amortization Charges
The amortization of Limited-TermElectric Plant is based on straight-line amortization over the life of the asset.
The amortization of Other Electric Plant consists of costs associated with the merger of PacifiCorpand Utah Power &Light Company.Amortization is
straight-line over a 15 year period.
FERC FORMNO.1 (ED.12-88)Page 336
Name of Respondent I his Report Is:Date of Report Year of Report |
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
DEPRECIATIONAND AMORTlZATION OF ELECTRIC PLANT (Continued)
C.Factors Used in Estimating Depreciation Charges
Line Deµreciable Eslinialed Nel Aµµlied Mariality Average
No Account No.PlantBase Avg.Service Salvage Depr.rates Curve Remaining(In Thousands)Life (Percent)(Percent)Tvoe Life(a)(b)(c)(d)(e)(f)(g)
12 STEAM
13
14 Hunter Plant
15 310.20 UT 246 43.49 2.24
16 310.30 UT 24,123 41.21 2.37
17 311.00 UT 197,340 43.05 -5.00 2.47
18 312.00 UT 486,156 41.52 -5.30 2.59
19 314.00 UT 136,970 40.71 -5.70 2.66
20 315.00 UT 93,685 43.31 -4.50 2.43
21 316.00 UT 6,707 39.39 -4.20 2.78
22
23 Jim Bridger Plant
24 310.20 WY 281 43.71 2.36
25 310.30 WY 171 44.78 2.31
26 311.00 WY 132,181 41.03 -6.60 2.81
27 312.00 WY 484,239 37.29 -6.90 3.07
28 314.00 WY 123,333 36.05 -7.10 3.18
29 315.00 WY 51,265 42.95 -6.20 2.69
30 315.70 WY 50 31.70 -6.20 3.44
31 316.00 WY 3,714 34.26 -6.00 3.37
32
33 Huntington Plant
34 310.30 UT 1,472 44.98 2.34
35 311.00 UT 93,701 41.68 -8.10 2.90
36 312.00 UT 202,144 38.70 -8.40 3.10
37 314.00 UT 76,084 34.89 -8.70 3.38
38 315.00 UT 27,250 41.50 -7.80 2.88
39 316.00 UT 4,851 33.06 -7.60 3.59
40
41 Cholla Plant
42 311.00 AZ 41,298 43.40 -4.30 2.19
43 312.00 AZ 212,960 42.41 -4.70 2.27
44 314.00 AZ 49,771 41.10 -5.00 2.38
45 315.00 AZ 45,528 43.53 -3.90 2.16
46 315.70 AZ 70 31.55 -3.90 3.19
47 316.00 AZ 2,891 38.32 -3.60 2.58
48
49 Dave Johnston Plant
50 310.20 WY 100 46.83 1.98
FERC FORM NO.1 (ED.12-95)Page 337
Name ot Respondent I his Report Is:Date ot Repori Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
DEPRECIATION AND AMORTIZATION OF ELECTRICPLANT (Continued)
C.Factors Used in Estimating Depreciation Ch irges
Line Deµieciable Esliniated Nel Aµµiied Mullalily Avelaye
No Account No.Plant Base Avg.Service Salvage Depr.rates Curve Remaining(In Thousands)Life (Percent)(Percent)Type Life(a)(b)(c)(d)(e)(f)(g)
12 310.30 WY 9,701 27.77 3.48
13 311.00 WY 45,774 39.52 -9.00 2.79
14 312.00 WY 240,515 39.91 -9.30 2.80
15 314.00 WY 59,012 40.91 -9.60 2.77
16 315.00 WY 15,489 43.81 -8.70 2.53
17 315.70 WY 174 31.70 -8.70 3.40
18 316.00 WY 1,592 32.01 -8.40 3.49
19
20 Wyodak Plant
21 310.20 WY 165 40.19 2.70
22 310.30 WY 13 44.00 2.53
23 311.00 WY 47,801 41.98 -3.60 2.79
24 312.00 WY 192,204 38.38 -3.90 3.02
25 314.00 WY 40,930 41.52 -4.20 2.89
26 315.00 WY 19,185 43.26 -3.20 2.71
27 316.00 WY 920 40.16 -3.00 3.04
28
29 Naughton Plant
30 310.20 WY 15 49.00 3.23
31 310.30 WY 1 49.00 3.22
32 311.00 WY 55,719 29.44 -8.50 4.71
33 312.00 WY 195,995 29.85 -8.60 4.72
34 314.00 WY 36,391 34.42 -8.80 4.47
35 315.00 WY 15,553 36.39 -8.20 4.26
36 316.00 WY 2,114 32.05 -8.10 4.72
37
38 Colstrip Plant
39 311.00 MT 55,588 43.54 -3.20 2.23
40 312.00 MT 106,994 42.45 -3.60 2.32
41 314.00 MT 28,825 40.02 -4.00 2.50
42 315.00 MT 8,902 43.59 -2.70 2.21
43 316.00 MT 2,231 37.01 -2.30 2.71
44
45 Craig Plant
46 311.00 CO 35,116 43.53 -4.40 2.47
47 312.00 CO 78,834 42.75 -4.70 2.55
48 314.00 CO 18,401 42.05 -5.10 2.62
49 315.00 CO 16,375 43.38 -4.00 2.46
50 316.00 CO 1,634 40.66 -3.70 2.74
FERC FORM NO.1 (ED.12-95)Page 337.1
\Name of Respondent I his Report is:Date ot Report Year ot Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
DEPRECIATIONAND AMORTIZATION OF ELECTRIC PLANT (Continued}
C.Factors Used in EstimatingDepreciation Charges
Lrne Deµaeuiable Esliriialed Nel Aµµ\ied Mullality Average
No Account No.PlantBase Avg.Service Salvage Depr.rates Curve Remaining(In Thousands)Life (Percent)(Percent)T e Life(a)(b)(c)(d)(e)(g)
12
13 Gadsby Plant
14 310.30 UT 8 57.58 2.14
15 311.00 UT 13,404 31.06 -11.50 4.31
16 312.00 UT 35,376 29.79 -11.60 4.44
17 314.00 UT 12,148 44.02 -11.70 3.76
18 315.00 UT 5,474 34.74 -11.30 4.06
19 316.00 UT 623 22.74 -11.30 5.28
20
21 Carbon Plant
22 310.30 UT 865 34.34 2.42
23 311.00 UT 10,372 36.15 -9.40 3.07
24 312.00 UT 44,558 32.77 -9.60 3.35
25 314.00 UT 15,832 38.12 -9.70 3.01
26 315.00 UT 3,756 39.90 -9.20 2.84
27 316.00 UT 669 25.68 -9.10 4.16
28
29 Blundell Plant
30 310.20 UT 30,813
31 311.00 UT 6,147 36.05 -2.60 3.03
32 312.00 UT 11,961 34.90 -2.90 3.15
33 314.00 UT 14,696 35.64 -3.20 3.12
34 315.00 UT 4,666 36.64 -2.20 2.96
35 316.00 UT 1,372 34.15 -2.00 3.29
36
37 James River Plant
38 311.00 WA 5,734 19.75 -2.50 5.33
39 312.00 WA 5,798 40.58 2.46
40 314.00 WA 18,601 19.34 -2.90 5.48
41 315.00 WA 4,283 19.80 -2.20 5.30
42
43 Hayden Plant
44 311.00 CO 5,033 49.28 -8.50 1.70
45 312.00 CO 48,576 46.28 -8.90 1.89
46 314.00 CO 6,384 48.69 -9.20 1.77
47 315.00 CO 2,481 47.35 -8.10 1.79
48 316.00 CO 1,107 42.90 -7.80 2.10
49
50
FERC FORM NO.1 (ED.12-95)Page 337.2
Name of Respondent I his Report is:Date of Report Year ot Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
DEPRECIATION AND AMORTIZATIONOF ELECTRICPLANT (Continued)
C.Factors Used in Estimating Depreciation Charges
Line Depieciable Eslilliated Nel Aµµlied Mutialily Aveldge
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)(g)
12 HYDRO
13
14 Swift 218
15 330.20 WA 6,277 77.19 1.44
16 330.50 WA 97 76.00 1.46
17 331.00 WA 2,958 71.22 -3.50 1.67
18 331.20 WA 1,645 53.73 -3.50 2.07
19 331.30 WA 779 48.17 -3.50 2.26
20 332.00 WA 37,927 76.12 -3.20 1.57
21 332.30 WA 110 43.93 -3.20 2.42
22 333.00 WA 9,807 66.06 -8.60 1.92
23 334.00 WA 1,117 62.80 -2.70 1.85
24 334.70 WA 331 39.91 -10.30 3.28
25 335.00 WA 570 67.43 -1.00 1.75
26 335.30 WA 9 43.20 -3.30 3.20
27 336.00 WA 395 48.07 -1.10 2.18
28
29 Yale 219
30 330.20 WA 760 40.00 2.51
31 331.00 WA 3,437 68.62 -3.50 1.71
32 331.20 WA 14 45.56 -3.50 2.36
33 331.30 WA 2,000 48.27 -3.50 2.25
34 332.00 WA 26,004 81.48 -3.20 1.19
35 332.20 WA 24 40.91 -3.20 2.56
36 333.00 WA 10,361 55.92 -8.60 2.15
37 334.00 WA 2,665 48.50 -2.70 2.25
38 334.70 WA 111 37.29 -10.30 3.40
39 335.00 WA 505 75.79 -1.00 1.59
40 336.00 WA 1,123 82.39 -1.10 1.40
41
42 Merwin 215
43 330.20 WA 301 102.76 0.92
44 330.50 WA 212 103.98 0.90
45 331.00 WA 5,593 58.40 -3.50 1.80
46 331.20 WA 13,398 42.58 -3.50 2.44
47 331.30 WA 1,588 43.35 -3.50 2.40
48 332.00 WA 8,270 86.38 -3.20 1.21
49 332.20 WA 705 44.46 -3.20 2.33
50 332.30 WA 30 43.16 -3.20 2.40
FERC FORM NO.1 (ED.12-95)Page 337.3
Name of Respondent I his Report Is:lJate of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
DEPRECIATION AND AMORTIZATIONOF ELECTRICPLANT (Continued)
C.Factors Used in Estimating Depreciation Ch trges
Line Depieciable Estimaled New Aµµlied Mutkalily Avelaye
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)(g)
12 333.00 WA 6,192 71.70 -8.60 1.62
13 334.00 WA 3,315 49.29 -2.70 2.12
14 334.70 WA 251 32.43 -10.30 3.62
15 335.00 WA 668 37.78 -1.00 2.69
16 335.20 WA 50 88.20 -3.30 1.68
17 336.00 WA 384 48.58 -1.10 2.07
18
19 Cresap Bay Park 2151
20 331.30 WA 5,006 43.35 -3.50 2.52
21 332.30 WA 68 43.16 -3.20 2.50
22 336.00 WA 1,346 48.58 -1.10 2.25
23
24 Merwin 2153
25 332.20 WA 58 44.46 -3.20 2.33
26 334.00 WA 2 49.29 -2.70 2.88
27
28 JC Boyle 18
29 331.00 OR 2,175 58.20 -3.50 1.97
30 331.30 OR 56 45.67 -3.50 2.37
31 332.00 OR 9,418 69.84 -3.20 1.71
32 332.20 OR 867 48.64 -3.20 2.24
33 333.00 OR 3,978 62.57 -8.60 2.02
34 334.00 OR 2,497 48.11 -2.70 2.29
35 334.70 OR 120 62.29 -10.30 3.72
36 335.00 OR 139 73.88 -1.00 1.67
37 336.00 OR 605 62.97 -1.10 1.77
38
39 Lemolo #2 41
40 331.00 OR 683 68.06 -2.90 2.10
41 331.20 OR 3 51.01 -2.90 2.44
42 331.30 OR 2 57.75 -2.90 2.28
43 332.00 OR 14,226 61.51 -2.60 2.18
44 332.20 OR 121 72.93 -2.60 2.01
45 333.00 OR 1,634 66.60 -7.20 2.27
46 334.00 OR 247 57.54 -2.30 2.32
47 334.70 OR 43 33.36 -9.10 3.91
48 335.00 OR 8 59.06 -0.80 2.29
49 336.00 OR 993 65.68 -0.90 2.04
50
FERC FORM NO.1 (ED.12-95)Page 337.4
Name of Respondent I his Report is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
DEPRECIATIONAND AMORTIZATIONOF ELECTRIC PLANT (Continued)
C.Factors Used in Estimi ting Depreciation Charges
Line Depleciable Emitrialed Net Aµµ\ied Mullelily Aveisye
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)(g)
12 Iron Gate 610
13 330.20 CA 5 74.00 1.60
14 331.00 CA 1,400 66.34 -3.50 1.86
15 331.20 CA 1,824 53.83 -3.50 2.14
16 331.30 CA 380 54.99 -3.50 2.11
17 332.00 CA 7,573 68.85 -3.20 1.80
18 332.20 CA 789 69.55 -3.20 1.79
19 333.00 CA 1,104 72.20 -8.60 1.92
20 334.00 CA 183 68.88 -2.70 1.84
21 334.70 CA 53 32.85 -10.30 3.71
22 335.00 CA 15 69.63 -1.00 1.83
23 335.20 CA 5 35.20 -3.30 3.69
24 336.00 CA 639 69.40 -1.10 1.72
25
26 Powerdale 27
27 330.20 OR 53.97 2.97
28 331.00 OR 646 42.59 -1.80 3.42
29 331.30 OR 55 32.42 -1.80 3.88
30 332.00 OR 10,255 37.21 -1.60 3.61
31 332.20 OR 681 23.12 -1.60 4.64
32 332.30 OR 21.69 -1.60 4.82
33 333.00 OR 1,516 28.16 -4.40 4.32
34 334.00 OR 293 35.68 -1.40 3.74
35 334.70 OR 4 30.33 -6.10 4.81
36 335.00 OR 19.80 -0.50 5.13
37 336.00 OR 44 31.01 -0.60 3.88
38
39 Grace 457
40 331.00 ID 1,114 77.91 -2.40 1.94
41 332.00 \D 7,536 66.51 -2.20 2.09
42 333.00 ID 2,211 53.39 -6.10 2.55
43 334.00 ID 858 54.86 -1.90 2.39
44 334.70 ID 4 26.64 -7.90 4.49
45 335.00 ID 93 39.07 -0.70 2.95
46 336.00 ID 43 55.29 -0.80 2.26
47
48 Clearwater #2 43
49 331.00 OR 745 69.53 -2.90 2.05
50 331.30 OR 7 57.87 -2.90 2.25
FERC FORM NO.1 (ED.12-95)Page 337.5
Name of Respondent I his Report is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
DEPRECIATIONAND AMORTIZATION OF ELECTRIC PLANT (Continued)
C.Factors Used in Estimating Depreciation Ch.arges
Line Deµreciable Esliniated Nel Aµµlied Mullality 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)(g)
12 332.00 OR 8,923 57.32 -2.60 2.24
13 332.20 OR 5 54.07 -2.60 2.32
14 333.00 OR 918 74.59 -7.20 2.13
15 334.00 OR 197 64.20 -2.30 2.17
16 334.70 OR 25 33.35 -9.10 3.90
17 335.00 OR 5 52.67 -0.80 2.41
18 336.00 OR 220 58.64 -0.90 2.15
19
20 Lemolo #1 40
21 331.00 OR 708 69.07 -2.90 1.84
22 332.00 OR 7,806 71.29 -2.60 1.79
23 332.20 OR 2 74.22 -2.60 1.74
24 333.00 OR 1,543 68.84 -7.20 2.00
25 334.00 OR 1,485 46.75 -2.30 2.44
26 334.70 OR 6 39.35 -9.10 3.44
27 335.00 OR 13 64.31 -0.80 1.95
28 336.00 OR 407 71.15 -0.90 1.72
29
30 Cutler 444
31 330.20 UT 31.00 3.46
32 330.30 UT 5 31.00 3.46
33 330.40 UT 90 31.00 3.46
34 331.00 UT 1,643 60.68 -2.30 2.72
35 332.00 UT 6,715 51.30 -2.10 2.86
36 332.00 UT 276 51.30 -2.10 2.86
37 333.00 UT 1,110 77.11 -5.80 2.67
38 334.00 UT 464 59.47 -1.80 2.78
39 335.00 UT 69 36.51 -0.70 3.39
40 336.00 UT 524 41.44 -0.80 3.06
41
42 Toketee 44
43 331.00 OR 1,425 52.44 -2.90 2.10
44 331.30 OR 5 57.89 -2.90 1.93
45 332.00 OR 6,272 72.82 -2.60 1.58
46 333.00 OR 2,021 61.83 -7.20 1.97
47 334.00 OR 407 59.65 -2.30 1.90
48 334.70 OR 26 35.12 -9.10 3.56
49 335.00 OR 50 59.99 -0.80 1.87
50 336.00 OR 111 53.73 -0.90 1.97
FERCFORM NO.1 (ED.12-95)Page 337.6
Name of Respondent I his keport Is:Date of Report Year of Repod
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
DEPRECIATION AND AMORTIZATION OF ELECTRICPLANT (Continued)
C.Factors Used in Estimeting Depreciation Ch arges
Line Deµieciable Esliinated Nel AµµIied Morlality Avelaye
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)(g)
12
13 Naches 216
14 330.20 WA 22 39.27 7.74
15 331.00 WA 509 31.57 -0.60 8.14
16 332.00 WA 5,295 28.95 -0.50 8.24
17 332.20 WA 2,415 12.95 -0.50 10.10
18 333.00 WA 1,311 38.68 -1.50 8.00
19 334.00 WA 105 29.46 -0.50 8.29
20 334.70 WA 13 16.30 -2.30 10.23
21 336.00 WA 1 67.82 -0.20 7.32
22
23 Prospect #2 32
24 330.20 OR 4 62.04 1.94
25 330.40 OR 3 46.00 2.39
26 331.00 OR 1,977 49.82 -2.70 2.39
27 331.20 OR 4 31.09 -2.70 3.34
28 331.30 OR 3 49.06 -2.70 2.41
29 332.00 OR 4,651 68.65 -2.50 1.93
30 332.20 OR 136 44.60 -2.50 2.55
31 333.00 OR 1,313 57.36 -6.80 2.33
32 334.00 OR 1,124 35.20 -2.10 3.06
33 334.70 OR 80 30.31 -8.60 4.07
34 336.00 OR 171 53.26 -0.90 2.20
35
36 Prospect #3 (Non)331
37 331.20 OR 11 31.55 -1.90 3.92
38
39 Pioneer 449
40 330.20 UT 9 132.92 1.23
41 330.30 UT 111 133.00 1.23
42 331.00 UT 329 61.16 -2.90 2.07
43 332.00 UT 7,764 43.81 -2.60 2.56
44 333.00 UT 783 51.97 -7.20 2.44
45 334.00 UT 382 47.15 -2.30 2.47
46 335.00 UT 10 41.80 -0.80 2.68
47 336.00 UT 12 51.58 -0.90 2.22
48
49 Lifton 458
50 330.20 ID 20 115.70 0.97
FERC FORM NO.1 (ED.12-95)Page 337.7
Name of Respondent I his Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
DEPRECIATION AND AMORTIZATIONOF ELECTRIC PLANT (Continued)
C.Factors Used in Estimating Depreciation Ch trges
Line Deµreciable Esiiiriated Nei Aµµiied Mullelily Aveiage
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)(g)
12 330.30 ID 24 109.25 1.01
13 331.00 ID 1,129 91.06 -4.60 1.31
14 331.30 ID 4 49.54 -4.60 2.12
15 332.00 ID 7,047 72.47 -4.20 1.54
16 333.00 ID 391 100.20 -11.30 1.37
17 334.00 ID 257 63.67 -3.50 1.74
18 335.00 ID 56 52.79 -1.30 2.00
19 336.00 ID 19 113.84 -1.50 1.02
20
21 Oneida 459
22 331.00 ID 1,166 69.60 -3.00 2.02
23 331.30 ID 32 34.41 -3.00 3.05
24 332.00 ID 4,426 64.58 -2.70 2.07
25 333.00 ID 2,141 58.15 -7.50 2.37
26 334.00 lD 696 55.36 -2.30 2.31
27 335.00 ID 6 46.35 -0.90 2.56
28 336.00 ID 370 58.56 -1.00 2.12
29
30 Oneida (Non)559
31 331.00 ID 4 106.04 -3.00 1.06
32 334.00 ID 151 54.86 -2.30 0.75
33
34 Ashton 455
35 331.00 ID 753 48.08 -2.70 2.79
36 331.20 ID 354 32.09 -2.70 3.33
37 332.00 ID 4,490 40.20 -2.50 2.98
38 333.00 ID 1,952 40.09 -6.80 3.16
39 334.00 ID 1,066 38.89 -2.10 3.09
40 334.70 ID 42 29.31 -8.60 4.35
41 335.00 ID 8 46.83 -0.80 2.88
42 336.00 ID 1 101.63 -0.90 2.11
43
44 Copco #1 611
45 330.20 CA 36 113.00 1.04
46 330.40 CA 1 55.00 1.89
47 331.00 CA 1,083 58.13 -3.50 1.93
48 331.30 CA 82 55.70 -3.50 1.99
49 332.00 CA 2,430 92.85 -3.20 1.33
50 333.00 CA 3,758 44.95 -8.60 2.52
FERC FORM NO.1 (ED.12-95)Page 337.8
Name of Respondent I his Report Is:lJafe of Repori Year of keport
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
DEPRECIATION AND AMORTIZATIONOF ELECTRICPLANT (Continued)
C.Factors Used in Estimating Depreciation Charges
Line DeµIeuiable Estiinated Nel Aµµ\ied Mullalily Aveiage
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)(g)
12 334.00 CA 939 54.12 -2.70 2.06
13 334.70 CA 59 35.40 -10.30 3.50
14 335.00 CA 1 64.68 -1.00 1.78
15 336.00 CA 105 44.37 -1.10 2.32
16
17 North Umpqua 48
18 331.00 OR 4,633 40.59 -2.90 2.84
19 331.30 OR 27 54.10 -2.90 2.47
20 332.00 OR 92 36.41 -2.60 2.99
21 333.00 OR 31 31.72 -7.20 3.40
22 334.00 OR 142 46.72 -2.30 2.69
23 334.70 OR 424 26.36 -9.10 4.39
24 335.00 OR 84 47.22 -0.80 2.68
25 336.00 OR 2,066 62.21 -0.90 2.23
26
27 Soda 461
28 330.20 ID 6 112.35 1.56
29 331.00 ID 572 77.97 -3.00 1.97
30 332.00 ID 4,987 63.98 -2.70 2.14
31 333.00 ID 1,597 57.51 -7.50 2.43
32 334.00 ID 459 62.88 -2.30 2.21
33 335.00 ID 16 45.63 -0.90 2.62
34
35 Soda (Non)561
36 332.00 ID 9 84.65 -2.70 0.62
37
38 Keno
39 330.20 OR 14 87.23 1.64
40 331.20 OR 10 45.56 -3.50 2.47
41 331.30 OR 213 55.15 -3.50 2.22
42 332.00 OR 6,767 65.73 -3.20 2.01
43 332.20 OR 236 68.91 -3.20 1.96
44 334.70 OR 13 32.29 -10.30 3.81
45 336.00 OR 106 69.37 -1.10 1.88
46
47 Fish Creek 45
48 331.00 OR 559 66.38 -2.90 2.15
49 332.00 OR 5,684 56.25 -2.60 2.31
50 332.20 OR 76 35.78 -2.60 3.00
FERC FORM NO.1 (ED.12-95)Page 337.9
Name of Respondent I his Report is:Date ot keport Ÿear of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
DEPRECIATIONAND AMORTIZATIONOF ELECTRIC PLANT (Continued)
C.Factors LJsed in Estimating Depreciation Charges
Line Deµleciable Esliilialed Nel AµµIied Mullality 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)(1)(g)
12 333.00 OR 542 70.26 -7.20 2.24
13 334.00 OR 109 61.91 -2.30 2.26
14 335.00 OR 7 62.46 -0.80 2.25
15 336.00 OR 409 58.74 -0.90 2.19
16
17 Copco #2 612
18 331.00 CA 1,546 47.29 -2.40 2.23
19 332.00 CA 2,747 91.66 -2.20 1.19
20 333.00 CA 3,457 60.82 -6.10 1.91
21 334.00 CA 500 48.28 -1.90 2.20
22 334.70 CA 277 30.12 -7.90 3.94
23 335.00 CA 33 35.48 -0.70 2.91
24 336.00 CA 240 40.43 -0.80 2.51
25
26 Prospect #3 33
27 331.00 OR 279 42.25 -1.90 3.46
28 331.30 OR 2 42.02 -1.90 3.47
29 332.00 OR 1,955 48.27 -1.70 3.26
30 332.20 OR 2,022 23.03 -1.70 4.58
31 333.00 OR 1,921 29.21 -4.60 4.22
32 334.00 OR 442 27.79 -1.50 4.21
33 335.00 OR 73 26.42 -0.50 4.33
34 336.00 OR 51 61.63 -0.60 2.93
35
36 Condit 213
37 330.40 WA 3 25.50 3.40
38 331.00 WA 799 39.20 -260.10 31.41
39 331.30 WA 158 19.94 -260.10 33.45
40 332.00 WA 4,073 41.28 -260.00 31.23
41 332.30 WA 209 9.59 -260.00 39.26
42 333.00 WA 1,149 39.17 -261.00 31.58
43 334.00 WA 94 44.10 -260.00 31.42
44 334.70 WA 54 19.36 -260.00 33.89
45 335.00 WA 29 14.20 -259.70 35.93
46 336.00 WA 60 54.06 -259.70 30.68
47
48 Condit-Non 213
49 330.20 WA 26.43 4.95
50
FERC FORMNO.1 (ED.12-95)Page 337.10
Name of Respondent I his Report is:lJate ot Report Year of keport
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
DEPRECIATION AND AMORTIZATION OF ELECTRIC PLANT (Continued)
C.Factors Used in Estimtting Depreciation Charges
Line Deµieciable Estillialed Nel Aµµlied Morldlily 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)(g)
12 Soda Springs 46
13 331.00 OR 812 70.28 -2.90 1.75
14 332.00 OR 3,467 71.07 -2.60 1.72
15 333.00 OR 614 76.63 -7.20 1.79
16 334.00 OR 400 42.81 -2.30 2.56
17 334.70 OR 30 35.94 -9.10 3.57
18 335.00 OR 2 37.33 -0.80 2.84
19 336.00 OR 26 34.58 -0.90 2.95
20
21 Slide Creek 47
22 331.00 OR 607 62.40 -2.90 2.07
23 332.00 OR 3,753 68.63 -2.60 1.93
24 333.00 OR 663 77.39 -7.20 1.97
25 334.00 OR 413 61.83 -2.30 2.11
26 334.70 OR 59 27.36 -9.10 4.26
27 335.00 OR 5 40.50 -0.80 2.75
28 336.00 OR 17 46.61 -0.90 2.40
29
30 Clearwater #1 42
31 331.00 OR 559 69.71 -2.60 1.66
32 332.00 OR 3,227 75.63 -2.60 1.55
33 332.20 OR 5 76.22 -2.60 1.54
34 333.00 OR 709 73.99 -7.20 1.74
35 334.00 OR 149 71.31 -2.30 1.66
36 334.70 OR 47 29.36 -9.10 4.01
37 335.00 OR 7 56.33 -0.80 1.99
38
39 Klamath 19
40 330.20 OR 624 40.00 2.57
41 330.40 OR 235 55.00 2.34
42 331.00 OR 8 42.84 -3.50 2.68
43 331.30 OR 11 61.51 -3.50 2.45
44 332.00 OR 2,781 74.21 -3.20 2.33
45 334.00 OR 2 66.07 -2.70 2.47
46 335.00 OR 36 70.18 -1.00 2.48
47
48 Big Fork 410
49 331.00 MT 305 24.39 -0.10 18.88
50 331.30 MT 13 35.80 -0.10 18.36
FERC FORM NO.1 (ED.12-95)Page 337.11
Nameof Respondent I his Report is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
DEPRECIATION AND AMORTIZATIONOF ELECTRICPLANT (Continued)
C.Factors Used in Estimating Depreciation Charges
Line Deµreciable Esliiriated Nel Aµµlied Mullalily Avelaye
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)(g)
12 332.00 MT 2,003 21.86 -0.10 19.02
13 332.20 MT 88 8.00 -0.10 22.18
14 332.30 MT 2 9.00 -0.10 21.63
15 333.00 MT 578 20.07 -0.30 19.29
16 334.00 MT 197 23.56 -0.10 18.94
17 336.00 MT 4 12.41 20.38
18
19 Prospect #1 31
20 331.00 OR 213 38.39 -2.70 1.37
21 331.30 OR 1 56.09 -2.70 1.73
22 332.00 OR 129 106.15 -2.50 0.78
23 333.00 OR 140 68.86 -6.80 1.51
24 334.00 OR 48 65.77 -2.10 1.44
25 336.00 OR 4 62.63 -0.90 1.45
26
27 Prospect #4 34
28 331.00 OR 51 47.43 -2.70 2.25
29 331.30 OR 9 33.09 -2.70 3.13
30 332.00 OR 49 57.14 -2.50 1.89
31 333.00 OR 53 81.87 -6.80 1.53
32 334.00 OR 22 70.71 -2.10 1.58
33
34 Eastside 16
35 331.00 OR 99 58.08 -0.60 2.19
36 332.00 OR 1,389 48.19 -0.50 2.51
37 333.00 OR 103 81.82 -1.50 1.81
38 334.00 OR 99 31.47 -0.50 3.60
39 334.70 OR 18 13.37 -2.30 8.20
40 335.00 OR 11 81.76 -0.20 1.68
41 336.00 OR 67 20.50 -0.20 5.17
42
43 Westside 17
44 331.00 OR 91 36.38 -0.60 1.67
45 331.30 OR 8 27.44 -0.60 2.68
46 332.00 OR 129 86.90 -0.50 -0.16
47 333.00 OR 26 77.04 -1.50 0.13
48 334.00 OR 29 42.55 -0.50 1.21
49 336.00 OR 62.97 -0.20 0.31
50
FERC FORM NO.1 (ED.12-95)Page 337.12
Name of Respondent I his Report Is:Date of keport Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
DEPRECIATIONAND AMORTIZATIONOF ELECTRICPLANT (Continued)
C.Factors Used in Estimating Depreciation Charges
Line Deµieciabie Eslilliated Nel Apµlied Muildlity Avelaye
No Account No.PlantBase Avg.Service Salvage Depr.rates Curve Remaining(In Thousands)Life (Percent)(Percent)T e Life(a)(b)(c)(d)(e)(g)12 Fall Creek 613
13 330.40 CA 17 25.00 5.13
14 331.00 CA 119 33.35 -0.60 4.38
15 331.30 CA 3 34.93 -0.60 4.26
16 332.00 CA 469 27.65 -0.50 4.89
17 333.00 CA 117 46.49 -1.50 3.76
18 334.00 CA 32 49.62 -0.50 3.54
19
20 Fall Creek 13
21 330.20 OR 1 103.00 7.33
22 330.40 OR 24.00 8.64
23 332.00 OR 149 19.40 -0.50 9.15
24
25 Naches Drop 214
26 330.20 WA 1 41.00 5.91
27 331.00 WA 44 61.62 -0.60 5.52
28 332.00 WA 142 45.16 -0.50 5.87
29 333.00 WA 169 42.70 -1.50 6.09
30 334.00 WA 22 26.64 -0.50 6.89
31
32 Cove 456
33 331.00 ID 187 77.21 -1.50 2.36
34 332.00 ID 1,178 79.40 -1.30 2.31
35 333.00 ID 360 52.73 -3.70 2.97
36 334.00 ID 319 31.67 -1.20 3.85
37 335.00 ID 3 28.73 -0.40 4.10
38 336.00 lD 9 97.88 -0.50 2.06
39
40 Paris 460
41 331.00 ID 38 42.89 -1.50 2.94
42 332.00 ID 96 64.75 -1.30 2.24
43 333.00 ID 69 43.13 -3.70 3.06
44 334.00 ID 97 34.51 -1.20 3.44
45 335.00 lD 7 27.96 -0.40 4.01
46
47 Wallowa Falls 29
48 331.00 OR 44 36.30 -1.60 3.62
49 331.30 OR 64 23.25 -1.60 4.73
50 332.00 OR 2,026 22.86 -1.40 4.77
FERC FORM NO.1 (ED.12-95)Page 337.13
Name of Respondent I his Report is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
DEPRECIATIONAND AMORTIZATIONOF ELECTRIC PLANT (Continued)
C.Factors Used in Estimating Depreciation Charges
Line DeµIeuiable Eslimated Net Aµµlied Muttailty Average
No Account No.PlantBase Avg.Service Salvage Depr.rates Curve Remaining(In Thousands)Life (Percent)(Percent)T e Life(a)(b)(c)(d)(e)(g)
12 333.00 OR 56 54.63 -3.90 3.09
13 334.00 OR 196 24.15 -1.20 4.64
14 334.70 OR 55.27 -5.50 3.63
15 336.00 OR 323 22.87 -0.50 4.70
16
17 Ferguson Ridge 292
18 334.70 WA 4 24.96 -5.50 3.59
19
20 St.Anthony 462
21 331.00 ID 86 39.72 -1.60 4.29
22 332.00 ¡D 571 29.06 -1.40 4.67
23 333.00 ID 426 25.83 -3.90 5.03
24 334.00 ID 161 30.20 -1.20 4.68
25 335.00 ID 41.05 -0.50 4.33
26
27 Olmstead 448
28 331.00 UT 164 85.05 -1.60 2.15
29 334.00 UT 16 18.34 -1.20 5.55
30 335.00 UT 3 37.23 -0.50 3.39
31 336.00 UT 4 32.87 -0.50 3.56
32
33 Bend 23
34 331.00 OR 37 56.03 -0.50 1.75
35 331.30 OR 10 36.77 -0.50 2.70
36 332.00 OR 76 82.28 -0.40 1.16
37 332.30 OR 2 36.96 -0.40 2.67
38 333.00 OR 77 63.23 -1.20 1.64
39 334.00 OR 76 25.05 -0.40 3.99
40 334.70 OR 535 17.18 -1.90 6.24
41 336.00 OR 68.98 -0.20 1.33
42
43 Cline Falls 24
44 331.00 OR 116 21.20 -0.50 8.43
45 332.00 OR 59 49.91 -0.40 6.82
46 333.00 OR 47 58.43 -1.20 6.77
47 334.00 OR 11 53.67 -0.40 6.79
48 334.70 OR 33 13.26 -1.90 10.74
49 336.00 OR 1 61.98 -0.20 6.54
50
FERC FORM NO.1 (ED.12-95)Page 337.14
Name of Respondent I his Report is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
DEPRECIATIONAND AMORTIZATION OF ELECTRIC PLANT (Continued)
C.Factors Used in Estimating Depreciation Charges
Line Deµieciable Estimaled Nei Aµµlied Mullalily Avelaye
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)(g)
12 Eagle Point 36
13 330.20 OR 12 53.00 5.00
14 331.00 OR 121 31.32 -1.00 5.78
15 332.00 OR 1,086 25.43 -0.90 6.12
16 332.20 OR 26 37.52 -0.90 5.50
17 333.00 OR 217 42.71 -2.50 5.50
18 334.00 OR 64 37.44 -0.80 5.57
19 336.00 OR 28 23.28 -0.30 6.23
20
21 Weber 454
22 331.00 UT 216 55.63 -2.00 2.76
23 331.30 UT 148 27.49 -2.00 4.02
24 332.00 UT 1,023 65.31 -1.80 2.56
25 333.00 UT 874 35.38 -4.90 3.62
26 334.00 UT 115 44.20 -1.50 3.11
27 335.00 UT 22 34.23 -0.60 3.57
28 336.00 UT 40 25.53 -0.60 4.12
29
30 Gunlock 463
31 331.00 UT 32 54.83 -2.00 2.70
32 332.00 UT 79 75.62 -1.80 2.32
33 333.00 UT 121 36.64 -4.90 3.49
34 334.00 UT 239 30.89 -1.50 3.74
35 335.00 UT 5 41.25 -0.60 3.17
36 336.00 UT 66.40 -0.60 2.38
37
38 Veyo 464
39 331.00 UT 67 38.10 -2.00 3.42
40 332.00 UT 356 38.20 -1.80 3.40
41 333.00 UT 144 64.88 -4.90 2.88
42 334.00 UT 140 35.97 -1.50 3.56
43 335.00 UT 8 40.45 -0.60 3.37
44 336.00 UT 62.15 -0.60 2.68
45
46 Sandcove 465
47 331.00 UT 31 48.54 -2.00 2.88
48 332.00 UT 395 55.99 -1.80 2.66
49 333.00 UT 162 31.40 -4.90 3.82
50 334.00 UT 228 25.67 -1.50 4.20
FERC FORM NO.1 (ED.12-95)Page 337.15
I Name of Respondent I his Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
DEPRECIATION AND AMORTlZATION OF ELECTRICPLANT (Continued)
C.Factors Used in Estimeting Depreciation Charges
Line Deµreciable Es¿imated Nel Aµµlied Muilaiity Aveiage
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)(g)
12 336.00 UT 2 93.80 -0.60 2.08
13
14 Stairs 452
15 331.00 UT 155 52.42 -2.40 2.40
16 332.00 UT 335 59.75 -2.20 2.19
17 333.00 UT 513 36.74 -6.10 3.19
18 334.00 UT 151 39.83 -1.90 2.90
19
20 Last Chance 468
21 331.00 ID 423 40.36 -2.40 2.87
22 332.00 lD 819 41.04 -2.20 2.82
23 333.00 lD 1,087 39.99 -6.10 3.03
24 334.00 ID 103 39.87 -1.90 2.91
25 336.00 ID 65 41.70 -0.80 2.72
26
27 American Fork 441
28 331.00 UT 87 61.13 -2.90 1.97
29 331.30 UT 32.97 -2.90 3.15
30 332.00 UT 601 66.22 -2.60 1.85
31 333.00 UT 121 53.51 -7.20 2.32
32 334.00 UT 117 46.74 -2.30 2.42
33 335.00 UT 2 41.64 -0.80 2.63
34 336.00 UT 9 37.12 -0.90 2.79
35
36 Upper Beaver 443
37 331.00 UT 154 76.14 -2.90 1.77
38 332.00 UT 1,791 47.36 -2.60 2.40
39 333.00 UT 118 52.53 -7.20 2.40
40 334.00 UT 401 38.38 -2.30 2.83
41 335.00 UT 10 41.62 -0.80 2.66
42 336.00 UT 2 81.42 -0.90 1.61
43
44 Snake Creek 451
45 331.00 UT 53 48.21 -2.00 2.81
46 332.00 UT 423 44.38 -1.80 2.92
47 333.00 UT 263 35.93 -4.90 3.48
48 334.00 UT 145 37.55 -1.50 3.27
49 335.00 UT 2 32.56 -0.60 3.57
50
FERC FORM NO.1 (ED.12-95)Page 337.16
Name of Respondent I his Report is:LJate ot keport Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
DEPRECIATIONAND AMORTIZATION OF ELECTRIC PLANT(Continued)
C.Factors Used in Estimt ting Depreciation Charges
Line Deµieuiable Estinised Nel Apµ\ied Mullaiity Aveiage
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)(g)
12 Viva Naughton 467
13 331.00 WY 386 51.78 -3.80 2.06
14 332.00 WY 104 51.89 -3.50 2.05
15 333.00 WY 486 51.82 -9.50 2.21
16 334.00 WY 159 50.48 -3.00 2.12
17 335.00 WY 21 49.01 -1.10 2.15
18
19 Granite 445
20 331.00 UT 122 63.88 -2.90 1.89
21 332.00 UT 3,402 59.10 -2.60 1.98
22 333.00 UT 676 46.15 -7.20 2.56
23 334.00 UT 174 43.27 -2.30 2.55
24 335.00 UT 1 56.63 -0.80 2.07
25
26 Fountain Green 446
27 331.00 UT 20 57.11 -1.00 8.16
28 332.00 UT 319 19.72 -0.90 8.14
29 333.00 UT 24 75.52 -2.50 8.31
30 334.00 UT 70 25.40 -0.80 8.26
31 335.00 UT 2 23.68 -0.30 8.27
32 336.00 UT 1 77.94 -0.30 7.65
33
34 Skookumchuck 201
35 331.00 WA 1,104 54.36 -4.60 1.92
36 332.10 WA 5,126
37 333.00 WA 1,143 54.38 -11.30 2.06
38 334.00 WA 343 51.47 -3.50 2.01
39
40 OTHER
41
42 Hermiston Plant
43 341.00 WA 11,020 34.92 -2.00 2.85
44 342.00 WA 3,089 35.00 -2.00 2.83
45 343.00 WA 93,445 35.00 -2.00 2.83
46 344.00 WA 38,055 35.00 -2.00 2.83
47 345.00 WA 9,059 35.00 -2.00 2.83
48 346.00 WA 497 35.00 -2.00 2.83
49
50
FERC FORM NO.1 (ED.12-95)Page 337.17
Name of Respondent i his Report Is:L)ate of Report Year ot Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
DEPRECIATION AND AMORTIZATION OF ELECTRIC PLANT (Continued)
C.Factors Used in Estimating Depreciation Ch irges
Line Depteuiable Estintaled Wel AµµIled Muttelity Aveiage
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)(g)12 Little Mountain
13 341.00 UT 204 27.13 -5.20 4.23
14 342.00 UT 121 29.71 -5.20 3.89
15 343.00 UT 1,275 25.12 -5.20 4.53
16 344.00 UT 1,605 30.94 -5.20 3.76
17 345.00 UT 215 24.61 -5.20 4.62
18 346.00 UT 37 18.19 -5.20 6.81
19
20 High Desert Solar Gen
21 344.00 OR 56 15.00 6.72
22
23 Canyon Lands Dist Serv
24 344.00 UT 36 15.00 6.72
25
26 Green River Solar Gen
27 344.00 UT 55 15.00 6.72
28
29 Foote Creek Wind Gen
30 344.00 WY 40,460 35.00 2.00 2.87
31
32 Transmission Plant
33 350.20 52,607 70.00 1.31
34 352.00 43,529 65.00 -15.00 1.67
35 353.00 690,005 55.00 -5.00 1.83
36 353.70 39,538 15.00 6.03
37 354.00 340,963 65.00 -25.00 1.78
38 355.00 394,284 50.00 -25.00 2.34
39 356.00 531,256 65.00 -45.00 2.09
40 356.20 30,369 70.00 1.26
41 357.00 2,015 50.00 -80.00 2.47
42 358.00 2,316 50.00 -30.00 2.13
43 359.00 10,969 70.00 1.39
44
45 Distribution Plant-UT
46 360.20 UT 8,295 52.00 1.99
47 361.00 UT 12,644 60.00 -10.00 1.87
48 362.00 UT 194,498 55.00 -10.00 2.02
49 362.70 UT 8,015 15.00 6.99
50 364.00 UT 254,972 42.00 -105.00 4.75
FERC FORMNO.1 (ED.12-95)Page 337.18
Name ot Respondent I his Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
DEPRECIATIONAND AMORTIZATION OF ELECTRICPLANT (Continued)
C.Factors Used in Estimeting Depreciation Charges
Line Deµieciable Esliurated Net Apµ\ied Muuality Averaye
No Account No.Plant Base Avg.Service Salvage Depr.rates Curve Remaining(in Thousands)Life (Percent)(Percent)T e L1fe(a)(b)(c)(d)(e)(g)
12 365.00 UT 165,792 42.00 -80.00 4.24
13 366.00 UT 111,550 50.00 -80.00 3.59
14 367.00 UT 307,394 50.00 -20.00 2.42
15 368.00 UT 290,728 40.00 -25.00 3.16
16 369.00 UT 103,228 50.00 -50.00 2.97
17 370.00 UT 88,788 30.00 -5.00 3.64
18 371.00 UT 4,775 15.00 -35.00 9.11
19 372.00 UT 50 25.00 4.54
20 373.00 UT 23,181 18.00 -35.00 7.55
21
22 Distribution Plant-OR
23 360.20 OR 3,534 50.00 2.00
24 361.00 OR 10,686 52.00 -5.00 2.11
25 362.00 OR 140,607 45.00 -10.00 2.55
26 362.70 OR 3,030 12.00 10.01
27 364.00 OR 238,458 35.00 -105.00 6.25
28 365.00 OR 188,941 40.00 -80.00 4.83
29 366.00 OR 61,082 50.00 -5.00 2.20
30 367.00 OR 100,230 40.00 -40.00 3.73
31 368.00 OR 291,540 35.00 -20.00 3.74
32 369.10 OR 44,123 45.00 -30.00 3.15
33 369.20 OR 76,650 40.00 -30.00 3.48
34 370.00 OR 55,766 30.00 -5.00 3.79
35 371.00 OR 2,497 15.00 -10.00 12.68
36 373.00 OR 15,038 35.00 -35.00 4.23
37
38 Distribution Plant-WA
39 360.20 WA 298 50.00 2.14
40 361.00 WA 1,435 50.00 -30.00 2.67
41 362.00 WA 37,818 45.00 -10.00 2.51
42 362.70 WA 534 15.00 7.42
43 364.00 WA 61,524 45.00 -150.00 5.70
44 365.00 WA 46,043 50.00 -80.00 3.70
45 366.00 WA 10,663 60.00 -50.00 2.54
46 367.00 WA 12,002 45.00 -40.00 3.20
47 368.00 WA 68,038 40.00 -80.00 4.69
48 369.10 WA 11,074 50.00 -35.00 2.80
49 369.20 WA 15,773 50.00 -35.00 2.77
50 370.00 WA 13,345 30.00 -5.00 3.63
FERC FORM NO.1 (ED.12-95)Page 337.19
Name of Respondent I his Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
DEPRECIATIONAND AMORTIZATION OF ELECTRICPLANT (Continued)
C.Factors Used in EstimatingDepreciation Charges
Line Depreciable Esliinated Nel Aµµlied Mullality Average
No Account No.Plant Base Avg.Service Salvage Depr.rates Curve Remaining(in Thousands)Life (Percent)(Percent)Tvoe Life(a)(b)(c)(d)(e)(f)(g)
12 371.00 WA 551 30.00 -85.00 6.57
13 373.00 WA 2,973 30.00 -70.00 5.97
14
15 Distribution Plant-WY
16 360.20 WY 1,881 50.00 1.98
17 361.00 WY 5,207 45.00 -10.00 2.43
18 362.00 WY 82,127 40.00 -10.00 2.73
19 362.70 WY 2,571 15.00 6.51
20 364.00 WY 56,447 43.00 -105.00 4.73
21 365.00 WY 63,355 45.00 -60.00 3.53
22 366.00 WY 6,981 55.00 -30.00 2.35
23 367.00 WY 16,499 40.00 -25.00 3.10
24 368.00 WY 48,891 40.00 -40.00 3.46
25 369.10 WY 7,027 50.00 -50.00 2.98
26 369.20 WY 9,192 50.00 -50.00 2.98
27 370.00 WY 11,251 30.00 -5.00 3.46
28 371.00 WY 741 20.00 -40.00 6.87
29 373.00 WY 5,073 40.00 -50.00 3.72
30
31 Distribution Plant -CA
32 360.20 CA 914 65.00 1.74
33 361.00 CA 1,412 45.00 -5.00 2.45
34 362.00 CA 11,303 55.00 -50.00 2.91
35 362.70 CA 229 15.00 7.66
36 364.00 CA 35,662 45.00 -120.00 5.22
37 365.00 CA 28,885 55.00 -100.00 3.80
38 366.00 CA 13,198 45.00 -25.00 2.91
39 367.00 CA 13,815 40.00 -35.00 3.59
40 368.00 CA 35,522 40.00 -75.00 4.76
41 369.10 CA 5,652 40.00 -30.00 3.42
42 369.20 CA 8,342 50.00 -30.00 2.67
43 370.00 CA 4,163 30.00 -10.00 4.01
44 371.00 CA 267 25.00 -85.00 8.42
45 373.00 CA 627 30.00 -100.00 7.22
46
47 General Plant-OR
48 390.00 OR 53,143 40.00 2.55
49 391.10 OR 5,068 5.00 2.42
50 392.00 OR 131 8.00 10.00 10.78
FERC FORM NO.1 (ED.12-95)Page 337.20
Name of Respondent I his Report is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
DEPRECIATIONAND AMORTIZATION OF ELECTRIC PLANT (Continued)
C.Factors Used in Estimeting Depreciation Charges
Line Deµ:euiable Estirriated Net AµµIled Murlalily 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)(g)12 392.01 OR 336 8.00 10.00 10.78
13 392.02 OR 814 8.00 10.00 10.78
14 392.03 OR 79 8.00 10.00 10.78
15 392.04 OR 5,064 14.00 10.00 6.31
16 392.05 OR 4,378 14.00 10.00 6.31
17 392.06 OR 353 14.00 10.00 6.31
18 392.08 OR 547 14.00 10.00 6.31
19 392.09 OR 2,329 35.00 20.00 2.25
20 396.00 OR 804 15.00 35.00 4.25
21 396.01 OR 285 15.00 35.00 4.25
22 396.02 OR 6,558 15.00 35.00 4.25
23 396.03 OR 4,386 15.00 35.00 4.25
24 396.04 OR 1,415 15.00 35.00 4.25
25 396.07 OR 724 15.00 35.00 4.25
26 396.08 OR 8,141 15.00 35.00 4.25
27 397.00 OR 82,035 20.00 -5.00 5.58
28
29 General Plant-WA
30 390.00 WA 9,294 35.00 -15.00 3.12
31 392.00 WA 24 8.00 10.00 12.49
32 392.01 WA 156 8.00 10.00 12.49
33 392.02 WA 96 8.00 10.00 12.49
34 392.04 WA 1,184 15.00 10.00 6.46
35 392.05 WA 1,185 15.00 10.00 6.46
