201306012001Annual Report.pdf

THIS FILINGIS (CHECK ONE BOX FOR EACH ITEM
Item 1:An Initial (Original)OR Resubmission No.Form Approved
Submission OMB No.1902-0021
(E×pires 3/31/2005)
Item 2:An OriginalSigned Form OR Conformed Copy
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 ând 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 riature.
Exact Legal Name of Respondent (Company)Year of Report
PacifiCorp Dec.31,2001
FERC FORM No.1 (REV.12-98)
825 N.E.Multnomah
Portland,Oregon 97232
RE CElVED tsos>s23-sooo
FiLED O
2002 JUN 10 AN 9:03
h PACIFICoRP UTILÜÈS C0tÜiiÌS10N
PACIFIC PØWER UTAH POWER
June 6,2002
JeanD.Jewell
Commission Secretary
Idaho Public Utilities Commission
Statehouse
Boise,Idaho 83720
Dear Ms.Jewell:
We are filing herewith our Annual Report,FERC Form No.1,of PacifiCorp to the Idaho
Public Utilities Commission for the year 2001.We also are filing a copy of our SEC Form
10-K.
ery truly ours,
Henry E.ay
Accounting Director
cc:Jeff Larsen
Enclosures:
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r
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w
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or
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a
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s
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fi
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,
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o
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INSTRUCTIONS FOR FILING THE
FERC FORM NO.1
GENEEUIL INFORIDATION
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 of 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.
(b)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 examination of the financial statements of for the year ended on
which we have reported separately under date of .We have also reviewed schedules
of FERC Form No.1 for the year filed with the Federal Energy Regulatory
Commission,for conformity in all material respects with the requirements of the Federal Energy Regulatory
Commission as set forth in its applicable Uniform System of Accounts and published accounting releases.Our review
for this purpose included such tests of the accounting records and such other auditing procedures as we considered
necessary in the circumstances.
Based on our review,in our opinion the accompanying schedules identified in the preceding paragraph (except as
noted below)conform in all material respects with the accounting requirements of the Federal Energy Regulatory
Commission as set forth in its applicable Uniform System of Accounts and published accounting releases.
State in the letter or report,which,if any,of the pages above do not conform to the Commission's
requirements.Describe the discrepancies that exist.
(d)Federal,State and Local Governments and other authorized users may obtain additional blank copies to meet
their requirements free of charge from:
Public Reference and Files Maintenance Branch
Federal Energy Regulatory Commission
888 First Street,NE.Room 2A ES-1
Washington,DC 20426
[phone]
IV.When to Submit
Submit this report form on or before April 30th of the year following the year covered by this report.
V.Where to Send Comments on Public Reporting Burde.n
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
GENEFUlL 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
:igures 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 LAY
Federal Power Act,16 U.S.C.791a-825r)
"Sec.3.The words defined in this section shall have the following meanings for purposes of this Act,to wit:
...(3)"Corporation"means any corporation,joint-stock company,partnership,association,business trust,
organized group of persons,whether incorporated or not,or a receiver or receivers,trustee or trustees of any of
the foregoing.It shalt not include 'municipalities,as hereinafter defined;
(4)"Person"means an individual or a corporation;
(5)"Licensee"means any person,State,or municipality Licensed under the provisions of section 4 of this Act,
and any assignee or successor in interest thereof;
7)"Municipality"means a city,county,irrigation district,drainage district,or other political subdivision
or agency of a State competent under the Laws thereof to carry an the business of developing,transmitting,
unitizing,or distributing power;..."
(11)"Project"means a complete unit of improvement or development,consisting of a power house,all water
conduits,all dams and appurtenant works and structures (including navigation structures)which are a part of said
unit,and all storage,diverting,or forebay reservoirs directly connected therewith,the primary line or Lines
transmitting power therefrom to the point of junction with the distribution system or with the interconnected
primary transmission system,all miscellaneous structures used and useful in connection with said unit or any part
thereof,and all water rights,rights-of-way,ditches,dams,reservoirs,Lands,or interest in Lands the use and
occupancy of which are necessary or appropriate in the maintenance and operation of such unit;
"Sec.4.The Commission is hereby authorized and empowered:
(a)To make investigations and to collect and record data concerning the utilization of the water 'resources of
any region to be developed,the water-power industry and its relation to other industries and to interstate or
foreign commerce,and concerning the location,capacity,development costs,and relation to markets of power sites;
..to the extent the Commission may deem necessary or useful for the purposes of this Act."
"Sec.304.(a)Every Licensee and every public utility shall file with the Commission such annual and other
periodic or special reports as the Commission may be rules and regulations or other prescribe as necessary or
appropriate to assist the Commission in the proper administration of this Act.The Commission my prescribe the
manner and form in which such reports shalt be made,and require from such persons specific answers to all
questions upon which the Commission may need information.The Commission may require that such reports shall
include,among other things,full information as to assets and Liabilities,capitalization,net investment,and
reduction thereof,gross receipts,interest due and paid,depreciation,and other reserves,cost of project and
other facilities,cost of maintenance and operation of the project and other facilities,cost of renewals and
replacement of the project works and other facilities,depreciation,generation,transmission,distribution,
delivery,use,and sale of electric energy.The Commission may require any such person to make adequate provision
for currently determining such costs and other facts.Such reports shall be made under oath unless the Commission
otherwise specifies."
"Sec.309.The Commission shall have power to perform any and all acts,and to prescribe,issue,make,and rescind
such orders,rules and regulations as it may find necessary or appropriate to carry out the provisions of this Act.
Among other things,such rules and regulations may define accounting,technical,and trade terms used in this Act;
and may prescribe the form or forms of all statements,declarations,applications,and reports to be filed with the
Commission,the information which they shall contain,and the time within which they shall be filed..."
General Penalties
"Sec.315.(a)Any licensee or public utility which willfully fails,within the time prescribed by the Commission,
to comply with any order of the Commission,to file any report required under this Act or any rule or regulation of
the Commission thereunder,to submit any information of document required by the Commission in the course of an
investigation conducted under this Act ...shall forfeit to the United States an amount not exceeding $1,000 to be
fixed by the Commission after notice and opportunity for hearing..."
FERC FORM NO.1 (ED.12-91)Page iv
FERC FORM NO.1:
ANNUAL REPORT OF MAJOR ELECTRIC UTILITIES,LICENSEES AND OTHER
IDENTIFICATION
Exact Legal Name of Respondent 02 Year of Report
PacifiCorp Dec.31,2001
03 Previous Name and Date of Change (if name changed during year)
//
04 Address of Principal Office at End of Year (Street,City,State,Zip Code)
825 N.E.Multnomah,Suite 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,Suite 1900 Portland,OR 97232
08 Telephone of Contact Person,lncluding 09 This Report Is 10 Date of Report
Area Code (1)An Original (2)A Resubmission (Mo,Da,Yr)
[phone] //
ATTESTATION
Ne undersigned officer cedifies that helshe has examined the accompanying report:that to the best of his/her knowledge,information,and belief,
.i 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
(Mo,Da,Yr)02GeoffeeryO.Huggins
V.P.&Principal Financial Officer $9 O 1-
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
Name of Respondent This R ort Is:Date of Report Year of Report(1)An Original (Mo,Da,Yr)2001PacifiCorpDec.31,(2)A Resubmission //
LIST OF SCHEDULES (Electric Utility)
Enter in column (c)the terms "none,""not applicable,"or "NA,"as appropriate,where no information or amounts have been reported for
certain pages.Omit pages where the respondents are "none,""not applicable,"or "NA".
Line Title of Schedule Reference Remarks
No.Page No.
(a)(b)(c)
1 General Information 101
2 Control Over Respondent 102
3 Corporations Controlled by Respondent 103
4 Officers 104
5 Directors 105
6 Security Holders and Voting Powers 106-107
7 Important Changes During the Year 108-109
8 Comparative Balance Sheet 110-113
9 Statement of Incomefor the Year 114-117
10 Statement of Retained Earnings for the Year 118-119
11 Statement of Cash Flows 120-121
12 Notes to Financial Statements 122-123
13 Summary of Utility Plant &Accumulated Provisions for Dep,Amort &Dep 200-201
14 Nuclear Fuel Materials 202-203 NA
15 Electric Plant in Service 204-207
16 Electric Plant Leased to Others 213 NA
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 NA
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 NA
33 Other Paid-in Capital 253
34 Discount on Capital Stock 254 NA
35 Capital Stock Expense 254
36 Long-Term Debit 256-257
FERC FORM NO.1 (ED.12-96)Page 2
Name of Respondent This R ort Is:Date of Report Year of Report(1)An Original (Mo,Da,Yr)2001PacifiCorpDec.31,(2)A Resubmission //
LIST OF SCHEDULES (Electric Utility)(continued)
Enter in column (c)the terms "none,""not applicable,"or "NA,"as appropriate,where no inforrhation 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)
37 Reconciliation of Reported Net Incomewith 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 Taxes-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 Commission Expenses 350-351
57 Research,Development and Demonstration Activities 352-353
58 Distribution of Salaries and Wages 354-355
59 Common Utility Plant and Expenses 356 NA
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 NA
65 Generating Plant Statistics (Small Plants)410-411
66 Transmission Line Statistics 422-423
'ERC FORMNO.1 (ED.12-96)Page 3
Name of Respondent This Re ort Is:Date of Report Year of Report
(1)An Original (Mo,Da,Yr)2001PacifiCorpDec.31,(2)A Resubmission //
LI3T OF SCHEDULES (Electric Utility)(continued)
Enter in column (c)the terms "none,""not applicable,"or "NA,"as appropriate,where no inforrnation or amounts have been reported for
certain pages.Omit pages where the respondents are "none,""not applicable,"or "NA".
Line Title of Schedule Reference Remarks
No.Page No.
(a)(b)(c)
67 Transmission Lines Added During Year 424-425
68 Substations 426-427
69 Electric Distribution Meters and Line Transformers 429
70 Environmental Protection Facilities 430
71 Environmental Protection Expenses 431
72 Footnote Data 450
Stockholders'Reports Check appropriate box:
.Four copies will be submitted
No annual report to stockholders is prepared
FERC FORM NO.1 (ED.12-96)Page 4
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)
(2)[¯]A Resubmission i i Dec.31,2001
GENERAL INFORMATION
1.Providename and title of officer having custody of the general corporate books of account and address of
office where the general corporate books are kept,and address of office where any other corporate books of account
are kept,if different from that where the general corporate books are kept.
Geoffrey O.Huggins,VP &Principal Financial Officer 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 incorporated under a special law,give reference to such law.If not incorporated,state that fact and give the type
of organization and the date organized.
Incorporated on January 9,1989 in the State of Oregon.
3.If at any time during the year the property of respondent was held by a receiver or trustee,give (a)name of
receiver or trustee,(b)date such receiver or trustee took possession,(c)the authority by which the receivership or
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 respondent during the year in each State in which
the respondent operated.
The Company is an electric utility that conducts a retail electric utility
business through Pacific Power and Utah Power and engages in power production
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 financial statements an accountant who is not
the principal accountant for your previous year's certified financial statements?
(1)Yes...Enter the date when such independent accountant was initially engaged:
(2)[X]No
FERC FORM No.1 (ED.12-87)PAGE 101
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)
(2)A Resubmission i i Dec.31,2001
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 Holdings,Inc.
PacifiCorp (100%controlled)
FERC FORM NO.1 (ED.12-96)Page 102
Name of Respondent This R ort Is:Date of Report Year of Report(1)An Original (Mo,Da,Yr)2001PacifiCorpDec.31,(2)A Resubmission //
CORPORATIONS CONTROLLED BY RESPONDENT
1.Report below the names of all corporations,business trusts,and similar organizations,controlled directly or indirectly by respondent
at any time during the year.If control ceased prior to end of year,give particulars (details)in a footnote.
2.If control was by other means than a direct holding of voting rights,state in a footnote the manner in which control was held,naming
any intermediaries involved.
3.If control was held jointly with one or more other interests,state the fact in a footnote and name the other interests.
Definitions
1.See the Uniform System of Accounts for a definition of control.
2.Direct control is that which is exercised without interposition of an intermediary.
3.Indirect control is that which is exercised by the interposition of an intermediary which exercises direct control.
4.Joint control is that in which neither interest can effectively control or direct action without the consent of the other,as where the
voting control is equally divided between two holders,or each party holds a veto power over the other.Joint control may exist by
mutual agreement or understanding between two or more parties who together have control within the meaning of the definition of
control in the Uniform System of Accounts,regardless of the relative voting rights of each party.
Line Name of Company Controlled Kind of Business Percent Voting Footnote
No.Stock Owned Ref.
(a)(b)(c)(d)
1 Centralia MiningCompany Mining 100
2 Energy West Mining Company Mining 100
3 Glenrock Coal Company Mining 100
4 Interwest Mining Company Mining 100
5 Pacific Minerals,Inc.Mining 100
6 Bridger Coal Company Mining 66.66
7 PacifiCorp EnvironmentalRemediation Co Environmental Services 100
8 PacifiCorp Future Generations,Inc.Rain Forest Carbon Credits 100
9 PacifiCorp Group Holdings Company Holding Company 100
10 PacifiCorp Financial Services,Inc.Financial Services 100
11 PacifiCorp Intemational Group Holdings Co Int'l Holding Company 100
12 PacifiCorp Investment Management,Inc Management Services for PERC 100
13 PacifiCorp Power Marketing,Inc.Wholesale Power Marketing 100
14 Pacific Klamath Energy,Inc.Klamath Falls Co-Gen Project 100
15
16
17
18
19
20
21
22
23
24
25
26
27
FERC FORM NO.1 (ED.12-96)Page 103
Name of Respondent This Re ort is:Date of Report Year of Report(1)An Original (Mo,Da,Yr)2001PacifiCorpDec.31,(2)A Resubmission //
OFFICERS
1.Report below the name,title and salary for each executive officer whose salary is $50,000 or more.An "executive officer"of a
respcndent 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
incurnbent,and the date the change in incumbency was made.
Line Title Name of Ôfficer ŠalaryforYearNo(a)(b)(c)
1
2 President and Chief Executive Officer Alan V.Richardson 348,800
3
4 Senior Vice President Terry F.Hudgens 433,668
5
6 Executive Vice President Andrew N.MacRitchie 187,996
7
8 Executive Vice President William D.Landels 266,426
9
10 President and Chief Executive Officer Judith A.Johansen 339,182
11
12 Senior Vice President Michael J.Pittman 395,368
13
14 Vice President Emest E.Wessman 161,681
15
16 Vice President Anne E.Eakin 151,935
17
18 Senior Vice President Donald N.Furman 267,284
19
20 Senior Vice President Timothy E.Meier 343,366
21
22 Senior Vice President A.Richard Walje 364,192
23
24 Controller Robert R.Dalley 271,833
25
26 Vice President Craig N.Longfield 282,113
27
28 Vice President Barry G.Cunningham 272,719
29
30 Vice President C.Alex Miller 342,423
31
32 Senior Vice President and Chief Financial Officer Karen K.Clark 505,427
33
34 Treasurer Bruce N.Williams 173,079
35
36 Vice President RobertA.Moir 145,303
37
38 Senior Vice President Matthew R.Wright 90,189
39
40 Senior Vice President Andrew P.Haller 439,855
41
42 Senior Vice President RobertA.Klein 214,028
43
44 VP &Principal Financial Officer Geoffrey O.Huggins 173,892
I
FERC FORM NO.1 (ED.12-96)Page 104
Name of Respondent This R ort Is:Date of Report Year of Report(1)An Original (Mo,Da,Yr)2001PacifiCorpDec.31,(2)A Resubmission //
OFFICERS
1.Raport below the name,title and salary for each executive officer whose salary is $50,000 or more.An "executive officer"of a
respc ndent includes its president,secretary,treasurer,and vice president in charge of a principal business unit,division or function
(suct 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 Title Name of Öfticer ŠalaryforYearNo(a)(b)(c)
1
2 Vice President Donald D.Larson 134,216
3
4 Vice President Stan Watters 415,095
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.12-96)Page 104.1
NameofRespondent This Repod Is:DateofRepod YearofRepod
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001
(2)A Resubmission //
DIRECTORS
1.Re port 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 of the directors who are offiœrs 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.
Liñe Name (and Ïitle)of Director Principal Ausiness AddressNo-(a)(b)
1 PacifiCogaBoandofDiredoni
2
3 "Sir Ian Robinson (Director &Chairman)1 Atlantic Quay
4 Gilasgow,Scotland Gi28SP UK
5
6 Keith R.McKennon 1540 SW Vista Ave #3000
7 Portland,CIR 97201
8
9
10 ***Alan V Richardson (Director &Chairman)825 NE Multnomah
11 Podland,Oregon 97232
12
13 Nolan E.Karras 4695 South 1900 West #3
14 Roy,Utah 84067
15
16 ***William D.Landels (Executive Vice President)201 South Main,Ste 2300
17 SaltLakeCig,UT 84140
18
19 ***lan M.Russell 1 Atlantic Quay
20 Glasgow,Scotland Gi28SP UK
21
22 *"Kenneth L.Vowles 1 Atlantic Quay
23 Gilasgow,Scotland Gi28SP UK
24
25 RobertG.Adiller 0305 SVVhnontgonleer#F508
26 Podland,Oregon 97201
27
28 ***Karen K.Clark (Senior V.P.and CFO)825 NE Multnomah
29 Podland,Oregon 97232
30
31 ***Andrew N.MacRitchie (Executive Vice President)825 NE Multnomah
32 Portland,Oregon 97232
33
34 ***Timothy E.Meier (Senior Vice President)825 NE Multnomah
35 Portland,Dregon 97232
36
37 *"Michael J.Pittman (Senior Vice President)825 NE Multnomah
38 Podland,Oregon 97232
39
40 ***Terry F.Hudgens (Senior Vice President)825 NE Multnomah
41 Podland,Oregon 97232
42
43 ***Judith A.Johansen (President &CEO)825 NE Multnomah
44 Portland,Dregon 97232
45
46 Matthew R.Wright (Executive Vice President)825 NE Multnomah
47 Portland,Oregon 97232
48
FERC FORM NO.1 (ED.12-95)Page 105
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001
(2)A Resubmission //
DIRECTORS
1.Re port 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 of the directors who are officers of the respondent.
2.De signate members of the Executive Committee by a triple asterisk and the Chairman of the Executive Committeeby a double asterisk.
LAG Name (and Ïitle)of Director Principal Business AddressNo-(a)(b)
1 A.Richard Walje (Senior Vice President)825 NE Multnomah
2 Portland,Oregon 97232
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
45
46
47
48
FERC FORM NO.1 (ED.12-95)Page 105.1
Name of Respondent This Report Is:Date of Report Year of Report(1)An Original (Mo,Da,Yr)PacifiCorp (2)A Resubmission //Dec.31,2001
SECURITY HOLDERS AND VOTING POWERS
1.Give the names and addresses of the 10 security holders of the respondent who,at the date of the latest closing of the stock book or compilation of
list of stockholders of the respondent,prior to the end of the year had the highest voting powers in the respondent,and state the number of votes which
each would have had the right to cast on that date if a meeting were then in order.If any such holder held in trust,give in a footnote the known
particulars of the trust(whether voting trust,etc.)duration of trust,and principal holders of beneficiary interests in the trust.If the stock book was not
closed or a list of stockholders was not compiled within one year prior to the end of the year,or if since the previous compilation of a List of stockholders,
some other class of security has become vested with voting rights,then show such 10 security holders as of the close of the year.Arrange the names
of the security holders in the order of voting power,commencing with the highest.Show in column (a)the titles of officers and directors included in such
list of 10 security holders.
2.If any security other than stock carries voting rights,explain in a footnote the circumstances whereby such security became vested with voting rights
give other important particulars (details)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.Furnish 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 meeting
of such closing:for election of directors of the respondent and NoneNonenumberofsuchvotescastbyproxy
Total:
By Proxy:
VOTING SECURITIESLineName(Title)and Address of Security
No.Number of Votes as of (date):03/19/2002
Holder Total Common 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 pic 297,324,604 297,324,604
9 1 Atlantic Quay
10 Glasgow,Scotland G2 8SP UK
11
12 Cedefast 2,080,645
13
14 Atomic Investments 2,000
15
16 John &Lois Hunting 2,000
17
18 Robert F.Hallwyler 1,411
FERC FORM NO.1 (ED.12-96)Page 106
Name of Respondent This Report Is:Date of Report Year of Report(1)An Original (Mo,Da,Yr)PacifiCo (2)A Resubmission //Dec.31,2001
SECURITY HOLDERSAND VOTING PCWERS (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
21
22 Thelma Vernice Wolff Trustee
23 FBO Thelma V.Wolff Living Trust 816
24
25 ElmerM.&Lillian E.Schuff 681
26
27 Agatha D.Nemish 678
28
29 ElmerM.Black &Helen L.Black TR UIA 629
30
31 Dale Kris &Neil Hansen Partnership 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 This Report Is:Date of Report Year of Report
PacifiCorp (1)p An Original Dec.31,2001
(2)A Resubmission
IM >ORTANTCHANGES DURING THE YEAR
Give particulars (details)concerning the matters indicated below.Make the statements explicit and precise,and number them in
accordance with the inquiries.Each inquiry should be answered.Enter "none,""not applicable,"or "NA"where applicable.If
information which answers an inquiry is givenelsewhere in the report,make a reference to the schedule in which it appears.
1.Changes in and important additions to franchise rights:Describe the actual consideration given therefore and state from whom the
franchise rights were acquired.If acquired without the payment of consideration,state that fact.
2.Acquisition of ownership in other companies by reorganization,merger,or consolidation with other companies:Give names of
companies involved,particulars concerning the transactions,name of the Commission authorizing the transaction,and reference to
Commission authorization.
3.Purchase or sale of an operating unit or system:Give a brief description of the property,and of the transactions relating thereto,
and reference to Commission authorization,if any was required.Give date 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 fumish 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
NarneofRespondent ThisRepodis:DateofRepod YearofRepod
(1)X_An Original (Mo,Da,Yr)
PacifiCorp (2)_A Resubmission //Dec 31,2001
IMPORTANT CHANGES DURING THE YEAR (Continued)
1.The following PacifiCorp franchise agreements were renewed or newly adopted in 2001
Renewal Date Expiration Date Fee %
California
None
Idaho
None
Oregon
Brownsville 2001 06 04 2021 06 04 5.0%Franchise
Stayton 2001 09 05 2011 10 04 4.0%Franchise
Warrenton 2001 10 03 2011 10 03 5.0%Franchise
Opener 2006
Seaside 2001 11 13 2021 11 13 3.5%Franchise
Umatilla 2001 12 04 2021 12 04 3.5 %Franchise
Utah
Holladay 2001 03 15 2011 03 15
Perry 2001 04 26 2026 03 10 2.0%MST
Pleasant View 2001 05 22 2026 04 27 6.0%MST
Washington
Grandview 2001 01 16 2021 01 16 3.0%Franchise
6.0%License
Dayton 2001 01 23 2011 01 23 3.0%License
3.0%Franchise
Naches 2001 05 14 2021 05 14 3.0%Franchise
3.0%License
Franklin County 2001 05 21 2026 05 21
wyoming
Laramie 2001 12 02 2026 12 02 2.0%Franchise
5 year openers
2.None
3.PacifiCorp's Hermiston facilities were transferred to the City of Hermiston October 1,
2001.The transfer comprised about 1,700 poles that were part of the city limits as they
existed on June 23,1999,but no facilities,equipment or personnel.The purchase price
for these assets was $8,064,879.00 and was approved by the Public Utility Commission of
Oregon UP 187 on September 26,2001.
4.None
5.None
6.On November 15,2001 PacifiCorp issued $800,000,000 in Bonds.See page 256 lines 9
and 17 for descriptions of the bonds.See footnote page 450 (page 256.6,line 20,column:
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 31,2001
IMPORTANT CHANGES DURINGTHE YEAR (Continued)
a)for commission authorization.
7.None
8.During 2001,wage increases went into effect with the International Brotherhood of
Electric Workers,Local 57,and Local 415 of 4.0%,Local 659,and Local 125 of 3.0%.Wage
increases went into effect with the Utility Workers Union of America,Local 127 of 4.0%,
and Local 197 of 3.0%.
9.PacifiCorp and its subsidiaries are parties to various legal claims,actions andcomplaints,certain of which involve material amounts.Although PacifiCorp is unable topredictwithcertaintywhetherornotitwillultimatelybesuccessfulintheseproceedingsor,if not,what the impact might be,management currently believes thatdispositionofthesematterswillnothaveamateriallyadverseeffectonPacifiCorp's
consolidated financial statements.
At December 31,2001,PacifiCorp had deferred power costs pursuant to orders received from
Idaho,Oregon,Utah,and Wyoming.While PacifiCorp is pursuing full recovery of these
costs,there can be no assurance that this will be achieved.Denial of recovery will
result in the write-off of deferred power costs reported under "Other Regulatory Assets"
on the balance sheet.
10.None
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)An Original (Mo,Da,Yr)
(2)A Resubmission //Dec.31,2001
COMPARATIVE BALANCE SHEET (ASSETS AND OTHEF 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 12,049,689,943 12,424,027,867
3 Construction Work in Progress (107)200-201 265,681,606 298,201,330
4 TOTAL Utility Plant (Enter Total of lines 2 and 3)12,315,371,549 12,722,229,197
5 (Less)Accum.Prov.for Depr.Amort.Depl.(108,111,115)200-201 4,674,742,315 4,914,429,624
6 Net Utility Plant (Enter Total of line 4 less 5)7,640,629,234 7,807,799,573
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)O O
10 Net Utility Plant (Enter Total of lines 6 and 9)7,640,629,234 7,807,799,573
11 Utility PlantAdjustments (116)122 0 0
12 Gas Stored Underground -Noncurrent (117)O 0
13 OTHER PROPERTY AND INVESTMENTS
14 Nonutility Property (121)221 12,815,250 12,359,971
15 (Less)Accum.Prov.for Depr.and Amort.(122)5,478,431 5,396,681
16 Investments in Associated Companies (123)7,395,158 10,120,424
17 Investment in Subsidiary Companies (123.1)224-225 575,253,560 702,714,155
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)88,674,526 82,898,390
21 Special Funds (125-128)2,566,973 2,711,862
22 TOTAL Other Property and Investments (Total of lines 14-17,19-21)681,227,036 805,408,121
23 CURRENT AND ACCRUED ASSETS
24 Cash (131)-12,444,561 -5,868,233
25 Special Deposits (132-134)-6,885,091 29,133,500
26 Working Fund (135)-1,747,749 -189,632
27 Temporary Cash Investments (136)55,417,301 125,131,751
28 Notes Receivable (141)452,523 386,294
29 Customer Accounts Receivable (142)553,622,283 266,619,450
30 Other Accounts Receivable (143)21,139,851 10,304,928
31 (Less)Accum.Prov.for Uncollectible Acct.-Credit (144)14,568,873 18,577,699
32 Notes Receivable from Associated Companies (145)130,282 838,304
33 Accounts Receivable from Assoc.Companies (146)59,952,512 3,507,413
34 Fuel Stock (151)227 53,541,066 62,176,475
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 93,359,223 88,828,440
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 O
43 Stores Expense Undistributed (163)227 0 0
44 Gas Stored Underground -Current (164.1)O O
45 Liquefied Natural Gas Stored and Held for Processing (164.2-164.3)0 0
46 Prepayments (165)21,596,134 21,521,357
47 Advances for Gas (166-167)0 0
48 Interest and Dividends Receivable (171)254,323 332,821
49 Rents Receivable (172)55,623 81,805
50 Accrued Utility Revenues (173)145,087,713 146,572,000
51 Miscellaneous Current and Accrued Assets (174)-82,577 -219,058
52 TOTAL Current and Accrued Assets (Enter Total of lines 24 thru 51)968,879,983 730,579,916
FERC FORM NO.1 (ED.12-94)Page 110
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)
(2)A Resubmission //Dec.31,2001
COMPARATIVE BALANCE SHEET (ASSETE AND OTHEF DEBITSJcontinued)
Ref.Balance at Balance atLineTitleofAccountPageNo.Beginning of Year End of YearNo.(a)(b)(c)(d)
53 DEFERRED DEBITS MM
54 Unamortized Debt Expenses (181)37,197,114 39,680,151
55 Extraordinary Property Losses (182.1)230 0 -0
56 Unrecovered Plant and Regulatory Study Costs (182.2)230 19,175,216 17,273,539
57 Other Regulatory Assets (182.3)232 887,390,222 1,363,246,472
58 Prelim.Survey and Investigation Charges (Electric)(183)768,817 666,122
59 Prelim.Sur.and Invest.Charges (Gas)(183.1,183.2)O 0
60 Clearing Accounts (184)186,516 161,909
61 Temporary Facilities (185)84,520 140,786
62 Misœllaneous Deferred Debits (186)233 91,322,557 100,497,507
63 Def.Losses from Disposition of Utility Pit.(187)0 0
64 Research,Devel.and Demonstration Expend.(188)352-353 0 0
65 Unamortized Loss on Reaquired Debt (189)46,560,934 41,098,577
66 Accumulated Deferred Income Taxes (190)234 218,331,387 66,588,096
67 Unrecovered Purchased Gas Costs (191)0 0
68 TOTAL Deferred Debits (Enter Total of lines 54 thru 67)1,301,017,283 1,629,353,159
69 TOTAL Assets and Other Debits (Enter Total of lines 10,11,12,22,52,68)10,591,753,536 10,973,140,769
FERC FORM NO.1 (ED.12-94)Page 111
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)
(2)A Resubmission //Dec.31,2001
COMPARATIVE BALANCE SHEET (LIABILITIESAND OTHER CREDITS)
Ref.Balance at Balance atLineTitleofAccount
No.(a)Page No.Beginning of Year End of Year
(b)(c)(d)
1 PROPRIETARY CAPITAL
2 Common Stock Issued (201)250-251 3,350,185,742 3,350,188,743
3 Preferred Stock Issued (204)250-251 216,463,300 116,463,300
4 Capital Stock Subscribed (202,205)252 0 0
5 Stock Liability for Conversion (203,206)252 0 0
6 Premium on Capital Stock (207)252 0 0
7 Other Paid-In Capital (208-211)253 0 45,637,600
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 43,799,002 42,121,516
11 Retained Eamings (215,215.1,216)118-119 908,060,106 811,336,300
12 Unappropriated Undistributed Subsidiary Eamings (216.1)118-119 -807,521,350 -668,931,851
13 (Less)Reaguired Capital Stock (217)250-251 0 0
14 TOTAL Proprietary Capital (Enter Total of lines 2 thru 13)3,623,388,796 3,612,572,576
15 LONG-TERM DEBT
16 Bonds (221)256-257 3,008,197,120 3,672,744,531
17 (Less)Reaquired Bonds (222)256-257 0 0
18 Advances from Associated Companies (223)256-257 379,054,473 362,888,000
19 Other Long-Term Debt (224)256-257 0 0
20 Unamortized Premium on Long-Term Debt (225)60,026 57,309
21 (Less)Unamortized Discount on Long-Term Debt-Debit (226)2,996,143 5,190,056
22 TOTAL Long-Term Debt (Enter Total of lines 16 thru 21)3,384,315,476 4,030,499,784
23 OTHER NONCURRENT LIABILITIES
24 Obligations Under Capital Leases -Noncurrent (227)27,273,739 27,345,575
25 Accumulated Provision for Property Insurance (228.1)10,891,473 8,616,567
26 Accumulated Provision for Injuries and Damages (228.2)73,975,588 68,641,977
27 Accumulated Provision for Pensions and Benefits (228.3)177,480,459 144,852,758
28 Accumulated Miscellaneous Operating Provisions (228.4)12,923,148 8,937,116
29 Accumulated Provision for Rate Refunds (229)0 0
30 TOTAL OTHER Noncurrent Liabilities (Enter Total of lines 24 thru 29)302,544,407 258,393,993
31 CURRENT AND ACCRUED LIABILITIES
32 Notes Payable (231)263,259,772 75,610,980
33 Accounts Payable (232)659,652,623 293,641,911
34 Notes Payable to Associated Companies (233)71,353,702 12,183,607
35 Accounts Payable to Associated Companies (234)16,060,693 39,669,357
36 Customer Deposits (235)6,940,774 9,585,148
37 Taxes Accrued (236)262-263 139,540,035 10,725,128
38 Interest Accrued (237)76,678À88 78,967,913
39 Dividends Declared (238)84,443,774 220,645,376
40 Matured Long-Term Debt (239)0 0
41 Matured Interest (240)0 0
42 Tax Collections Payable (241)10,829,906 10,133,470
43 Miscellaneous Current and Accrued Liabilities (242)85,738,612 100,188,693
44 Obligations Under Capital Leases-Current (243)-65,374 -71,835
45 TOTAL Current &Accrued Liabilities (Enter Total of lines 32 thru 44)1,414,433,005 851,279,748
FERC FORM NO.1 (ED.12-89)Page 112
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)
(2)A Resubrnission //Dec.31,2001
COMPARATIVE BALANCE SHEET (LIABILITIES AND OTHER CREDITS)(Continued)
Ref.Balanœ at Balance atLineTitleofAccount
No.(a)Page No.Beginning of Year End of Year
(b)(c)(d)
46 DEFERRED CREDITS
47 Customer Advances for Construction (252)14,639,806 12,298,129
48 Accumulated Deferred Investment Tax Credits (255)266-267 109,226,949 101,288,543
49 Deferred Gains from Disposition of Utility Plant (256)O O
50 Other Deferred Credits (253)269 117,912,368 343,559,666
51 Other Regulatory Liabilities (254)278 72,847,601 229,812,545
52 Unamortized Gain on Reaquired Debt (257)814,643 557,597
53 Accumulated Deferred Income Taxes (281-283)272-277 1,551,630,485 1,532,878,188
54 TOTAL Deferred Credits (EnterTotal of lines 47 thru 53)1,867,071,852 2,220,394,668
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)10,591,753,536 10,973,140,769
FERC FORM NO.1 (ED.12-89)Page 113
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
STATEMENT OF INCOME FOR THE YEAR
1.Report amounts for accounts 412 and 413,Revenue and Expenses from Utility Plant Leased to Others,in another Utility column (i,
k,m,o)in a similar manner to a utility department.Spread the amount(s)over Lines 02 thru 24 as appropriate.Include these amounts
in columns (c)and (d)totals.
2.Report amounts in account 414,Other Utility Operating income,in the same manner as accounts 412 and 413 above.
3.Report data for lines 7,9,and 10 for Natural Gas companies using accounts 404.1,404.2,404.3,407.1 and 407.2.
4.Use pages 122-123 for important notes regarding the statement of income or any account thereof.
5.Give concise explanations concerning unsettled rate proceedings where a contingency exists such that refunds of a material amount
may need to be made to the utility's customers or which may result in a material refund to the utility with respect to power or gas
purchases.State for each year affected the gross revenues or costs to which the contingency relates and the tax effects together with
an explanation of the major factors which affect the rights of the utility to retain such revenues or recover amounts paid with respect to
power and gas purchases.
6.Give concise explanations concerning significant amounts of any refunds made or received during the year
Line Account (Ref.)TOTAL
No.Page No.Current Year Previous Year
(a)(b)(c)(d)
1 UTILITY OPERATING INCOME
2 Operating Revenues (400)300-301 4,570,082,969 4,108,770,698
3 Operating Expenses
4 Operation Expenses (401)320-323 3,289,108,892 2,972,684,389
5 Maintenance Expenses (402)320-323 213,546,538 163,203,337
6 Depreciation Expense (403)336-337 349,992,527 338,754,599
7 Amort.&Depl.of Utility Plant (404-405)336-337 44,067,420 40,386,582
8 Amort.of Utility PlantAcq.Adj.(406)336-337 5,571,724 5,857,361
9 Amort.Property Losses,Unrecov Plant and Regulatory Study Costs (407)
10 Amort.of Conversion Expenses (407)
11 Regulatory Debits (407.3)102,268 1,951,714
12 (Less)Regulatory Credits (407.4)1,353,351
13 Taxes Other Than IncomeTaxes (408.1)262-263 128,380,502 121,451,546
14 Income Taxes -Federal (409.1)262-263 -83,954,282 140,505,147
15 -Other (409.1)262-263 -2,905,000 13,631,972
16 Provision for Deferred IncomeTaxes (410.1)234,272-277 376,245,053 227,108,183
17 (Less)Provision for Deferred Income Taxes-Cr.(411.1)234,272-277 158,220,693 274,140,674
18 Investment Tax Credit Adj.-Net (411.4)266 -5,873,148 -5,934,108
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)3,634,620 10,598,784
22 Losses from Disposition of Allowances (411.9)
23 TOTAL Utility Operating Expenses (Enter Total of lines 4 thru 22)4,151,073,830 3,734,861,264
24 Net Util Oper Inc (Enter Tot line 2 less 23)Carry fwd to P117,line 25 419,009,139 373,909,434
FERC FORM NO.1 (ED.12-96)Page 114
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
STATEMENT OF INCOME FOR THE YEAR (Continued)
resulting from settlement of any rate proceeding affecting revenues received or costs incurred for power or gas purchases,and 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
NoCurrentYearPreviousYearCurrentYearPreviousYearCurrentYearPreviousYear
(e)(f)(g)(h)(i)(j)
4,570,082,969 4,108,770,698 2
3
3,289,108,892 2,972,684,389 4
213,546,538 163,203,337 5
349,992,527 338,754,599 6
44,067,420 40,386,582 7
5,571,724 5,857,361 8
9
10
102,268 1,951,714 11
1,353,351 12
128,380,502 121,451,546 13
-83,954,282 140,505,147 14
-2,905,000 13,631,972 15
376,245,053 227,108,183 16
158,220,693 274,140,674 17
-5,873,148 -5,934,108 18
19
20
3,634,620 10,598,784 21
22
4,151,073,830 3,734,861,264 23
419,009,139 373,909,434 24
FERC FORM NO.1 (ED.12-96)Page 115
Name of Respondent This R ort Is:Date of Report Year of Report(1)An Original (Mo,Da,Yr)PacifiCorp Dec.31 2001(2)A Resubmission //'
STATEMENT OF INCOME FOR THE YEAR (Continued)
Line OTHER UTILITY OTHER UTILITY OTHER UTILITY
No Current Year Previous Year Current Year Previous Year Current 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 of Respondent This Report Is:Date of Report Year of Report
(1)An Original (Mo,Da,Yr)PacifiCorp (2)A Resubmission //Dec.31,2001
3TATEMENT OF INCOME FOR THE YEAR (Continued)
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)419,009,139 373,909,434
26 Other Income and Deductions
27 Other Income
28 Nonutilty Operating Income
29 Revenues From Merchandising,Jobbing and Contract Work (415)6,380,613 9,654,080
30 (Less)Costs and Exp.of Merchandising,Job.&Contract Work (416)2,212,321 2,772,899
31 Revenues From Nonutility Operations (417)1,520,753 21,998,518
32 (Less)Expenses of Nonutility Operations (417.1)39,556 18,815,598
33 Nonoperating Rental Income (418)-210,212 602,132
34 Equity in Earnings of Subsidiary Companies (418.1)119 138,589,499 -145,756,923
35 Interest and Dividend Income (419)4,023,249 9,666,462
36 Allowance for Other Funds Used During Construction (419.1)4,356,322
37 Miscellaneous Nonoperating Income (421)1,835,555 4,900,162
38 Gain on Disposition of Property (421.1)6,717,249 1,947,186
39 TOTAL Other Income (Enter Total of lines 29 thru 38)156,604,829 -114,220,558
40 Other Income Deductions
41 Loss on Disposition of Property (421.2)-968,266 14,076,787
42 Miscellaneous Amortization (425)340 21,769 44,068
43 Miscellaneous income Deductions (426.1-426.5)340 1,646,166 -29,267,090
44 TOTAL Other Income Deductions (Total of lines 41 thru 43)699,669 -15,146,235
45 Taxes Applic.to Other Income and Deductions
46 Taxes Other Than Income Taxes (408.2)262-263 196,289 160,500
47 Income Taxes-Federal (409.2)262-263 4,993,000
48 Income Taxes-Other (409.2)262-263 -415,000 663,000
49 Provision for Deferred Inc.Taxes (410.2)234,272-277 39,560 131,024
50 (Less)Provision for Deferred Income Taxes-Cr.(411.2)234,272-277 1,081,394 2,506,502
51 Investment Tax Credit Adj.-Net (411.5)-2,065,258 -2,065,260
52 (Less)Investment Tax Credits (420)
53 TOTAL Taxes on Other Income and Deduct.(Total of 46 thru 52)-3,325,803 1,375,762
54 Net Other Income and Deductions (Enter Total lines 39,44,53)159,230,963 -100,450,085
55 Interest Charges
56 Interest on Long-Term Debt (427)186,225,383 212,636,944
57 Amort.of Debt Disc.and Expense (428)4,143,306 4,369,274
58 Amortization of Loss on Reaquired Debt (428.1)5,462,357 6,219,217
59 (Less)Amort.of Premium on Debt-Credit (429)2,718 498,151
60 (Less)Amortization of Gain on Reaguired Debt-Credit (429.1)257,046 337,388
61 Interest on Debt to Assoc.Companies (430)340 36,433,069 41,136,700
62 Other Interest Expense (431)340 25,144,331 24,239,520
63 (Less)Allowance for Borrowed Funds Used During Construction-Cr.(432)7,541,450 9,209,549
64 Net Interest Charges (Enter Total of lines 56 thru 63)249,607,232 278,556,567
65 Income Before Extraordinary ltems (Total of lines 25,54 and 64)328,632,870 -5,097,218
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 IncomeTaxes-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)328,632,870 -5,097,218
FERC FORM NO.1 (ED.12-96)Page 117
Name of Respondent This Re ort Is:Date of Report Year of Report
(1)An Original (Mo,Da,Yr)2001PacifiCorpDec.31,(2)A Resubmission //
STA EMENT OF RETAINED EARNINGS FOR THE 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 eamings 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 eamings.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 eventuallyto be accumulated.
8.If any notes appearing in the report to stockholders are applicable to this statement,include them on pages 122-123.
Line contra Þnmary Amount
No.Item Account Affected(a)(b)(c)
UNAPPROPRIATED RETAINED EARNINGS (Account 216)
1 Balance-Beginning of Year 904,484,296
2 Changes
3 Adjustments to Retained Earnings (Account 439)
4
5
6
7
8
9 TOTAL Credits to Retained Eamings (Acct.439)
10 214 -1,677,486
11
12
13
14
15 TOTAL Debits to Retained Earnings (Acct.439)-1,677,486
16 Balance Transferred from Income (Account 433 less Account 418.1)77,245,256
17 Appropriations of Retained Earnings (Acct.436)
18
19
20
21
22 TOTAL Appropriations of Retained Earnings (Acct.436)
23 Dividends Declared-Preferred Stock (Account 437)
24 Various series and rates 238 -11,736,290
25
26
27
28
29 TOTAL Dividends Declared-Preferred Stock (Acct.437)-11,736,290
30 Dividends Declared-Common Stock (Account 438)
31 Common stock 238 -160,555,286
32
33
34
35
36 TOTAL Dividends Declared-Common Stock (Acct.438)-160,555,286
37 Transfers from Acct 216.1,Unapprop.Undistrib.Subsidiary Earnings
38 Balance -End of Year (Total 1,9,15,16,22,29,36,37)807,760,490
FERC FORM NO.1 (ED.12-96)Page 118
Name of Respondent This Re ort Is:Date of Report Year of Report(1)An Original (Mo,Da,Yr)2001PacifiCorpDec.31,(2)A Resubmission //
STA EMENT OF RETAINED EARNINGS FOR THE YEAR
I
1.Report all changes in appropriated retained earnings,unappropriated retained earnings,and unappropriated undistributed i
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 Eamings,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 resented 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.
Lme contra Pnmary Amount
No.Item Account Affected(a)(b)(c)
APPROPRIATED RETAINED EARNINGS (Account 215)
39
40
41
42
43
44
45 TOTALAppropriated Retained Earnings (Account 215)
APPROP.RETAINED EARNINGS -AMORT.Reserve,Federal (Account 215.1)
46 TOTALApprop.Retained Earnings-Amort.Reserve,Federal (Acct.215.1)3,575,810
47 TOTALApprop.Retained Earnings (Acct.215,215.1)(Total 45,46)3,575,810
48 TOTAL Retained Earnings (Account 215,215.1,216)(Total 38,47)811,336,300
UNAPPROPRIATEDUNDISTRIBUTED SUBSIDIARY EARNINGS (Account 216.1)ggy
49 Balance-Beginningof Year (Debit or Credit)-807,521,350
50 Equity in Earnings for Year (Credit)(Account 418.1)138,589,499
51 (Less)Dividends Received (Debit)
52
53 Balance-End of Year (Total lines 49 thru 52)-668,931,851
FERC FORM NO.1 (ED.12-96)Page 119
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001
(2)A Resubmission //
STATEMENT OF CASH FLOWS
1.If the notes to the cash flow statement in the respondents annual stockholders report are applicable to this statement,such notes should be included
in page 122-123.Information about non-cash investing and financing activities should be provided on Page 122-123.Provide also on pages 122-123 a
reconciliation between "Cash and Cash Equivalents at End of Year"with related amounts on the balance sheet.
2.Under "Other"specify significant amounts and group others.
3.Operating Activities -Other:Include gains and losses pertaining to operating activities only.Gains and losses pertaining to investing and financing
activities should be reported in those activities.Show on Page 122-123 the amount of interest paid (net of amounts capitalized)and income taxes paid.
Line Llescnption (See Instruction No.6 tor Explanation ot codes)Amounts
No.(a)(b)
1 Net Cash Flow from Operating Activities:
2 Net Income 215,834,755
3 Noncash Charges (Credits)to income:
4 Depreciation and Depletion 348,907,199
5 Amortization of 48,389,410
6
7
8 Deferred Income Taxes (Net)217,305,966
9 Investment Tax Credit Adjustment (Net)-7,938,406
10 Net (Increase)Decrease in Receivables 356,205,887
11 Net (Increase)Decrease in Inventory -4,104,626
12 Net (Increase)Decrease in Allowances Inventory
13 Net Increase (Decrease)in Payables and Accrued Expenses -462,953,197
14 Net (Increase)Decrease in Other Regulatory Assets 78,840,279
15 Net Increase (Decrease)in Other Regulatory Liabilities -33,582,104
16 (Less)Allowance for Other Funds Used During Construction
17 (Less)Undistributed Earnings from Subsidiary Companies 117,933,030
18 Other:-425,706,982
19
20
21
22 Net Cash Provided by (Used in)Operating Activities (Total 2 thru 21)213,265,151
23
24 Cash Flows from Investment Activities:
25 Construction and Acquisition of Plant (including land):
26 Gross Additions to Utility Plant (less nuclear fuel)-447,550,792
27 Gross Additions to Nuclear Fuel
28 Gross Additions to Common Utility Plant
29 Gross Additions to Nonutility Plant
30 (Less)Allowance for Other Funds Used During Construction
31 Other:
32
33
34 Cash Outflows for Plant (Total of lines 26 thru 33)-447,550,792
35
36 Acquisition of Other Noncurrent Assets (d)
37 Proceeds from Disposal of Noncurrent Assets (d)11,740,966
38
39 Investments in and Advances to Assoc.and Subsidiary Companies 2,018,284
40 Contributions and Advances from Assoc.and Subsidiary Companies
41 Disposition of Investments in (and Advances to)gj
42 Associated and Subsidiary Companies
43
44 Purchase of Investment Securities (a)
45 Proceeds from Sales of Investment Securities (a)
FERC FORM NO.1 (ED.12-96)Page 120
Name of Respondent This R ort Is:Date of Report Year of Report(1)An Original (Mo,Da,Yr)2001PacifiCorpDec.31,(2)A Resubmission //
STATEMENT OF CASH FLOWS
4.Investing Activities include at Other (line 31)net cash outflow to acquire other companies.Provide a reconciliation of assets acquired with liabilities
assur ned on pages 122-123.Do not include on this statement the dollar amount of Leases capitalized per US of A General Instruction 20;instead
proviele a reconciliation of the dollar amount of Leases capitalized with the plant cost on pages 122-123.
5.Codes used:
(a)Not 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.Et ter on pages 122-123 clarifications and explanations.
Line Description (See Instruction No.6 for Explanation of codes)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 9,550,149
54
55
56 Net Cash Provided by (Used in)Investing Activities
57 Total of lines 34 thru 55)424 241 393
58
59 Cash Flows from Financing Activities:
60 Proceeds from Issuance of:
61 Long-Term Debt (b)791,516,593
62 Preferred Stock
63 Common Stock
64 Other:
65
66 Net Increase in Short-Term Debt (c)
67 Other:66,928,054
68
69
70 Cash Provided by Outside Sources (Total 61 thru 69)858,444,647
71
72 Payments for Retirement of:
73 Long-term Debt (b)-135,697,309
74 Preferred Stock -100,000,000
75 Common Stock
76 Other:-74,164,845
77
78 Net Decrease in Short-Term Debt (c)-187,648,792
79
80 Dividends on Preferred Stock -13,663,834
81 Dividends on Common Stock -22,426,139
82 Net Cash Provided by (Used in)Financing Activities
83 (Total of lines 70 thru 81)324,843,728
84
85 Net Increase (Decrease)in Cash and Cash Equivalents
86 (Total of lines 22,57 and 83)113,867,486
87
88 Cash and Cash Equivalents at Beginning of Year 34,339,900
89
90 Cash and Cash Equivalents at End of Year 148,207,386
FERC FORM NO.1 (ED.12-96)Page 121
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)g An Original Dec.31,2001
(2)A Resubmission
NOTES TO FINANCIAL STATEMENTS
1.Use the space below for important notes regardingthe 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 giventhese 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 fumish the data required by instructions above and on pages 114-121,such notes may be included herein.
PAGE 122 INTENTIONALLY LEFT BLANK
SEE PAGE 123 FOR REQUIRED INFORMATION.
FERC FORM NO.1 (ED.12-96)Page 122
Name of Respondent This Report is:Date of Report Year of Report
(1)X_An Original (Mo,Da,Yr)
PacifiCorp (2)_A Resubmission //Dec 31,2001
NOTES TO FINANCIAL STATEMENTS (Continued)
See Supplemental Filling
FERC FORM NO.1 (ED.12-88)Page 123
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31 2001(2)A Resubmission //
SUMMARY OF UTILITY PLANT AND ACCU VIULATEDPROVISIONS
FOR DEPRECIATION.AMORTIZATION AND DEPLETION
Line Classification Total Electric
No.(a)(b)(c)
1 Utility Plant
2 In Service
3 Plant in Service (Classified)12,289,186,553 12,289,186,553
4 Property Under Capital Leases 27,273,739 27,273,739
5 Plant Purchased or Sold
6 Completed Construction not Classified
7 Experimental PlantUnclassified
8 Total (3 thru 7)12,316,460,292 12,316,460,292
9 Leased to Others
10 Held for Future Use 2,838,111 2,838,111
11 Construction Work in Progress 298,201,330 298,201,330
12 Acquisition Adjustments 104,729,464 104,729,464
13 Total Utility Plant (8 thru 12)12,722,229,197 12,722,229,197
14 Accum Prov for Depr,Amort,&Depl 4,914,429,624 4,914,429,624
15 Net Utility Plant (13 less 14)7,807,799,573 7,807,799,573
16 Detail of Accum Prov for Depr,Amort &Depl
17 In Service:
18 Depreciation 4,691,902,955 4 691,902,955
19 Amort &Depl of Producing Nat Gas Land/Land Right
20 Amort of Underground Storage Land/Land Rights
21 Amort of Other Utility Plant 222,366,313 222,366,313
22 Total In Service (18 thru 21)4,914,269,268 4,914,269,268
23 Leased to Others
24 Depreciation
25 Amortization and Depletion
26 Total Leased to Others (24 &25)
27 Held for Future Use
28 Depreciation 160,356 160,356
29 Amortization
30 Total Held for Future Use (28 &29)160,356 160,356
31 Abandonment of Leases (Natural Gas)
32 Amort of Plant Acquisition Adj
33 Total Accum Prov (equals 14)(22,26,30,31,32)4,914,429,624 4,914,429,624
FERC FORM NO.1 (ED.12-89)Page 200
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
SUMMARY OF UTILITY PLANT AND ACCUMULATED PROVISIONS
FOR DEPRECIATION.AMORTIZATION AND DEPLETION
Gas Other (Specify)Other (Specify)Other (Specify)Common Line
(d)(e)(f)(g)(h)No.
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
FERC FORM NO.1 (ED.12-89)Page 201
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
ELECTRIC PLANT IN SERVICE (Account 10 ,
'02,103 and 106)
1.Report below the original cost of electric plant in service according to the prescribed act ounts.
2.In addition to Account 101,Electric Plant in Service (Classified),this page and the next nclude Account 102,Electric Plant Purchased or Sold;
Account 103,Experimental Electric Plant Unclassified;and Account 106,Completed Construction Not Classified-Electric.
3.Include in column (c)or (d),as appropriate,corrections of additions and retirements for he current or preceding year.
4.Enclose in parentheses credit adjustments of plant accounts to indicate the negative eff3ct of such accounts.
5.Classify Account 106 according to prescribed accounts,on an estimated basis if necessary,and include the entries in column (c).Also to be included
in column (c)are entries for reversals of tentative distributions of prior year reported in colu nn (b).Likewise,if the responder t 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
retire nents,on an estimated basis,with appropriate contra entry to the account for accumt lated depreciation provision.Include also in column (d)
revertals of tentative distributions of prior year of unclassified retirements.Show in a footnate the account distributions of these tentative classifications
in col Jmns (c)and (d),including the reversals of the prior years tentative account distributions of these amounts.Careful observance of the above
Line Account Balance Additions
No.Beginning of Year
(a)(b)(c)
1 1.INTANGIBLE PLANT
2 (301)Organization 26,288,163
3 (302)Franchises and Consents 12,877,636 1,608,948
4 (303)Miscellaneous Intangible Plant 367,860,574 24,861,619
5 TOTAL Intangible Plant (Enter Total of lines 2,3,and 4)407,026,373 26,470,567
6 2.PRODUCTION PLANT
7 A.Steam Production Plant
8 (310)Land and Land Rights 79,945,027 13
9 (311)Structures and Improvements 745,208,300 5,836,210
10 (312)Boiler Plant Equipment 2,346,308,838 54,600,428
11 (313)Engines and Engine-Driven Generators
12 (314)Turbogenerator Units 637,378,975 18,635,003
13 (315)Accessory Electric Equipment 314,187,508 4,313,531
14 (316)Misc.Power Plant Equipment 30,425,736 1,359,148
15 TOTAL Steam Production Plant (Enter Total of lines 8 thru 14)4,153,454,384 84,744,333
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 18,296,724 1,039,931
26 (331)Structures and Improvements 72,423,833 1,382,295
27 (332)Reservoirs,Dams,and Waterways 258,977,933 3,980,334
28 (333)Water Wheels,Turbines,and Generators 72,898,006 2,151,894
29 (334)Accessory Electric Equipment 27,599,085 476,066
30 (335)Misc.Power PLant Equipment 3,635,275 46,963
31 (336)Roads,Railroads,and Bridges 11,247,552 105,125
32 TOTAL Hydraulic Production Plant (Enter Total of lines 25 thru 31)465,078,408 9,182,608
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 80,268,212 756,958
39 (345)Accessory Electric Equipment 9,274,455
FERC FORM NO.1 (ED.12-95)Page 204
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)pAn Original (Mo,Da,Yr)Dec.31,2001
(2)A Resubmission //
ELECTRIC PLANT IN SERVICE (Account 101,102,103 and 106)(Continued)
instructions and the texts of Accounts 101 and 106 will avoid serious omissions of the reported amount of respondent's plant actually in service at end 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 journal entries have been filed with the Commission as required by the Uniform System of Accounts,give also date
of such filing.
Retirements Adjustments Transfers Balanœ at Line
(d)(e)(f)End f Year No.
mis--asumim mummassim mummmmmmmmmars a
26,288,163 2
14,486,584 3
7,243 392,714,950 4
7,243 433,489,697 5
2,267 -17,224 79,925,549 8
390,028 910,630 751,565,112 9
28,707,176 -1,066,126 2,371,135,964 10
11
20,860,265 249,260 635,402,973 12
207,136 22,242 318,316,145 13
18,212 -82,486 31,684,186 14
50,185,084 16,296 4,188,029,929 15
MIR R MNERWEISERWERW RERR MBER 16
17
18
19
20
21
22
23
1,710 -124,572 19,210,373 25
19,686 -95,289 73,691,153 26
87,740 95,289 262,965,816 27
72,818 74,977,082 28
992 -28,708 28,045,451 29
3,682,238 30
13,769 11,338,908 31
196,715 -153,280 473,911,021 32
NWWREMMWREWHEWWWBK MM 24WB¾aWERE 33
842,880 34
11,224,005 35
3,210,083 36
94,719,851 37
-17,981 81,007,189 38
9,274,455 39
FERC FORM NO.1 (ED.12-95)Page 205
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001
(2)A Resubmission //
ELECTRIC PLANT IN SERVICE (Account 101,102,133 and 106)(Continued)
Line Account Balance Additions
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)200,074,270 756,958
42 TOTAL Prod.Plant (Enter Total of lines 15,23,32,and 41)4,818,607,062 94,683,899
43 3.TRANSMISSION PLANT
44 (350)Land and Land Rights 87,223,821 123,770
45 (352)Structures and Improvements 43,529,078 1,056,977
46 (353)Station Equipment 729,543,384 29,846,808
47 (354)Towers and Fixtures 340,962,981 2,578,579
48 (355)Poles and Fixtures 394,284,006 25,405,270
49 (356)Overhead Conductors and Devices 561,625,891 6,834,716
50 (357)Underground Conduit 2,014,642
51 (358)Underground Conductors and Devices 2,316,215
52 (359)Roads and Trails 10,969,314 20,346
53 TOTAL Transmission Plant (Enter Total of lines 44 thru 52)2,172,469,332 65,866,466
54 4.DISTRIBUTION PLANT ggg
55 (360)Land and Land Rights 26,108,957 399,213
56 (361)Structures and Improvements 31,382,319 1,005,855
57 (362)Station Equipment 480,730,124 42,427,518
58 (363)Storage Battery Equipment
59 (364)Poles,Towers,and Fixtures 647,063,890 28,143,534
60 (365)Overhead Conductors and Devices 494,589,236 20,328,655
61 (366)Underground Conduit 203,474,373 7,408,789
62 (367)Underground Conductors and Devices 449,940,231 25,620,545
63 (368)Line Transformers 734,716,869 33,278,978
64 (369)Services 281,060,162 25,791,537
65 (370)Meters 173,313,144 4,622,317
66 (371)Installations on Customer Premises 8,831,870 152,645
67 (372)Leased Property on Customer Premises 49,658
68 (373)Street Lighting and Signal Systems 46,893,110 1,991,443
69 TOTAL Distribution Plant (Enter Total of lines 55 thru 68)3,578,153,943 191,171,029
70 5.GENERAL PLANT
71 (389)Land and Land Rights 14,506,036 106,420
72 (390)Structures and Improvements 194,580,309 3,173,768
73 (391)Office Furniture and Equipment 100,805,832 9,045,335
74 (392)Transportation Equipment 66,642,086 4,417,357
75 (393)Stores Equipment 9,211,918 86,647
76 (394)Tools,Shop and Garage Equipment 43,405,014 1,437,183
77 (395)Laboratory Equipment 31,893,925 579,490
78 (396)Power Operated Equipment 90,173,806 5,313,336
79 (397)Communication Equipment 182,000,056 16,298,066
80 (398)Miscellaneous Equipment 4,812,941 92,934
81 SUBTOTAL (Enter Total of lines 71 thru 80)738,031,923 40,550,536
82 (399)Other Tangible Property 347,692,078 2,493,275
83 TOTAL General Plant (Enter Total of lines 81 and 82)1,085,724,001 43,043,811
84 TOTAL (Accounts 101 and 106)12,061,980,711 421,235,772
85 (102)Electric Plant Purchased (See Instr.8)
86 (Less)(102)Electric Plant Sold (See Instr.8)151,184,605
87 (103)Experimental Plant Unclassified
88 TOTAL Electric Plant in Service (Enter Total of lines 84 thru 87)11,910,796,106 421,235,772
FERC FORM NO.1 (ED.12-95)Page 206
Name of Respondent This Report Is Date of Report Year of Report
PacifiCorp (1)An Oiginal (Mo,Da,Yr)Dec.31,2001(2)A Re,ubmission //
ELECTRIC PLANT IN SERVICE (Account 101,102,103 and 106)(Continued)
Retirements Adjustments Transfers Balance at LineEndofYearNo(d)(e)(f)(g)
534,784 40
-17,981 200,813,247 41
50,381,799 -154,965 4,862,754,197 42
43
33,586 -203,042 87,110,963 44
81,184 281,798 44,786,669 45
4,924,679 -331,919 754,133,594 46
9,529 2,349,979 345,882,010 47
937,240 -1,426,229 417,325,807 48
317,433 -456,749 567,686,425 49
2,014,642 50
2,316,215 51
10,989,660 52
6,303,651 213,838 2,232,245,985 53
54
210,334 -56,405 26,241,431 55
33,913 40,237 32,394,498 56
3,178,493 -885,980 519,093,169 57
58
5,799,320 7,479 669,415,583 59
3,139,902 -7,475 511,770,514 60
584,791 210,298,371 61
1,164,074 474,396,702 62
7,315,727 760,680,120 63
1,217,205 305,634,494 64
4,067,845 173,867,616 65
126,450 231 8,858,296 66
49,658 67
778,381 -231 48,105,941 68
27,616,435 -902,144 3,740,806,393 69
501,940 -28,686 14,081,830 71
2,584,789 -7,139 195,162,149 72
2,113,740 10,607 107,748,034 73
3,531,264 17,514 67,545,693 74
7,967 9,290,598 75
30,055 74,699 44,886,841 76
606 35,298 32,508,107 77
6,882,575 90,379 88,694,946 78
1,520,151 455,574 197,233,545 79
44,208 -42,817 4,818,850 80
17,217,295 605,429 761,970,593 81
92,267,942 2,280 257,919,691 82
109,485,237 2,280 605,429 1,019,890,284 83
193,794,365 2,280 -237,842 12,289,186,556 84
85
151,184,605 86
87
42,609,760 2,280 -237,842 12,289,186,556 88
FERC FORM NO.1 (ED.12-95)Page 207
Name of Respondent This R ort Is:Date of Report Year of Report(1)An Original (Mo,Da,Yr)PacifiCorp Dec.31 2001(2)A Resubmission //
EL :CTRIC PLANT HELD FOR FUTURE USE (Account 105)
1.Report separately each property held for future use at end of the year having an original cost of $250,000 or more.Group other items of property held
for future use.
2.For property having an original cost of $250,000 or more previously used in utility operations,now held for future use,give in column (a),in addition to
other required information,the date that utility use of such property was disc3ntinued,and the date the original cost was transferred to Account 105.
Line Description and Location Date Óriginally Included Ibate Êxpected to be used Balance at
No.Of Prooerty in This Account in Utility Service End of Year
(a)(b)(c)(d)
1 Land and Rights:
2
3 NORTH HORN MOUNTAIN COAL PROPERTIES 010175 932,014
4 SOUTHEAST SUBSTATION 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 2,838,111
FERC FORM NO.1 (ED.12-96)Page 214
\larneofRespondent TTiis Repod Is:DateofRepod YearofRepod
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001
(2)A Resubmission //
CONSTRUGTION WORK IN PROGRESS --ELECTRIC (Account 107)
1.Report below descriptions and balances at end of year of projects in process of construction (107)
2.Show items relating to "research,development,and demonstration"projects last,under a caption Research,Development,and Demonstrating (see
Account 107 of the Uniform System of Accounts)
3.Minor projects (5%of the Balance End of the Year for Account 107 or $100,000,whichever is less)may be grouped.
Line Description of Project Construction work in progress -
No.Eledric(Account107)(a)(b)
1 Intangible:
2 Revenue Requirements Modeling 2,966,184
3 WES-Advanced Risk/Trading Modeling System 6,888,465
4 W/indows 2000 Upgrade 1,394,044
5 IMAPBronze-Incident Mgmt &Analysis 3,139,525
6 IMAPSilver Phase Implementation 1,643,696
7 Lewis River Relicensing 7,091,017
8 Menuin Relicensing 3,151,071
9 Swift Relicensing 2,879,309
10 KlamathRelicensing 3,909,435
11 North Umpqua Relicensing 44,619,385
12 Rogue Relicensiry)1,268,895
13 PowerdaleRelicensing 3,742,811
14 G.race Relicensing 1,372,151
15 Oneida Relicensing 1,792,927
16 Soda Relicensiryg 1,034,334
17 DSIPPrograrn 1,221,103
18
19
20 Production:
21 Merwin Fish Trap Water/Alarms 1,674,719
22 Cholla C:Doling TovverRebuild -UnithW 1,800,671
23 Dave Johnston UO Coal Yard Dust Supression 2,283,479
24 Gadsby Gas Turbine Peakers 29,743,622
25 Herrniston-VVaterReuse Land Applic Phase 2 &3 1,193,490
26 Naughton U2 Turbine L-0 Blades (2 Rows)2,155,101
27
28
29 Transmission:
30 Bend Area Transmission Project 1,835,708
31 Grace-Tenninal138kV Ln 105 Struct Repl 1,703,137
32 Wheelon-American Falls Struct Repl 2000 1,603,940
33 Inst2nd Meridian 500/230kVTransfonTier 3,970,159
34 McFadden-Blackhawk Bld 10.4 Mi L Proj.1,835,104
35 Foote Creek Phase VI Project 2,880,465
36 Terminal-Oquirrh 138kV Line Rebuild 2,016,184
37
38 Distribution:
39 Ivins Sub Convedto69kV &Incr Capacity 2,683,182
40 GatewayProject-SLC 5,403,016
41 Dregon -Replace Substation Transforriers 1,249,063
42 Distribution Continued:
43 TCTTAL 298,201,330
FERC FORM NO.1 (ED.12-87)Page 216
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
CONSTRUCTION WORK IN PROGRESS --ELECTRIC (Account 107)
1.Report below descriptions and balances at end of year of projects in process of construction (107)
2.Show items relating to "research,development,and demonstration"projects last,under a caption Research,Development,and Demonstrating (see
Account 107 of the Uniform System of Accounts)
3.Minor projects (5%of the Balance End of the Year for Account 107 or $100,000,whichever is less)may be grouped.
Line Description of Project Construction work in progress -
No.Electric (Account 107)(a)(b)
1 Network Reliability Initiatives 1,053,553
2 Park City Area 46kV Capacitors 1,467,129
3
4
5 General:
6 CBS Reorganization LCT L7B Remodel 1,296,640
7 West Valley Plant -Interconnection Cost 1,126,884
8 DSM Activities 2,260,198
9 Establish 2 Training Centers 3,726,026
10
11
12 Miscellaneous Projects Each Under 1 Million Dollars 135,125,508
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 TOTAL 298,201,330
FERC FORM NO.1 (ED.12-87)Page 216.1
Name of Respondent This Reoort Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)
(2)A Resubrnission //Dec.31,2001
CONSTRUCTION OVERHEADS -ELECTRIC
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 3italized should be shown as separate items.2.On Page 218 fumish information conceming construction overheads.3.A respondent should not report "none"to the page if no
overhe id 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.Enteron this page engineering,supervision,adminLstrative,and allowancefor funds used during construction,etc.,which are first
assigne d to a blanket work order and then prorated to construction jobs.
Line Description of overhead Total amount charged for the yearNo.(a)(b)
1 Allowance for funds used during construction 7,542,137
2
3 Construction Overheads 35,865,377
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 43,407,514
FERC FORM NO.1 (ED.12-89)Page 217
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
GENERAL D :SCRIPTION OF CONSTRUCTION OVERHEAD PROCEDURE
1.For each construction overhead explain:(a)the nature and extent of work,etc.the overhead charges are intended to cover,(b)the
general procedure for determining the amount capitalized,(c)the method of distribution to construction jobs,(d)whether different rates
are applied to different types of construction,(e)basis of differentiation in rates for different types of construction,and (f)whether the
overhead is directly or indirectly assigned.
2.Show below the computation of allowance for funds used during construction rates,in accordance with the provisions of Electric
Plant instructions 3(17)of the U.S.of A.
3.Where a net-of-tax rate for borrowed funds is used,show the appropriate tax effect adjustment to the computations below in a
manner that clearly indicates the amount of reduction in the gross rate for tax effects.
General Administration:
Represents salaries and expenses of a general administrative nature chargeable 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.
COMPUTATION OF ALLOWANCE FOR FUNDS USED DURING CONSTRUCTION RATES
For line 1(5),column (d)below,enter the rate granted in the last rate proceeding.If such is not available,use the average
rate earned during the preceding three years.
1.Componentsof Formula (Derived from actual book balances and actual cost rates):
Line Title Amount Capitalization Cost Rate
No.Ratio(Percent)Percentage(a)(b)(c)(d)
1 Average Short-Term Debt &S 383,002,410
Computation of Allowance text
2 Short-term Interest s 4.39
3 Long-Term Debt D 3,384,315,476 48.29 d 7.01
4 Preferred Stock P 216,463,300 3.09 p 6.18
5 Common Equity C 3,406,925,496 48.62 c 10.90
6 Total Capitalization 7,390,706,682 100.00 100%
7 Average Construction Work in W 288,052,331
Progress Balance
2.Gross Rate for Borrowed Funds S D S
s (-)+d(-)(1 --)4.39WD+P+C W
3.Rate for Other Funds
[1-][p()+c(C
W D+P+C D+P+C
4.Weighted Average Rate Actually Used for the Year:
a.Rate for Borrowed Funds -4.39
b.Rate for Other Funds -0.00
FERC FORM NO.1 (ED.12-88)Page 218
Name of Respondent This Re ort Is:Date of Report Year of Report(1)An Original (Mo,Da,Yr)PacifiCorp Dec.31,2001(2)A Resubmission //
ACCUMUI.ATED PROVISION FOR DEPRECIATION OF ELECTRIC UTILITY PLANT (Account 108)
1.Explain in a footnote any important adjustments during year.
2.Explain in a footnote any difference between the amount for book cost of plant retired,Line 11,column (c),and that reported for
electric plant in service,pages 204-207,column 9d),excluding retirements of non-depreciable property.
3.The provisions of Account 108 in the Uniform System of accounts require that retirements of depreciable plant be recorded when
such plant is removed from service.If the respondent has a significant amount of plant retired at year end which has not been recorded
and/or classified to the various reserve functional classifications,make preliminary closing entries to tentatively functionalize the book
cost of the plant retired.In addition,include all costs included in retirement work in progress at year end in the appropriate functional
classifications.
4.Show separately interest credits under a sinking fund or similar method of depreciation accounting.
S iction A.Balances and Changes During Year
Line Item Total biectnc Plant in t-lectnc Plant Held Electnc Plant(c+d+e)Service for Future Use Leased to OthersNo-(a)(b)(c)(d)(e)
1 Balance Beginning of Year 4,490,290,654 4,490,133,529 157,125
2 Depreciation Provisions for Year,Charged to
3 (403)Depreciation Expense 363,340,037 363,340,037
4 (413)Exp.of Elec.Pit.Leas.to Others
5 Transportation Expenses-Clearing
6 Other ClearingAccounts
7 Other Accounts (Specify):978,023 974,792 3,231
8 Account 151 (Fuel Stock)12,282,263 12,282,263
9 TOTAL Deprec.Prov for Year (Enter Total of 376,600,323 376,597,092 3,231
lines 3 thru 8)
10 Net Charges for Plant Retired:
11 Book Cost of Plant Retired 186,475,861 186,475,861
12 Cost of Removal 20,385,717 20,385,717
13 Salvage (Credit)11,345,440 11,345,440
14 TOTAL Net Chrgs.for Plant Ret.(Enter Total 195,516,138 195,516,138
of lines 11 thru 13)
15 Other Debit or Cr.Items (Describe):20,688,472 20,688,472
16
17 Balance End of Year (Enter Totals of lines 1,4,692,063,311 4,691,902,955 160,35E
9,14,15,and 16)
Section E.Balances at End of Yes r According to Functionil Classification
18 Steam Production 1,941,463,728 1,941,463,728
19 Nuclear Production
20 Hydraulic Production-Conventional 200,419,496 200,419,496
21 Hydraulic Production-Pumped Storage
22 Other Production 31,747,071 31,747,071
23 Transmission 804,599,490 804,439,134 160,35E
24 Distribution 1,312,066,681 1,312,066,681
25 General 401,766,845 401,766,845
26 TOTAL (Enter Total of lines 18 thru 25)4,692,063,311 4,691,902,955 160,35E
FERC FORM NO.1 (ED.12-88)Page 219
Name of Respondent This Re ort Is:Date of Report Year of Report
PacifiCo R um ssion
I,Da,Yr)
Dec.31,2001
NONUTILITY PROPERTY (Account 121
1.Give a brief description and state the location of Nonutility property included in Account 121.
2.Designate with a double asterisk any property which is Leased to another company.State name of Lessee and whether Lessee is an associated
company.
3.F Jrnish particulars (details)concerning sales,purchases,or transfers of Nonutility Property during the year.
4.L st separately all property previously devoted to public service and give date of transfer to Account 121,Nonutility Property.
5.IV inor 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 pt blic service (Line 44),or (2)other Nonutility property (Line 45).
Line Description and Location Balance of Begining Purchases,Sales,Balance at End
No of Year Transfers,etc.of Year
(a)(b)(c)(d)
1 NAUGHTON NO 4 STEAM ELECTRIC STATION 930,908 930,908
2 HUNTER NO 1 STEAM ELECTRIC STATION 783,042 85,516 868,558
3 AXTELL PROJECT 265,000 265,000
4 WELLINGTON PROJECT 712,583 712,583
5 DELTA-FILLMORE RAILROAD RIGHT OF WAY 157,000 157,000
6 FUTURE LAKE DISTRICT SERVICE CENTER SITE 150,000 -42,920 107,080
7 TIMP DISTRICT SERVICE CENTER AND OFFICE 688,650 688,650
8 REED RANCH 282,937 -282,937
9 COOS BAY DISTRICT OFFICE 301,380 301,380
10 ALBANY OFFICE -N.C.S.T.116,985 116,985
11 JUNCTION CITY DISTRICT 166,076 166,076
12 NORTH CANAL PROJECT 226,320 226,320
13 SIMPLE CHOICE LICENSING FEE 4,277,946 4,277,946
14 MADRAS DISTRICT OFFICE 345,542 -345,542
15 LAND -DRY CREEK SITE 408,205 408,205
16 LAND -DECKER PROJECT WYOMING 314,390 314,390
17 COPCO #1 HYDRO NONUTILITY 960,377 960,377
18 CHERRYWOOD SUB NONUTILITY 202,096 202,096
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39 Minor Item Previously Devoted to Public Service 731,600 -39,811 691,789
40 Minor Items-Other Nonutility Property 794,213 170,415 964,628
41
42
43
44 Minor Item Previously Devoted to Public Service
45 Minor Items-Other Nonutility Property
46 TOTAL 12,815,250 -455,279 12,359,971
ERC FORM NO.1 (ED.12-95)Paga 221
Blank Page
(Next Page is:224)
Name of Respondent This Report Is:Date of Report Year of Report
(1)An Original (Mo,Da,Yr)PacifiCom (2)A Resubmission //Dec.31,2001
INVESTM INTS IN SUBSIDIARY COMPANIES Account 123.1)
1.Report below investments in Accounts 123.1,investments in Subsidiary Companies.
2.Pravide a subheading for each company and List there under the information called for below.Sub -TOTAL by company and give a TOTAL in
colur ns (e),(f),(g)and (h)
(a)In testment in Securities -List and describe each security owned.For bonds give also principal amount,date of issue,maturity and interest rate.
(b)In'testment 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.RE port separately the equity in undistributed subsidiary earnings since acquisition.The TOTAL in column (e)should equal the amount entered for
Account 418.1.
Line Description of Investment Date Acquired Date Of Amount of Investment atMaturityBeginningofYearNo(a)(b)(c)(d)
1
2 PACIFICORP GROUP HOLDINGS COMPANY
3 Common Stock 99,483,436
4 Capital Contributions 2,919,883
5 Equity in Earnings 391,783,768
6 SUBTOTAL 494,187,087
7
8 PACIFIC POWER &LIGHT COMPANY
9 Common Stock 100
10 SUBTOTAL 100
11
12 CENTRALIA MINING COMPANY
13 Capital Contributions
14 SUBTOTAL
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 59,806,234
23 SUBTOTAL 59,806,235
24
25 GLENROCK COAL
26 Common Stock 1
27 SUBTOTAL 1
28
29 PACIFICORP POWER MARKETING
30 Capital Contributions -3,728,721
31 Equity in Earnings 5,219,740
32 SUBTOTAL 1,491,019
33
34 INTERWEST MINING
35 Common Stock 1,000
36 SUBTOTAL 1,000
37
38 PACIFIC KLAMATH ENERGY
39 Capital Contributions 5,009,270
40 Equity in Eamings -137,805
41 SUBTOTAL 4,871,465
42 Total Cost of Account 123.1 $0 TOTAL 575,253,560
FERG FORM NO.1 (ED.12-89)Page 224
Name of Respondent This Report is:Date of Report Year of Report(1)An Original (Mo,Da,Yr)PacifiCorp (2)A Resubmission //Dec.31,2001
INVESTMENTS IN SUBSIDIARY COMPANIES (Account 123.1)(Continued)
4.For any securities,notes,or accounts that were pledged designate such securities,notes,or accounts in a footnote,and state the name of pledgee
and purpose of the pledge.
5.If Commission approval was required for any advance made or security acquired,designate such fact in a footnote and give name of Commission,
date of authorization,and case or docket number.
6.Report column (f)interest and dividend revenues form investments,including such revenues form securities disposed of during the year.
7.In column (h)report for each investment disposed of during the year,the gain or loss represented by the difference between cost of the investment (or
the other amount at which carried in the books of account if differenœ 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 Šubsidiary Revenues for Year Amount of Investment at Óain or Loss from Investment LineEarninsofYearEndfYearDispsedofNo.
2
99,483,436 3
2,919,883 4
137,990,005 529,773,773 5
137,990,005 632,177,092 6
7
8
100 9
100 10
11
12
1,000 1,000 13
1,000 1,000 14
15
16
1,000 17
1,000 18
19
20
1 21
-4,810,813 54,995,421 22
-4,810,813 54,995,422 23
24
25
1 26
1 27
28
29
3,728,721 30
3,235,900 -8,455,640 31
3,235,900 -4,726,919 32
33
34
1,000 35
1,000 36
37
38
-5,009,270 39
229,760 -91,955 40
229,760 -5,101,225 41
142,973,844 -15,513,249 702,714,155 42
FERC FORM NO.1 (ED.12-89)PEge 225
Name of Respondent This Report Is:Date of Report Year of Report(1)An Original (Mo,Da,Yr)PacifiCorp (2)A Resubmission //Dec.31,2001
INVESTM INTS IN SUBSIDIARY COMPANIES tAccount 123.1)
1.R(port below investments in Accounts 123.1,investments in Subsidiary Companies.