36 392.06 WA 138 15.00 10.00 6.46
37 392.09 WA 438 40.00 15.00 2.30
38 396.01 WA 191 14.00 20.00 6.21
39 396.02 WA 1,810 14.00 20.00 6.21
40 396.03 WA 1,368 14.00 20.00 6.21
41 396.04 WA 477 14.00 20.00 6.21
42 396.07 WA 158 14.00 20.00 6.21
43 396.08 WA 2,112 14.00 20.00 6.21
44 397.00 WA 11,167 25.00 -5.00 3.75
45
46 Mining Operations -WA
47 399.51 8.00 10.00 4.10
48 399.52 13.00 15.00 5.99
49 399.60 13.00 10.17
50 399.61 10.00 3.06
FERC FORM NO.1 (ED.12-95)Page 337.21
Name of Respondent I his Report Is:IJate of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
DEPRECIATION AND AMORTIZATION OF ELECTRICPLANT(Continued)
C.Factors Used in Estimeting Depreciation Ch arges
Line Deµreciable Estilitaled Net AµµLed Morldlity 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)(g)
12
13 General Plant-UT
14 389.20 35 40.00 2.51
15 390.00 6,708 40.00 5.00 2.38
16 392.01 2,247 12.00 15.00 5.47
17 392.04 26,699 12.00 15.00 4.62
18 392.09 6,265 30.00 30.00 1.75
19 396.03 34,952 15.00 20.00 4.06
20 397.00 44,521 20.00 5.03
21
22 Mining Operations -UT
23 399.30 UT 59,124 25.00 4.46
24 399.45 UT 138,556 11.00 5.00 5.57
25 399.51 UT 1,199 15.00 5.00 4.43
26 399.52 UT 2,556 20.00 1.91
27 399.60 UT 2,363 15.00 4.15
28 399.61 UT 1,937 8.00 18.50
29 399.70 UT 43,285 15.00 6.84
30
31 General Plant -WY
32 390.00 WY 5,003 35.00 -5.00 3.19
33 392.00 WY 140 8.00 15.00 12.75
34 392.01 WY 99 8.00 15.00 12.75
35 392.02 WY 224 8.00 15.00 12.75
36 392.04 WY 2,927 12.00 5.00 8.76
37 392.05 WY 2,781 12.00 5.00 8.76
38 392.06 WY 280 12.00 5.00 8.76
39 392.08 WY 164 12.00 5.00 8.76
40 392.09 WY 2,003 30.00 3.55
41 396.00 WY 775 10.00 45.00 6.40
42 396.01 WY 4,990 10.00 45.00 6.40
43 396.02 WY 3,346 10.00 45.00 6.40
44 396.03 WY 1,193 10.00 45.00 6.40
45 396.04 WY 2,178 10.00 45.00 6.40
46 396.07 WY 485 10.00 45.00 6.40
47 396.08 WY 3,646 10.00 45.00 6.40
48 397.00 WY 21,423 20.00 5.34
49
50 General Plant -CA
FERC FORM NO.1 (ED.12-95)Page 337.22
Nameot Respondent I his Report Is:IJate ot keport Year of keport
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
DEPRECIATIONAND AMORTIZATIONOF ELECTRICPLANT (Continued)
C.Factors Used in Estimating Depreciation Charges
Line Depreciable Esliniated Nel AµµIied Mullalily Aveiage
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)(g)
12 390.00 CA 1,412 45.00 -10.00 1.93
13 392.01 CA 6 8.00 10.00 10.90
14 392.04 CA 225 15.00 5.00 6.09
15 392.05 CA 277 15.00 5.00 6.09
16 392.06 CA 58 15.00 5.00 6.09
17 392.09 CA 245 30.00 3.24
18 396.02 CA 692 15.00 15.00 5.45
19 396.03 CA 505 15.00 15.00 5.45
20 396.04 CA 190 15.00 15.00 5.45
21 396.07 CA 48 15.00 15.00 5.45
22 396.08 CA 629 15.00 15.00 5.45
23 397.00 CA 3,950 20.00 3.89
24
25 General Plant -MT
26 390.00 MT 340 30.00 3.32
27 392.01 MT 12.00 15.00 7.09
28 392.04 MT 2 15.00 15.00 5.69
29 392.09 MT 30.00 30.00 2.36
30 396.01 MT 15 12.00 20.00 6.69
31 397.00 MT 2,301 20.00 4.97
32
33 General Plant
34 390.30 10,053 15.00 6.67
35 391.00 32,341 20.00 5.00
36 391.20 73,700 5.00 20.00
37 391.30 2,107 8.00 12.50
38 393.30 9,289 25.00 4.00
39 394.00 43,794 24.00 4.17
40 395.00 31,962 20.00 5.00
41 397.20 6,951 11.00 9.09
42 398.00 4,830 20.00 5.00
43
44
45
46
47
48
49
50
FERC FORM NO.1 (ED.12-95)Page 337.23
BLANK PAGE
(Next Page is:340)
Name ot Respondent I his keport is:Date of Report Year of keport
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
PAR I lUULAKS CUNGERNING UbH IAIN INCUME UbUUCI lONS AND IN I EMESI CHARG -S ACCOUNI S
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 amountand 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 Miscellaneous Amortization (Account 425)
2 Amortization of Misc.IntangiblePlant (Acct 303)
3 Associated with purchase of Centralia Coal Mine 44,068
4
5 Total -425 44,068
6
7
8 Donations (426.1)
9 Utah Lend-A-Hand 50,000
10 Live Captioning Services 66,000
11 Olympics 40,000
12 Olympic Music Ed.Program 95,000
13 Other -each less than 5%of account 561,367
14
15 Total -426.1 812,367
16
17
18 Life insurance (Account 426.2)
19 Life Insurance -8,251,674
20
21 Total -426.2 -8,251,674
22
23
24 Penalties(426.3)
25 Internal Revenue Service 3,126
26 FERC Project #696 10,000
27 Other -each less than 5%of account 3,304
28
29 Total -426.3 16,430
30
31
32 Civic,Political,and Related Exp (Account 426.4)
33 Commfor Oregon 50,000
34 Baker,Donelson,Bearman &Caldwel 88,693
35 Other -each leass than 5%of account 706,275
36
37 Total -426.4 844,968
38
39
40
41
¯ERC FORM NO.1 (ED.12-87)Page 340
Name of Respondent I his Report is:Date of Repori Vear of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
PAR I IGULARSCUNUt-RNING UER I AIN INGUME ULUUC I IONSANU IN I ERES I CHARGl-S AUGUUN I S
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 amountand 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 Amount
No.(a)(b)
1 Other Deductions (Account 426.5)
2 ScottishPower merger related expenses -26,479,568
3 Other -each less than 5%of account 3,790,386
4
5 Total -426.5 -22,689,182
6
7
8 Interest on Debt to Assoc.Co.(Account 430)
9 PacifiCorp Holdings,Inc.10,975,420
10 PacifiCorp Minerals,Inc.988,488
11 Pacific Capital I -8.25%18,456,240
12 Pacific Capital II -7.7%10,716,552
13
14 Total -430 41,136,700
15
16
17 Other Interest Expense (Account 431)
18 Customer Deposits 334,534
19 Short-term Debt Interest:
20 CommercialPaper -4.5%to 7.125%3,809,195
21 CommercialPaper -4.5%to 7.125%3,279,849
22 Corp.Owned Life Insurance Loans -7.22%6,079,864
23 Interest Rates Swaps -Net Interest Payment
24 Sumitomo Bank -5.725%to 8.025%1,726,611
25 Bank of America -5.725%to 8.025%
26 Intemal Revenue Service 4,800,000
27 Other Taxes 133,324
28 Customer Overpayments -6.00%37,701
29 Misc.Interest Charges 58,085
30 Non-owner Buyer's Reclamation Fund and
31 Overcollection of Coal Revenues -8.02%562,025
32 Centralia Scrubber Project -9.75%to 10.0%-4,868
33 Sunnyside Cogeneration Deposit -5.34%to 6.17%-102,143
34 Utah Rate Case 8.84%19,660
35 Short-term Debt Commitment Fees -7.0%to 9.0%1,146,755
36 Deferred Compensation -5.14%to 8.4%1,678,189
37 Trojan Decommissioning -5.67%to 5.76%39,175
38 Power Sales/Purchases 641,564
39
40 Total -431 24,239,520
41
FERGFORM NO.1 (ED.12-87)Page 340.1
Name of Respondent I his Report is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
R -bULAIURY UUlvlMIbbluN t-APENbbb
1.Raport 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.Raport 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 I otal .Deterred
No.(Fumish name of regulatory commission or body the Regulatory oÿ Expense for in Account
docket or case number and a description of the case)Commission Utility Curbrent ear BegirÎn ng3o Year
(a)(b)(c)(d)(e)
1 Before the Public Service Commission of Utah:
2 Annual Fee 2,440,837 2,440,837
3 Other rate case expenses (12 months)509,265 509,265
4
5 Before the Idaho Public Utilities Commission:
6 Annual Fee 312,455 312,455
7 Other rate case expenses (12 months)10,878 10,878
8
9 Before the Public Service Commission
10 of Wyoming:
11 Annual Fee 630,241 630,241
12 Other rate case expenses (12 months)328,684 328,684
13
14 Before the Public Utilities Commission
15 of Califomia:
16 Annual Fee 93,485 93,485
17 Other rate case expenses (12 months)-806 -806
18
19 Before the Public Utility Commission
20 of Oregon:
21 Annual Fee 2,496,773 2,496,773
22 Other rate case expenses (12 months)-240 -240
23
24 Before the Washington Utilities and
25 Transportation Commission:
26 Annual Fee 383,053 383,053
27 Other rate case expenses (12 months)2,241 2,241
28
29 Before the Federal Energy Regulatory
30 Commission:
31 Annual Fee 1,310,579 1,310,579
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46 TOTAL 7,667,423 850,022 8,517,445
FERC FORM NO.1 (ED.12-96)Page 350
Name ot Respondent I his keport Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
REb JLA I URY CUMMlbblUN EAPt-Nbbs (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.
EXPENSt-8 INGURRI U DURING Yt-AM AMURI ILED DURING Y =AR
CURRI:NILY CHARGED 10 beterred to contra Amount Deterred in LineDepartmentAoiAmountAccount182.3 Account A cont 8a2.3 No.
(f)(g)(h)(i)(j)(k)(I)
1
Electric 928 2,440,837 2
Electric 928 509,265 3
4
5
Electric 928 312,455 6
Electric 928 10,878 7
8
9
10
Electric 928 630,241 11
Electric 928 328,684 12
13
14
15
Electric 928 93,485 16
Electric 928 -806 17
18
19
20
Electric 928 2,496,773 21
Electric 928 -240 22
23
24
25
Electric 928 383,053 26
Electric 928 2,241 27
28
29
30
Electric 928 1,310,579 31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
|8,517,445 46
VERC FORM NO.1 (E ).12-96)Page 351
Name ot Respondent I his Report is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
RESEARCH,ObVELOPMENl ,AND DEMONS I KA I IONAU I IVI I It-5
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 Pedormed Intemally:(3)Transmission
(1)Generation a.Overhead
a.hydroelectric b.Underground
i.Recreation fish and wildlife (4)Distribution
li Other hydroelectric (5)Environment(other than equipment)
b.Fossil-fuel steam (6)Other (Classify and include items in excess of $5,000.)
c.Intemal combustion or gas turbine (7)T3tal Cost Incurred
d.Nuclear B.Ek ctric,R,D &D Pedormed Extemally:
e.Unconventional generation (1)Rasearch Support to the electrical Research Council or the Electric
f.3iting and heat rejection Power Research Institute
Line Classification Description
No-(a)(b)
2 A.Electric R,D &D pedormed intemally
3 (1)Generation
4 b.Fossil-fuel steam Hunter Research Farm
5 Power Supply Cattle
6
7 (7)Total Cost Incurred
8
9
10 B.Electric R,D &D performed extemally NONE
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
ERC FORM NO.1 (ED.12-87)Fage 352
Name of Respondent i his Report is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
RbsbARCH,DEVELUPMENI ,AND UEMUNSI RA I ION AU \IVI I lbS (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 intemally 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 accumulatingof 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 Extemally AMOUNTS CHARGED IN CURRENT YEAR Unamortized LineCurrentYearCurrentYearAccountAmountAccumulationNo.(c)(d)(e)(f)(9)
13,686 506 13,686 4
534,909 506 534,909 b
548,595 548,595 /
10
11
12
14
34
FERC FORM NO.1 (ED.12-87)Page 353
Name of Respondent I his Report is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
DIS I RI I ION UI-ALAklEB AND RAbba
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.
Line Classification Direct Payrolf Auóóàtton ót
No Distribution Payroll charged for Total
Cleanng Accounts(a)(b)(c)(d)
1 Electric
2 Operation
3 Production 56,714,091
4 Transmission 10,283,545
5 Distribution 24,454,045
6 CustomerAccounts 37,707,005
7 Customer Service and Informational 116,810
8 Sales 4,737,860
9 Administrative and General 104,501,911
10 TOTAL Operation (Enter Total of lines 3 thru 9)238,515,267
11 Maintenance
12 Production 37,987,546
13 Transmission 5,765,794
14 Distribution 56,397,291
15 Administrative and General
16 TOTAL Maint.(Total of lines 12 thru 15)100,150,631
17 Total Operation and Maintenance
18 Production (Enter Total of lines 3 and 12)94,701,637
19 Transmission (Enter Total of lines 4 and 13)16,049,339
20 Distribution (Enter Total of lines 5 and 14)80,851,336
21 CustomerAccounts (Transcribe from line 6)37,707,005
22 CustomerService and Informational (Transcribe from line 7)116,810
23 Sales (Transcribe from line 8)4,737,860
25 TOTAL Oper.and Maint.(Total of lines 18 thru 24)338,665,898|338,665,898
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 CustomerAccounts
35 CustomerService 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 Terminalingand Proœssing
44 Transmission
45 Distribution
46 Administrative and General
FERCFORM NO.1 (ED.12-88)Page 354
Name of Respondent I his Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
Ulb I aldU I luN UF bALARIEb AND WAbbb (t,ontinued)
Line Classification Direct Payroll Allocatiór'i Of
Distribution Payroll charged for TotalNo-Cleanng Accounts(a)(b)(c)(d)
48 Total Operation and Maintenance
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 CustomerAccounts (Line 34)
56 Customer Service and Informational (Line 35)
57 Sales (Line 36)
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)338,665,898 338,665,898
63 Utility Plant
65 Electric Plant 52,303,259 52,303,259
66 Gas Plant
67 Other
68 TOTAL Construction (Total of lines 65 thru 67)52,303,259 52,303,259
69 Plant Removal (By Utility Departments)
70 Electric Plant
71 Gas Plant
72 Other
73 TOTAL Plant Removal (Total of lines 70 thru 72)
74 Other Accounts (Specify):
75 Fuel Stock 51,208,490 51,208,490
76 Miscellaneous Income Deductions -15,873 -15,873
77
78
79
80
81
82
83
84
85
86
87
88
89
90
91
92
93
94
95 TOTAL Other Accounts 51,192,617 51,192,617
96 TOTAL SALARIES AND WAGES 442,161,774 442,161,774
FERC FORM NO.1 (ED.12-88)Page 355
Name of Respondent I his keport is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
ELEUI RIO ENERUY AGUUUNI
Report below the information called for conceming the disposition of electric energy generated,purchased,exchanged and wheeled during the year.
Line Item MegaWatt Hours Line Item MegaWatt Hours
No.No.
(a)(b)(a)(b)
2 Generation (Excluding Station Use):22 Sales to Ultimate Consumers (Including 48,300,47Š
3 Steam 48,405,380 InterdepartmentalSales)
4 Nuclear -51 23 RequirementsSales for Resale (See 188,555
5 Hydro-Conventional 4,360,554 instruction 4,page 311.)
6 Hydro-PumpedStorage 24 Non-RequirementsSales for Resale (See 29,771,574
7 Other 2,052,763 instruction 4,page 311.)
8 Less Energy for Pumping 25 Energy Fumished Without Charge
9 Net Generation (Enter Total of lines 3 54,818,178 26 Energy Used by the Company (Electric 97,932
through 8)Dept Only,Excluding Station Use)
10 Purchases 28,098,219 27 Total Energy Losses 4,806,379
11 Power Exchanges:28 TOTAL (Enter Total of Lines 22 Through 83,164,913
12 Received 6,946,122 27)(MUST EQUAL LINE 20)
13 Delivered 6,448,750
14 Net Exchanges (Line 12 minus line 13)497,372
15 Transmission For Other (Wheeling)
16 Received 13,553,792
17 Delivered 13,553,792
18 Net Transmission for Other (Line 16 minus
line 17)
19 Transmission By Others Losses -248,856
20 TOTAL (Enter Total of lines 9,10,14,18 83,164,913
and 19)
FERC FORM NO.1 (ED.12-90)Page 401a
Name of Respondent I his Report is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
MUNIHLY PEAKb ANDUUIPUI
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-RequirementsSales For Resale reported on Line 24.include in the monthly amounts any
energy losses associated with the sales so that the total on Line 41 exceeds the amount on Line 24 by the amount of losses incurred (or estimated)in
making the Non-Requirements Sales for Resale.
4.Report in column (d)the system's monthly maximummegawatt Load (60-minute integration)associated with the net energy for the system defined as
the difference between columns (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:PacifiCorp
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 7,256,863 2,569,540 7,382 31 0800 PST
30 February 6,686,041 2,418,771 7,172 18 0800 PST
31 March 6,883,196 2,609,160 6,897 1 0800 PST
32 April 6,185,989 2,245,472 6,439 24 0800 PST
33 May 6,472,178 2,257,599 6,836 23 1500 PDT
34 June 6,775,453 2,296,818 7,960 28 1600 PDT
35 July 6,835,961 2,001,166 8,480 31 1600 PDT
36 August 7,184,015 2,347,956 8,295 1 1500 PDT
37 September 6,660,454 2,487,531 7,402 14 1600 PDT
38 October 7,287,512 2,990,220 6,826 23 0800 PST
39 November 7,720,883 3,111,578 7,568 22 0900 PST
40 December 7,216,368 2,435,763 7,985 11 1800 PST
41 TOTAL 83,164,913 29,771,574
FERC FORM NO.1 (ED.12-90)Page 401b
Nameof Respondent i his Report Is:Date of Report Year of Report
PacifiCorp R su
malssion (I ,Da,Yr)
Dec.31,2000
STEAM-ELECTRICGENERATINGPLANT 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 bumed converted to Mct.7.Quantities of fuel bumed (Line 37)and average cost
per unit of fuel bumed (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:Carbon Plant Name:Gadsby Plant
(a)(b)(c)
1 Kind of Plant (Intemal Comb,Gas Turb,Nuclear Steam Steam
2 Type of Constr (Conventional,Outdoor,Boiler,etc)Outdoor Boiler Outdoor Boiler
3 Year Originally Constructed 1954 1951
4 Year Last Unit was Installed 1957 1955
5 Total installed Cap (Max Gen NamePlate Ratings-MW)188.64 251.64
6 Net Peak Demand on Plant -MW (60 minutes)190 227
7 Plant Hours Connected to Load 8784 7472
8 Net Continuous Plant Capability (Megawatts)O 0
9 When Not Limited by Condenser Water 175 235
10 When Limited by Condenser Water 0 0
11 Average Number of Employees 72 35
12 Net Generation,Exclusive of Plant Use -KWh 1372236000 718120000
13 Cost of Plant:Land and Land Rights 956546 1020271
14 Structures and Improvements 10372194 13403934
15 EquipmentCosts 64815522 53622212
16 Total Cost 76144262 68046417
17 Cost per KW of Installed Capacity (line 5)403.6485 270.4118
18 Production Expenses:Oper,Supv,&Engr 1558989 415875
19 Fuel 9089823 35661055
20 Coolants and Water (Nuclear Plants Only)0 0
21 Steam Expenses 127095 0
22 Steam From Other Sources O 0
23 Steam Transferred (Cr)0 0
24 Electric Expenses O O
25 Misc Steam (or Nuclear)Power Expenses 2935242 2083115
26 Rents 2133 0
27 Allowances O O
28 Maintenance Supervision and Engineering 0 0
29 Maintenance of Structures O O
30 Maintenance of Boiler (or reactor)Plant 2739910 971664
31 Maintenance of Electric Plant 1343814 1093920
32 Maintenance of Misc Steam (or Nuclear)Plant 1009421 1093920
33 Total Production Expenses 18806427 41319549
34 Expenses per Net KWh 0.0137 0.0575
35 Fuel:Kind (Coal,Gas,Oil,or Nuclear)Coal Oil Gas
36 Unit (Coal-tons/Oil-barrel/Gas-mcf/Nuclear-indicate)Tons Barrel MCF
37 Quantity (units)of Fuel Burned 630164 0 1335 0 8864139 0
38 Avg Heat Cont -Fuel Burned (btu/indicate if nuclear)12352 0 140000 0 1049 0
39 Avg Cost of Fuellunit,as Delvd f.o.b.during year 15.060 0.000 37.102 0.000 0.000 0.000
40 Average Cost of Fuel per Unit Bumed 14.346 0.000 37.102 0.000 4.023 0.000
41 Average Cost of Fuel Burned per Million BTU 0.581 0.000 6.310 0.000 3.835 0.000
42 Average Cost of Fuel Bumed per KWh Net Gen 0.000 0.007 0.000 0.000 0.050 0.000
43 Average BTU per KWh Net Generation 0.000 11350.258 0.000 0.000 12949.678 0.000
FERC 1 ORM NO.1 (ED.12-95)Page 402
Name of Respondent I his Report is:I.Jate of Report Year of Report
PacifiCorp R u
maission (,Da,Yr)Dec.31,2000
STEAM-ELECTRICGENERATING 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 Load
Dispatching,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 plants
designed for peak load service.Designate automatically operated plants.11.For a plant equipped with combinationsof 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 e×cess costs attributed to research and development;(b)types of cost units
used for the various components of fuel cost;anc (c)any other informative data concerning plant type fuel used,fuel enrichment type and quantity for
the report period and other physical and operating characteristics of plant.
Plant Plant Plant Line
Narne:Naughton Plant Name:Huntington Plant Name:Hunter Plant No.
(d)(e)(f)
Steam Steam Steam 1
Outdoor Boiler Outdoor Boiler Outdoor Boiler 2
1963 1974 1978 3
1971 1977 1983 4
707.20 996.00 1223.50 5
717 905 1304 6
8770 8784 8784 7
0 0 0 8
700 895 1122 9
0 0 0 10
159 165 227 11
5368410000 7053195000 8070630000 12
458248 2364398 29606749 13
55719136 93700731 197339824 14
250052091 310328895 723518497 15
306229475 406394024 950465070 16
433.0168 408.0261 776.8411 17
1424388 1125694 -119185 18
64675128 45525425 59256046 19
0 0 0 20
2832367 1571532 2947454 21
0 0 0 22
0 0 0 23
0 0 0 24
7535889 9284631 2436461 25
0 86716 504 26
0 0 0 27
0 0 0 28
0 0 0 29
3348072 4647948 18384601 30
497837 1084300 1102843 31
3602613 2698665 277718 32
83916294 66024911 84286442 33
0.0156 0.0094 0.0104 34
Coal Gas Oil Coal Oil Coal Oil 35
Tons MCF Barrel Tons Barrel Tons Barre!36
2828964 596148 2900 3028902 0 10736 3574969 0 16576 37
9890 1044 140000 11909 0 140000 12003 0 140000 38
21.265 0.000 38.008 14.340 0.000 38.217 16.540 0.000 39.927 39
22.026 3.782 38.008 14.895 0.000 38.276 16.390 0.000 39.927 40
1.114 3.622 6.464 0.625 0.000 6.510 0.683 0.000 6.790 41
0.000 0.012 0.000 0.000 0.007 0.000 0.000 0.007 0.000 42
0.000 10542.644 0.000 0.000 10237.706 0.000 0.000 10645.895 0.000 43
FERC FORM NO.1 (ED.12-88)Page 403
Name of Respondent I his keport is:Date of Report Year of keport
PacifiCorp R su
maission (Mo/,Da,Yr)Dec.31,2000
STEAM-ELECTRIC GENERATING PLANTSTATISTICS (Large Plants)(Continued)
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 intemal 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 bumed converted to Mct.7.Quantities of fuel bumed (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 bumed in a plant fumish only the composite heat rate for all fuels bumed.
Line Item Plant Plant
No.Name:BlundellPlant Name:Centralia Plant
(a)(b)(c)
1 Kind of Plant (Internal Comb,Gas Turb,Nuclear Steam -Geothermal Steam
2 Type of Constr (Conventional,Outdoor,Boiler,etc)Indoor Conventional
3 Year Originally Constructed 1984 1972
4 Year Last Unit was Installed 1984 1972
5 Total Installed Cap (Max Gen Name Plate Ratings-MW)26.10 693.49
6 Net Peak Demandon Plant -MW (60 minutes)20 638
7 Plant Hours Connected to Load 8642 2968
8 Net Continuous Plant Capability (Megawatts)0 0
9 When Not Limited by Condenser Water 23 637
10 When Limited by Condenser Water 0 0
11 Average Numberof Employees 12 158
12 Net Generation,Exclusive of Plant Use -KWh 151736000 1532884000
13 Cost of Plant:Land and Land Rights 31026429 0
14 Structures and improvements 6146757 0
15 Equipment Costs 32695632 0
16 Total Cost 69868818 0
17 Cost per KW of Installed Capacity (line 5)2676.9662 0.0000
18 Production Expenses:Oper,Supv,&Engr 220740 -3566144
19 Fuel 0 28048033
20 Coolants and Water (Nuclear Plants Only)0 0
21 Steam Expenses 139920 211178
22 Steam From Other Sources 3660711 0
23 Steam Transferred (Cr)0 0
24 Electric Expenses 0 0
25 Misc Steam (or Nuclear)Power Expenses 720145 2695792
26 Rents 0 21
27 Allowances O O
28 MaintenanceSupervision and Engineering 0 0
29 Maintenanceof Structures O 0
30 Maintenanceof Boiler (or reactor)Plant 7268 584252
31 Maintenanceof Electric Plant 42039 53933
32 Maintenanceof Misc Steam (or Nuclear)Plant 302704 486279
33 Total Production Expenses 5093527 28513344
34 Expenses per Net KWh 0.0336 0.0186
35 Fuel:Kind (Coal,Gas,Oil,or Nuclear)Coal Oil
36 Unit (Coal-tons/Oil-barrel/Gas-mcf/Nuclear-indicate)Tons Barrel
37 Quantity (units)of Fuel Bumed 0 0 0 1038147 0 3689
38 Avg Heat Cont -Fuel Bumed (btulindicate if nuclear)0 0 0 7978 0 140000
39 Avg Cost of Fuellunit,as Delvd f.o.b.during year 0.000 0.000 0.000 28.610 0.000 30.766
40 Average Cost of Fuel per Unit Burned 0.000 0.000 0.000 26.908 0.000 30.766
41 Average Cost of Fuel Burned per Million BTU 0.000 0.000 0.000 1.686 0.000 5.232
42 Average Cost of Fuel Burned per KWh Net Gen 0.000 0.000 0.000 0.000 0.018 0.000
43 Average BTU per KWh Net Generation 0.000 0.000 0.000 0.000 10820.360 0.000
FERCCORM NO.1 (ED.12-95)Page 402.1
Name of Respondent I his Report Is:Date of Report Year ot Report
PacifiCorp R u
malssion (I ,Da,Yr)
Dec.31,2000
STEAM-ELECTRIC GENERATINGPLANTSTATISTICS (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 Load
Dispatching,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 plants
designed for peak load senrice.Designate automaticallyoperated 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;ant (c)any other informative data concerning plant type fuel used,fuel enrichment type and quantity for
the report period and other physical and operating characteristics of plant.
Plant Plant Plant Line
Name:Dave Johnston Plant Name:Colstrip Plant Name:Jim Bridger Plant No.
(d)(e)(f)
Steam Steam Steam 1
Semi-Outdoor Conventional Semi-Outdoor 2
1959 1984 1974 3
1972 1986 1979 4
816.77 155.61 1541.00 5
813 154 1438 6
8777 8665 8784 7
0 0 0 8
762 144 1413 9
0 0 0 10
181 211 350 11
5667267000 988479000 10776247000 12
10417291 1293387 1146361 13
45774148 55588416 132172475 14
316781384 146952192 662601365 15
372972823 203833995 795920201 16
456.6436 1309.9029 516.4959 17
3635082 33271 2513551 18
30161510 7537532 118240371 19
0 0 1855148 20
1020850 530000 0 21
0 0 0 22
0 0 0 23
0 37553 0 24
7436300 1218674 14052911 25
-13224 45059 13 26
0 0 0 27
0 93186 0 28
0 166358 0 29
4869031 1821457 6331620 30
1294272 218027 1399120 31
6276128 191743 6451932 32
54679949 11892860 150844666 33
0.0096 0.0120 0.0140 34
Coal Oil Coal Oil Coal Oil 35
Tons Barrel Tons Barrel Tons Barrel 36
3864082 0 15154 628068 0 2502 6021643 0 23062 37
8238 0 140000 8426 0 141000 9262 0 140000 38
7.300 0.000 38.066 11.775 0.000 40.418 19.049 0.000 35.977 39
7.656 0.000 38.066 11.840 0.000 40.418 19.498 0.000 35.977 40
0.465 0.000 6.474 0.703 0.000 6.825 1.053 0.000 6.119 41
0.000 0.005 0.000 0.000 0.008 0.000 0.000 0.011 0.000 42
0.000 11249.463 0.000 0.000 10722.543 0.000 0.000 10363.582 0.000 43
FERC FORM NO.1 (ED.12-88)Page 403.1
Name of Respondent I his Report Is:Date of Report Year of Report
PacifiCorp R u
malssion (Mo/,Da,Yr)
Dec.31,2000
STEAM-ELECTRICGENERATINGPLANTSTATISTICS(Large Plants)(Continued)
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 inthispagegas-turbine and intemal 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 bumed converted to Mct.7.Quantities of fuel bumed (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 onefuelisbumedinaplantfumishonlythecompositeheatrateforallfuelsbumed.
Line Item Plant Plant
No.Name:Wyodak Plant Name:Cholla Plant
(a)(b)(c)
1 Kind of Plant (Intemal Comb,Gas Turb,Nuclear Steam Steam
2 Type of Constr (Conventional,Outdoor,Boiler,etc)Conventional Full Outdoor
3 Year Originally Constructed 1978 1981
4 Year Last Unit was Installed 1978 1981
5 Total installed Cap (Max Gen Name Plate Ratings-MW)289.66 414.00
6 Net Peak Demand on Plant -MW (60 minutes)286 383
7 Plant Hours Connected to Load 7823 7338
8 Net Continuous Plant Capability (Megawatts)0 0
9 When Not Limited by Condenser Water 268 380
10 When Limited by Condenser Water 0 0
11 Average Number of Employees 76 78
12 Net Generation,Exclusive of Plant Use -KWh 2135036000 2322601000
13 Cost of Plant:Land and Land Rights 210526 1178241
14 Structures and improvements 47801109 41298337
15 Equipment Costs 253238495 311220775
16 Total Cost 301250130 353697353
17 Cost per KW of Installed Capacity (line 5)1040.0129 854.3414
18 Production Expenses:Oper,Supv,&Engr 1241387 922533
19 Fuel 20381980 36556743
20 Coolants and Water (Nuclear Plants Only)O 0
21 Steam Expenses 94684 2208574
22 Steam From Other Sources O 0
23 Steam Transferred (Cr)0 0
24 Electric Expenses O 927569
25 Misc Steam (or Nuclear)Power Expenses 2484162 774618
26 Rents O 73322
27 Allowances O O
28 Maintenance Supervision and Engineering 0 1744800
29 Maintenance of Structures O 467247
30 Maintenance of Boiler (or reactor)Plant 3347297 4583140
31 Maintenance of Electric Plant 1727806 1270232
32 Maintenance of Misc Steam (or Nuclear)Plant 1739998 1393234
33 Total Production Expenses 31017314 50922012
34 Expenses per Net KWh 0.0145 0.0219
35 Fuel:Kind (Coal,Gas,Oil,or Nuclear)Coal Oil Coal Oil
36 Unit (Coal-tons/Oil-barrel/Gas-mcf/Nuclear-indicate)Tons Barrel Tons Barrel
37 Quantity (units)of Fuel Burned 1577152 0 4696 1228738 0 7588
38 Avg Heat Cont -Fuel Burned (btulindicate if nuclear)8052 0 140000 10044 0 140131
39 Avg Cost of Fuellunit,as Delvd f.o.b.during year 12.566 0.000 34.688 28.836 0.000 38.491
40 Average Cost of Fuel per Unit Bumed 12.820 0.000 34.688 29.514 0.000 38.491
41 Average Cost of Fuel Bumed per Million BTU 0.796 0.000 5.899 1.469 0.000 6.540
42 Average Cost of Fuel Burned per KWh Net Gen 0.000 0.010 0.000 0.000 0.016 0.000
43 Average BTU per KWh Net Generation 0.000 11908.960 0.000 0.000 10646.135 0.000
F IRC I ORM NO.1 (ED.12-95)P ige 402.2
Nameof Respondent I his Report is:Date of Report Year of Report(1)An Original (Mo,Da,Yr)PacifiCorp (2)A Resubmission //Dec.31,2000
STEAM-ELECTRICGENERATINGPLANT STATlŠTICS (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 Load
Dispatching,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 plants
designed for peak load service.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 for
the report period and other physical and operating characteristics of plant.
Plant Plant Plant Line
Name:Craig Plant Name:Hayden Plant Name:James River No.
(d)(e)(f)
Steam Steam Steam 1
Outdoor Boiler Outdoor Boiler Outdoor Boiler 2
1979 1965 1996 3
1980 1976 1996 4
172.13 81.25 52.21 5
164 83 56 6
8784 8748 8469 7
0 0 0 8
165 78 52 9
0 0 0 10
300 111 21 11
1364959000 513145000 370435000 12
137086 129492 0 13
35116377 5033038 5733734 14
115244074 58547489 28682438 15
150497537 63710019 34416172 16
874.3249 784.1233 659.1874 17
208371 170012 0 18
16556032 5795372 0 19
0 0 0 20
960677 425060 0 21
0 0 5860255 22
0 0 0 23
342944 101178 0 24
1646775 924855 0 25
594 0 0 26
0 0 0 27
290299 180883 0 28
169534 109661 0 29
1407676 413555 0 30
289580 389343 0 31
281830 201872 0 32
22154312 8711791 5860255 33
0.0162 0.0170 0.0158 34
Coal Oil Coal Oil 35
Tons Barrel Tons Barrel 36
694499 0 1595 261608 0 709 0 0 0 37
10141 0 140000 10453 0 132599 O O 0 38
23.013 0.000 38.440 20.880 0.000 41.941 0.000 0.000 0.000 39
23.751 0.000 38.440 22.039 0.000 41.941 0.000 0.000 0.000 40
1.171 0.000 6.538 1.054 0.000 7.530 0.000 0.000 0.000 41
0.000 0.012 0.000 0.000 0.011 0.000 0.000 0.000 0.000 42
0.000 10326.468 0.000 0.000 10665.849 0.000 0.000 0.000 0.000 43
F ËRC FORM NO.1 (ED.12-88)Page 403.2
Name of Respondent I his Report is:Date of Report Year of Report
PacifiCorp R su
malssion (Mo/,Da,Yr)
Dec.31,2000
STEAM-ELECTRIC GENERATING PLANT STATISTICS (Large Plants)(Continued)
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 intemal 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 bumed (Line 37)and average cost
per unit of fuel bumed (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 bumed in a plant furnish only the composite heat rate for all fuels bumed.
Line item Plant Plant
No.Name:Hermiston Plant Name:Little Mountain
(a)(b)(c)
1 Kind of Plant (Internal Comb,Gas Turb,Nuclear Steam Gas -Turbine
2 Type of Constr (Conventional,Outdoor,Boiler,etc)Gas Turbine Outdoor Boiler
3 Year Originally Constructed 1996 1972
4 Year Last Unit was Installed 1996 1972
5 Total Installed Cap (Max Gen Name Plate Ratings-MW)237.00 16.00
6 Net Peak Demand on Plant -MW (60 minutes)254 0
7 Plant Hours Connected to Load 8721 0
8 Net Continuous Plant Capability (Megawatts)0 0
9 When Not Limited by Condenser Water 236 14
10 When Limitedby Condenser Water 0 0
11 Average Number of Employees 26 7
12 Net Generation,Exclusive of Plant Use -KWh 1941537000 0
13 Cost of Plant:Land and Land Rights 842245 635
14 Structures and Improvements 11019961 204044
15 EquipmentCosts 144144955 3254927
16 Total Cost 156007161 3459606
17 Cost per KW of installed Capacity (line 5)658.2581 216.2254
18 Production Expenses:Oper,Supv,&Engr -1 0
19 Fuel 41581536 95969
20 Coolants and Water (Nuclear Plants Only)0 0
21 Steam Expenses O O
22 Steam From Other Sources O O
23 Steam Transferred (Cr)0 0
24 Electric Expenses 7338875 0
25 Misc Steam (or Nuclear)Power Expenses 24240 0
26 Rents O O
27 Allowances O O
28 Maintenance Supervision and Engineering 0 0
29 Maintenance of Structures O O
30 Maintenance of Boiler (or reactor)Plant 0 0
31 Maintenance of Electric Plant 0 0
32 Maintenance of Misc Steam (or Nuclear)Plant 0 0
33 Total Production Expenses 48944650 95969
34 Expenses per Net KWh 0.0252 0.0000
35 Fuel:Kind (Coal,Gas,Oil,or Nuclear)Gas
36 Unit (Coal-tons/Oil-barrel/Gas-mcf/Nuclear-indicate)MCF
37 Quantity (units)of Fuel Bumed 0 13722889 0 0 0 0
38 Avg Heat Cont -Fuel Bumed (btulindicate if nuclear)0 1021 0 0 0 0
39 Avg Cost of Fuellunit,as Delvd f.o.b.during year 0.000 3.030 0.000 0.000 0.000 0.000
40 Average Cost of Fuel per Unit Burned 0.000 3.030 0.000 0.000 0.000 0.000
41 Average Cost of Fuel Burned per Million BTU 0.000 2.969 0.000 0.000 0.000 0.000
42 Average Cost of Fuel Bumed per KWh Net Gen 0.000 0.021 0.000 0.000 0.000 0.000
43 Average BTU per KWh Net Generation 0.000 7213.688 0.000 0.000 0.000 0.000
FERC DORM NO.1 (ED.12-95)Page 402.3
Name of Respondent I his Report Is:Date of Report Year of Report(1)An Original (Mo,Da,Yr)PacifiCorp (2)A Resubmission //Dec.31,2000
STEAM-ELECTRIC GENERATINGPLANT 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 Load
Dispatching,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 plants
designed for peak load service.Designate automatically operated plants.11.For a plant equipped with combinationsof 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 conceming plant type fuel used,fuel enrichment type and quantity for
the report period and other physical and operating characteristics of plant.
Plant Plant Plant Line
Narne:Hunter Unit No.1 Name:Hunter UnitNo.2 Name:Hunter Unit No.3 No.