2.Pravide a subheading for each company and List there under the information called for below.Sub -TOTAL by company and give a TOTAL in
colun ns (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.Roport separately the equity in undistributed subsidiary earnings since acquisition.The TOTAL in column (e)should equal the amount entered for
Account 418.1.
Line Description of Investment Date Acquired Date Of Amount of Investment atMaturityBegmmngofYearNo(a)(b)(c)(d)
2 PACIFICORP CAPITAL I
3 Capital Contributions 6,712,000
4 Equity in Earnings
5 SUBTOTAL 6,712,000
6
7 PACIFICORP CAPITAL II
8 Capital Contributions 4,176,000
9 Equity in Earnings
10 SUBTOTAL 4,176,000
11
12 PACIFICORP INVESTMENT MANAGEMENT INC.
13 Capital Contributions 100,000
14 Equity in Eamings 21,479
15 SUBTOTAL 121,479
16
17 PACIFICORP ENVIRONMENTAL REMEDIATION COMPANY
18 Capital Contributions 900,000
19 Equity in Earnings 2,986,174
20 SUBTOTAL 3,886,174
21
22 PFS ACQUISITION CORP.
23 Common Stock
24 SUBTOTAL
25
26 PACIFICORP FUTURE GENERATIONS INC
27 Common Stock
28 Capital Contributions
29 Equity in Earnings
30 SUBTOTAL
31
32
33
34
35
36
37
38
39
40
41
42 Total Cost of Account 123.1 $0 TOTAL 575,253,560
FER(:FORM NO.1 (ED.12-89)Page 224.1
Name of Respondent This Report Is:Date of Report Year of Report(1)An Original (Mo,Da,Yr)PacifiCorp (2)A Resubmission //Dec.31,2001
INVESTMENT3 IN SUBSIDIARY COMPANIES (Account 123.1)(Continued)
4.For any securities,notes,or accounts that were pledged designate such securities,notes,or accounts in a footnote,and state the name of pledgee
and purpose of the pledge.
5.If Commission approval was required for any advance made or security acquired,designate such fact in a footnote and give name of Commission,
date of authorization,and case or docket number.
6.Report column (f)interest and dividend revenues form investments,including such revenues form securities disposed of during the year.
7.In column (h)report for each investment disposed of during the year,the gain or loss represented by the difference between cost of the investment (or
the other amount at which carried in the books of account if difference from cost)and the selling price thereof,not including interest adjustment includible
in column (f).
8.Report on Line 42,column (a)the TOTAL cost of Account 123.1
Equity in Šubsidiary Revenues for Year Amount of Investment at Gain or Loss from Investment LineEarninsofYearEndfYearDispsedofNo.
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
3,548 25,027 14
3,548 125,027 15
16
17
900,000 18
639,775 3,625,949 19
639,775 4,525,949 20
21
22
23
24
25
26
27
28
-436 -436 29
-436 -436 30
31
32
33
34
35
36
37
38
39
40
41
142,973,844 -15,513,249 702,714,155 42
FERC FORM NO.1 (ED.12-89)Page 225.1
Name of Respondent This Report Is:Date of Report Year of Report
(1)An Original (Mo,Da,Yr)PacifiCorp (2)A Resubmission //Dec.31,2001
MATERIALS AND SUPPLIES
1.For Account 154,report the amount of plant materials and operating supplies under the primary functional classifications as indicated in column (a)
estimates of amounts by function are acceptable.In column (d),designate the department or departments which use the class of material.
2.Give an explanation of important inventory adjustments during the year (in a footnote)showing general classes of material and supplies and the
various accounts (operating expenses,clearing accounts,plant,etc.)affected debited or credited.Show separately debit or credits to stores expense
cleariig,if applicable.
Line Account Balance Balance Department or
No.Beginning of Year End of Year Departments which
Use Material(a)(b)(c)(d)
1 Fuel Stock (Account 151)53,541,066 62,176,475 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)30,568,693 29,627,461 Electric
6 Assigned to -Operations and Maintenance
7 Production Plant (Estimated)43,530,193 44,551,828 Electric
8 Transmission Plant (Estimated)2,404,930 2,130,232 Electric
9 Distribution Plant (Estimated)10,621,715 7,054,296 Electric
10 Assigned to -Other 6,233,692 5,464,623 Electric
11 TOTAL Account 154 (Enter Total of lines 5 thru 10)93,359,223 88,828,440
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)146,900,289 151,004,915
FERC FORM NO.1 (ED.12-96)Page 227
Blank Page
(Next Page is:228)
Name of Respondent This Report Is:Date of Report Year of Report
(1)An Original (Mo,Da,Yr)PacifiCorp (2)A Resubmission //Dec.31,2001
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.Raport 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
succ3eding years in columns (j)-(k).
5.Raport on line 4 the Environmental Protection Agency (EPA)issued allowances.Report withheld portions Lines 36-40.
Line Allowances Inventory Current Year 2002
No.(Account 158.1)No.Amt.No.Amt.
(a)(b)(c)(d)(e)
1 Balance-Beginning of Year 165,736.00 151,634.00
2
3 Acquired During Year:
4 Issued (Less Withheld Allow)2,220.00 26.00
5 Returned by EPA
6
7
8 Purchases/Transfers:
9 Ameren 10,000.00
10
11
12
13
14
15 Total 10,000.00
16
17 Relinquished During Year:
18 Charges to Account 509 96,458 00
19 Other:
20
21 Cost of Sales/Transfers:
22 Dynegy 15,000.00
23 APS 15,000.00
24 AEP 5,000.00
25 Coral 12.00
26 Panda 2.00
27 Ameren
28 Total 35,014.00
29 Balance-End of Year 46,484.00 151,660.00
30
31 Sales:
32 Net Sales Proceeds(Assoc.Co.)
33 Net Sales Proceeds (Other)35,014.00
34 Gains 35,014.00
35 Losses
Allowances Withheld (Acct 158.2)
36 Balanæ-Beginning of Year 2,258.00 2,258.00
37 Add:Withheld by EPA 1.00 1.00
38 Deduct:Returned by EPA 2,259.00
39 Cost of Sales
40 Balanœ-End of Year 2,259.00
41
42 Sales:
43 Net Sales Proceeds (Assoc.Co.)
44 Net Sales Proceeds (Other)2,259.00
45 Gains 2,259.00
46 Losses
FERC FORM NO.1 (ED.12-95)Page 228
Name of Respondent This Report Is:Date of Report Year of Report(1)An Original (Mo,Da,Yr)PacifiCorp (2)A Resubmission //Dec.31,2001
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.
2003 2004 FutureYears Totals Line
No.Amt.No.Amt.No.Amt.No.Amt.No.
(f)(g)(h)(i)(j)(k)(!)(m)
103,526.00 85,818.00 3,759,828.00 4,266,542.00 1
2
3
26.00 26.00 156,978.00 159,276.00 4
5
6
8
10,000.00 9
10
11
12
13
14
10,000.00 15
16
17
96 458 00 18
20
21
15,000.00 22
15,000.00 23
5,000.00 24
12.00 25
2.00 26
18,500.00 18,500.00 27
18,500.00 53,514.00 28
103,552.00 85,844 00 3,898,306.00 4,285,846.00 29
30
31
32
18,500.00 53,514.00 33
18,500.00 53,514.00 34
35
2,258.00 2,258 00 110,932.00 119,964.00 36
1.00 1.00 4,531.00 4,535.00 37
2,276.00 4,535.00 38
39
2,259.00 2,259.00 113,187.00 119,964.00 40
41
42
43
2,259.00 44
2,259.00 45
46
ERC FORM NO.1 (ED.12-95)Page 229
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001
(2)A Resubmission //
UN RECOVEREDPLANT AND REGULATORY STUDY COSTS (182.2)
Line Description of Unrecovered Plant Total Costs WRITTEN OFF DURING YEAR Balance atNo.and Regulatory Study Costs [Include Amount 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 19,175,216 50,749,624 52,651,301 17,273,539
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 19,175,216 50,749,624 52,651,301 17,273,539
FERC FORM NO.1 (ED.12-88)Page 230b
Name of Respondent This Re ort Is:Date of Report Year of Report(1)An Original (Mo,Da,Yr)2001PacifiCorpDec.31,(2)A Resubmission //
OTHER REGULATORY ASSETS (Account 182.3)
1.Report below the particulars (details)called for concerning other regulatory assets which are created through the rate making actions
of regulatory agencies (and not includable in other accounts)
2.For regulatory assets being amortized,show period of amortization in column (a)
3.Minor items (5%of the Balance at End of Year for Account 182.3 or amounts less than $50,000,whichever is less)may be grouped
by classes.
Line Description and Purpose of Debits CREDITS Balance at
No.Other Regulatory Assets Account Amount End of YearCharged
(a)(b)(c)(d)(e)
1 DEMAND SIDE RESOURCES:
2 STATE OF OREGON:
3 Weatherization Amort 0%(10)146,850 187,566 724,578
4 Weatherization Amort 0%(30)3,252 132,898 13,008
5 Weatherization Amort 0%(5)19,222
6 Irrigation Ditch to Pipe (15)648 1,796 2,778
7 Irrigation (15)126,876 141,091 568,912
8 Irrigation (5)1,314 132
9 Energy Efficient Showerheads (10)774,587 207 3,597,153
10 Energy Efficient Showerheads (12)1,529,609
11 Energy Efficient Showerheads (5)164,113
12 DSM R&D Technology (16)552 631 846
13 Water Heater Solar (16)87
14 Weatherization Amort 6.5%(10)127,512 132,336 480,936
15 Weatherization Amort 6%(30)123,058 56,203
16 Weatherization Amort 6%(5)9,775 29,700
17 Green Lights (16)1,538
18 Major Customer Accounts (15)105,183 36,321
19 Major Customer Accounts (5)9,706 8,640
20 Meter Info -Service Pilot (16)2,364
21 Market Transformation (16)31,785
22 Market Transformation (5)32,352 3,669 146,394
23 Small Retrofit (16)232,644 359,536 1,227,547
24 Small Retrofit (5)41,766 209,736
25 Energy Finanswer Operation Service (16)4,764 5,922 21,426
26 Northwest Energy Efficiency Alliance 420,720 1,360,594 3,153,265
27 Commercial Codes (16)45,264 50,249 174,714
28 Energy Finanswer Schools (16)828 914 2,946
29 Industrial Partners (10)4,374
30 Low Income (10)395,241 413,329 1,527,439
31 Low income (30)298,412
32 Low Income (5)49,322 199,812
33 Manufactured Housing (10)2,238,708 111,198 7,156,429
34 Manufactured Housing (50)2,287,482
35 Manufactured Housing (5)3,793
36 Pacific Environments (15)600 702 915
37 Home Comfort (15)9,048 34,576 182,397
38 Home Comfort (30)9,480
39 Pacific Environments (15)144,098 727,530
40 Technology Monitoring &Analysis (10)6,936 2,445 12,322
41 Technology Monitoring &Analysis (16)7,927
42 Hasslefree Efficiency Acquisition (10)63,546 103,421 270,040
43 Hasslefree Efficiency Acquisition (15)65.429 39,117
44 TOTAL 2,229,772,785 1,754,216,534 1,363,246,472
¯ERC FORM NO.1 (ED.12-94)Page 232
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001
(2)A Resubmission //
OTHER REGULATORY ASSETS (Account 182.3)
1.Raport below the particulars (details)called for concerning other regulatory assets which are created through the rate making actions
of re·;ulatory agencies (and not includable in other accounts)
2.For regulatory assets being amortized,show period of amortization in column (a)
3.Minor items (5%of the Balance at End of Year for Account 182.3 or amounts less than $50,000,whichever is less)may be grouped
by classes.
Line Description and Purpose of Debits CREDITS Balance at
No.Other Regulatory Assets Account Amount End of YearCharged
(a)·(b)(c)(d)(e)
1 DEMANDSIDE RESOURCES:(cont'd)
2 STATE OF OREGON (cont'd)
3 Hasslefree Efficiency Acquisition (5)6,650 61,260
4 Self Audit -1999-2000 (1)90 4,553 616
5 Energy Finanswer (5)981,744 451,325 4,003,761
6 Energy Finanswer (16)66,318 1,022,381 265,272
7 Competitive Bidding (10)3,901 2,982
8 Low Income Competitive Bidding (10)4,490 8,979
9 Residential Building Codes (50)8,124 8,305 12,877
10 Residential Building Codes (10)5,234 4,741
11 RFP Low Income (30)1,150,311 747,658 4,438,109
12 RFP Low Income (5)59,706 147,264
13 Energy Partners (15)14,119 70,593
14 Industrial Finanswer 1992-99 (15)694,494 89,930 3,070,320
15 Industrial Finanswer 1993-1999 (15)676,625
16 Industrial Finanswer 1996-1998 (5)55,589 197,904
17 Technology Assessment (10)304 600
18 NehemiahWeatherization (10)3,743
19 Large Commercial Bldg Retrofit (10)363,372 -414,920 1,498,303
20 Large Commercial Bldg Retrofit (5)4,985 6,744
21 Large Commercial Bldg Retrofit (16)531 395,563 2,124
22 DSM Other Programs (16)88,344 87,853 360,727
23 DSM Other Programs (5)8,731 2,160
24 Energy Finanswer 12,000 (10)102,108 34,668 208,231
25 Energy Finanswer 12,000 (16)113,882
26 Econs (5)1,548
27 RFP General (5)132 144 947
28 E.Rated Appliance (5)2,284 95
29 Home Comfort (5)1,899
30 Conservation for Wholesale (10)2,465 2,465
31 Manufactured Acquisition (10)97,686 97,686
32 Home Comfort Analysis (10)2,681 2,681
33 ESC Loans in GAWL (10)1,711 1,711
34 Super Efficient Refrigerator (10)19,272 812 109,084
35 Super Efficient Refrigerator (15)20,743
36 Super Efficient Refrigerator (5)654 828
37 Load Studies (10)7,584 1,123 13,812
38 Load Studies (16)8,537
39 Regional Energy Management (16)408 461 625
40 Program Development &Support (16)1,538
41 Super Good Cents (10)1,200,052 1,051,768
42 Super Good Cents (5)2,404,332 24,904 6,155,830
43 Super Good Cents (50)2,434,779
44 TOTAL 2,229,772,785 1,754,216,534 1,363,246,472
¯ERC FORM NO.1 (ED.12-94)Page 232.1
Name of Respondent This Re ort Is:Date of Report Year of Report(1)An Original (Mo,Da,Yr)2001PacifiCorpDec.31,(2)A Resubmission //
OTHER REGULATORY ASSETS (Account 182.3)
1.Report below the particulars (details)called for concerning other regulatory assets which are created through the rate making actions
of re3ulatory agencies (and not includable in other accounts)
2.F 3r 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 YeatCharged
(a)·(b)(c)(d)(e)
1 DEMAND SIDE RESOURCES:(cont'd)
2 STATE OF OREGON (cont'd)
3 H-Pro Energy Efficiency (10)198,912 20,668 449,647
4 H-Pro Energy Efficiency (5)6,984
5 H-Pro Energy Efficiency (15)216,491
6 New Construction Super Good Cents (10)9,120 36,136 86,594
7 New Construction Super Good Cents (50)9,343
8 Energy Finanswer Light Pro Network (10)1,092 1,666
9 Energy Finanswer Light Pro Network (16)1,227
10 Irrigation (10)5,465
11 Irrigation (15)1,023
12 Super Good Cents Home Improvement (30)7,344 7,673 11,446
13 NW Compfl Bulb,OR 1995 (15)11,904 14,688 22,483
14 NW Compfl Bulb,OR 1995 (5)872
15 HIP Supplementary Measures (30)389,112 21,499 1,854,973
16 HIP Rebate Weatherization (30)324,474 246,408
17 HIP Rebate Weatherization (5)75,030 57,092 300,120
18 DSR Carrying Charges 3,945,569 5,583,711 -15,110,239
19 DSR Deferred Amortization 1,327,381 21,160,451 -7,983,703
20 DSR Oregon DSM Expense-Deferred 420,914
21 Merger Stipulation 12,156 143,522 15,912
22 Industrial Small Retrofit 2001 19,020 19,020
23 Low Income RFP 2001 6,010 6,010
24 Low Income WZ 2001 314,315 314,315
25 Enhanced Audit 2001 267,419 267,419
26 Cash Rebate 2001 218,058 218,058
27 Low Income RFP 2001 1,690 1,690
28 HEA Analysis 2001 71,877 71,877
29 Industrial Finanswer 2001 2,036,939 2,036,939
30 Energy Finanswer 2001 978,604 978,604
31 Commercial Retrofit 2001 26 26
32 Commercial Retrofit Lighting 2001 940,643 940,643
33 Small Retrofit (EF 12,000)2001 763,596 763,596
34 Industrial Retrofit Lighting 2001 86,979 86,979
35 Hasslefree Efficiency 2001 64,167 64,167
36 Low Interest WZ 2001 41,274 41,274
37 Self Audit 2001 19,224 19,224
38 Compact Fluorescent Bulbs (CLF)2001 5,361,145 5,361,145
39 WZ Loans 0%2001 34,487 34,487
40 NEEA Actuals 2001 850,955 850,955
41 DSR Mesures 2001 1,826
42
43
44 TOTAL 2,229,772.785 1,754,216,534 1,363,246,472
¯ERC FORM NO.1 (ED.12-94)Page 232.2
Name of Respondent This Re ort Is:Date of Report Year of Report
(1)An Original (Mo,Da,Yr)2001PacifiCorpDec.31,(2)A Resubmission //
OTHER REGULATORY ASSETS (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.Minor items (5%of the Balance at End of Year for Account 182.3 or amounts less than $50,000,whichever is less)may be grouped
by classes.
Line Description and Purpose of Debits CREDITS Balance at
No.Other Regulatory Assets Account Amount End of YearCharged
(a)(b)(c)(d)(e)
1 DEMAND SIDE RESOURCES:(cont'd)
2 STATE OF IDAHO
3 Idaho Weatherization (12)316 2,526
4 Super Good Cents (12)128,278 1,026,281
5 Weatherization (12)79,296 634,366
6 Low Income Program (12)23,792 199,845
7 Cash Grant (12)27,396 219,165
8 Weather Loans (12)1,487 -42 2,023
9 Early Loan Payoff Program (12)57,936 463,492
10 Irrigation Rebate (12)585 4,683
11 Regional Mobile Home (MAP)(12)8,130 113,101 839,765
12 Technology Monitoring (12)443 3,543
13 Hasslefree Efficiency Acquisition (12)3,208 27,476
14 Energy Finanswer (12)105 23,098 191,486
15 Major Customer (12)194 1,555
16 Industrial Finanswer (12)3,449 30,205
17 Commercial Retrofit (12)70 559
18 Energy Finanswer 12,000 (12)1,304 10,428
19 Conservation for Wholesale (12)361 2,890
20 Manufactured Acquisition (12)5,077 40,620
21 Home Comfort Analysis (12)348 2,784
22 Super Efficient Refrigerator (12)16,582 147,209
23 Regional Energy Management (12)52 415
24 Program Development &Support (12)103 826
25 Load Studies (12)1,017 8,134
26 Interest Bearing Variable (12)4 32
27 Energy Finanswer Light Pro Network (12)1 10
28 Irrigation (12)1,861 14,891
29 Self Audit -1998 (12)85 907
30 DSM Other Programs (12)1,158 9,264
31 DSR Market Research (12)1,311 10,491
32 Northwest Energy Efficiency Alliance (12)6,534 52,275
33 DSR Deferred Net Lost Revenue (12)278,796 2,230,371
34 Low Income Bid (12)1,843 58,235 611,851
35 Energy Finanswer 2001 (12)40,452 40,452
36 Hasslefree Efficency 2001 (12)2,811 2,811
37 Industrial Finanswer 2001 (12)13,109 13,109
38 Low income WZ 2001 (12)21,695 21,695
39 Self Audit 2001 (12)529 529
40 NEEA 2001 (12)257,731 257,731
41
42
43
44 TOTAL 2,229,772,785 1,754,216,534 1,363,246,472
ERC FORM NO.1 (ED.12-94)Page 232.3
Name of Respondent This R ort Is:Date of Report Year of Report(1)An Original (Mo,Da,Yr)2001PacifiCorpDec.31,(2)A Resubmission //
OTHER REGULATORY ASSETS (Account 182.3)
1.Report below the particulars (details)called for concerning other regulatory assets which are created through the rate making actions
of re-gulatory agencies (and not includable in other accounts)
2.For regulatory assets being amortized,show period of amortization in column (a)
3.Minor items (5%of the Balance at End of Year for Account 182.3 or amounts less than $50,000,whichever is less)may be grouped
by classes.
Line Description and Purpose of Debits CREDITS Balance at
No.Other Regulatory Assets Account Amount End of YearCharged
(a)(b)(c)(d)(e)
1 DEMAND SIDE RESOURCES:(cont'd)
2 STATE OF CALIFORNIA
3 Super Good Cents -Mobile Home (10)8,940 8,940
4 Weatherization Amort 0%(10)2,726 1,373
5 Low Income Direct Weather (10)76,921 126,137
6 Hasslefree Efficiency Acquisition (10)5,061 6,438
7 Energy Finanswer (10)10,207 12,091
8 ESC Loans in GAWL (10)165 165
9 Industrial Finanswer (10)97 194
10 Energy Finanswer 12,000 (10)75 75
11 Water Heater Rebate (10)660 224
12 Regional Mobile Home (MAP)(10)44,597 117,831
13 Home Comfort Analysis (10)28,761 70,705
14 Manufactured Homes -HUD (10)10,726 6,978
15 Home Comfort (10)860
16 Irrigation (10)30,139 57,684
17 Super Efficient Refrigerator (10)48 48
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 2,229,772,785 1,754,216,534 1,363,246,472
2ERC FORM NO.1 (ED.12-94)Page 232.4
Name of Respondent This R ort is:Date of Report Year of Report
(1)An Original (Mo,Da,Yr)2001PacifiCorpDec.31,(2)A Resubmission //
OTHER REGULATORY ASSETS (Account 182.3)
1.Raport below the particulars (details)called for concerning other regulatory assets which are created through the rate making actions
of re1ulatory agencies (and not includable in other accounts)
2.F->r regulatory assets being amodized,show period of amortization in column (a)
3.Minor items (5%of the Balance at End of Year for Account 182.3 or amounts less than $50,000,whichever is less)may be grouped
by classes.
Line Description and Purpose of Debits CREDITS Balance at
No.Other Regulatory Assets Account Amount End of Year
Charged
(a)(b)(c)(d)(e)
1 DEMAND SIDE RESOURCES:(cont'd)
2 STATE OF UTAH
3 Super Good Cents (10)20,631 17,048
4 Energy Partners (15)8,118 40,588
5 Industrial Finanswer (15)326,024 77,912 958,022
6 Existing Commercial Buildings (15)6,039 33,382
7 Commercial Retrofit (15)2,459 20,634
8 Low IncomeWeatherization (10)59,498 161,461
9 RFP Resource Acquisition (10)8,114 8,114
10 RFP CES /WAY (10)85,792 369,558
11 Major Customer Accounts (10)29,949 108,826
12 DSR Commercial Codes (10)498 1,994
13 Utah Schedule 5 (10)6,717 20,442
14 RFP Low income (10)902 4,511
15 RFP General (10)932 336 932
16 Technology Monitoring (10)6,771 13,542
17 Energy Finanswer (15)385,068 230,501 2,189,910
18 Energy Efficient Showerheads (10)2,024 2,962
19 Commercial Competitive Bidding (15)19,609 137,264
20 Commercial Retrofit (15)184,468 785 189,967
21 Energy Finanswer 12,000 (15)19,882 134,171
22 Conservation for Wholesale (15)1,907 11,445
23 HomeComfort Analysis (10)2,833 2,833
24 Energy Finanswer Schools,UT (10)171 683
25 Super Efficient Refrigerator (10)14,406 50,836
26 Regional Energy Management (10)377 755
27 Program Development &Support (10)749 1,499
28 Load Studies (10)7,375 14,749
29 Market Research,UT (10)1,174 4,696
30 Energy Finanswer Light Pro Network (10)966 1,932
31 Heat Pump (H Pro)(10)1,009 4,023
32 DSM Other Programs (10)7,265 27,998
33 ECONS (10)286,209 872,687
34 RFP EUA Onsite (10)215,739 908,630
35 DSR Carrying Charges (5)14,201 14,666 63,869
36 DSR Deferred Net Lost Revenue (5)196,058 1,259,295
37 Industrial Retrofit Lighting 2001 27,106 27,106
38 Self Audit 2001 -2002 2,933 2,933
39 Compact Fluoresœnt Lamps (CFL)2001 1,252,114 1,252,114
40 Commercial Retrofit Lighting 61,245 61,245
41
42
43
44 TOTAL 2,229,772,785 1,754,216,534 1,363,246,472
¯ERC FORM NO.1 (ED.12-94)Page 232.5
Name of Respondent This R ort Is:Date of Report Year of Report(1)An Original (Mo,Da,Yr)2001PacifiCorpDec.31,(2)A Resubmission //
O HER REGULATORY ASSETS (Account 182.3)
1.Report below the particulars (details)called for concerning other regulatory assets which arë created through the rate making actions
of regulatory agencies (and not includable in other accounts)
2.Far 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 GREDITS 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 WYOMING -PPL
3 Super Good Cents (10)59,771 228,011
4 Major Customer Accounts (10)4,316 18,433
5 Energy Finanswer (10)30,447 123,759
6 MAP WY-P (10)695 -3,474
7 Special Contracts DSM 42 42
8 Industrial Finanswer (10)104,406 7,237 160,775
9 Commercial Retrofit (10)3 100 753
10 Energy Finanswer 12,000 (10)40,386 4,475 47,502
11 Super Efficient Refrigerator (10)1,454 5,815
12 Self Audit (10)460 50 1,564
13
14 STATE OF WYOMING -UPL
15 Super Good Cents (10)2,457 6,525
16 Major Customer Accounts (10)5,281 14,992
17 RFP General (10)
18 Super Efficient Refrigerator (10)152 609
19 Energy Finanswer (10)1,921 6,593
20 Industrial Finanswer (10)14,022 86,552
21 Energy Finanswer 12,000 (10)450 450
22 DSR Deferred Net Lost Revenue (10)59,355 492,087
23 Self Audit (10)508 508
24
25
26
27 STATE OF WASHINGTON
28 Energy Finanswer 403,477 412,801
29 Industrial Finanswer 761,860 814,355
30 Low Income 767,252 818,533
31 Self Audit 7,586 7,888
32 Commercial Small Retrofit 139,008 139,962
33 Commercial Retrofit Lighting 60,530 61,484
34 NEEA 321,568 434,031
35 Hasslefree 16,161 17,821
36 Compact Fluorescent Lamps 1,168,600 1,168,600
37 Residential Program Research 24,174 24,174
38 Revenue Recovery SBC Offset 2,378,868 -2,378,868
39 Industrial Retrofit 19,533 19,533
40 Energy Code Development 1,500 1,500
41 Home Comfort 28,027 28,027
42 Weatherization 28,904 28,904
43
44 TOTAL 2,229,772,785 1,754,216,534 1,363,246,472
'ERC FORM NO.1 (ED.12-94)Page 232.6
Name of Respondent This R ort Is:Date of Report Year of Report(1)An Original (Mo,Da,Yr)2001PacifiCorpDec.31,(2)A Resubmission //
O HER REGULATORY ASSETS (Account 182.3)
1.R3port below the particulars (details)called for concerning other regulatory assets which are created through the rate making actions
of regulatory agencies (and not includable in other accounts)
2.For regulatory assets being amortized,show period of amortization in column (a)
3.Minor items (5%of the Balance at End of Year for Account 182.3 or amounts less than $50,000,whichever is less)may be grouped
by classes.
Line Description and Purpose of Debits CREDITS Balance at
No.Other Regulatory Assets Account Amount End of YearCharged
(a)(b)(c)(d)(e)
1 OTHER REGULATORY ASSETS -COST -OTHER:
2
3 FAS 106 Regulatory Asset Deferrals
4 Wyoming PP&L (7)1,144,788 1,136,906
5 Wyoming UP&L (7)361,512 369,444
6
7 FAS 109 IncomeTax Regulatory Assets 28,971,357 33,399,163 589,805,154
8
9 FAS 87/88 Deferred Pension Costs 88,919,308
10 FAS 87/88 Deferred Pension Costs -CA GEN -1,185,677
11 FAS 87/88 Deferred Pension Costs -MT GEN -846,635
12 FAS 87/88 Deferred Pension Costs Write Down -86,886,996
13
14 EnvironmentalCost under Amortization (10)2,898,614 7,035,533 11,809,688
15
16 Oregon Direct Access 267,543
17
18 IDAI Costs -No Calif -Direct Access 1,665,523
19
20 Non-cost -Cholla -California Generation 23,016 -358,660
21 Non-cost -Cholla -Montana Generation 21,228 -330,728
22
23 FAS 109 Inc Tax Regulatory Asset -CA Gen -10,252,815
24 FAS 109 Inc Tax Regulatory Asset -MT Gen -9,589,686
25
26 Provision for Disallowed Colstrip 3 -WA.(22)1,035,092 1,087,280 995,951
27
28 Cholla Plant Transaction (26)1,122,425 17,491,125
29
30 Cholla Contract Review (4)198,572 198,572
31
32 Retail Access Project 47,209,753 37,865,556 12,937,097
33
34 Transition Costs -Retirement &Displacement(10)156,244,588 189,514,186 114,469,845
35
36 Glenrock Mine Reclamation 97 -UT (5)2,300,787 2,300,787
37
38 Y2K Expense 98-00 -UT (2)942,315 97,736
39
40 ComputerMainframeWritedown 97 -UT (4)843,274 843,274
41
42 Early Retirement98 -UT (4)3,683,020 3,683,020
43
44 TOTAL 2,229,772,785 1,754,216,534 1,363,246,472
ERC FORM NO.1 (ED.12-94)Page 232.7
Name of Respondent This Re ort Is:Date of Report Year of Report(1)An Original (Mo,Da,Yr)2001PacifiCorpDec.31,(2)A Resubmission //
OTHER REGULATORY ASSETS (Account 182.3)
1.Report below the particulars (details)called for concerning other regulatory assets which are created through the rate making actions
of re gulatory agencies (and not includable in other accounts)
2.F >r 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 FAS 87/88 Pension -UT (10)3,159,014 18,954,084
2
3 Y2K Expense 98-00 -OR (7)268,659 805,977
4
5 Deferred Excess Net Power Costs -WY 194,076,319 115,497,402 94,598,850
6
7 BSIP/SAP -UT (4)5,041,888 1,701,685 3,340,203
8
9 Glenrock Mine E×cluding Reclamation -UT (10)11,220,018 976,799 10,243,219
10
11 Software Write-Down 1997 -UT (4)1,800,272 385,773 1,414,499
12
13 Software Write-Down 1999 -UT (4)1,284,579 275,267 1,009,312
14
15 Transition Team Costs -UT (4)1,700,666 364,428 1,336,238
16
17 Deferred Excess Net Power Costs -OR UM 995 366,327,984 218,986,075 147,341,909
18
19 Deferred Excess Net Power Costs -UT 214,603,489 107,143,603 107,459,886
20
21 Deferred Excess Net Power Costs -ID 78,860,187 41,489,243 37,370,944
22
23 Deferred Excess Net Power Costs -OR UE 116 20,679,508 20,679,508
24
25 Contra Regulatory Assets 147,000,000 -147,000,000
26
27 Energy Trust of Oregon SB 1149 350,716 12,524 338,192
28
29 SB 1149 ImplementationCosts -Phase 1 Residential 1,357,384 103,630 1,253,754
30 SB 1149 ImplementationCosts Small 523,145 43,161 479,984
31 SB 1149 ImplementationCosts Large 3,621,891 302,520 3,619,371
32
33 FAS 133 Derivative Net Regulatory Asset 1,056,850,462 788,466,602 268,383,860
34
35
36
37
38
39
40
41
42
43
44 TOTAL 2,229,772,785 1,754,216,534 1,363,246,472
¯ERCFORM NO.1 (ED.12-94)Page 232.8
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001
(2)A Resubmission //
M SCELLANEOUS DEFFERED DEBITS (Account 186)
1.Report below the particulars (details)called for concerning miscellaneous deferred debits.
2.For any deferred debit being amortized,show period of amortization in column (a)
3.Minor item (1%of the Balance at End of Year for Account 186 or amounts less than $50,000,whichever is less)may be grouped by
classes.
Line Description of Miscellaneous Balance at Debits CREDITS Balance at
No.Deferred Debits Beginning of Year ACËouend Amount End of Year
(a)(b)(c)((e)(f)
1 Bonneville Power Administration
2 Balancing Account 333,336 88,619,946 78,970,800 9,982,482
3
4 Water assessment payment to
5 Emery Water Conservancy
6 District (Amortization Period
7 12 months)129,862 259,725 259,725 129,862
8
9 Mill Fork tract mine rights
10 lease payments 25,216,689 590,719 8,053 25,799,355
11
12 California property taxes
13 (amortized over 6 months)863,873 829,097 875,771 817,199
14
15 Joseph Hydro Buyout (20)2,346,922 137,380 2,209,542
16
17 Idaho Customer Balancing
18 Account -232,945 1,993,382 10,833,639 -9,073,202
19
20 Cove Hydro Projects -Amortized
21 through 1-31-2002 5,619 375 5,533 461
22
23 Firth Cogeneration Buyout (10)2,136,440 427,292 1,709,148
24
25 Lacomb Irrigation (24)963,930 45,720 918,210
26
27 Option purchases -58,800 2,285,720 526,920 1,700,000
28
29 Property damage repairs -
30 Insurance losses -67,136 4,916,972 4,862,986 -13,150
31
32 Sales of Electric Utility
33 Facilities and Properties 975,036 765,348 1,350,042 390,342
34
35 Bogus Creek (42)1,613,360 41,280 1,572,080
36 Bogus Creek settlement (7)-590,000 118,000 -472,000
37
38 Halsey Mill Cogen.Option (8)149,018 149,018
39
40 Intangible Pension Asset:
41 SERP Plan 3,465,000 3,465,000
42 Prepaid CMC Pension
43
44 Business Energy Tax Credit:
45 Super Good Cents 7,249 2,626 4,623
46 Weatherization Loan Program 13,266 23,490 22,662 14,094
47 Misc.Work in Progress
48 Deferred Regulatory Ôomm.
Expenses (See pages 350 -351)
49 TOTAL 91,322,557 100,497,507
FERC FORM NO.1 (ED.12-94)Page 233
Name of Respondent This Report is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001
(2)A Resubmission //
M SCELLANEOUS DEFFERED DEBITS (Account 186)
1.Report below the particulars (details)called for concerning miscellaneous deferred debits.
2.For any deferred debit being amortized,show period of amortization in column (a)
3.Minor item (1%of the Balance at End of Year for Account 186 or amounts less than $50,000,whichever is less)may be grouped by
classes.
Line Description of Miscellaneous Balance at Debits CREDITS Balance at
No.Deferred Debits Beginning of Year couend Amount End of Year
(a)(b)(c)(d (e)(f)
1 Loan Program 49 49
2 Energy Finanswer 4,987 402,287 261,808 145,466
3 Industrial Finanswer 9,653 926,830 401,776 534,707
4 Finanswer -2 2
5 CashRebate/Incentive 392,201 782,082 669,252 505,031
6 Commercial Retrofit 9,714 9,714
7 Low Income Weatherization 4,325 4,325
8
9 Glenrock Coal Company -Def.
10 Stripping costs -97,554 444,069 449,359 -102,844
11
12 Trail Mountain Exploration 1,263,034 1,263,034
13
14 Bridger Deferred Billings 5,803 277,629 283,432
15
16 Tri-State Firm Wheeling (16)4,149,630 1,059,480 3,090,150
17
18 Mead Phoenix Availability
19 &Trans Charge (50)17,534,360 377,760 17,156,600
20
21 Financing Costs Deferred 585,019 8,079,950 7,563,437 1,101,532
22
23 Clark Firm Transmission 1,505,144 1,505,144
24
25 Biomass COD Prepayment 551,525 19,983 527,338 44,170
26
27 Buffalo Buyout (7)176,941 270,682 315,859 131,764
28
29 Lakeview Buyout (13)349,845 43,280 306,565
30
31 TGS Buyout (20)284,064 14,825 269,239
32
33 Hermiston Swap (20)8,408,341 539,573 7,868,768
34
35 Hydrologic Assessment 72,533 72,533
36
37 Deferred Longwall Costs 660,275 1,858,158 1,787,976 730,457
38
39 Transition Costs -WA (5)15,555,628 82,754 4,414,929 11,223,453
40
41 Hayden Settlement 1,644,137 349,494 1,294,643
42
43 BETC Retrofit 145,561 1,423,044 790,040 778,565
44
45 Northwest Power Pool 88,219 1,429,166 1,405,665 111,720
46
47 Misc.Work in Progress
48 Deferred Regulatory Òomm.
Expenses (See pages 350 -351)
49 TOTAL 91,322,557 100,497,507
FERC FORM NO.1 (ED.12-94)Page 233.1
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
M SCELLANEOUS DEFFERED DEBITS (Account 186)
1.Report below the particulars (details)called for concerning miscellaneous deferred debits.
2.For any deferred debit being amortized,show period of amortization in column (a)
3.Minor item (1%of the Balance at End of Year for Account 186 or amounts less than $50,000,whichever is less)may be grouped by
classes.
Line Description of Miscellaneous Balance at Debits CREDITS Balance at
No.Deferred Debits Beginning of Year ca end Amount End of Year
(a)(b)(c)((e)(f)
1 Other Deferred Debits with
2 Amounts less than $50,000 748,406 1,273,132 1,470,326 551,212
3
4 Yakima Hydro -Transaction Cost 5,002,055 5,002,055
5
6 Deferred Aquila Streamflow
7 Hedge Costs 1,750,000 291,670 1,458,330
8
9 Oregon Customer Balancing 11,743,610 13,592,011 -1,848,401
10
11 Point to Point Transmission 3,264,009 1,929,000 1,335,009
12
13 Deferred Projects New
14 Generation 9,977,484 3,896,033 6,081,451
15
16 Deferred Costs Wyodak
17 Settlement 7,401,932 363,113 7,038,819
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 Misc.Work in Progress
48 beferred Regulatory Ôomm.
Expenses (See pages 350 -351)
49 TOTAL 91,322,557 100,497,507
FERC FORM NO.1 (ED.12-94)Page 233.2
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
ACCUIUULATEDDEFERRED INCOME TAXES (Account 190)
1.Report the information called for below concerning the respondent's accounting for deferred income taxes.
2.At Other (Specify),include deferrals relating to other income and deductions.
Line Description and Location Balance of Begining Balance at End
No.of Year of Year
(a)(b)(c)
1 Electric
2 Bond Refinancing 299,103 211,607
3 Deferred Compensation 305,913 4,255,501
4 Bad Debt 2,993,526 4,623,570
5 Obsolete Parts 3,323,048 7,359,582
6 Cholla/GE Contract Amortization 20,603,144 22,639,621
7 Other 178,386,675 17,208,305
8 TOTAL Electric (Enter Total of lines 2 thru 7)205,911,409 56,298,186
9 Gas
10
11
12
13
14
15 Other
16 TOTAL Gas (Enter Total of lines 10 thru 15
17 Other (Specify)12,419,978 10,289,910
18 TOTAL (Acct 190)(Total of lines 8,16 and 17)218,331,387 66,588,096
Notes
FERC FORM NO.1 (ED.12-88)Page 234
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
CAPITAL STOCKS (Account 201 and 204)
1.Report below the particulars (details)called for concerning common and preferred stock at end of year,distinguishing separate
series of any general class.Show separate totals for common and preferred stock.If information to meet the stock exchange reporting
requirement outlined in column (a)is available from the SEC 10-K Report Form filing,a specific reference to report form (i.e.,year and
company title)may be reported in column (a)provided the fiscal years for both the 10-K report and this report are compatible.
2.Entries in column (b)should represent the number of shares authorized by the articles of incorporation as amended to end of year.
Line Class and Series of Stock and Number of shares Par or Stated Call Price at
No.Name of Stock Series Authorized by Charter Value per share End of Year
(a)(b)(c)(d)
1 Common Stock (Account 201)750,000,000
2 (PacifiCorp is a fully owned subsidiary of
3 ScottishPower)
4
5
6 TOTAL_COMMON STOCK 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 $7.48 Series 100.00
22
23 TOTAL_PREFERRED STOCK 19,626,533
24
25
26
27
28
29
30
31
32
33
34 Authorized and unissued Capital Stock
35
36
37
38
39
40
41
42
FERC FORM NO.1 (ED.12-91)Page 250
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
CAPITAL STOCKS (Account 201 and 204)(Continued)
3.Give particulars (details)concerning shares of any class and series of stock authorized to be issued by a regulatory commission
which have not yet been issued.
4.The identification of each class of preferredstock should show the dividend rate and whether the dividends are cumulative or
non-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.
OUTSTANDING FER BALANCE SHEET HELD BY REE PONDENT Line(Total amount outstanding without reduction
for amounts held by respondent)AS REACQUIRED E TOCK (Account 217)IN SINKING AND OTHER FUNDS No.
Šhares Amount Šhares Óost $hares Amount(e)(f)(g)(h)(i)(j)
297,324,604 3,350,188,743 1
2
3
4
5
297,324,604 3,350,188,743 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
750,000 75,000,000 21
22
1,164,633 116,463,300 23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
FERC FORM NO.1 (ED.12-88)Page 251
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
OT·lER PAID-IN CAPITAL (Accounts 200-211,inc.)
Report below the balance at the end of the year and the information specified below for the respective othër paid-in capital accounts.Provide a
subheading for each account and show a total for the account,as well as total of all accounts for reconciliation with balance sheet,Page 112.Add more
columns for any account if deemed necessary.Explain changes made in any account during the year and give the accounting entries effecting such
change.
(a)Donations Received from Stockholders (Account 208)-State amount and give brief explanation of the origin and purpose of each donation.
(b)Reduction in Par or Stated value of Capital Stock (Account 209):State amount and give brief explanation of the capital change which gave rise to
amounts reported under this caption including identification with the class and series of stock to which related.
(c)Gain on Resale or Cancellation of Reacquired Capital Stock (Account 210):Report balance at beginning of year,credits,debits,and balance at end
of year with a designation of the nature of each credit and debit identified by the class and series of stock to which related.
(d)Miscellaneous Paid-in Capital (Account 211)-Classify amounts included in this account according to captions which,together with brief explanations,
disclose the general nature of the transactions which gave rise to the reported amounts.
Le I em Ar ount
1 Additional Paid In Capital 66,928,055
2 FAS 133 Derivative Gain/(Loss)-21,290,455
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 TOTAL 45,637,600
FERC FORM NO.1 (ED.12-87)Page 253
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
CAPITAL STOCK EXPENSE (Account 214)
1.Report the balance at end of the year of discount on capital stock for each class and series of capital stock.
2.If any change occurred during the year in the balance in respect to any class or series of stock,attach a statement giving particulars
(details)of the change.State the reason for any charge-offof capital stock expense and specify the account charged.
Line Class and Senes of Stock Balance at End 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
9 $1.98 Serial
10 $7.48 Serial 840,433
11
12
13
14
15
16
17
18
19
20
21
22 TOTAL 42,121,516
FERC FORM NO.1 (ED.12-87)Page 254b
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec 31,2001(2)A Resubmission //
L3NG-TERM DEBT (Account 221,222,223 and 224)
1.Report by balance sheet account the particulars (details)concerning long-term debt included in Accounts 221,Bonds,222,
Reacquired Bonds,223,Advances from Associated Companies,and 224,Other long-Term Debt.
2.In column (a),for new issues,give Commission authorization numbers and dates.
3.For bonds assumed by the respondent,include in column (a)the name of the issuing company as well as a description of the bonds.
4.For advances from Associated Companies,report separately advances on notes and advances on open accounts.Designate
demand notes as such.Include in column (a)names of associated companies from which advances were received.
5.For receivers,certificates,show in column (a)the name of the court -and date of court order under which such certificates were
issued.
6.In column (b)show the principal amount of bonds or other long-term debt originally issued.
7.In column (c)show the expense,premium or discount with respect to the amount of bonds or other long-term debt originally issued.
8.For column (c)the total expenses should be listed first for each issuance,then the amount of premium (in parentheses)or discount.
Indicate the premium or discount with a notation,such as (P)or (D).The expenses,premium or discount should not be netted.
9.Furnish in a footnote particulars (details)regarding the treatment of unamortized debt expense,premium or discount associated with
issues redeemed during the year.Also,give in a footnote the date of the Commission's authorization of treatment other than as
specified by the Uniform System of Accounts.
Line Class and Series of Obligation,Coupon Rate PrincipalAmount 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 6.750%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 6.900%Series due November 15,2011 500,000,000 3,429,569
10 1,735,000 D
11 8.493%Series due October 1,2012 19,772,000
12 8.797%Series due October 1,2013 16,203,000
13 8.734%Series due October 1,2014 28,218,000
14 8.294%Series due October 1,2015 46,946,000
15 8.635%Series due October 1,2016 18,750,000
16 8.470%Series due October 1,2017 19,609,000
17 7.700%Series due November 15,2031 300,000,000 2,791,686
18 864,000 D
19
20 First Mortgage and Collateral Trust Bonds:
21 8.90%Series B Medium-Term Notes due Feb.15,2001 20,000,000 174,297
22 8.90%Series B Medium-Term Notes due Feb.15,2001 20,000,000 174,297
23 8.88%Series B Medium-Term Notes due Feb.15,2001 20,000,000 174,297
24 8.90%Series B Medium-Term Notes due Feb.15,2001 20,000,000 169,297
25 9.10%Series A Medium-Term Notes due March 1,2001 5,000,000 30,114
26 6.02%Series F Medium-Term Notes due May 15,2001 4,500,000 34,413
27 9.12%Series C Medium-Term Notes due July 5,2001 5,000,000 40,830
28 9.12%Series C Medium-Term Notes due July 5,2001 10,000,000 81,659
29 9.06%Series B Medium-Term Notes due July 9,2001 1,000,000 6,018
30 9.15%Series C Medium-Term Notes due July 16,2001 3,000,000 24,498
31 9.17%Series B Medium-Term Notes due July 17,2001 1,000,000 6,268
32 9.06%Series C Medium-Term Notes due July 23,2001 1,000,000 8,166
33 TOTAL 4,436,925,925 69,964,207
FERC FORM NO.1 (ED.12-96)Page 256
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
LONG-TERM DEBT (Account 221,222,223 and 224)(Continued)
10.Identify separate undisposed amounts applicable to issues which were redeemed in prior years.
11.Explain any debits and credits other than debited to Account 428,Amortization and Expense,or credited to Account 429,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.
AMORTIZA ¯ION PERIOD Uutstanding--LineNominalDateDateof(Total amount outstanainhewithout Interest for Year
of Issue Maturity Date From Date To reductionr srpamdennts Id by Amount No.
(d)(e)(f)(g)Îhn
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 31,793,000 2,773,825 7
041592 100111 041592 100111 2,974,000 248,634 8
111501 111511 111501 111511 500,000,000 3,833,333 9
10
041592 100112 041592 100112 14,125,000 1,248,174 11
041592 100113 041592 100113 12,084,000 1,099,845 12
041592 100114 041592 100114 21,668,000 1,950,324 13
041592 100115 041592 100115 36,643,000 3,124,205 14
041592 100116 041592 100116 15,100,000 1,335,424 15
041592 100117 041592 100117 16,064,000 1,390,414 16
111501 111531 111501 111531 300,000,000 2,566,667 17
18
19
20
021291 021501 021291 021501 217,556 21
021291 021501 021291 021501 217,556 22
021291 021501 021291 021501 217,067 23
021391 021501 021391 021501 217,556 24
062591 030101 062591 030101 75,833 25
072793 051501 072793 051501 100,835 26
070591 070501 070591 070501 233,067 27
070591 070501 070591 070501 466,133 28
070991 070901 070991 070901 47,313 29
071691 071601 071691 071601 148,687 30
071791 071701 071791 071701 49,926 31
072391 072301 072391 072301 50,837 32
4,035,632,531 215,398,174 33
FERC FORM NO.1 (ED.12-96)Page 257
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
LONG-TERM DEBT (Account 221,222,223 and 224)
1.Report by balance sheet account the particulars (details)conceming 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 PrincipalAmount Total expense,
No.(For new issue,give commission Authorization numbers and dates)Of Debt issued Premium or Discount
(a)(b)(c)
1 9.09%Series C Medium-Term Notes due July 24,2001 1,000,000 8,166
2 9.10%Series C Medium-Term Notes due July 30,2001 5,000,000 40,830
3 7.50%Series E Medium-Term Notes due Aug.1,2001 2,000,000 12,598
4 8.99%Series C Medium-Term Notes due Aug.7,2001 3,000,000 24,498
5 9.00%Series C Medium-Term Notes due Aug.8,2001 500,000 4,083
6 9.00%Series B Medium-Term Notes due Aug.8,2001 2,500,000 15,669
7 7.20%Series D Medium-Term Notes due Aug.15,2002 12,000,000 76,552
8 7.20%Series D Medium-Term Notes due Aug.15,2002 6,500,000 41,466
9 7.20%Series D Medium-Term Notes due Aug.15,2002 10,000,000 63,793
10 7.20%Series D Medium-Term Notes due Aug.15,2002 6,000,000 38,276
11 7.18%Series D Medium-Term Notes due Aug.15,2002 10,000,000 63,793
12 7.18%Series D Medium-Term Notes due Aug.15,2002 3,500,000 22,328
13 7.12%Series D Medium-Term Notes due Aug.15,2002 4,000,000 25,517
14 7.25%Series E Medium-Term Notes due Sept.9,2002 20,000,000 150,295
15 7.25%Series E Medium-Term Notes due Sept.9,2002 20,000,000 150,295
16 7.21%Series E Medium-Term Notes due Sept.9,2002 10,000,000 75,148
17 7.14%Series E Medium-Term Notes due Sept.10,2002 1,500,000 11,272
18 6.98%Series E Medium-Term Notes due Sept.16,2002 10,000,000 75,148
19 6.97%Series E Medium-Term Notes due Sept.16,2002 2,000,000 15,030
20 6.95%Series E Medium-Term Notes due Sept.16,2002 10,000,000 75,148
21 7.00%Series E Medium-Term Notes due Sept.17,2002 1,000,000 7,515
22 6.97%Series E Medium-Term Notes due Sept.23,2002 1,500,000 11,272
23 7.40%Series E Medium-Term Notes due Jan.22,2003 1,000,000 6,333
24 7.36%Series E Medium-Term Notes due Jan.27,2003 3,000,000 18,998
25 6.34%Series F Medium-Term Notes due July 28,2003 19,000,000 150,051
26 6.34%Series F Medium-Term Notes due July 28,2003 4,000,000 31,590
27 6.34%Series F Medium-Term Notes due July 28,2003 2,000,000 15,795
28 6.34%Series F Medium-Term Notes due July 28,2003 2,000,000 15,795
29 6.34%Series F Medium-Term Notes due July 28,2003 10,000,000 78,974
30 6.31%Series F Medium-Term Notes due July 28,2003 6,000,000 47,385
31 6.31%Series F Medium-Term Notes due July 28,2003 18,000,000 142,154
32 6.31%Series F Medium-Term Notes due July 28,2003 18,000,000 142,154
33 TOTAL 4,436,925,925 69,964,207
FERC FORM NO.1 (ED.12-96)Page 256.1
NameofRespondent ThisRepodIs:DateofRepod YearofRepod
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001
(2)A Resubmission //
LONG-TERM DEBT (Account 221,222,223 and 224)(Continued)
10.Identify separate undisposed amounts applicable to issues which were redeemed in prior years.
11.Explain any debits and credits other than debited to Account 428,Amortization and Expense,or credited to Account 429,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 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.
AMORTIZA lON PERIOD Uutstandin9 LineNominalDateDateof(Total amount outstanainhewithout Interest for Year
of Issue Maturity Date From Date To reductionr sr amoennts Id by Amount No.
(d)(e)(1)(g)I (¡)
072491 072401 072491 072401 51,257 1
073091 073001 073091 073001 264,153 2
110692 080101 110692 080101 87,500 3
080791 080701 080791 080701 161,820 4
080891 080801 080891 080801 27,125 5
080891 080801 080891 080801 135,625 6
081492 081502 081492 081502 12,000,000 864,000 7
081492 081502 081492 081502 6,500,000 468,000 8
081492 081502 081492 081502 10,000,000 720,000 9
081492 081502 081492 081502 6,000,000 432,000 10
081492 081502 081492 081502 10,000,000 718,000 11
081492 081502 081492 081502 3,500,000 251,300 12
081492 081502 081492 081502 4,000,000 2&4,800 13
090892 090902 090892 090902 20,000,000 1,4503300 14
090492 090902 090492 090902 20,000,000 1,450,000 15
090992 090902 090992 090902 10,000,000 721,000 16
091092 091002 091092 091002 1,5003300 107,100 17
091592 091602 091592 091602 10,0003300 698,000 18
091592 091602 091592 091602 2,000,000 139,400 19
091692 091602 091692 091602 10,0003300 695,000 20
091792 091702 091792 091702 1,0003300 70,000 21
092192 092302 092192 092302 1,5003300 104,550 22
012293 012203 012293 012203 1,000,000 7.‡,000 23
012693 012703 012693 012703 3,000,000 220,800 24
072893 072803 072893 072803 19,000,000 1,264,600 25
072893 072803 072893 072803 4,000,000 253,600 26
072893 072803 072893 072803 2,000,000 126,800 27
072893 072803 072893 072803 2,000,000 126,800 28
072193 072803 072193 072803 10,000,000 634,000 29
072893 072803 072893 072803 6,000,000 378,600 30
072893 072803 072893 072803 18,000,000 1,135,800 31
072893 072803 072893 072803 18,000,000 1,135,800 32
4,035,632,531 215,398,174 33
FERC FORM NO.1 (ED.12-96)Page 257.1
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
LONG-TERM DEBT (Account 221,222,223 and 224)
1.Report by balance sheet account the particulars (details)concerning long-term debt included in Accounts 221,Bonds,222,
Reacquired Bonds,223,Advances from Associated Companies,and 224,Other long-Term Debt.
2.In column (a),for new issues,give Commission authorization numbers and dates.
3.For bonds assumed by the respondent,include in column (a)the name of the issuing company as well as a description of the bonds.
4.For advances from Associated Companies,report separately advances on notes and advances on open accounts.Designate
demand notes as such.Include in column (a)names of associated companies from which advances were received.
5.For receivers,certificates,show in column (a)the name of the court -and date of court order under which such certificates were
issued.
6.In column (b)show the principal amount of bonds or other long-term debt originally issued.
7.In column (c)show the expense,premium or discount with respect to the amount of bonds or other long-term debt originally issued.
8.For column (c)the total expenses should be listed first for each issuance,then the amount of premium (in parentheses)or discount.
Indicate the premium or discount with a notation,such as (P)or (D).The expenses,premium or discount should not be netted.
9.Furnish in a footnote particulars (details)regarding the treatment of unamortized debt expense,premium or discount associated with
issues redeemed during the year.Also,give in a footnote the date of the Commission's authorization of treatment other than as
specified by the Uniform System of Accounts.
Line Class and Series of Obligation,Coupon Rate Principal Amount Total expense,
No.(For new issue,give commission Authorization numbers and dates)Of Debt issued Premium or Discount
(a)(b)(c)
1 6.31%Series F Medium-Term Notes due July 28,2003 1,000,000 7,897
2 9.00%Series C Medium-Term Notes due Sept.1,2003 55,226,000 63,366
3 7.03%Series E Medium-Term Notes due Oct.15,2003 5,000,000 33,788
4 7.27%Series E Medium-Term Notes due Oct.21,2003 2,000,000 13,515
5 7.39%Series E Medium-Term Notes due Oct.21,2003 5,000,000 33,788
6 7.30%Series E Medium-Term Notes due Oct.22,2003 2,000,000 13,515
7 7.86%Series D Medium-Term Notes due Feb.16,2004 2,500,000 21,110
8 7.81%Series D Medium-Term Notes due Feb.16,2004 20,000,000 168,880
9 7.79%Series D Medium-Term Notes due Feb.16,2004 6,000,000 50,664
10 7.75%Series D Medium-Term Notes due Feb.16,2004 3,000,000 25,332
11 6.75%Series H Medium-Term Notes due Jul.15,2004 175,000,000 2,680,166
12 500,500 D
13 7.32%Series E Medium-Term Notes due Sept.3,2004 7,500,000 56,361
14 7.11%Series E Medium-Term Notes due Sept.24,2004 6,500,000 48,846
15 7.30%Series E Medium-Term Notes due Oct.22,2004 10,000,000 67,576
16 7.30%Series E Medium-Term Notes due Oct.22,2004 10,000,000 67,576
17 7.66%Series E Medium-Term Notes due Oct.22,2004 5,000,000 32,745
18 7.53%Series E Medium-Term Notes due Oct.26,2004 750,000 5,068
19 7.71%Series E Medium-Term Notes due Oct.27,2004 3,000,000 20,273
20 7.71%Series E Medium-Term Notes due Oct.27,2004 3,250,000 21,962
21 7.60%Series E Medium-Term Notes due Nov.1,2004 1,000,000 6,549
22 7.72%Series E Medium-Term Notes due Nov.2,2004 1,500,000 9,824
23 7.43%Series E Medium-Term Notes due Jan.24,2005 1,000,000 6,333
24 7.43%Series E Medium-Term Notes due Jan.24,2005 2,500,000 15,832
25 7.34%Series E Medium-Term Notes due Oct.17,2005 5,000,000 33,788
26 7.36%Series E Medium-Term Notes due Oct.17,2005 5,000,000 33,788
27 6.12%Series G Medium-Term Notes due Jan.15,2006 100,000,000 679,467
28 7.67%Series C Medium-Term Notes due Jan.10,2007 5,724,000 36,625
29 6.625%Series G Medium-Term Notes due June 1,2007 100,000,000 1,267,428
30 630,000 D
31 7.43%Series E Medium-Term Notes due Sept.11,2007 2,000,000 15,530
32 7.22%Series E Medium-Term Notes due Sept.18,2007 2,500,000 19,412
33 TOTAL 4,436,925,925 69,964,207
FERC FORM NO.1 (ED.12-96)Page 256.2
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
LONG-TERM DEBT (Account 221,222,223 and 224)(Continued)
10.Identify separate undisposed amounts applicable to issues which were redeemed in prior years.
11.Explain any debits and credits other than debited to Account 428,Amortization and Expense,or credited to Account 429,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.
AMORTIZA ION PERIOD Uutstandine LineNominalDateDateof(Total amount outstanaing without Interest for Year
of Issue Maturity Date From Date To reductionr srpamdennts held by Amount No.
(d)(e)(f)(g)
Îhn
072893 072803 072893 072803 1,000,000 63,100 1
061091 090103 061091 090103 8,705,425 938,241 2
101592 101503 101592 101503 5,000,000 351,500 3
102192 102103 102192 102103 2,000,000 145,400 4
102192 102103 102192 102103 5,000,000 369,500 5
102292 102203 102292 102203 2,000,000 146,000 6
021492 021604 021492 021604 2,500,000 196,500 7
021492 021604 021492 021604 -20,000,000 1,562,000 8
021492 021604 021492 021604 6,000,000 467,400 9
021492 021604 021492 021604 3,000,000 232,500 10
071597 071504 071597 071504 175,000,000 11,812,500 11
12
090492 090304 090492 090304 7,500,000 549,000 13
092492 092404 092492 092404 6,500,000 462,150 14
102292 102204 102292 102204 10,000,000 730,000 15
102292 102204 102292 102204 10,000,000 730,000 16
110692 102204 110692 102204 5,000,000 383,000 17
102692 102604 102692 102604 750,000 56,475 18
102792 102704 102792 102704 3,000,000 231,300 19
102792 102704 102792 102704 3,250,000 250,575 20
110692 110104 110692 110104 1,000,000 76,000 21
110292 110204 110292 110204 1,500,000 115,800 22
012293 012405 012293 012405 1,000,000 74,300 23
012293 012405 012293 012405 2,500,000 185,750 24
101592 101705 101592 101705 5,000,000 367,000 25
101592 101705 101592 101705 5,000,000 368,000 26
012296 011506 012296 011506 100,000,000 6,120,000 27
011092 011007 011092 011007 5,724,000 439,031 28
060995 060107 060995 060107 100,000,000 6,625,000 29
30
091192 091107 091192 091107 2,000,000 148,600 31
091892 091807 091892 091807 2,500,000 180,500 32
4,035,632,531 215,398,174 33
FERC FORM NO.1 (ED.12-96)Page 257.2
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001
(2)A Resubmission //
LONG-TERM DEBT (Account 221,222,223 and 224)
1.Report by balance sheet account the particulars (details)concerning long-term debt included in Accounts 221,Bonds,222,
Reacquired Bonds,223,Advances from Associated Companies,and 224,Other long-Term Debt.
2.In column (a),for new issues,give Commission authorization numbers and dates.
3.For bonds assumed by the respondent,include in column (a)the name of the issuing company as well as a description of the bonds.
4.For advances from Associated Companies,report separately advances on notes and advances on open accounts.Designate
demand notes as such.Include in column (a)names of associated companies from which advances were received.
5.For receivers,certificates,show in column (a)the name of the court -and date of court order under which such certificates were
issued.
6.In column (b)show the principal amount of bonds or other long-term debt originally issued.
7.In column (c)show the expense,premium or discount with respect to the amount of bonds or other long-term debt originally issued.
8.For column (c)the total expenses should be listed first for each issuance,then the amount of premium (in parentheses)or discount.
Indicate the premium or discount with a notation,such as (P)or (D).The expenses,premium or discount should not be netted.
9.Furnish in a footnote particulars (details)regarding the treatment of unamortized debt expense,premium or discount associated with
issues redeemed during the year.Also,give in a footnote the date of the Commission's authorization of treatment other than as
specified by the Uniform System of Accounts.
Line Class and Series of Obligation,Coupon Rate Principal Amount Total expense,
No.(For new issue,give commission Authorization numbers and dates)Of Debt issued Premiumor Discount
(a)(b)(c)
1 7.27%Series E Medium-Term Notes due Sept.24,2007 4,000,000 31,059
2 6.375%Series H Medium-Term Notes due May 15,2008 200,000,000 1,416,179
3 644,000 D
4 7.00%Series H Medium-Term Notes due Jul.15,2009 125,000,000 1,976,904
5 451,250 D
6 9.15%Series C Medium-Term Notes due Aug.9,2011 8,000,000 75,327
7 8.95%Series C Medium-Term Notes due Sept.1,2011 25,000,000 175,398
8 8.95%Series C Medium-Term Notes due Sept.1,2011 20,000,000 132,118
9 8.92%Series C Medium-Term Notes due Sept.1,2011 20,000,000 188,318
10 8.29%Series C Medium-Term Notes due Dec.30,2011 3,000,000 23,040
11 8.26%Series C Medium-Term Notes due Jan.10,2012 1,000,000 7,649
12 8.28%Series C Medium-Term Notes due Jan.10,2012 2,000,000 13,297
13 8.25%Series C Medium-Term Notes due Feb.1,2012 3,000,000 22,946
14 8.13%Series E Medium-Term Notes due Jan.22,2013 10,000,000 75,827
15 7.25%Series F Medium-Term Notes due Aug.1,2013 10,000,000 91,474
16 7.25%Series F Medium-Term Notes due Aug.1,2013 10,000,000 91,474
17 7.25%Series F Medium-Term Notes due Aug.1,2013 10,000,000 91,474
18 7.25%Series F Medium-Term Notes due Aug.1,2013 10,000,000 91,474
19 8.53%Series C Medium-Term Notes due Dec.16,2021 15,000,000 115,202
20 8.375%Series C Medium-Term Notes due Dec.31,2021 5,000,000 38,400
21 8.26%Series C Medium-Term Notes due Jan.7,2022 5,000,000 33,243
22 8.27%Series C Medium-Term Notes due Jan.10,2022 4,000,000 30,594
23 8.05%Series E Medium-Term Notes due Sept.1,2022 15,000,000 131,471
24 8.07%Series E Medium-Term Notes due Sept.9,2022 8,000,000 70,118
25 8.12%Series E Medium-Term Notes due Sept.9,2022 50,000,000 438,238
26 8.11%Series E Medium-Term Notes due Sept.9,2022 12,000,000 105,177
27 8.05%Series E Medium-Term Notes due Sept.14,2022 10,000,000 87,648
28 8.08%Series E Medium-Term Notes due Oct.14,2022 26,000,000 208,198
29 8.08%Series E Medium-Term Notes due Oct.14,2022 25,000,000 200,190
30 8.23%Series E Medium-Term Notes due Jan.20,2023 5,000,000 37,914
31 8.23%Series E Medium-Term Notes due Jan.20,2023 4,000,000 30,331
32 -81,560 P
33 TOTAL 4,436,925,925 69,964,207
FERC FORM NO.1 (ED.12-96)Page 256.3
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
LONG-TERM DEBT (Account 221,222,223 and 224)(Continued)
10.Identify separate undisposed amounts applicable to issues which were redeemed in prior years.
11.Explain any debits and credits other than debited to Account 428,Amortization and Expense,or credited to Account 429,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.
AMORTIZA ¯ION PERIOD Uutstandin9-.LineNominalDateDateof(Total amount outstanaing without Interest for Year
of Issue Maturity Date From Date To reductionr srpamdenntsheld by Amount No.
(d)(e)(f)(g)Îhn
092292 092407 092292 092407 4,000,000 290,800 1
051298 051508 051298 051208 200,000,000 12,750,000 2
3
071597 071509 071597 071509 125,000,000 8,750,000 4
5
080991 080911 080991 080911 8,000,000 732,000 6
081691 090111 081691 090111 25,000,000 2,237,500 7
081691 090111 081691 090111 20,000,000 1,790,000 8
081691 090111 081691 090111 20,000,000 1,784,000 9
123191 123011 123191 123011 3,000,000 248,700 10
010992 011012 010992 011012 1,000,000 82,600 11
011092 011012 011092 011012 2,000,000 165,600 12
011592 020112 011592 020112 3,000,000 247,500 13
012093 012213 012093 012213 10,000,000 813,000 14
072893 080113 072893 080113 10,000,000 725,000 15
072893 080113 072893 080113 10,000,000 725,000 16
072893 080113 072893 080113 10,000,000 725,000 17
072893 080113 072893 080113 10,000,000 725,000 18
121691 121621 121691 121621 15,000,000 1,279,500 19
123191 123121 123191 123121 5,000,000 418,750 20
010892 010722 010892 010722 5,000,000 413,000 21
010992 011022 010992 011022 4,000,000 330,800 22
091892 090122 091892 090122 15,000,000 1,207,500 23
090992 090922 090992 090922 8,000,000 645,600 24
091192 090922 091192 090922 50,000,000 4,060,000 25
091192 090922 091192 090922 12,000,000 973,200 26
091492 091422 091492 091422 10,000,000 805,000 27
101592 101422 101592 101422 26,000,000 2,100,800 28
101592 101422 101592 101422 25,000,000 2,020,000 29
012093 012023 012093 012023 5,000,000 411,500 30
012993 012023 012993 012023 4,000,000 329,200 31
32
4,035,632,531 215,398,174 33
FERC FORM NO.1 (ED.12-96)Page 257.3
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)p An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
L3NG-TERM DEBT (Account 221,222,223 and 224)
1.Report by balance sheet account the particulars (details)concerning long-term debt included in Accounts 221,Bonds,222,
Reacquired Bonds,223,Advances from Associated Companies,and 224,Other long-Term Debt.
2.In column (a),for new issues,give Commission authorization numbers and dates.
3.For bonds assumed by the respondent,include in column (a)the name of the issuing company as well as a description of the bonds.
4.For advances from Associated Companies,report separately advances on notes and advances on open accounts.Designate
demand notes as such.Include in column (a)names of associated companies from which advances were received.
5.For receivers,certificates,show in column (a)the name of the court -and date of court order under which such certificates were
issued.
6.In column (b)show the principal amount of bonds or other long-term debt originally issued.
7.In column (c)show the expense,premium or discount with respect to the amount of bonds or other long-term debt originally issued.
8.For column (c)the total expenses should be listed first for each issuance,then the amount of premium (in parentheses)or discount.
Indicate the premium or discount with a notation,such as (P)or (D).The expenses,premium or discount should not be netted.
9.Furnish in a footnote particulars (details)regarding the treatment of unamortized debt expense,premium or discount associated with
issues redeemed during the year.Also,give in a footnote the date of the Commission's authorization of treatment other than as
specified by the Uniform System of Accounts.
Line Class and Series of Obligation,Coupon Rate PrincipalAmount Total expense,
No.(For new issue,give commission Authorization numbers and dates)Of Debt issued Premium or Discount
(a)(b)(c)
1 7.26%Series F Medium-Term Notes due July 21,2023 27,000,000 246,981
2 7.26%Series F Medium-Term Notes due July 21,2023 11,000,000 100,622
3 7.40%Series F Medium-Term Notes due July 28,2023 2,000,000 18,295
4 7.37%Series F Medium-Term Notes due Aug.11,2023 15,500,000 141,785
5 7.23%Series F Medium-Term Notes due Aug.16,2023 15,000,000 137,211
6 7.24%Series F Medium-Term Notes due Aug.16,2023 30,000,000 274,423
7 6.75%Series F Medium-Term Notes due Sept.14,2023 5,000,000 38,250
8 6.75%Series F Medium-Term Notes due Sept.14,2023 -2,000,000 15,300
9 6.72%Series F Medium-Term Notes due Sept.14,2023 2,000,000 15,300
10 6.75%Series F Medium-Term Notes due Oct.26,2023 20,000,000 152,326
11 6.75%Series F Medium-Term Notes due Oct.26,2023 16,000,000 121,861
12 6.75%Series F Medium-Term Notes due Oct.26,2023 12,000,000 91,396
13 8.625%Series F Medium-Term Notes due Dec.13,2024 20,000,000 151,025
14 498,600 D
15 6.71%Series G Medium-Term Notes due Jan.15,2026 100,000,000 904,467
16
17
18 Pollution Control Obligations -Secured by Pledged First Mortgage Bonds:
19 Daily Adj.Rate Poll Ctrl Revenue Refunding Bonds,Moffat County,CO,Series 1994 40,655,000 874,159
20 5-5/8%Lincoln County,WY,Series due Nov.1,2021 8,300,000 228,980
21 197,125 D
22 5.65%Emery County,Utah,Series due Nov.1,2023 46,500,000 1,624,793
23 5-5/8%Emery County,Utah,Series due Nov.1,2023 16,400,000 625,551
24 389,500 D
25 Daily Adj.Rate Poll Ctrl Rev Refunding Bonds,Sweetwater County,WY,Series 1994 21,260,000 510,479
26 Daily Adj.Rate Poll Ctrl Rev Refunding Bonds,Converse County,WY,Series 1994 8,190,000 209,777
27 Daily Adj.Rate Poll Ctrl Rev Refunding Bonds,Emery County,UT,Series 1994 121,940,000 3,274,246
28 Daily Adj.Rate Poll Ctrl Rev Refunding Bonds,Carbon County,UT,Series 1994 9,365,000 206,519
29 Daily Adj.Rate Poll Ctrl Rev Refunding Bonds,Lincoln County,WY,Series 1994 15,060,000 422,858
30
31 Pollution Control Revenue Bonds:
32 Customized Purchase Poll Ctrl Rev Refndng Bonds,Sweetwater Cnty,WY,Ser.1992A 9,335,000 147,642
33 TOTAL 4,436,925,925 69,964,207
FERC FORM NO.1 (ED.12-96)Page 256.4
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
LONG-TERM DEBT (Account 221,222,223 and 224)(Continued)
10.Identify separate undisposed amounts applicable to issues which were redeemed in prior years.
11.Explain any debits and credits other than debited to Account 428,Amortization and Expense,or credited to Account 429,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-TermDebt 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.
AMORTIZA ION PERIOD Uutstanding LineNominalDateDateof(Total arnount outstandinhewithout Interest for Year
of Issue Maturity Date From Date To reductionr srpamdennts Id by Amount No.
(d)(e)(f)(g)Îhn
072293 072123 072293 072123 27,000,000 1,960,200 1
072293 072123 072293 072123 11,000,000 798,600 2
072893 072823 072893 072823 2,000,000 148,000 3
081193 081123 081193 081123 15,500,000 1,142,350 4
081693 081623 081693 081623 15,000,000 1,084,500 5
081693 081623 081693 081623 30,000,000 2,172,000 6
091493 091423 091493 091423 5,000,000 337,500 7
091493 091423 091493 091423 2,000,000 135,000 8
091493 091423 091493 091423 2,000,000 134,400 9
102693 102623 102693 102623 20,000,000 1,350,000 10
102693 102623 102693 102623 16,000,000 1,080,000 11
102693 102623 102693 102623 12,000,000 810,000 12
121394 121324 121394 121324 20,000,000 1,725,000 13
14
012396 011526 012396 011526 100,000,000 6,710,000 15
16
17
18
111794 050113 111794 050113 40,655,000 1,280,045 19
111593 110121 111593 110121 8,300,000 466,875 20
21
111593 110123 111593 110123 46,500,000 2,627,250 22
111593 110123 111593 110123 16,400,000 922,500 23
24
111794 110124 111794 110124 21,260,000 718,609 25
111794 110124 111794 110124 8,190,000 277,322 26
111794 110124 111794 110124 121,940,000 3,861,566 27
111794 110124 111794 110124 9,365,000 294,862 28
111794 110124 111794 110124 15,060,000 509,058 29
30
31
092992 040105 092992 040105 9,335,000 281,636 32
4,035,632,531 215,398,174 33
FERC FORM NO.1 (ED.12-96)Page 257.4
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
LONG-TERM DEBT (Account 221,222,223 and 224)
1.Report by balance sheet account the particulars (details)concerning long-term debt included in Accounts 221,Bonds,222,
Reacquired Bonds,223,Advances from Associated Companies,and 224,Other long-Term Debt.
2.In column (a),for new issues,give Commission authorization numbers and dates.
3.For bonds assumed by the respondent,include in column (a)the name of the issuing company as well as a description of the bonds.
4.For advances from Associated Companies,report separately advances on notes and advances on open accounts.Designate
demand notes as such.Include in column (a)names of associated companies from which advances were received.
5.For receivers,certificates,show in column (a)the name of the court -and date of court order under which such certificates were
issued.
6.In column (b)show the principal amount of bonds or other long-term debt originally issued.
7.In column (c)show the expense,premium or discount with respect to the amount of bonds or other long-term debt originally issued.
8.For column (c)the total expenses should be listed first for each issuance,then the amount of premium (in parentheses)or discount.
Indicate the premium or discount with a notation,such as (P)or (D).The expenses,premium or discount should not be netted.
9.Furnish in a footnote particulars (details)regarding the treatment of unamortized debt expense,premium or discount associated with
issues redeemed during the year.Also,give in a footnote the date of the Commission's authorization of treatment other than as
specified by the Uniform System of Accounts.
Line Class and Series of Obligation,Coupon Rate Principal Amount Total expense,
No.(For new issue,give commission Authorization numbers and dates)Of Debt issued Premium or Discount
(a)(b)(c)
1 Customized Purchase Poll Ctrl Rev Refndng Bonds,Sweetwater Cnty,WY,Ser.1992B 6,305,000 138,478
2 Customized Purchase Poll Ctrl Rev Refndng Bonds,Converse County,WY,Series 1992 22,485,000 194,271
3 Customized Purchase Poll Ctrl Rev Refndng Bonds,Sweetwater Cnty,WY,Ser.1988B 11,500,000 84,822
4 Customized Purchase Poll Ctrl Rev Refndng Bonds,Converse County,WY,Series 1988 17,000,000 155,970
5 Daily Adjustable Rate Poll Ctrl Revenue Bonds,Sweetwater County,WY,Series 1984 15,000,000 122,887
6 105,000 D
7 Weekly Adj.Rate Poll Ctrl Rev Refndng Bonds,Sweetwater County,WY,Ser.1990A 70,000,000 660,750
8 Customized Purchase Poll Ctrl Rev Refunding Bonds,Emery County,UT,Series 1991 45,000,000 872,505
9 Customized Purchase Poll Ctrl Rev Refunding Bonds,Lincoln Cnty,WY,Series 1991 45,000,000 771,836
10 Flexible Rate Demand Poll Ctrl Revenue Bonds,City of Forsyth,MT,Series 1986 8,500,000 304,824
11 Customized Purchase Poll Ctrl Rev Refndng Bonds,Sweetwater Cnty,WY,Ser.1988A 50,000,000 422,443
12 Customized Purchase Poll Ctrl Rev Refndng Bonds,City of Forsyth,MT,Series 1988 45,000,000 380,198
13 Customized Purchase Poll Ctrl Rev Refndng Bonds,City of Gillette,WY,Ser.1988 41,200,000 351,905
14 Daily Adj.Rate Environ.Imprvmnt Rev Bonds,Converse County,WY,Series 1995 5,300,000 132,043
15 Daily Adj.Rate Environ.Imprvmnt Rev Bonds,Lincoln County,WY,Series 1995 22,000,000 404,262
16 Daily Adj.Rate Environ.Imprvmnt Rev Bonds,Sweetwater County,WY,Series 1995 24,400,000 225,000
17 6.15%EmeryCounty,Utah,Series due September 1,2030 12,675,000 556,549
18 178,464 D
19
20 Less:Funds held by Trustee
21
22 SUBTOTAL ACCOUNT 221 3,898,212,000 51,045,553
23
24
25
26 Reacquired Bonds (Account 222)
27
28
29
30
31 Advances from Associated Companies (Account 223)
32 Advance from Pacific Minerals,Inc.(PMI)
33 TOTAL 4,436,925,925 69,964,207
FERC FORM NO.1 (ED.12-96)Page 256.5
Name of Respondent This Report is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
LONG-TERM DEBT (Account 221,222,223 and 224)(Continued)
10.Identify separate undisposed amounts applicable to issues which were redeemed in prior years.
11.Explain any debits and credits other than debited to Account 428,Amortization and Expense,or credited to Account 429,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.
AMORTIZA:¯ION PERIOD Uutstanding LineNominalDateDateof(Total amount outstandinhewithout Interest for Year
of Issue Maturity Date From Date To reductionr srpamoennts Id by Amount No.
(d)(e)(f)(g)Îhnd
092992 120105 092992 120105 6,305,000 190,221 1
092992 070106 092992 070106 22,485,000 678,369 2
010188 010114 011488 010114 11,500,000 367,631 3
010188 010114 011488 010114 17,000,000 565,471 4
120184 120114 120184 120114 15,000,000 427,130 5
6
072590 070115 072590 070115 70,000,000 2,359,342 7
052391 070115 052391 070115 45,000,000 1,468,206 8
011791 010116 011791 010116 45,000,000 1,640,897 9
120186 120116 120186 120116 8,500,000 258,062 10
010188 010117 011488 010117 50,000,000 1,775,666 11
010188 010118 011488 010118 45,000,000 1,438,555 12
010188 010118 011488 010118 41,200,000 1,369,565 13
111795 110125 111795 110125 5,300,000 173,251 14
111795 110125 111795 110125 22,000,000 719,154 15
121495 110125 121495 110125 24,400,000 793,764 16
092496 090130 092496 090130 12,675,000 779,512 17
18
19
-2,005,894 20
21
3,672,744,531 186,225,382 22
23
24
25
26
27
28
29
30
31
32
4,035,632,531 215,398,174 33
FERC FORMNO.1 (ED.12-96)Page 257.5
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
L JNG-TERM DEBT (Account 221,222,223 and 224)
1.Report by balance sheet account the particulars (details)concerning long-term debt included in Accounts 221,Bonds,222,
Reacquired Bonds,223,Advances from Associated Companies,and 224,Other long-Term Debt.