(d)(e)(f)
Steam Steam Steam 1
Outdoor Boiler Outdoor Boiler Outdoor Boiler 2
1978 1980 1983 3
1978 1980 1983 4
442.97 284.96 495.57 5
411 261 464 6
7351 8156 8125 7
O 0 0 8
403 259 460 9
O O O 10
76 76 75 11
2722089000 1918169000 3430372000 12
9868916 9868916 9868916 13
59966532 49161664 88211628 14
202052812 138532740 382932945 15
271888260 197563320 481013489 16
613.7848 693.3019 970.6267 17
-39757 -39714 -39714 18
19713495 14302133 25240417 19
0 0 0 20
1527200 398506 1021748 21
0 0 0 22
0 0 0 23
0 0 0 24
774637 766117 895706 25
168 168 168 26
0 0 0 27
O O O 28
0 0 0 29
7205175 3753102 7426324 30
495521 200457 406865 31
122975 22933 131811 32
29799414 19403702 35083325 33
0.0109 0.0101 0.0102 34
Coal Oil Coal Oil Coal Oil 35
Tons Barrel Tons Barrel Tons Barre!36
1189403 0 4939 860448 0 2423 1525118 0 9215 37
12137 O 140000 12031 0 140000 11883 0 140000 38
16.540 0.000 39.428 16.540 0.000 41.079 16.540 0.000 39.892 39
16.411 0.000 39.428 16.506 0.000 41.079 16.309 0.000 39.892 40
0.676 0.000 6.706 0.686 0.000 6.986 0.686 0.000 6.784 41
0.000 0.007 0.000 0.000 0.008 0.000 0.000 0.007 0.000 42
0.000 10617.070 0.000 0.000 10801.103 0.000 0.000 10581.981 0.000 43
FERC FORMNO.1 (ED.12-88)Page 403.3
Name ot Respondent I his Repod is:Date of Report Year ot keport
PacifiCorp R su
malssion (Mo,Da,Yr)
Dec.31,2000
HYDROELECTRIC GENERATINGPLANTSTATISTICS (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.2420 FERC Licensed Project No.2401
No.Plant Name:Cutler Plant Name:Grace
(a)(b)(c)
1 Kind of Plant (Run-of-River or Storage)Storage Storage
2 Plant Construction type (Conventional or Outdoor)Conventional Conventional
3 Year Originally Constructed 1927 1908
4 Year Last Unit was Installed 1927 1923
5 Total installed cap (Gen name plate Rating in MW)30.00 33.00
6 Net Peak Demand on Plant-Megawatts (60 minutes)22 33
7 Plant Hours Connect to Load 6,071 8,784
9 (a)Under Most Favorable Oper Conditions 29 33
10 (b)Under the Most Adverse Oper Conditions 0 17
11 Average Number of Employees 3 18
12 Net Generation,Exclusive of Plant Use -Kwh 62,288,000 136,837,000
14 Land and Land Rights 3,511,587 48,432
15 Structures and Improvements 1,643,742 1,113,610
16 Reservoirs,Dams,and Waterways 6,990,436 7,535,795
17 Equipment Costs 1,642,430 3,165,923
18 Roads,Railroads,and Bridges 523,663 43,134
19 TOTAL cost (Total of 14 thru 18)14,311,858 11,906,894
20 Cost per KW of Installed Capacity (line 5)477.0619 360.8150
22 Operation Supervision and Engineering 318,798 350,678
23 Water for Power 0 0
24 Hydraulic Expenses 1,369 1,506
25 Electric Expenses O O
26 Misc Hydraulic Power Generation Expenses 556,561 723,997
27 Rents 26,700 30,112
28 Maintenance Supervision and Engineering 23,867 26,254
29 Maintenance of Structures O O
30 Maintenance of Reservoirs,Dams,and Waterways O O
31 Maintenance of Electric Plant -1,099 -1,209
32 Maintenance of Misc Hydraulic Plant -30,755 -33,830
33 Total Production Expenses (total 22 thru 32)895,441 1,097,508
34 Expenses per net KWh 0.0144 0.0080
EERC FORM NO.1 (ED.12-88)Page 406
Name of Respondent I his keport Is:Date of Report Year of Report(1)An Original (Mo,Da,Yr)PacifiCorp (2)A Resubmission //Dec.31,2000
HYDROELECTRICGENERATINGPLANTSTATlSTICS (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.596 FERC Licensed Project No.472 FERC Licensed Project No.20 LinePlantName:Olmsted PlantName:Oneida Plant Name:Soda No.(d)(e)(f)
Run-of-River Storage Storage 1
Conventional Conventional Conventional 2
1904 1915 1924 3
1922 1920 1924 4
10.30 30.00 14.00 5
8 23 7 6
8,282 8,784 7,510 7
7 28 14 9
2 28 4 10
2 2 4 11
27,350,000 44,194,000 24,601,000 12
2,790 36,698 515,170 14
247,210 1,201,802 572,786 15
208,730 4,426,072 4,987,430 16
19,160 2,994,903 2,072,224 17
3,547 370,214 0 18
481,437 9,029,689 8,147,610 19
46.7415 300.9896 581.9721 20
109,454 318,798 148,772 22
0 0 0 23
470 1,369 639 24
0 0 0 25
298,333 487,870 276,211 26
9,167 27,002 13,165 27
8,194 23,867 11,138 28
0 0 0 29
0 0 0 30
-377 -1,099 -513 31
-10,559 -30,755 -14,352 32
414,682 827,052 435,060 33
0.0152 0.0187 0.0177 34
FERC FORM NO.1 (ED.12-88)Page 407
Name of Respondent I his Report Is:Date of Report Year of Report
PacifiCorp R su
malssion (I ,Da,Yr)
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 FERCLicensed Project No.935 FERC Licensed Project No.2071
No.Plant Name:Merwin Plant Name:Yale
(a)(b)(c)
1 Kind of Plant (Run-of-River or Storage)Storage Storage
2 Plant Construction type (Conventional or Outdoor)Conventional Conventional
3 Year OriginallyConstructed 1931 1953
4 Year Last Unit was Installed 1958 1953
5 Total installed cap (Gen name plate Rating in MW)136.00 134.00
6 Net Peak Demand on Plant-Megawatts (60 minutes)149 170
7 Plant Hours Connect to Load 8,784 5,351
9 (a)Under Most Favorable Oper Conditions 144 134
10 (b)Under the Most Adverse Oper Conditions 95 99
11 Average Number of Employees O 0
12 Net Generation,Exclusive of Plant Use -Kwh 478,439,000[535,269,000
14 Land and Land Rights 981,076 1,434,708
15 Structures and Improvements 20,579,931 5,450,848
16 Reservoirs,Dams,and Waterways 9,004,709 26,028,393
17 Equipment Costs 10,475,828 13,641,224
18 Roads,Railroads,and Bridges 384,269 1,123,374
19 TOTAL cost (Total of 14 thru 18)41,425,813 47,678,547
20 Cost per KW of Installed Capacity (line 5)304.6016 355.8101
22 Operation Supervision and Engineering 511,104 504,168
23 Water for Power 0 0
24 Hydraulic Expenses 429,677 423,358
25 Electric Expenses O O
26 Misc Hydraulic Power Generation Expenses 1,322,991 600,074
27 Rents 53,694 52,535
28 Maintenance Supervision and Engineering 9,170 9,035
29 Maintenance of Structures O O
30 Maintenance of Reservoirs,Dams,and Waterways O O
31 Maintenance of Electric Plant 1,177 1,160
32 Maintenance of Misc Hydraulic Plant 339,156 334,168
33 Total Production Expenses (total 22 thru 32)2,666,969 1,924,498
34 Expenses per net KWh 0.0056 0.0036
FERCFORMNO.1 (ED.12-88)Page 406.1
Nameof Respondent I his Report is:Date of Repori Year of Report(1)An Original (Mo,Da,Yr)PacifiCorp (2)A Resubmission //Dec.31,2000O-
HYDROELECTRIC GENERATING PLANT STATlŠTICS(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,intemalcombustion engine,or gas turbine equipment.
FERC Licensed Project No.2111 FERCLicensed Project No.2082 FERC Licensed Project No.2082 LinePlantName:Swift No.1 Plant Name:Copco No.1 Plant Name:Copco No.2 No.(d)(e)(f)
Storage Storage Run-of-River!1
Conventional Conventional Conventional 2
1958 1918 1925 3
1958 1922 1925 4
240.00 20.00 27.00 5
248 26 30 6
5,691 6,273 6,241 7
264 26 30 9
140 26 26 10
0 0 0 11
609,872,000 118,970,000 134,456,000 12
6,780,711 190,388 20,914 14
5,382,626 1,164,748 1,545,887 15
37,258,277 2,429,719 2,746,995 16
11,834,543 4,757,314 4,267,973 17
395,145 105,442 240,200 18
61,651,302 8,647,611 8,821,969 19
256.8804 432.3806 326.7396 20
902,988 89,344.120,615 22
0 0 0 23
758,254 912 1,231 24
0 0 0 25
435,836 505,922 780,315 26
94,194 23,021 33,024 27
16,182 19,056 25,725 28
0 0 0 29
0 0 0 30
2,077 8,222 11,099 31
598,510 153,823 207,661 32
2,808,041 800,300 1,179,670 33
0.0046 0.0067 0.0088 34
FERC FORMNO.1 (ED.12-88)Page 407.1
Name of Respondent I his keport Is:Date of Report Year of Report
PacifiCorp R su
malssion (Mo/,Da,Yr)
Dec.31,2000
HYDROELECTRICGENERATINGPLANT 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 FERCLicensed Project No.2082 FERC Licensed Project No.2082
No.Plant Name:John C.Boyle Plant Name:Iron Gate
(a)(b)(c)
1 Kind of Plant (Run-of-River or Storage)Storage Storage
2 Plant Construction type (Conventional or Outdoor)Outdoor Outdoor
3 Year Originally Constructed 1958 1962
4 Year Last Unitwas Installed 1958 1962
5 Total installed cap (Gen name plate Rating in MW)79.99 18.00
6 Net Peak Demand on Plant-Megawatts (60 minutes)90 20
7 Plant Hours Connect to Load 6,989 8,485
9 (a)Under Most Favorable Oper Conditions 90 20
10 (b)Under the Most Adverse Oper Conditions 82 20
11 Average Numberof Employees O O
12 Net Generation,Exclusive of Plant Use -Kwh 368,405,000 122,465,000
14 Land and Land Rights 129,807 341,706
15 Structures and Improvements 2,230,957 3,603,836
16 Reservoirs,Dams,and Waterways 10,285,392 8,362,010
17 Equipment Costs 6,733,720 1,361,499
18 Roads,Railroads,and Bridges 604,730 638,679
19 TOTAL cost (Total of 14 thru 18)19,984,606 14,307,730
20 Cost per KW of Installed Capacity (line 5)249.8388 794.8739
22 Operation Supervision and Engineering 357,794 80,410
23 Water for Power 0 0
24 Hydraulic Expenses 3,647 821
25 Electric Expenses O O
26 Misc Hydraulic Power Generation Expenses 540,956 450,720
27 Rents 7,204 20,989
28 MaintenanceSupervision and Engineering 39,829 17,150
29 Maintenanceof Structures O 0
30 Maintenanceof Reservoirs,Dams,and Waterways O O
31 Maintenanceof Electric Plant 2,193 7,400
32 Maintenanceof Misc Hydraulic Plant 3,582 138,440
33 Total Production Expenses (total 22 thru 32)955,205 715,930
34 Expenses per net KWh 0.0026 0.0058
i ERC FORMNO.1 (ED.12-88)Page 406.2
Name of Respondent I his keport is:Date ot keport Year of Report
PacifiCorp R u
malssion (Mo/,Da,Yr)
Dec.31,2000
HYDROELECTRICGENERATINGPLANT 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.1927 FERC Licensed Project No.1927 FERC Licensed Project No.1927 LinePlantName:Soda Springs Plant Name:Slide Creek Plant Name:Fish Creek No.(d)(e)(f)
Run-of-River Run-of-River Run-of-River 1
Outdoor Outdoor Outdoor 2
1952 1951 1952 3
1952 1951 1952 4
11.00 18.00 11.00 5
13 19 13 6
8,488 8,754 6,177 7
12 18 12 9
12 17 12 10
0 0 0 11
70,890,000 104,304,000|62,442,000 12
0 0 0 14
811,726 607,138 557,744 15
3,467,419 3,753,383 5,759,697 16
1,045,759 1,140,398 658,974 17
25,845 16,778 409,412 18
5,350,749 5,517,697 7,385,827 19
486.4317 306.5387 671.4388 20
85,693 140,226 85,693 22
0 0 0 23
502 821 502 24
0 0 0 25
123,513 183,336 136,540 26
992 1,623 992 27
18,365 30,051 18,365 28
0 0 0 29
0 0 0 30
8,174 13,376 8,174 31
25,461 41,664 25,461 32
262,700 411,097 275,727 33
0.0037 0.0039 0.0044 34
FERC FORM NO.1 (ED.12-88)Page 407.2
Name of Respondent I his Report Is:Date ot keport Year of Report
PacifiCorp R u
malssion (Mo,Da,Yr)Dec.31,2000
HYDROELECTRICGENERATING PLANTSTATISTICS (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.1927 FERC Licensed Project No.1927
No-Plant Name:Clearwater No.1 Plant Name:Clearwater No.2
(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 1953 1953
4 Year Last Unit was Installed 1953 1953
5 Total installed cap (Gen name plate Rating in MW)15.00 26.00
6 Net Peak Demand on Plant-Megawatts (60 minutes)14 23
7 Plant Hours Connect to Load 7,452 8,363
9 (a)Under Most Favorable Oper Conditions 15 26
10 (b)Under the Most Adverse Oper Conditions 12 26
11 Average Number of Employees O O
12 Net Generation,Exclusive of Plant Use -Kwh 60,762,000 71,149,000
14 Land and Land Rights O 0
15 Structures and Improvements 559,122 752,235
16 Reservoirs,Dams,and Waterways 3,231,528 8,928,212
17 EquipmentCosts 912,368 114,127
18 Roads,Railroads,and Bridges 0 219,901
19 TOTAL cost (Total of 14 thru 18)4,703,018 10,014,475
20 Cost per KW of Installed Capacity (line 5)313.5345 385.1721
22 Operation Supervision and Engineering 116,855 202,548
23 Water for Power 0 0
24 Hydraulic Expenses 684 1,185
25 Electric Expenses O O
26 Misc Hydraulic Power Generation Expenses 196,283 274,696
27 Rents 1,352 2,344
28 Maintenance Supervision and Engineering 25,043 43,407
29 Maintenance of Structures O O
30 Maintenance of Reservoirs,Dams,and Waterways O O
31 Maintenance of Electric Plant 11,147 19,321
32 Maintenance of Misc Hydraulic Plant 34,720 60,181
33 Total Production Expenses (total 22 thru 32)386,084 603,682
34 Expenses per net KWh 0.0064 0.0085
I ERC FORM NO.1 (ED.12-88)Page 406.3
Name of Respondent I his keport Is:LJate ot Report Year of Report(1)An Original (Mo,Da,Yr)PacifiCorp (2)A Resubmission //Dec.31,2000
HYDROELECTRICGENERATINGPLANT 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.1927 FERC Licensed Project No.1927 FERC Licensed Project No.1927 LinePlantName:Lemolo No.1 Plant Name:Lemolo No.2 Plant Name:Toketee No.(d)(e)(f)
Run-of-River Run-of-River Conventional 1
Outdoor Outdoor Outdoor 2
1955 1956 1950 3
1955 1956 1950 4
29.00 33.00 42.50 5
28 35 46 6
8,676 8,5141 8,776 7
29 35 42 9
23 33 42 10
0 0 0 11
162,969,000 203,335,000 256,380,000 12
0 0 0 14
707,812 688,448 1,429,228 15
7,508,090 14,346,986 6,271,942 16
3,046,960 1,932,948 2,504,050 17
407,171 993,032 111,245 18
11,670,033 17,961,414 10,316,465 19
402.4149 544.2853 242.7404 20
225,919 i 257,080 331,096|22
0 0 0 23
1,322 1,505 1,938 24
0 0 0 25
352,850 330,415 334,996 26
2,615 3,350 4,282 27
48,416 55,094 70,956 28
0 0 0 29
0 0 0 30
21,551 24,523 31,583 31
67,125 84,187 98,375 32
719,798 756,154 873,226 33
0.0044 0.0037 0.0034 34
PERC FORMNO.1 (ED.12-88)Page 407.3
Name of Respondent I his Report is:Date of Report Year of Report
PacifiCorp R u
malssion (Mo/,Da,Yr)
Dec.31,2000
HYDROELECTRIC GENERATINGPLANT 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 FERCLicensed Project No.2630 FERC Licensed Project No-0
No.Plant Name:Prospect No.2 Plant Name:
(a)(b)(c)
1 Kind of Plant (Run-of-River or Storage)Run-of-River
2 Plant Construction type (Conventional or Outdoor)Conventional
3 Year Originally Constructed 1928
4 Year Last Unit was Installed 1928
5 Total installed cap (Gen name plate Rating in MW)32.00 0.00
6 Net Peak Demand on Plant-Megawatts (60 minutes)38 0
7 Plant Hours Connect to Load 8,784 0
9 (a)Under Most Favorable Oper Conditions 36 0
10 (b)Under the Most Adverse Oper Conditions 26 0
11 Average Number of Employees 6 0
12 Net Generation,Exclusive of Plant Use -Kwh 259,612,000 0
14 Land and Land Rights 105,168 0
15 Structures and Improvements 1,984,210 0
16 Reservoirs,Dams,and Watenways 4,787,270 0
17 Equipment Costs 2,517,146 0
18 Roads,Railroads,and Bridges 170,902 0
19 TOTAL cost (Total of 14 thru 18)9,564,696 0
20 Cost per KW of installed Capacity (line 5)298.8968 0.0000
22 Operation Supervision and Engineering 143,123 0
23 Water for Power 0 0
24 Hydraulic Expenses 1,459 0
25 Electric Expenses O 0
26 Misc Hydraulic Power Generation Expenses 792,904 0
27 Rents 24,504 0
28 Maintenance Supervision and Engineering 26,242 0
29 Maintenance of Structures O O
30 Maintenance of Reservoirs,Dams,and Waterways O O
31 Maintenance of Electric Plant 139,157 0
32 Maintenance of Misc Hydraulic Plant -2,648 0
33 Total Production Expenses (total 22 thru 32)1,124,741 0
34 Expenses per net KWh 0.0043 0.0000
FERC FORM NO.1 (ED.12-88)Page 406.4
Name of Respondent I his Report is:Date of Report Year ot Report
PacifiCorp R u
malssion (Mo,Da,Yr)
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.O FERCLicensed Project No.O FERC Licensed Project No.O LinePlantName:Plant Name:Plant Name:No.(d)(e)(f)
1
2
3
4
0.00 0.00 0.00 5
0 0 0 6
0 0 0 7
0 0 0 9
0 0 0 10
0 0 0 11
0 0 Op 12
0 0 0 14
0 0 0 15
0 0 0 16
0 0 0 17
0 0 0 18
0 0 0 19
0.0000 0.0000 0.0000 20
0 0 0 22
0 0 0 23
0 0 0 24
0 0 0 25
0 0 0 26
0 0 0 27
O O O 28
0 0 0 29
0 0 0 30
0 0 0 31
0 0 0 32
0 0 0 33
0.0000 0.0000 0.0000 34
ERC FORMNO.1 (ED.12-88)Page 407.4
Name of Respondent I his Report Is:Date ot kepod Year of keport
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
U-NERAIINGPLANI blAllbllub(bmall Plants)
1.Srnall generating plants are steam plants of,less than 25,000 Kw;intemal combustion and gas turbine-plants,conventional hydro plants and pumped
storade 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 F3deral 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 Name of Plant Oea le a e eg Net nderation Cost of Plant
o.Const-(In MW)MW Plant Unse
(a)(b)(c)(60 In.)(e)(f)
1 Hydro Plants:Licensed Proj No.
2 American Fork 696 1907 0.95 1.0 5,860 936,920
3 Ashton 2381 1917 6.85 7.4 40,610 8,760,593
4 Beaver -Upper 814 1907 2.52 2.3 9,669 2,478,735
5 Bend 2643 1913 1.11 2.0 5,249 825,371
6 Bigfork 2652 1910 4.15 4.0 13,021 3,262,751
7 Cline Falls 1913 1.00 1.0 2,955 266,366
8 Condit 2342 1913 9.60 16.0 90,723 6,777,731
9 Cove 2401 1917 7.50 7.0 21,771 2,067,958
10 Drop 1914 1.40 1.1 7,432 381,176
11 Eagle Point 1957 2.81 3.0 18,384 1,555,101
12 East Side 2082 1924 3.20 3.0 14,211 1,797,772
13 Fall Creek 2082 1903 2.20 2.0 11,584 948,722
14 Fountain Green 1922 0.16 0.2 984 440,817
15 Granite 1896 2.00 1.3 6,227 4,377,009
16 Gunlock 1917 0.75 0.6 1,377 481,400
17 Keno Regulating Dam 7,493,171
18 Last Chance 4580 1983 1.73 1.4 5,914 2,497,399
19 Naches 1909 6.37 6.0 27,789 9,774,067
20 North Umpqua 8,446,972
21 Paris 703 1910 0.72 0.8 2,028 309,081
22 Pioneer 2722 1897 5.00 5.3 16,601 9,400,969
23 Powerdale 2659 1923 6.00 7.0 29,669 13,576,596
24 Prospect No.1 2630 1912 3.76 5.0 26,993 539,021
25 Prospect No.3 2337 1932 7.20 8.0 44,087 6,797,687
26 Prospect No.4 2630 1944 1.00 1.0 5,253 184,245
27 Sand Cove 1926 0.80 0.6 1,174 842,890
28 Snake Creek 1910 1.18 0.5 2,520 886,912
29 Stairs 597 1895 1.00 1.6 5,299 1,156,616
30 St.Anthony 2381 1915 0.50 0.6 2,902 1,249,159
31 Upper Klamath Lake 3,701,020
32 Veyo 1920 0.50 0.3 284 719,316
33 Viva Naughton 1986 0.74 0.6 815 1,154,968
34 Wallowa Falls 308 1921 1.10 1.8 6,813 2,710,291
35 Weber 1744 1911 3.85 4.0 18,239 2,447,502
36 West Side 2082 1908 0.60 1.0 3,475 321,524
37
38
39
40 PumpingPlant
41 Lifton 1917 -4,347 10,447,023
42
43
44
45
46
FERC FORM NO.1 (ED.12-87)Page 410
Name of Respondent i nis Report is:L)ate of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
GENERAI INO PLAN I b I A I lb l 108 (bmall 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 Óperation Produdtion i-xpenses Fuel Costs (in cents LinInstCapacityExc'l.Fuel 1-uel tvlaintenance Kind of Fuel (per Million Btu)No(g)(h)(i)(j)(k)(1)
1
986,232 77,437 -253 2
1,278,919 331,374 -1,824 3
983,625 160,536 -671 4
743,578 104,230 819 5
786,205 -5,403 3,220 6
266,366 36,557 737 7
657,707 382,327 16,929 8
275,728 231,567 -1,997 9
272,269 10
553,417 95,266 14,307 11
561,804 85,826 1,824 12
431,237 98,3Š9 19,921 13
2,755,104 10,003 -43 14
685,868 160,765 -532 15
641,867 62,416 -200 16
-1,833 17
1,443,583 92,41 -462 18
1,534,361 220,013 11,233 19
20
429,279 42,198 -190 21
1,872,961 224,219 -1,331 22
2,262,599 161,481 4,424 23
143,357 99,200 19,123 24
944,123 133,408 36,619 25
184,246 4Ò,914 5,086 26
1,053,613 5Ž,486 -213 27
751,620 10Ò,260 -314 28
1,156,616 125,027 -266 29
2,498,318 6Š,97Ž -133 30
13,7Ò5 31
1,438,632 59,091 -133 32
1,560,767 44,719 33
2,463,901 30,518 811 34
635,715 193,450 -1,025 35
535,874 72,015 342 36
37
38
39
40
177,165 41
42
43
44
45
46
·ERC FORM NO.1 (ED 12-87)Page 411
Name ot kespondent I his Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
IRANbMIbbluNLINEblAllbl Ob
1.Report information conceming 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 mileageof 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 IJealbWAlluN vuLIAbetKv)Lbl Fole iles)(Indicate wiiere Type of base NumberNo.other than u ergrc uria I nes
60 cycle,3 ph ise)Supporting report cir ,uit miles)Of
uri otructure uti iuotuie6 CircuitsFromToOperatingDesignedStructureOf.Line of riotherDesignatedine(a)(b)(c)(d)(e)(f)(g)(h)
1 Malin,Oregon Indian Springs.,CA 500.0C 500.00 Stee1Tower 47.00 1
2 Midpoint,Idaho Malin,Oregon 500.0C 500.00 Stee1Tower 446.00 1
3 Malin,Oregon Medford,Oregon 500.0C 500.00 Steel Tower 83.00 1
4 Centrâlia Plant #1,WA BPA Paul,Washington 500.0C 500.00 Steel Tower 1.00 1
5 Centralia Plant #2,WA BPA Paul,Washington 500.0C 500.00 Steel Tower 1.00 1
6 Alvey Sub,Oregon Dixonville Sub,Oregon 500.0(500.00 Steel Tower 58.00 1
7 Malin,Oregon Captain Jack,OR 500.0C 500.00 Steel Tower 7.00 1
8 Dixonville,Oregon Meridian,OR 500.0(500.00 Steel Tower 74.00 1
9
10 Ben Lomond Sub.,Utah Borah Substation,Idaho 345.0C 345.00 Steel -H 134.00 1
11 Ben Lomond Sub.,Utah Terminal Substation,UT 345.00 345.00 Steel -D 47.00 2
12 Spanish Fork Sub.,Utah CampWilliams Sub.,Utah 345.0E 345.00 Steel-SP 35.00 2
13 Huntington Plant,Utah Sigurd Substation,Utah 345.0C 345.00 Steel -H 86.00 1
14 Huntington Plt.Sub.,UT Spanish Fork Sub.,Utah 345.0C 345.00 Steel -H 78.00 1
15 Terminal Substation,UT Ninety South Sub.,Utah 345.0C 345.00 Steel -SP 15.00 2
16 Emery Substation,Utah Sigurd Substation,Utah 345.0C 345.00 Steel -H 68.00 1
17 Sigurd Substation,Utah Camp Williams Sub.,Utah 345.0C 345.00 Steel-H-P 116.00 1
18 Camp Williams Sub.,Utah Ninety South Sub.,Utah 345.0(345.00 Steel -SP 8.00 2
19 Terminal Substation,UT Camp Williams Sub.,Utah 345.0C 345.00 Steel-D 25.00 1
20 Emery Substation,Utah Camp Williams Sub.,Utah 345.0(345.00 Steel-H 86.00 1
21 Newcastle,Utah Utah -Nevada Border 345.00 345.00 Steel -D 54.00 1
22 Sigurd Substation,Utah Newcastle,Utah 345.00 345.00 Steel -D 137.00 1
23 Goshen Substation,Idaho Kinport Substation,ID 345.0C 345.00 Steel-H 41.00 1
24 Huntington Plant,Utah Four Comers Sub.,NM 345.0C 345.00 Wood -U 55.00 1
25 Camp Williams Sub.,Utah Huntington Plant,Utah 345.0C 345.00 Wood -U 152.00 1
26 Huntington Plant,Utah Pinto Substation,Utah 345.0C 345.00 Wood -U 156.00 1
27 Camp Williams Sub.,Utah Sigurd Substation,Utah 345.0(345.00 Wood -U 111.00 1
28 Jim Bridger Plant #3,WY Borah Substation,Idaho 345.0C 345.00 Steel Tower 240.00 1
29 Jim Bridger Plant#2,WY Kinport Substation,ID 345.0C 345.00 Steel Tower 234.00 1
30
31 Fairview,Oregon Isthmus,Oregon 230.0C 230.00 H Frame Wood 12.00 1
32 Antelope Sub.,idaho Lost River 230KV Line,ID 230.00 230.00 Wood -H 20.00 1
33 Walla Walla,Washington Hells Canyon,1D 230.0C 230.00 H Frame Wood 72.00 1
34 Bethel,Oregon Fry,Oregon 230.0C 230.00 H Frame Wood 26.00 1
35 Fry,Oregon Dixonville,Oregon 230.0C 230.00 H Frame Wood 44.00 1
36 I U I AL 14,862.00 100.00 186
FERC FORM NO.1 (ED.12-87)Page 422
Name of Respondent I his Report is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
i RANbMlbbiuN LINE-b lAI lb I108 (Gontinued)
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 the
arrangement and giving particulars (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 (l)on the book cost at end of year.
Dub i Ur Lilm-(Include in bolut'nn 0)Land,EXPENSES,EXCEPT DEPRECIATIONAND TAXES
Size of Land rights,and clearing right-of-way)
Conductor
and Material Land Construction and Total Cost Operation Maintenance Rents Total LineOtherCostsExpensesExpensesExpenses
(i)(j)(k)(I)(m)(n)(0)(p)No.
2-1852 134,35E 4,416,172 4,550,528 1
1272.0 3,109,688 150,594,765 153,704,453 2
1272.0 2,907,175 38,143,310 41,050,485 3
1780.0 4
1780.0 5
1272.0 1,381,912 20,171,022 21,552,934 6
1272.0 9,226 1,455,664 1,464,893 7
1272.0 4,882,242 25,405,882 30,288,125 8
9
954.0 5,298,306 35,010,252 40,308,560 10
1272.0 10,057,366 21,789,991 31,847,357 11
1272.0 6,069,82E 10,158,595 16,228,424 12
954.0 318,831 20,042,861 20,361,692 13
954.0 791,811 17,665,937 18,457,748 14
1272.0 2,615,56C 7,457,557 10,073,117 15
954.0 281,834 13,580,607 13,862,441 16
954.0 510,49C 19,733,876 20,244,366 17
1272.0 497,77E 3,895,713 4,393,492 18
1272.0 4,357,236 7,964,678 12,321,916 19
954.0 926,211 27,916,176 28,842,387 20
954.0 2,320,872 50,294,434 52,615,307 21
954.0 56,02E 13,548,540 13,604,569 22
795.0 313,477 2,565,555 2,879,032 23
954.0 117,662 2,618,232 2,735,894 24
795.0 887,90C 18,107,268 18,995,168 25
795.0 26
795.0 84,952 9,750,779 9,835,738 27
1272.0 1,128,222 26,192,950 27,321,172 28
1272.0 1,099,79E 27,995,064 29,094,860 29
30
954.0 285,322 1,310,266 1,595,588 31
795.0 12,92E 1,195,831 1,208,760 32
1272.0 54,442 7,273,134 7,327,577 33
1272.0 351,982 1,136,646 1,488,628 34
1272.0 485,896 3,215,605 3,701,501 35
78,485,365 1,279,390,372 1,357,875,737 36
FERC FORM NO.1 (ED.12-87)Page 423
Name of kespondent I his Repod Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
IRANbMlbblUN LINEblAIIbl Ub
1.Report information conceming 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 DEolbNAI luN vULIabE (Kv)y Le Pole miles)(Indicate where ype of Ése of NumberNo.other than u ergrouna lines
60 cycle,3 phase)Supporting _
report circuit miles)Of
uli cauuule vil ui >CircuitsFromToOperatingDesignedStructureofLineoferDeslanatedine(a)(b)(c)(d)(e)(f)(g)(h)
1 Alvey,Oregon Dixonville,Oregon 230.0C 230.00 H Frame Wood 59.00 1
2 Troutdale,Oregon Linneman,Oregon 230.0(230.00 Steel Tower 6.00 1
3 Troutdale,Oregon Gresham,Oregon 230.00 230.00 Steel Tower 6.00 1
4 McNary,Washington Walla Walla,Washington 230.0C 230.00 H Frame Wood 56.00 1
5 Sigurd Substation,Utah Garfield,Utah 230.0(230.00 Wood-U 118.00 1
6 Dixonville,Oregon Reston,Oregon 230.0C 230.00 H Frame Wood 17.00 1
7 Yamsey,Oregon Klamath Falls,Oregon 230.00 230.00 H Frame Wood 56.00 1
8 Yamsey,Oregon Klamath Falls,Oregon 230.0C 230.00 Steel Tower 6.00 1
9 Dixonville,Oregon Lone Pine,Oregon 230.00 230.00 H Frame Wood 5.00 1
10 Klamath Falls,Oregon Medford,Oregon 230.0(230.00 H Frame Wood 76.00 1
11 Klamath Falls,Oregon Malin,Oregon 230.0(230.00 H Frame Wood 35.00 1
12 Table Rock,SW Station,OR Grants Pass,Oregon 230.0C 230.00 H Frame Wood 35.00 1
13 Grants Pass,Oregon Days Creek,Oregon 230.0C 230.00 H Frame Wood 71.00 1
14 Sigurd Substation,Utah Pavant Substation,Utah 230.0C 230.00 Wood -U 43.00 1
15 Pavant Substation,Utah Nevada -Utah State line 230.0C 230.00 Wood -U 98.00 1
16 Bannack Pass,Idaho Antelope Sub.,Idaho 230.0C 230.00 Wood -U 76.00 1
17 Brady Substation,Idaho Treasureton Sub.,Idaho 230.0C 230.00 Wood -U 66.00 1
18 Ben Lomond Sub.,Utah Naughton Plt.#1,WY 230.0C 230.00 Wood -U 88.00 1
19 Sigurd Substation,Utah Arizona -Utah State line 230.0C 230.00 Wood -U 149.00 1
20 Birch Creek Sub.,WY Railroad Substation,WY 230.0C 230.00 Wood -HSW 12.00 1
21 Birch Creek Sub.,WY Railroad Substation,WY 230.0C 230.00 Wood -HSW 7.00 1
22 Ben Lomond Sub.,Utah Naughton Pit.#2,WY 230.0C 230.00 Wood -U 50.00 1
23 Ben Lomond Sub.,Utah Naughton PIt.#2,WY 230.0(230.00 Wood -U 29.00 1
24 Chappel Creek,WY Naughton Plant,WY 230.0(230.00 Wood Tower 46.00 1
25 Ben Lomond Sub.,Utah Terminal Substation,UT 230.0E 230.00 Steel -D-P 46.00 1
26 Naughton Plant,Wyoming Treasureton Sub.,Idaho 230.0C 230.00 Wood-U 78.00 1
27 Naughton Plant,Wyoming Treasureton Sub.,Idaho 230.0C 230.00 Wood-U 1.00 1
28 Swift Plant #1,WA Cowlitz Co.Line,WA 230.0C 230.00 H Frame Wood 2.00 1
29 Swift Plant #2,WA BPA Woodland,WA 230.0C 230.00 H Frame Wood 23.00 1
30 Union Gap,Washington BPA Midway,WA 230.0C 230.00 H Frame Wood 39.00 1
31 Walla Walla,Washington Lewiston,ID 230.0C 230.00 H Frame Wood 45.00 1
32 Walla Walla,Washington Wanapum,Washington 230.0C 230.00 H Frame Wood 33.00 1
33 Pomona,Washington Wanapum,Washington 230.0C 230.00 H Frame Wood 37.00 1
34 Centralia,Washington BPA Tap,Washington 230.0C 230.00 H Frame Wood 3.00 1
35 Pomona,Washington Wanapum,Washington 230.0C 230.00 H Frame Wood 8.00 1
36 lut AL 14,862.00 100.00 186
FERC FORM NO.1 (ED.12-87)Page 422.1
Name of Respondent I his Report is:Date of Report Ÿear of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
I MANbMlbblUN LINI-8 I Al Ib I Ibb (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 the
arrangement and giving particulars (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.
LUb i UI-LINt-(Include in bolumn (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)(0)(p)No.
954.0 1,428,247 13,290,734 14,718,981 1
954.0 413,491 413,491 2
954 .0 368,846 409,801 778,647 3
1272.0 64,434 1,222,329 1,286,763 4
795.0 390,876 7,597,210 7,988,088 5
39,971 942,038 982,009 6
795.0 7
795.0 247,092 3,464,513 3,711,606 8
795.0 397,687 2,845,689 3,243,376 9
795.0 173,608 5,627,891 5,801,499 10
1272.0 115,44E 1,544,163 1,659,611 11
954.0 191,124 3,750,526 3,941,650 12
1272.0 379,961 9,736,318 10,116,279 13
795.0 41,06C 4,295,760 4,336,820 14
795.0 15
1272.0 5,102 2,402,452 2,407,555 16
795.0 72,118 1,853,261 1,925,379 17
795.0 420.405 3,436,856 3,857,265 18
954.0 22,604 4,349,733 4,372,337 19
954.0 345,11E 1,097,508 1,442,627 20
954.0 181,047 1,487,637 1,668,684 21
1272.0 736,02E 4,312,907 5,048,936 22
1272.0 5,717 1,292,208 1,297,925 23
954.0 170,967 5,900,151 6,071,118 24
1272.0 572,45E 9,753,573 10,326,032 25
954.0 56,49E 1,955,283 2,011,781 26
954.0 56E 27,749 28,318 27
954.0 1,292 174,634 175,927 28
954.0 103,531 1,710,390 1,813,921 29
1272.0 130,737 1,567,695 1,698,432 30
1272.0 366,29C 2,657,369 3,023,659 31
954.0 235,532 1,353,911 1,589,443 32
1780.0 205,171 2,640,020 2,845,191 33
954.0 21,50C 105,180 126,680 34
556.5 16E 1,334,252 1,334,421 35
78,485,365 1,279,390,372 1,357,875,737 36
FERC FORMNO.1 (ED.12-87)Page 423.1
Nameof Respondent I his Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
lRANbMlbbluN LIldt-blAI18I US
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 reportsubstationcostsandexpensesonthispage.
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 theremainderoftheline.
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 Ut,>IONA l lUN v dL I Abe v )y Lbl gole miles)(Indicate where ype o ase of NumberNo.other than u rgrc una lines60cycle,3 phase)Supporting report cir:uit rniles)Of
Uli ,MlULLUld Ull Ules CircuitsFromToOperatingDesignedStructureof.Line of erDesignatedine(a)(b)(c)(d)(e)(f)(g)(h)
1 Billings,Montana Yellowtail,Montana 230.0(230.00 H Frame Wood 39.00 1
2 Yellowtail,Montana Muddy Ridge,Wyoming 230.0C 230.00 H Frame Wood 176.00 1
3 Sheridan,Wyoming Decker,Montana 230.0C 230.00 H Frame Wood 14.00 1
4 Dave Johnston Plant,Wyomig Casper,Wyoming 230.0C 230.00 H Frame Wood 31.00 1
5 Yellowtail,Montana Casper,Wyoming 230.0C 230.00 H Frame Wood 169.00 1
6 Rock Springs,Wyoming Kemmerer,Wyoming 230.0C 230.00 H Frame Wood 71.00 1
7 Rock Springs,Wyoming Atlantic City,Wyoming 230.0C 230.00 H Frame Wood 69.00 1
8 Thermopolis,Wyoming Riverton,Wyoming 230.0C 230.00 H Frame Wood 51.00 1
9 Casper,Wyoming Riverton,Wyoming 230.0C 230.00 H Frame Wood 110.00 1
10 Dave Johnston Plant,WY Rock Springs,Wyoming 230.0E 230.00 H Frame Wood 233.00 1
11 Dave Johnston Plant,WY Spence,Wyoming 230.0C 230.00 H Frame Wood 31.00 1
12 Riverton,Wyoming Atlantic City,Wyoming 230.00 230.00 H Frame Wood 50.00 1
13 Rock Springs,Wyoming FlamingGorge,Utah 230.0C 230.00 H Frame Wood 48.00 1
14 Palisades,Wyoming Green River,Wyoming 230.0C 230.00 H Frame Wood 9.00 1
15 Buffalo,Wyoming Gillette,Wyoming 230.0(230.00 H Frame Wood 68.00 1
16 Jim Bridger Plant,WY Point of Rocks,Wyoming 230.00 230.00 H Frame Wood 4.00 1
17 Dave Johnston Plant,WY Yellowcake,Wyoming 230.0C 230.00 H Frame Wood 69.00 1
18 Jim Bridger Plant,WY Point of Rocks Ln 2,WY 230.0C 230.00 H Frame Wood 8.00 1
19 Blue Rim,Wyoming South Trona,Wyoming 230.0C 230.00 H Frame Wood 13.00 1
20 Monument,Wyoming Exxon Plant,Wyoming 230.0C 230.00 H Frame Wood 13.00 1
21 Firehole,Wyoming Mansface,Wyoming 230.0(230.00 Steel Pole 2.00 1
22 Firehole,Wyoming Mansface,Wyoming 230.0C 230.00 H Frame Wood 10.00 1
23 Monuments,Wyoming South Trona,Wyoming 230.0C 230.00 H Frame Wood 19.00 1
24 Jim Bridger Plant,WY Mustang Sub.,Wyoming 230.0C 230.00 H Frame Wood 73.00 1
25 Spence Sub.,Wyoming Mustang Sub.,Wyoming 230.0C 230.00 H Frame Wood 77.00 1
26 Rock Springs,Wyoming Flaming Gorge,Utah 230.0C 230.00 Steel Tower 7.00 127Line59,CA Copco II,CA 230.0C 230.00 H Frame Wood 5.00 1
28
29 Montana-IdahoState line Grace Plant,Idaho 161.0C 161.00 Wood -H 57.00 90.00 1
30 Goshen Substation,Idaho Rigby Substation,Idaho 161.0C 161.00 Wood -H 29.00 1
31 Goshen Substation,Idaho Antelope Substation,ID 161.0C 161.00 Wood -H 45.00 1
32 Goshen Substation,Idaho Sugar Mill Substation,ID 161.0C 161.00 Wood -SP 16.00 1
33 Sugar Mill Sub.,Idaho Rigby Substation,Idaho 161.0C 161.00 Wood -SP 17.00 134GoshenSubstation,idaho Bonneville Sub.,Idaho 161.0C 161.00 Wood -SP-H 23.00 1
35 Billings,Montana Yellowtail,Montana 161.0C 161.00 H Frame Wood 46.00 1
36 I U i AL 14,862.00 100.00 186
FERC FORMNO.1 (ED.12-87)Page 422.2
Name of Respondent I his Report is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
I RANSMlbbluN LINE bl A I lb I lub (Gontmued)
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 the
arrangement and giving particulars (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 bome 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 (1)on the book cost at end of year.
LUb I UI-Llle (incluae m Golumn 0)Land,EXPENSES,EXCEPT DEPRECIATIONAND TAXES
Size of Land rights,and clearing right-of-way)
Conductor
and Material Land Construction and Total Cost Operation Maintenance Rents Total LineOtherCostsExpensesExpensesExpenses(i)(j)(k)(I)(m)(n)(0)(p)No.