2.In column (a),for new issues,give Commission authorization numbers and dates.
3.For bonds assumed by the respondent,include in column (a)the name of the issuing company as well as a description of the bonds.
4.For advances from Associated Companies,report separately advances on notes and advances on open accounts.Designate
demand notes as such.Include in column (a)names of associated companies from which advances were received.
5.For receivers,certificates,show in column (a)the name of the court -and date of court order under which such certificates were
issued.
6.In column (b)show the principal amount of bonds or other long-term debt originally issued.
7.In column (c)show the expense,premium or discount with respect to the amount of bonds or other long-term debt originally issued.
8.For column (c)the total expenses should be listed first for each issuance,then the amount of premium (in parentheses)or discount.
Indicate the premium or discount with a notation,such as (P)or (D).The expenses,premium or discount should not be netted.
9.Furnish in a footnote particulars (details)regarding the treatment of unamortized debt expense,premium or discount associated with
issues redeemed during the year.Also,give in a footnote the date of the Commission's authorization of treatment other than as
specified by the Uniform System of Accounts.
Line Class and Series of Obligation,Coupon Rate Principal Amount Total expense,
No.(For new issue,give commission Authorization numbers and dates)Of Debt issued Premium or Discount
(a)(b)(c)
1 Advance from Demand Side Receivable,Inc.(DSR)
2 8-1/4%Debentures Series C payable to PacifiCorp Capital I 223,712,000 7,487,809
3 7.70%Debentures Series D payable to PacifiCorp Capital II 139,176,000 4,586,685
4
5 SUBTOTAL ACCOUNT 223 362,888,000 12,074,494
6
7
8 Other Long-Term Debt (Account 224)
9 8.55%Quarterly Income Debt Securities (QUIDS)(Junior Subordinated
10 Deferrable Interest Debentures,Series B)55,825,925 2,520,556
11 8.375%Quarterly Income Debt Securities (QUIDS)(Junior Subordinated
12 Deferrable Interest Debentures,Series A)120,000,000 4,323,604
13
14 SUBTOTAL ACCOUNT 224 175,825,925 6,844,160
15
16
17
18
19
20 Long-Term DebtAuthorized but Unissued
21
22
23
24
25
26
27
28
29
30
31
32
33 TOTAL 4,436,925,925 69,964,207
FERC FORM NO.1 (ED.12-96)Page 256.6
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001
(2)A Resubmission //
LONG-TERM DEBT (Account 221,222,223 and 224)(Continued)
10.Identify separate undisposed amounts applicable to issues which were redeemed in prior years.
11.Explain any debits and credits other than debited to Account 428,Amortization and Expense,or credited to Account 429,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 respondenthas 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 respondenthas 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.
AMORTIZATION PERIOD Outstanding LineNominalDateDateof(Total amount outstandinhg without Interest for Year
of Issue Maturity Date From Date To reductionr srparnndenntseld by Amount No.
(d)(e)(f)(g)Îh)(i)
1
061196 063036 061196 063036 223,712,000 18,456,240 2
080497 093037 080497 093037 139,176,000 10,716,552 3
4
362,888,000 29,172,792 5
6
7
8
9
100595 123125 100595 123125 10
11
053195 063035 053195 063035 12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
H29c&>LW 629¾¾4,035,632,531 215,398,174 33
FERC FORM NO.1 (ED.12-96)Page 257.6
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001
(2)A Resubmission //
RECONCILIATION OF REPORTED NET INCOME WITH TAXABLE INCOME FOR FEDERAL INCOME TAXES
1.Report the reconciliation of reported net income for the year with taxable income used in computing Federal income tax accruals and 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 return 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 member of a group which files a consolidated Federal tax return,reconcile reported net income with taxable net income as if a
separate return were to be field,indicating,however,intercompany amounts to be eliminated in such a consolidated retum.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 meet a 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 Particulars (Details)Amount
No.(a)(b)
1 Net Income for the Year (Page 117)328,632,870
2
3
4 Taxable Income Not Reported on Books
5 Contributions in Aid of Construction 3,680,247
6 Gain/Loss on Property Disposition -19,721,249
7 Misc.Items on Return Unaccrued 875,292
8 Cholla APS Safe Harbor Lease (Disc.)149,964
9 Deductions Recorded on Books Not Deducted for Return
10 Federal Income Tax -83,954,282
11 Equity in Earningsof Subsidiary Companies 22,252,385
12 Merger Credits/Centralia Giveback -7,348,628
13 Other Items 192,209,216
14 Income Recorded on Books Not Included in Return
15 Allowance for Funds Used During Construction 10,849,753
16 Deferred Income Tax 144,488,121
17 Redding Contract 550,046
18 Other Items 3,333,324
19 Deductions on Return Not Charged Against Book Income
20 Removal Costs 13,815,502
21 Final Reclamation -301,509
22 Pension/Retirement Accrued 114,043,568
23 Merger Transaction Cost 4,733,952
24 Utility Asset Writedown 12,738,221
25 ADR Repair Allowance 1,715,001
26 Other Items 371,713,502
27 Federal Tax Net Income -240,903,664
28 Show Computation of Tax:
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
FERC FORM NO.1 (ED.12-96)Page 261
Blank Page
(Next Page is:262)
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
TAXESACCRUED,PREPAID AND CHARGED DURING YEAR
1.Give particulars (details)of the combined prepaid and accrued tax accounts and show the total taxes charged to operations and other accounts during
the year.Do not include gasoline and other sales taxes which have been charged to the accounts to which the taxed material was charged.If the
actual,or estimated amounts of such taxes are know,show the amounts in a footnote and designate whether estimated or actual amounts.
2.Include on this page,taxes paid during the year and charged direct to final accounts,(not charged to prepaid or accrued taxes.)
Enter the amounts in both columns (d)and (e).The balancing of this page is not affected by the inclusion of these taxes.
3.Include in column (d)taxes charged during the year,taxes charged to operations and other accounts through (a)accruals credited to taxes accrued,
(b)amounts credited to proportions of prepaid taxes chargeable to current year,and (c)taxes paid and charged direct to operations or accounts other
than accrued and prepaid tax accounts.
4.List the aggregate of each kind of tax in such manner that the total tax for each State and subdivision can readily be ascertained.
Line Kind of Tax BALANCE AT BE 3INNING OF YEAR C ar ed a ds Adjust-
No.(See instruction 5)Taxes Accrued Prepaid Taxes Dunng During ments(Account 236)(Include m Account 165)Year Year(a)(b)(c)(d)(e)(f)
1 Federal:
2 Income 94,664,717 -84,316,282 34,085,024 7,755,560
3 FICA 268,223 24,780,703 28,654,916 3,605,990
4 Unemployment 392,479 2,648,610 2,949,533 18,744
5 Highway Motor Vehicle
6 Diesel Fuel 149,932 207,105 357,037
7 Excise Tax -Coal 136,448 6,671,199 6,769,517
8 Excise Tax -Superfund
9 SUBTOTAL 95,611,799 -50,008,665 72,816,027 11,380,294
10
11
12
13 Arizona:
14 Property 1,387,072 2,518,305 2,646,224
15 Income Tax 506,179 -279,000 105,861
16 Road Use
17 Unemployment
18 SUBTOTAL 1,893,251 2,239,305 2,752,085
19
20
21
22 California:
23 Property 863,356 1,632,919 1,682,030
24 Unemployment
25 Employee Training Fund
26 Bank/Corp.Franchise 989,333 -307,000 160,271
27 PUC Use Tax 96,146 96,146
28 Sales and Use Tax 7,653 261 33,542 30,337
29 Motor Vehicle 72,591 72,591
30 Local Franchise Tax 580,403 771,420 729,318
31 SUBTOTAL 2,440,745 2,266,337 2,773,898 30,337
32
33
34
35 Colorado
36 Property 2,952,720 2,816,498 2,769,218
37 Income 637,113 356,092
38 SUBTOTAL 3,589,833 2,816,498 3,125,310
39
40
41 TOTAL 139,540,035 9,709,586 58,115,802 195,243,132 6,706,406
FERC FORM NO.1 (ED.12-96)Page 262
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001
(2)A Resubmission //
TAXES ACCRUED,PREPAIDAND CHARGED DURING YEAR (Continued)
5.If any tax (exclude Federal and State income taxes)-covers more then one year,show the required information separately for each tax year,
identifying the year in column (a).
6.Enter all adjustments of the accrued and prepaid tax accounts in column (f)and explain each adjustment in a foot-note.Designate debit adjustments
by parentheses.
7.Do not include on this page entries with respect to deferred income taxes or taxes collected through payroll deductions or otherwise pending
transmittal of such taxes to the taxing authority.
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 409.1
pertaining to electric operations.Report in column (I)the amounts charged to Accounts 408.1 and 109.1 pertaining to other utility departments and
amounts charged to Accounts 408.2 and 409.2.Also shown in column (1)the taxes charged to utility plant or other balance sheet accounts.
9.For any tax apportioned to more than one utility department or account,state in a footnote the basis (necessity)of apportioning such tax.
BALANCE AT IND OF YEAR DISTRIBUTION OF TAXES CHARGED Line
(Taxes accrued Prepaid Taxes Electric Extraordinary Items Adjustments to Ret Other No.Account 236)(Incl.in Account 165)(Account 408.1,409.1)(Account 409.3)Earmngs (Account 439)
(g)(h)(i)(j)(k)(I)
1
-15,918,028 -83,954,282 -362,000 2
24,780,703 3
110,300 2,648,610 4
5
207,105 6
38,130 6,671,199 7
8
-15,769,598 -56,524,969 6,516,304 9
10
11
12
13
1,259,152 2,518,305 14
121,318 -277,000 -2,000 15
16
17
1,380,470 2,241,305 -2,000 18
19
20
21
22
814,245 1,601,077 31,842 23
24
25
522,062 -305,000 -2,000 26
96,146 27
4,709 28
72,591 29
622,505 771,420 30
1,963,521 2,067,497 198,579 31
32
33
34
35
3,000,000 2,815,454 1.044 36
993,205 37
3,993,205 2,815,454 1,044 38
39
40
10,725,128 10,540,607 41,521,220 16,594,318 41
FERC FORM NO.1 (ED.12-96)Page 263
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission I /
TAXES ACCRUED,PREPAIDAND CHARGED DURING YEAR
1.Give particulars (details)of the combined prepaid and accrued tax accounts and show the total taxes charged to operations and other accounts during
the year.Do not include gasoline and other sales taxes which have been charged to the accounts to which the taxed material was charged.If the
actual,or estimated amounts of such taxes are know,show the amounts in a footnote and designate whether estimated or actual amounts.
2.Include on this page,taxes paid during the year and charged direct to final accounts,(not charged to prepaid or accrued taxes.)
Enter the amounts in both columns (d)and (e).The balancing of this page is not affected by the inclusion of these taxes.
3.Include in column (d)taxes charged during the year,taxes charged to operations and other accounts through (a)accruals credited to taxes accrued,
(b)amounts credited to proportions of prepaid taxes chargeable to current year,and (c)taxes paid and charged direct to operations or accounts other
than accrued and prepaid tax accounts.
4.List the aggregate of each kind of tax in such manner that the total tax for each State and subdivision can readily be ascertained.
Line Kind of Tax BALANCE AT BE 3INNING OF YEAR Chaar ed Oaids Adjust-
No.(See instruction 5)Yaxes Accrued Prepaid Ïaxes Dunng Dunng ments(Account 236)(Include m Account 165)Year Year(a)(b)(c)(d)(e)(f)
1 Idaho:
2 Property 1,088,635 2,883,496 2,357,584
3 Income 1,913,245 -624,000 529,681
4 KWH 273 12,150 11,780
5 Unemployment
6 Regulatory Commission 165,034 353,547 377,027
7 Diesel Fuel
8 Motor Vehicle 8,410 8,410
9 Road Use
10 Local Franchise Tax
11 SUBTOTAL 3,002,153 165,034 2,633,603 3,284,482
12
13
14 Montana:
15 Property 1,717,632 2,216,386 2,826,755
16 Unemployment
17 Corporate License 1,485,119 -268,000 214,426
18 Local Franchise Tax
19 Consumer Council
20 Motor Vehicle
21 Regulatory Commission
22 Wholesale Energy 140,448 111,714
23 SUBTOTAL 3,202,751 2,088,834 3,152,895
24
25 Nevada
26 Property
27 Unemployment
28 CEP
29 Employee Business Tax
30 SUBTOTAL
31
32 New Mexico:
33 Property 3,975 7,672 7,809
34 Income -27,125 -22,000 20,174
35 SUBTOTAL -23,150 -14,328 27,983
36
37 Oregon:
38 Property 6,601 7,310,007 15,175,458 15,811,401
39 Unemployment
40 Other
41 TOTAL 139,540,035 9,709,586 58,115,802 195,243,132 6,706,406
FERC FORM NO.1 (ED.12-96)Page 262.1
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
TAXES ACCRUED,PREPAID AND CHARGED DURING YEAR (Continued)
5.If any tax (exclude Federal and State income taxes)-covers more then one year,show the required information separately for each tax year,
identifying the year in column (a).
6.Enter all adjustments of the accrued and prepaid tax accounts in column (f)and explain each adjustment in a foot-note.Designate debit adjustments
by parentheses.
7.Do not include on this page entries with respect to deferred income taxes or taxes collected through payroll deductions or otherwise pendingtransmittalofsuchtaxestothetaxingauthority.
8.Report in columns (i)through (I)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 and
amounts charged to Accounts 408.2 and 409.2.Also shown in column (l)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 (neœssity)of apportioning such tax.
BALANCE AT IND OF YEAR DISTRIBUTION OF TAXES CHARGED Line
(Taxes accrued Prepaid Taxes Electric Extraordinary Items Adjustments to Ret.Other No.Account 236)(Incl.in Account 165)(Account 408.1,409.1)(Account 409.3)Earmngs (Account 439)
(g)(h)(i)(j)(k)(I)
1
1,614,547 2,881,396 2,100 2
759,564 -621,000 -3,000 3
643 12,150 4
5
188,514 353,547 6
7
8,410 8
9
10
2,374,754 188,514 2,272,546 361,057 11
12
13
14
1,107,263 2,216,146 240 15
16
1,002,693 -267,000 -1,000 17
18
19
20
21
28,734 140,448 22
2,138,690 2,089,594 -760 23
24
25
26
27
28
29
30
31
32
3,838 7,672 33
-69,299 -22,000 34
-65,461 -14,328 35
36
37
7,939,439 14,852,150 323,307 38
39
40
10,725,128 10,540,607 41,521,220 16,594,318 41
FERC FORM NO.1 (ED.12-96)Page 263.1
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
TAXES ACCRUED,PREPAID AND CHARGED DURING YEAR
1.Give particulars (details)of the combined prepaid and accrued tax accounts and show the total taxes charged to operations and other accounts during
the year.Do not include gasoline and other sales taxes which have been charged to the accounts to which the taxed material was charged.If the
actual,or estimated amounts of such taxes are know,show the amounts in a footnote and designate whether estimated or actual amounts.
2.Include on this page,taxes paid during the year and charged direct to final accounts,(not charged to prepaid or accrued taxes.)
Enter the amounts in both columns (d)and (e).The balancing of this page is not affected by the inclusion of these taxes.
3.Include in column (d)taxes charged during the year,taxes charged to operations and other accounts through (a)accruals credited to taxes accrued,
(b)amounts credited to proportions of prepaid taxes chargeable to current year,and (c)taxes paid and charged direct to operations or accounts other
than accrued and prepaid tax accounts.
4.List the aggregate of each kind of tax in such manner that the total tax for each State and subdivision can readily be ascertained.
Line Kind of Tax BALANCE AT BE 3\NNING OF YEAR Chaar ed a ds Adjust-No.(See instruction 5)Taxes Accrued Prepaid Taxes Dunng Dunng ments(Account 236)(Include in Account 165)Year Year
(a)(b)(c)(d)(e)(f)
1 Regulatory Commission 623,469 2,519,811 2,528,454
2 Excise Tax 8,751,576 3,104,000 2,303,823 -8,079,000
3 City of Portland 99,632 -67,000 9,018
4 Motor Vehicle 171,111 171,111
5 Tri Met
6 Lane County
7 Local Franchise Tax 252,262 16,370,917 16,294,877
8 SUBTOTAL 9,110,071 7,933,476 37,274,297 37,118,684 -8,079,000
9
10 Utah:
11 Property 283,114 29,564,226 30,168,189
12 income 6,427,273 -4,495,000 2,196,358
13 Unemployment
14 Regulatory Commission 1,209,966 2,556,599 2,693,261
15 Special Fuel
16 Motor Vehicle 363,769 363,769
17 Road Use 2,463,516 2,617,722
18 Misc.Municipal
19 Environmental
20 Local Franchise Tax
21 Gross Receipts Tax 1,440,480 2,617,001 2,601,331
22 SUBTOTAL 8,150,867 1,209,966 30,606,595 40,486,424 2,617,722
23
24 Washington:
25 Property 5,219,093 4,149,460 4,868,402
26 Unemployment
27 Business 13,408 37,320 41,399
28 Public Utility Tax (Rev.)1,043,329 6,950,350 7,110,603
29 Regulatory Commission 96,093 340,413 350,464
30 Compensating 5,169 156,203 157,672
31 Environmental
32 Local Franchise Tax 21,064 221,627 220,858
33 Centralia Production Tax
34 Motor Vehicle 147,651 147,651
35 SUBTOTAL 6,302,063 96,093 11,846,821 12,895,580 157,672
36
37 Washington D.C.:
38 Unemployment
39 Franchise 2,697
40 SUBTOTAL 2,697
41 TOTAL 139,540,035 9,709,586 58,115,802 195,243,132 6,706,406
FERC FORM NO.1 (ED.12-96)Page 262.2
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
TAXES ACCRUED,PREPAID AND CHARGED DURING YEAR (Continued)
5.If any tax (exclude Federal and State income taxes)-covers more then one year,show the required information separately for each tax year,
identifying the year in column (a).
6.Enter all adjustments of the accrued and prepaid tax accounts in column (f)and explain each adjustment in a foot-note.Designate debit adjustments
by parentheses.
7.Do not include on this page entries with respect to deferred income taxes or taxes collected through payroll deductions or otherwise pending
transmittal of such taxes to the taxing authority.
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 409.1
pertaining to electric operations.Report in column (I)the amounts charged to Accounts 408.1 and 109.1 pertaining to other utility departments and
amounts charged to Accounts 408.2 and 409.2.Also shown in column (1)the taxes charged to utility plant or other balance sheet accounts.
9.For any tax apportioned to more than one utility department or account,state in a footnote the basis (necessity)of apportioning such tax.
BALANCEAT IND OF YEAR DISTRIBUTION OF TAXES CHARGED Line
(Taxes accrued PrepaidTaxes Electric Extraordinary Items Adjustments to Ret.Other No.Account 236)(Incl.in Account 165)(Account 408.1,409.1)(Account 409.3)Earnmgs (Account 439)
(g)(h)(i)(j)(k)(I)
632,112 2,519,811 1
1,472,753 3,127,000 -23,000 2
23,614 -66,000 -1,000 3
171,111 4
5
6
328,302 16,370,917 7
1,824,669 8,571,551 34,284,067 2,990,229 8
9
10
-320,849 27,541,280 2,022,946 11
-264,085 -4,474,000 -21,000 12
13
1,346,628 2,556,599 14
15
363,769 16
154,206 17
18
19
20
1,456,150 2,617,001 21
1,025,422 1,346,628 25,684,281 4,922,314 22
23
24
4,500,150 4,064,206 85,254 25
26
9,329 37,320 27
883,076 6,950,350 28
106,144 340,413 29
6,638 30
31
21,833 221,627 32
33
147,651 34
5,421,026 106,144 11,236,183 610,638 35
36
37
38
2,697 39
2,697 40
10,725,128 10,540,607 41,521,220 16,594,318 41
FERC FORMNO.1 (ED.12-96)Page 263.2
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
TAXES ACCRUED,PREPAID AND CHARGED DURING YEAR
1.Give particulars (details)of the combined prepaid and accrued tax accounts and show the total taxes charged to operations and other accounts during
the year.Do not include gasoline and other sales taxes which have been charged to the accounts to which the ta×ed material was charged.If the
actual,or estimated amounts of such taxes are know,show the amounts in a footnote and designate whether estimated or actual amounts.
2.Include on this page,taxes paid during the year and charged direct to final accounts,(not charged to prepaid or accrued taxes.)
Enter the amounts in both columns (d)and (e).The balancing of this page is not affected by the inclusion of these taxes.
3.Include in column (d)taxes charged during the year,taxes charged to operations and other accounts through (a)accruals credited to taxes accrued,
(b)amounts credited to proportions of prepaid taxes chargeable to current year,and (c)taxes paid and charged direct to operations or accounts other
than accrued and prepaid tax accounts.
4.List the aggregate of each kind of tax in such manner that the total tax for each State and subdivision can readily be ascertained.
Line Kind of Tax BALANCE AT BE 3\NNING OF YEAR Chaar ed a ds Adjust-No.(See instruction 5)Taxes Accrued Prepaid Ïaxes Dunng Dunng ments(Account 236)(Include m Account 165)Year Year(a)(b)(c)(d)(e)(f)
1
2
3 Wyoming:
4 Property 3,511,312 5,007,142 6,515,967
5 Unemployment
6 Regulatory Commission 305,017 632,787 655,540
7 Glenrock Production Tax 707,656 328,236
8 Local Franchise Tax 7,654 820,762 752,449
9 Sales and Use Tax 266,635 807,082 599,381
10 Motor Vehicle 154,010 154,010
11 Special Fuel
12 Environmental
13 SUBTOTAL 4,493,257 305,017 6,614,701 9,213,284 599,381
14
15 Goshute Possessory 7,006 7,006
16 Sho-Ban Possessory 132,862 132,712
17 Navajo Business Activity 14,328 14,328
18 Navajo Possessory Interest 42,816 27,767 56,699
19 Ute Possessory Interest 9,314 9,314
20 Crow Utility Tax 36,368 36,369
21 Umatilla 43,055 43,055
22 Franchise Taxes Assoc.
23 with Unbilled Revenues 1,684,514 3,000,000 852,263
24 Misc.Taxes 928,799 928,799
25 MSHA Assessments 54,450 54,450
26 Items Posted In Error 5,497,854 5,497,854
27 SUBTOTAL 1,763,698 9,751,804 7,596,480
28
29
30
31
32
33
34
35
36
37
38
39
40
41 TOTAL 139,540,035 9,709,586 58,115,802 195,243,132 6,706,406
FERC FORM NO.1 (ED.12-96)Page 262.3
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001
(2)A Resubmission //
TAXES ACCRUED,PREPAID AND CHARGED DURING YEAR (Continued)
5.If any tax (exclude Federal and State income taxes)-covers more then one year,show the required information separately for each tax year,
identifying the year in column (a).
6.Enter all adjustments of the accrued and prepaid tax accounts in column (f)and explain each adjustment in a foot-note.Designate debit adjustments
by parentheses.
7.Do not include on this page entries with respect to deferred income taxes or taxes collected through payroll deductions or otherwise pending
transmittal of such taxes to the taxing authority.
8.Report in columns (i)through (l)how the taxes were distributed.Report in column (l)only the amounts charged to Accounts 408.1 and 409.1
pertaining to electric operations.Report in column (I)the amounts charged to Accounts 408.1 and 109.1 pertaining to other utility departments and
amounts charged to Accounts 408.2 and 409.2.Also shown in column (I)the taxes charged to utility plant or other balance sheet accounts.
9.For any tax apportioned to more than one utility department or account,state in a footnote the basis (necessity)of apportioning such tax.
BALANCE AT IND OF YEAR DISTRIBUTION OF TAXES CHARGED Line
(Taxes accrued Prepaid Taxes Electric Extraordinary Items Adjustments to Ret.Other NoAccount236)(Incl.in Account 165)(Account 408.1,409.1)(Account 409.3)Earnings (Account 439)
(g)(h)(i)(j)(k)(1)
1
2
3
2,002,488 4,797,025 210,116 4
5
327,770 632,787 6
379,420 7
75,967 820,762 8
58,934 9
154,010 10
11
12
2,516,809 327,770 5,617,787 996,913 13
14
7,006 15
150 132,862 16
14,328 17
13,884 27,767 18
-99 9,314 19
72,738 36,369 20
43,055 21
22
3,832,251 3,000,000 23
928,798 24
54,450 25
5,497,854 26
3,918,924 9,751,803 27
28
29
30
31
32
33
34
35
36
37
38
39
40
10,725,128 10,540,607 41,521,220 16,594,318 41
FERC FORM NO.1 (ED.12-96)Page 263.3
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001
(2)A Resubmission //
ACCUMULATED DEFERRED INVESTMENT TAX CREDITS (Account 255)
Report below information applicable to Account 255.Where appropriate,segregate the balances and transactions by utility and
nonutility operations.Explain by footnote any correction adjustments to the account balance shown in column (g).Include in column (i)
the average period over which the tax credits are amortized.
Line Account Balance at Beginning Allocations to
No Subd sions of Year Deferred for Year Current Year's income Adjustments
a (b)Account No.Amount Account No.Amount(c)(d)(e)(f)(9)
1 Electric Utility
2 3%18,284 411.4 18,28A
3 4%2,438,960 411.4 324,814
4 7%
5 10%78,705,450 411.4 &420 5,464,614
6
7 Idaho 1,301,381 411.4 65,436
8 TOTAL 82,464,075 5,873,146
9 Other (List separately
and show 3%,4%,7%,
10%and TOTAL)
10
11 Nonutility
12 10%26,762,874 420 2,065,25E
13
14 Total Nonutility 26,762,874 2,065,25E
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.12-1 9)Page 266
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
ACCUMULATED DEFERRED INVESTMENT TAX CRED TS (Account 255)(continued)
Balance at End Average Period ADJUSTMENT EXPLANATION Line
of Year of Allocation NotoIncome
(h)(i)
35 2
2,114,146 35 3
4
73,240,836 30,35 5
6
1,235,945 32 7
10
11
24,697,616 12
13
24,697,616 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
ERC FORM NO.1 (ED 12-89)Page 267
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)pAn Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
OTHER DEFFERED CREDITS (Account 253)
1.Report below the particulars (details)callec for concerning other deferred credits.
2.Fcr any deferred credit being amortized,stow the period of amcrtization.
3.Minor items (5%of the Balance End of Yet r for Account 253 or -tmounts less than $10,000,whichever ii greater)may be grouped by classes.
Line Description and Other Balance at DEBITS Balance at
No.Deferred Credits Beginning of Year Contra Amount Credits End of Year
Account(a)(b)(c)(d)(e)(f)
1 Cogeneration Bonds -Sunnyside 413,417 826,834 826,834 413,417
2
3 Working Capital Deposit DG&T 946,000 143 3,702,000 4,607,000 1,851,000
4
5 Working Capital and Coal Pile
6 Deposits from Provo City 273,000 143 546,000 546,000 273,000
7
8 Working capital deposit from UAMPS 539,000 143 2,150,000 2,686,000 1,075,000
9
10 Reclamation Costs -Dave Johnston
11 Coal Mine 37,529,519 151 10,727,751 22,166 26,823,934
12
13 Reclamation Costs -Centralia Coal
14 Mine 10,992,758 151 10,992,758
15
16 Reclamation Costs -Trapper Mine 1,995,586 151 2,432,181 2,664,329 2,227,734
17
18 Reclamation Costs -Deer Creek 151
19 Mine 1,171,326 58,467 232,060 1,344,919
20
21 Reclamation Costs -Deseret Mine 1,406,898 151 60,206 330,428 1,677,120
22
23 Reclamation Costs -
24 Trail Mountian Mine 1,109,783 151 36,955 1,146,738
25
26 Deferred Compensation -PPL 9,833,725 131 1,931,493 667,820 8,570,052
27
28 401(k)Plan administrative costs 265,107 131 1,140,097 1,045,747 170,757
29
30 Building Rent Revenues -Portland -3,102 931 3,953 3,489 -3,566
31
32 Centralia Mine Coal Cost Refund 208,824 Various 702,143 493,319
33
34 Mill Fork Tract Lease Bonus Paymnt 15,120,000 131 15,120,000 10,080,000 10,080,000
35
36 Skookumchuck Timber Harvest Contrt Various 283,699 283,699
37
38 Pension administrative costs -76,673 131 1,154,603 880,040 -351,236
39
40 Transmission Service Deposit 3,922,425 142 27,849,825 32,302,800 8,375,400
41
42 Other Deferred Credits 2,850,000 456 5,700,000 5,700,000 2,850,000
43
44 Other Deferred Credits 3,798,500 456 8,748,918 7,455,418 2,505,000
45
46 MCI F.O.G.wire lease 560,758 454 3,359,432 3,358,409 559,735
47 TOTAL 117,912,368 1,141,392,768 1,367,040,066 343,559,666
FERC FORM NO.1 (ED.12-94)Page 269
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001
(2)A Resubmission //
O 'HER DEFFERED CREDITS (Account 253)
1.Report below the particulars (details)callet for concerning other deferred credits.
2.F(r any deferred credit being amortized,st ow the period of amcrtization.
3.M nor items (5%of the Balance End of Yet r for Account 253 or amounts less than $10,000,whichever il greater)may be gro iped by classes.
Line Description and Other Balance at DEBITS Balance at
No.Deferred Credits Beginning of Year Contra Amount Credits End of Year
Account(a)(b)(c)(d)(e)(f)
1
2 Firth Cogeneration Buyout 1,745,400 131 407,260 29,090 1,367,230
3
4 Monsanto Contract 3,333,324 456 3,333,324
5
6 Redding Contract 8,250,040 447 30,050,063 29,500,067 7,700,044
7
8 Footcreek Contract 1,944,062 2,012,882 1,875,242 1,806,422
9
10 University of Wyoming Electric
11 Prepayment 2,639,448 445 4,502,222 2,742,590 879,816
12
13 Lakeview Buyout 275,000 131 55,000 220,000
14
15 Environmental Liabilities -
16 Non Current 4,939,091 182 5,077,447 138,356
17
18 Environmental Liabilities -182 4,013,633 5,950,642 1,937,009
19 Centralia Plant
20
21 Environmental Liabilities -182 3,249,917 6,493,694 3,243,777
22 Centralia Mine
23
24 Stock incentive Plan -1999 71,056 123 123,570 98,842 46,328
25
26 Stock Incentive Plan -2000 441,143 123 433,078 152,055 160,120
27
28 Stock Incentive Plan -2001 123 58,878 58,878
29
30 Stock Inæntive Plan -2002 123 3,721 124,111 120,390
31
32 Wyoming Joint Powers Water
33 Board Settlement 4,800,000 7,200,000 2,400,000
34
35 FAS 133 Derivative Net Liability
36 Non-Current 182 976,918,991 1,228,328,446 251,409,455
37
38 Oregon Residential -267,794 536,064 803,858
39
40 Oregon Commercial &Irrigation -7,906 15,806 23,712
41
42 Washington Residential -215,964 432,341 648,305
43
44 Washington Commercial &Irrigation -1,057 3,385 4,442
45
46 Comp Reduct 1,909,674 7,933,704 8,645,223 2,621,193
47 TOTAL 117,912,368 1,141,392,768 1,367,040,066 343,559,666
FERC FORM NO.1 (ED.12-94)Page 269.1
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
ACCUMULATED DEFERRED INCOMETAXES -ACCELERATED AMORTIZATION PROPER Y (Account 281)
1.Report the information called for below concerning the respondent's accounting for deferred income taxes rating to amortizable
property.
2.F 3r other (Specify),include deferrals relating to other income and deductions.
CHANGES DURING YEARLineAccountBalanceat
No.Beginning of Year Amounts Debited Amounts Credited
to Account 410.1 to Account 411.1
(a)(b)(c)(d)
1 Accelerated Amortization (Account 281)
2 Electric
3 Defense Facilities 2,305,874 334,272
4 Pollution Control Facilities
5 Other
6
7
8 TOTAL Electric (Enter Total of lines 3 thru 7)2,305,874 334,272
9 Gas
10 Defense Facilities
11 Pollution Control Facilities
12 Other
13
14
15 TOTAL Gas (Enter Total of lines 10 thru 14)
16
17 TOTAL (Acct 281)(Total of 8,15 and 16)2,305,874 334,272
18 Classification of TOTAL
19 Federal Income Tax 2,030,015 334,272
20 State Income Tax 275,859
21 Local Income Tax
NOTEL
VERC FORM NO.1 (ED.12-96)Page 272
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
ACCUMULATED DEFERRED INCOME TAXES _ACCELERATED AMORTIZATION PROPERTY (Account 281)(Continued)
3.Use footnotes as required.
CHANGES DURING YEAR ADJUSTMENTS
Amounts Debited Amounts Credited Debits Credits Balance at Line
to Account 410.2 to Account 411.2 Account Amount Account Amount End of Year No.
Credited Debited(e)(f)(g)(h)(k)
1,971,602 3
4
5
6
7
1,971,602 8
9
10
11
12
13
14
15
16
1,971,602 17
'18
281 275,859 1,971,602 19
281 275,859 20
21
NOTES (Continued)
ERC FORM NO.1 (ED.12-96)Page 273
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001
(2)A Resubmission //
ACCUMULATE 3 DEFFERED INCOME TAXES -OTHER PROPERTY (Account 282)
1.Repon the information called for below concerning the respondent's accounting for deferred income taxes rating to property not
subject to accelerated amodization
2.For other (Specify),include deferrals relating to other income and deductions.
CHANGES DURING YEAR
Line Account Balance at
No.Beginning of Year Amounts Debited Amounts Credited
to Account 410.1 to Account 411.1
(a)(b)(c)(d)
1 Account 282
2 Electric 968,231,462 10,516,177 6,972,236
3 Gas
4 FAS 109 542,437,146
5 TOTAL (Enter Total of lines 2 thru 4)1,510,668,608 10,516,177 6,972,236
6 Nonutility 8,779,741
7
8
9 TOTAL Account 282 (Enter Total of lines 5 thru 1,519,448,349 10,516,177 6,972,236
10 Classification of TOTAL
11 Federal income Tax 1,458,546,418 10,516,177 6,972,236
12 State Income Ta× 60,901,931
13 Local Income Tax
NOTES
ERC FORM NO.1 (ED.12-96)Page 274
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission I /
ACCUMULATED DEFERRED INCOME TAXES -OTHER PROPERTY(Account 282)(Continued)
3.Use footnotes as required.
CHANGES DURING YEAR ADJUSTMENTS
Amounts Debited Amounts Credited Debits Credits Balance at Line
to Account 410.2 to Account 411.2 Account Amount Account Amount End of Year No.
Credited Debited(e)(g)(h)(¡)(k)
282 60,901,931190 282 283 79,527,71E 990,401,188 2
3
182 &254 22,382,272 182 &254 15,054,157 535,109,030 4
83,284,204 94,581,873 1,525,510,21E 5
10,84E 882,564 190 62,581 7,845,444 6
7
8
10,84E 882,564 83,346,785 94,581,872 1,533,355,662 9
-,'
10
10,84E 882,564 22,444,854 94,581,872 1,533,355,662 11
60,901,931 12
13
NOTES (Continued)
FERC FORM NO.1 (ED.12-96)Page 275
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission I /
ACCUMULATED DEFFERED INCOME TAXES -OTHER (Account 283)
1.Report the information called for below concerning the respondent's accounting for deferred income taxes relating to amounts
recorded in Account 283.
2.Far other (Specify),include deferrals relating to other income and deductions.
CHANGES DURING YEAR
Line Account Balance at Amounts Debited Amounts Óredited
No.Beginning of Year to Account 410.1 to Account 411.1(a)(b)(c)(d)
1 Account 283
2 Electric
3 UPL/PPL Merger Amortization 3,935,631
4 Loss on Reacquired Debt 14,019,598 1,065,483 3,916,165
5 Expense of Pollution Control
6 Property Taxes (California and 5,500,902
7
8 Other 6,415,663 93,040,173 38,669,461
9 TOTAL Electric (Total of lines 3 thru 8)29,871,794 94,105,656 42,585,626
10 Gas
11
12
13
14
15
16
17 TOTAL Gas (Total of lines 11 thru 16)
18 Nonutility -Investments 4,468 4,468
19 TOTAL (Acct 283)(Enter Total of lines 9,17 and 18)29,876,262 94,105,656 42,590,094
20 Classification of TOTAL
21 Federal Income Tax 27,214,170 94,105,656 42,590,094
22 State Income Tax 2,662,092
23 Local Income Tax
NOTES
ERC FORM NO.1 (ED.12-96)Page 276
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
ACCUMULATED DEFERRED INCOME TAXES-OTHER(Account 283)(Continued)
3.Provide in the space below explanations for Page 276 and 277.Include amounts relating to insignificant items listed under Other.
4.Use footnotes as required.
CHANGES DURING YEAR ADJUSTMENTS
Amounts Debited Amounts Credited Debits Credits Balance at Line
to Account 410.2 to Account 411.2 ACccouen Amount ADcecuendt Amount End of Year No.
(e)(f)rdt (h)(i)(j)(k)
2
282 5,073,078 -1,137,447 3
190 190 11,168,916 4
5
190 5,500,902 6
7
190 97,676,023 190 24,409,103 -12,480,545 8
108,250,003 24,409,103 -2,449,076 9
10
11
12
13
14
15
16
17
18
108,250,003 24,409,103 -2,449,076 19
20
108,250,003 21,747,011 -2,449,076 21
2,662,092 22
23
NOTES (Continued)
ERC FORM NO.1 (ED.12-96)Page 277
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001
(2)A Resubmission //
OTHER REGULATORY LIABILITIES (Account 254)
1.Reporting below the particulars (Details)called for conceming other regulatory liabilities wNich are created through the rate-making
acticns of regulatory agencies (and not includable in other amounts)
2.F3r regulatory Liabilities being amortized show period of amortization in column (a).
3.19 inor 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 Description and Purpose of DEBITS Balance at
No.Other Regulatory Liabilities Account Amount Credits End of Year
Credited(a)(b)(c)(d)(e)
1 1996 Depreciation Study 403 14,109,405 3,527,352
2
3 FAS 109 Income Tax Regulatory Liab 182.3 54,792,505 51,634,017 41,331,388
4
5 Centralia Gain Giveback 456.2 60,829,535 175,641,315 125,532,748
6
7 Merger Credits Various 19,416,091 47,232,572 27,816,481
8
9 Utah Rate Refund Various 11,217,000 38,190,000 26,973,000
10
11 BPA Washington Balancing Account Various 4,631,576 4,631,576
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 160,364,536 317,329,480 229,812,545
FERC FORM NO.1 (ED.12-94)Page 278
Blank Page
(Next Page is:300)
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001
(2)A Resubmission //
E .ECTRIC OPERATING REVENUES (Account 400)
1.Report below operating revenues for each prescribed account,and manufactured gas revenues in total.
2.Report number of customers,columns (f)and (g),on the basis of meters,in addition to the number of flat rate accounts;except that
where separate meter readings are added for billing purposes,one customer should be counted for each group of meters added.The
-average number of customers means the average of twelve figures at the close of each month.
3.If increases or decreases from previous year (columns (c),(e),and (g)),are not derived from previously reported figures,explain any
inconsistencies in a footnote.