1272.0 32,996 1,446,800 1,479,798 1
1272.0 120,94E 5,055,094 5,176,043 2
1272.0 26,092 559,444 585,537 3
795.0 14,928 846,933 861,861 4
1271.0 130,197 5,364,748 5,494,945 5
1271.0 52,90E 2,131,926 2,184,832 6
954.0 31,85E 1,644,995 1,676,854 7
1272.0 57,112 1,561,658 1,618,770 8
954.0 67,857 3,223,884 3,291,741 9
1272.0 58,102 8,372,050 8,430,152 10
1272 17,91C 2,658,898 2,676,808 11
1271.0 41,154 1,728,582 1,769,736 12
1272.0 30,76E 1,637,634 1,668,403 13
1272.0 11 627,422 627,433 14
1272.0 14,42E 4,195,868 4,210,296 15
1272.0 4,80C 134,061 138,861 16
1272.0 294,29E 5,933,408 6,227,698 17
1272.0 3,967 439,682 443,649 18
1272.0 847,677 847,677 19
1272.0 160,129 160,129 20
1272.0 21
1272.0 2,661,277 2,661,277 22
1272.0 2,707,965 2,707,965 23
1272.0 9,760,523 9,760,523 24
1272.0 9,508,067 9,508,067 25
1272.0 4,482 320,875 325,357 26
Hmmmmm 4,33E 726,970 731,309 27
28
397.5 18,97E 1,083,716 1,102,694 29
397.5 27,520 462,741 490,261 30
397.5 8,857 2,197,100 2,205,957 31
397.5 48,227 802,255 850,482 32
397.5 27,536 706,893 734,429 33
954.0 362,27£2,804,992 3,167,271 34
556.5 23,36E 1,089,252 1,112,620 35
78,485,365 1,279,390,372 1,357,875,737 36
FERC FORM NO.1 (ED.12-87)Page 423.2
Name of Respondent I his Repod is:Date of Repod Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission I /
IRANbMlbbluN LINE blAIIbl ub
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 UEoleWAl luN vdLlAbE (Kv)LE H fole miles)(Indicate where ype e Ase of NumberNo.other than u rgr<urta lines
60 cycle,3 ph ise)Supporting report cir :uit miles)Of
From To Operating Designed Structure Circuits
(a)(b)(c)(d)(e)f)(g)(h)
1 Rigby Sub.,idaho Jefferson Roberts,Idaho 161.0(161.00 Wood -SP 18.00 1
2
3 Naughton Plant,Wyoming Evanston Substation,WY 138.00 138.00 Wood-H 56.00 1
4 Evanston Substation,WY Anschutz Substation,WY 138.0C 138.00 Wood -H 5.00 1
5 Evanston Substation,WY Anschutz Substation,WY 138.0C 138.00 Wood -H 10.00 1
6 Naughton Plant,Wyoming Carter Creek Sub.,WY 138.0C 138.00 Wood -H 26.00 1
7 Railroad Sub.,Wyoming Carter Creek Sub.,WY 138.0C 138.00 Wood -H 26.00 1
8 Painter Substation,WY Natural Gas Sub.,WY 138.00 138.00 Wood -H 5.00 1
9 Grace Plant,Idaho Terminal Sub.,UT(103-104)138.0(138.00 Steel-S 42.00 2
10 Grace Point,ID Terminal Sub,UT (103-104)138.00 138.00 Wood -H 110.00 2
11 Grace Plant,Idaho Terminal Sub.,UT (105)138.0(138.00 Wood -H 138.00 2
12 Grace Plant,Idaho Soda Plant,Idaho 138.00 138.00 Wood -H 6.00 4.00 2
13 Oneida Plant,Idaho Ovid Substation,Idaho 138.00 138.00 Wood-H 23.00 1
14 Antelope Substation,ID Scoville Sub.,Idaho 138.0C 138.00 Wood-H 1.00 1
15 Soda Plant,idaho Monsanto Sub.,Idaho 138.0C 138.00 Wood -H 7.00 1
16 Caribou Substation,ID Grace Plant,Idaho 138.0C 138.00 Wood-H 12.00 1
17 Caribou Substation,ID Becker Substation,Idaho 138.0C 138.00 Wood-H 5.00 1
18 Treasureton Sub.,Idaho Franklin Sub.,Idaho 138.0C 138.00 Wood -H &SP 10.00 1
19 Franklin Substation,ID Smithfield Sub.,Utah 138.0(138.00 Wood-H 21.00 1
20 Terminal Substation,UT Kennecott Sub.,Utah 138.0C 138.00 Steel-S 11.00 2
21 Terminal Substation,UT 30 South Switch Rack,UT 138.0(138.00 Steel -S 7.00 1
22 Jordan,UT Terminal Substation,Ut 138.0(138.00 Wood -H 6.00 1
23 Wheelon Substation,Utah American Falls Sub.,ID 138.0C 138.00 Wood -H 82.00 1
24 Terminal Substation,UT Helper Substation,Utah 138.0C 138.00 Wood -H 116.00 1
25 Hale Plant,Utah Nebo Substation,Utah 138.0(138.00 Wood -H 48.00 1
26 Carbon Plant,Utah Helper Substation,Utah 138.0(138.00 Wood -H 2.00 1
27 Terminal Substation,UT Tooele Substation,Utah 138.0(138.00 Wood -H 23.00 1
28 Wheelon Substation,Utah Smithfield Sub.,Utah 138.0(138.00 Wood -H 18.00 1.00 2
29 Helper Substation,Utah Moab Substation,Utah 138.0(138.00 Wood -H 115.00 1
30 Ninetieth South Sub,Utah Carbon Plant,Utah 138.0C 138.00 Wood -H 72.00 2
31 Terminal Substation,UT Ninetieth South Sub,Utah 138.0(138.00 Wood -H 16.00 2
32 30 South Switch Rack,UT McClelland Sub.,Utah 138.0C 138.00 Wood-SP 6.00 1
33 Moab Substation,Utah Pinto Substation,Utah 138.0(138.00 Wood -H 58.00 1
34 Pinto Substation,Utah Abajo,UT 138.0(138.00 Wood -H 44.00 1
35 Carbon Plant,Utah Ashley Substation,Utah 138.0C 138.00 Wood -H 91.00 1
36 I U I AL 14,862.00 100.00 186
FERCFORM NO.1 (ED.12-87)Page 422.3
Name of Respondent I his Report is:Date ot keport Ÿear of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
RANbMlsbluN LINt·b i A I lb i lub (Conbnued)
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 the
arrangement and giving particulars (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.
LUb I Ut LINt-(Include m Golumn U)Land'EXPENSES,EXCEPT DEPRECIATION AND TAXES
Size of Land rights,and clearing right-of-way)
Conductor
and Material Land Construction and Total Cost Operation Maintenance Rents Total LineOtherCostsExpensesExpensesExpenses
(i)(j)(k)(1)(m)(n)(0)(p)No.
556.5 76,30E 1,205,029 1,281,335 1
2
795.0 146,646 3,875,641 4,022,286 3
795.0 129,125 473,050 602,179 4
195.0 3,381 290,803 294,184 5
795.0 41,411 3,110,678 3,152,089 6
795.0 72,622 3,810,587 3,883,209 7
795.0 -12,424 -278,836 -291,260 8
795.0 639,52E 8,257,073 8,896,602 9
795.0 10
250.0 132,96C 9,036,746 9,169,706 11
795.0 3,28E 146,357 149,646 12
336.0 4,817 390,908 395,725 13
397.5 146 389 537 14
397.5 2,556 109,052 111,607 15
795.0 18,284 421,186 439,470 16
397.5 14,424 145,941 160,365 17
795.0 39,101 509,109 548,210 18
397.5 47,612 1,023,680 1,071,293 19
250.0 4,658 310,988 315,646 20
500.0 1,837 779,661 781,498 21
666,572 1,648,799 2,315,372 22
250.0 113,701 3,002,479 3,116,180 23
250.0 458,79E 6,013,633 6,472,432 24
397.5 27,545 4,135,637 4,163,182 25
954.0 786 98,977 99,763 26
397.5 4,801 984,416 989,217 27
397.5 188,018 737,230 925,248 28
397.5 33,96E 2,271,829 2,305,797 29
795.0 345,835 3,766,189 4,112,024 30
1272.0 429,542 823,671 1,253,213 31
795.0 62,181 1,425,159 1,487,340 32
397.5 40,115 993,401 1,033,516 33
397.5 43,002 1,927,208 1,970,210 34
397.5 47,374 1,601,383 1,648,757 35
78,485,365 1,279,390,372 1,357,875,737 36
FERC FORM NO.1 (ED.12-87)Page 423.3
Name of Respondent I his keport Is:Date of Report Year ot keport
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
I WANSMlbbluN LINE b I A I lb I Ub
1.Report information conceming 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 mileageof 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 UbbibNA I IUIN VUL I Abb (itV)Lh Pole miles)(Indicate where Type of Mse of NumberNo.other than u rgrtuna lines
60 cycle,3 phase)Supporting report circuit miles)Of
Oli õuuuule On "suido CircuitsFromToOperatingDesignedStructureof.Line of herDesignatedine(a)(b)(c)(d)(e)(f)(g)(h)
1 McClelland Sub.,Utah Cottonwood Sub.,Utah 138.0C 138.00 Wood-SP 5.00 1
2 Ashley Substation,Utah Vemal Substation,Utah 138.0C 138.00 Wood -H 12.00 1
3 Sigurd Substation,Utah West Cedar Substation,UT 138.0(138.00 Wood -H 115.00 1
4 Ben Lomond Sub.,Utah El Monte Substation,UT 138.0C 138.00 Wood -H 13.00 1
5 Cottonwood Sub.,Utah Ninetieth South Sub,Utah 138.00 138.00 Wood -SP 11.00 1
6 TerminalSubstation,UT Rowley Substation,Utah 138.0C 138.00 Wood -H 56.00 1
7 Huntington Plant,Utah McFadden Substation,UT 138.0C 138.00 Wood -H 7.00 1
8 Ben Lomond Sub.,Utah El Monte Substation,UT 138.0C 138.00 Wood -H 6.00 1
9 Cottonwood Sub.,Utah Silvercreek Sub.,Utah 138.0C 138.00 Wood -SP 30.00 1
10 Ninetieth South Sub,Utah Taylorsville Sub.,Utah 138.0E 138.00 Wood -SP 7.00 1
11 Gadsby Plant,Utah McClellandSub.,Utah 138.0(138.00 Wood-SP 4.00 1
12 Ninetieth South Sub,Utah Oquirrh Substation,Utah 138.0(138.00 Wood -SP 7.00 2
13 Nebo,UT Jerusalem,UT 138.0(138.00 Wood Tower 24.00 1
14 Ben Lomond Sub.,Utah Westem Zircon Sub.,UT 138.0(138.00 Wood -H 14.00 1
15 Tooele Substation,Utah Oquirrh Substation,Utah 138.0(138.00 Wood -SP 22.00 1
16 Wheelon Substation,Utah Nucor Steel Sub.,Utah 138.0C 138.00 Wood -H 6.00 4.00 1
17 Nebo Substation,Utah Martin-MariettaSub.,UT 138.0C 138.00 Wood -H 30.00 1
18 West Cedar Sub.,Utah MiddletonSubstation.,UT 138.0C 138.00 Wood -H 80.00 1
19 Gadsby Plant,Utah Terminal Substation,UT 138.0C 138.00 Wood -H 12.00 1
20 Oquirrh Substation,Utah Kennecott Sub.,Utah 138.0E 138.00 Wood -H 4.00 1
21 Oquirrh Substation,Utah Bamey Substation,Utah 138.0C 138.00 Wood -HS 3.00 2
22 West Cedar Sub.,Utah Pepcon Substation,Utah 138.0E 138.00 Wood -SP 14.00 1
23 Taylorsville Substation,Uh Mid-Valley Substation,Utah 138.0C 138.00 Steel-SP 5.00 1
24 Warren Substation,Utah Kimberly Clark Sub.,UT 138.0C 138.00 Wood -HP 1.00 1
25 Honeyville,Utah Promontory,Utah 138.0C 138.00 Wood Tower 22.00 1
26 Ninetieth South Sub,Utah Hale Plant,Utah 138.0(138.00 Wood Tower 32.00 1
27 Dumas,UT Bimple,UT 138.0C 138.00 Wood Tower 5.00
28 ColumbiaSub,Utah Sunnyside Co.Gen.,Utah 138.0C 138.00 Wood Tower 2.00 1
29 Syracuse Sub,Utah Ben Lomond Sub,Utah 138.0(138.00 Steel-D-P 1
30 Hale Plant,Utah Midway Sub,Utah 138.0C 138.00 Wood -H 15.00 1
31 Jordan 138 kv,UT Fifth West 138 kv,UT 138.0C 138.00 Steel Tower 1.00 1
32 Gadsby 138 kv,UT Jordan 138 kv,UT 138.0C 138.00 Steel Tower 1.00 1
33 2-138 kv Riverdale Sub,UT 2-138 kv Riverdale Sub,UT 138.0E 138.00 Steel Tower 1.00 2
34 Panther,UT Willo Creek,UT 138.0C 138.00 Wood Tower 1.00 1
35 Hamer Substalon,UT Butterville Substation,UT 138.00 138.00 Wood Tower
36 I U I AL 14,862.00 100.00 186
FERC FORMNO.1 (ED.12-87)Page 422.4
Name ot Respondent I his Report Is:Date ot Report Ÿear of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
i KANbivilbbluN LINE bl A I lb I IUS (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 podion 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 the
arrangement and giving particulars (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 bome 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.
DUb i UE LINt-(include m bolumfl 0)LSDO'EXPENSES,EXCEPT DEPRECIATIONAND TAXES
Size of Land rights,and clearing right-of-way)
Conductor
and Material Land Construction and Total Cost Operation Maintenance Rents Total LineOtherCostsExpensesExpensesExpenses
(i)(j)(k)(1)(m)(n)(0)(p)No.
795.0 13,732 239,547 253,280 1
397.5 5,546 255,095 260,641 2
397.5 52,195 2,508,609 2,560,804 3
795.0 18,845 606,679 625,524 4
795.0 547,65E 1,577,471 2,125,130 5
795.0 222,286 2,194,256 2,416,541 6
397.5 264 218,455 218,719 7
795.0 24,901 408,189 433,090 8
397.5 177,825 2,859,589 3,037,414 9
795.0 5,17E 435,845 441,023 10
795.0 56,756 925,859 982,618 11
795.0 291,996 1,538,756 1,830,754 12
397.5 253,54C 2,123,379 2,376,919 13
250.0 96,457 966,338 1,062.795 14
795.0 252,891 3,023,817 3,276,708 15
795.0 46,947 909,120 956,067 16
397.5 66,452 1,753,775 1,820,227 17
397.5 25,14E 1,355,334 1,380,482 18
1272.0 668,771 810,473 1,479,244 19
795.0 201,459 201,459 20
795.0 16,66E 427,998 444,666 21
795.0 43,516 1,067,486 1,111,001 22
1272.0 33,46E 2,452,332 2,485,798 23
297.5 14,722 141,422 156,144 24
397.5 475,682 2,872,286 3,347,968 25
397.5 146,424 5,258,180 5,404,604 26
397.5 3,136,585 3,136,585 27
397.5 41 2 -39 28
1272.0 353,104 353,104 29
397.5 246,502 5,134,249 5,380,752 30
1272.0 16 733,316 733,332 31
1272.0 754 381,901 382,655 32
795.0 76,205 76,205 33
397.5 40,890 40,890 34
380,47E 2,789,283 3,169,761 35
78,485,365 1,279,390,372 1,357,875,737 36
FERC FORM NO.1 (ED.12-87)Page 423.4
Name of Respondent I his Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
IRANbMIbbluN LINi-blAlibi Ub
1.Report information conœming transmission lines,cost of lines,and expenses for year.List each transmission line having nominalvoltage of 132
kilovolts or greater.Repon 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 repod
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 mileageof 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 Ut-eleWA l luN v UL I Abe (M)LEN i H Pole iles)(Indicate where Type of (he se NumberNo.other than un ergrcuna i nes
60 cycle,3 phase)Supporting report cir;uit miles)Of
uti ouuttuie un ouuuul 6 CircuitsFromToOperatingDesignedStructureofLineofArjotherDesignatedLine(a)(b)(c)(d)(e)(f)(g)(h)
1 Midway Substation,UT Silver Creek Sub,UT 138.0C 138.00 Wood Tower
2 Midway Substation,UT Cottonwood Sub,UT 138.0E 138.00 Wood Tower
3 Pavant Substaion,UT Delta,UT 138.0(138.00 Wood Tower 26.00 1
4 Blundell Substation,UT Milford Substation,UT 138.0C 138.00 Wood Tower 13.00 1
5
6
7 AII 115 kv lines 115.0C 115.00 Wood &Steel 1,427.00
8 All 69 kv lines 69.0(69.00 Wood &Steel 2,972.00 1.00
9 All 57 kv lines 57.0(57.00 Wood &Steel 118.00
10 All 46 kv lines 46.0(46.00 Wood &Steel 2,506.00
11
12
13 Expense Excpt Dep.&Tax
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36 1 0 \AL 14,862.00 100.00 186
FERC FORM NO.1 (ED.12-87)Page 422.5
Name of Respondent I his Report is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
I RANbMlbblUN LINE bl A I lb l tub (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,fumish a succinct statement explaining the
arrangement and giving particulars (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 how
determined.Specify whether lessee is an associated company.
10.Base the plant cost figures called for in columns (j)to (l)on the book cost at end of year.
Dub I ut-Liim-(Incluce in L,olumn 0)Land,EXPENSES,EXCEPT DEPRECIATIONAND 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)(0)(p)No.
2,695,423 2,695,423 1
5,380,752 5,380,752 2
55,43E 1,140,316 1,195,755 3
22,500 771,201 793,701 4
5
6
3,309,971 96,204,082 99,514,053 7
3,060,676 157,784,936 160,845,611 8
32,414 6,120,602 6,153,016 9
3,623,775 117,903,610 121,527,385 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
78,485,365 1,279,390,372 1,357,875,737 36
FERC FORMNO.1 (ED.12-87)Page 423.5
Nameof Respondent I his keport Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
RANUMISSIONLINESADUt-D 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-g ound 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
L I..INb Utt ibNAl lUN Lill OUPPUNI ING b I MUU I UKb GINGUI I b MbK bl KUUi UN :ine Length AveidyeNo.From To in Type Number per Present UltimateMilesMiles(a)(b)(c)(d)(e)(f)(g)
1 None
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
F ERC FORM NO.1 (ED.12-86)Page 424
Name of Respondent I his Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
I RANbivllsbluN LINab AUDED DURING Y EAk (Gontmued)
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.
DUNUUL I URE Voltage t.INi-U Jo |Line
Size Specification Configuration KV Land and Poles,Towers Conductors Total No.and Spacing (Operating)Land Rights and Fixtures and Devices(h)(i)(j)(k)(!)(m)(n)(o)
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
39
40
41
42
43
44
FERC FORM NO.1 (ED.12-86)Page 425
Nameof Respondent I his Report is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
SUBSIAIluNS
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 accordingtofunctionalcharacter,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 whetherattendedorunattended.At the end of the page,summarize according to function the capacities reported for the individual stations incolumn(f).
Line VOLTAGE (In MVa)
No.Name and Location of Substation Character of Substation Primary Secondary Tertiary
(a)(b)(c)(d)(e)
1 CALIFORNIA
2 BIG SPRINGS DISTRIB-UNATTENDED 69.00 12.50
3 CANBY#2 DISTRIB-UNATTENDED 69.00 2.40
4 CLEARLAKE DISTRIB-UNATTENDED 69.00 12.50
5 CRESCENTCITY DISTRIB-UNATTENDED 12.00 4.16
6 FILKINS DISTRIB-UNATTENDED 12.00 4.00
7 GASQUET DISTRIB-UNATTENDED 69.00 4.16
8 GOOSELAKE DISTRIB-UNATTENDED 69.00 2.40
9 HAMBURG DISTRIB-UNATTENDED 69.00 2.40
10 HAPPY CAMP DISTRIB-UNATTENDED 69.00 12.50
11 HORN BROOK DISTRIB-UNATTENDED 69.00 12.00
12 LAKE EARL DISTRIB-UNATTENDED 69.00 12.50
13 LITTLESHASTA DISTRIB-UNATTENDED 69.00 7.20
14 LUCERNE DISTRIB-UNATTENDED 69.00 12.00
15 MACDOEL DISTRIB-UNATTENDED 69.00 20.80 12.00
16 MILLERREDWOOD DISTRIB-UNATTENDED 69.00 13.20
17 MONTAGUE DISTRIB-UNATTENDED 69.00 12.50
18 NUTGLADE DISTRIB-UNATTENDED 69.00 2.40
19 PATRICKSCREEK DISTRIB-UNATTENDED 69.00 7.20
20 PEREZ DISTRIB-UNATTENDED 69.00 12.50
21 SCOTTBAR DISTRIB-UNATTENDED 69.00 12.00
22 SEIAD DISTRIB-UNATTENDED 69.00 12.50
23 SHASTINA DISTRIB-UNATTENDED 115.00 20.80
24 SHOTGUNCREEK DISTRIB-UNATTENDED 69.00 12.50
25 SIMONSON DISTRIB-UNATTENDED 69.00 12.50
26 SMITHRIVER DISTRIB-UNATTENDED 69.00 12.50
27 SNOW BRUSH DISTRIB-UNATTENDED 69.00 7.20
28 SOUTHDUNSMUIR DISTRIB-UNATTENDED 69.00 4.16
29 TULELAKE DISTRIB-UNATTENDED 69.00 12.50
30 WALKER-BRYAN DISTRIB-UNATTENDED 69.00 12.00
31 YUBA DISTRIB-UNATTENDED 69.00 12.50
32 YUROK DISTRIB-UNATTENDED 69.00 12.50 4.16
33 TOTAL 2071.00 312.98 16.16
34 NUMBEROF SUBSTATIONS -DISTRIBUTION-31
35
36
I37AGERTRANS-UNATTENDED 115.00 69.00
38 COPCOIl 230KV TRANS-UNATTENDED 230.00 115.00
39 CRAGVIEW TRANS-UNATTENDED 115.00 69.00
40 DELNORTE TRANS-UNATTENDED 115.00 69.00
FERC FORM NO.1 (ED.12-96)Page 426
Name of Respondent I his Report is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
SUBSI A I luNS (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 by
reason of sole ownership by the respondent.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 Numberof Numberof CONVERSIONAPPARATUS AND SPECIAL E2UIPMENT LineTransformersSpare(In Service)(In MVa)In Service Transformers Type of Equipment Number of Units Total Öapacity No.
(In MVa)(f)(g)(h)(i)(j)(k)
1
6 1 2
1 1 3
4 1 4
1 2 5
1 2 6
9 1 /
3 1 8
1 1 9
8 1 10
3 1 11
13 1 12
2 1 13
4 1 14
31 2 16
4 1 16
5 1 1/
2 1 18
1 1 19
2 1 20
2 1 21
2 1 22
6 1 23
1 1 24
5 1 25
6 1 26
1 27
2 1 28
20 1 29
4 1 30
4 1 31
5 2 32
158 35 33
34
36
36
6 1 37
125 1 38
19 1 39
150 2 40
FERC FORM NO.1 (ED.12-96)Page 427
Name of Respondent I his Report Is:Date of Report Year ot Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
SUBSIAI luNS
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 incolumn(f).
Line V3LTAGE (In M'Ja)
No Nameand Location of Substation Character of Substation
Primary Secondary Tertiary
(a)(b)(c)(d)(e)
1 FALL CREEK TRANS-ATTENDED 2.40 69.00
2 INTERNATIONALPAPER TRANS-UNATTENDED 69.00 2.30
3 IRON GATE TRANS-ATTENDED 6.60 69.00
4 WEED JUNCTION TRANS-UNATTENDED 115.00 69.00
5 TOTAL 768.00 531.30
6 NUMBER OF SUBSTATIONS -TRANSMISSION -8
7
8
9 ALTURAS T/D-UNATTENDED 115.00 69.00 12.50
10 BELMONT T/D-UNATTENDED 69.00 12.50
11 CASTELLA T/D-UNATTENDED 69.00 2.40
12 COPCO#2 T/D-ATTENDED 6.60 115.00 69.00
13 DOGCREEK T/D-UNATTENDED 69.00 2.40
14 DORRIS T/D-UNATTENDED 69.00 12.00
15 FT.JONES T/D-UNATTENDED 69.00 12.00
16 GREENHORN T/D-UNATTENDED 69.00 12.50
17 MCCLOUD T/D-UNATTENDED 2.40 12.50 69.00
18 MTSHASTA T/D-UNATTENDED 69.00 12.50 4.16
19 NEWELL T/D-UNATTENDED 69.00 12.50
20 NORTHCREST T/D-UNATTENDED 69.00 12.50
21 NORTHDUNSMUIR T/D-UNATTENDED 69.00 12.00 4.00
22 REDWOOD T/D-UNATTENDED 69.00 12.50
23 TUNNEL T/D-UNATTENDED 69.00 12.50 2.40
24 WEED T/D-UNATTENDED 69.00 12.50
25 YREKA T/D-UNATTENDED 115.00 69.00 12.50
26 TOTAL 1136.00 406.30 173.56
27 NUMBEROF SUBSTATIONS -TRANS/DISTRIB -17
28
29
30 IDAHO
31 ALEXANDER DISTRIB-UNATTENDED 46.00 12.50
32 AMMON DISTRIB-UNATTENDED 69.00 12.47 7.20
33 ANDERSON DISTRIB-UNATTENDED 69.00 12.47 7.20
34 ARCO DISTRIB-UNATTENDED 69.00 12.47 7.20
35 ARIMO DISTRIB-UNATTENDED 43.80 12.50
36 BANCROFT DISTRIB-UNATTENDED 46.00 12.50
37 BELSON DISTRIB-UNATTENDED 69.00 12.47 7.20
38 BERENICE DISTRIB-UNATTENDED 69.00 24.94 14.40
39 CAMAS DISTRIB-UNATTENDED 69.00 12.47 7.20
40 CANYON CREEK DISTRIB-UNATTENDED 69.00 24.94 14.40
FERC FORM NO.1 (ED.12-96)Page 426.1
'Name of Respondent I his Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission /I
SUbb I A I lUNS (Continued)
5.Show in columns (1),(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 by
reason of sole ownership by the respondent.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 accounts
affected in respondent's books of account.Specify in each case whether lessor,co-owner,or other party is an associated company.
Capacity of Substation Numberof Numberot CONVERSIONAPPARATUS AND SPECIAL EDUIPMENT Line
(In Service)(in MVa)Tran
erv
cee TranSsoarœers Type of Equipment Numberof Units Tot ÒapaacityNo.
(f)(g)(h)(i)(j)(k)
3 1 1
9 1 2
19 1 3
13 1 4
344 9 b
31 2 9
25 1 10
2 1 11
62 2 12
1 13
9 1 14
7 1 16
13 1 16
11 2 1 /
16 2 18
7 1 19
20 2 20
6 2 21
9 1 22
6 2 23
8 1 24
95 2 2b
327 25 26
5 1 31
13 1 32
20 1 33
3 1 34
9 1 3b
2 1 36
13 1 37
13 1 38
13 1 39
20 1 40
I
FERC FORM NO.1 (ED.12-96)Page 427.1
Name of Respondent I his Report Is:Date of keport Year of Report
PacifiCor (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
SUBS I A I luNS
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 CHESTERFIELD DISTRIB-UNATTENDED 46.00 12.50
2 CLEMENTS DISTRIB-UNATTENDED 69.00 12.47 7.20
3 CLIFTON DISTRIB-UNATTENDED 46.00 12.50
4 DOWNEY DISTRIB-UNATTENDED 46.00 12.50
5 DUBOIS DISTRIB-UNATTENDED 69.00 12.47 7.20
6 EASTMONT DISTRIB-UNATTENDED 69.00 12.47 7.20
7 EGIN DISTRIB-UNATTENDED 69.00 12.47 7.20
8 GEORGETOWN DISTRIB-UNATTENDED 69.00 12.50
9 GRACE CITY DISTRIB-UNATTENDED 46.00 12.50
10 HAMER DISTRIB-UNATTENDED 69.00 12.47 7.20
11 HAYES DISTRIB-UNATTENDED 69.00 12.47 7.20
12 HENRY DISTRIB-UNATTENDED 46.00 12.47
13 HOLBROOK DISTRIB-UNATTENDED 69.00 12.50
14 HOOPES DISTRIB-UNATTENDED 69.00 12.47 7.20
15 IDAHO FALLS DISTRIB-UNATTENDED 46.00 12.47
16 INDIAN CREEK DISTRIB-UNATTENDED 69.00 12.47
17 JEFFCO DISTRIB-UNATTENDED 69.00 24.94 14.40
18 KETTLE DISTRIB-UNATTENDED 69.00 24.94 14.40
19 LAVA DISTRIB-ATTENDED 46.00 12.50
20 LIFTON 2 DISTRIB-UNATTENDED 69.00 12.50
21 LUND DISTRIB-UNATTENDED 46.00 12.50
22 MCCAMMON DISTRIB-UNATTENDED 46.00 12.47
23 MENAN DISTRIB-UNATTENDED 69.00 12.47 7.20
24 MERRILL DISTRIB-UNATTENDED 69.00 12.47 7.20
25 MILLER DISTRIB-UNATTENDED 69.00 12.47 7.20
26 MONTPELIER DISTRIB-UNATTENDED 46.00 12.50
27 MOODY DISTRIB-UNATTENDED 69.00 12.47 7.20
28 NEWDALE DISTRIB-UNATTENDED 69.00 12.47 7.20
29 OSGOOD DISTRIB-UNATTENDED 69.00 12.47
30 PRESTON DISTRIB-UNATTENDED 46.00 12.50
31 RAYMOND DISTRIB-UNATTENDED 69.00 12.50
32 RENO DISTRIB-UNATTENDED 69.00 12.47 7.20
33 REXBURG DISTRIB-UNATTENDED 69.00 12.47
34 RIGBY DISTRIB-UNATTENDED 69.00 12.47
35 RIRIE DISTRIB-UNATTENDED 69.00 12.47 7.20
36 ROBERTS DISTRIB-UNATTENDED 69.00 12.47
37 RUBY DISTRIB-UNATTENDED 69.00 12.47
38 SANDCREEK DISTRIB-UNATTENDED 69.00 12.47
39 SANDUNE DISTRIB-UNATTENDED 69.00 24.94 14.40
40 SHELLEY DISTRIB-UNATTENDED 46.00 12.47
FERC FORM NO.1 (ED.12-96)Page 426.2
Nameot Respondent I his Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission I /
SUBSl A I IONS(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 by
reason of sole ownership by the respondent.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 accounts
affected in respondent'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 EDUIPMENT Line
(in Service)(In MVa)Transfeo rs TranSsoarmers Type of Equipment Number of Units Ï01 ÖMapaacityNo.
(f)(g)(h)(i)(j)(k)
4 1 1
6 1 2
5 1 3
5 1 4
13 1 b
6 1 6
6 1 |
6 1 8
5 1 9
13 1 10
9 1 11
2 12
6 1 13
9 1 14
22 1 16
3 1 16
20 1 1/
13 1 18
3 1 19
6 2 20
2 1 21
4 1 22
8 1 23
20 1 24
6 1 2b
8 1 26
13 1 2/
20 1 28
20 1 29
13 1 30
3 1 31
20 1 32
33 2 33
20 1 34
9 1 36
9 1 36
7 1 3/
40 2 38
20 1 39
20 1 40
FERCFORM NO.1 (ED.12-96)Page 427.2
Name of Respondent I his Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
SUBSI Al IONS
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 SMITH DISTRIB-UNATTENDED 69.00 12.47 7.20
2 SOUTH FORK DISTRIB-UNATTENDED 69.00 12.47
3 ST CHARLES DISTRIB-UNATTENDED 69.00 12.50
4 SUGAR CITY DISTRIB-UNATTENDED 69.00 12.47 7.20
5 SUNNY DELL DISTRIB-UNATTENDED 69.00 12.47 7.20
6 TANNER DISTRIB-UNATTENDED 46.00 12.50 7.20
7 TARGHEE DISTRIB-UNATTENDED 46.00 12.47 7.20
8 THORNTON DISTRIB-UNATTENDED 69.00 12.47 7.20
9 UCON DISTRIB-UNATTENDED 69.00 12.47 7.20
10 WATKINS DISTRIB-UNATTENDED 69.00 12.47
11 WEBSTER DISTRIB-UNATTENDED 69.00 12.47 7.20
12 WESTON DISTRIB-UNATTENDED 46.00 12.50
13 WINSPER DISTRIB-UNATTENDED 69.00 24.94 7.20
14 TOTAL 3930.80 860.97 273.60
15 NUMBEROF SUBSTATIONS -DISTRIBUTION -63
16
17
18 AMPS AUTO TRANS TRANS-UNATTENDED 230.00 69.00
19 ANTELOPE TRANS-UNATTENDED 230.00 138.00 161.00
20 BONNEVILLE TRANS-UNATTENDED 161.00 69.00
21 CARIBOU TRANS-UNATTENDED 138.00 46.00
22 CONDA TRANS-UNATTENDED 138.00 46.00
23 FISHCREEK TRANS-UNATTENDED 161.00 46.00
24 FRANKLINAUTO TRANS TRANS-UNATTENDED 138.00 46.00
25 GOSHEN TRANS-ATTENDED 138.00 46.00 69.00
26 JEFFERSON TRANS-UNATTENDED 161.00 161.00
27 MALAD TRANS-UNATTENDED 138.00 69.00 12.50
28 MUD LAKE 69.00 12.00
29 SCOVILLEAUTO TRANS TRANS-UNATTENDED 138.00 69.00
30 SUGAR MILLAUTO TRANS TRANS-UNATTENDED 161.00 69.00 46.00
31 TREASURETON#2 AUTO TRANS TRANS-UNATTENDED 230.00 138.00
32 TOTAL 2231.00 1024.00 288.50
33 NUMBEROF SUBSTATIONS -TRANSMISSION -14
34
35
36 OREGON
37 26TH STREET DISTRIB-UNATTENDED 20.80 4.10
38 35TH STREET DISTRIB-UNATTENDED 20.80 4.10
39 ARLINGTON DISTRIB-UNATTENDED 69.00 12.50
40 BANDON DISTRIB-UNATTENDED 20.80 12.00
FERCFORM NO.1 (ED.12-96)Page 426.3
Name of Respondent I his Report is:IJate of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
SUBb l A I IONS (Continued)
5.Show in columns (1),(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 othenvise than by
reason of sole ownership by the respondent.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 Numberof Number of CONVERSIONAPPARATUS AND SPECIAL EQUIPMENT Line
(in Service)(in MVa)Tran
e
cee TranSsoar
ers Type of Equipment Number of Units Tot CapaacityNo.
(f)(g)(h)(i)(j)(k)
20 1 1
13 1 2
6 1 3
13 1 4
13 1 5
2 1 6
4 1 7
6 1 8
14 1 9
9 1 10
20 1 11
5 1 12
20 1 13
711 67 14
16
16
1/
75 1 18
415 3 19
67 1 20
27 1 21
67 1 22
25 3 23
67 1 24
691 9 26
133 3 26
13 4 27
14 1 28
67 1 29
168 3 30
467 2 31
2296 34 32
33
34
3b
36
5 1 3/
1 2 38
4 1 39
3 1 40
FERC FORM NO.1 (ED.12-96)Page 427.3
Nameof Respondent I his Report is:Date of Report Year of Report(1)An Original (Mo,Da,Yr)Dec.31 2000PacifiCorp(2)A Resubmission //
SUBblAIIONS
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)
N Nameand Location of Substation Character of Substation Primary Secondary Tertiary
(a)(b)(c)(d)(e)
1 BEACON DISTRIB-UNATTENDED 69.00 12.50
2 BEATTY DISTRIB-UNATTENDED 69.00 12.50
3 BLALOCK DISTRIB-UNATTENDED 69.00 12.50
4 BLANDENA DISTRIB-UNATTENDED 57.00 4.15
5 BLY DISTRIB-UNATTENDED 69.00 12.50
6 BOISE CASCADE DISTRIB-UNATTENDED 69.00 2.30
7 BONANZA DISTRIB-UNATTENDED 69.00 12.50
8 BROWNSVILLE DISTRIB-UNATTENDED 69.00 20.80
9 CANNON BEACH DISTRIB-UNATTENDED 115.00 12.50
10 CASE BEER DISTRIB-UNATTENDED 69.00 20.80
11 CHILOQUIN MARKET DISTRIB-UNATTENDED 69.00 12.50
12 CHINA HAT DISTRIB-ATTENDED 115.00 12.50
13 CLEARWATER #1 DISTRIB-UNATTENDED 7.20 115.00 12.00
14 CLEARWATER #2 DISTRIB-UNATTENDED 11.50 6.90
15 COLLISEUM DISTRIB-UNATTENDED 20.80 4.10
16 COLUMBIA DISTRIB-UNATTENDED 115.00 12.47
17 CROOKED RIVER RANCH DISTRIB-UNATTENDED 69.00 20.80
18 CUTLER CITY DISTRIB-UNATTENDED 20.80 4.16
19 DEE DISTRIB-UNATTENDED 69.00 2.40
20 DOUGLAS-VENEER DISTRIB-UNATTENDED 69.00 12.00
21 ELK CREEK DAM CONST.DISTRIB-UNATTENDED 69.00 12.50
22 FIELDER CREEK DISTRIB-UNATTENDED 115.00 20.80
23 FOOTHILLS DISTRIB-UNATTENDED 69.00 12.50
24 FRALEY DISTRIB-UNATTENDED 69.00 12.00
25 GARDENVALLEY DISTRIB-UNATTENDED 69.00 20.80
26 GAZLEY DISTRIB-UNATTENDED 69.00 12.50
27 GEARHART DISTRIB-UNATTENDED 12.50 4.16
28 GLENEDEN DISTRIB-UNATTENDED 20.80 4.16
29 GLIDE DISTRIB-UNATTENDED 115.00 12.50
30 GORDONHOLLOW DISTRIB-UNATTENDED 69.00 20.80
31 GRASS VALLEY DISTRIB-UNATTENDED 20.00 7.20 2.40
32 GROVE DISTRIB-UNATTENDED 12.00 4.16
33 HAMAKER DISTRIB-UNATTENDED 69.00 12.50
34 HAZELWOOD DISTRIB-UNATTENDED 12.00 20.00
35 HENLEY DISTRIB-UNATTENDED 69.00 12.50
36 HENRY STREET DISTRIB-UNATTENDED 20.80 2.40
37 HILL STREET DISTRIB-UNATTENDED 12.50 2.30
38 HINKLE DISTRIB-UNATTENDED 69.00 12.50
39 HOOD RIVER DISTRIB-UNATTENDED 69.00 12.50 7.20
40 JORDAN POINT DISTRIB-UNATTENDED 115.00 12.50
FERC FORM NO.1 (ED.12-96)Page 426.4
Name of Respondent I his Report is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
SUBS I A \luNS (Continued)
5.Show in columns (I),(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 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 accounts
affected in respondent's books of account.Specify in each case whether lessor,co-owner,or other party is an associated company.
Capacity of Substation Numberof Numberof CONVERSIONAPPARATl.S 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)(j)(k)
8 1
3 1 2
2 1 3
8 2 4
7 1 b
1 1 6
9 1 /
13 1 8
13 1 9
20 1 10
6 1 11
25 1 12
1 13
1 1 14
9 2 1b
20 1 16
5 1 1/
1 1 18
9 1 19
6 1 20
6 1 21
25 1 22
21 2 23
5 1 24
20 1 2b
3 1 26
1 2/
4 1 28
9 1 29
6 1 30
1 2 31
1 1 32
8 1 33
13 1 34
6 1 3b
2 1 36
1 1 3/
20 1 38
40 2 39
45 2 40
FERC FORM NO.1 (ED.12-96)Page 427.4
Name of Respondent I his Report Is:IJafe of Report Year ot keport
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
SUBSI Al \ØNS
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 JOSEPH DISTRIB-UNATTENDED 20.80 12.50
2 K STREET 66.00 12.50
3 KENWOOD DISTRIB-UNATTENDED 69.00 12.50
4 KINGSLEYFIELD DISTRIB-UNATTENDED 69.00 2.40
5 KNAPPASVENSEN DISTRIB-UNATTENDED 115.00 12.47
6 LAKEVIEW DISTRIB-UNATTENDED 69.00 12.00
7 LANCASTER DISTRIB-UNATTENDED 69.00 20.80
8 MAPLE STREET DISTRIB-UNATTENDED 20.00 2.40
9 MEDCO DISTRIB-UNATTENDED 115.00 12.50
10 MINAM DISTRIB-UNATTENDED 69.00 12.50
11 MODOC DISTRIB-UNATTENDED 69.00 12.50
12 MORO DISTRIB-UNATTENDED 20.80 2.40
13 MYRTLE POINT DISTRIB-UNATTENDED 115.00 20.80
14 NELSCOTT DISTRIB-UNATTENDED 20.80 4.16
15 OAKLAND DISTRIB-UNATTENDED 115.00 12.50
16 ORCHARD STREET DISTRIB-UNATTENDED 12.50 4.00
17 OROMITE DISTRIB-UNATTENDED 69.00 12.47
18 PACIFIC PLYWOOD DISTRIB-UNATTENDED 69.00 4.16
19 PROVOLT DISTRIB-UNATTENDED 69.00 12.50
20 RED BLANKET DISTRIB-UNATTENDED 69.00 4.16
21 RICH MFG.DISTRIB-UNATTENDED 57.00 11.00 4.16
22 RIDDLE-VENEER DISTRIB-UNATTENDED 69.00 12.00
23 ROGUE RIVER DISTRIB-UNATTENDED 69.00 20.80 12.50
24 ROSS AVENUE DISTRIB-UNATTENDED 69.00 12.50
25 RUCH DISTRIB-UNATTENDED 69.00 12.50
26 SELMA DISTRIB-UNATTENDED 69.00 12.50
27 SHASTA WAY DISTRIB-UNATTENDED 12.50 4.00
28 SIMTAG BOOSTERPUMP DISTRIB-UNATTENDED 34.50 4.16
29 SOUTH DUNES DISTRIB-UNATTENDED 115.00 12.50
30 SPRAGUE RIVER DISTRIB-UNATTENDED 69.00 12.50
31 STAYTON CITY DISTRIB-UNATTENDED 20.80 2.40
32 STEAM BOAT STATION DISTRIB-UNATTENDED 115.00 7.20
33 SUTHERLIN DISTRIB-UNATTENDED 115.00 12.47
34 TEXUM DISTRIB-UNATTENDED 69.00 12.50
35 TILLER DISTRIB-UNATTENDED 115.00 12.00
36 TOLO DISTRIB-UNATTENDED 69.00 12.50
37 TOM CREEK DISTRIB-UNATI¯ENDED 69.00 2.40
38 TONGUE POINT DISTRIB-UNATTENDED 22.00 2.40
39 TURKEY HILL DISTRIB-UNATTENDED 69.00 12.50
40 U.S.PLYWOOD DISTRIB-UNATTENDED 20.80 2.40
FERCFORM NO.1 (ED.12-96)Page 426.5
Name of Respondent I his Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
SUBSl A I IONS (Continued)
5.Show in columns (I),(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 by
reason of sole ownership by the respondent.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 accounts
affected in respondent'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 CONVERSIONAPPARATLS AND SPECIALEQUIPMENT 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)
2 1 1
2 1 2
3 1 3
2 2 4
6 1 b
9 1 6
13 1 /
1 1 8
20 1 9
1 10
4 1 11
1 1 12
9 1 13
4 1 14
9 1 1b
1 1 16
4 1 1/
8 1 18
11 1 19
2 1 20
8 1 21
9 1 22
25 2 23
9 1 24
9 1 2b
9 1 26
1 1 2/
15 2 28
9 1 29
7 1 30
1 1 31
1 32
3 1 33
17 2 34
1 1 3b
11 1 38
1 1 3/
1 1 38
13 1 39
13 2 40
FERC FORMNO.1 (ED.12-96)Page 427.5
Name of Respondent inis Report is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
bußS I Al IUNS
1.Report below the information called for conceming 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 accordingtofunctionalcharacter,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 whetherattendedorunattended.At the end of the page,summarize according to function the capacities reported for the individual stations incolumn(f).
Line VOLTAGE (in MVa)
No.Nameand Location of Substation Character of Substation Primary Secondary Tediary
(a)(b)(c)(d)(e)
1 UMAPlNE DISTRIB-UNATTENDED 69.00 12.50
2 WARRENTON DISTRIB-UNATTENDED 115.00 12.50
3 WASCO DISTRIB-UNATTENDED 20.80 4.16
4 WECOMA BEACH DISTRIB-UNATTENDED 20.00 4.10
5 WEST SIDE DISTRIB-ATTENDED 69.00 12.50
6 WINSTON DISTRIB-UNATTENDED 69.00 12.50
7 YOUNGSBAY DISTRIB-UNATTENDED 115.00 22.00 12.47
8 TOTAL 5673.60 1065.57 50.73
9 NUMBEROF SUBSTATIONS -DISTRIBUTION-91
10
11
12 BEND TRANS-ATTENDED 69.00 12.47
13 BROOKS-SCANLONLBR TRANS-UNATTENDED 12.50 69.00
14 CALAPOOYA TRANS-UNATTENDED 230.00 69.00
15 COLD SPRINGS TRANS-UNATTENDED 230.00 69.00
16 COVE TRANS-UNATTENDED 230.00 69.00
17 DALREED TRANS-UNATTENDED 230.00 34.50
18 DAYS CREEK TRANS-UNATTENDED 115.00 69.00
19 DIAMOND HILL TRANS-UNATTENDED 230.00 69.00
20 DIXONVILLE 230KV TRANS-ATTENDED 230.00 115.00 69.00
21 DIXONVILLE 500KV TRANS-ATTENDED 500.00 230.00
22 FISH CREEK TRANS-UNATTENDED 6.55 115.00
23 FISH HOLE TRANS-UNATTENDED 115.00 69.00
24 FRY TRANS-UNATTENDED 230.00 115.00
25 GRANTS PASS TRANS-UNATTENDED 230.00 115.00 69.00
26 GREEN SPRINGS PLANT TRANS-UNATTENDED 125.00 71.00
27 HAZELWOOD TRANS-UNATTENDED 115.00 69.00
28 HURRICANE TRANS-UNATTENDED 230.00 69.00
29 ISTHMUS TRANS-UNATTENDED 230.00 115.00
30 KENNEDY TRANS-UNATTENDED 69.00 57.00
31 KLAMATH FALLS TRANS-ATTENDED 230.00 69.00
32 LONEPINE (NEW)TRANS-ATTENDED 230.00 115.00
33 LONEPINE (OLD)TRANS-ATTENDED 115.00 69.00
34 MALIN TRANS-ATTENDED 500.00 230.00 69.00
35 MERIDIAN 500KV TRANS-UNATTENDED 500.00 230.00
36 MONPAC TRANS-UNATTENDED 115.00 69.00
37 PILOT BUTTE TRANS-UNATTENDED 230.00 69.00 12.50
38 PONDEROSA TRANS-UNATTENDED 230.00 115.00 12.50
39 PROSPECT CENTRAL TRANS-ATTENDED 2.30 69.00 115.00
40 REDMOND TRANS-UNATTENDED 12.50 115.00 69.00
FERC FORM NO.1 (ED.12-96)Page 426.6
Name of Respondent I his Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
SUBSlAl luNS (continued)
5.Show in columns (I),(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 by
reason of sole ownership by the respondent.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 accounts
affected in respondent'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 CONVERSIONAPPARATUS AND SPECIAL EDUlPMENT 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)
12 1 1
25 2 2
1 1 3
3 1 4
21 2 b
9 1 6
43 3 |
802 107 8
10
11
19 2 12
20 1 13
75 1 14
60 1 16
127 3 ib
80 4 1/
50 1 18
75 1 19
344 4 20
650 1 21
13 1 22
19 1 23
560 2 24
458 5 25
6 1 26
53 2 2/
25 1 28
250 1 29
33 1 30
250 2 31
625 3 32
108 3 33
342 2 34
650 1 35
50 1 3b
400 3 3/
250 1 38
47 2 39
50 2 40
FERC FORM NO.1 (ED.12-96)Page 427.6
Name of Respondent I nis Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
SUBSIAIIONS
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 whetherattendedorunattended.At the end of the page,summarize according to function the capacities reported for the individual stations in
column (f).
Line V3LTAGE (in MVa)
No.Name and Location of Substation Character of Substation Primary Secondary Tertiary
(a)(b)(c)(d)(e)
1 ROBERTS CREEK TRANS-UNATTENDED 115.00 69.00
2 ROUNDUP TRANS-UNATTENDED 230.00 69.00
3 SLIDE CREEK TRANS-UNATTENDED 6.55 115.00
4 TOKETEE TRANS-ATTENDED 6.90 115.00
5 TROUT DALE TRANS-UNATTENDED 230.00 115.00 69.00
6 WILLOW CREEK TRANS-UNATTENDED 69.00 34.50
7 TOTAL 6249.30 3268.47 485.00
8 NUMBEROF SUBSTATIONS-TRANSMISSION -35
9
10
11 AGNESS AVENUE T/D-UNATTENDED 115.00 12.50
12 ALBINA T/D-ATTENDED 115.00 69.00 11.00
13 ALDERWOOD T/D-UNATTENDED 115.00 12.50
14 AMERICAN CAN T/D-UNATTENDED 69.00 12.50
15 APPLE GATE T/D-UNATTENDED 115.00 69.00 13.20
16 ASHLAND T/D-UNATTENDED 115.00 69.00 12.50
17 ATHENA T/D-UNATTENDED 69.00 12.50
18 BELKNAP T/D-UNATTENDED 69.00 12.50
19 BLOSS T/D-ATTENDED 115.00 12.50
20 BROOKHURST T/D-UNATTENDED 69.00 12.50
21 BRYANT T/D-UNATTENDED 69.00 12.50
22 BUCHANAN T/D-UNATTENDED 115.00 20.80
23 BUCKAROO T/D-UNATTENDED 69.00 12.50
24 CAMPBELL T/D-UNATTENDED 115.00 12.50
25 CARNES T/D-UNATTENDED 69.00 12.50
26 CAVE JUNCTION T/D-UNATTENDED 115.00 69.00 12.50
27 CAVEMAN T/D-UNATTENDED 115.00 12.50
28 CHERRY LANE T/D-UNATTENDED 69.00 12.00
29 CHILOQUlN T/D-UNATTENDED 230.00 115.00 69.00
30 CIRCLE BOULEVARD T/D-UNATTENDED 115.00 20.80
31 CLEVELAND AVE.T/D-ATTENDED 69.00 12.50
32 CLOAKE T/D-UNATTENDED 69.00 20.80
33 COBURG T/D-UNATTENDED 69.00 20.80
34 COLUMBIA T/D-UNATTENDED 57.00 11.00 4.16
35 COOS RIVER T/D-UNATTENDED 115.00 20.80
36 COQUILLE T/D-UNATTENDED 115.00 20.80
37 CROW FOOT T/D-UNATTENDED 115.00 20.80
38 CULLY T/D-UNATTENDED 115.00 12.50
39 CULVER T/D-UNATTENDED 69.00 12.50
40 DAIRY T/D-UNATTENDED 69.00 12.50
FERC FORM NO.1 (ED.12-96)Page 426.7
Name of Respondent I his Report Is:Date of Report Year of Report |
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
SUBS I A I IONS(Continued)
5.Show in columns (I),(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 by
reason of sole ownership by the respondent.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 accounts
affected in respondent's books of account.Specify in each case whether lessor,co-owner,or other party is an associated company.
Capacity of Substation Numberof Number of CONVERSION APPARATUS AND SPECIAL EDUIPMENT Line
(In Service)(in MVa)Tran
erv
cee TranSsoarmers Type of Equipment Number of Units Total ÔMapacityNo.
(f)(g)(h)(i)(j)(k)
50 1 1
60 1 2
21 1 3
20 3 4
500 3 b
5 1 6
6345 64 /
10
25 1 11
174 3 12
25 1 13
60 2 14
65 2 16
70 2 16
9 1 1 /
40 2 18
32 2 19
50 2 20
34 2 21
40 2 22
19 2 23
20 1 24
9 1 2b
70 2 26
20 1 2/
25 1 28
119 2 29
65 2 30
45 2 31
20 1 32
10 1 33
28 4 34
20 1 3b
40 2 36
20 1 3/
25 1 38
13 1 39
25 1 40
FERC FORM NO.1 (ED.12-96)Page 427.7
Name of Respondent I his Report Is:lJate of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
SUBSIAllUNS
1.Report below the information called for conceming 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 accordingtofunctionalcharacter,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 DAL1.AS T/D-UNATTENDED 115.00 20.80
2 DESCHUTES T/D-UNATTENDED 69.00 12.50
3 DEVILSLAKE T/D-UNATTENDED 115.00 20.00
4 DIXON T/D-UNATTENDED 115.00 4.16
5 DODGEBRIDGE T/D-UNATTENDED 69.00 20.80
6 EASY VALLEY T/D-UNATTENDED 115.00 12.50
7 EMPIRE NEW T/D-UNATTENDED 115.00 20.80
8 ENTERPRISE T/D-UNATTENDED 69.00 20.80 12.50
9 FERNHILL T/D-ATTENDED 115.00 12.47
10 FREEWATER TID-UNATTENDED 69.00 7.20
11 GLENDALE T/D-UNATTENDED 230.00 12.50
12 GOLDHILL T/D-UNATTENDED 69.00 12.50
13 GOSHEN T/D-UNATTENDED 115.00 20.80
14 GRANT T/D-UNATTENDED 115.00 20.80
15 GREEN T/D-ATTENDED 69.00 20.80
16 GRIFFINCREEK T/D-UNATTENDED 115.00 12.50
17 HARRISBURG T/D-UNATTENDED 69.00 20.80
18 HERMISTON T/D-UNATTENDED 69.00 12.50
19 HILLVIEW T/D-UNATTENDED 115.00 20.00
20 HOLLADAY T/D-UNATTENDED 115.00 11.00
21 HOLLYWOOD TID-UNATTENDED 115.00 12.50
22 HORNET T/D-UNATTENDED 69.00 12.50
23 INDEPENDENCE T/D-UNATTENDED 69.00 20.80
24 JACKSONVILLE T/D-UNATTENDED 115.00 69.00 12.50
25 JEFFERSON T/D-UNATTENDED 69.00 20.80
26 JEROME PRAIRIE T/D-UNATTENDED 115.00 12.50
27 JUNCTIONCITY T/D-UNATTENDED 69.00 20.80
28 KILLINGSWORTH T/D-UNATTENDED 69.00 12.50
29 KNOTT T/D-UNATTENDED 115.00 57.00 12.50
30 LAKEPORT T/D-UNATTENDED 69.00 12.50
31 LEBANON T/D-UNATTENDED 115.00 20.80
32 LEMOLO#1 T/D-UNATTENDED 11.50 115.00 12.50
33 LINCOLN T/D-UNATTENDED 115.00 12.47
34 LOCKHART T/D-UNATTENDED 115.00 20.80
35 LYONS (NEW)T/D-UNATTENDED 69.00 12.00
36 MADRAS TID-UNATTENDED 69.00 12.50
37 MALLORY T/D-UNATTENDED 115.00 12.47
38 MARYS RIVER T/D-UNATTENDED 115.00 20.80
39 MEDFORD T/D-UNATTENDED 115.00 69.00 12.50
40 MERLIN T/D-UNATTENDED 115.00 12.50
FERC FORM NO.1 (ED.12-96)Page 426.8
Nameof Respondent I nts Report Is:Date of Report Year of Report
PacifiCo (1)An Original (Mo,Da,Yr)Dec.31,2000rp(2)A Resubmission //
SUds i Al luNb (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 by
reason of sole ownership by the respondent.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 accounts
affected in respondent's books of account.Specify in each case whether lessor,co-owner,or other party is an associated company.
Number of Number of CONVERSIONAPPARATUS AND SPECIAL E2UIPMENT LineIancervic
)
an Transfeo eers TranSs
o ers Type of Equipment Number of Units Tot Capaacity No.
(f)(g)(h)(i)(j)(k)
50 2 1
13 1 2
50 2 3
7 1 4
13 1 b
45 2 6
20 1 /
19 2 8
13 1 9
2 1 10
25 2 11
11 1 12
20 1 13
40 2 14
25 1 16
20 1 16
13 1 1/
40 2 18
45 2 19
75 3 20
50 2 21
20 1 22
20 1 23
75 2 24
13 1 2b
20 1 26
25 2 2/
40 2 28
177 4 29
50 2 30
42 2 31
3 1 32
105 3 33
40 2 34
22 2 3b
25 2 36
25 1 3/
20 1 38
79 6 39
45 2 40
FERCFORM NO.1 (ED.12-96)Page 427.8
Name of Respondent I his Report is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
SUBSIAllUNS
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 MERRILL T/D-UNATTENDED 69.00 12.50
2 MILE-HI T/D-UNATTENDED 115.00 69.00 12.00
3 MURDERCREEK T/D-UNATTENDED 115.00 20.00 12.00
4 MYRTLE CREEK T/D-UNATTENDED 69.00 12.00
5 NORTH BEND PLANT T/D-UNATTENDED 115.00 12.00 4.00
6 OAK KNOLL T/D-UNATTENDED 115.00 12.50
7 O'BRIEN (NEW)T/D-UNATTENDED 115.00 12.50
8 OREMET T/D-UNATTENDED 115.00 20.80 12.00
9 OVERPASS T/D-UNATTENDED 69.00 12.50
10 PALLETTE T/D-UNATTENDED 40.00 20.00
11 PARK ROSE T/D-UNATTENDED 57.00 12.50
12 PARK STREET T/D-UNATTENDED 115.00 12.50
13 PENDLETON T/D-UNATTENDED 69.00 12.50 4.16
14 PILOT ROCK T/D-UNATTENDED 69.00 12.50
15 POWELL BUTTE T/D-UNATTENDED 115.00 12.50
16 PRINEVILLE T/D-UNATTENDED 115.00 12.50
17 QUEEN AVE T/D-UNATTENDED 69.00 20.80
18 RIDDLE T/D-UNATTENDED 69.00 12.50
19 ROSEBURG T/D-UNATTENDED 69.00 20.80
20 RUSSELLVILLE TID-UNATTENDED 115.00 12.50
21 SAGERD T/D-UNATTENDED 115.00 12.50
22 SCENIC T/D-UNATTENDED 115.00 69.00 12.50
23 SCIO T/D-UNATTENDED 69.00 12.00
24 SEASlDE T/D-UNATTENDED 115.00 12.50 4.00
25 SODA SPRINGS T/D-UNATTENDED 6.55 115.00 7.20
26 SOUTH GATE T/D-UNATTENDED 69.00 20.80
27 STATESTREET T/D-UNATTENDED 115.00 20.80
28 STAYTON T/D-UNATTENDED 69.00 20.80
29 STEVENS ROAD T/D-ATTENDED 115.00 20.80
30 SWEET HOME T/D-UNATTENDED 115.00 20.80
31 TAKELMA T/D-UNATTENDED 115.00 20.80
32 TALENT T/D-UNATTENDED 69.00 12.50
33 TUCKER T/D-UNATTENDED 115.00 69.00 12.47
34 UMATILLA T/D-UNATTENDED 69.00 12.50
35 VERNON T/D-UNATTENDED 69.00 12.47
36 VILAS ROAD TID-ATTENDED 115.00 12.50
37 VILLAGE GREEN T/D-UNATTENDED 115.00 20.80
38 VINE STREET T/D-UNATTENDED 20.80 69.00
39 WALLOWA T/D-UNATTENDED 69.00 12.50
40 WARM SPRINGS T/D-UNATTENDED 20.80 69.00
FERC FORMNO.1 (ED.12-96)Page 426.9
Name of Respondent I nis Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
SUBS I A i luNS (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 by
reason of sole ownership by the respondent.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 accounts
affected in respondent'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 CONVERSIONAPPARATL S 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)(j)(k)
17 2 1
39 2 2
100 4 3
14 1 4
41 3 b
45 2 6
9 1 |
75 3
40 2 9
1 1 10
39 2 11
40 2 12
43 6 13
19 2 14
5 1 15
50 2 16
45 2 1/
14 1 18
50 2 19
45 2 20
40 2 21
70 3 22
7 1 23
46 3 24
13 2 2b
20 1 26
40 2 2/
40 2 26
25 1 29
42 2 30
13 1 31
25 1 32
100 2 33
25 2 34
50 2 3b
25 1 36
20 2 3/
20 1 38
7 1 39
13 1 40
FERC FORM NO.1 (ED.12-96)Page 427.9
Name of Respondent I his Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
SUBS lAl IONS
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 WESTERN KRAFT T/D-UNATTENDED 115.00 12.50
2 WESTON NEW T/D-UNATTENDED 69.00 12.50
3 WEYERHAEUSER T/D-UNATTENDED 69.00 12.50
4 WHITE CITY T/D-UNATTENDED 115.00 12.50
5 WILLOW COVE T/D-UNATTENDED 34.50 4.16
6 WINCHESTER T/D-UNATTENDED 115.00 69.00 12.50
7 TOTAL 10782.15 2739.70 277.69
8 NUMBER OF SUBSTATIONS-TRANS/DISTRIB-116
9
10
11 UTAH
12 ALTA VIEW DISTRIB-UNATTENDED 46.00 12.00
13 AMALGA DISTRIB-UNATTENDED 46.00 12.47 7.20
14 AMERICAN FORK DISTRIB-UNATTENDED 43.80 12.47 7.20
15 ARAGONITE DISTRIB-UNATTENDED 138.00 12.47 7.20
16 AURORA DISTRIB-UNATTENDED 42.90 12.40 7.20
17 BEAR RIVER DISTRIB-UNATTENDED 43.80 12.47 7.20
18 BENJAMIN DISTRIB-UNATTENDED 44.00 12.47
19 BINGHAM DISTRIB-UNATTENDED 43.80 12.47 7.20
20 BLUE CREEK DISTRIB-UNATTENDED 46.00 12.47 7.20
21 BLUFF DISTRIB-UNATTENDED 69.00 12.47 7.20
22 BLUFFDALE DISTRIB-UNATTENDED 43.80 12.47 7.20
23 BOTHWELL DISTRIB-UNATTENDED 42.90 12.47 7.20
24 BOX ELDER DISTRIB-UNATTENDED 42.90 12.47 7.20
25 BRIAN HEAD DISTRIB-UNATTENDED 34.50 12.47 7.20
26 BRICKYARD DISTRIB-UNATTENDED 43.80 12.47 7.20
27 BRIGHTON DISTRIB-UNATTENDED 43.80 24.90 14.40
28 BROOKLAWNCREAMERY DISTRIB-UNATTENDED 46.00 12.47 7.20
29 BRUNSWICK DISTRIB-UNATTENDED 43.80 12.47 7.20
30 BUSH DISTRIB-UNATTENDED 43.80 12.47 7.20
31 BUTLERVILLE DISTRIB-UNATTENDED 43.80 12.47 7.20
32 CAMERON DISTRIB-UNATTENDED 138.00 46.00
33 CAMPWILLIAMS DISTRIB-UNATTENDED 138.00 12.47 7.20
34 CANNON DISTRIB-UNATTENDED 43.80 12.47 7.20
35 CANYONLANDS DISTRIB-UNATTENDED 69.00 12.47
36 CAPITOL DISTRIB-UNATTENDED 43.80 12.47 7.20
37 CARBIDE DISTRIB-UNATTENDED 67.00 12.50 7.20
38 CARBONVILLE DISTRIB-UNATTENDED 43.80 12.47
39 CASTO DISTRIB-UNATTENDED 43.80 12.47 7.20
40 CEDAR NORTH DISTRIB-UNATTENDED 34.50 4.20
FERC FORM NO.1 (ED.12-96)Page 426.10
Name of Respondent i nis Report is:Date of Report Year of Repod
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
bUdb I A l luNS (continued)
5.Show in columns (I),(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 Numberof CONVERSION APPARATUSAND SPECIAL EQUIPMENT Line
(in Service)(In MVa)an
erv
s TranSsoar
ers Type of Equipment Numberof Units Tot ÖMapaacityNo.
(f)(g)(h)(i)(j)(k)
50 2 1
22 2 2
40 2 3
60 3 4
28 3 b
75 3 6
4306 210 /
10
11
20 1 12
11 1 13
20 1 14
1 1b
3 1 16
12 2 1/
2 3 18
20 1 19
2 3 20
1 3 21
9 1 22
4 1 23
3 2 24
12 1 26
7 1 26
26 1 2/
1 28
20 3 29
11 1 30
20 2 31
2 1 33
22 1 34
2 3 36
16 1 36
1 3/
6 1 38
13 1 39
5 1 40
FERC FORM NO.1 (ED.12-96)Page 427.10
Name of Respondent I his Report Is:Date of Reporf Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission I /
SUBSIAIIUNS
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 CENTENNIAL DISTRIB-UNATTENDED 138.00 12.47 7.20
2 CENTERVILLE DISTRIB-UNATTENDED 43.80 12.47 7.20
3 CENTRAL DISTRIB-UNATTENDED 42.90 12.47
4 CHAPARRAL DISTRIB-UNATTENDED 46.00 2.40
5 CHERRYWOOD DISTRIB-UNATTENDED 132.00 12.47 7.20
6 CIRCLEVILLE DISTRIB-UNATTENDED 67.00 12.47 7.20
7 CLEAR CREEK DISTRIB-UNATTENDED 43.80 12.47 7.20
8 CLEARFIELD DISTRIB-UNATTENDED 43.80 12.47 7.20
9 CLEAR LAKE DISTRIB-UNATTENDED 44.00 12.50 7.20
10 CLINTON DISTRIB-UNATTENDED 132.00 12.70 7.20
11 CLIVE DISTRIB-UNATTENDED 42.90 12.47 7.20
12 COALVILLE DISTRIB-UNATTENDED 43.80 24.90 12.47
13 COLLEGE DISTRIB-UNATTENDED 42.90 24.00 7.20
14 COLTONWELL DISTRIB-UNATTENDED 46.00 12.50
15 COLUMBIA DISTRIB-UNATTENDED 138.00 45.00 6.60
16 CORINNE DISTRIB-UNATTENDED 42.90 12.47
17 COVEFORT DISTRIB-UNATTENDED 43.80 12.47 7.20
18 CRESCENT JUNCTION DISTRIB-UNATTENDED 46.00 12.50 7.20
19 CUDAHY DISTRIB-UNATTENDED 132.00 12.47 7.20
20 DAIRY FORK DISTRIB-UNATTENDED 46.00 12.50 7.20
21 DAMMERON VALLEY DISTRIB-UNATTENDED 67.00 12.47
22 DECKER LAKE DISTRIB-UNATTENDED 138.00 12.47 7.20
23 DELLE DISTRIB-UNATTENDED 43.80 12.47 7.20
24 DELTA DISTRIB-UNATTENDED 43.80 12.47 7.20
25 DESERET DISTRIB-UNATTENDED 42.90 4.16 2.40
26 DEWEYVILLE DISTRIB-UNATTENDED 42.90 12.47 7.20
27 DIMPLEDELL DISTRIB-UNATTENDED 138.00 12.50
28 DIXIE DEER DISTRIB-UNATTENDED 34.50 12.47 7.20
29 DOG VALLEY DISTRIB-UNATTENDED 46.00 12.50
30 DRAGERTON DISTRIB-UNATTENDED 43.80 12.47 7.20
31 DRAPER DISTRIB-UNATTENDED 43.80 12.47 7.20
32 DUMAS DISTRIB-UNATTENDED 138.00 12.47 7.20
33 EAST BENCH DISTRIB-UNATTENDED 43.80 4.16 2.40
34 EAST HYRUM DISTRIB-UNATTENDED 43.80 12.47 7.20
35 EAST MILLCREEK DISTRIB-UNATTENDED 43.80 12.47 7.20
36 EAST PROVO DISTRIB-UNATTENDED 46.00 12.50 4.16
37 EDEN DISTRIB-UNATTENDED 43.80 12.47 7.20
38 ELBERTA DISTRIB-UNATTENDED 46.00 12.50
39 ELK MEADOWS DISTRIB-UNATTENDED 42.90 12.40 7.20
40 EL MONTE DISTRIB-UNATTENDED 132.00 45.00 6.60
FERC FORM NO.1 (ED.12-96)Page 426.11
Nameof Respondent I his Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
SUBS l A I 10NS (Continued)
5.Show in columns (I),(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 by
reason of sole ownership by the respondent.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 Number of CONVERSIONAPPARATUS AND SPECIAL EDUIPMENT Line
(In Service)(in MVa)Tran
erv
s TranSsoarœers Type of Equipment Number of Units Tot 62Paacity No.
(f)(g)(h)(i)(j)(k)
22 1 1
16 1 2
4
3 1 6
4 1 /
11 2 8
3 9
20 1 10
4 1 11
19 2 12
2 13
1 3 14
1 1b
2 3 1 /
1 18
19
1 20
28 1 22
6 1 23
24
2 1 2b
5 1 26
22 1 2/
2 1 28
22 2 31
20 1 32
5 1 33
3 1 34
22 1 3b
2 3 36
7 2 3/
4 1 38
1 3 39
40
FERCFORM NO.1 (ED.12-96)Page 427.11
Nameof Respondent I his Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
SUBS I A I lUNS
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 ELSINORE DISTRIB-UNATTENDED 44.00 12.47 7.20
2 EMERY CITY DISTRIB-UNATTENDED 69.00 12.47
3 EMIGRATION D1STRIB-UNATTENDED 43.80 12.47 7.20
4 EMMA PARK DISTRIB-UNATTENDED 132.00 12.47 7.20
5 ENTERPRISEVALLEY DISTRIB-UNATTENDED
6 EUREKA DISTRIB-UNATTENDED 46.00 12.50
7 FARMINGTON DISTRIB-UNATTENDED 43.80 12.47 7.20
8 FAYETTE DISTRIB-UNATTENDED 43.80 12.47 7.20
9 FERRON DISTRIB-UNATTENDED 69.00 12.50
10 FIDDLERS CANYON DISTRIB-UNATTENDED 34.50 12.50
11 FIELDING DISTRIB-UNATTENDED 44.00 12.47 7.20
12 FIFTH WEST DISTRIB-UNATTENDED 132.00 12.47 7.20
13 FLUX DISTRIB-UNATTENDED 42.90 12.47 7.20
14 FOOL CREEK DISTRIB-UNATTENDED 42.90 12.47 7.20
15 FOUNTAINGREEN DISTRIB-UNATTENDED
16 FREEDOM DISTRIB-UNATTENDED 45.00 12.47 7.20
17 FREEPORT DISTRIB-UNATTENDED 46.00 7.20 4.15
18 FRUIT HEIGHTS DISTRIB-UNATTENDED 43.80 12.47 7.20
19 GARDENCITY DISTRIB-UNATTENDED 67.00 12.47 7.20
20 GARKANE INTERIE DISTRIB-UNATTENDED 68.50 46.00 2.40
21 GATEWAY DISTRIB-UNATTENDED 69.00 34.50 12.50
22 GENEVA DISTRIB-UNATTENDED 132.00 13.80
23 GOSHEN UTAH DISTRIB-UNATTENDED 46.00 12.47
24 GRANTSVILLE DISTRIB-UNATTENDED 43.80 12.47 7.20
25 GRAVEL PIT DISTRIB-UNATTENDED 46.00 12.47
26 GREEN CANYON DISTRIB-UNATTENDED 132.00 45.00 6.60
27 GREEN RIVER DISTRIB-UNATTENDED 46.00 12.50
28 GRINDING DISTRIB-UNATTENDED 138.00 13.80
29 GROW DISTRIB-UNATTENDED 132.00 46.00 12.47
30 GUNNISON DISTRIB-UNATTENDED 45.00 50.00
31 HALE DISTRIB-UNATTENDED 43.80 12.47
32 HAMILTON FORT DISTRIB-UNATTENDED 34.00 12.47
33 HAMMER DISTRIB-UNATTENDED 138.00 12.47 7.20
34 HATCH DISTRIB-UNATTENDED 138.00 69.00
35 HAVASU DISTRIB-UNATTENDED 69.00 24.94 12.47
36 HELPER DISTRIB-UNATTENDED 120.00 45.00 6.60
37 HELPER CITY DISTRIB-UNATTENDED 45.00 4.16
38 HENEFER DISTRIB-UNATTENDED 43.50 12.47 7.20
39 HIAWATHA DISTRIB-UNATTENDED 44.00 24.00 4.16
40 HINKLEY DISTRIB-UNATTENDED 43.80 12.47 7.20
FERC FORM NO.1 (ED.12-96)Page 426.12
Name ot kespondent I his Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
SUBSI A I lUNS (Continued)
5.Show in columns (1),(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 Numberof Number of CONVERSIONAPPARATUS AND SPECIAL EQUIPMENT LineTransformersSpare(In Service)(In MVa)In Senrice Transformers Type of Equipment Number of Units Total Öapacity No.
(in MVa)(f)(g)(h)(i)(j)(k)
2 1 1
2 3 2
22 3 3
1 4
10 b
2 3 6
13 3 |
1 2 8
6 3 9
10
2 1 11
22 1 12
4 1 13
1 1 14
2 16
16
3 1/
14 1 18
7 1 19
20
21
22
2 1 23
5 1 24
3 2 27
13 1 31
20 1 33
34
3 3b
36
3 3 37
1 3 38
1 3 39
40
I
FERC FORM NO.1 (ED.12-96)Page 427.12
Name of Respondent I his Report is:Date ot keport Year of keport
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
SUBSIAlluNS
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 incolumn(f).
Line V3LTAGE (In MVa)
No.Name and Location of Substation Character of Substation Primary Secondary Tertiary
(a)(b)(c)(d)(e)
1 HOGGARD DISTRIB-UNATTENDED 132.00 12.47 7.20
2 HOGLE DISTRIB-UNATTENDED 43.80 12.47 7.20
3 HOLLADAY DISTRIB-UNATTENDED 43.80 12.47 7.20
4 HONEYVILLE DISTRIB-UNATTENDED 132.00 46.00 6.60
5 HURRICANE DISTRIB-UNATTENDED 67.00 12.47 7.20
6 HURRICANEBENCH DISTRIB-UNATTENDED 69.00 12.50
7 HURRICANEFIELDS DISTRIB-UNATTENDED 34.20 12.00 7.20
8 IRONTON DISTRIB-UNATTENDED 46.00 12.47
9 IVINS DISTRIB-UNATTENDED 34.40 12.47 7.20
10 JUAB DISTRIB-UNATTENDED 43.50 12.47 7.20
11 JUNCTION DISTRIB-UNATTENDED 69.00 12.47 7.20
12 KAIBAB DISTRIB-UNATTENDED 67.00 12.47 7.20
13 KAMAS DISTRIB-UNATTENDED 43.80 12.47 7.20
14 KANARAVILLE DISTRIB-UNATTENDED 34.40 12.47 7.20
15 KEARNS DISTRIB-UNATTENDED 43.80 12.47 7.20
16 KENSINGTON DISTRIB-UNATTENDED 43.80 4.16 2.40
17 KYUNE DISTRIB-UNATTENDED 46.00 7.20
18 LA-Z-BOY DISTRIB-UNATTENDED 43.80 12.47 7.20
19 LAKEPARK DISTRIB-UNATTENDED 132.00 12.47 7.20
20 LAKEPOINT DISTRIB-UNATTENDED 42.90 12.47 7.20
21 LAMPO DISTRIB-UNATTENDED 138.00 46.00
22 LARK DISTRIB-UNATTENDED 42.90 12.47 7.20
23 LASAL DISTRIB-UNATTENDED 67.00 12.50 7.20
24 LAYTON DISTRIB-UNATTENDED 43.80 12.47 7.20
25 LEGRANDE DISTRIB-UNATTENDED 43.80 12.47 7.20
26 LEWISTON DISTRIB-UNATTENDED 43.80 12.47 7.20
27 LINCOLN DISTRIB-UNATTENDED 43.80 12.47 7.20
28 LINDON DISTRIB-UNATTENDED 46.00 12.47 7.20
29 LISBON DISTRIB-UNATTENDED 67.00 12.50 7.20
30 LOAFER DISTRIB-UNATTENDED 46.00 12.50 7.20
31 LOGAN CANYON DISTRIB-UNATTENDED 46.00 7.20
32 LONETREE DISTRIB-UNATTENDED 34.50 19.90 12.47
33 LOST CREEK DISTRIB-UNATTENDED 46.20 7.20
34 LOWERBEAVER DISTRIB-UNATTENDED 44.00 12.00 6.60
35 LYNNDYL DISTRIB-UNATTENDED 43.90 12.50 7.20
36 MAESER DISTRIB-UNATTENDED 67.00 12.47 4.16
37 MANTUA DISTRIB-UNATTENDED 45.00 24.00 12.50
38 MAPLETON DISTRIB-UNATTENDED 46.00 12.50
39 MARRIOTT DISTRIB-UNATTENDED 43.80 12.47 7.20
40 MARYSVALE DISTRIB-UNATTENDED 43.70 9.10 5.20
FERC FORMNO.1 (ED.12-96)Page 426.13
Name of Respondent I his Report is:Date of Report Vear of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
SUHS I A I luNS (Continued)
5.Show in columns (I),(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 by
reason of sole ownership by the respondent.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.
Number of Numberof CONVERSIONAPPARATUSAND SPECIAL E2UIPMENT LineIan
ervic
)S s o Tran
e
cee TranSsoarœers Type of Equipment Numberof Units Tot Capaacity No.
(f)(g)(h)(¡)(j)(k)
1201
16 1 2
29 2 3
1 4
4 1 b
1 1 /
2 3 8
2 3 10
3 3 11
6 1 13
3 14
32 2 1b
6 1 16
2 1/
7 1 18
19
2 1 20
21
3 1 22
5 1 23
20 2 24
2 3 2b
14 1 26
22 1 2/
23 1 28
1 29
1 30
1 31
4 1 3b
13 1 36
1 3 3/
6 3 38
22 1 39
2 3 40
FERC FORM NO.1 (ED.12-96)Page 427.13
Name of Respondent t his Report Is:Date of keport Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
SUBS I A l lUNS
1.Report below the information called for conceming 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 V3LTAGE (In MVa)
No Nameand Location of Substation Character of Substation Primary Secondary Tertiary
(a)(b)(c)(d)(e)
1 MATHIS DISTRIB-UNATTENDED 43.80 12.47 7.20
2 MCCORNICKIRRIGATION DISTRIB-UNETTENDED 46.00 12.50
3 MCKAY DISTRIB-UNATTENDED 43.80 12.47 7.20
4 MEADOWBROOK DISTRIB-UNATTENDED 46.00 12.47 7.20
5 MEDICAL DlSTRIB-UNATTENDED 43.80 12.47 7.20
6 MELLING DISTRIB-UNATTENDED 34.40 4.20
7 MIDVALE DISTRIB-UNATTENDED 43.80 12.47 7.20
8 MIDWAY DISTRIB-UNATTENDED 132.00 45.00
9 MILFORD DISTRIB-UNATTENDED 42.90 12.47 7.20
10 MILFORD DISTRIB-UNATTENDED 46.00 7.20
11 MILLS DISTRIB-UNATTENDED 44.00 7.20
12 MILLVILLE DISTRIB-UNATTENDED 43.80 12.47 7.20
13 MINERALPRODUCTS DISTRIB-UNATTENDED 69.00 46.00 6.60
14 MINERSVlLLE DISTRIB-UNATTENDED 44.00 12.47 7.20
15 MOAB CITY DISTRIB-UNATTENDED 67.00 12.50 7.20
16 MONTEZUMA DISTRIB-UNATTENDED 69.00 12.40 7.20
17 MOORE DISTRIB-UNATTENDED 69.00 12.50 7.20
18 MORGAN DISTRIB-UNATTENDED 42.90 12.47 7.20
19 MORONI DISTRIB-UNATTENDED 43.80 12.47 7.20
20 MOSSJUNCTION DISTRIB-UNATTENDED 42.00 12.47 7.20
21 MOUNTAINDELL DISTRIB-UNATTENDED 43.80 12.40
22 MOUNTAINGREEN DISTRIB-UNATTENDED 43.80 12.47 7.20
23 NEBO DISTRIB-UNATTENDED 138.00 46.00
24 NEWHARMONY DISTRIB-UNATTENDED 69.00 12.47 7.20
25 NEWLAVERKIN DISTRIB-UNATTENDED 69.00 12.47 7.20
26 NEWGATE DISTRIB-UNATTENDED 43.80 12.47 7.20
27 NEWTON DISTRIB-UNATTENDED 43.80 12.47 7.20
28 NIBLEY DISTRIB-UNATTENDED 43.80 12.47
29 NORTH BENCH DISTRIB-UNATTENDED 43.80 12.47 25.00
30 NORTHEAST DISTRIB-UNATTENDED 41.80 12.47 7.20
31 NORTHFlELDS DISTRIB-UNATTENDED 42.90 12.47 7.20
32 NORTHHOLDENIRRIGATION DISTRIB-UNATTENDED 46.00 12.47 7.20
33 NORTHLOGAN DISTRIB-UNATTENDED 43.80 12.47 7.20
34 NORTHOGDEN DISTRIB-UNATTENDED 43.80 12.47 7.20
35 NORTHSALT LAKE DISTRIB-UNATTENDED 43.80 12.47 7.20
36 NORTHRIDGE DISTRIB-UNATTENDED 46.00 12.47 7.20
37 OAKLAND AVENUE DISTRIB-UNATTENDED 43.80 12.47 7.20
38 OAKLEY DISTRIB-UNATTENDED 42.90 12.47 7.20
39 OAK SPRINGS DISTRIB-UNATTENDED 46.00 12.47
40 OCKEY DISTRIB-UNATTENDED 46.00 7.20
FERC FORM NO.1 (ED.12-96)Page 426.14
Name of Respondent I his Report Is:lJate of Report Year of Report
PacifiCo (1)An Original (Mo,Da,Yr)Dec.31 2000(2)A Resubmission //
SUtsS I Al IONS(Continued)
5.Show in columns (I),(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 by
reason of sole ownership by the respondent.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 Number of CONVERSIONAPPARATUS AND SPECIAL EDUIPMENT Line
(In Service)(in MVa)Tran
erv
cee TranSsoarœers Type of Equipment Number of Units Tota apaacity No.
(f)(g)(h)(i)(J)(k)
9 1 1
6 1 2
22 1 3
22 1 4
36 4 b
5 1 6
16 1 /
2 11
13 1 12
13
2 3 14
16
13 1 16
4 1 1 /
5 3 18
5 1 19
2 3 20
7 1 22
1 23
1 24
2b
22 1 26
5 1 27
13 1 28
19 3 29
27 3 30
2 1.31
4 1 32
7 1.33
13 1 34
14 1 3b
1 36
2 3/
3 1 38
1 4U
FERC FORM NO.1 (ED.12-96)Page 427.14
Name of Respondent I nis Report is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
SUBSIAllbNS
1.Report below the information called for conceming 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 whetherattendedorunattended.At the end of the page,summarize according to function the capacities reported for the individual stations incolumn(f).
Line VOLTAGE (In MVa)
No.Name and Location of Substation Character of Substation Primary Secondary Tertiary
(a)(b)(c)(d)(e)
1 OLYMPUS DISTRIB-UNATTENDED 43.80 12.47 7.20
2 OPHIR DISTRIB-UNATTENDED 42.90 12.47 7.20
3 ORANGE DISTRIB-UNATTENDED 43.80 12.47 7.20
4 ORANGEVILLE DISTRIB-UNATTENDED 69.00 12.47
5 OREM DISTRIB-UNATTENDED 43.80 12.47 7.20
6 PANGUITCH DISTRIB-UNATTENDED 67.00 12.47 7.20
7 PARIETTE DISTRIB-UNATTENDED 43.80 25.00 14.40
8 PARRISH DISTRIB-UNATI ENDED 138.00 46.00 13.80
9 PARK CITY DISTRIB-UNATTENDED 43.80 12.47 7.20
10 PARK WAY DISTRIB-UNATTENDED 132.00 12.47 7.20
11 PARLEYS DISTRIB-UNATTENDED 43.80 12.47 7.20
12 PARRY DISTRIB-UNATTENDED 44.00 4.16 2.40
13 PELICAN POINT DISTRIB-UNATTENDED 46.00 12.50
14 PINECREEK DISTRIB-UNATTENDED 43.90 12.47 7.20
15 PINNACLE DISTRIB-UNATTENDED 46.00 12.47 7.20
16 PLEASANTGROVE DISTRIB-UNATTENDED 43.10 12.47
17 PLEASANTVIEW DISTRIB-UNATTENDED 43.80 12.47
18 PONDEROSA DISTRIB-UNATTENDED 44.00 6.60
19 PRICE DISTRIB-UNATTENDED 43.80 72.00 46.00
20 PROLER DISTRIB-UNATTENDED 46.00 2.40
21 PROMONTORY DISTRIB-UNATTENDED 44.00 12.47 7.20
22 QUAIL CREEK DISTRIB-UNATTENDED 34.50 12.47 7.20
23 QUARRY DISTRIB-UNATTENDED 46.00 12.47 7.20
24 QUITCHAPA DISTRIB-UNATTENDED 34.50 12.47 7.20
25 RAINS#2 DISTRIB-UNATTENDED 45.00 7.20
26 RANDOLPH DISTRIB-UNATTENDED 44.00 12.50 7.20
27 RASMUSSON DISTRIB-UNATTENDED 44.00 12.47 6.60
28 RATTLE SNAKE DISTRIB-UNATTENDED 67.00 24.94
29 REDNARROWS DISTRIB-UNATTENDED 46.00 12.50
30 RED ROCK DISTRIB-UNATTENDED 69.00 4.16
31 REDWOOD DISTRIB-UNATTENDED 43.80 12.47 7.20
32 RESEARCHPARK DISTRIB-UNATTENDED 43.80 12.47 7.20
33 RICH DISTRIB-UNATTENDED 67.00 12.47 7.20
34 RICHFIELD DISTRIB-UNATTENDED 43.80 12.47 7.20
35 RICHMOND DISTRIB-UNATTENDED 43.80 12.47 7.20
36 RIDGELAND DISTRIB-UNATTENDED 138.00 12.47 7.20
37 RIDINGRECEIVING DISTRIB-UNATTENDED 138.00 46.00 13.80
38 RITER DISTRIB-UNATTENDED 43.80 12.47 7.20
39 ROSE PARK DISTRIB-UNATTENDED 43.80 12.47 7.20
40 ROUNDVALLEY DISTRIB-UNATTENDED 46.00 7.20
FERC FORM NO.1 (ED.12-96)Page 426.15
Name of Respondent I his Report is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
SUBS I A I lUNS (Continued)
5.Show in columns (I),(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 by
reason of sole ownership by the respondent.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 Number of CONVERSIONAPPARATUS AND SPECIAL EQUIPMENT Line
(In Service)(In MVa)Tran
e
TranSsoarmers Type of Equipment Number of Units Total Capaacity No.
(f)(g)(h)(i)(j)(k)
22 1 1
3 1 2
22 3 3
13 1 4
28 2 b
5 1 6
4 1 |
8
25 2 9
22 1 10
17 2 11
4 12
3 3 13
2 1 14
14 1 16
28 1 16
5 1 1/
1 18
4 19
5 1 20
2 3 21
44 2 23
4 3 24
3 2b
2 1 26
3 2/
13 1 28
3 1 30
22 2 31
14 1 32
3 1 33
22 2 34
11 1 3b
22 2 36
20 1 38
27 3 39
40
FERC FORMNO.1 (ED.12-96)Page 427.15
Name of Respondent I his Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
SUdsIAI\0NS
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 V3LTAGE (In MVa)
No.Name and Location of Substation Character of Substation
-Primary Secondary Tertiary
(a)-(b)(c)(d)(e)
1 ROWLEY DISTRIB-UNATTENDED 132.00 13.80
2 ROYAL DISTRIB-UNATTENDED 46.00 12.50 4.16
3 SALINA DISTRIB-UNATTENDED 43.80 12.47 7.20
4 SANDY DISTRIB-UNATTENDED 43.80 12.47 7.20
5 SANPITCH DISTRIB-UNATTENDED 45.00 7.20
6 SANTAQUIN DISTRIB-UNATTENDED 46.00 12.50
7 SARATOGA DISTRIB-UNATTENDED 43.80 12.47
8 SCIPlO DISTRIB-UNATTENDED 42.00 7.20 12.47
9 SCOFIELD DISTRIB-UNATTENDED 46.00 12.50 7.20
10 SCOFIELD RESERVOIR DISTRIB-UNATTENDED 46.00 12.50 7.20
11 SECOND STREET DISTRIB-UNATTENDED 43.80 12.47 7.20
12 SEVEN MILE DISTRIB-UNATTENDED 69.00 12.47
13 SEVIER DISTRIB-UNATTENDED 132.00 7.20
14 SHARON DISTRIB-UNATTENDED 43.80 12.47 7.20
15 SINK DISTRIB-UNATTENDED 44.00 6.60
16 SILVER CREEK DISTRIB-UNATTENDED 134.50 46.00 13.80
17 SKULLVALLEY DISTRIB-UNATTENDED 41.80 12.47 7.20
18 SMITHFIELD DISTRIB-UNATTENDED 132.00 45.00 6.60
19 SNARR DISTRIB-UNATTENDED 43.80 12.47 7.20
20 SNYDERVILLE DISTRIB-UNATTENDED 43.80 12.47 7.20
21 SOLDIERSUMMIT DISTRIB-UNATTENDED 46.00 12.50
22 SOUTH EAST DISTRIB-UNATTENDED 46.50 12.47 7.20
23 SOUTH GRANGER DISTRIB-UNATTENDED 43.80 12.47 7.20
24 SOUTH MILFORD IRRIGATION DISTRIB-UNATTENDED 43.50 12.47 7.20
25 SOUTH MOUNTAIN DISTRIB-UNATTENDED 138.00 12.47 7.20
26 SOUTHOGDEN DISTRIB-UNATTENDED 43.80 12.47 7.20
27 SOUTH PARK DISTRIB-UNATTENDED 43.80 12.47 7.20
28 SOUTHWEST DISTRIB-UNATTENDED 43.80 12.47 7.20
29 SOUTHYARD DISTRIB-UNATTENDED 46.00 4.16 2.40
30 SPANISHVALLEY DISTRIB-UNATTENDED 69.00 12.50
31 SPRINGDALE DISTRIB-UNATTENDED 34.50 12.47
32 ST.JOHN DISTRIB-UNATTENDED 42.90 12.47 7.20
33 STANSBURY DISTRIB-UNATTENDED 43.80 12.47 7.20
34 SUMMIT PARK DISTRIB-UNATTENDED 43.80 12.47 7.20
35 SUNSTONE DISTRIB-UNATTENDED 43.80 7.20
36 SUPERIOR DISTRIB-UNATTENDED 67.00 12.40 7.20
37 SUTHERLAND DISTRIB-UNATTENDED 43.80 24.90 14.40
38 SWISS DISTRIB-UNATTENDED 44.00 12.47 7.20
39 TABIONA DISTRIB-UNATTENDED 66.00 11.95 4.16
40 TAYLOR DISTRIB-UNATTENDED 43.80 12.47 7.20
FERC FORM NO.1 (ED.12-96)Page 426.16
Name of Respondent I nis Report is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
SUBS I A l luNS (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 by
reason of sole ownership by the respondent.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 accounts
affected in respondent's books of account.Specify in each case whether lessor,co-owner,or other party is an associated company.