Line Title of Account OPERATING REVENUES
No Amount for Year Amount for Previous Year
(a)(b)(c)
1 Sales of Electricity
2 (440)Residential Sales 861,838,043 834,996,675
3 (442)Commercial and Industrial Sales
4 Small (or Comm.)(See Instr.4)747,478,882 700,213,182
5 Large (or Ind.)(See Instr.4)720,008,423 714,220,302
6 (444)Public Street and Highway Lighting 14,846,317 13,990,710
7 (445)Other Sales to Public Authorities 19,301,159 17,873,190
8 (446)Sales to Railroads and Railways
9 (448)Interdepartmental Sales
10 TOTAL Sales to Ultimate Consumers 2,363,472,824 2,281,294,059
11 (447)Sales for Resale 2,052,663,496 1,736,151,126
12 TOTAL Sales of Electricity 4,416,136,320 4,017,445,185
13 (Less)(449.1)Provision for Rate Refunds 26,972,980 1,503,068
14 TOTAL Revenues Net of Prov.for Refunds 4,389,163,340 4,015,942,117
15 Other Operating Revenues
16 (450)Forfeited Discounts 6,353,184 4,015,689
17 (451)Miscellaneous Service Revenues 7,052,319 7,126,746
18 (453)Sales of Water and Water Power
19 (454)Rent from Electric Property 15,452,307 12,237,674
20 (455)Interdepartmental Rents
21 (456)Other Electric Revenues 152,061,819 69,448,472
22
23
24
25
26 TOTAL Other Operating Revenues 180,919,629 92,828,581
27 TOTAL Electric Operating Revenues 4,570,082,969 4,108,770,698
FERC FORM NO.1 (ED.12-96)Page 300
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
E.ECTRIC OPERATING REVENUES (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.
MEGAWATT HOURS SOLD AVG.NO.CUSTOMERS PER MONTH Line
Amount for Year Amount for Previous Year Number for Year Number for Previous Year No.
(d)(e)(f)(g)
13.290,940 13 375,862 1,282,221 1,262 293 2
13,752,540 13,471,314 179,664 175,420 4
19,956,202 20,749,637 34,974 35,004 5
148,433 138,347 4,272 4,218 6
560,347 565,313 28 28 7
8
9
47,708,462 48,300,473 1,501,159 1,476,963 10
22,850,898 29,953,491 98 119 11
70,559,360 78,253,964 1,501,257 1,477,082 12
13
70,559,360 78,253,964 1,501,257 1,477,082 14
Line 12,column (b)includes $1,484,287 of unbilled revenues.
Line 12,column (d)includes 166,241 MWH relating to unbilled revenues
FERC FORM NO.1 (ED.12-96)Page 301
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
SALES OF ELECTRICITY BY RATE SCHEDULES
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
appliæble 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.F3r any rate schedule having a fuel adjt stment clause state in a footnote the estimated additional revenue billed pursuant thereto.
6.Raport amount of unbilled revenue as oi end of year for each applicable revenue account subheading.
Line Number and litie of Mate schedule MWh Sold Nevenue Average NUmber KWh of Sales e hn e er
No-(a)(b)(c)of Cus omers Per stomer
1 Account 440 Residential Sales
2 Centralia Refund CA-PPL 19
3 Charges Between Cust.CA-PPL 1,190
4 Low Income CA-PPL 22,094 1,314,925 2,026 10,905 0.0595
5 Multi-Family CA-PPL 434 29,048 15 28,933 0.0669
6 Multi-Family Submetered CA-PPL 1,264 79,459 16 79,000 0.0629
7 Outdoor Area Light CA-PPL 448 73,681 470 953 0.1645
8 Clean Air Wood Heat CA-PPL 28,904 2,126,449 2,129 13,576 0.0736
9 PacifiCorp Owned Property CA-PPL 1
10 Residential Service CA-PPL 312,082 22,139,688 29,268 10,663 0.0709
11 AIC Charge ID-PPL 1,497
12 BPA Balancing Account ID-PPL -5,043,162
13 Charges Between Cust.ID-PPL 2,247
14 Customer Owned Energy ID-PPL 2 515 1 2,000 0.2575
15 Line Ext.Annual Inc.Cost ID-PPL -5,730
16 Merger Credits ID-PPL -122,169
17 Misc.Charges &Credits ID-PPL 4,197
18 Residential Service ID-PPL 268,058 22,097,865 28,857 9,289 0.0824
19 Res.Ser.Time of Use ID-PPL 290,427 18,778,667 15,981 18,173 0.0647
20 Security Area Lighting ID-PPL 270 36,050 174 1,552 0.1335
21 Bluesky Energy OR-PPL 125,189 2,361
22 BPA Balancing Account OR-PPL -2,658,047
23 Charges Between Cust.OR-PPL 22,799
24 Cont.Dollar Min.Guar.OR-PPL 288
25 Line Ext.80%Guarantee OR-PPL 553
26 Misc.Charges &Ser.OR-PPL 10,708
27 New Service OR-PPL 1
28 Energy Cost Rec.Amort.OR-PPL -6,414,006
29 Outdoor Area Lighting OR-PPL 5,329 398,489 3,865 1,379 0.0748
30 Net Metering OR-PPL 113 5,952 17 6,647 0.0527
31 PacifiCorp Owned Property OR-PPL 5
32 Residential Service OR-PPL 5,035,654 334,524,870 424,908 11,851 0.0664
33 Three Phase Service OR-PPL 6,214 433,075 269 23,100 0.0697
34 AIC Charge UT-UPL 15,933
35 Bluesky Energy UT-UPL 112,400 2,242
36 Charges Between Cust.UT-UPL 14,340
37 Misc.Charges &Credits UT-UPL 1,583
38 Mobile Home UT-UPL 11,362 631,325 11 1,032,909 0.0556
39 New Service UT-UPL 2
40 Rate Refund UT-UPL -10,272,593
41 TOTAL Billed 47,874,704 2,515,935,185 1,501,15E 31,892 0.0526
42 Total Unbilled Rev.(See Instr.6)-166,242 1,484,287 C C -0.0089
43 TOTAL 47,708,462 2,517,419,472 1,501,156 31,781 0.0527
FERO FORM NO.1 (ED.12-95)Page 304
NarneofRespondent ThisRepodis:DateofRepod YearofRepod
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
SALES OF ELECTRICITY BY RATE SCHEDULES
1.Report below for each rate schedule in effect during the year the MWH of electricity sold,revenue,average number of customer,average Kwh per
customer,and average revenue per Kwh,excluding date for Sales for Resale which is reported on Pages 310-311.
2.Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues,"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.Vuhere 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 billings are made monthly).
5.F3r any rate schedule having a fuel adjt stment clause state in a footnote the estimated additional revenue billed pursuant thereto.
6.Repodamountofunbilled revenue aso end ofyearforeach applicablerevenueaccountsubheadirxy
Line Number and lit of Mate schedule MWh bold Revenue Av rca eyNumbserKWh o aleesr hn e er
1 Account440(Continued)
2 LirwaExt UT-UPL 16,635
3 Line Ext.80%Guarantee UT-UPL 102
4 Monthly Min.Guarantee UT-UPL 240
5 Residential Service UT-UPL 4,903,100 331,532,301 577,412 8,492 0.0676
6 TimeofDayOption UT-UPL 91 7,222 7 13,000 0.0794
7 Home Electronic Lifeline UT-UPL 101,595 6,968,133 15,158 6,702 0.0686
8 Security Area Lighting UT-UPL 3,584 715,902 3,953 907 0.1997
9 Temp.SenticeUT-UPL 116
10 Bluesky Energy WA-PPL 13,863 266
11 BPA Balancing Account WA-PPL -2,973,853
12 Charges BeNveen Cust VVA-PPL 937
13 Line Ext.80%Guarantee WA-PPL 549
14 A4isc.Charges &CreditsVVA-PPL 3,662 198,791 821 4,460 0.0543
15 Outdoor Area Light WA-PPL 1,424 143,521 1,411 1,009 0.1008
16 Residential Service WA-PPL 1,462,005 78,547,021 97,139 15,051 0.0537
17 Three Phase ServiaaVVA-PPL 3,441 200,145 136 25,301 0.0582
18 Bluesky EnergyVVY-PPL 30,540 638
19 BlueskyEnergyVVY-UPL 1,492 34
20 Centralia Refund WY-PPL -1,269,658
21 Centralia Refund WY-UPL -158,926
22 Charges BehNeenCust VVY-PPL 1,622
23 Charges Between Cust.WY-UPL 6,427
24 Investment &Maint.Poles WY-UPL 15 1
25 Line Ext.Annual Inc.Cost WY-PPL 308
26 Alisc.Charges &ServioeVVY-UPL 99
27 NewService\AŒ-PPL 1
28 OptionalSemiceVVY-UPL 46 2,695 3 15,333 110586
29 Optional Service WY-PPL 114,227 6,177,221 5,132 22,258 0.0541
30 Outdoor Area Light WY PPL 1,460 136,998 1,389 1,051 0.0938
31 Exp.Partial Req.Service WY-PPL 27 1,730 3 9,000 0.0641
32 ResidentialServios VVY-PPL 661,538 43,022,972 82,259 8,042 0.0650
33 Residential Service WY-UPL 97,293 7,874,770 10,681 9,109 0.0809
34 Security Area LightingVVY-UPL 98 24,127 107 916 0.2462
35 Three Phase Service WY-UPL 5 417 1 5,000 0.0834
36 Three Phase ServiasVVY-PPL 710 43,067 18 39,444 0.0607
37 University of Wyoming WY-PPL 417
38 Unbilled Revenue CA-PPL -6,984 -489,000 0.0700
39 Unbilled Revenue ID-PPL 3,862 4,000 0.0010
40 Unbilled Revenue OR-PPL -85,492 -2,840,173 0.0332
41 T(UTAL Billed 47,874,704 2,515,935,185 1,501,156 31,892 0.0526
42 Total Unbilled Rev.(See Instr.6)-166,242 1,484,287 C C -0.0089
43 TOTAL 47,708,462 2,517,419,472 1,501,15E 31,781 0.0527
FER(:FORM NO.1 (ED.12-95)Page 304.1
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001
(2)A Resubmission //
SALES OF ELECTRICITY BY RATE SCHEDULES
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.VVhere 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 aillings are made monthly).
5.F 3r any rate schedule having a fuel adjt stment clause state in a footnote the estimated additional revenue billed pursuant thereto.
6.Raport amount of unbilled revenue as o1 end of year for each applicable revenue account subheading.
Line Number and IItle of Rate schedule MWh Sold Revenue Average Number KWh of Sales K.__gevnue PerofCustomersPerCustomerKvvhSoldNo-(a)(b)(c)(d)(e)(f)
1 Account 440 (Continued)
2 Unbilled Revenue UT-UPL 58,878 5,742,000 0.0975
3 Unbilled Revenue WA-PPL -6,927 -206,328 0.0298
4 Unbilled Revenue WY-PPL -10,746 -478,864 0.0446
5 Unbilled Revenue WY-UPL 1,388 99,000 0.0713
6 Less Multiple Billings CA-PPL -904
7 Less Multiple Billings ID-PPL -369
8 Less Multiple Billings OR-PPL -10,721
9 Less Multiple Billings UT-UPL -9,411
10 Less Multiple Billings WA-PPL -3,009
11 Less Multiple Billings WY-PPL -2,787
12 Less Multiple Billings WY-UPL -186
13
14 Total Acct.440 Residential 13,290,940 851,565,470 1,282,219 10,366 0.0641
15
16 Account 442.1 Comrnercial Sales
17 Charges Between Cust.CA-PPL 59,188
18 Water Heating Service CA-PPL 340 26,564 38 8,947 0.0781
19 Contr.DollarMin.Guar.CA-PPL 4,625
20 Gen.Service 20KW &Over CA-PPL 66,650 5,976,370 850 78,412 0.0897
21 General Senrice Flat Rate CA-PPL 809 97,071 69 11,725 0.1200
22 General Service CA-PPL 56,558 5,440,589 6,342 8,918 0.0962
23 G.S.100 KW &Over Opt.CA-PPL 89,517 6,504,655 227 394,348 0.0727
24 G.S.T&U Over 1000kw CA-PPL 54,100 2,998,402 10 5,410,000 0.0554
25 Line Ext.80%Guarantee CA-PPL 20,006
26 Misc.Charges &Services CA-PPL 2
27 Outdoor Area Light CA-PPL 1,007 158,297 639 1,576 0.1572
28 Line Ext.80%Guarantee ID-PPL 399
29 BPA Balancing Account ID-PPL -262,691
30 Charges Between Customers ID-PPL 86,346
31 Space Heating ID-PPL 11,998 851,820 335 35,815 0.0710
32 G.S.Dist.Volt.T&U ID-PPL 1,278 66,193 1 1,278,000 0.0518
33 Gen.Ser.High Voltage ID-PPL 32,093 1,408,190 3 10,697,667 0.0439
34 Gen.Ser.Large Power ID-PPL 174,155 10,090,933 832 209,321 0.0579
35 Gen.Ser.Large Farm ID-PPL 19,827 1,228,339 180 110,150 0.0620
36 Gen.Ser.Small Power ID-PPL 77,751 6,756,211 4,377 17,764 0.0869
37 Gen.Ser.Small Farm ID-PPL 12,708 1,101,578 1,026 12,386 0.0867
38 Line Ext.40%Guarantee ID-PPL 1,442
39 Line Ext.80%Guarantee ID-PPL 29,303
40 Merger Credits ID-PPL -66,337
41 TOTAL Billed 47,874,704 2,515,935,185 1,501,15E 31,892 0.0526
42 Total Unbilled Rev.(See Instr.6)-166,242 1,484,287 C C -0.0089
43 TOTAL 47,708,462 2,517,419,472 1,501,15E 31,781 0.0527
FERG FORM NO.1 (ED.12-95)Page 304.2
Name of Respondent This R ort Is:Date of Report Year of Report(1)An Original (Mo,Da,Yr)2001PacifiCorpDec.31,(2)A Resubmission //
SALES OF ELECTRICITY BY RATE SCHEDULES
1.Report below for each rate schedule in effect during the year the MWH of electricity sold,revenue,average number of customer,average Kwh per
customer,and average revenue per Kwh,excluding date for Sales for Resale which is reported on Pages 310-311.
2.Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues,"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.
Line Number and I Itle of Mate schedule MWh Sold Revenue Average Number KWh of Sales ne er
No (a)(b)(c)(somers Per ustomer
1 Account 442.1 (Continued)
2 Misc.Charges &Credits ID-PPL -2,058
3 Line Ext.80%Guarantee ID-PPL 5,836
4 Security Area Lighting ID-PPL 281 66,142 223 1,260 0.2354
5 1000KW &Over OR-PPL 76,635 3,385,331 84 912,321 0.0442
6 Bluesky Energy OR-PPL 95,082 49
7 BPA Balancing Account OR-PPL -37,283
8 Charges Between Cust.OR-PPL 898,737
9 Cont.Dollar Min.Guar.OR-PPL 11,392
10 General Service Farm OR-PPL 56,077 1,846,482 7,564 7,414 0.0329
11 Gen.Ser.Flat Rate OR-PPL 16,449 1,063,583 859 19,149 0.0647
12 Gen.Ser.Manual Billing OR-PPL 2 132 1 2,000 0.0660
13 General Service OR-PPL 2,055,842 133,740,980 66,243 31,035 0.0651
14 Gen.Ser.1000KW &Over OR-PPL 57,054 2,318,821 2 28,527,000 0.0406
15 General Service Farm OR-PPL 13,612 616,688 126 108,032 0.0453
16 Gen.Ser.Less 1000KW OR-PPL 1,673,477 83,144,685 2,234 749,094 0.0497
17 G.S.Time of Use 1000KW OR-PPL 498,306 21,633,075 68 7,328,029 0.0434
18 Line Ext.60%Guar.OR-PPL 15,433
19 Line Ext.80%Guar.OR-PPL 241,534
20 Misc.Charges &Ser.OR-PPL 19,087 2
21 Energy Cost Rec.Amort.OR-PPL -6,125,408
22 Outdoor Area Lighting OR-PPL 13,294 1,021,514 5,210 2,552 0.0768
23 Par.Req.Over 1000kw OR-PPL 97 73,691 1 97,000 0.7597
24 Rec.Field Lighting OR-PPL 920 72,203 106 8,679 0.0785
25 Temp.Serviœ OR-PPL -865
26 AIC Charge UT-UPL 10,511
27 Line Ext.80%Guar.UT-UPL 615
28 Line Ext.Applicant Built UT-UPL -8,107
29 Bluesky Energy UT-UPL 673 5
30 Charges Between Cust.UT-UPL 480,200
31 Space Heating UT-UPL 17,045 1,383,837 526 32,405 0.0812
32 Time of Day Option UT-UPL 148,220 10,138,332 1,251 118,481 0.0684
33 Time/Day Less 10,000KW UT-UPL 216 15,809 3 72,000 0.0732
34 Dist.Voltage UT-UPL 4,863,261 249,078,452 9,700 501,367 0.0512
35 Dist.Volt.Small Cust.UT-UPL 946,070 63,677,055 49,881 18,967 0.0673
36 Time of Day Opt.High Volt.UT-UP 6,048 244,433 1 6,048,000 0.0404
37 Time of Day Lagoon Schd.UT-UPL 7,330 295,170 1 7,330,000 0.0403
38 High Voltage UT-UPL 241,561 8,487,083 32 7,548,781 0.0351
39 Gen.Ser.Fixed Use UT-UPL 2,241 185,610 134 16,724 0.0828
40 Line Ext.AGR Annual Guar.UT-UPL 84,177
41 TOTAL Billed 47,874,704 2,515,935,185 1,501,15E 31,897 0.0526
42 Total Unbilled Rev.(See Instr.6)-166,242 1,484,287 C C -0.0089
43 TOTAL 47,708,462 2,517,419,472 1,501,15E 31,781 0.0527
FERt:FORM NO.1 (ED.12-95)Page 304.3
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
SALES OF ELECTRICITY BY RATE SCHEDULES
1.Report below for each rate schedule in effect during the year the MWH of electricity sold,revenue,average number of customer,average Kwh per
customer,and average revenue per Kwh,excluding date for Sales for Resale which is reported on Pages 310-311.
2.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 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 aillings are made monthly).
5.F3r 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.
Line Number and I Itle of Rate schedule MWh Sold Revenue Average Number KWh of bales Revenue Per
of Customers Per Customer KWh SoldNo(a)(b)(c)(d)(e)(f)
1 Account 442.1 (Continued)
2 Line Ext.Annual Incurred Cost UT 51,172
3 Line Ext.AGA UT-UPL 3
4 Misc.Charges &Ser.UT-UPL 69,169
5 Line Ext.80%Guarantee UT-UPL 101,891
6 Contract Dollar UT-UPL 21,506
7 Outdoor Lighting UT-UPL 7,616 574,940 222 34,306 0.0755
8 Rent Revenue T&D UT-UPL 718 3
9 Rate Refund UT-UPL -9,183,654
10 Security Area Lighting UT-UPL 9,838 1,664,493 5,215 1,886 0.1692
11 Supplemantary Power UT-UPL 9,441 481,253 1 9,441,000 0.0510
12 Traffic Other Signal Ser.UT-UPL 1,962 114,374 293 6,696 0.0583
13 AIC Charge WA-PPL 669
14 Bluesky Energy WA-PPL 44 1
15 BPA Balancing Account WA-PPL -102,734
16 Charges Between Cust.WA-PPL 59,867
17 Water Heating Service WA-PPL 229 16,997 41 5,585 0.0742
18 Cont.Dollar Min.Guar.WA-PPL 3,024
19 Cont.Water Heating Ser.WA-PPL 383 28,348 89 4,303 0.0740
20 General Service Farm WA-PPL 47,827 2,867,571 3,178 15,049 0.0600
21 General Service Flat Rate WA-PPL 1,514 112,890 162 9,346 0.0746
22 General Service Seasonal WA-PPL 332 61,538 136 2,441 0.1854
23 General Service WA-PPL 435,302 24,493,293 12,050 36,125 0.0563
24 Gen.Ser.1000KW &Over WA-PPL 143,621 5,774,679 26 5,523,885 0.0402
25 G.S.Farm Under 1000KW WA-PPL 62,991 2,768,036 73 862,890 0.0439
26 G.S.Under 1000KW WA-PPL 629,235 27,954,547 752 836,749 0.0444
27 Line Ext.80%Guarantee WA-PPL 35,632
28 Outdoor Area Lighting WA-PPL 2,812 267,519 1,625 1,730 0.0951
29 Rec.Feild Lighting WA-PPL 367 23,905 35 10,486 0.0651
30 Water Heating Churches WA-PPL 239 13,334 9 26,556 0.0558
31 Line Ext.Applicant Built WY-PPL 644
32 Bluesky Energy WY-PPL 593 6
33 Centralia Refund WY-PPL -1,626,912
34 Centralia Refund WY-UPL -179,817
35 Charges Between Cust.WY-UPL 27,663
36 Charges Between Cust.WY-PPL 401,163
37 Water Heating Service WY-PPL 8 380 2 4,000 0.0475
38 Cont.Dollar Min.Guar.WY-PPL 5,785
39 General Service Fixed Use WY-UPL 279 33,630 35 7,971 0.1205
40 General Service Flat Rate WY-UPL 2 193 1 2,000 0.0965
41 TOTAL Billed 47,874,704 2,515,935,185 1,501,15E 31,892 0.0526
42 Total Unbilled Rev.(See Instr.6)-166,242 1,484,287 C C -0.0089
43 TOTAL 47,708,462 2,517,419,472 1,501,156 31,781 0.0527
FERG FORM NO.1 (ED.12-95)Page 304.4
Name of Respondent This R ort Is:Date of Report Year of Report
(1)An Original (Mo,Da,Yr)2001PacifiCorpDec.31,(2)A Resubmission //
SALES OF ELECTRICITY BY RATE SCHEDULES
1.Report below for each rate schedule in effect during the year the MWH of electricity sold,revenue,average number of customer,average Kwh per
customer,and average revenue per Kwh,excluding date for Sales for Resale which is reported on Pages 310-311.
2.Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues,"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 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 aillings are made monthly).
5.F3r 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.
Line Number and I Itle of Mate schedule MWh Sold Revenue Average Number KWh of Sales hn e er
No-(a)(b)(c)of Cus omers Per stomer
1 Account 442.1 (Continued)
2 General Service Flat Rate WY-PPL 842 92,399 221 3,810 0.1097
3 Gen.Ser.Manual Billing WY-UPL 426 31,814 3 142,000 0.0747
4 Gen.Ser.Single Meter WY-PPL 8 1,214 2 4,000 0.1518
5 Gen.Ser.Single Meter WY-UPL 87,149 6,666,106 2,042 42,678 0.0765
6 General Service WY-UPL 79 5,561 9 8,778 0.0704
7 General Service WY-PPL 534,371 29,863,050 18,173 29,405 0.0559
8 Investment &Maint.Poles WY-UPL 14 1
9 Gen.Ser.100-999KWWY-PPL 370,084 16,773,022 385 961,257 0.0453
10 Gen.Ser.Industrial Rate WY-PPL 11,135 390,200 1 11,135,000 0.0350
11 Gen.Ser.Optional WY-UPL 12,768 636,740 7 1,824,000 0.0499
12 G.S.T&U 1000KW Over WY-PPL 81,929 3,030,420 10 8,192,900 0.0370
13 Line of Ext.60%Guarantee WY-PPL 300
14 Line of Ext.80%Guarantee WY-UPL 14,956
15 Line of Ext.80%Guarantee WY-PPL 89,836
16 Outdoor Area Light WY-PPL 4,348 403,110 ,2,020 2,152 0.0927
17 Outdoor Nightime Lighting WY-UPL 43 7,627 2 21,500 0.1774
18 Recreational Field Lighting WY-PP 537 32,782 54 9,944 0.0610
19 Security Area Light Ser.WY-UPL 320 75,176 143 2,238 0.2349
20 University of Wyoming WY-PPL 2,246 67,398 72 31,194 0.0300
21 Unbilled Revenue CA-PPL -3,525 -279,000 0.0791
22 Unbilled Revenue ID-PPL 3,193 223,000 0.0698
23 Unbilled Revenue OR-PPL -46,191 -1,418,000 0.0307
24 Unbilled Revenue UT-UPL 77,908 5,142,000 0.0660
25 Unbilled Revenue WA-PPL -23,157 -972,000 0.0420
26 Unbilled Revenue WY-PPL -10,602 -375,000 0.0354
27 Unbilled Revenue WY-UPL 1,802 98,000 0.0544
28 Less Multiple Billings CA-PPL -1,083
29 Less Multiple Billings ID-PPL -599
30 Less Multiple Billings OR-PPL -13,962
31 Less Multiple Billings UT-UPL -6,084
32 Less Multiple BillingsWA-PPL -2,234
33 Less Multiple BillingsWY-PPL -2,564
34 Less Multiple BillingsWY-UPL -146
35
36 Total Account 442.1 Commercial 13,752,540 738,295,228 179,665 76,545 0.0537
37
38 Account 442.2 Industrial Sales
39 Charges Between Cust.CA-PPL 1,269
40 Gen.Ser.20KW &Over CA-PPL 1,179 133,873 21 56,143 0.1135
41 TOTAL Billed 47,874,704 2,515,935,185 1,501,15E 31,892 0.0526
42 Total Unbilled Rev.(See instr.6)-166,242 1,484,287 C C -0.0089
43 TOTAL 47,708,462 2,517,419,472 1,501,15E 31,781 0.0527
FERO FORM NO.1 (ED.12-95)Page 304.5
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001
(2)A Resubmission //
SALES OF ELECTRICITY BY RATE SCHEDULES
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
300401.If the sales under any rate schedule are classified in more than one revenue account,List the rate schedule and sales data under each
applbable revenue account subheading.
3.VVhere 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 3illings are made monthly).
5.F3r any rate schedule having a fuel adjt stment clause state in a footnote the estim;ted additional revenue billed pursuant thereto.
6.Raport amount of unbilled revenue as oi end of year for each applicable revenue account subheading.
Line Number and I Itle of Mate schedule MWh Sold Revenue Average Number KWh of Sales ev nue Per
of Customers Per Customer h SoldNo-(a)(b)(c)(d)(e)(f)
1 Account 442.2 (Continued)
2 General Service CA-PPL 1,039 100,385 111 9,360 0.0966
3 Gen.Ser.100KW &Over CA-PPL 10,457 841,754 22 475,318 0.0805
4 G.S.Time/Use 1000KW CA-PPL 53,404 3,019,446 7 7,629,143 0.0565
5 Outdoor Area Lighting CA-PPL 22 3,102 9 2,444 0.1410
6 BPA Balancing Account CA-PPL -3,587,105
7 Charges Between Customers ID-PPL 3,419
8 Space Heating ID-PPL 299 21,695 7 42,714 0.0726
9 Monsanto Chem.Co.Cont.ID-PPL 1,333,051 24,671,278 1 1,333,051,000 0.0185
10 NU Industries Contract ID-PPL 121,888 4,022,288 2 60,944,000 0.0330
11 Gen.Ser.High Voltage ID-PPL 55,719 2,417,208 15 3,714,600 0.0434
12 Gen.Ser.Large Power ID-PPL 87,657 4,515,753 119 736,613 0.0515
13 Gen.Ser.Large Farm ID-PPL 7,663 424,616 40 191,575 0.0554
14 Gen.Ser.Small Power ID-PPL 8,127 698,104 389 20,892 0.0859
15 Gen.Ser.Small Farm ID-PPL 2,967 269,982 290 10,231 0.0910
16 Line Ext.40%Guarantee ID-PPL 2,978
17 Line Ext.80%Guarnatee ID-PPL 2,519
18 Line Ext.Annual Inc.Cost ID-PPL 2,940
19 Merger Credits ID-PPL -24,356
20 Misc.Charges &Credits ID-PPL 3,161
21 Security Area Lighting ID-PPL 23 5,418 24 958 0.2356
22 Trafic &Other Signal Ser.ID-PPL 24 2,527 3 8,000 0.1053
23 1000KW &Over OR-PPL 246,407 10,089,349 77 3,200,091 0.0409
24 Bluesky Energy OR-PPL 8,467 1
25 BPA Balancing Account OR-PPL 224
26 Charges Between Cust.OR-PPL 65,386
27 Cont.Dollar Min.Guar.OR-PPL 60
28 General Service Farm OR-PPL 116 8,544 154 753 0.0737
29 General Sentice Flat Rate OR-PPL 4 743 4 1,000 0.1858
30 Gen.Ser.Manual Billing OR-PPL 5 3,572 1 5,000 0.7144
31 General Senrice OR-PPL 89,691 6,098,204 1,808 49,608 0.0680
32 G.S.1000KW &Over OR-PPL 792,551 30,983,943 3 264,183,667 0.0391
33 Gen.Ser.Large Farm OR-PPL 1,554 23,537 4 388,500 0.0151
34 Gen.Ser.Less 1000KW OR-PPL 389,721 20,265,436 385 1,012,262 0.0520
35 G.S.T&U 1000kw OR-PPL 1,949,546 80,574,088 109 17,885,743 0.0413
36 Line Ext.80%Guar.OR-PPL 952
37 Energy Cost Rec.Amort.OR-PPL -5,217,378
38 Outdoor Area Lighting OR-PPL 677 48,764 215 3,149 0.0720
39 Part.Req.Over 1000kw OR-PPL 149,784 7,270,179 4 37,446,000 0.0485
40 Small Partial Req.Service OR-PPL 79 40,490 2 39,500 0.5125
41 TOTAL Billed 47,874,704 2,515,935,185 1,501,156 31,892 0.0526
42 Total Unbilled Rev.(See Instr.6)-166,242 1,484,287 C C -0.0089
43 TOTAL 47,708,462 2,517,419,472 1,501,156 31,781 0.0527
FERG FORM NO.1 (ED.12-95)Page 304.6
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001
(2)A Resubmission //
SALES OF ELECTRICITY BY RATE SCHEDULES
1.Report below for each rate schedule in effect during the year the MWH of electricity sold,revenue,average number of customer,average Kwh per
customer,and average revenue per Kwh,excluding date for Sales for Resale which is reported on Pages 310-311.
2.Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues,"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.
Line Number and litle of Mate schedule MWh Sold Revenue Average Number KWh of Sales i gev nue Per
of Customers Per Customer Avvh SoldNo-(a)(b)(c)(d)(e)(f)
1 Account 442.2 (Continued)
2 Teledyne Wah Cont.OR-PPL 125,472 27,798,367 1 125,472,000 0.2216
3 AIC Charge UT-UPL 118,889
4 Back-up Maint.&Sup.UT-UPL 922 86,361 1 922,000 0.0937
5 Charges Between Cust.UT-UPL -94,482
6 Space Heating UT-UPL 235 19,269 21 11,190 0.0820
7 ERN Electrochemical Co.UT-UPL 10,038 1,342,442 1 10,038,000 0.1337
8 Geneva Steel Corp.UT-UPL 473,330 13,841,831 1 473,330,000 0.0292
9 Kennecott Copper UT-UPL 707,963 16,399,068 4 176,990,750 0.0232
10 Magnesium Corp.UT-UPL 441,194 7,919,087 1 441,194,000 0.0179
11 Nucor Steel Corp.UT-UPL 550,564 14,933,662 1 550,564,000 0.0271
12 Praxair Inc.Contract UT-UPL 233,304 6,709,464 1 233,304,000 0.0288
13 Texaco Exploration &Prod.UT-UPL 303,529 9,228,807 15 20,235,267 0.0304
14 Elec.Furnace Oper.Cont.UT-UPL 3,377 281,735 5 675,400 0.0834
15 G.S.Demand Time of Day UT-UPL 1,993 119,606 5 398,600 0.0600
16 G.S.T&D Less 10000KW UT-UPL 26,281 931,835 1 26,281,000 0.0355
17 Gen.Ser.Dist.Voltage UT-UPL 1,550,172 78,574,470 1,506 1,029,331 0.0507
18 Gen.Ser.Dist.Volt.Mig.UT-UPL 205 10,554 2 102,500 0.0515
19 Gen.Ser.Dist.Volt.Small UT-UP 61,361 4,234,515 4,053 15,140 0.0690
20 Gen.Ser.High Volt.UT-UPL 2,173,081 72,170,793 102 21,304,716 0.0332
21 G.S.Time of Day Opt.UT-UPL 37,192 2,642,239 152 244,684 0.0710
22 G.S.TimelDay High Volt.UT-UPL 13,324 727,039 5 2,664,800 0.0546
23 General Service UT-UPL 5 588 2 2,500 0.1176
24 Line Ext.AGR Annual Guar.UT-UPL 85,490
25 Line Ext.Annual Inc.Cost UT-UPL 11,909
26 Misc.Charges &Credits UT-UPL 12,768
27 Outdoor Nightime Light UT-UPL 11 3,734 7 1,571 0.3395
28 Rate Refund UT-UPL -7,187,532
29 Security Area Light Ser.UT-UPL 1,800 283,281 645 2,791 0.1574
30 SP Contract Firm UT-UPL 3,610 100,965 0.0280
31 Traffic &Other Sigan!Service UT 66 3,766 8 8,250 0.0571
32 BPA Balancing Account WA-PPL -2,263
33 Charges Between Cust.WA-PPL 2,107
34 Water Heating Service WA-PPL 52 2,960 4 13,000 0.0569
35 General Service Farm WA-PPL 6,167 384,752 144 42,826 0.0624
36 General Service Flat Rate WA-PPL 33 4,697 4 8,250 0.1423
37 General Service Seasonal WA-PPL 3 754 1 3,000 0.2513
38 General Service WA-PPL 23,058 1,301,475 399 57,789 0.0564
39 Gen.Ser.Over 1000kW WA-PPL 410,817 15,770,582 37 11,103,162 0.0384
40 G.S.L.Farm Less 1000kw WA-PPL 4,152 189,862 16 259,500 0.0457
41 TOTAL Billed 47,874,704 2,515,935,185 1,501,15E 31,892 0.0526
42 Total Unbilled Rev.(See Instr.6)-166,242 1,484,287 C C -0.0089
43 TOTAL 47,708,462 2,517,419,472 1,501,15E 31,781 0.0527
FERG FORM NO.1 (ED.12-95)Page 304.7
Nameof Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
SALES OF ELECTRICITY BY RATE SCHEDULES
1.Report below for each rate schedule in effect during the year the MWH of electricity sold,revenue,average number of customer,average Kwh per
customer,and average revenue per Kwh,excluding date for Sales for Resale which is reported on Pages 310-311.
2.Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues,"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 amount of unbilled revenue as of end of year for each applicable revenue account subheading.
Line Number and i Itle of Mate Schedule MWh Sold Revenue Average Number KWh of Sales n eËder
No-(a)(b)(c)of Cus omers Per stomer
1 Account 442.2 Industrial Sales
2 G.S.Less 1000KW WA-PPL 166,134 7,472,287 151 1,100,225 0.0450
3 Line Ext.80%Guarantee WA-PPL 8,011
4 Outdoor Area Lighting WA-PPL 210 19,025 74 2,838 0.0906
5 Special Contract Cust.WA-PPL 451,968 11,541,961 1 451,968,000 0.0255
6 Back-up Supp.Power WY-UPL 1,865 181,416 1 1,865,000 0.0973
7 Centralia Refund WY-PPL -5,870,388
8 Centralia Refund WY-UPL -1,068,937
9 Charges Between Cust.WY-UPL 15,902
10 Charges Between Cust.WY-PPL 177,232
11 Amoco Prod.Contract WY-UPL 360,193 13,446,578 1 360,193,000 0.0373
12 Chevron Contract WY-UPL 22,620 588,119 4 5,655,000 0.0260
13 Continental Ind.Contract WY-PPL 7,859 328,831 34 231,147 0.0418
14 Cont.Dollar Min.Guar.WY-PPL -14,981
15 Aldila Contract WY-UPL 8,590 283,457 1 8,590,000 0.0330
16 Express Pipeline Cont.WY-PPL 18,056 545,040 1 18,056,000 0.0302
17 Gen.Ser.Flat Rate WY-PPL 83 7,670 17 4,882 0.0924
18 Gen.Ser.High Voltage WY-UPL 744 46,976 2 372,000 0.0631
19 Gen.Ser.Manual Bill WY-UPL 4,070 214,500 7 581,429 0.0527
20 Gen.Ser.Single Meter WY-UPL 34,700 2,199,865 393 88,295 0.0634
21 General Service WY-PPL 85,588 4,411,414 1,666 51,373 0.0515
22 Gen.Ser.100-999KW WY-PPL 178,073 7,571,244 116 1,535,112 0.0425
23 Gen.Ser.Indus.Rate WY-PPL 621,688 21,376,464 13 47,822,154 0.0344
24 Gen.Ser.Optional WY-UPL 15,306 723,680 3 5,102,000 0.0473
25 G.S.T&U Over 1000kw WY-PPL 1,512,366 50,244,264 66 22,914,636 0.0332
26 Gen.Ser.Over 1000kw WY-PPL 1,114,570 31,824,502 5 222,914,000 0.0286
27 Large Power Service WY-UPL 677,383 24,048,514 13 52,106,385 0.0355
28 Line Ext.60%Guarantee WY-PPI 35,833
29 Line Ext.80%Guarantee WY-UPL 3,805
30 Line Ext.80%Guarantee WY-PPL 304,945
31 Midamerica Pipeline WY-PPL 34 6,440 1 34,000 0.1894
32 Outdoor Area Light WY-PPL 118 10,414 60 1,967 0.0883
33 Partial Req.Service WY-PPL 637,591 22,129,206 4 159,397,750 0.0347
34 Security Area Light Ser.WY-PPL 12 3,225 6 2,000 0.2688
35 University of Wyoming WY-PPL 393,386 10,621,422 1 393,386,000 0.0270
36 Unbilled Revenue CA-PPL -1,603 -86,000 0.0536
37 Unbilled Revenue ID-PPL -1,938 145,000 -0.0748
38 Unbilled Revenue OR-PPL -89,815 -4,327,631 0.0482
39 Unbilled Revenue UT-UPL 3,818 2,502,000 0.6553
40 Unbilled Revenue WA-PPL -8,839 -264,000 0.0299
41 TOTAL Billed 47,874,704 2,515,935,185 1,501,15E 31,892 0.0526
42 Total Unbilled Rev.(See Instr.6)-166,242 1,484,287 C C -0.0089
43 TOTAL 47,708,462 2,517,419,472 1,501,156 31,781 0.0527
FERGFORM NO.1 (ED.12-95)Page 304.8
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001
(2)A Resubmission //
SALES OF ELECTRICITY BY RATE SCHEDULES
1.Report below for each rate schedule in effect during the year the MWH of electricity sold,revenue,average number of customer,average Kwh per
customer,and average revenue per Kwh,excluding date for Sales for Resale which is reported on Pages 310-311.
2.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.Tle average number of customers should be the number of bills rendered during the year divided by the numberof billing periods during the year (12
if all billings are made monthly).
5.F3r any rate schedule having a fuel adjtstment 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.