Number of Number of CONVERSIONAPPARATUS AND SPECIAL EQUIPMENT LineIan
rvice)
Ibnso Tran
erv
s TranSsoarœers Type of Equipment Number of Units Tot Capaacity No.
(f)(g)(h)(i)(j)(k)
63 1 1
3 2
9 3 3
22 1 4
6 1 6
4 1 /
1 3
1 3
1 10
7 2 11
2 3 12
13
20 1 14
1 ib
1 16
2 1 1 /
18
27 3 19
13 1 20
2 21
29 4 22
23
1 24
25 2 26
13 1 2/
25 1 28
6 1 30
6 3 33
5 3 34
3b
9 1 36
3 1 3/
1 38
4 1 39
11 1 40
FERC FORM NO.1 (ED.12-96)Page 427.16
Name of Respondent I his Report is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
SUBS lAl IONS
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 M7a)
No Name and Location of Substation Character of Substation Primary Secondary Tertiary
(a)(b)(c)(d)(e)
1 THIEF CREEK DISTRIB-UNATTENDED 132.00 25.00 14.40
2 THIRDWEST DISTRIB-UNATTENDED 43.80 12.47 7.20
3 THIRTEENTHSOUTH DISTRIB-UNATTENDED 41.80 12.47 7.20
4 THISTLE DISTRIB-UNATTENDED 46.00 12.47 7.20
5 THOMPSON DISTRIB-UNATTENDED 45.00 7.20 4.16
6 TIMP DISTRIB-UNATTENDED 130.00 46.00 7.20
7 TWENTYTHIRDSTREET OGDEN DISTRIB-UNATTENDED 43.80 4.16 2.30
8 UINTAH DISTRIB-UNATTENDED 43.80 12.47 7.20
9 UNION DISTRIB-UNATTENDED 43.80 12.47 7.20
10 UNIVERSITY DISTRIB-UNATTENDED 43.80 12.47 7.20
11 UPALCO DISTRIB-UNATTENDED 138.00 69.00 12.50
12 UTE DISTRIB-UNATTENDED 69.00 7.20
13 VALLEY CENTER DISTRIB-UNATTENDED 43.80 12.47 7.20
14 VERMILLION DISTRIB-UNATTENDED 46.00 12.47 7.20
15 VERNAL DISTRIB-UNATTENDED 67.00 12.47 7.20
16 VICKERS DISTRIB-UNATTENDED 44.00 12.47
17 VINE YARD DISTRIB-UNATTENDED 46.00 12.47 7.20
18 WALLSBURG DISTRIB-UNATTENDED 132.00 12.47 7.20
19 WARREN DISTRIB-UNATTENDED 132.00 12.47 7.20
20 WASATCH DISTRIB-UNATTENDED 41.80 12.74 7.20
21 WASHAKIE DISTRIB-UNATTENDED 132.00 4.16 2.40
22 WELBY DISTRIB-UNATTENDED 43.80 12.47 7.20
23 WELFARE DISTRIB-UNATTENDED 46.00 12.50
24 WELLINGTON DISTRIB-UNATTENDED 46.00 12.50
25 WESTCOMMERCIAL DISTRIB-UNATTENDED 43.80 12.50 7.20
26 WESTJORDAN DISTRIB-UNATTENDED 138.00 12.47 7.20
27 WESTOGDEN DISTRIB-UNATTENDED 132.00 12.47 7.20
28 WEST ROY DISTRIB-UNATTENDED 43.80 12.47 7.20
29 WESTTEMPLE DISTRIB-UNATTENDED 43.80 4.16 7.20
30 WHITE MESA DISTRIB-UNATTENDED 67.00 12.47 7.20
31 WILLOWCREEK DISTRIB-UNATTENDED 44.00 12.47
32 WINKLEMAN DISTRIB-UNATTENDED 45.00 7.20 5.00
33 WOLF CREEK DISTRIB-UNATTENDED 69.00 12.50 4.16
34 WOODRUFF DISTRIB-UNATTENDED 44.00 12.47 7.20
35 WOODS CROSS DISTRIB-UNATTENDED 43.80 12.47 7.20
36 WOODSIDE DISTRIB-UNATTENDED 46.00 12.50 4.00
37 WYUTA DISTRIB-UNATTENDED 43.80 12.47 7.20
38 TOTAL 18164.00 4500.43 1742.22
39 NUMBEROF SUBSTATIONS -DISTRIBUTION-306
40
FERC FORMNO.1 (ED.12-96)Page 426.17
Name of Respondent i his Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission I /
SUBSI A I luNS (Continued)
5.Show in columns (I),(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 by
reason of sole ownership by the respondent.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 accounts
affected in respondent's books of account.Specify in each case whether lessor,co-owner,or other party is an associated company.
Capacity of Substation Number ot Number of CONVERSION APPARATUS AND SPECIALEQUIPMENT LineTransformersSpare(in Service)(In MVa)In Service Transformers Type of Equipment Number of Units Total Ôapacity No.
(In MVa)
(f)(g)(h)(i)(j)(k)
13 1 1
24 2 2
24 2 3
1 1 4
1 b
3 /
17 2
36 2 9
5 10
11
1 12
22 1 13
3 1 14
33 2 16
2 1 16
13 1 1 /
14 1 18
10 1 19
2 1 20
13 1 21
25 2 22
3 3 23
4 3 24
24 2 2b
1 26
22 1 27
22 1 28
53 2 29
5 1 30
2 1 31
1 32
5 1 33
2 3 34
22 1 35
1 3/
2412 403 38
I 40
FERC FORMNO.1 (ED.12-96)Page 427.17
Name of Respondent I ms Report Is:Date of keport Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
SUBSIAI luNS
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 MVaexcept those serving customers with energy for resale,may be grouped accordingtofunctionalcharacter,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 whetherattendedorunattended.At the end of the page,summarize according to function the capacities reported for the individual stations incolumn(f).
Line VOLTAGE (in MVa)
No Name and Location of Substation Character of Substation Primary Secondary Tertiary
(a)(b)(c)(d)(e)
2 ABAJO TRANS-ATTENDED 138.00 69.00
3 ANGEL TRANS-ATTENDED 138.00 46.00 12.50
4 ASHLEY TRANS-ATTENDED 135.00 69.00
5 BARNEY TRANS-ATTENDED 138.00 44.00
6 BENLOMOND TRANS-ATTENDED 345.00 230.00 138.00
7 BLACK HAWK TRANS-ATTENDED 67.00 45.00 6.60
8 BOOK CLIFFS TRANS-ATTENDED 69.00 44.00 2.40
9 COLEMAN TRANS-ATTENDED 138.00 69.00 34.50
10 COTTONWOOD TRANS-ATTENDED 132.00 46.00 12.47
11 HIGHLAND TRANS-ATTENDED 138.00 46.00 12.50
12 HORSESHOE TRANS-ATTENDED 132.00 43.80 12.47
13 HUNTER TRANS-345.00 138.00 43.80
14 HUNTINGTONCITY TRANS-ATTENDED 67.00 43.80 12.50
15 JERUSALEM TRANS-UNATTENDED 138.00 46.00
16 JORDAN TRANS-ATTENDED 138.00 46.00 12.47
17 LAVERKIN TRANS-ATTENDED 138.00 69.00 34.50
18 MCCLELLAND TRANS-UNATTENDED 132.00 12.00
19 MCFADDEN TRANS-ATTENDED 138.00 69.00 13.80
20 MlDDLETON TRANS-ATTENDED 132.00 69.00 34.50
21 MID-VALLEY TRANS-UNATTENDED 345.00 138.00
22 MOAB TRANS-ATTENDED 132.00 69.00 12.47
23 NINETY SOUTH TRANS-ATTENDED 345.00 138.00 46.00
24 OQUIRRH TRANS-ATTENDED 138.00 46.00 13.80
25 PAROWAN VALLEY TRANS-ATTENDED 230.00 138.00 34.50
26 PAVANI TRANS-230.00 46.00 13.80
27 PlNTO TRANS-ATTENDED 345.00 138.00 69.00
28 RIVERDALE TRANS-ATTENDED 132.00 45.00 12.47
29 SIGURD TRANS-345.00 230.00 138.00
30 SIXTH SOUTH TRANS-ATTENDED 138.00 43.80 12.47
31 SNOWVILLE TRANS-ATTENDED 69.00 43.80 12.47
32 SPANISH FORK TRANS-345.00 138.00 46.00
33 SPHINX TRANS-ATTENDED 115.00 45.00 12.47
34 SYRACUSE TRANS-ATTENDED 138.00 46.00 12.47
35 TAYLORSVILLE TRANS-ATTENDED 138.00 46.00 13.80
36 TERMINAL TRANS-ATTENDED 345.00 230.00 138.00
37 TOOELE TRANS-ATTENDED 132.00 45.00 6.60
38 WEST CEDAR TRANS-230.00 138.00 34.50
39 WEST WATER TRANS-ATTENDED 67.00 43.00 12.47
40 WINCHESTER HILLS TRANS-ATTENDED 34.50 34.50 12.47
FERCFORM NO.1 (ED.12-96)Page 426.18
Name of Respondent I his Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission I /
SUBS I A I lUNS (continued)
5.Show in columns (I),(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 by
reason of sole ownership by the respondent.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 accounts
affected in respondent'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 CONVERSIONAPPARATES AND SPECIAL EDUIPMENT Line
(In Service)(In MVa)TransfeNreers TranSsoarmers Type of Equipment Numberof Units Tot ÖapaacityNo.
(f)(g)(h)(i)(j)(k)
1
40 1 2
87 2 3
134 2 4
112 1 b
1734 5 6
25 1 /
6 3 8
77 3 9
112 4 10
40 2 11
2 1 12
53 2 14
75 1 16
13 6 16
8 1 1/
320 3 18
45 1 19
116 3 20
500 1 21
6 4 22
978 6 23
75 1 24
117 1 2b
2 26
257 3 27
22 2 28
4 29
22 1 30
6 1 31
20 3 33
42 3 34
22 1 3b
492 1 36
22 2 37
1 38
1 3 39
1 1 40
FERC FORM NO.1 (ED.12-96)Page 427.18
Nameof kespondent I nis Report is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
SUBSIAHUNS
1.Report below the information called for conceming 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 exceptthose 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 TOTAL 6791.50 3085.70 1036.77
2 NUMBER OF SUBSTATIONS -TRANSMISSION -39
3
4
5 WASHINGTON
6 CENTRALIA COAL HANDLING DISTRIB-UNATTENDED 34.50 4.16
7 TOTAL 34.50 4.16
8 NUMBER OF SUBSTATIONS -DISTRIBUTION-1
9
10 CENTRAL TRANS-UNATTENDED 69.00 12.00 4.16
11 CENTRALIA COAL MINE TRANS-UNATTENDED 230.00 34.50
12 OUTLOOK TRANS-UNATTENDED 230.00 115.00
13 POMONA HEIGHTS TRANS-UNATTENDED 230.00 115.00
14 WALLA WALLA TRANS-ATTENDED 230.00 69.00
15 WALLULA TRANS-UNATTENDED 230.00 69.00
16 TOTAL 1219.00 414.50 4.16
17 NUMBER OF SUBSTATIONS -TRANSMISSION -6
18
19
20 ATTALIA TID-UNATTENDED 69.00 12.50
21 BOWMAN STREET T/D-UNATTENDED 69.00 12.50
22 CASCADE KRAFT T/D-UNATTENDED 69.00 12.47 4.10
23 CLINTON T/D-UNATTENDED 115.00 13.20
24 DAYTON T/D-UNATTENDED 69.00 7.20
25 DODD RD T/D-UNATTENDED 69.00 20.80
26 GRANDVIEW T/D-UNATTENDED 115.00 12.50
27 HOPLAND T/D-UNATTENDED 115.00 12.50
28 MILLCREEK T/D-UNATTENDED 69.00 12.50
29 NOB HILL T/D-UNATTENDED 115.00 12.50
30 NORTH PARK T/D-UNATTENDED 115.00 12.50
31 ORCHARD T/D-UNATTENDED 115.00 12.50
32 PACIFIC T/D-UNATTENDED 115.00 12.50
33 PASCO T/D-UNATTENDED 115.00 69.00 7.20
34 POMEROY T/D-UNATTENDED 69.00 12.50
35 PROSPECT POINT T/D-UNATTENDED 69.00 12.50
36 PUNKIN CENTER T/D-UNATTENDED 115.00 12.50
37 RIVER ROAD T/D-UNATTENDED 115.00 12.50
38 SELAH T/D-UNATTENDED 115.00 12.50
39 SULPHER CREEK TID-UNATTENDED 115.00 12.50
40 SUNNYSIDE T/D-UNATTENDED 115.00 12.50
FERC FORM NO.1 (ED.12-96)Page 426.19
Name of Respondent ihis Report is:lJate of keport Year of keport
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
SUBS I A I IUNS (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 by
reason of sole ownership by the respondent.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 accounts
affected in respondent'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 EDUIPMENT Line
(In Service)(In MVa)n e
cee TranSsoarmers Type of Equipment Number of Units Total ÖMapaacityNo.
(f)(g)(h)(i)(j)(k)
5582 83 1
4
1 1 6
1 1 /
26 2 10
31 1 11
125 1 12
56 2 13
300 2 14
120 2 15
658 10 16
1/
18
19
25 1 20
45 2 21
118 6 22
25 1 23
10 1 24
25 2 25
42 2 26
34 2 2/
45 3 28
42 2 29
45 2 30
45 2 31
28 3 32
15 3 33
6 1 34
40 2 3b
19 2 36
51 4 3/
40 2 38
67 39
45 2 40
FERCFORM NO.1 (ED.12-96)Page 427.19
Name of Respondent ihis Report Is:Date ot Report Year ot Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
SUBS I Al IONS
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 TIETON T/D-UNATTENDED 115.00 34.50 12.47
2 TOPPENISH TID-UNATTENDED 115.00 12.50
3 TOUCHET T/D-UNATTENDED 69.00 12.50
4 UNION GAP T/D-ATTENDED 230.00 115.00 12.50
5 VOELKER T/D-ATTENDED 115.00 12.50
6 WAITSBURG T/D-UNATTENDED 69.00 7.20
7 WAPATO T/D-UNATTENDED 115.00 12.50
8 WENAS T/D-UNATTENDED 115.00 12.50
9 WHITE SWAN T/D-UNATTENDED 69.00 12.50
10 WILEY T/D-UNATTENDED 115.00 12.50
11 TOTAL 3174.00 566.87 36.27
12 NUMBER OF SUBSTATIONS -TRANS/DISTRIB -31
13
14 WYOMING
15 AIRBASE DISTRIB-UNATTENDED 12.50 4.16
16 ALKALI ANTICLINE DISTRIB-UNATTENDED 34.50 4.16
17 ANTELOPE MINE DISTRIB-UNATTENDED 230.00 34.50
18 BAILEY DOME DISTRIB-UNATTENDED 34.50 13.80 2.40
19 BAIROIL DISTRIB-UNATTENDED 115.00 57.00 34.50
20 BARX DISTRIB-UNATTENDED 230.00 34.50
21 BELLAMY NO 2 DISTRIB-UNATTENDED 115.00 34.50
22 BIG MUDDY DISTRIB-UNATTENDED 69.00 12.50
23 BLACKS FORK DISTRIB-UNATTENDED 230.00 34.50
24 BLUFF#1 DISTRIB-UNATTENDED 34.50 4.16
25 BRYAN DISTRIB-UNATTENDED 115.00 12.50
26 BUFFALO-TOWN DISTRIB-UNATTENDED 20.80 2.40
27 BYRON DISTRIB-UNATTENDED 34.50 4.10
28 CASSA DISTRIB-UNATTENDED 57.00 20.80 12.47
29 CENTER STREET DISTRIB-UNATTENDED 115.00 4.16
30 CHATHAM DISTRIB-UNATTENDED 34.50 4.16
31 CHUKAR DISTRIB-UNATTENDED 12.50 4.00
32 COLTER DISTRIB-UNATTENDED 34.50 2.40
33 COLUMBIA-GENEVASTL DISTRIB-UNATTENDED 230.00 13.20
34 COLUMBINE DISTRIB-UNATTENDED 20.80 2.40
35 COMMUNITYPARK DISTRIB-UNATTENDED 69.00 12.50
36 COWLEY-DEAVER(DEAVERTOWN)DISTRIB-UNATTENDED 34.50 4.10
37 CROOKS GAP DISTRIB-UNATTENDED 34.50 13.80
38 DEERCREEK DISTRIB-UNATTENDED 69.00 12.50
39 DOUGLAS DISTRIB-UNATTENDED 57.00 4.00
40 DRY FORK DISTRIB-ATTENDED 69.00 4.00
FERCFORM NO.1 (ED.12-96)Page 426.20
Name of Respondent I his Report is:Date ot Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
SUBSI A I IONS(Continued)
5.Show in columns (I),(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 by
reason of sole ownership by the respondent.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 accounts
affected in respondent's books of account.Specify in each case whether lessor,co-owner,or other party is an associated company.
Capacity of Substation Numberof Number of CONVERSIONAPPARATLS AND SPECIAL EDUIPMENT Line
(In Service)(In MVa)Tran eo ceeœ TranSsoarmers Type of Equipment Numberof Units Tot ÔMapaacityNo.
(f)(g)(h)(i)(j)(k)
22 2 1
50 2 2
6 1 3
348 5 4
25 1 b
6 1 6
45 2 /
13 1 8
21 2 9
45 2 10
1393 64 11
14
1 1 16
1 16
25 1 1/
18
53 3 19
20 1 20
150 2 23
1 24
25 1 2b
2 1 26
1 1 2/
1 2 28
13 1 29
1 30
1 31
1 32
45 2 33
1 34
40 2 3b
1 36
2 1 37
6 1 38
6 1 39
9 1 40
FERC FORMNO.1 (ED.12-96)Page 427.20
Name of Respondent I his Report Is.Date of Report Year ot Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
SUBS I A I lUNS
1.Report below the information called for concerning substations of the respondent as of the end of the year.
2.Substations which selve 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 incolumn(f).
Line VOLTAGE (In MVa)
No Name and Location of Substation Character of Substation Primary Secondary Tertiary
(a)(b)(c)(d)(e)
1 EMIGRANT DISTRIB-ATTENDED 115.00 12.47
2 EVANS DISTRIB-UNATTENDED 69.00 13.20
3 FAIR GROUNDS DISTRIB-UNATTENDED 69.00 12.00
4 FARMERS UNION DISTRIB-UNATTENDED 34.50 4.16
5 FETTERMAN DISTRIB-UNATTENDED 13.20 2.40
6 FORT CASPER DISTRIB-ATTENDED 69.00 12.50
7 FORT SANDERS DISTRIB-UNATTENDED 115.00 13.20
8 FRONTSTREET DISTRIB-UNATTENDED 13.80 2.40
9 GALLUP DISTRIB-UNATTENDED 34.50 2.40
10 GLENDO DISTRIB-UNATTENDED 57.00 4.00
11 GLENROCK DISTRIB-UNATTENDED 69.00 4.10
12 GREAT DIVIDE DISTRIB-UNATTENDED 115.00 34.50
13 GREEN RIVER DISTRIB-UNATTENDED 34.50 4.16
14 GREY BULL DISTRIB-UNATTENDED 34.50 4.16
15 HANNA DISTRIB-ATTENDED 34.50 13.20
16 JACKALOPE DISTRIB-UNATTENDED 115.00 12.50
17 LABONTE DISTRIB-ATTENDED 13.80 2.40
18 LANDER DISTRIB-UNATTENDED 34.50 12.50
19 LARAMIE DISTRIB-UNATTENDED 115.00 13.20
20 LARAMIE PLANT DISTRIB-UNATTENDED 13.20 2.40
21 LINCH DISTRIB-UNATTENDED 69.00 13.80
22 LOVELL (LOVELL TOWN)DISTRIB-UNATTENDED 34.50 4.16
23 MANDERSON DISTRIB-UNATTENDED 34.50 2.40
24 MEDICINE WHEEL DISTRIB-UNATTENDED 34.50 4.16
25 MILL IRON DISTRIB-UNATTENDED 34.50 13.09
26 MILLS DISTRIB-UNATTENDED 12.50 4.16
27 MOXA DISTRIB-UNATTENDED 69.00 2.40
28 MURPHY DOME DISTRIB-UNATTENDED 34.50 12.50
29 ORIN DISTRIB-UNATTENDED 57.00 7.20
30 ORPHA DISTRIB-UNATTENDED 57.00 7.20
31 PAC.FRUIT EXPRESS DISTRIB-UNATTENDED 13.20 2.40
32 PARCO DISTRIB-UNATTENDED 34.50 13.20
33 PARK STREET DISTRIB-UNATTENDED 34.50 4.10
34 PITCHFORK DISTRIB-UNATTENDED 69.00 24.90
35 PLATTE PIPE NATURAL DISTRIB-UNATTENDED 57.00 2.40
36 PLATTE RIVER DJ DISTRIB-UNATTENDED 69.00 7.20
37 POISON SPIDER DISTRIB-UNATTENDED 69.00 2.40
38 POPLAR STEET DISTRIB-UNATTENDED 12.50 4.00
39 RAINBOW DISTRIB-UNATTENDED 230.00 34.50 13.20
40 RED BUTTE DISTRIB-UNATTENDED 69.00 12.50
FERC FORM NO.1 (ED.12-96)Page 426.21
Name of Respondent i nas Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
SUBS I A I luNs (continued)
5.Show in columns (I),(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 by
reason of sole ownership by the respondent.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 accounts
affected in respondent's books of account.Specify in each case whether lessor,co-owner,or other party is an associated company.
Number of Number of CONVERSION APPARATUS AND SPECIAL EQUIPMENT LineIancervi
)
s o Tran
en
cee TranSsoarœers Type of Equipment Number of Units Total ÖMapaacityNo.
(f)(g)(h)(i)(j)(k)
13 1 1
9 1 3
1 1 4
3 1 b
25 1 6
13 1 /
1 1 8
4 1 9
1 10
3 1 11
20 1 12
1 1 13
3 1 14
6 1 16
25 1 16
1 1 1/
13 1 18
9 1 19
1 1 20
13 1 21
3 1 22
1 23
1 24
13 1 2b
1 1 26
1 2/
5 1 28
1 29
1 1 30
1 31
3 1 32
1 1 33
4 2 34
1 3b
1 1 36
3 1 3/
3 1 38
13 1 39
20 1 40
FERC FORM NO.1 (ED.12-96)Page 427.21
Name of Respondent I his Report is:Date of keport Year ot keport
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
SUBSI A I IUNS
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 e×cept 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 V3LTAGE (In MVa)
No Name and Location of Substation Character of Substation Primary Secondary Tertiary
(a)(b)(c)(d)(e)
1 REFINERY DISTRIB-UNATTENDED 115.00 12.50
2 RELIANCE DISTRIB-UNATTENDED 34.50 2.40
3 RESERVOIR DISTRIB-UNATTENDED 12.50 4.00
4 RIVERDOME DISTRIB-UNATTENDED 34.50 4.00
5 SAGEHILL DISTRIB-UNATTENDED 34.50 13.80
6 SERVICEPIPE-MIDWESTHT'S DISTRIB-UNATTENDED 69.00 2.40
7 SERVICEPIPE IND STA DISTRIB-UNATTENDED 34.50 2.40
8 SHOSHONI DISTRIB-UNATTENDED 34.50 2.40
9 SINCLAIR DISTRIB-UNATTENDED 34.50 2.40
10 SOUTHCODY DISTRIB-UNATTENDED 69.00 25.00
11 SOUTHELK BASIN DISTRIB-UNATTENDED 34.50 7.20 4.00
12 SPRINGCREEK DISTRIB-UNATTENDED 115.00 13.20
13 STANDARDOIL DISTRIB-ATTENDED 69.00 2.40
14 SVILAR DISTRIB-UNATTENDED 34.50 2.40
15 TEAPOT DISTRIB-UNATTENDED 69.00 12.50
16 TEN MILE DISTRIB-UNATTENDED 69.00 34.50
17 THERMOPOLISTOWN DISTRIB-UNATTENDED 34.50 4.00
18 VETERANS DISTRIB-ATTENDED 34.50 13.20
19 WAMSUTTER DISTRIB-UNATTENDED 34.50 2.40
20 WARM SPRINGSSPL DISTRIB-UNATTENDED 115.00 2.40
21 WELCH DISTRIB-UNATTENDED 57.00 2.40
22 WERTZ-SINCLAIR DISTRIB-UNATTENDED 57.00 13.80 4.00
23 WESTADAMS DISTRIB-UNATTENDED 34.50 4.16
24 WORLAND DISTRIB-UNATTENDED 115.00 34.50
25 WORLANDTOWN DISTRIB-UNATTENDED 34.50 4.16
26 TOTAL 5756.30 939.84 70.57
27 NUMBEROF SUBSTATIONS -DISTRIBUTION -91
28
29
30 BUFFALO TRANS-UNATTENDED 230.00 20.80
31 CASPER TRANS-UNATTENDED 230.00 115.00 69.00
32 D.J.COAL MINE TRANS-UNATTENDED 69.00 34.50
33 ELK BASIN TRANS-ATTENDED 7.20 34.50
34 FIRE HOLE TRANS-UNATTENDED 230.00 34.50
35 FRANNIE TRANS-UNATTENDED 230.00 34.50
36 GARLAND TRANS-UNATTENDED 230.00 34.50
37 GLENDO-AUTO TRANS-UNATTENDED 69.00 57.00
38 GRASS CREEK TRANS-UNATTENDED 230.00 34.50
39 HILLTOP TRANS-ATTENDED 115.00 34.50 20.80
40 LITTLE MOUNTAIN TRANS-UNATTENDED 230.00 34.50
FERC FORM NO.1 (ED.12-96)Page 426.22
Name of Respondent I his Report is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
SUBS IA1ldNS (Continued)
5.Show in columns (I),(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 by
reason of sole ownership by the respondent.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 accounts
affected in respondent'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 E~)UIPMENT Line
(In Service)(In MVa)Transfeo rs TranS arœers Type of Equipment Number of Units Tot Capaacity No.
(f)(g)(h)(i)(j)(k)
45 2 1
1 2
1 1 3
1 4
6 1 b
4 1 6
1 1 8
1 1 9
5 1 10
1 2 11
20 1 12
16 2 13
1 1 14
2 1 16
13 1 16
5 1 1/
25 2 18
1 1 19
20
1 21
1 2 22
3 1 23
13 1 24
5 1 2b
803 97 26
20 1 30
565 6 31
13 1 32
5 1 33
25 1 34
50 2 3b
45 2 36
8 1 3/
25 1 38
45 2 39
20 1 40
FERC FORMNO.1 (ED.12-96)Page 427.22
Name ot Respondent I his Report Is:Date ot Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
SUBSIAI10NS
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 Tediary
(a)(b)(c)(d)(e)
1 MUSTANG TRANS-UNATTENDED 230.00 115.00
2 OREGON BASIN TRANS-UNATTENDED 230.00 34.50
3 PLATTE TRANS-UNATTENDED 230.00 115.00 34.50
4 POINT OF ROCKS TRANS-UNATTENDED 230.00 34.50
5 RIVERTON TRANS-UNATTENDED 230.00 34.50 12.50
6 ROCKSPRINGS TRANS-UNATTENDED 230.00 34.50
7 SALT CREEK PAN AM TRANS-UNATTENDED 69.00 34.50
8 SOUTHTRONA TRANS-UNATTENDED 230.00 34.50
9 WESTVACO TRANS-UNATTENDED 230.00 34.50
10 WYOPO TRANS-UNATTENDED 230.00 34.50
11 YELLOWCAKE TRANS-UNATTENDED 230.00 34.50
12 TOTAL 4239.20 1009.30 136.80
13 NUMBER OF SUBSTATIONS -TRANSMISSION -22
14
15
16 ASTLE T/D-UNATTENDED 34.50 13.20
17 BRIDGERPUMP T/D-UNATTENDED 230.00 34.50 13.20
18 MANSFACE T/D-UNATTENDED 230.00 34.50
19 MIDWEST T/D-UNATTENDED 230.00 69.00 34.50
20 MINERS T/D-UNATTENDED 230.00 115.00 34.50
21 ROCKSPRINGSPLANT T/D-UNATTENDED 34.50 13.80 2.40
22 TOTAL 989.00 280.00 84.60
23 NUMBER OF SUBSTATIONS-TRANS/DISTRIB -6
24 SUMMARY OF SUBSTATIONS
25
26 CALIFORNIA
27 DISTRIBUTION -31
28 TRANSMISSION -8
29 TRANS/DISTRIB-17
30
31 IDAHO
32 DISTRIBUTION -63
33 TRANSMISSION -14
34
35 OREGON
36 DISTRIBUTION -91
37 TRANSMISSION -35
38 TRANS/DISTRIB-116
39
40 UTAH
FERC FORMNO.1 (ED.12-96)Page 426.23
Name of Respondent I his Report Is:Date of Report Ÿear of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
SUBS l A I luNS (Continued)
5.Show in columns (I),(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 by
reason of sole ownership by the respondent.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 accounts
affected in respondent's books of account.Specify in each case whether lessor,co-owner,or other party is an associated company.
Capacity of Substation Number ot Number of CONVERSIONAPPARATUS AND SPECIAL EQUlPMENT LineTransformersSpare(In Senrice)(In MVa)In Service Transformers Type of Equipment Numberof Units Total Ôapacity No.
(In MVa)(f)(g)(h)(i)(j)(k)
200 2 1
75 3 2
240 4 3
20 1 4
50 3 b
50 2 b
40 2 /
150 2 8
75 3 9
20 1 10
25 1 11
1766 43 12
14
15
13 1 16
73 4 1/
20 1 18
90 4 19
58 3 2U
11 2 21
265 15 22
158 5 2/
344 9 28
327 25 29
3U
31
711 67 32
2296 34 33
34
802 107 3b
6345 64 3/
4306 210 38
40
FERC FORM NO.1 (ED.12-96)Page 427.23
Name of Respondent I his Report is:Date ot keport Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
SUBSIAIlUNS
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 incolumn(f).
Line V3LTAGE (In MVa)
No.Name and Location of Substation Character of Substation Primary Secondary Tertiary
(a)(b)(c)(d)(e)
1 DISTRIBUTION -306
2 TRANSMISSION -39
3
4 WASHINGTON
5 DISTRIBUTION -1
6 TRANSMISSION -6
7 TRANS/DISTRIB -31
8
9 WYOMING
10 DISTRIBUTION -91
11 TRANSMISSION -22
12 TRANS/DISTRIB -6
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 426.24
Name of Respondent I nis Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
SUdb l A I luNS (Contmued)
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 by
reason of sole ownership by the respondent.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 accounts
affected in respondent's books of account.Specify in each case whether lessor,co-owner,or other party is an associated company.
Capacity of Substation Nurnber of Number of CONVERSIONAPPARATES AND SPECIAL EDUIPMENT 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)
2412 403 1
5582 83 2
4
1 1 b
658 10 6
1393 64 |
803 97 10
1766 43 11
265 15 12
13
14
24
34
40
i
FERC FORM NO.1 (ED.12-96)Page 427.24
Name of Respondent I his Report is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
ELECI MU DISI RIBU I ION Mb I BRS AND LINt i NANSPORMbHS
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 LINETRANSFORMERS
No.Meters Number I otal capacity (in (MVa)
(a)(b)(c)(d)
1 Numberat Beginning of Year 1,623,057 427,538 14,497
2 Additions During Year
3 Purchases 84,756 14,668 497
4 Associated with Utility Plant Acquired
5 TOTAL Additions (Enter Total of lines 3 and 4)84,756 14,668 497
6 Reductions During Year
7 Retirements 26,667 9,489 321
8 Associated with Utility Plant Sold
9 TOTAL Reductions (Enter Total of lines 7 and 8)26,667 9,489 321
10 Number at End of Year (Lines 1 +5 -9)1,681,146 432,717 14,673
11 In Stock 28,313 8,477 287
12 Locked Meters on Customers'Premises
13 Inactive Transformers on System
14 In Customers'Use 1,652,833 424,240 14,386
15 In Company's Use
16 TOTAL End of Year (Total 11 to 15.This should equal line 10)1,681,146 432,717 14,673
FERC FORM NO.1 (ED.12-88)Page 429
Nameof Respondent I his Report Is:IJate of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission //
t-Nv lNUNivlENI AL i-ku l bu l luN NAblLl l lEo
1.For purposes of this response,environmental protection facilities shall be defined as any building,structure,equipment,facility,or
improvement designed and constructed solely for control,reduction,prevention or abatement of discharges or releases into the
environment of gaseous,Liquid,or solid substances,heat,noise or for the control,reduction,prevention,or abatement of any other
adverse impact of an activity on the environment.
2.Report the differences in cost of facilities installed for environmental considerations over the cost of alternative facilities which would
otherwise be used without environmental considerations.Use the best engineering design achievable without environmental
restrictions as the basis for determining costs without environmental considerations.It is not intended that special design studies be
made for purposes of this response.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 or
modified in connection with the production,transmission,and distribution of electrical energy and shall be reported herein for all such
environmental facilities placed in service on or after January 1,1969,so long as it is readily determinable that such facilities were
constructed or modified for environmental rather than operational purposes.Also report similar expenditures for environmental plant
included in construction work in progress.Estimate the cost of facilities when the original cost is not available or facilities are jointly
owned with another utility,provided the respondent explains the basis of such estimations.Examples of these costs would include a
portion of the costs of tall smokestacks,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 such
estimations in a footnote.
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)mufflers
environmentally clean fuels such as Low ash or low (3)Sound proofing equipment
sulfur fuels including storage and handling equipment (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)the
actual costs that are included in column (e).
6.Report construction work in progress relating to environmental facilities at Line 9.
Line Classification of Cost CHANGES DURINGYEAR Balance at Actual CostNo.Additions ketirements Adjustmerrls End of Year
(a)(b)(c)(d)(e)(f)
1 Air PollutionControl Facilities 6,506,130 36,983,192 851,743,786 851,743,786
2 Water PollutionControl Facilities 199,379 3,574,232 96,605,224 96,605,224
3 Solid Waste Disposal Costs 891,963 6,522,662 176,198,265 176,198,265
4 Noise Abatement Equipment 9,801 264,859 264,859
5 Esthetic Costs 1,236,000 58,012,868 43,315,759
6 Additional Plant Capacity 182,650 2,561,669 84,524,783 84,524,783
7 Miscellaneous (Identify significant)7,136,233 7,136,233
8 TOTAL (Total of lines 1 thru 7)9,016,122 49,651,556 1,274,486,018 1,259,788,909
9 Construction Work in Progress 3,879,031 3,879,031
FERC FORM NO.1 (ED.12-88)Page 430
Name of Respondent I his Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2000
(2)A Resubmission //
ENV IkuNlvlbW l AL Pku l bu l luN EAPENSEs
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 Item 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 Item 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 ltem 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).
Lme blassitication of Expenses Amount Aótual ExpéMéé
No (a)(b)(c)
1 Depreciation -2,841,237
2 Labor,Maint,Mtrls,&Supplies Cost Related to Env Fac &Programs 3,710,676 3,710,676
3 Fuel Related Costs
4 Operation of Facilities 11,276,970 11,276,970
5 Fly Ash and Sulfur Sludge Removal 7,371,196 7,371,196
6 Difference in Cost of Environmentally Clean Fuels
7 Replacement Power Costs 12,334,265
8 Taxes and Fees 3,728,483
9 Administrative and General 4,321,469 4,321,469
10 Other (Identify significant)30,139,053 30,139,053
11 TOTAL 70,040,875 56,819,364
ERC F ORM NO.1 (ED.12-88)Page 431
Name of Respondent This Report is:Date of Report Year of Report
(1)X An Original (Mo,Da,Yr)
PacifiCorp (2)A Resubmission //Dec 31,2000
FOOTNOTEDATA
Schedule Page:103 Line No.:1 Column:a
On May 5,2000,the assets of Centralia Mining Company were sold to TransAlta.
Schedule Page:103 Line No.:2 Column:aLiquidated1/18/2000
Schedule Page:103 Line No.:6 Column:a
Transferred from PGHC on 8/11/2000
Schedule Page:103 Line No.:15 Column:a
Dissolved 7/28/2000
Schedule Page:103 Line No.:16 Column:a
Footnote Linked.See note on 103,Row:6,col/item:a
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)
PacifiCorp (2)A Resubmission //Dec 31,2000
FOOTNOTE DATA
Schedule Page:104 Line No.:2 Column:b
Elected President March 16,2000
Schedule Page:104 Line No.:4 Column:bResignedSeptember29,2000
Schedule Page:104 Line No.:6 Column:b
Elected April 1,2000
Schedule Page:104 Line No.:8 Column:b
Elected May 15,2000
Schedule Page:104 Line No.:10 Column:bResignedFebruary25,2000
Schedule Page:104 Line No.:12 Column:b
Resigned February 1,2000
Schedule Page:104 Line No.:16 Column:b
Elected December 1,2000
Schedule Page:104 Line No.:18 Column:bResignedJune2,2000
Schedule Page:104 Line No.:20 Column:bResignedMay12,2000
Schedule Page:104 Line No.:22 Column:b
Title change May 15,2000 (was vice president)
Schedule Page:104 Line No.:26 Column:bResignedJanuary31,2000
Schedule Page:104 Line No.:28 Column:bResignedJanuary14,2000
Schedule Page:104 Line No.:34 Column:b
Title change May 15,2000 (was Vice President)
Schedule Page:104 Line No.:36 Column:b
Not reelected May 15,2000
Schedule Page:104 Line No.:40 Column:b
Elected Corporate Secretary May 15,2000;resigned Corporate Secretary December 11,2000
Schedule Page:104.1 Line No.:4 Column:b
Elected CFO January 17,2000;Elected Senior Vice President May 15,2000
Schedule Page:104.1 Line No.:6 Column:b
Elected February 16,2000
Schedule Page:104.1 Line No.:8 Column:b
Elected May 15,2000
Schedule Page:104.1 Line No.:10 Column:b
Elected May 15,2000
Schedule Page:104.1 Line No.:12 Column:b
Elected December 11,2000
FERC FORM NO.1 (ED.12-87)Page 450
BharneofRespondent ThisRepodis:DateofRepon YearofRepon
(1)X An Original (Mo,Da,Yr)
Pacificorp (2)A Resubmission //Dec 31,2000
FOOTNOTEDATA
Schedule Page:105 Line No.:9 Column:aResignedFebruary25,2000
Schedule Page:105 Line No.:36 Column:a
Elected January 25,2000
Schedule Page:105 Line No.:39 Column:a
Elected May 15,2000
Schedule Page:105 Line No.:42 Column:a
Elected May 15,2000
Schedule Page:105 Line No.:45 Column:a
Elected May 15,2000
Schedule Page:105 Líne No.:48 Column:a
Elected May 15,2000
Schedule Page:105.1 Line No.:3 Column:a
Elected December 1,2000
Schedule Page:105.1 Line No.:20 Column:a
Resigned April 5,2000
Schedule Page:105.1 Line No.:34 Column:a
Resigned January 1,2000
Schedule Page:105.1 Line No.:43 Column:a
Elected March 14,2000
Schedule Page:105.1 Line No.:46 Column:a
Elected March 14,2000
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)
PacifiCorp (2)A Resubmission //Dec 31,2000
FOOTNOTE DATA
Schedule Page:120 Line No.:5 Column:b
Amount Account
Amortization of OrganizationCosts 1,758,797 404AmortizationofSoftwareDevelopment34,656,070 404AmortizationofOtherIntangibleAssets3,971,716 404AmortizationofOverburden&Reclamation 1,397,638 425AmortizationofElectricPlantAcq.Adj.-Common 5,857,361 406
Amortization of RegulatoryAssets -Debits 95,844 407.3
Amortization of UnrecoveredPlant -Trojan 1,855,870 407.3
49,593,296
Schedule Page:120 Line No.:18 Column:b
Amount Account
(Gain)/Loss on Sale of Property 13,135,683 254 /411.6 /411.7AccumulatedProvisionforMergerCredits-2,684,744 242
Stamp Tax Accrual (Merger Cost)-40,503,393 232AccumulatedProvisionforPension&Benefits -38,594,776 228
Regulatory Asset -2000 Utah &Oregon Rate Orders -38,628,233 182.3
Wyoming Order -Deferred Excess Net Power Costs -16,019,933 182.3
Write-Off of Assets Under Construction -4,900,000 107
Other 480,404
-127,714,993
Schedule Page:120 Line No.:53 Column:b
Amount Account
Customer Advances for Construction 2,602,923 252OtherInvestments/Special Funds 251,666 124 /128
2,854,590
Schedule Page:120 Line No.:76 Column:b
Amount Account
Inter-Company Borrowing (Note Agreements)-185,178,992 233
FERC FORM NO.1 (ED.12-87)Page 450
Name of Respondent This Report is:Date of Repod Year of Report
(1)X_An Original (Mo,Da,Yr)
PacifiCorp (2)_A Resubmission //Dec 31,2000
FOOTNOTEDATA
Schedule Page:204 Line No.:82 Column:b
Account Beginning Balance Additions Retirements Transfers Adjust Ending Balance
399.21 3,865,734 -1,219,820 -(2,280)2,643,634399.22 37,224,744 -4,129,706 --33,095,038399.23 6,561,429 ----6,561,429399.30 78,598,533 50,668 5,792,100 --.72,857,102
399.41 5,743,306 -441,604 --5,301,702
399.41 3,754,485 -3,754,485 ---
399.41 2,629,895 -2,629,895 ---
399.41 9,113,417 -9,113,417 ---
399.42 7,433,469 ----7,433,469399.42 5,007,981 -5,007,981 ---
399.42 3,783,349 -3,783,349 ---
399.42 8,857,804 -8,857,804 ---
399.43 1,464,867 ----1,464,867399.44 2,101,991 -891,824 --1,210,167399.45 136,259,028 3,252,018 917,807 -(37,260)138,555,979
399.51 2,848,083 67,635 806,655 --2,109,062399.52 57,999,103 (3,303)32,738,691 -37,260 25,294,369399.60 5,794,475 143,978 1,943,46970 --3,994,982
399.61 5,790,740 16,263 2,449,372 --3,357,632399.70 46,129,914 1,996,856 4,431,125 --43,812,644399.70 4,903,216 -4,903,216 ---
399.70 1,461,078 -1,461,078 ---
399.70 571,995 -571,995 ---
437,898,638 5,524,114 (95,728,394)--347,692,078
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)
PacifiCorp (2)_A Resubmission //Dec 31,2000
FOOTNOTEDATA
Schedule Page:214 Line No.:3 Column:c
The dates that this land and these land rights are expected to be used in utility service
are not determined.
Schedule Page:214 Line No.:4 Column:c
The dates that this land and these land rights are expected to be used in utility service
are not determined.
Schedule Page:214 Line No.:9 Column:c
The dates that this land and these land rights are expected to be used in utility service
are not determined.
Schedule Page:214 Line No.:23 Column:c
The dates that other property is expected to be used in utility service are not
determined.
Schedule Page:214 Line No.:25 Column:c
The dates that other property is expected to be used in utility service are notdetermined.
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)
PacifiCorp (2)_A Resubmission //Dec 31,2000
FOOTNOTE DATA
Schedule Page:219 Line No.:3 Column:c
The amount from account 108 charged to account 403,combined with the reduction of$10,851,057 for the depreciation of the regulatory liability "1996 Depreciation Study"in
account 254,makes up the total amount charged to account 403 for the year.
Schedule Page:219 Line No.:7 Column:c
Total includes:
Account 503.1 1,051,011
Account 421 3,316
1,054,327
Schedule Page:219 Line No.:15 Column:c
Transfer of reserves related to electric plant.
FERC FORM NO.1 (ED.12-87)Page 450
Name of Respondent This Reportis:Date of Report Year of Report
(1)X An Original (Mo,Da,Yr)
PacifiCorp (2)_A Resubmission //Dec 31,2000
FOOTNOTEDATA
Schedule Page:232 Line No.:1 Column:a
The amortization period is shown in parenthesis in column (a)and
is in years.
Schedule Page:232.7 Line No.:4 Column:c
Credits charged to various accounts.
Schedule Page:232.7 Line No.:5 Column:c
Credits charged to various accounts.
Schedule Page:232.7 Line No.:16 Column:c
Credits charged to various accounts.
Schedule Page:232.7 Line No.:18 Column:c
Credits charged to various accounts.
Schedule Page:232.7 Line No.:34 Column:c
Credits charged to various accounts.
Schedule Page:232.7 Line No.:35 Column:c
Credits charged to various accounts.
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)
PacifiCorp (2)A Resubmission //Dec 31,2000
FOOTNOTE DATA
Schedule Page:234 Line No.:7 Column:a
Line 7 -Other:
Supplemental Executive RetirementPlan
(SERP)3,703,568 4,026,575Long-Term IncentivePlan
315,876 (717,698)
Sales of Emission Allowances
77,959 (16,917)
Federal IncomeTax Interest
4,313,733 9,296,694
Sick Leave,Vacation &PT
(1,449,543)(3,945,564)
Injuries &Damages
6,029,805 5,399,296
PPL 1985 Prepaid Pension
1,002,326 -
Delta Land &Water Rights Writedown
(3,135)(3,135)
Terracor Properties Writedown
192,145 -
Trojan Decommissioning
(494,043)338,379OtherM-1 Line 4 &5 Differences
2,105,800 2,464,509
NW Power Act
(31,648)(186,983)
Deferred Revenues
(944,986)(944,986)
Noncash Pension,Bonus &Severance
27,217,199 14,738,420
Utiltiy Asset Writedowns
33,776,472 24,612,813
Property Tax Litigation Accrual
25,114 (5,246)
Bonus Liability
8,152,301 10,800,965
Glenrock 263A
21,206 (477,720)
Rate Case
335,522 -
Exchange Tulana Farms
295,695 295,695
Sec 174 R &E Expenditures
31,286,805 (737,165)
PMI DeferredTax Adjustments
473,958 11,747,457CentraliaMiningCompany
9,236,146 5,808,550
MonsantoContract
2,512,897 1,264,997
Redding Contract
5,548,619 3,130,890
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)
PacifiCorp (2)_A Resubmission //Dec 31,2000
FOOTNOTEDATA
Glenrock OverburdenAmort
8,488 8,488
95 Pension Expense
42,496 -
Disallowed Coal Strip
416,599 416,599
Utah Rate Case Refund
21,901,214 78,834,359
Sale of Montana Assets
2,923,151 -
CA/MTAsset Writeoff
1,474,337 2,177,092
Universityof WY Contract
2,893 1,001,671
CentraliaSale Accruals
-2,979,075
WY Deferred Net Power Costs
-6,079,565
Total
160,468,969 178,386,675
edule Page:234 Line No.:17 Column:a
Line 17 -Other:
Malin Line
14,999,323 13,821,531UraniumPropertyWritedowns
91,402 91,402RooseveltLandWritedown
354,841 354,841
30 South Substation Site Writedown
196,435 196,435NonutilityAssetWritedown
83,084 83,084OntarioWaterRightsSale
(1,121,015)-
Centralia Mining Reclamation -NOB's
(2,084,308)(2,127,315)
Deferred Gain on Sale of Telephone Property
356,127 -
Total
12,875,889 12,419,978
FERC FORM NO.1 (ED.12-87)Page 450.1
NameofRespondent ThisRepodis:DateofRepod YearofRepon
(1)X_An Original (Mo,Da,Yr)
PacifiCorp (2)_A Resubrnission //Dec 31,2000
FOOTNOTEDATA
Schedule Page:250 Line No.:1 Column:c
Common stock has no par or stated value.
Schedule Page:250 Line No.:1 Column:d
This class of stock is not redeemable.
Schedule Page:250 Line No.:9 Column:a
Except as specifically noted,all preferred stock series trade
as unlisted securities.
Schedule Page:250 Line No.:13 Column:d
This series of preferred stock is not redeemable.
Schedule Page:250 Line No.:14 Column:d
This series of preferred stock is not redeemable.
Schedule Page:250 Line No.:21 Column:d
This series of preferred stock is not redeemable prior to August 15,2001.The entire
series is subject to mandatory redemption on August 15,2001 at $100 per share.
Schedule Page:250 Line No.:22 Column:d
This series of preferred stock is not redeemable prior to June 15,2002.The series issubjecttosinkingfundrequirementsfromJune15,2002 through June 15,2006,and theremainingsharesaresubjecttomandatoryredemptiononJune15,2007,in each case at$100 per share.
Schedule Page:250 Line No.:35 Column:a
Capital stock authorized but not yet issued as of
December 31,1999 is as follows:
Authorizations for the issuance of common stock (15,000,000
shares authorized;6,210,000 available as of December 31,2000)
are as follows:
Oregon Public Utility Commission,Docket No.UF-4113 (2),Order
No.96-037,dated February 13,1996.
Utah Public Service Commission,Docket No.93-2035-07,datedJanuary29,1996.
Public Service Commission of Wyoming,Docket No.20000-ES-95-102,
dated January 2,1996.Washington Utilities and Transportation Commission,Docket No.UE-931372,dated January 31,1996.
Idaho Public Utilities Commission,Docket No.PAC-S-93-4,Order
No.26292,dated December 29,1995.
Montana Public Service Commission,Docket No.D95.12.182,Order
No.5887,dated January 3,1996.
FERC FORM NO.1 (ED.12-87)Page 450
NarneofRespondent ThisRepodis:DateofRepod YearofRepod
(1)X An Original (Mo,Da,Yr)
PacifiCorp (2)_A Resubmission //Dec 31,2000
FOOTNOTEDATA
Schedule Page:256.4 Line No.:30 Column:a
Pollution Control Obligations Secured by Pledged First Mortgage
Bonds:
Issue Amount Pledgee
Var.rate Series 1994 $40,655,000 Moffat County,COVar.rate Series 1994 21,260,000 Sweetwater Cnty,WY
Var.rate Series 1994 8,190,000 Converse County,WY
Var.rate Series 1994 121,940,000 Emery County,UTVar.rate Series 1994 9,365,000 Carbon County,UT
Var.rate Series 1994 15,060,000 Lincoln County,WY5-5/8%Series due Nov 2021 8,300,000 Lincoln County,WY
5.65%Series due Nov.2023 46,500,000 Emery County,UT5-5/8%Series due Nov 2023 16,400,000 Emery County,UT
Pollution Control Obligations were issued to either finance or
refinance the cost of certain pollution control facilities at
steam electric plants located within the boundaries of therespectivepledgees.
Schedule Page:256.6 Line No.:11 Column:a
The reconciliation of net changes to Account 223 is as follows:
Beginning Interest Ending
Balance Advances Repayments Added Balance
PMI 18,615,100 9,749,609 13,186,724 988,488 16,166,473
PCI 223,712,000 223,712,000
PCII 139,176,000 139,176,000
TOT.381,503,100 9,749,609 13,186,724 988,488 379,054,473
Schedule Page:256.6 Line No.:17 Column:i
Account 430 Interest on Debt to Associated Companies 41,136,700
less:Acct 223 Advances from Assoc.Co's -L-T interest for year 30,161,280
Account 233 Notes Payable to Assoc.Co's -S-T interest for year 10,975,420
(not in column i)
Schedule Page:256.6 Line No.:32 Column:a
Long-term debt authorized but not yet issued as of December 31,2000 is as follows:
Authorizations for the issuance of $1,600,000,000 of long-term debt of which$1,600,000,000 remains available as of December 31,2000 are as follows:
Oregon Public Utility Commission,Docket No.UF-4167,Order No.99-786,dated December 23,
1999.
Utah Public Service Commission,Docket No.99-2035-05,dated January 11,2000.Washington Utilities and Transportation Commission,Docket No.UE-991745,dated December
8,1999.
Idaho Public Utilities Commission,Docket No.PAC-E-99-3,Order No.28240,dated December20,1999.
Authorizations for the issuance of pollution control revenue bonds ($125,000,000
authorized;$79,225,000 available as of December 31,2000)are as follows:
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)
PacifiCorp (2)_A Resubmission //Dec 31,2000
FOOTNOTE DATA
Oregon Public Utility Commission,Docket No.UF-4128,Order No.95-518,dated May 25,1995.
Utah Public Service Commission,Docket No.95-2035-02,dated May 24,1995.
Public Service Commission of Wyoming,Docket No.20000-E8-95-95,dated May 17,1995.Washington Utilities and Transportation Commission,Docket No.UE-950490,dated May 24,
1995.
Idaho Public Utilities Commission,Docket No.PAC-S-95-2,Order No.26039,dated June 13,1995.
FERC FORM NO.1 (ED.12-87)Page 450.1
NanysofRespondent ThisRepodis:DateofRepod YearofRepod
(1)X An Original (Mo,Da,Yr)
PacifiCorp (2)A Resubmission //Dec 31,2000
FOOTNOTEDATA
Schedule Page:261 Line No.:28 Column:b
Show Computation of Tax:
Federal Income Tax at 35.00%$131,794,6981999&2000 Federal Accrual to Return 1,490,430Adjustments
2000 PMI Federal Tax Accrual (83,148)1994 -1998 IRS Audit Adjustments 9,130,435Rounding(480)
PMI /GCC /DSR 1999 &2000 Fed.Accrual 3,166,212
to Return Adj.
Total $145,498,147
Reconciliation:
Account 570001 Federal Income Tax $140,505,147Exp-Utility
Account 570002 Federal Income Tax 4,993,000Exp-Non-Utility
Total $145,498,147
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)
PacifiCorp (2)_A Resubmission //Dec 31,2000
FOOTNOTE DATA
Schedule Page:262 Line No.:2 Column:f
Diesel fuel credits
Schedule Page:262 Line No.:3 Column:f
Transfer to accounts payable
Schedule Page:262 Line No.:4 Column:f
Footnote Linked.See note on 262,Row:3,col/item:f
Schedule Page:262 Line No.:7 Column:f
Reclass Federal Excise Tax
Schedule Page:262 Line No.:9 Column:I
Account Line 2 Line 3 Line 4 Line 6 Line 7408.2 &409.2 4,993,000
151 1,511,604 112,798 9,122,950
184 159,235
Miscellaneous (780,917)Misc.payroll expenses not charged thru BIS
Total 4,993,000 730,687 112,798 159,235 9,122,950
Grand Total 15,118,670
Schedule Page:262 Line No.:18 Column:I
Account Line 15
408.2 &409.2 9,868
107
108
232
151
415,6,7,8
184
185
188
181,2,3,6
401 &402
154 &426
Total 9,868
Schedule Page:262 Line No.:28 Column:f
Reflects Sales and Use Taxes not included in columns (d)and (e)in accordance withinstruction1.
Schedule Page:262 Line No.:31 Column:I
Account Line 23 Line 26 Line 27 Line 29408.2 &409.2 23,796 18,918
107
108
232
151
415,6,7,8
184 70,477
185
188
181,2,3,6
FERC FORM NO.1 (ED.12-87)Page 450
Name of Respondent This Report is:Date of Report Year of Repod
(1)X_An Original (Mo,Da,Yr)
Pacificorp (2)_A Resubrnission i i Dec 31,2000
FOOTNOTEDATA
401 &402 93,485
589.1 &931 11,000
Total 34,796 18,918 93,485 70,477
GrandTotal 217,676
Schedule Page:262 Line No.:38 Column:I
Account Line 36
408.2 &409.2 1,044
107
108
232
151
415,6,7,8
184
185
188
181,2,3,6
401 &402
589.1 &931
Total 1,044
Schedule Page:262.1 Line No.:2 Column:f
Montana Property Tax payment booked to Idaho.
Schedule Page:262.1 Line No.:11 Column:I
Account Line 2 Line 3 Line 6 Line 8
408.2 &409.2 2,100 27,226
107
108
232
151
415,6,7,8
184 8,165
185
188
181,2,3,6
401 &402 312,454
589.1 &931
Total 2,100 27,226 312,454 8,165
Grand Total 349,945
Schedule Page:262.1 Line No.:15 Column:f
Footnote Linked.See note on 262.1,Row:2,col/item:f
Schedule Page:262.1 Line No.:23 Column:I
Account Line 15 Line 17
408.2 &409.2 240 9,976
107
108
FERC FORM NO.1 (ED.12-87)Page 450.1
Name of Respondent This Report is:Date of Report Year of Report
(1)X An Original (Mo,Da,Yr)
PacifiCorp (2)A Resubmission //Dec 31,2000
FOOTNOTE DATA
232
151
415,6,7,8
184
185
188
181,2,3,6
401 &402
589.1 &931
Total 240 9,976
Grand Total 10,216
Schedule Page:262.1 Line No.:35 Column:I
Account Line 34
408.2 &409.2 2,101
107
108
232
151
415,6,7,8
184
185
188
181,2,3,6
401 &402
589.1 &931
Total 2,101
Schedule Page:262.2 Line No.:8 Column:I
Account Line 38 Line 40 Line 1 Line 2 Line 3 Line 4408.2 &409.2 38,675 316,707 2,351
184 169,417
401 &402 2,496,773
589.1 276,669
Miscellaneous (540,484)(208,937)
Total 315,344 (540,484)2,496,773 316,707 (206,586)169,417
Grand Total 2,551,171
Line 40 and Line 3 -The miscellaneouscharges did not go through the balance sheet.These were miscellaneoustaxes and fees.
Schedule Page:262.2 Line No.:22 Column:I
Account Line 11 Line 12 Line 14 Line 16408.2 &409.2 14,400 266,163
107
108
232
FERC FORM NO.1 (ED.12-87)Page 450.2
Name of Respondent This Report is:Date of Report Year of Report
(1)X An Original (Mo,Da,Yr)
Pacificorp (2)_A Resubmission //Dec 31,2000
FOOTNOTE DATA
151 1,847,126
415,6,7,8
184 360,167
185
188
181,2,3,6
401 &402 2,440,837
589.1
Total 1,861,526 266,163 2,440,837 360,167
Grand Total 4,928,693
Schedule Page:262.2 Line No.:33 Column:f
Footnote Linked.See note on 262,Row:7,col/item:f
Schedule Page:262.2 Line No.:35 Column:I
Account Line 25 Line 27 Line 29 Line 30 Line 34
408.2 &409.2 78,000
107
108
232
143 &146 236,480
151 (7)381,172 565,337
415,6,7,8
184 144,756
185
188
181,2,3,6
401 &402 383,053
589.1 7,104
Total 85,097 617,652 383,053 565,337 144,756
GrandTotal 1,795,895
Schedule Page:262.3 Line No.:4 Column:f
Reclass Wyoming's Sales and Use Tax
Schedule Page:262.3 Line No.:7 Column:f
Footnote Linked.See note on 262,Row:3,col/item:f
Schedule Page:262.3 Line No.:9 Column:f
Reflects Sales and Use Taxes not included in columns (d)and (e)in accordance with
instruction 1.Reclass Wyoming Sales and Use Tax.
Schedule Page:262.3 Line No.:13 Column:I
Account Line 4 Line 6 Line 7
408.2 &409.2 240
107
108
232
143 &146
151 208,679 419,717
415,6,7,8
184
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)
PacifiCorp (2)_A Resubmission //Dec 31,2000
FOOTNOTEDATA
185
188
181,2,3,6
401 &402 630,241
589.1 27,208
Total 236,127 630,241 419,717
Grand Total 1,286,085
Schedule Page:262.3 Line No.:25 Column:a
This balance represents tax collections payable which was reclassed to account 241 incalendar2000.
Schedule Page:262.3 Line No.:25 Column:f
Footnote Linked.See note on 262.3,Row:25,col/item:a
FERC FORM NO.1 (ED.12-87)Page 450.4
Name of Respondent This Report is:Date of Report Year of Report
(1)X An Original (Mo,Da,Yr)
PacifiCorp (2)A Resubmission //Dec 31,2000
FOOTNOTEDATA
Schedule Page:276 Line No.:8 Column:a
CHANGESDURINGYEAR ADJUSTMENTS
Balance at Amounts Amounts Debits
Beginning Debited to Credited to Accounts Balance at
Account of Year Account 410.1 Account 411.1 Credited Amount End of Year
(a)(b)(c)(d)(g)(h)(k)
Line 8 -Other:
Purcahse Power Agreement Settlement (362,553)(362,553)Other M-1 Differences 5,125,832 1,946,316 878,674 6,193,474HermistonBreakageFee-2,868,040 255,960 2,612,080
Special Assessment 198,981 198,981FAS1061,420,297 591,180 1,668,143 190 2,382,153 (2,038,819)Regulatory Asset 505,865 63,740 2,399,842 (1,830,237)Coalpile inventory Adjustment 46,194 737,365 337,481 446,078
APS Abandonment 101,288 275,981 223,939 153,330Weatherization/Customer Service 18,995,311 3,359,270 8,704,375 13,650,206
Idaho Customer Balancing Account (128,081)(128,081)
Prepaid Taxes (549,338)404,165 1,250,497 (1,395,670)Trust Income &Expense (617,064)(617,064)
Agnew Advance Royalty Payment (242,241)(242,241)
Hazardous Waste (5,912,733)42,082 1,220,287 (7,090,938)
Extraction Tax 215,854 698,485 113,851 800,488
Garfield Advance Royalties 109,207 292,215 190 401,422 -
83 -88 IRS Settlement (4,242,887)(4,242,887)
Glenrock Inventroy Adj 1,820,702 58,134 190 1,878,836
Mine Road Relocation 39,783 39,783
Section 453 InstallmentInterest 48,450 190 48,450 -
Amort of Pollution Control Liability 1,813,371 134,125 1,679,247
1
R &E -Solar Il Project 398,820 398,820SoftwareWrite-off (2,655,901)2,111,934 446,630 (990,597)PMI Deferred Tax Adjustments 578,115 2,556,824 2,167,146 967,793CMCInventoryAdj2,506,350 3,856,923 (1,350,573)GCCDeferred Tax Adjustments 57,010 164,336 (107,326)Electric Mutual Insurance Receivable (745,081)417,450 (327,631)
18,525,551 16,423,182 23,822,209 4,710,861 6,415,663
Schedule Page:276 Line No.:18 Column:k
Balance at
Beginning
of Year
(b)
Line 18 -Other:
Investments 4,468
4,468
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)
PacifiCorp (2)_A Resubmission //Dec 31,2000
FOOTNOTEDATA
Schedule Page:310 Line No.:2 Column:jPriorPeriodAdjustment
Schedule Page:310 Line No.:3 Column:jPriorPeriodAdjustment
Schedule Page:310 Line No.:5 Column:jPriorPeriodAdjustment
Schedule Page:310 Line No.:6 Column:jPriorPeriodAdjustment
Schedule Page:310 Line No.:7 Column:jPriorPeriodAdjustment
Schedule Page:310 Line No.:8 Column:jPriorPeriodAdjustment
Schedule Page:310 Line No.:9 Column:jPriorPeriodAdjustment
Schedule Page:310 Line No.:10 Column:jPriorPeriodAdjustment
Schedule Page:310.1 Line No.:1 Column:jPriorPeriodAdjustment
Schedule Page:310.1 Line No.:2 Column:bSecondary,Economy and/or non-firm sales,including some hourly firm transactions.
Schedule Page:310.1 Line No.:3 Column:b
Secondary,Economy and/or non-firm sales,including some hourly firm transactions.
Schedule Page:310.1 Line No.:6 Column:b
Secondary,Economy and/or non-firm sales,including some hourly firm transactions.
Schedule Page:310.1 Line No.:8 Column:b
Secondary,Economy and/or non-firm sales,including some hourly firm transactions.
Schedule Page:310.1 Line No.:12 Column:bSecondary,Economy and/or non-firm sales,including some hourly firm transactions.
Schedule Page:310.1 Line No.:13 Column:b
Secondary,Economy and/or non-firm sales,including some hourly firm transactions.
Schedule Page:310.2 Line No.:2 Column:jPriorPeriodAdjustment
Schedule Page:310.2 Line No.:3 Column:jPriorPeriodAdjustment
Schedule Page:310.2 Line No.:4 Column:b
Secondary,Economy and/or non-firm sales,including some hourly firm transactions.
Schedule Page:310.2 Line No.:8 Column:jPriorPeriodAdjustment
Schedule Page:310.2 Line No.:9 Column:b
Secondary,Economy and/or non-firm sales,including some hourly firm transactions.
Schedule Page:310.2 Line No.:10 Column:b
Secondary,Economy and/or non-firm sales,including some hourly firm transactions.
Schedule Page:310.2 Line No.:14 Column:jPriorPeriodAdjustment
Schedule Page:310.3 Line No.:1 Column:b
Black Hills Power &Light Company -FERC 236 -Contract termination date:December 31,2023.
Schedule Page:310.3 Line No.:2 Column:b
FERC FORM NO.1 (ED.12-87)Page 450
NameofRespondent This Repodis:DateofRepod YearofRepod
(1)X_An Original (Mo,Da,Yr)
PacifiCorp (2)_A Resubmission //Dec 31,2000
FOOTNOTEDATA
Black Hills Power &Light Company -FERC 246 -Contract termination date:June 30,2012.
Schedule Page:310.3 Line No.:3 Column:b
Black Hills Power &Light Company -FERC 424 -Contract termination date:March 31,2002.
Schedule Page:310.3 Line No.:4 Column:bSecondary,Economy and/or non-firm sales,including some hourly firm transactions.
Schedule Page:310.3 Line No.:5 Column:bSecondary,Economy and/or non-firm sales,including some hourly firm transactions.
Schedule Page:310.3 Line No.:8 Column:jPriorPeriodAdjustment
Schedule Page:310.3 Line No.:13 Column:bSecondary,Economy and/or non-firm sales,including some hourly firm transactions.
Schedule Page:310.4 Line No.:1 Column:bSecondary,Economy and/or non-firm sales,including some hourly firm transactions.
Schedule Page:310.4 Line No.:3 Column:jPriorPeriodAdjustment
Schedule Page:310.4 Line No.:5 Column:jPriorPeriodAdjustment
Schedule Page:310.4 Line No.:6 Column:jPriorPeriodAdjustment
Schedule Page:310.4 Line No.:9 Column:jPriorPeriodAdjustment
Schedule Page:310.4 Line No.:10 Column:bSecondary,Economy and/or non-firm sales,including some hourly firm transactions.Schedule Page:310.4 Line No.:14 Column:jPriorPeriodAdjustment
Schedule Page:310.5 Line No.:1 Column:b
Clark County PUD #1 -FERC 428 -Contract termination:November 30,2002.
Schedule Page:310.5 Line No.:2 Column:b
Clark County PUD #1 -FERC T-12 -Contract Termination date:December 12,2007
Schedule Page:310.5 Line No.:3 Column:jPriorPeriodAdjustment
Schedule Page:310.5 Line No.:5 Column:bSecondary,Economy and/or non-firm sales,including some hourly firm transactions.
Schedule Page:310.5 Line No.:8 Column:jPriorPeriodAdjustment
Schedule Page:310.5 Line No.:10 Column:bSecondary,Economy and/or non-firm sales,including some hourly firm transactions.
Schedule Page:310.5 Line No.:12 Column:bCowlitzCountyPUD-FERC T-12 -Contract Termination date:April 30,2002
Schedule Page:310.5 Line No.:13 Column:b
Deseret Generation &Transmission Cooperative -FERC 462 -Contract Termination July 25,2003.
Schedule Page:310.5 Line No.:13 Column:jPriorPeriodAdjustment
Schedule Page:310.5 Line No.:14 Column:b
Deseret Generation &Transmission Cooperative -FERC 462 -Contract Termination July 25,2003.
Schedule Page:310.6 Line No.:3 Column:j
FERC FORM NO.1 (ED.12-87)Page 450.1
Name of Respondent This Report is:Date of Report Year of Report
(1)X_An Original (Mo,Da,Yr)
PacifiCorp (2)_A Resubmission //Dec 31,2000
FOOTNOTEDATA
Prior Period Adjustment
Schedule Page:310.6 Line No.:4 Column:jPriorPeriodAdjustment
Schedule Page:310.6 Line No.:9 Column:bSecondary,Economy and/or non-firm sales,including some hourly firm transactions.
Schedule Page:310.6 Line No.:12 Column:b
Flathead Electric Cooperative,Inc./Energy Northwest Inc.-FERC T-12 -ContractTerminationdate:September 30,2006
Schedule Page:310.6 Line No.:13 Column:jPriorPeriodAdjustment
Schedule Page:310.6 Line No.:14 Column:bSecondary,Economy and/or non-firm sales,including some hourly firm transactions.
Schedule Page:310.7 Line No.:1 Column:b
Secondary,Economy and/or non-firm sales,including some hourly firm transactions.
Schedule Page:310.7 Line No.:2 Column:bSecondary,Economy and/or non-firm sales,including some hourly firm transactions.
Schedule Page:310.7 Line No.:5 Column:b
Eugene Water and Electric Board -FERC 419 -Contract termination date:July 31,2000.
Schedule Page:310.7 Line No.:5 Column:jPriorPeriodAdjustment
Schedule Page:310.7 Line No.:6 Column:j
Prior Period Adjustment
Schedule Page:310.7 Line No.:7 Column:b
Eugene Water and Electric Board -FERC 419 -Contract termination date:July 31,2000.
Schedule Page:310.7 Line No.:9 Column:b
Fiberweb -FERC T-12 -Contract Termination date:September 30,2000.
Schedule Page:310.7 Line No.:10 Column:b
Flathead Electric Cooperative,Inc./Energy Northwest Inc.-FERC T-12 -ContractTerminationdate:September 30,2006
Schedule Page:310.7 Line No.:14 Column:jPriorPeriodAdjustment
Schedule Page:310.8 Line No.:2 Column:jPriorPeriodAdjustment
Schedule Page:310.8 Line No.:4 Column:b
Hurricane,City of -FERC T-12 -Contract Termination date:August 31.2007
Schedule Page:310.8 Line No.:5 Column:j
Prior Period Adjustment
Schedule Page:310.8 Line No.:7 Column:bSecondary,Economy and/or non-firm sales,including some hourly firm transactions.
Schedule Page:310.8 Line No.:8 Column:bSecondary,Economy and/or non-firm sales,including some hourly firm transactions.
Schedule Page:310.8 Line No.:9 Column:b
Secondary,Economy and/or non-firm sales,including some hourly firm transactions.
Schedule Page:310.8 Line No.:11 Column:jPriorPeriodAdjustment
Schedule Page:310.8 Line No.:14 Column:j
Prior Period Adjustment
Schedule Page:310.9 Line No.:2 Column:b
Secondary,Economy and/or non-firm sales,including some hourly firm transactions.
FERC FORM NO.1 (ED.12-87)Page 450.2
Name of Respondent This Report is:Date of Report Year of Report
(1)X An Original (Mo,Da,Yr)
PacifiCorp (2)_A Resubmission //Dec 31,2000
FOOTNOTEDATA
Schedule Page:310.9 Line No.:3 Column:bSecondary,Economy and/or non-firm sales,including some hourly firm transactions.
Schedule Page:310.9 Line No.:11 Column:bSecondary,Economy and/or non-firm sales,including some hourly firm transactions.
Schedule Page:310.9 Line No.:12 Column:b
Secondary,Economy and/or non-firm sales,including some hourly firm transactions.
Schedule Page:310.9 Line No.:13 Column:b
Nevada Power Company -FERC 312 -Contract termination date:May 31,2010.
Schedule Page:310.9 Line No.:13 Column:jPriorPeriodAdjustment
Schedule Page:310.9 Line No.:14 Column:jPriorPeriodAdjustment
Schedule Page:310.10 Line No.:1 Column:jPriorPeriodAdjustment
Schedule Page:310.10 Line No.:2 Column:bSecondary,Economy and/or non-firm sales,including some hourly firm transactions.
Schedule Page:310.10 Line No.:3 Column:bSecondary,Economy and/or non-firm sales,including some hourly firm transactions.
Schedule Page:310.10 Line No.:7 Column:jPriorPeriodAdjustment
Schedule Page:310.10 Line No.:9 Column:jPriorPeriodAdjustment
Schedule Page:310.10 Line No.:13 Column:b
Secondary,Economy and/or non-firm sales,including some hourly firm transactions.
Schedule Page:310.11 Line No.:2 Column:jPriorPeriodAdjustment
Schedule Page:310.11 Line No.:3 Column:b
Secondary,Economy and/or non-firm sales,including some hourly firm transactions.
Schedule Page:310.11 Line No.:4 Column:b
Secondary,Economy and/or non-firm sales,including some hourly firm transactions.
Schedule Page:310.11 Line No.:5 Column:bSecondary,Economy and/or non-firm sales,including some hourly firm transactions.
Schedule Page:310.11 Line No.:8 Column:b
Secondary,Economy and/or non-firm sales,including some hourly firm transactions.
Schedule Page:310.11 Line No.:9 Column:b
Secondary,Economy and/or non-firm sales,including some hourly firm transactions.
Schedule Page:310.11 Line No.:11 Column:b
Public Service Company of Colorado -FERC 320 -Contract termination date:October 31,2022.
Schedule Page:310.11 Line No.:11 Column:jPriorPeriodAdjustment
Schedule Page:310.11 Line No.:12 Column:b
Public Service Company of Colorado -FERC 320 -Contract termination date:October 31,2022.
Schedule Page:310.11 Line No.:13 Column:bSecondary,Economy and/or non-firm sales,including some hourly firm transactions.
Schedule Page:310.12 Line No.:2 Column:bSecondary,Economy and/or non-firm sales,including some hourly firm transactions.
Schedule Page:310.12 Line No.:3 Column:b
FERC FORM NO.1 (ED.12-87)Page 450.3
NanteofRespondent ThisRepodis:DateofRepod YearofRepod
(1)X An Original (Mo,Da,Yr)
PacifiCorp (2)A Resubmission //Dec 31,2000
FOOTNOTEDATA
Secondary,Economy and/or non-firm sales,including some hourly firm transactions.
Schedule Page:310.12 Line No.:4 Column:bSecondary,Economy and/or non-firm sales,including some hourly firm transactions.
Schedule Page:310.12 Line No.:7 Column:b
Okanagon County PUD -FERC T-12 -Contract Termination date:September 30,2001
Schedule Page:310.12 Line No.:11 Column:jPriorPeriodAdjustment
Schedule Page:310.12 Line No.:12 Column:b
Puget Sound Power &Light Company -FERC 254 -Contract termination date:October 31,2003.
Schedule Page:310.12 Line No.:13 Column:bSecondary,Economy and/or non-firm sales,including some hourly firm transactions.
Schedule Page:310.12 Line No.:14 Column:b
Secondary,Economy and/or non-firm sales,including some hourly firm transactions.
Schedule Page:310.13 Line No.:3 Column:bCityofRedding-FERC 364 -Contract termination date:November 30,2015.
Schedule Page:310.13 Line No.:3 Column:jPriorPeriodAdjustment
Schedule Page:310.13 Line No.:4 Column:b
City of Redding -FERC 364 -Contract termination date:May 31,2014.
Schedule Page:310.13 Line No.:4 Column:jPriorPeriodAdjustment
Schedule Page:310.13 Line No.:5 Column:bCityofRedding-FERC 364 -Contract termination date:November 30,2015.
Schedule Page:310.13 Line No.:6 Column:bCityofRedding-FERC 364 -Contract termination date:May 31,2014.
Schedule Page:310.13 Line No.:9 Column:b
Secondary,Economy and/or non-firm sales,including some hourly firm transactions.
Schedule Page:310.13 Line No.:11 Column:bSecondary,Economy and/or non-firm sales,including some hourly firm transactions.
Schedule Page:310.13 Line No.:13 Column:b
Sacramento Municipal Utility District -FERC 250 -Contract termination date:December31,2014.
Schedule Page:310.13 Line No.:13 Column:jPriorPeriodAdjustment
Schedule Page:310.13 Line No.:14 Column:b
Sacramento Municipal Utility District -FERC 250 -Contract termination date:December31,2014.
Schedule Page:310.14 Line No.:1 Column:b
Secondary,Economy and/or non-firm sales,including some hourly firm transactions.
Schedule Page:310.14 Line No.:4 Column:b
Secondary,Economy and/or non-firm sales,including some hourly firm transactions.
Schedule Page:310.14 Line No.:8 Column:b
Secondary,Economy and/or non-firm sales,including some hourly firm transactions.
Schedule Page:310.14 Line No.:10 Column:bSecondary,Economy and/or non-firm sales,including some hourly firm transactions.
Schedule Page:310.14 Line No.:12 Column:b
Sierra Pacific Power Company -FERC 258 -Contract termination date:February 28,2009.
Schedule Page:310.14 Line No.:12 Column:j
FERC FORM NO.1 (ED.12-87)Page 450.4
Name of Respondent This Report is:Date of Report Year of Report
(1)X An Original (Mo,Da,Yr)
PacifiCorp (2)_A Resubmission //Dec 31,2000
FOOTNOTEDATA
Prior Period Adjustment
Schedule Page:310.14 Line No.:13 Column:b
Sierra Pacific Power Company -FERC 267 -Contract termination date:April 30,2021.
Schedule Page:310.14 Line No.:13 Column:j
Prior Period Adjustment
Schedule Page:310.14 Line No.:14 Column:jPriorPeriodAdjustment
Schedule Page:310.15 Line No.:1 Column:b
Sierra Pacific Power Company -FERC 258 -Contract termination date:February 28,2009.
Schedule Page:310.15 Line No.:2 Column:b
Sierra Pacific Power Company -FERC 267 -Contract termination date:April 30,2021.
Schedule Page:310.15 Line No.:3 Column:b
Secondary,Economy and/or non-firm sales,including some hourly firm transactions.
Schedule Page:310.15 Line No.:6 Column:b
Secondary,Economy and/or non-firm sales,including some hourly firm transactions.
Schedule Page:310.15 Line No.:9 Column:b
Southern California Edison Company -FERC 248 -Contract termination date:September 30,
2006.
Schedule Page:310.15 Line No.:9 Column:j
Prior Period Adjustment
Schedule Page:310.15 Line No.:10 Column:b
Southern California Edison Company -FERC 248 -Contract termination date:September 30,
2006.
Schedule Page:310.15 Line No.:11 Column:b
Springfield Utility Board -FERC 423 -Contract termination date:July 31,2015.
Schedule Page:310.15 Líne No.:13 Column:b
California Dept.of Water Resources -FERC 311 -Contract termination date:December 31,
2004.
Schedule Page:310.15 Line No.:13 Column:j
Prior Period Adjustment
Schedule Page:310.15 Line No.:14 Column:b
California Dept.of Water Resources -FERC 311 -Contract termination date:December 31,
2004.
Schedule Page:310.16 Line No.:5 Column:b
Secondary,Economy and/or non-firm sales,including some hourly firm transactions.
Schedule Page:310.16 Line No.:9 Column:b
Secondary,Economy and/or non-firm sales,including some hourly firm transactions.
Schedule Page:310.16 Line No.:11 Column:j
Prior Period Adjustment
Schedule Page:310.16 Line No.:12 Column:b
Secondary,Economy and/or non-firm sales,including some hourly firm transactions.
Schedule Page:310.16 Line No.:13 Column:b
Secondary,Economy and/or non-firm sales,including some hourly firm transactions.
Schedule Page:310.17 Line No.:1 Column:b
Secondary,Economy and/or non-firm sales,including some hourly firm transactions.
Schedule Page:310.17 Line No.:2 Column:b
Secondary,Economy and/or non-firm sales,including some hourly firm transactions.
Schedule Page:310.17 Line No.:5 Column:j
Prior Period Adjustment
FERC FORM NO.1 (ED.12-87)Page 450.5
Name of Respondent This Report is:Date of Report Year of Report
(1)X An Original (Mo,Da,Yr)
PacifiCorp (2)_A Resubmission //Dec 31,2000
FOOTNOTEDATA
Schedule Page:310.17 Line No.:6 Column:jPriorPeriodAdjustment
Schedule Page:310.17 Line No.:7 Column:b
Secondary,Economy and/or non-firm sales,including some hourly firm transactions.
Schedule Page:310.17 Line No.:8 Column:bSecondary,Economy and/or non-firm sales,including some hourly firm transactions.
Schedule Page:310.17 Line No.:11 Column:b
Utah Municipal Power Agency -FERC 433 -Contract termination date:July 1,2005.
Schedule Page:310.17 Line No.:11 Column:jPriorPeriodAdjustment
Schedule Page:310.17 Line No.:12 Column:b
Utah Municipal Power Agency -FERC 433 -Contract termination date:July 1,2005.
Schedule Page:310.17 Line No.:13 Column:b
Utah Municipal Power Agency -FERC 433 -Contract termination date:June 30,2017.
Schedule Page:310.17 Line No.:14 Column:b
Secondary,Economy and/or non-firm sales,including some hourly firm transactions.
Schedule Page:310.18 Line No.:1 Column:b
Secondary,Economy and/or non-firm sales,including some hourly firm transactions.
Schedule Page:310.18 Line No.:4 Column:b
WaferTech -FERC T-12 -Contract Termination date:November 30,2002
Schedule Page:310.18 Line No.:5 Column:b
Western Area Power Administration -FERC 313 -Contract termination date:December 31,2004.
Schedule Page:310.18 Line No.:5 Column:jPriorPeriodAdjustment
Schedule Page:310.18 Line No.:6 Column:b
Western Area Power Administration -FERC 328 -Contract termination date:December 31,2004.
Schedule Page:310.18 Line No.:6 Column:jPriorPeriodAdjustment
Schedule Page:310.18 Line No.:7 Column:jPriorPeriodAdjustment
Schedule Page:310.18 Line No.:8 Column:j
Prior Period Adjustment
Schedule Page:310.18 Line No.:9 Column:b
Western Area Power Administration -FERC 313 -Contract termination date:December 31,2004.
Schedule Page:310.18 Line No.:10 Column:b
Western Area Power Administration -FERC 328 -Contract termination date:December 31,2004.
Schedule Page:310.18 Line No.:11 Column:b
Secondary,Economy and/or non-firm sales,including some hourly firm transactions.
Schedule Page:310.18 Line No.:12 Column:b
Secondary,Economy and/or non-firm sales,including some hourly firm transactions.
Schedule Page:310.18 Line No.:14 Column:b
Secondary,Economy and/or non-firm sales,including some hourly firm transactions.
Schedule Page:310.19 Line No.:2 Column:g
Accrual Adjustment
Schedule Page:310.19 Line No.:2 Column:j
FERC FORM NO.1 (ED.12-87)Page 450.6
Name of Respondent This Report is:Date of Report Year of Report
(1)X_An Original (Mo,Da,Yr)
PacifiCorp (2)A Resubmission //Dec 31,2000
FOOTNOTEDATA
Footnote Linked.See note on 310.19,Row:2,col/item:g
FERC FORM NO.1 (ED.12-87)Page 450.7
Nan>eofRespondent This Repodis:DateofRepod YearofRepod
(1)X An Original (Mo,Da,Yr)
PacifiCorp (2)_A Resubmission //Dec 31,2000
FOOTNOTEDATA
Schedule Page:326 Line No.:3 Column:b
Non-Firm.
Schedule Page:326 Line No.:4 Column:I
Prior period adjustment.
Schedule Page:326 Line No.:5 Column:b
Non-Firm.
Schedule Page:326 Line No.:7 Column:b
Non-Firm.
Schedule Page:326 Line No.:9 Column:b
Arizona Public Service -Contract Termination Date:October 31,2020.
Schedule Page:326 Line No.:10 Column:b
Arizona Public Service -Contract Termination Date:October 31,2020.
Schedule Page:326 Line No.:10 Column:I
Settlement of certain disputes concerning rights and obligations under Power Agreement.
Schedule Page:326 Line No.:11 Column:b
Non-Firm.
Schedule Page:326 Line No.:13 Column:b
Non-Firm.
Schedule Page:326 Line No.:13 Column:I
Operating expense,bond interest,amortization and taxes.Operating reservation.
Schedule Page:326 Line No.:14 Column:b
Avista Corp.-Contract Termination Date:September 15,2003.
Schedule Page:326.1 Line No.:2 Column:b
Non-Firm.
Schedule Page:326.1 Line No.:4 Column:b
Under Electric Service Agreement subject to termination upon timely notification.
Schedule Page:326.1 Line No.:8 Column:b
Black Hills Power &Light Company -Contract Termination Date:December 31,2000.
Schedule Page:326.1 Line No.:9 Column:IOperationandmaintenanceexpenseassociated with the combustion turbine located in RapidCity,South Dakota.
Schedule Page:326.1 Line No.:11 Column:b
Non-Firm.
Schedule Page:326.1 Line No.:13 Column:b
Bonneville Power Administration -Contract Termination Date:March 31,2003.
Schedule Page:326.2 Line No.:1 Column:b
Non-Firm.
Schedule Page:326.2 Line No.:2 Column:I
Premium for physical call option.
Schedule Page:326.2 Line No.:9 Column:b
Non-Firm.
Schedule Page:326.2 Line No.:11 Column:b
Non-Firm.
Schedule Page:326.2 Line No.:12 Column:I
Imbalance energy expense.
Schedule Page:326.2 Line No.:13 Column:b
Non-Firm.
Schedule Page:326.3 Line No.:3 Column:I
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)
PacifiCorp (2)_A Resubmission //Dec 31,2000
FOOTNOTEDATA
Operating expense,bond interest,amortization and taxes.
Schedule Page:326.3 Line No.:4 Column:b
Non-Firm.
Schedule Page:326.3 Line No.:4 Column:I
Operating expense,bond interest,amortization and taxes.
Schedule Page:326.3 Line No.:9 Column:b
Non-Firm.
Schedule Page:326.3 Line No.:11 Column:b
Columbia Storage Power Exchange -Contract Termination Date:March 31,2003.
Schedule Page:326.3 Line No.:14 Column:b
Non-Firm.
Schedule Page:326.4 Line No.:6 Column:b
Deseret Generation &Transmission Coop.-Contract Termination Date:July 25,2003.
Schedule Page:326.4 Line No.:6 Column:I
Damages for improper curtailment and dispatch.
Schedule Page:326.4 Line No.:7 Column:b
Deseret Generation &Transmission Coop.-Contract Termination Date:July 25,2003.
Schedule Page:326.4 Line No.:7 Column:I
Prior period adjustment.
Schedule Page:326.4 Line No.:9 Column:IOperatingexpense,bond interest,amortization and taxes.
Schedule Page:326.4 Line No.:10 Column:b
Non-Firm.
Schedule Page:326.4 Line No.:13 Column:b
Non-Firm.
Schedule Page:326.5 Line No.:1 Column:b
Non-Firm.
Schedule Page:326.5 Line No.:4 Column:b
Non-Firm.
Schedule Page:326.5 Line No.:6 Column:b
Non-Firm.
Schedule Page:326.5 Line No.:8 Column:b
Non-Firm.
Schedule Page:326.5 Line No.:13 Column:b
Under Electric Service Agreement subject to termination upon timely notification.
Schedule Page:326.5 Line No.:14 Column:b
Flathead Electric Cooperative,Inc.-Contract Termination Date:12 months notification.
Schedule Page:326.6 Line No.:3 Column:b
Non-Firm.
Schedule Page:326.6 Line No.:6 Column:b
Under Electric Service Agreement subject to termination upon timely notification.
Schedule Page:326.6 Line No.:7 Column:b
Grant County PUD No.2 -Contract Termination Date:2 years written notice.
Schedule Page:326.6 Line No.:8 Column:IOperatingexpense,bond interest,amortization and taxes.
Schedule Page:326.6 Line No.:9 Column:I
Operating expense,bond interest,amortization and taxes.
Schedule Page:326.6 Line No.:10 Column:b
Non-Firm.
FERC FORM NO.1 (ED.12-87)Page 450.1
Name of Respondent This Report is:Date of Report Year of Report
(1)X An Original (Mo,Da,Yr)
PacifiCorp (2)A Resubmission //Dec 31,2000
FOOTNOTEDATA
Schedule Page:326.6 Line No.:10 Column:I
Operating reservation.
Schedule Page:326.6 Line No.:11 Column:I
Prior period adjustment.
Schedule Page:326.6 Line No.:12 Column:IOperatingreservation.
Schedule Page:326.6 Line No.:14 Column:b
Under Electric Service Agreement subject to termination upon timely notification.
Schedule Page:326.7 Line No.:1 Column:I
On peak incentive,supplemental dispatch efficiency expense,start-up charges,committeesettlementsandpriorperiodadjustment.
Schedule Page:326.7 Line No.:2 Column:I
Charge for hourly load shaping.
Schedule Page:326.7 Line No.:3 Column:b
Non-Firm.
Schedule Page:326.7 Line No.:4 Column:b
Under Electric Service Agreement subject to termination upon timely notification.
Schedule Page:326.7 Line No.:6 Column:b
Non-Firm.
Schedule Page:326.7 Line No.:6 Column:I
Operating reservation.
Schedule Page:326.7 Line No.:9 Column:I
Prior period adjustment .
Schedule Page:326.7 Line No.:14 Column:b
Non-Firm.
Schedule Page:326.8 Line No.:1 Column:IOperatingreservation.
Schedule Page:326.8 Line No.:5 Column:b
Non-Firm.
Schedule Page:326.8 Line No.:9 Column:b
Non-Firm.
Schedule Page:326.8 Line No.:11 Column:b
Non-Firm.