Line Number and litle of Rate schedule MWh Sold Revenue Average Number KWh of Sales hn e er
No (a)(b)(c)(somers Per ustomer
1 Account 442.2 (Continued)
2 Unbilled Revenue WY-PPL -28,776 5,283 -0.0002
3 Unbilled Revenue WY-UPL 11,057 421,000 0.0381
4 Less Multiple Billings CA-PPL -16
5 Less Multiple Billings ID-PPL -19
6 Less Multiple Billings OR-PPL -622
7 Less Multiple Billings UT-UPL -507
8 Less Multiple Billings WA-PPL -131
9 Less Multiple Billings WY-PPL -99
10 Less Multiple Billings WY-UPL -11
11
12 Total Account 442.2 Industrial 18,664,076 658,615,848 12,208 1,528,840 0.0353
13
14 Account 442.3 Irrigation Sales
15 Agricultural Pumping Ser.CA-PPL 73,929 4,603,941 1,301 56,825 0.0623
16 Charges Between Cust.CA-PPL 64,339
17 Klamath Basin Off Proj.CA-PPL 12 93 1 12,000 0.0078
18 Klamath Basin On Proj.CA-PPL 19,510 117,060 566 34,470 0.0060
19 Klamath Basin Contracts CA-PPL 3,274 12,303 39 83,949 0.0038
20 Line Ext.80%Guarantee CA-PPL 4,705
21 AIC Charge ID-PPL 1,097
22 Line Ext.Annual 80%Guar.ID-PPL 1,581
23 BPA Balancing Account ID-PPL -101,881 1,149,959 -0.0113
24 Canal Co.Large ID-PPL 61,942 1,039,011 92 673,283 0.0168
25 Canal Co.Small ID-PPL 162 6,256 16 10,125 0.0386
26 Charges Between Cust.ID-PPL 18,249
27 Irrigation &Pumping Ser.ID-PPL 598,337 23,224,645 4,448 134,518 0.0388
28 Irrigation BPA Bal.Acct.OR-PPL 52,702
29 Line Ext.Cont.40%Guar.OR-PPL 15,870
30 Line Ext.Cont.80%Guar.OR-PPL 18,680
31 Merger Credits ID-PPL -12,597
32 Agricultural Pumping Ser.OR-PPL 110,401 6,679,958 6,472 17,058 0.0605
33 Charges Between Cust.OR-PPL 179,110
34 General Service Farm OR-PPL 32 2,510 27 1,185 0.0784
35 General Service OR-PPL 1,193 85,358 85 14,035 0.0715
36 Irrigation BPA Bal.Acct.OR-PPL -108,203
37 Klarnath Basin OR-PPL 109,548 640,156 1,999 54,801 0.0058
38 Gen.Ser.Large Farm OR-PPL 7 692 2 3,500 0.0989
39 Gen.Ser.Less 1000kw OR-PPL 61 7,342 1 61,000 0.1204
40 G.S.Timel Use 1000kw OR-PPL 62,918 2,805,760 3 20,972,667 0.0446
41 TOTAL Billed 47,874,704 2,515,935,185 1,501,156 31,892 0.0526
42 Total Unbilled Rev.(See Instr.6)-166,242 1,484,287 C C -0.0089
43 TOTAL 47,708,462 2,517,419,472 1,501,15E 31,781 0.0527
FERG FORM NO.1 (ED.12-95)Page 304.9
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)pAn Original (Mo,Da,Yr)Dec.31,2001
(2)p A Resubmission //
SALES OF ELECTRICITY BY RATE SCHEDULES
1.Report below for each rate schedule in effect during the year the MWH of electricity sold,revenue,average number of customer,average Kwh per
customer,and average revenue per Kwh,excluding date for Sales for Resale which is reported on Pages 310-311.
2.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 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.Far any rate schedule having a fuel adjt stment clause state in a footnote the estimated additional revenue billed pursuant thereto.
6.Raport amount of unbilled revenue as oi end of year for each applicable revenue account subheading.
Line Number and litie of Mate schedule MWh Sold Revenue Average Number KWh of Sales hn e er
No-(a)(b)(c)(somers Per stomer
1 Account 442.3 (Continued)
2 Line Ext.80%Guar.OR-PPL 12,377
3 Energy Cost Rec.Amort.OR-PPL -187,853
4 Charges Between Cust.UT-UPL 30,099
5 Irrigation &PumpingSer.UT-UPL 174,461 7,716,252 2,188 79,735 0.0442
6 Line Ext.AGR Annual Guar.UT-UPL 10,876
7 Line Ext.805 Guarantee UT-UPL 8,979
8 Rate Refund UT-UPL -329,220
9 Temp.Service UT-UPL 1,210
10 Agricultural Pumping Ser.WA-PPL 159,767 8,036,815 5,408 29,543 0.0503
11 Charges Between Cust.WA-PPL 29,553
12 Contract Dollar Min.Guar.WA-PPL 30
13 General Service Farm WA-PPL 122 8,136 20 6,100 0.0667
14 Gen.Ser.Seasonal WA-PPL 7 1,235 4 1,750 0.1764
15 Irrigation BPA Bal.Acct.WA-PPL -1,769,629
16 G.S.Farm Less 1000kw WA-PPL 3,209 139,742 6 534,833 0.0435
17 Line Ext.80%Guar.WA-PPL 24,177
18 Agricultural Pumping Ser.WY-PPL 14,871 692,667 512 29,045 0.0466
19 Centralia Refund WY-PPL -27,691
20 Centralia Refund WY-UPL -2,328
21 Charges Between Cust.WY-PPL 8,503
22 Charges Between Cust.WY-UPL 1,853
23 Irrigation &PumpingSer.WY-UPL 1,250 105,213 20 62,500 0.0842
24 Line Ext.80%Guarantee WY-PPL 1,475
25 Line Ext.80%Guar.WY-UPL 2,774
26 Unbilled Revenue CA-PPL 457 48,000 0.1050
27 Unbilled Revenue OR-PPL -876 -700,000 0.7991
28 Unbilled Revenue WA-PPL -589 -600,000 1.0187
29 Unbilled Revenue WY-PPL 2 2,000 1.0000
30 Less Multiple Billing CA-PPL -111
31 Less Multiple Billing ID-PPL -15
32 Less Multiple Billing OR-PPL -232
33 Less Multiple Billing UT-UPL -20
34 Less Multiple BillingWA-PPL -56
35 Less Multiple BillingWY-PPL -10
36
37 Total Account 442.3 Irrigation 1,292,126 53,875,822 22,766 56,757 0.0417
38
39 Account 444 Street &Highway
40 Outdoor Area Lighting CA-PPL 4 642 4 1,000 0.1605
41 TOTAL Billed 47,874,704 2,515,935,185 1,501,159 31,892 0.0526
42 Total Unbilled Rev.(See Instr.6)-166,242 1,484,287 C C -0.0089
43 TOTAL 47,708,462 2,517,419,472 1,501,159 31,781 0.0527
FERt:FORM NO.1 (ED.12-95)Page 304.10
Name of Respondent This Repod Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001
(2)A Resubmission //
SALES OF ELECTRICITY BY RATE SCHEDULES
1.Report below for each rate schedule in effect during the year the MWH of electricity sold,revenue,avérage 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 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 billings are made monthly).
5.Far any rate schedule having a fuel adjL Stment clause state in a footnote the estimt=ted additional revenue billed pursuant thereto.
6.Report amount of unbilled revenue as oi end of year for each applicable revenue account subheading.
Line Numberand I Itle of Rate schedule MWh Sold Revenue Average Number KWh of Sales Revenue Per
of Customers Per Customer KWh SoldNo-(a)(b)(c)(d)(e)(f)
1 Account 444 (Continued)
2 Street Light Service CA-PPL 2,465 297,228 244 10,102 0.1206
3 Merger Credits ID-PPL -860
4 Street Light Service ID-PPL 1,910 264,091 202 9,455 0.1383
5 Traffic Other Signal Ser.ID-PPL 196 19,684 20 9,800 0.1004
6 Energy Cost Rec.Amort.OR-PPL -68,569
7 Outdoor Area Lighting OR-PPL 39 4,205 17 2,294 0.1078
8 Street Light Service OR-PPL 50,974 4,005,819 1,281 39,792 0.0786
9 Misc.Charges &Ser.UT-UPL 4,529
10 Outdoor Nighttime Light UT-UPL 1,300 98,406 39 33,333 0.0757
11 Security Area Light Ser.UT-UPL 224 42,543 105 2,133 0.1899
12 Street Light Service UT-UPL 54,935 7,025,519 1,998 27,495 0.1279
13 Traffic Other Signal Ser.UT-UPL 11,871 691,651 1,728 6,870 0.0583
14 U/G Cable Street Light UT-UPL 127
15 Street Light Service WA-PPL 10,016 839,760 408 24,549 0.0838
16 Centralia Refund WY-PPL -8,854
17 Centralia Refund WY-UPL -1,299
18 Outdoor Area Light WY-PPI 7 610 2 3,500 0.0871
19 Street Light Service WY-PPL 12,301 1,195,333 496 24,800 0.0972
20 Street Light Service WY-UPL 1,565 381,598 103 15,194 0.2438
21 Traffic Other Signal Ser.WY-PPL 21 1,340 2 10,500 0.0638
22 Traffic Other Signal Ser.WY-UPL 166 10,814 13 12,769 0.0651
23 Unbilled Revenue ID-PPL 55 10,000 0.1818
24 Unbilled Revenue UT-UPL 282 2,000 0.0071
25 Unbilled Revenue WY-UPL 102 30,000 0.2941
26 Less Multiple Billing CA-PPL -106
27 Less Multiple Billing ID-PPL -57
28 Less Multiple Billing OR-PPL -725
29 Less Multiple Billing UT-UPL -1,062
30 Less Multiple Billing WA-PPL -144
31 Less Multiple Billing WY-PPL -229
32 Less Multiple Billing WY-UPL -66
33
34 Total Acct.444 Street &Highway 148,433 14,846,317 4,273 34,737 0.1000
35
36 Account 445 Other Sales Public
37 Gen.Ser.Dist.Voltage UT-UPL 52,273 2,394,903 9 5,808,111 0.0458
38 G.S.Dist.Volt.Small UT-UPL 136 8,687 9 15,111 0.0639
39 G.S.High Volt.UT-UPL 445,410 14,855,688 6 74,235,000 0.0334
40 Security Area Light Ser.UT-UPL 22 4,261 5 4,400 0.1937
41 TOTAL Billed 47,874,70A 2,515,935,185 1,501,15E 31,892 0.0526
42 Total Unbilled Rev.(See Instr.6)-166,242 1,484,287 C C -0.0089
43 TOTAL 47,708,462 2,517,419,472 1,501,15E 31,781 0.0527
FER¢:FORM NO.1 (ED.12-95)Page 304.11
Name of Respondent This Repoit Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001
(2)A Resubmission //
SALES OF ELECTRICITY BY RATE SCHEDULES
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
appliable 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 >illings are made monthly).
5.F3r any rate schedule having a fuel adjt stment clause state in a footnote the estimated additional revenue billed pursuant thereto.
6.Raport amount of unbilled revenue as oi end of year for each applicable revenue account subheading.
Line Number and I Ille of Mate Schedule MWh Sold Revenue Average Number KWh of Sales Revenue Per
of Customers Per Customer KWh SoldNo.(a)(b)(c)(d)(e)(f)
1 Account 445 (Continued)
2 Other Sales to Public Authority 58,200 1,742,210 0.0299
3 Misc.Charges &Ser.UT-UPL 7,292 248,410 0.0341
4 Unbilled Revenue UT-UPL -2,986 47,000 -0.0157
5 Less Miltiple Billings UT-UPL -1
6
7 Total Account 445 Other Sales 560,347 19,301,159 28 20,012,393 0.0344
8
9 Account 448 Interdepartmental
10 PacifiCorp Owned Prop.UT-UPL 1
11
12 Total Account 448 Interdepartment 1
13
14 Account 450 Forfeited Disc.
15 Late Fee CA-PPL 189,193
16 Late Fee ID-PPL 376,401
17 Late Fee OR-PPL 1,493,668
18 Late Fee UT-UPL 2,396,557
19 Late Fee WA-PPL 43,890
20 Late Fee WY-PPL 344,186
21 Late Fee WY-UPL 66,738
22 Forfeited Disc.All Other OR-PPL 1,442,551
23
24 Total Account 450 Forfeited Disc.6,353,184
25
26 Account 451 Misc.Services
27 Maint.Fee Charge CA-PPL 1,454
28 Misc.Charges &Ser.CA-PPL 36,840
29 Misc.Charges &Ser.ID-PPL 49,801
30 Temp.Service ID-PPL 14,445
31 Demand Pulse Access OR-PPL 1,500
32 Energy Finanswer OR-PPL 989,925
33 Hassel Free Guarantee OR-PPL 1,264,489
34 Hassle Free Water Heater OR-PPL 14,069
35 Home Comfort OR-PPL 43,635
36 Industrial Finanswer OR-PPL 183,003
37 Irrigation Finanswer OR-PPL 17,707
38 Maintenance Fee OR-PPL 39,132
39 Misc.Charges &Ser.OR-PPL 945,565
40 Pacific Environments OR-PPL 6,471
41 TOTAL Billed 47,874,70A 2,515,935,185 1,501,159 31,892 0.0526
42 Total Unbilled Rev.(See Instr.6)-166,242 1,484,287 C C -0.0089
43 TOTAL 47,708,462 2,517,419,472 1,501,159 31,781 0.0527
FERt:FORM NO.1 (ED.12-95)Page 304.12
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission I l
SALES OF ELECTRICITY BY RATE SCHEDULES
1.Report below for each rate schedule in effect during the year the MWH of electricity sold,revenue,average number of customer,average Kwh per
customer,and average revenue per Kwh,excluding date for Sales for Resale which is reported on Pages 310-311.
2.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.Tie 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 3illings are made monthly).
5.F3r 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.
Line Number and I Itle of Rate Schedule MVVh Sold Revenue Average Number KVVh of Sales Revenue PerofCustomersPerCustomerKWhSoldNo-(a)(b)(c)(d)(e)(f)
1 Retrofit Energy Finanswer OR-PPL 100,424
2 Account 451 (Continued)
3 Weatherization Loans OR-PPL 32,782
4 Equipment Rental Charge UT-UPL 2,072
5 Misc.Charges &Ser.UT-UPL 3,041,633
6 Weatherization Loans UT-UPL 383
7 Maintenance Fee WA-PPL 1,320
8 Misc.Charges &Ser.WA-PPL 159,919
9 Maintenance Fee WY-PPL 8,032
10 Misc.Charges &Ser.WY-PPL 81,963
11 Misc.Charges &Ser.WY-UPL 15,755 1
12 Less Multiple Billing WY-UPL -1
13
14 Total Account 451 Misc.Services 7,052,319
15
16 Account 454 Rent From Electric
17 Misc.Charges &Ser.CA-PPL 58
18 Rent Revenue General CA-PPL 62,910
19 Rent Revenue Hydro CA-PPL -40,239
20 Rent Revenue T&D CA-PPL 50
21 Joint Pole Use CA-PPL 484,414
22 Misc.Charges &Ser.ID-PPL 14,078
23 Rent Revenue General ID-PPL 133,400
24 Rent Revenue Hydro ID-PPL 3,937
25 Rent Revenue T&D ID-PPL 535
26 Joint Pole Use ID-PPL 138,350
27 Rent Revenue General OR-PPL 1,557,926
28 Rent Revenue Hydro OR-PPL 2,610
29 Rent Revenue T&D OR-PPL 254,914
30 Joint Pole Use OR-PPL 6,938,220
31 Equipment Rental Charge UT-UPL 674,296
32 Misc.Charges &Ser.UT-UPL 42,896
33 Rent Revenue General UT-UPL 1,070,159
34 Rent Revenue Hydro UT-UPL 72,488
35 Rent Revenue Steam UT-UPL 145,101
36 Rent Revenue T&D UT-UPL 638,925
37 Joint Pole Use UT-UPL 1,303,063
38 Misc.Charges &Ser.WA-PPL 1,817
39 Rent Revenue General WA-PPL 532,206
40 Rent Revenue Hydro WA-PPL 149,218
41 TOTAL Billed 47,874,704 2,515,935,185 1,501,156 31,892 0.0526
42 Total Unbilled Rev.(See Instr.6)-166,242 1,484,287 C C -0.0089
43 TOTAL 47,708,462 2,517,419,472 1,501,15€31,781 0.0527
FER(:FORM NO.1 (ED.12-95)Page 304.13
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)gAn Original (Mo,Da,Yr)Dec.31,2001
(2)A Resubmission //
SALES OF ELECTRICITY BY RATE SCHEDULES
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
applizable 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 3illings are made monthly).
5.F >r any rate schedule having a fuel adjt stment clause state in a footnote the estimeted additional revenue billed pursuant thereto.
6.Raport amount of unbilled revenue as o1 end of year for each applicable revenue account subheading.
Line Number and I Itle of Mate schedule MWh Sold Kevenue Average Number KVVh of Sâles hn e er
No-(a)(b)(c)(somers Per stomer
1 Rent Revenue T&D WA-PPL 11,830
2 Account 454 (Continued)
3 Joint Pole Use WA-PPL 851,248
4 Misc.Charges &Ser.WY-PPL 21,192
5 Rent Revenue General WY-PPL 31,116
6 Rent Revenue General WY-UPL 20,449
7 Rent Revenue Steam WY-PPL 30,481
8 Rent Revenue Steam WY-UPL 7,018
9 Rent Revenue T&D WY-PPL 1,640
10 Rent Revenue T&D WY-UPL 25,563
11 Joint Pole Use WY-PPL 240,523
12 Joint Pole Use WY-UPL 28,615
13 Temp.Service WY-UPL 1,300
14
15 Total Account 454 Rent From Elect 15,452,307
16
17 Account 456 Other Electric Rev.
18 Fish &Wildlife CA-PPL 3,399
19 Misc.Charges &Ser.ID-PPL 2,583,324
20 Decoupling Revenue OR-PPL -115,170
21 DSR Inactive OR-PPL -315,905
22 DSR Net Lost Revenue OR-PPL -10,297
23 DSR Renewables OR-PPL -422,353
24 Line Loss Trans.Rev.OR-PPL 32,943,950
25 Misc.Charges &Ser.OR-PPL 7,003,176
26 Wheeling OR-PPL 65,646,976
27 Fish &Wildlife UT-UPL 2,180
28 Maintenance Fee UT-UPL 8,254
29 Misc.Charges &Ser.UT-UPL 2,461,568
30 OSB Contract Services UT-UPL 265,186
31 DSM Revenue WA-PPL -2,378,686
32 Fish &Wildlife WA-PPL 6,544
33 Misc.Charges &Ser.WA-PPL 3,056,869
34 Colstrip Unit 3 WA-PPL -52,188
35 Misc.Charges &Ser.WY-PPL 11,170,991
36 Misc.Charges &Ser.WY-UPL 18,535
37 Misc.Char.&Ser.Gen.Office PP 24,385,070
38 Wheeling General Office PPL 5,800,395
39
40 Total Account 456 Other Electric 152,061,818
41 TOTAL Billed 47,874,704 2,515,935,185 1,501,15E 31,892 0.0526
42 Total UnbilledRev.(See Instr.6)-166,242 1,484,287 C C -0.0089
43 TOTAL 47,708,462 2,517,419,472 1,501,156 31,781 0.0527
FERt:FORM NO.1 (ED.12-95)Page 304.14
Blank Page
(Next Page is:310)
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)|¯¯|X An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
SALES FOR RESALE (Account 447)
1.Report all sales for resale (i.e.,sales to purchasers other than ultimate consumers)transaeted on a settlement basis other than
power exchanges during the year.Do not report exchanges of electricity (i.e.,transactions involvinga balancing of debits and credits
for energy,capacity,etc.)and any settlements for imbalanced exchanges on this schedule.Power exchanges must be reported on the
Purchased Power schedule (Page 326-327).
2.Enter the name of the purchaser in column (a).Do note abbreviate or truncate the name or use acronyms.Explain in a footnote any
ownership interest or affiliation the respondent has with the purchaser.
3.In column (b),enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows:
RQ -for requirements service.Requirements service is service which the supplier plans to provide on an ongoing basis (i.e.,the
supplier includes projected load for this service in its system resource planning).In addition,the reliability of requirements service must
be the same as,or second only to,the supplier's senrice 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 senrice.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 senrice 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 De nand (MW)
No.(Footnote Affiliations)C -SaÎi
u br DMen
a d (Month eDemant Month yC emand
(a)(b)(c)(d)(e)(f)
1 Requirement Sales
2 Blanding City RQ T-6 1 1 1
3 Brigham City RQ 318 17 17 16
4 Deaver,Town of RQ T-4 0 0 NA
5 Helper City RQ T-6 1 1 1
6 Helper City Annex RQ T-6 1 1 1
7 Navajo Tribal Utility Authority (Mexica RQ T-6 0 0 0
8 Navajo Tribal Utility Authority (Red Me RQ T-6 1 1 1
9 Portland General Electric Company RQ 147 NA NA NA
10 Portland General Electric Company RQ 147 NA NA NA
11 Price City RQ T-6 11 11 10
12 Accrual adjustment RQ NA NA NA
13
14
Subtotal RQ 0 0 0
Subtotal non-RQ 0 0 0
Total 0 0 0
FERC FORMNO.1 (ED.12-90)Page 310
Name of Respondent This Re ort Is:Date of Report Year of Report
PacifiCorp (1)X An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
SALES FOR RESALE (Account 447)(Continued)
OS -for other service.use this category only for those services which cannot be placed in the above-defined categories,such as all
non-firm service regardless of the Length of the contract and service from designated units of Less than one year.Describe the nature
of the service in a footnote.
AD -for Out-of-period adjustment.Use this code for any accounting adjustments or "true-ups"for service provided in prior reporting
years.Provide an explanation in a footnote for each adjustment.
4.Group requirements RQ sales together and report them starting at line number one.After listing all RQ sales,enter "Subtotal -RQ"
in column (a).The remaining sales may then be listed in any order.Enter "Subtotal-Non-RQ"in column (a)after this Listing.Enter
"Total"in column (a)as the Last Line of the schedule.Report subtotals and total for columns (9)through (k)
5.In Column (c),identify the FERC Rate Schedule or Tariff Number.On separate Lines,List all FERC rate schedules or tariffs under
which service,as identified in column (b),is provided.
6.For requirements RQ sales and any type of-service involving demand charges imposed on a monthly (or Longer)basis,enter the
average monthly billing demand in column (d),the average monthly non-coincident peak (NCP)demand in column (e),and the average
monthly coincident peak (CP)
demand in column (f).For all other types of service,enter NA in columns (d),(e)and (f).Monthly NCP demand is the maximum
metered hourly (60-minute integration)demand in a month.Monthly CP demand is the metered demand during the hour (60-minute
integration)in which the supplier's system reaches its monthly peak.Demand reported in columns (e)and (f)must be in megawatts.
Footnote any demand not stated on a megawatt basis and explain.
7.Report in column (g)the megawatt hours shown on bills rendered to the purchaser.
8.Report demand charges in column (h),energy charges in column (i),and the total of any other types of charges,including
out-of-period adjustments,in column (j).Explain in a footnote all components of the amount shown in column (j).Report in column (k)
the total charge shown on bills rendered to the purchaser.
9.The data in column (g)through (k)must be subtotaled based on the RQ/Non-RQ grouping (see instruction 4),and then totaled on
the Last -line of the schedule.The "Subtotal -RQ"amount in column (g)must be reported as Requirements Sales For Resale on Page
401,line 23.The "Subtotal -Non-RQ"amount in column (g)must be reported as Non-Requirements Sales For Resale on Page
401,iine 24.
10.Footnote entries as required and provide explanations following all required data.
MegaWatt Hours REVENUE .
Sold Demand Charges Energy Charges Other Charges Total ($)Line
($)($)($)(h+1+))No.
(9)(h)(i)(j)(k)
1
6,526 93,240 113,973 207,213 2
102,888 1,577,900 1,792,322 3,370,222 3
894 13,404 16,126 29,530 4
5,729 103,292 101,562 204,854 5
3,794 67,832 67,252 135,084 6
846 21,212 14,754 35,966 7
3,848 63,085 67,039 130,124 8
321 20,248 20,248 9
12,699 744,179 744,179 10
65,034 1,004,249 1,134,221 2,138,470 11
-2,017 -71,029 -71,029 12
13
14
200,562 2,944,214 4,051,428 -50,781 6,944,861
22,650,336 144,796,075 1,895,637,729 5,284,831 2,045,718,635
22,850,898 147,740,289 1,899,689,157 5,234,050 2,052,663,496
FERC FORM NO.1 (ED.12-90)Page 311
Name of Respondent This Re ort Is:Date of Report Year of Report
PacifiCorp (1)X An Original (Mo,Da,Yr)Dec.31,2001
(2)A Resubmission //
SALES FOR RESALE (Account 447)
1.Report all sales for resale (i.e.,sales to purchasers other than ultimate consumers)transacted on a settlement basis other than
power exchanges during the year.Do not report exchanges of electricity (i.e.,transactions involving a balancing of debits and credits
for energy,capacity,etc.)and any settlements for imbalanced exchanges on this schedule.Power exchanges must be reported on the
Purchased Power schedule (Page 326-327).
2.Enter the name of the purchaser in column (a).Do note abbreviate or truncate the name or use acronyms.Explain in a footnote any
ownership interest or affiliation the respondent has with the purchaser.
3.In column (b),enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows:
RQ -for requirements service.Requirements service is service which the supplier plans to provide on an ongoing basis (i.e.,the
supplier includes projected load for this service in its system resource planning).In addition,the reliability of requirements service must
be the same as,or second only to,the supplier's service to its own ultimate consumers.
LF -for tong-term service."Long-term"means five years or Longer and "firm"means that service cannot be interrupted for economic
reasons and is intended to remain reliable even under adverse conditions (e.g.,the supplier must attempt to buy emergency energy
from third padies 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 CompanyAorPLblicAuthority S istical
Sa
urenaboerDMeea
d Month N De
aDnodnth
y
CmP emand
(a)(b)(c)(d)(e)(f)
1 Nonrequirement Sales NA NA NA
2 Allegheny Energy Supply Company.LLC SF WSPP NA NA NA
3 American Electric Power Co.,Inc.OS WSPP NA NA NA
4 American Electric Power Co.,Inc.SF WSPP NA NA NA
5 Anaheim,City of OS WSPP NA NA NA
6 Anaheim,City of SF WSPP NA NA NA
7 Aquila Power Corporation OS WSPP NA NA NA
8 Aquila Power Corporation SF WSPP NA NA NA
9 Arizona Electric Power Cooperative IF T-12 25 25 25
10 Arizona Public Service Company AD WSPP NA NA NA
11 Arizona Public Service Company OS WSPP NA NA NA
12 Arizona Public Service Company SF WSPP NA NA NA
13 Avista Corporation AD T-12 NA NA NA
14 Avista Corporation SF T-12 2 0 0
Subtotal RQ 0 0 0
Subtotal non-RQ 0 0 0
Total 0 0 0
FERC FORM NO.1 (ED.12-90)Page 310.1
Name of Respondent This Re ort is:Date of Report Year of Report
PacifiCorp (1)X An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
SALES FOR RESALE (Account 447)(Continued)
OS -for other service.use this category only for those services which cannot be placed in the above-defined categories,such as all
non-firm service regardless of the Length of the contract and service from designated units of Less than one year.Describe the nature
of the service in a footnote.
AD -for Out-of-period adjustment.Use this code for any accounting adjustments or "true-ups"for service provided in prior reporting
years.Provide an explanation in a footnote for each adjustment.
4.Group requirements RQ sales together and report them starting at line number one.After listing all RQ sales,enter "Subtotal -RQ"
in column (a).The remaining sales may then be listed in any order.Enter "Subtotal-Non-RQ"in column (a)after this Listing.Enter
"Total"in column (a)as the Last Line of the schedule.Report subtotals and total for columns (9)through (k)
5.In Column (c),identify the FERC Rate Schedule or Tariff Number.On separate Lines,List all FERC rate schedules or tariffs under
which service,as identified in column (b),is provided.
6.For requirements RQ sales and any type of-service involving demand charges imposed on a monthly (or Longer)basis,enter the
average monthly billing demand in column (d),the average monthly non-coincident peak (NCP)demand in column (e),and the average
monthly coincident peak (CP)
demand in column (f).For all other types of sentice,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 harges h+al($)I-ine
(g)(h)(i)(j)(k)
1
115,325 4,050,528 4,050,528 2
1,135 38,750 38,750 3
389,182 37,448,679 37,448,679 4
362 57,920 57,920 5
66,786 25,967,205 25,967,205 6
1,145 147,750 147,750 7
409,075 56,329,515 56,329,515 8
38,976 1,302,750 642,324 1,945,074 9
-10 5,120 5,120 10
39,728 3,852,008 250 3,852,258 11
697,131 87,115,341 87,115,341 12
600 600 13
2,400 2,400 14
200,562 2,944,214 4,051,428 -50,781 6,944,861
22,650,336 144,796,075 1,895,637,729 5,284,831 2,045,718,635
22,850,898 147,740,289 1,899,689,157 5,234,050 2,052,663,496
FERC FORM NO.1 (ED.12-90)Page 311.1
Name of Respondent This Re ort Is:Date of Report Year of Report
PacifiCorp (1)X An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
SALES FOR RESALE (Account 447)
1.Report all sales for resale (i.e.,sales to purchasers other than ultimate consumers)transacted on a settlement basis other than
power exchanges during the year.Do not report exchanges of electricity (i.e.,transactions involvinga balancing of debits and credits
for energy,capacity,etc.)and any settlements for imbalanced exchanges on this schedule.Power exchanges must be reported on the
Purchased Power schedule (Page 326-327).
2.Enter the name of the purchaser in column (a).Do note abbreviate or truncate the name or use acronyms.Explain in a footnote any
ownership interest or affiliation the respondent has with the purchaser.
3.In column (b),enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows:
RQ -for requirements service.Requirements semice 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 senrice.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 senrice 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 De nand (MW)
No.(Footnote Affiliations)C s -SaÎl
u br DMerahr
d (Month N Demant Monthy
CmP emand
(a)(b)(c)(d)(e)(f)
1 Avista Corporation SF WSPP ,NA NA NA
2 Avista Energy,Inc.SF WSPP NA NA NA
3 Axia Energy,LP SF WSPP NA NA NA
4 Azusa Light and Water Department SF T-3 NA NA NA
5 BP Energy Company SF WSPP NA NA NA
6 Basin Electric Power Company SF T-3 NA NA NA
7 Black Hills Power and Light Company LF 236 65 65 60
8 Black Hills Power and Light Company LF 246 NA NA NA
9 Black Hills Power and Light Company LF 424 60 60 37
10 Black Hills Power and Light Company OS T-12 NA NA NA
11 Black Hills Power and Light Company OS T-3 NA NA NA
12 Black Hills Power and Light Company OS WSPP NA NA NA
13 Black Hills Power and Light Company SF T-12 NA NA NA
14 Black Hills Power and Light 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 310.2
Name of Respondent This Re ort Is:Date of Report Year of Report
PacifiCorp (1)X An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
SALES FOR RESALE (Account 447)(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 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 repon 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 Dernand Charges Energy Charges Other Charges Total ($)Line
($)($)($)(h+i+])No.
(9)(h)(i)(j)(k)
14,765 1,390,800 1,390,800 1
56,236 7,481,351 7,481,351 2
2,800 449,200 449,200 3
464 69,960 69,960 4
122,400 12,648,600 12,648,600 5
712 25,742 25,742 6
473,373 9,065,437 4,832,170 13,897,607 7
1,655 35,396 35,396 8
14,025 540,000 364,893 904,893 9
910 37,479 37,479 10
495 12,795 12,795 11
1,365 66,175 66,175 12
821 87,510 87,510 13
793 199,340 199,340 14
200,562 2,944,214 4,051,428 -50,781 6,944,861
22,650,336 144,796,075 1,895,637,729 5,284,831 2,045,718,635
22,850,898 147,740,289 1,899,689,157 5,234,050 2,052,663,496
FERC FORM NO.1 (ED.12-90)Page 311.2
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)[¯]X An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
SALES FOR RESALE (Account 447)
1.Report all sales for resale (i.e.,sales to purchasers other than ultimate consumers)transacted on a settlement basis other than
power exchanges during the year.Do not report exchanges of electricity (i.e.,transactions involvinga balancing of debits and credits
for energy,capacity,etc.)and any settlements for imbalanced exchanges on this schedule.Power exchanges must be reported on the
Purchased Power schedule (Page 326-327).
2.Enter the name of the purchaser in column (a).Do note abbreviate or truncate the name or use acronyms.Explain in a footnote any
ownership interest or affiliation the respondent has with the purchaser.
3.In column (b),enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows:
RQ -for requirements service.Requirements service is service which the supplier plans to provide on an ongoing basis (i.e.,the
supplier includes projected load for this service in its system resource planning).In addition,the reliability of requirements service must
be the same as,or second only to,the supplier's service to its own ultimate consumers.
LF -for tong-term service."Long-term"means five years or Longer and "firm"means that service cannot be interrupted for economic
reasons and is intended to remain reliable even under adverse conditions (e.g.,the supplier must attempt to buy emergency energy
from third parties to maintain deliveries of LF service).This category should not be used for Long-term firm service which meets the
definition of RQ senrice.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 categony for all firm senrices where the duration of each period of commitment for service is
one year or less.
LU -for Long-term senrice from a designated generating unit."Long-term"means five years or Longer.The availability and reliability of
service,aside from transmission constraints,must match the availability and reliability of designated unit.
IU -for intermediate-term service from a designated generating unit.The same as LU service except that "intermediate-term"means
Longer than one year but Less than five years.
Line Name of Company or Public Authority Statistical FERC Rate Average Actual De nand (MW)
No (Footnote Affiliations)Classifi-Schedule or Monthly Billing Avera e AveracationTariffNumberDemand(MW)Monthly NC Demant Monthly CP emand
(a)(b)(c)(d)(e)(f)
1 Black Hills Power and Light Company SF WSPP NA NA NA
2 Bonneville Power Administration LF WSPP NA NA NA
3 Bonneville Power Administration LU T-12 NA NA NA
4 Bonneville Power Administration SF WSPP NA NA NA
5 Burbank,City of OS WSPP NA NA NA
6 Burbank,City of SF WSPP NA NA NA
7 California ISO AD T-12 NA NA NA
8 California ISO SF T-12 NA NA NA
9 California Power Exchange AD T-12 NA NA NA
10 California Power Exchange SF T-12 NA NA NA
11 Cheyenne Light,Fuel and Power Company AD 421 NA NA NA
12 Cheyenne Light,Fuel and Power Company IF 421 134 133 117
13 Cinergy Services Inc.SF WSPP NA NA NA
14 Clark County Public Utility District LF 428 260 260 216
Subtotal RQ 0 0 0
Subtotal non-RQ 0 0 0
Total 0 0 0
FERC FORM NO.1 (ED.12-90)Page 310.3
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)X An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
SALES FOR RESALE (Account 447)(Continued)
OS -for other service.use this category only for those services which cannot be placed in the above-defined categories,such as all
non-firm service regardless of the Length of the contract and service from designated units of Less than one year.Describe the nature
of the service in a footnote.
AD -for Out-of-period adjustment.Use this code for any accounting adjustments or "true-ups"for service provided in prior reporting
years.Provide an explanation in a footnote for each adjustment.
4.Group requirements RQ sales together and report them starting at line number one.After listing all RQ sales,enter "Subtotal -RQ"
in column (a).The remaining sales may then be listed in any order.Enter "Subtotal-Non-RQ"in column (a)after this Listing.Enter
"Total"in column (a)as the Last Line of the schedule.Report subtotals and total for columns (9)through (k)
5.In Column (c),identify the FERC Rate Schedule or Tariff Number.On separate Lines,List all FERC rate schedules or tariffs under
which service,as identified in column (b),is provided.
6.For requirements RQ sales and any type of-service 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 RQINon-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)O.
(g)(h)(i)(j)(k)
1,705 154,112 154,112 1
119,286 5,427,513 5,427,513 2
41,833 2,968,470 2,968,470 3
47,510 10,027,600 10,027,600 4
166 18,700 18,700 5
40,953 10,165,925 10,165,925 6
-418 2,077,515 2,077,515 7
667 19,327 19,327 8
357 53,247 53,247 9
25 5,422 5,422 10
1,000 1,000 11
144,309 1,277,044 2,720,225 3,997,269 12
400 10,600 10,600 13
855,757 4,846,960 13,551,579 18,398,539 14
200,562 2,944,214 4,051,428 -50,781 6,944,861
22,650,336 144,796,075 1,895,637,729 5,284,831 2,045,718,635
22,850,898 147,740,289 1,899,689,157 5,234,050 2,052,663,496
FERC FORMNO.1 (ED.12-90)Page 311.3
Name of Respondent This Re ort Is:Date of Report Year of Report
PacifiCorp (1)X An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission I /
SALES FOR RESALE (Account 447)
1.Report all sales for resale (i.e.,sales to purchasers other than ultimate consumers)transacted on a settlement basis other than
power exchanges during the year.Do not report exchanges of electricity (i.e.,transactions involving a balancing of debits and 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 the
earliest date that either buyer or setter can unilaterally get out of the contract.
IF -for intermediate-term firm service.The same as LF service except that "intermediate-term"means longer than one year but Less
than five years.
SF -for short-term firm service.Use this category for all firm services where the duration of each period of commitment for service is
one year or less.
LU -for Long-term service from a designated generating unit."Long-term"means five years or Longer.The availability and reliability of
service,aside from transmission constraints,must match the availability and reliability of designated unit.
IU -for intermediate-term service from a designated generating unit.The same as LU service except that "intermediate-term"means
Longer than one year but Less than five years.
Line Name of Company or Public Authority Statistical FERC Rate Avera e Actual De nand (MW)
No.(Footnote Affiliations)ss -SaÎih ulrenb
r
DMer
a d (Month eDemant Month yœC emand
(a)(b)(c)(d)(e)(f)
1 Clark County Public Utility District LF T-12 NA NA NA
2 Clark County Public Utility District SF T-12 NA NA NA
3 Colorado Springs Utilities SF WSPP NA NA NA
4 Constellation Power Source,Inc.OS WSPP NA NA NA
5 Constellation Power Source,Inc.SF WSPP NA NA NA
6 Coral Power,L.L.C.SF WSPP NA NA NA
7 Cowlitz County Public Utility District LF T-12 11 11 7
8 Deseret Generation &Transmission Coope AD 462 NA NA NA
9 Deseret Generation &Transmission Coope AD T-3 NA NA NA
10 Deseret Generation &Transmission Coope LF 462 NA NA NA
11 Deseret Generation &Transmission Coope OS 462 NA NA NA
12 Duke Energy Trading &Marketing,LLC OS WSPP NA NA NA
13 Duke Energy Trading &Marketing,LLC SF WSPP NA NA NA
14 Dynegy Power Marketing,Inc.SF WSPP NA NA NA
Subtotal RQ 0 0 0
Subtotal non-RQ 0 0 0
Total 0 0 0
FERC FORM NO.1 (ED.12-90)Page 310.4
Name of Respondent This Re ort Is:Date of Report Year of Report
PacifiCorp (1)X An Original (Mo,Da,Yr)Dec.31,2001
(2)A Resubmission //
SALES FOR RESALE (Account 447)(Continued)
OS -for other service.use this category only for those services which cannot be placed in the above-defined categories,such as all
non-firm service regardless of the Length of the contract and service from designated units of Less than one year.Describe the nature
of the service in a footnote.
AD -for Out-of-period adjustment.Use this code for any accounting adjustments or "true-ups"for service providedin 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 L
Sold Demand Charges Energy Charges Other Charges Total ($)ne
($)($)($)(h+i+])
(g)(h)(i)(j)(k)
63,530 630,652 1,524,006 2,154,658 1
61,440 4,400,640 4,400,640 2
1,865 64,465 64,465 3
100 3,200 3,200 4
502,094 81,535,702 81,535,702 5
59,409 11,679,848 11,679,848 6
69,952 119,643 1,115,549 1,235,192 7
15,636 1,957,167 1,957,167 8
30,000 6,762,061 6,762,061 9
227,729 17,689,028 17,689,028 10
26,497 198,728 198,728 11
476 112,595 112,595 12
349,586 33,006,862 33,006,862 13
246,056 23,705,660 23,705,660 14
200,562 2,944,214 4,051,428 -50,781 6,944,861
22,650,336 144,796,075 1,895,637,729 5,284,831 2,045,718,635
22,850,898 147,740,289 1,899,689,157 5,234,050 2,052,663,496
FERC FORM NO.1 (ED.12-90)Page 311.4
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)X An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission I /
SALES FOR RESALE (Account 447)
1.Report all sales for resale (i.e.,sales to purchasers other than ultimate consumers)transacted on a settlement basis other than
power exchanges during the year.Do not report exchanges of electricity (i.e.,transactions involving a balancing of debits and credits
for energy,capacity,etc.)and any settlements for imbalanced exchanges on this schedule.Power exchanges must be reported on the
Purchased Power schedule (Page 326-327).