Schedule Page:326.8 Line No.:11 Column:I
Operating reservation.
Schedule Page:326.8 Line No.:12 Column:b
Under Electric Service Agreement subject to termination upon timely notification.
Schedule Page:326.8 Line No.:14 Column:b
Non-Firm.
Schedule Page:326.9 Line No.:2 Column:b
Under Electric Service Agreement subject to termination upon timely notification.
Schedule Page:326.9 Line No.:3 Column:b
Under Electric Service Agreement subject to termination upon timely notification.
Schedule Page:326.9 Line No.:4 Column:b
Non-Firm.
Schedule Page:326.9 Line No.:8 Column:b
Non-Firm.
Schedule Page:326.9 Line No.:10 Column:I
Operating reservation.
FERC FORM NO.1 (ED.12-87)Page 450.2
Narne of Respondent This Reportis:Date of Report Year of Report
(1)X An Original (Mo,Da,Yr)
PacifiCorp (2)_A Resubrnission //Dec 31,2000
FOOTNOTE DATA
Schedule Page:326.9 Line No.:13 Column:b
Prior period adjustment.
Schedule Page:326.9 Line No.:13 Column:I
Prior period adjustment .
Schedule Page:326.9 Line No.:14 Column:b
Prior period adjustment.
Schedule Page:326.9 Line No.:14 Column:I
Prior period adjustment.
Schedule Page:326.10 Line No.:1 Column:b
Non-Firm.
Schedule Page:326.10 Line No.:3 Column:b
Non-Firm.
Schedule Page:326.10 Line No.:5 Column:b
Under Electric Service Agreement subject to termination upon timely notification.
Schedule Page:326.10 Line No.:6 Column:b
Non-Firm.
Schedule Page:326.10 Line No.:9 Column:b
Non-Firm.
Schedule Page:326.10 Line No.:11 Column:b
Portland General Electric Company -Contract Termination Date:December 18,2001.
Schedule Page:326.10 Line No.:11 Column:IOperationexpenseplusamortizationofunrecovered costs of Cove Project.
Schedule Page:326.10 Line No.:12 Column:b
Non-Firm.
Schedule Page:326.10 Line No.:12 Column:I
Operating reservation.
Schedule Page:326.10 Line No.:13 Column:b
Prior period adjustment .
Schedule Page:326.10 Line No.:13 Column:I
Recovery of PGE Pilot,schedule 78 charges.
Schedule Page:326.11 Line No.:1 Column:b
Non-Firm.
Schedule Page:326.11 Line No.:3 Column:b
Non-Firm.
Schedule Page:326.11 Line No.:6 Column:b
Under Electric Service Agreement subject to termination upon timely notification.
Schedule Page:326.11 Line No.:7 Column:b
Non-Firm.
Schedule Page:326.11 Line No.:9 Column:b
Non-Firm.
Schedule Page:326.11 Line No.:11 Column:b
Non-Firm.
Schedule Page:326.11 Line No.:11 Column:I
Operating expense,bond interest,amortization and taxes.Operating reservation.
Schedule Page:326.11 Line No.:14 Column:b
Redding,City of -Contract Termination Date:May 31,2014.
Schedule Page:326.11 Line No.:14 Column:I
Prior period adjustment.
Schedule Page:326.12 Line No.:1 Column:b
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)
PacifiCorp (2)_A Resubmission //Dec 31,2000
FOOTNOTEDATA
Non-Firm.
Schedule Page:326.12 Line No.:3 Column:b
Non-Firm.
Schedule Page:326.12 Line No.:3 Column:I
Premium for physical call option.
Schedule Page:326.12 Line No.:5 Column:b
Non-Firm.
Schedule Page:326.12 Line No.:7 Column:b
Non-Firm.
Schedule Page:326.12 Line No.:11 Column:b
Sacramento Municipal Utility District -Contract Termination Date:December 31,2014.
Schedule Page:326.12 Line No.:12 Column:b
Non-Firm.
Schedule Page:326.12 Line No.:14 Column:b
Non-Firm.
Schedule Page:326.13 Line No.:2 Column:b
Non-Firm.
Schedule Page:326.13 Line No.:4 Column:b
Non-Firm.
Schedule Page:326.13 Line No.:4 Column:I
Prior period adjustment.
Schedule Page:326.13 Line No.:5 Column:I
Prior period adjustment.
Schedule Page:326.13 Line No.:7 Column:b
Non-Firm.
Schedule Page:326.13 Line No.:8 Column:IOperatingreservation.
Schedule Page:326.13 Line No.:9 Column:b
Non-Firm.
Schedule Page:326.13 Line No.:12 Column:b
Non-Firm.
Schedule Page:326.14 Line No.:2 Column:b
Southern California Edison Co.-Contract Termination Date:March 15,2003.
Schedule Page:326.14 Line No.:2 Column:I
Prior period adjustment.
Schedule Page:326.14 Line No.:5 Column:b
Non-Firm.
Schedule Page:326.14 Line No.:6 Column:b
Under Electric Service Agreement subject to termination upon timely notification.
Schedule Page:326.14 Line No.:7 Column:b
Under Electric Service Agreement subject to termination upon timely notification.
Schedule Page:326.14 Line No.:10 Column:b
Non-Firm.
Schedule Page:326.14 Line No.:12 Column:b
Non-Firm.
Schedule Page:326.14 Line No.:12 Column:IOperatingreservation.
Schedule Page:326.15 Line No.:2 Column:b
Non-Firm.
FERC FORM NO.1 (ED.12-87)Page 450.4
Name of Respondent This Report is:Date of Report Year of Report
(1)X_An Original (Mo,Da,Yr)
PacifiCorp (2)A Resubmission //Dec 31,2000
FOOTNOTEDATA
Schedule Page:326.15 Line No.:4 Column:b
Non-Firm.
Schedule Page:326.15 Line No.:5 Column:b
Transalta Energy Marketing Corp.-Contract Termination Date:June 30,2007.
Schedule Page:326.15 Line No.:7 Column:b
Tri-State Generation &Transmission -Contract Termination Date:December 31,2020.
Schedule Page:326.15 Line No.:8 Column:b
Non-Firm.
Schedule Page:326.15 Line No.:10 Column:bNon·-Firm.
Schedule Page:326.15 Line No.:13 Column:b
Non-Firm.
Schedule Page:326.15 Line No.:14 Column:b
Non-Firm.
Schedule Page:326.16 Line No.:5 Column:b
Under Electric Service Agreement subject to termination upon timely notification.
Schedule Page:326.16 Line No.:6 Column:b
Non-Firm.
Schedule Page:326.16 Line No.:8 Column:b
Non-Firm.
Schedule Page:326.16 Line No.:11 Column:b
Non-Firm.
Schedule Page:326.16 Line No.:11 Column:I
Premium for physical call option.
Schedule Page:326.16 Line No.:14 Column:I
Accounting accrual.
Schedule Page:326.17 Line No.:2 Column:I
Exchange energy expense.
Schedule Page:326.17 Line No.:3 Column:I
Exchange energy expense.
Schedule Page:326.17 Line No.:4 Column:I
Exchange energy expense .
Schedule Page:326.17 Line No.:7 Column:I
Load factoring and storage expense.
Schedule Page:326.17 Line No.:8 Column:I
Exchange energy expense.
Schedule Page:326.17 Line No.:9 Column:I
Exchange energy expense.
Schedule Page:326.17 Line No.:10 Column:I
Exchange energy expense.
Schedule Page:326.17 Line No.:11 Column:I
Load factoring and storage expense.
Schedule Page:326.17 Line No.:12 Column:c
Pacific Northwest Electric Power Planning and Conservation Act,FERC Electric Tariff,Original Volume No.1.
Schedule Page:326.17 Line No.:12 Column:h
These megawatthours represent book entry only.No actual energy transfer took place.
Schedule Page:326.17 Line No.:12 Column:i
These megawatthours represent book entry only.No actual energy transfer took place.
FERC FORM NO.1 (ED.12-87)Page 450.5
Name of Respondent This Reportis:Date of Report Year of Report
(1)X_An Original (Mo,Da,Yr)
PacifiCorp (2)_A Resubmission //Dec 31,2000
FOOTNOTEDATA
Schedule Page:326,17 Line No.:12 Column:I
Pacific Northwest Electric Power Planning and Conservation Act,FERC Electric Tariff,Original Volume No.1.
Schedule Page:326.17 Line No.:13 Column:IExchangeenergyexpense.
Schedule Page:326.17 Line No.:14 Column:I
Exchange energy expense.
Schedule Page:326.18 Line No.:1 Column:IExchangeenergyexpense.
Schedule Page:326.18 Line No.:3 Column:I
Load factoring and storage expense.
Schedule Page:326.18 Line No.:4 Column:I
(16)Storage charge.
Schedule Page:326.18 Line No.:5 Column:IExchangeenergyexpense.
Schedule Page:326.18 Line No.:9 Column:I
Exchange energy expense.
Schedule Page:326.18 Line No.:10 Column:I
Imbalance energy expense.
Schedule Page:326.18 Line No.:11 Column:IExchangeenergyexpense.
Schedule Page:326.18 Line No.:12 Column:I
Imbalance energy expense.
Schedule Page:326.19 Line No.:2 Column:I
(16)Storage charge.
Schedule Page:326.19 Line No.:4 Column:IExchangeenergyexpense.
Schedule Page:326.19 Line No.:6 Column:IExchangeenergyexpense.
Schedule Page:326.19 Line No.:10 Column:b
Not applicable:adjustment for inadavertant interchange.
FERC FORM NO.1 (ED.12-87)Page 450.6
Name of Respondent This Report is:Date of Report Year of Report
(1)X An Original (Mo,Da,Yr)
PacifiCorp (2)_A Resubmission //Dec 31,2000
FOOTNOTE DATA
Schedule Page:328 Line No.:1 Column:b
Various signatories to the Original Volume 11 Point-to-Point Transmission Tariff.
Schedule Page:328 Line No.:1 Column:c
Various signatories to the Original Volume 11 Point-to-Point Transmission Tariff.
Schedule Page:328 Line No.:1 Column:d
Non-firm.
Schedule Page:328 Line No.:2 Column:b
Footnote Linked.See note on 328,Row:1,col/item:c
Schedule Page:328 Line No.:2 Column:c
Footnote Linked.See note on 328,Row:1,col/item:c
Schedule Page:328 Line No.:2 Column:d
Non-firm.
Schedule Page:328 Line No.:3 Column:b
Footnote Linked.See note on 328,Row:1,col/item:c
Schedule Page:328 Line No.:3 Column:c
Footnote Linked.See note on 328,Row:1,col/item:c
Schedule Page:328 Line No.:3 Column:d
Non-firm.
Schedule Page:328 Line No.:4 Column:b
Footnote Linked.See note on 328,Row:1,col/item:c
Schedule Page:328 Line No.:5 Column:d
Black Hills Power &Light -FERC 42 -Contract Termination Date:December 31,2006.
Schedule Page:328 Line No.:5 Column:m
Network Integration transmission service.
Schedule Page:328 Line No.:6 Column:d
Black Hills Power &Light -FERC 236 -Contract Termination Date:December 31,2023.
Schedule Page:328 Line No.:7 Column:b
Footnote Linked.See note on 328,Row:1,collitem:c
Schedule Page:328 Line No.:7 Column:c
Footnote Linked.See note on 328,Row:1,collitem:c
Schedule Page:328 Line No.:8 Column:d
Bonneville Power Administration -FERC 324 -Contract Termination Date:Earlier of one year written notice,or expiration of the life of
the project.
Schedule Page:328 Line No.:8 Column:m
Demand dollars plus a fixed cost calculated using plant investment values at various U.S.governmentfacilities.
Schedule Page:328 Line No.:9 Column:d
Bonneville Power Administration -FERC 299 -Contract Termination Date:Earlier of three years prior written notice,or upon
termination of all deliveries.
Schedule Page:328 Line No.:9 Column:m
Charges for monitoring,scheduling,load following and spinning reserve.
Schedule Page:328 Line No.:10 Column:d
Bonneville Power Administration -FERC 237 -Under transfer agreements subject to termination upon timely notification.
Schedule Page:328 Line No.:10 Column:m
Sole use of facilities charge.
Schedule Page:328 Line No.:11 Column:d
Bonneville Power Administration -FERC 256 -Subject to termination upon timely notification.
Schedule Page:328 Line No.:12 Column:b
Footnote Linked.See note on 328,Row:1,col/item:c
FERC FORM NO.1 (ED.12-87)Page 450
NanteofRespondent This Repodis:DateofRepod YearofRepod
(1)X An Original (Mo,Da,Yr)
PacifiCorp (2)A Resubmission //Dec 31,2000
FOOTNOTEDATA
Schedule Page:328 Line No.:12 Column:c
Footnote Linked.See note on 328,Row:1,col/item:c
Schedule Page:328 Line No.:12 Column:d
Non-firm.
Schedule Page:328 Line No.:14 Column:b
Footnote Linked.See note on 328,Row:1,col/item:c
Schedule Page:328 Line No.:14 Column:c
Footnote Linked.See note on 328,Row:1,col/item:c
Schedule Page:328 Line No.:14 Column:d
Non-firm.
Schedule Page:328 Line No.:15 Column:b
Footnote Linked.See note on 328,Row:1,col/item:c
Schedule Page:328 Line No.:15 Column:c
Footnote Linked.See note on 328,Row:1,col/item:c
Schedule Page:328 Line No.:15 Column:d
Non-firm.
Schedule Page:328 Line No.:15 Column:m
Prior period adjustment.
Schedule Page:328 Line No.:16 Column:d
Deseret Generation &Transmission Coop.-FERC 280 -Contract Termination Date:April 18,2021.
Schedule Page:328 Line No.:17 Column:c
Footnote Linked.See note on 328,Row:1,col/item:c
Schedule Page:328 Line No.:17 Column:d
Non-finn.
Schedule Page:328.1 Line No.:1 Column:b
Footnote Linked.See note on 328,Row:1,col/item:c
Schedule Page:328.1 Line No.:1 Column:c
Footnote Linked.See note on 328,Row:1,col/item:c
Schedule Page:328.1 Line No.:1 Column:d
Non-finn.
Schedule Page:328.1 Line No.:2 Column:b
Footnote Linked.See note on 328,Row:1,col/item:c
Schedule Page:328.1 Line No.:2 Column:c
Footnote Linked.See note on 328,Row:1,col/item:c
Schedule Page:328.1 Line No.:2 Column:d
Non-firm.
Schedule Page:328.1 Line No.:3 Column:b
Footnote Linked.See note on 328,Row:1,col/item:c
Schedule Page:328.1 Line No.:3 Column:c
Footnote Linked.See note on 328,Row:1,col/item:c
Schedule Page:328.1 Line No.:4 Column:d
Fall River Rural Electric Coop -FERC 322 -Contract Termination Date:February 4,2027.
Schedule Page:328.1 Line No.:5 Column:d
Flathead Electric Coop.,Inc.-FERC Vol.11 -Contract Termination Date:12 months advance notice.
Schedule Page:328.1 Line No.:5 Column:m
Charges for monitoring,scheduling,load following and spinning reserve.
Schedule Page:328.1 Line No.:6 Column:d
Idaho Power Company -OV-11 -Contract Termination Date:September 30,2001.
FERC FORM NO.1 (ED.12-87)Page 450.1
Name of Respondent This Report is:Date of Report Year of Report
(1)X An Original (Mo,Da,Yr)
PacifiCorp (2)_A Resubmission //Dec 31,2000
FOOTNOTEDATA
Schedule Page:328.1 Line No.:7 Column:b
Footnote Linked.See note on 328,Row:1,col/item:c
Schedule Page:328.1 Line No.:7 Column:c
Footnote Linked.See note on 328,Row:1,col/item:c
Schedule Page:328.1 Line No.:8 Column:b
Footnote Linked.See note on 328,Row:1,col/item:c
Schedule Page:328.1 Line No.:8 Column:c
Footnote Linked.See note on 328,Row:1,col/item:c
Schedule Page:328.1 Line No.:8 Column:d
Non-firm.
Schedule Page:328.1 Line No.:8 Column:m
Prior period adjustment.
Schedule Page:328.1 Line No.:9 Column:b
Footnote Linked.See note on 328,Row:1,col/item:c
Schedule Page:328.1 Line No.:9 Column:d
Non-firm.
Schedule Page:328.1 Line No.:10 Column:b
Footnote Linked.See note on 328,Row:1,col/item:c
Schedule Page:328.1 Line No.:10 Column:c
Footnote Linked.See note on 328,Row:1,col/item:c
Schedule Page:328.1 Line No.:11 Column:d
Moon Lake -FERC 302 -Contract Termination Date:Year to year.
Schedule Page:328.1 Line No.:12 Column:c
Footnote Linked.See note on 328,Row:1,col/item:c
Schedule Page:328.1 Line No.:12 Column:d
Non-firm.
Schedule Page:328.1 Line No.:13 Column:b
Footnote Linked.See note on 328,Row:1,col/item:c
Schedule Page:328.1 Line No.:13 Column:c
Footnote Linked.See note on 328,Row:1,col/item:c
Schedule Page:328.1 Line No.:13 Column:d
Non-firm.
Schedule Page:328.1 Line No.:14 Column:b
Footnote Linked.See note on 328,Row:1,col/item:c
Schedule Page:328.1 Line No.:14 Column:c
Footnote Linked.See note on 328,Row:1,col/item:c
Schedule Page:328.1 Line No.:14 Column:d
Non-firm.
Schedule Page:328.1 Line No.:15 Column:b
Footnote Linked.See note on 328,Row:1,col/item:c
Schedule Page:328.1 Line No.:15 Column:c
Footnote Linked.See note on 328,Row:1,col/item:c
Schedule Page:328.1 Line No.:15 Column:m
Prior period adjustment.
Schedule Page:328.1 Line No.:16 Column:d
Powerex -OV-11 -Contract Termination Date:October 31,2003.
Schedule Page:328.1 Line No.:17 Column:b
Footnote Linked.See note on 328,Row:1,col/item:c
FERC FORM NO.1 (ED.12-87)Page 450.2
NameofRespondent ThisRepodis:DateofRepod YearofRepod
(1)X An Original (Mo,Da,Yr)
PacifiCorp (2)_A Resubmission //Dec 31,2000
FOOTNOTEDATA
Schedule Page:328.1 Line No.:17 Column:c
Footnote Linked.See note on 328,Row:1,col/item:c
Schedule Page:328.2 Line No.:1 Column:b
Footnote Linked.See note on 328,Row:1,col/item:c
Schedule Page:328.2 Line No.:1 Column:c
Footnote Linked.See note on 328,Row:1,col/item:c
Schedule Page:328.2 Line No.:1 Column:d
Non-firm.
Schedule Page:328.2 Line No.:2 Column:c
Footnote Linked.See note on 328,Row:1,col/item:c
Schedule Page:328.2 Line No.:2 Column:d
Non-firm.
Schedule Page:328.2 Line No.:3 Column:b
Footnote Linked.See note on 328,Row:1,col/item:c
Schedule Page:328.2 Line No.:3 Column:d
Non-firm.
Schedule Page:328.2 Line No.:4 Column:b
Footnote Linked.See note on 328,Row:1,col/item:c
Schedule Page:328.2 Line No.:4 Column:c
Footnote Linked.See note on 328,Row:1,col/item:c
Schedule Page:328.2 Line No.:4 Column:d
Non-firm.
Schedule Page:328.2 Line No.:5 Column:c
Footnote Linked.See note on 328,Row:1,col/item:c
Schedule Page:328.2 Line No.:5 Column:d
Seawest Windpower,Inc.-OV-11 -Contract Termination Date:12 months advance notice.
Schedule Page:328.2 Line No.:6 Column:d
Non-firm.
Schedule Page:328.2 Line No.:7 Column:b
Footnote Linked.See note on 328,Row:1,col/item:c
Schedule Page:328.2 Line No.:7 Column:c
Footnote Linked.See note on 328,Row:1,col/item:c
Schedule Page:328.2 Line No.:7 Column:d
Non-firm.
Schedule Page:328.2 Line No.:7 Column:m
Prior period adjustment.
Schedule Page:328.2 Line No.:8 Column:b
Footnote Linked.See note on 328,Row:1,col/item:c
Schedule Page:328.2 Line No.:8 Column:c
Footnote Linked.See note on 328,Row:1,col/item:c
Schedule Page:328.2 Line No.:9 Column:d
Non-firm.
Schedule Page:328.2 Line No.:9 Column:m
Prior period adjustment.
Schedule Page:328.2 Line No.:10 Column:b
Footnote Linked.See note on 328,Row:1,col/item:c
Schedule Page:328.2 Line No.:10 Column:c
Footnote Linked.See note on 328,Row:1,col/item:c
FERC FORM NO.1 (ED.12-87)Page 450.3
Narneof Respondent This Report is:Date of Report Year of Report
(1)X An Original (Mo,Da,Yr)
PacifiCorp (2)_A Resubmission //Dec 31,2000
FOOTNOTEDATA
Schedule Page:328.2 Line No.:10 Column:d
Non-firm.
Schedule Page:328.2 Line No.:11 Column:d
State of South Dakota -OV-11 -Contract Termination Date:12 months advance notice.
Schedule Page:328.2 Line No.:12 Column:b
Footnote Linked.See note on 328,Row:1,col/item:c
Schedule Page:328.2 Line No.:12 Column:c
Footnote Linked.See note on 328,Row:1,col/item:c
Schedule Page:328.2 Line No.:12 Column:d
Non-firm.
Schedule Page:328.2 Line No.:13 Column:d
Tri-State Generation &Transmission Coop.-FERC 123 -Contact Termination Date:October 1,2014.
Schedule Page:328.2 Line No.:13 Column:m
Prior period adjustment.
Schedule Page:328.2 Line No.:14 Column:d
USBR -FERC 67 -Under transfer agreement subject to termination when easement from United States for transmission line between
Redmond,Oregon and Prineville,Oregon is removed.
Schedule Page:328.2 Line No.:14 Column:m
Fixed annual charge.
Schedule Page:328.2 Line No.:15 Column:d
Utah Associated Municipal Power -FERC 297 -Contract Termination Date:December 31,2003.
Schedule Page:328.2 Line No.:15 Column:m
Charges for monitoring,scheduling,load following and spinning reserve.
Schedule Page:328.2 Line No.:16 Column:d
Utah Municipal Power Agency -FERC 279 -Under transfer agreements subject to termination upon timely notice.
Schedule Page:328.2 Line No.:16 Column:m
Charges for monitoring,scheduling,load following and spinning reserve.
Schedule Page:328.2 Line No.:17 Column:b
Footnote Linked.See note on 328,Row:1,col/item:c
Schedule Page:328.2 Line No.:17 Column:c
Footnote Linked.See note on 328,Row:1,col/item:c
Schedule Page:328.2 Line No.:17 Column:d
Non-firm.
Schedule Page:328.3 Line No.:1 Column:d
Western Area Power Administration -FERC 45 -Under transfer agreements subject to termination upon timely notification.
Schedule Page:328.3 Line No.:1 Column:m
Prior period adjustment.
Schedule Page:328.3 Line No.:2 Column:d
Westem Area Power Administration -FERC 262/263 -Contract Termination Date:June 1,2047.
Schedule Page:328.3 Line No.:3 Column:d
Western Area Power Administration -FERC 262/263 -Contract Termination Date:June 1,2047.
Schedule Page:328.3 Line No.:4 Column:d
Westem Area Power Administration -OV-11 -Contract Termination Date:May 31,2003.
Schedule Page:328.3 Line No.:5 Column:b
Footnote Linked.See note on 328,Row:1,col/item:c
Schedule Page:328.3 Line No.:5 Column:d
Western Area Power Administration -OV-11 -Contract Termination Date:12 months advance notice.
Schedule Page:328.3 Line No.:5 Column:m
FERC FORM NO.1 (ED.12-87)Page 450.4
Name of Respondent This Report is:Date of Report Year of Report
(1)X_An Original (Mo,Da,Yr)
PacifiCorp (2)_A Resubmission //Dec 31,2000
FOOTNOTE DATA
Network Integration transmission service.
Schedule Page:328.3 Line No.:6 Column:b
Footnote Linked.See note on 328,Row:1,col/item:c
Schedule Page:328.3 Line No.:6 Column:c
Footnote Linked.See note on 328,Row:1,col/item:c
Schedule Page:328.3 Line No.:6 Column:d
Non-firm.
Schedule Page:328.3 Line No.:7 Column:d
Western Area Power Administration -FERC 286 -Contract Termination Date:Four years written notice.
FERC FORM NO.1 (ED.12-87)Page 450.5
Name of Respondent This Report is:Date of Report Year of Report
(1)X_An Original (Mo,Da,Yr)
PacifiCorp (2)_A Resubmission //Dec 31,2000
FOOTNOTEDATA
Schedule Page:332 Line No.:1 Column:f
Prior period adjustment &Use of Facilities expense.Ancillary Services.
Schedule Page:332 Line No.:2 Column:f
Prior Period adjustment.
Schedule Page:332 Line No.:3 Column:f
Prior period adjustment &Use of Facilities expense.
Schedule Page:332 Line No.:5 Column:f
Prior Period adjustment.Respondent's portion of specified costs of certain facilities.
Schedule Page:332 Line No.:8 Column:f
Use of Facilities expense.
Schedule Page:332 Line No.:9 Column:f
Prior Period adjustment.
Schedule Page:332 Line No.:10 Column:fAncillaryServices.
Schedule Page:332 Line No.:11 Column:f
Transmission service charges and administration fees.
Schedule Page:332 Line No.:12 Column:f
Prior Period adjustment.Respondent's portion of specified costs of certain facilities.
Schedule Page:332 Line No.:14 Column:f
Use of Facilities expense.
Schedule Page:332 Line No.:15 Column:fAncillaryServices.
Prior Period adjustment.Respondent's portion of specified costs of certain facilities.
Schedule Page:332 Line No.:16 Column:f
Respondent's portion of specified costs of certain facilities.
Schedule Page:332.1 Line No.:2 Column:f
Ancillary Services.
Schedule Page:332.1 Line No.:4 Column:f
Ancillary Services.
Schedule Page:332.1 Line No.:5 Column:f
Prior Period adjustment.
Schedule Page:332.1 Line No.:6 Column:fAncillaryServices.
Prior period adjustment.
Schedule Page:332.1 Line No.:8 Column:f
Use of Facilities expense.
Schedule Page:332.1 Line No.:9 Column:fAncillaryServices.
Prior Period adjustment.
Schedule Page:332.1 Line No.:10 Column:f
Prior Period adjustment.
Schedule Page:332.1 Line No.:11 Column:f
Prior period adjustment &Use of Facilities expense.Ancillary Services.
Schedule Page:332.1 Line No.:12 Column:f
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)
PacifiCorp (2)A Resubmission //Dec 31,2000
FOOTNOTEDATA
Accrual adjustment.
FERC FORM NO.1 (ED.12-87)Page 450.1
Name of Respondent This Report is:Date of Report Year of Report
(1)X_An Original (Mo,Da,Yr)
PacifiCorp (2)_A Resubmission //Dec 31,2000
FOOTNOTEDATA
Schedule Page:335 Line No.:14 Column:a
This club membership should have gone to below the line to account 426.5.
Schedule Page:335 Line No.:20 Column:a
Footnote Linked.See note on 335,Row:14,col/item:a
Schedule Page:335 Line No.:23 Column:a
This was a donation that should have gone below the line to account 426.1.
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)
PacifiCorp (2)_A Resubmission //Dec 31,2000
FOOTNOTEDATA
Schedule Page:336 Line No.:11 Column:b
Account 403 includes a reduction of $10,851,057 for the depreciation of the regulatoryliability"1996 Depreciation Study"in account 254,which is depreciated over a 2 yearperiod.
Schedule Page:336.2 Line No.:30 Column:bdepletion
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)
PacifiCorp (2)A Resubmission //Dec 31,2000
FOOTNOTEDATA
Schedule Page:340.1 Line No.:26 Column:a
Rates vary due to applicable law.
Schedule Page:340.1 Line No.:27 Column:a
Footnote Linked.See note on 340.1,Row:26,col/item:a
Schedule Page:340.1 Line No.:38 Column:a
Based upon weighted average prime rate.
FERC FORM NO.1 (ED.12-87)Page 450
Name of Respondent This Reportis:Date of Report Year of Report
(1)X An Original (Mo,Da,Yr)
PacifiCorp (2)A Resubmission //Dec 31,2000
FOOTNOTEDATA
Schedule Page:402 Line No.:-1 Column:f
This represents the respondent's share.Hunter Plant Unit No.1isownedbyrespondentandProvoCityCorporationwithundividedinterestof93.75%and 6.25%respectively.Hunter Unit No.2
is owned by respondent,Deseret Generation &TransmissionCooperative,and Utah Associated Municipal Power Systems,eachwithundividedinterestof60.31%,25.108%and 14.582%,respectively.
Schedule Page:402.1 Line No.:-1 Column:c
Centralia Plant is operated by respondent and column (c)represents respondent's share.Ownership of the plant is as follows:PacifiCorp -47.5%;The Washington Water PowerCompany-15.0%;Puget Sound Power &Light Company -7.0%;Portland General ElectricCompany-2.5%;The City of Seattle -8.0%;The City of Tacoma -8.0%;Public UtilityDistrictofSnohomishCounty-8.0%;Public Utility No.1 of Grays Harbor County -4.0%.The plant was purchased in May 2000 by Trans Alta.
Schedule Page:402.1 Line No.:-1 Column:eColstripPlantisoperatedbyPPLMontana,LLC and isjointlyowned.Data reported on lines 5 through 43 representsrespondent's 10%share of Colstrip Plant Units No.3 and No.4.
Schedule Page:402.1 Line No.:-1 Column:f
Jim Bridger Plant is operated by PacifiCorp and column (f)represents the respondent's share.Ownership of the plant
is as follows:PacifiCorp -66 2/3%;Idaho Power Company -
33 1/3%.
Schedule Page:402.2 Line No.:-1 Column:b
Wyodak Plant is operated by PacifiCorp and column (b)representstherespondent's share.Ownership of the plant is as follows:PacifiCorp -80%;Black Hills Corporation -20%.
Schedule Page:402.2 Line No.:-1 Column:c
Cholla Plant is operated by Arizona Public Service Company.Respondent owns Unit No.4 plus 37.23%of related commonfacilities.Data reported on lines 5 through 43 representsrespondent's share.
Schedule Page:402.2 Line No.:-1 Column:d
Craig Plant is operated by Tri-State Generation and Transmission
Association and is jointly owned.Data reported on lines 5through43representsrespondent's 19.28%share of Craig Plant
Units No.1 and No.2.
Schedule Page:402.2 Line No.:-1 Column:eHaydenPlantisoperatedbyPublicService Company of Colorado
and is jointly owned.Data reported on lines 5 through 43representsrespondent's 24.5%(45 MW)share of Hayden Unit No.1,
12.6%(33 MW)share of Hayden Unit No.2 and 17.5%of commonfacilities.
Schedule Page:402.2 Line No.:-1 Column:fPacifiCorpownsthesteamturbinegenerator and associatedsystemsdirectlyrelatedtotheoperationofthisunitat
the James River Corporation's Camas paper mill.Modifications
and upgrades to the existing Camas paper mill were necesary
to supply steam to the turbine and to ensure continuedoperationoftheunitintheeventofmillclosure.JamesRiverretainedownershipofthesemodifications.James RiversuppliesthefuelanddeliversthesteamtoPacifiCorp's
FERC FORM NO.1 (ED.12-87)Page 450
NameofRespondent ThisRepodis:DateofRepod YearofRepod
(1)X An Original (Mo,Da,Yr)
PacifiCorp (2)A Resubmission //Dec 31,2000
FOOTNOTEDATA
turbine.None of the facilities are jointly owned.Each asset
is wholly owned,either by PacifiCorp or James River Corporation..
Schedule Page:402.3 Line No.:-1 Column:b
Hermiston Plant is operated by Hermiston Generating Company
L.P.and is jointly owned.Data reported on lines 5 through
43 represents respondent's 50%share of Hermiston Plant.
Schedule Page:402.3 Line No.:-1 Column:d
Hunter Plant Unit No.1 is owned by respondent and Provo City Corporation with undivided
interest of 93.75%and 6.25%respectively.Data reported in column (d)representsrespondent's share.
Schedule Page:402.3 Line No.:-1 Column:e
Hunter Plant Unit No.2 is owned by respondent,Deseret Generation &TransmissionCooperativeandUtahAssociatedMunicipalPowerSystems,each with undivided interest of60.31%,25.108%and 14.582%respectively.Data reported in column (e)representsrespondentsshare.
FERC FORM NO.1 (ED.12-87)Page 450.1
NarneofRespondent ThisRepodis:DateofRepod YearofRepon
(1)X_An Original (Mo,Da,Yr)
PacifiCorp (2)_A Resubmission //Dec 31,2000
FOOTNOTEDATA
Schedule Page:406.1 Line No.:1 Column:e
Pondage for peaking -storage,Upper Klamath Lake.
Schedule Page:406.1 Line No.:1 Column:fStorage,Upper Klamath Lake.
Schedule Page:406.1 Line No.:10 Column:b
Assumes draw down to elevation of 190 feet.
Schedule Page:406.1 Line No.:10 Column:c
Assumes draw down to elevation of 430 feet.
Schedule Page:406.1 Line No.:10 Column:d
Assumes draw down to elevation of 878 feet.
Schedule Page:406.1 Line No.:10 Column:e
Assumes normal pond elevation.
Schedule Page:406.1 Line No.:10 Column:f
Assumes normal pond elevation.
Schedule Page:406.1 Line No.:11 Column:b
Part of the Lewis River Project.The average employee number
for the entire Lewis River Project is 29
Schedule Page:406.1 Line No.:11 Column:c
Part of the Lewis River Project.The average employee number
for the entire Lewis River Project is 29
Schedule Page:406.1 Line No.:11 Column:d
Part of the Lewis River Project.The average employee number for
the entire Lewis River Project is 29
Schedule Page:406.1 Line No.:11 Column:e
Part of Licensed Project No.2082 in California.The averageemployeenumberfortheentireLicensedProjectNo.2082 is 16.
Schedule Page:406.1 Line No.:11 Column:f
Part of Licensed Project No.2082 in California.The averageemployeenumberfortheentireLicensedProjectNo.2082 is 16.
Schedule Page:406.2 Line No.:1 Column:b
Pondage for peaking -storage,Upper Klamath Lake.
Schedule Page:406.2 Line No.:1 Column:c
Storage for regulation.
Schedule Page:406.2 Line No.:1 Column:f
Forebay for peaking.
Schedule Page:406.2 Line No.:10 Column:b
Assumes normal pond elevation.
Schedule Page:406.2 Line No.:10 Column:c
Assumes normal pond elevation.
Schedule Page:406.2 Line No.:10 Column:d
Assumes normal pond elevation.
Schedule Page:406.2 Line No.:11 Column:b
Part of Licensed Project No.2082 in California.The averageemployeenumberfortheentireLicensedProjectNo.2082 is 16.
Schedule Page:406.2 Line No.:11 Column:c
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)
PacifiCorp (2)A Resubmission //Dec 31,2000
FOOTNOTEDATA
Part of Licensed Project No.2082 in California.The averageemployeenumberfortheentireLicensedProjectNo.2082 is 16.
Schedule Page:406.2 Line No.:11 Column:d
The average employee number for the entire Licensed ProjectNo.1927 plants is 29.
Schedule Page:406.2 Line No.:11 Column:e
The average employee number for the entire Licensed ProjectNo.1927 plants is 29.
Schedule Page:406.2 Line No.:11 Column:f
The average employee number for the entire Licensed Project
No.1927 plants is 29.
Schedule Page:406.3 Line No.:1 Column:bForebayforpeaking.
Schedule Page:406.3 Line No.:1 Column:c
Forebay for peaking.
Schedule Page:406.3 Line No.:1 Column:d
Storage,Lemolo Lake.
Schedule Page:406.3 Line No.:1 Column:e
Storage,Lemolo Lake.
Schedule Page:406.3 Line No.:1 Column:f
Pondage for peaking -storage,Lemolo Lake.
Schedule Page:406.3 Line No.:10 Column:b
Assumes normal pond elevation.
Schedule Page:406.3 Line No.:10 Column:c
Assumes normal pond elevation.
Schedule Page:406.3 Line No.:10 Column:f
Assumes normal pond elevation.
Schedule Page:406.3 Line No.:11 Column:b
The average employee number for all Licensed Project No.1927plantsis29.
Schedule Page:406.3 Line No.:11 Column:c
The average employee number for all Licensed Project No.1927plantsis29.
Schedule Page:406.3 Line No.:11 Column:d
The average employee number for the entire Licensed ProjectNo.1927 plants is 29.
Schedule Page:406.3 Line No.:11 Column:e
The average employee number for the entire Licensed Project
No.1927 plants is 29.
Schedule Page:406.3 Line No.:11 Column:f
The average employee number for the entire Licensed ProjectNo.1927 plants is 29.
Schedule Page:406.4 Line No.:1 Column:b
Forebay for peaking.
Schedule Page:406.4 Line No.:10 Column:b
Assumes normal pond elevation.
FERC FORM NO.1 (ED.12-87)Page 450.1
Name of Respondent This Report is:Date of Report Year of Report
(1)X An Original (Mo,Da,Yr)
PacifiCorp (2)_A Resubrnission //Dec 31,2000
FOOTNOTEDATA
Schedule Page:410 Line No.:3 Column:a
Licensed Project No.2381 applicable to both Ashton and
St.Anthony plants.
Schedule Page:410 Line No.:9 Column:a
Licensed Project No.2401 applicable to both Cove and Graceplants(See page 406 for Grace plant).
Schedule Page:410 Line No.:17 Column:a
Used in regulating release of water from Klamath Lake and inmaintainingproperwatersurfacelevelinKlamathRiverbetween
Klamath Falls and Keno,Oregon.
Schedule Page:410 Line No.:20 Column:a
Common plant in North Umpqua Project.All common roads,employeehouses,control equipment,etc.are in this account.
Schedule Page:410 Line No.:30 Column:a
Licensed Project No.2381 applicable to both Ashton andSt.Anthony plants.
Schedule Page:410 Line No.:31 Column:aStoragereservoirforsixplantsonKlamath River (Copco No.1,Copco No.2,East Side,West Side,John C.Boyle,and Iron Gate).
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)
PacifiCorp (2)_A Resubrnission //Dec 31,2000
FOOTNOTEDATA
Schedule Page:422 Line No.:4 Column:a
Centralia Plant is operated by respondent.Ownership of theplantisasfollows:PacifiCorp,47.5%;The Washington WaterPowerCompany,15.0%;Puget Sound Power &Light Company,7.0%;Portland General electric Company,2.5%;The City of Seattle,8.0%;The City of Tacoma,8.0%;Public Utility District ofSnohomushCounty,8.0%;PUD No.1 of Grays Harbor,4.0%.TheCentraliaPlantwaspurchasedinMay2000byTransAlta.
Schedule Page:422 Line No.:5 Column:a
See Footnote Page 422 line 4 Column a.
Schedule Page:422.2 Line No.:16 Column:a
See Footnote Page 422.2 Line 17 Column a.
Schedule Page:422.2 Line No.:18 Column:a
Jim Bridger Plant is operated by respondent.Ownership of theplantisasfollows:PacifiCorp 66 2/3%;Idaho Power Company,
33 1/3%
Schedule Page:422.2 Line No.:29 Column:gIncludes90.43 miles of line between Goshen,Idaho and Monida,Montana,leased from Idaho Power Company.Idaho Power Companyisnotanassociatedcompany.
Schedule Page:422.5 Line No.:13 Column:a
Detail not available for individual lines.
FERC FORM NO.1 (ED.12-87)Page 450
Name of Respondent This Reportis:Date of Report Year of Report
(1)X_An Original (Mo,Da,Yr)
PacifiCorp (2)_A Resubmission //Dec 31,2000
FOOTNOTEDATA
Schedule Page:431 Line No.:10 Column:b
Coal Mine Reclamation costs $9,002,437
Interest On Pollution Control Bonds 19,824,316OperationandMaintenance-Hatchery 1,182,773OperationandMaintenance-Recreation 129,527
30,139,053
FERC FORM NO.1 (ED.12-87)Page 450
INDEX
:Scheduha Page Nk).
Accrued and prepaid taxes ...................................262-263
Accumulated Deferred Income Taxes ...............................234
272-277
Accumulated provisions for depreciation of
common utility plant .......................................356utilityplant.........................................219utilityplant(summary).....................................200-201Advances
from associated companies .....................................256-257Allowances...........................................228-229kmortization
miscellaneous ............................................340
of nuclear fuel ......................................202-203AppropriationsofRetainedEarnings......................................118-119AssociatedCompanies
advances from .............................................256-257corporationscontrolledbyrespondent.......................................103
control over respondent .......................................102interestondebtto...................................256-257
Attestation ...............................iBalancesheet
comparative .................................110-113
notes to ....................................122-123
Bonds ................................256-257CapitalStock................................251discount..................................254
expense ......................................254installmentsrecived..................................252premiums....................................252reacquired........................................251
subscribed .................................252
Cash flows,statement of .............................120-121Changes
important during year ...........................................108-109
Construction
overheads,electric ..............................................217overheadprocedures,general description of ..................................218
work in progress -common utility plant ..................................356
work in progress -electric ...................................216workinprogress-other utility departments ..............................200-201Control
corporations controlled by respondent .................................103
over respondent .......................................102securityholdersandvotingpowers................................106-107Corporation
controlled by .............................103incorporated..................................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 Page Ekl
Deferred
credits,other ................................269
debits,miscellaneous ..........................................233
income taxes accumulated -accelerated
amortization property ..................................272-273
income taxes accumulated -other property ............................274-275
income taxes accumulated -other .....................................276-277
income taxes accumulated -pollution control facilities ..............................234
Definitions,this report form ..............................iii
Depreciation and amortization
of common utility plant ..............................356
of electric plant ..............................219
336-337
Directors .................................105
Discount on capital stock ................................254
Discount -premium on long-term debt ..................................256-257
Distribution of salaries and wages ............................354-355
Dividend appropriations ...........................118-119
Earnings,Retained ............................118-119
Electric energy account ................................401
Environmental protection
expenses ..................................431
facilities .............................430
Expenses
electric operation and maintenance .............................320-323
electric operation and maintenance,summary ...............................323
unamortized debt ...............................256
Extraordinary property losses ................................230
Filing requirements,this report form
General description of construction overhead procedure ...............................218
General information ..................................101
Instructions for filing the FERC Form 1 .............................i-iv
Generating plant statistics
hydroelectric (large)....................................406-407
pumped storage (large)...............................408-409
small plants ................................410-411
steam-electric (large).................................402-403
Hydro-electric generating plant statistics ................................406-407
Identification .............................101
Important changes during year ................................108-109
Income
statement of,by departments ..-.................................114-117
statement of,for the year (see also revenues).................................114-117
deductions,interest on debt to associated companies ..............................340
deductions,miscellaneous amortization .................................340
deductions,other income deduction ............................340
deductions,other interest charges .............................340
Incorporation information ............................101
Installments received on capital stock ...........................252
FERC FORM NO.1 (ED.12-95)Index 2
NDEX (continued)
Schedule Paqe 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 Paqe Ak).
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 ..............................251Prepaidtaxes.....................................262-263Property-losses,extraordinary ..............................230
Pumped storage generating plant statistics ..................................408-409
Purchased power (including power exchanges).............................326-327
Reacquired capital stock ..............................250Reacquiredlong-term debt ...........................256-257
Receivers'certificates ...............................................256-257
Reconciliation of reported net income with taxable income
from Federal income taxes ...................................261Regulatorycommissionexpensesdeferred.............................233Regulatorycommissionexpensesforyear...................................350-351
Research,development and demonstration activities .............................352-353RetainedEarnings
amortization reserve Federal ................................119appropriated....................................118-119statementof,for the year ................................118-119unappropriated.............................118-119
Revenues -electric operating .............................300-301
Salaries and wages
directors fees ..............................105
distribution of .....................................354-355
officers'............------...--.....................104Salesofelectricitybyrateschedules.......-----.....................304Sales-for resale ........---........................310-311Salvage-nuclear fuel .................................202-203
Schedules,this report form .............................2-4Securities
exchange registration --------------..................250-251holdersandvotingpowers.............................106-107
Statement of Cash Flows ...........................120-121Statementofincomefortheyear..........................114-117Statementofretainedearningsfortheyear.............................118-119
Steam-electric generating plant statistics ............................402-403
Stock liability for conversion .........................252
Substations ............................426Supplies-materials and -------------...........227
FERC FORM NO.1 (ED.12-90)Index 4
[NDEX (continued)
Schedule Page Eh .
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