2.Enter the name of the purchaser in column (a).Do note abbreviate or truncate the name or use acronyms.Explain in a footnote any
ownership interest or affiliation the respondent has with the purchaser.
3.In column (b),enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows:
RQ -for requirements service.Requirements senrice is service which the supplier plans to provide on an ongoing basis (i.e.,the
supplier includes projected load for this service in its system resource planning).In addition,the reliability of requirements service must
be the same as,or second only to,the supplier's service to its own ultimate consumers.
LF -for tong-term service."Long-term"means five years or Longer and "firm"means that service cannot be interrupted for economic
reasons and is intended to remain reliable even under adverse conditions (e.g.,the supplier must attempt to buy emergency energy
from third parties to maintain deliveries of LF service).This category should not be used for Long-term firm service which meets the
definition of RQ service.For all transactions identified as LF,provide in a footnote the termination date of the contract defined as the
earliest date that either buyer or setter can unilaterally get out of the contract.
IF -for intermediate-term firm service.The same as LF service except that "intermediate-term"means longer than one year but Less
than five years.
SF -for short-term firm service.Use this category for all firm services where the duration of each period of commitment for service is
one year or less.
LU -for Long-term service from a designated generating unit."Long-term"means five years or Longer.The availability and reliability of
service,aside from transmission constraints,must match the availability and reliability of designated unit.
IU -for intermediate-term service from a designated generating unit.The same as LU service except that "intermediate-term"means
Longer than one year but Less than five years.
Line Name of Company or Public Authority Statistical FERC Rate Avera e Actual De nand (MW)
No.(Footnote Affiliations)s -Sachne Irenber DMe
a d (Month N Demant Month yœCogl$emand
(a)(b)(c)(d)(e)(f)
1 Edison Mission Marketing &Trading,Inc AD T-12 NA NA NA
2 Edison Mission Marketing &Trading,Inc IF T-12 NA NA NA
3 El Paso Energy Marketing Company SF WSPP NA NA NA
4 Energy Northwest,Inc.LF T-12 NA NA NA
5 Enron Power Marketing,Inc.AD T-3 NA NA NA
6 Enron Power Marketing,Inc.AD WSPP NA NA NA
7 Enron Power Marketing,Inc.OS WSPP NA NA NA
8 Enron Power Marketing,Inc.SF WSPP NA NA NA
9 Eugene Water &Electric Board SF WSPP NA NA NA
10 Flathead Electric Cooperative,Inc.LF T-12 NA NA NA
11 Flathead Electric Cooperative,Inc.SF T-12 NA NA NA
12 Glendale,City of SF T-3 NA NA NA
13 Green Mountain Energy Resouræs,LLC AD T-3 NA NA NA
14 Green Mountain Energy Resourœs,LLC LF 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 310.5
Name of Respondent This Re ort is:Date of Report Year of Report
PacifiCorp (1)X An Original (Mo,Da,Yr)Dec.31 2001(2)A Resubmission //
SALES FOR RESALE (Account 447)(Continued)
OS -for other service.use this category only for those services which cannot be placed in the above-defined categories,such as all
non-firm service regardless of the Length of the contract and service from designated units of Less than one year.Describe the nature
of the service in a footnote.
AD -for Out-of-period adjustment.Use this code for any accounting adjustments or "true-ups"for service provided in prior reporting
years.Provide an explanation in a footnote for each adjustment.
4.Group requirements RQ sales together and report them starting at line number one.After listing all RQ sales,enter "Subtotal -RQ"
in column (a).The remaining sales may then be listed in any order.Enter "Subtotal-Non-RQ"in column (a)after this Listing.Enter
"Total"in column (a)as the Last Line of the schedule.Report subtotals and total for columns (9)through (k)
5.In Column (c),identify the FERC Rate Schedule or Tariff Number.On separate Lines,List all FERC rate schedules or tariffs under
which service,as identified in column (b),is provided.
6.For requirements RQ sales and any type of-service 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 reponed 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+;)No.
(9)(h)(i)(j)(k)
-24,825 -24,825 1
129,846 4,052,751 4,052,751 2
261,689 42,648,444 42,648,444 -3
60,802 1,450,128 1,450,128 4
-75 -6,000 -6,000 5
697 169,413 169,413 6
1,124 126,490 66,110 192,600 7
2,395,207 306,706,416 306,706,416 8
2,225 276,385 276,385 9
435,378 14,520,453 14,520,453 10
14,012 2,237,507 2,237,507 11
634 147,250 147,250 12
-4,020 -3,109,594 -3,109,594 13
877 5,875,009 134,221 6,009,230 14
200,562 2,944,214 4,051,428 -50,781 6,944,861
22,650,336 144,796,075 1,895,637,729 5,284,831 2,045,718,635
22,850,898 147,740,289 1,899,689,157 5,234,050 2,052,663,496
FERC FORM NO.1 (ED.12-90)Page 311.5
Name of Respondent This Report is:Date of Report Year of Report
PacifiCorp (1)X An Original (Mo,Da,Yr)Dec.31,2001
(2)A Resubmission //
SALES FOR RESALE(Account 447)
1.Report all sales for resale (i.e.,sales to purchasers other than ultimate consumers)transacted on a settlement basis other than
power exchanges during the year.Do not report exchanges of electricity (i.e.,transactions involving a balancing of debits and credits
for energy,capacity,etc.)and any settlements for imbalanced exchanges on this schedule.Power exchanges must be reported on the
Purchased Power schedule (Page 326-327).
2.Enter the name of the purchaser in column (a).Do note abbreviate or truncate the name or use acronyms.Explain in a footnote any
ownership interest or affiliation the respondent has with the purchaser.
3.In column (b),enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows:
RQ -for requirements service.Requirements senrice 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 senrice."Long-term"means five years or Longer and "firm"means that service cannot be interrupted for economic
reasons and is intended to remain reliable even under adverse conditions (e.g.,the supplier must attempt to buy emergency energy
from third parties to maintain deliveries of LF service).This category should not be used for Long-term firm service which meets the
definition of RQ service.For all transactions identified as LF,provide in a footnote the termination date of the contract defined as the
earliest date that either buyer or setter can unilaterally get out of the contract.
IF -for intermediate-term firm service.The same as LF service except that "intermediate-term"means longer than one year but Less
than five years.
SF -for short-term firm service.Use this category for all firm services where the duration of each period of commitment for service is
one year or less.
LU -for Long-term service from a designated generating unit."Long-term"means five years or Longer.The availability and reliability of
service,aside from transmission constraints,must match the availability and reliability of designated unit.
IU -for intermediate-term service from a designated generating unit.The same as LU service except that "intermediate-term"means
Longer than one year but Less than five years.
Line Name of Company or Public Authority Statistical FERC Rate Avera e Actual De nand (MW)
No.(Footnote Affiliations)s -SaÎi urenb
r
DMe
a d (Month N Demant Month yœCmP emand
(a)(b)(c)(d)(e)(f)
1 Hinson Power Company,Inc.AD T-12 NA NA NA
2 Hinson Power Company,Inc.IF T-12 NA NA NA
3 Hurricane,City of LF T-12 NA NA NA
4 Idaho Power Company AD WSPP NA NA NA
5 Idaho Power Company OS WSPP NA NA NA
6 Idaho Power Company SF WSPP NA NA NA
7 Los Angeles Department of Water and Pow LU 301 NA NA NA
8 Los Angeles Department of Water and Pow OS WSPP NA NA NA
9 Los Angeles Department of Water and Pow SF WSPP NA NA NA
10 MIECO Inc.SF WSPP NA NA NA
11 Merrill Lynch Capital Services,Inc.SF WSPP NA NA NA
12 Metropolitan Water District of Southern SF WSPP NA NA NA
13 Mirant Americas Energy Marketing,LP OS WSPP NA NA NA
14 Mirant Americas Energy Marketing,LP SF WSPP NA NA NA
Subtotal RQ 0 0 0
Subtotal non-RQ 0 0 0
Total 0 0 0
FERC FORM NO.1 (ED.12-90)Page 310.6
Name of Respondent This Re ort Is:Date of Report Year of Report
PacifiCorp (1)X An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
SALES FOR RESALE (Account 447)(Continued)
OS -for other service.use this category only for those services which cannot be placed in the above-defined categories,such as all
non-firm service regardless of the Length of the contract and service from designated units of Less than one year.Describe the nature
of the service in a footnote.
AD -for Out-of-period adjustment.Use this code for any accounting adjustments or "true-ups"for service provided in prior reporting
years.Provide an explanation in a footnote for each adjustment.
4.Group requirements RQ sales together and report them starting at line number one.After listing all RQ sales,enter "Subtotal -RQ"
in column (a).The remaining sales may then be listed in any order.Enter "Subtotal-Non-RQ"in column (a)after this Listing.Enter
"Total"in column (a)as the Last Line of the schedule.Report subtotals and total for columns (9)through (k)
5.In Column (c),identify the FERC Rate Schedule or Tariff Number.On separate Lines,List all FERC rate schedules or tariffs under
which service,as identified in column (b),is provided.
6.For requirements RQ sales and any type of-service involving demand charges imposed on a monthly (or Longer)basis,enter the
average monthly billing demand in column (d),the average monthly non-coincident peak (NCP)demand in column (e),and the average
monthly coincident peak (CP)
demand in column (f).For all other types of service,enter NA in columns (d),(e)and (f).Monthly NCP demand is the maximum
metered hourly (60-minute integration)demand in a month.Monthly CP demand is the metered demand during the hour (60-minute
integration)in which the supplier's system reaches its monthly peak.Demand reported in columns (e)and (f)must be in megawatts.
Footnote any demand not stated on a megawatt basis and explain.
7.Report in column (g)the megawatt hours shown on bills rendered to the purchaser.
8.Report demand charges in column (h),energy charges in column (i),and the total of any other types of charges,including
out-of-periodadjustments,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 RQINon-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 L
Sold Demand Charges Energy Charges Other Charges o a
(g)(h)(i)(j)(k)
87 147,267 147,267 1
145 19,001 19,001 2
10,344 289,632 289,632 3
-220 -54,600 -54,600 4
200 46,500 46,500 5
499,837 65,477,918 65,477,918 6
544,334 22,784,673 22,784,673 7
64,335 4,037,020 4,037,020 8
82,224 13,573,085 13,573,085 9
10,600 242,000 242,000 10
34,000 7,529,200 7,529,200 11
21,750 2,592,100 2,592,100 12
425 12,625 12,625 13
757,802 118,898,232 118,898,232 14
200,562 2,944,214 4,051,428 -50,781 6,944,861
22,650,336 144,796,075 1,895,637,729 5,284,831 2,045,718,635
22,850,898 147,740,289 1,899,689,157 5,234,050 2,052,663,496
FERC FORM NO.1 (ED.12-90)Page 311.6
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)X An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
SALES FOR RESALE (Account 447)
1.Report all sales for resale (i.e.,sales to purchasers other than ultimate consumers)transacted on a settlement basis other than
power exchanges during the year.Do not report exchanges of electricity (i.e.,transactions involvinga balancing of debits and credits
for energy,capacity,etc.)and any settlements for imbalanced exchanges on this schedule.Power exchanges must be reported on the
Purchased Power schedule (Page 326-327).
2.Enter the name of the purchaser in column (a).Do note abbreviate or truncate the name or use acronyms.Explain in a footnote any
ownership interest or affiliation the respondent has with the purchaser.
3.In column (b),enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows:
RQ -for requirements service.Requirements service is service which the supplier plans to provide on an ongoing basis (i.e.,the
supplier includes projected load for this senrice 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,providein 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 categony 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 De nand (MW)
No.(Footnote Affiliations)C -SaÎi
u br DMenMahr
d (Month N Demant Month yC emand
(a)(b)(c)(d)(e)(f)
1 Modesto Irrigation District SF WSPP NA NA NA
2 Morgan Stanley Capital Group,Inc.OS WSPP NA NA NA
3 Morgan Stanley Capital Group,Inc.SF WSPP NA NA NA
4 Municipal Energy Agency of Nebraska OS WSPP NA NA NA
5 Municipal Energy Agency of Nebraska SF WSPP NA NA NA
6 Nevada Power Company OS WSPP NA NA NA
7 Nevada Power Company SF WSPP NA NA NA
8 PECO Energy Power Company SF WSPP NA NA NA
9 PPL Montana.LLC OS WSPP NA NA NA
10 PPL Montana.LLC SF WSPP NA NA NA
11 Pacific Northwest Generating Cooperativ IF 429 60 60 60
12 Port of Oakland SF T-12 NA NA NA
13 Portland General Electric Company OS WSPP NA NA NA
14 Portland General Electric Company SF WSPP NA NA NA
Subtotal RQ 0 0 0
Subtotal non-RQ 0 0 0
Total 0 0 0
FERC FORM NO.1 (ED.12-90)Page 310.7
Name of Respondent This Re ort Is:Date of Report Year of Report
PacifiCorp (1)X An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
SALES FOR RESALE (Account 447)(Continued)
OS -for other service.use this category only for those services which cannot be placed in the above-defined categories,such as all
non-firm service regardless of the Length of the contract and service from designated units of Less than one year.Describe the nature
of the service in a footnote.
AD -for Out-of-period adjustment.Use this code for any accounting adjustments or "true-ups"for service provided in prior reporting
years.Provide an explanation in a footnote for each adjustment.
4.Group requirements RQ sales together and report them starting at line number one.After listing all RQ sales,enter "Subtotal -RQ"
in column (a).The remaining sales may then be listed in any order.Enter "Subtotal-Non-RQ"in column (a)after this Listing.Enter
"Total"in column (a)as the Last Line of the schedule.Report subtotals and total for columns (9)through (k)
5.In Column (c),identify the FERC Rate Schedule or Tariff Number.On separate Lines,List all FERC rate schedules or tariffs under
which service,as identified in column (b),is provided.
6.For requirements RQ sales and any type of-service involving demand charges imposed on a monthly (or Longer)basis,enter the
average monthly billing demand in column (d),the average monthly non-coincident peak (NCP)demand in column (e),and the average
monthly coincident peak (CP)
demand in column (f).For all other types of service,enter NA in columns (d),(e)and (f).Monthly NCP demand is the maximum
metered hourly (60-minute integration)demand in a month.Monthly CP demand is the metered demand during the hour (60-minute
integration)in which the supplier's system reaches its monthly peak.Demand reported in columns (e)and (f)must be in megawatts.
Footnote any demand not stated on a megawatt basis and explain.
7.Report in column (g)the megawatt hours shown on bills rendered to the purchaser.
8.Report demand charges in column (h),energy charges in column (i),and the total of any other types of charges,including
out-of-period adjustments,in column (j).Explain in a footnote all components of the amount shown in column (j).Report in column (k)
the total charge shown on bills rendered to the purchaser.
9.The data in column (g)through (k)must be subtotaled based on the RQ/Non-RQ grouping (see instruction 4),and then totaled on
the Last -line of the schedule.The "Subtotal -RQ"amount in column (g)must be reported as Requirements Sales For Resale on Page
401,line 23.The "Subtotal -Non-RQ"amount in column (g)must be reported as Non-Requirements Sales For Resale on Page
401,iine 24.
10.Footnote entries as required and provide explanations following all required data.
MegaWatt Hours REVENUE .
Sold Demand Charges Energy Charges Other Charges Total ($)Line
($)($)($)(h+l+j)No.
(9)(h)(i)(i)(k)
295 13,110 13,110 1
210 22,345 22,345 2
500,350 53,837,155 53,837,155 3
135 8,775 8,775 4
1,645 109,100 109,100 5
21,772 950,812 950,812 6
365,034 77,555,673 77,555,673 7
5,840 925,840 925,840 8
3,600 536,100 536,100 9
4,135 458,305 458,305 10
172,740 300,000 2,656,741 2,956,741 11
15,281 3,361,820 3,361,820 12
4 80 250 330 13
221,518 12,582,163 12,582,163 14
200,562 2,944,214 4,051,428 -50,781 6,944,861
22,650,336 144,796,075 1,895,637,729 5,284,831 2,045,718,635
22,850,898 147,740,289 1,899,689,157 5,234,050 2,052,663,496
FERC FORM NO.1 (ED.12-90)Page 311.7
Name of Respondent This Re ort Is.Date of Report Year of Report
PaciflCorp (1)X An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
SALES FOR RESALE (Account 447)
1.Report all sales for resale (i.e.,sales to purchasers other than ultimate consumers)transacted on a settlement basis other than
power exchanges during the year.Do not report exchanges of electricity (i.e.,transactions involving a balancing of debits and credits
for energy,capacity,etc.)and any settlements for imbalanced exchanges on this schedule.Power exchanges must be reported on the
Purchased Power schedule (Page 326-327).
2.Enter the name of the purchaser in column (a).Do note abbreviate or truncate the name or use acronyms.Explain in a footnote any
ownership interest or affiliation the respondent has with the purchaser.
3.In column (b),enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows:
RQ -for requirements senrice.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 semice).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 sentices 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 De Tiand (MW)
No.(Footnote Affiliations)C ssin TSachne ulmb
r
DMen
a d (Month N Demant Month yC emand
(a)(b)(c)(d)(e)(f)
1 PowerEX AD WSPP ,NA NA NA
2 PowerEX OS WSPP NA NA NA
3 PowerEX SF WSPP NA NA NA
4 PublicService Company of Colorado AD 320 NA NA NA
5 Public Service Company of Colorado LF 320 176 176 172
6 PublicService Company of Colorado OS T-3 NA NA NA
7 PublicSemice Company of Colorado OS WSPP NA NA NA
8 PublicService Company of Colorado SF T-3 NA NA NA
9 PublicSenrice Company of Colorado SF WSPP 53 0 0
10 PublicService Company of New Mexico AD WSPP NA NA NA
11 PublicService Company of New Mexico OS WSPP NA NA NA
12 PublicService Company of New Mexico SF WSPP 468 0 0
13 Public Utility District No.1 of Dougla SF T-3 NA NA NA
14 Public Utility District No.1 of Okanog LF T-12 NA NA NA
Subtotal RQ 0 0 0
Subtotal non-RQ 0 0 0
Total 0 0 0
FERC FORM NO.1 (ED.12-90}Page 310.8
Name of Respondent This Report is:Date of Report Year of Report
PacifiCorp (1)X An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
SALES FOR RESALE (Account 447)(Continued)
OS -for other service.use this categony 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 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 averagemonthlycoincidentpeak(CP)
demand in column (f).For all other types of senrice,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)0.
(9)(h)(i)(j)(k)
-2 -33 -33 1
364 15,050 15,050 2
393,553 49,261,449 49,261,449 3
-1,848,657 -1,848,657 4
1,152,178 29,377,920 25,601,395 54,979,315 5
1,385 157,800 157,800 6
11,016 888,669 1,500 890,169 7
25 12,500 12,500 8
259,885 525 13,355,247 13,355,772 9
3,075 3,075 10
39,231 4,134,435 453,375 4,587,810 11
418,257 14,050 60,105,595 60,119,645 12
6,520 599,610 599,610 13
29,535 445,978 445,978 14
200,562 2,944,214 4,051,428 -50,781 6,944,861
22,650,336 144,796,075 1,895,637,729 5,284,831 2,045,718,635
22,850,898 147,740,289 1,899,689,157 5,234,050 2,052,663,496
FERC FORM NO.1 (ED.12-90)Page 311.8
Name of Respondent This Re ort Is:Date of Report Year of Report
PacifiCorp (1)X An Original (Mo,Da,Yr)Dec.31 2001(2)A Resubmission //
SALES FOR RESALE(Account 447)
1.Report all sales for resale (i.e.,sales to purchasers other than ultimate consumers)transacted on a settlement basis other than
power exchanges during the year.Do not report exchanges of electricity (i.e.,transactions involving a balancing of debits and credits
for energy,capacity,etc.)and any settlements for imbalanced exchanges on this schedule.Power exchanges must be reported on the
Purchased Power schedule (Page 326-327).
2.Enter the name of the purchaser in column (a).Do note abbreviate or truncate the name or use acronyms.Explain in a footnote any
ownership interest or affiliation the respondent has with the purchaser.
3.In column (b),enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows:
RQ -for requirements service.Requirements service is service which the supplier plans to provide on an ongoing basis (i.e.,the
supplier includes projected load for this service in its system resource planning).In addition,the reliability of requirements service must
be the same as,or second only to,the supplier's service to its own ultimate consumers.
LF -for tong-term service."Long-term"means five years or Longer and "firm"means that service cannot be interrupted for economic
reasons and is intended to remain reliable even under adverse conditions (e.g.,the supplier must attempt to buy emergency energy
from third parties to maintain deliveries of LF service).This category should not be used for Long-term firm service which meets the
definition of RQ service.For all transactions identified as LF,provide in a footnote the termination date of the contract defined as the
earliest date that either buyer or setter can unilaterally get out of the contract.
IF -for intermediate-term firm service.The same as LF service except that "intermediate-term"means longer than one year but 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 PublicAuthority Statistical FERC Rate Avera e Actual De nand (MW)
No.(Footnote Affiliations)s -Sachne Ireb
r
DMenMahr
d (Month N Demant Month y
CmP emand
(a)(b)(c)(d)(e)(f)
1 Public Utility District No.2 of Grant SF WSPP NA NA NA
2 Puget Sound Energy AD 254 NA NA NA
3 Puget Sound Energy LF 254 200 200 200
4 Puget Sound Energy OS T-3 NA NA NA
5 Puget Sound Energy OS WSPP NA NA NA
6 Puget Sound Energy SF T-3 NA NA NA
7 Puget Sound Energy SF WSPP NA 0 NA
8 Redding,City of AD 364 NA NA NA
9 Redding,City of AD 364 NA NA NA
10 Redding,City of SF WSPP NA NA NA
11 Reliant Energy Services,Inc.SF WSPP NA NA NA
12 Riverside,City of OS WSPP NA NA NA
13 Riverside,City of SF WSPP NA NA NA
14 Sacramento Municipal Utility District AD 250 NA NA NA
Subtotal RQ 0 0 0
Subtotal non-RQ 0 0 0
Total 0 0 0
FERC FORM NO.1 (ED.12-90)Page 310.9
Name of Respondent This Re ort is:Date of Report Year of Report
PacifiCorp (1)X An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
SALES FOR RESALE (Account 447)(Continued)
OS -for other service.use this category only for those services which cannot be placed in the above-defined categories,such as all
non-firm service regardless of the Length of the contract and service from designated units of Less than one year.Describe the nature
of the service in a footnote.
AD -for Out-of-period adjustment.Use this code for any accounting adjustments or "true-ups"for service provided in prior reporting
years.Provide an explanation in a footnote for each adjustment.
4.Group requirements RQ sales together and report them starting at line number one.After listing all RQ sales,enter "Subtotal -RQ"
in column (a).The remaining sales may then be listed in any order.Enter "Subtotal-Non-RQ"in column (a)after this Listing.Enter
"Total"in column (a)as the Last Line of the schedule.Report subtotals and total for columns (9)through (k)
5.In Column (c),identify the FERC Rate Schedule or Tariff Number.On separate Lines,List all FERC rate schedules or tariffs under
which service,as identified in column (b),is provided.
6.For requirements RQ sales and any type of-service involving demand charges imposed on a monthly (or Longer)basis,enter the
average monthly billing demand in column (d),the average monthly non-coincident peak (NCP)demand in column (e),and the average
monthly coincident peak (CP)
demand in column (f).For all other types of service,enter NA in columns (d),(e)and (f).Monthly NCP demand is the maximum
metered hourly (60-minute integration)demand in a month.Monthly CP demand is the metered demand during the hour (60-minute
integration)in which the supplier's system reaches its monthly peak.Demand reported in columns (e)and (f)must be in megawatts.
Footnote any demand not stated on a megawatt basis and explain.
7.Report in column (g)the megawatt hours shown on bills rendered to the purchaser.
8.Report demand charges in column (h),energy charges in column (i),and the total of any other types of charges,including
out-of-period adjustments,in column (j).Explain in a footnote all components of the amount shown in column (j).Report in column (k)
the total charge shown on bills rendered to the purchaser.
9.The data in column (g)through (k)must be subtotaled based on the RQ/Non-RQ grouping (see instruction 4),and then totaled on
the Last -line of the schedule.The "Subtotal -RQ"amount in column (g)must be reported as Requirements Sales For Resale on Page
401,line 23.The "Subtotal -Non-RQ"amount in column (g)must be reported as Non-Requirements Sales For Resale on Page
401,iine 24.
10.Footnote entries as required and provide explanations following all required data.
MegaWatt Hours REVENUE .
Sold Demand Charges Energy Charges Other Charges Total ($)ne
($)($)($)(h+i+j)-
(9)(h)(i)(j)(k)
5,290 852,100 852,100 1
49,738 49,738 2
1,051,201 32,136,000 18,056,665 50,192,665 3
205 3,288 3,288 4
12 2,400 1,400 3,800 5
22,135 1,014,339 1,014,339 6
146,552 14,373,310 14,373,310 7
-363,887 -363,887 8
-612,245 -612,245 9
162 10,499 10,499 10
205,815 22,855,158 22,855,158 11
30 900 900 12
4,500 1,984,500 1,984,500 13
-341,655 -341,655 14
200,562 2,944,214 4,051,428 -50,781 6,944,861
22,650,336 144,796,075 1,895,637,729 5,284,831 2,045,718,635
22,850,898 147,740,289 1,899,689,157 5,234,050 2,052,663,496
FERC FORM NO.1 (ED.12-90)Page 311.9
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)X An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
SALES FOR RESALE (Account 447)
1.Report all sales for resale (i.e.,sales to purchasers other than ultimate consumers)transacted on a settlement basis other than
power exchanges during the year.Do not report exchanges of electricity (i.e.,transactions involvinga balancing of debits and 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 semice.Requirements senrice 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 senrice 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 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 Companyor Public Authority Statistical FERC Rate Avera e Actual De Tiand (MW)
No.(Footnote Affiliations)a on TSaÎihe Ir br DMenMahr
d (Month N Demant Month y
CmP emand
(a)(b)(c)(d)(e)(f)
1 Sacramento Municipal Utility District LF 250 NA NA NA
2 Sacramento Municipal Utility District OS 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 AD WSPP NA NA NA
7 San Diego Gas &Electric Company SF WSPP NA NA NA
8 Santa Clara,City of SF 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 LF 258 75 75 63
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 This Report Is:Date of Report Year of Report
PacifiCorp (1)OX An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission I /
SALES FOR RESALE (Account 447)(Continued)
OS -for other service.use this category only for those services which cannot be placed in the above-defined categories,such as all
non-firm senrice 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 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+;)0.
(9)(h)(i)(j)(k)
436,110 6,476,233 6,476,233 1
525 14,430 14,430 2
96,002 10,701,656 10,701,656 3
50,414 2,764,970 2,764,970 4
90,144 3,756,048 3,756,048 5
-26 -428 -428 6
896,541 14,913,612 14,913,612 7
35,022 1,943,915 1,943,915 8
32,410 7,600,425 7,600,425 9
71 1,065 1,065 10
171,745 27,139,476 27,139,476 11
-828,593 -828,593 12
-585,862 -585,862 13
454,589 15,012,000 9,364,533 24,376,533 14
200,562 2,944,214 4,051,428 -50,781 6,944,861
22,650,336 144,796,075 1,895,637,729 5,284,831 2,045,718,635
22,850,898 147,740,289 1,899,689,157 5,234,050 2,052,663,496
FERC FORM NO.1 (ED.12-90)Page 311.10
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)DX An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
SALES FOR RESALE (Account 447)
1.Report all sales for resale (i.e.,sales to purchasers other than ultimate consumers)transacted on a settlement basis other than
power exchanges during the year.Do not report exchanges of electricity (i.e.,transactions involving a balancing of debits and credits
for energy,capacity,etc.)and any settlements for imbalanced exchanges on this schedule.Power exchanges must be repoded 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 senrice.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 senrice 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)Cla sin TS he ulmb
r
DMe
a d (Month N Demant MonthAywCP emand
(a)(b)(c)(d)(e)(f)
1 Sierra Pacific Power Company OS WSPP NA NA NA
2 Sierra Pacific Power Company SF WSPP NA NA NA
3 Snohomish County Public Utility Distric SF WSPP NA NA NA
4 Southern California Edison Company LF 248 200 200 200
5 Springfield Utility Board LF 423 37 33 25
6 Springfield Utility Board SF T-3 NA NA NA
7 State of California AD 311 NA NA NA
8 State of California LF 311 100 100 100
9 State of California SF WSPP NA NA NA
10 Tacoma,City of SF WSPP NA NA NA
11 Tractebel Energy Marketing,Inc.SF WSPP NA NA NA
12 TransAlta Energy Marketing Corporation OS WSPP NA NA NA
13 TransAlta Energy Marketing Corporation SF WSPP NA NA NA
14 Tri-State Generation and Transmission A 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 310.11
Name of Respondent This Re ort Is:Date of Report Year of Report
PacifiCorp (1)X An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
SALES FOR RESALE (Account 447)(Continued)
OS -for other service.use this category only for those services which cannot be placed in the above-defined categories,such as all
non-firm service regardless of the Length of the contract and service from designated units of Less than one year.Describe the nature
of the service in a footnote.
AD -for Out-of-period adjustment.Use this code for any accounting adjustments or "true-ups"for service provided in prior reporting
years.Provide an 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 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 RQINon-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 ($)Lme
($)(S)($)(h+i+;)No.
(9)(h)(i)(j)(k)
1,310 50,555 50,555 1
262,895 41,744,390 41,744,390 2
1,750 199,680 199,680 3
1,089,042 24,648,000 67,397,128 92,045,128 4
192,742 2,155,820 6,995,641 9,151,461 5
145,595 2,902,069 2,902,069 6
-1,032,246 -1,032,246 7
613,200 21,036,000 13,637,568 34,673,568 8
14,463 4,888,450 4,888,450 9
2,108 665,690 665,690 10
12,400 1,744,200 1,744,200 11
175 78,750 78,750 12
497,861 57,404,268 57,404,268 13
22,320 815,808 20,300 836,108 14
200,562 2,944,214 4,051,428 -50,781 6,944,861
22,650,336 144,796,075 1,895,637,729 5,284,831 2,045,718,635
22,850,898 147,740,289 1,899,689,157 5,234,050 2,052,663,496
FERC FORM NO.1 (ED.12-90)Page 311.11
Name of Respondent This Re ort Is:Date of Report Year of Report
PacifiCorp (1)X An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
SALES FOR RESALE (Account 447)
1.Report all sales for resale (i.e.,sales to purchasers other than ultimate consumers)transaeted on a settlement basis other than
power exchanges during the year.Do not report exchanges of electricity (i.e.,transactions involvinga balancing of debits and credits
for energy,capacity,etc.)and any settlements for imbalanced exchanges on this schedule.Power exchanges must be reported on the
Purchased Power schedule (Page 326-327).
2.Enter the name of the purchaser in column (a).Do note abbreviate or truncate the name or use acronyms.Explain in a footnote any
ownership interest or affiliation the respondent has with the purchaser.
3.In column (b),enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows:
RQ -for requirements service.Requirements service is service which the supplier plans to 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 padies 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 senrice.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 De nand (MW)
No.(Footnote Affiliations)a s -SaÎihe Irenb
r
DMenahr
d (Month N Demant Month y
CmP emand
(a)(b)(c)(d)(e)(f)
1 Tri-State Generation and Transmission A SF WSPP 370 370 80
2 Tucson Gas &Electric Company OS WSPP NA NA NA
3 Tucson Gas &Electric Company SF WSPP NA NA NA
4 Utah Associated Municipal Power Systems OS WSPP NA NA NA
5 Utah Associated Municipal Power Systems SF WSPP NA NA NA
6 Utah Municipal Power Agency LF 433 8 8 8
7 Utah Municipal Power Agency LF 433 32 32 32
8 Utah Municipal Power Agency OS T-3 NA NA NA
9 Utah Municipal Power Agency SF T-3 NA NA NA
10 Wafertech LF T-12 10 10 10
11 Western Area Power Administration LF 313 NA NA NA
12 Westem Area Power Administration OS WSPP NA NA NA
13 Western Area Power Administration SF WSPP NA NA NA
14 Williams Energy Services Co.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 310.12
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)DXAn Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
SALES FOR RESALE (Account 447)(Continued)
OS -for other service.use this category only for those services which cannot be placed in the above-defined categories,such as all
non-firm service regardless of the Length of the contract and service from designated units of Less than one year.Describe the nature
of the service in a footnote.
AD -for Out-of-period adjustment.Use this code for any accounting adjustments or "true-ups"for service provided in prior reporting
years.Provide an explanation in a footnote for each adjustment.
4.Group requirements RQ sales together and repon them stading 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.Repon 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-senrice 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
(S)($)(S)(h+i+j)No.
(9)(h)(i)(j)(k)
233,139 16,924 13,435,881 13,452,805 1
12,452 1,780,162 1,780,162 2
22,273 3,626,730 3,626,730 3
7,725 503,474 503,474 4
8,825 596,555 596,555 5
48,617 1,536,000 1,015,281 2,551,281 6
132,664 645,950 3,183,936 3,829,886 7
3,233 156,830 156,830 8
886 78,906 78,906 9
87,600 132,000 1,296,480 1,428,480 10
434,680 13,909,760 13,909,760 11
19,153 1,194,637 1,194,637 12
60,477 9,273,598 9,273,598 13
-52 -3,825 -3,825 14
200,562 2,944,214 4,051,428 -50,781 6,944,861
22,650,336 144,796,075 1,895,637,729 5,284,831 2,045,718,635
22,850,898 147,740,289 1,899,689,157 5,234,050 2,052,663,496
FERC FORMNO.1 (ED.12-90)Page 311.12
Name of Respondent This Re ort Is:Date of Report Year of Report
PacifiCorp (1)X An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
SALES FOR RESALE (Account 447)
1.Report all sales for resale (i.e.,sales to purchasers other than ultimate consumers)transacted on a settlement basis other than
power exchanges during the year.Do not report exchanges of electricity (i.e.,transactions involving a balancing of debits and credits
for energy,capacity,etc.)and any settlements for imbalanced exchanges on this schedule.Power exchanges must be reported on the
Purchased Power schedule (Page 326-327).
2.Enter the name of the purchaser in column (a).Do note abbreviate or truncate the name or use acronyms.Explain in a footnote any
ownership interest or affiliation the respondent has with the purchaser.
3.In column (b),enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows:
RQ -for requirements service.Requirements service is senrice 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 senrice."Long-term"means five years or Longer and "firm"means that service cannot be interrupted for economic
reasons and is intended to remain reliable even under adverse conditions (e.g.,the supplier must attempt to buy emergency energy
from third parties to maintain deliveries of LF service).This category should not be used for Long-term firm service which meets the
definition of RQ service.For all transactions identified as LF,provide in a footnote the termination date of the contract defined as the
earliest date that either buyer or setter can unilaterally get out of the contract.
IF -for intermediate-term firm service.The same as LF service except that "intermediate-term"means longer than one year but Less
than five years.
SF -for short-term firm service.Use this category for all firm services where the duration of each period of commitment for service is
one year or less.
LU -for Long-term service from a designated generating unit."Long-term"means five years or Longer.The availability and reliability of
service,aside from transmission constraints,must match the availability and reliability of designated unit.
IU -for intermediate-term service from a designated generating unit.The same as LU service except that "intermediate-term"means
Longer than one year but Less than five years.
Line Name of Company or Public Authority Statistical FERC Rate Avera e Actual De nand (MW)
No.(Footnote Affiliations)n
TSaÎi
u br DMer
a d (Month N Demant Month yœC emand
(a)(b)(c)(d)(e)(f)
1 Williams Energy Services Co.SF WSPP NA NA NA
2 Accrual adjustment NA NA NA NA
3 0 0 0
4 0 0 0
5 0 0 0
6 0 0 0
7 0 0 0
8 0 0 0
9 0 0 0
10 0 0 0
11 0 0 0
12 0 0 0
13 0 0 0
14 0 0 0
Subtotal RQ 0 0 0
Subtotal non-RQ 0 0 0
Total 0 0 0
FERC FORM NO.1 (ED.12-90)Page 310.13
Name of Respondent This Re ort Is:Date of Report Year of Report
PacifiCorp (1)X An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
SALES FOR RESALE (Account 447)(Continued)
OS -for other service.use this category only for those services which cannot be placed in the above-defined categories,such as all
non-firm service regardless of the Length of the contract and service from designated units of Less than one year.Describe the nature
of the service in a footnote.
AD -for Out-of-period adjustment.Use this code for any accounting adjustments or "true-ups"for service provided in prior reportingyears.Provide an explanation in a footnote for each adjustment.
4.Group requirements RQ sales together and report them starting at line number one.After listing all RQ sales,enter "Subtotal -RQ"
in column (a).The remaining sales may then be listed in any order.Enter "Subtotal-Non-RQ"in column (a)after this Listing.Enter"Total"in column (a)as the Last Line of the schedule.Report subtotals and total for columns (9)through (k)
5.In Column (c),identify the FERC Rate Schedule or Tariff Number.On separate Lines,List all FERC rate schedules or tariffs under
which service,as identified in column (b),is provided.
6.For requirements RQ sales and any type of-service involvingdemand 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,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 Page401,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 Energy Charges Other Charges o a
(g)(h)(i)(j)(k)
708,739 118,636,027 118,636,027 1
9,281 2,193,672 2,193,672 2
3
4
5
6
7
8
9
10
11
12
13
14
200,562 2,944,214 4,051,428 -50,781 6,944,861
22,650,336 144,796,075 1,895,637,729 5,284,831 2,045,718,635
22,850,898 147,740,289 1,899,689,157 5,234,050 2,052,663,496
FERC FORM NO.1 (ED.12-90)Page 311.13
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
ELECTRIC OPERATION AND MAINTENANCE EXPENSES
If the amount for previous year is not derived from previously reported figures,e::plain in footnote.
Line Account 'Amount for Arnount forCurrentYearPreviousYearNo(a)(b)(c)
1 1.POWER PRODUCTION EXPENSEs
2 A.Steam Power Generation
3 Operation
4 (500)Operation Supervision and Engineering 27,790,828 10,206,932
5 (501)Fuel 458,552,629 456,031,590
6 (502)Steam Expenses 7,823,036 14,925,133
7 (503)Steamfrom Other Sources 8,084,109 9,520,966
8 (Less)(504)Steam Transferred-Cr.
9 (505)Electric Expenses 1,896,069 1,409,243
10 (506)Miscellaneous Steam Power Expenses 67,770,811 55,839,085
11 (507)Rents 420,534 188,519
12 (509)Allowances
13 TOTAL Operation (Enter Total of Lines 4 thru 12)572,338,016 548,121,468
14 Maintenance
15 (510)Maintenance Supervision and Engineering 2,300,999 2,309,168
16 (511)Maintenance of Structures 10,599,236 912,799
17 (512)Maintenance of Boiler Plant 70,662,236 53,468,303
18 (513)Maintenance of Electric Plant 19,421,569 11,844,444
19 (514)Maintenance of Miscellaneous Steam Plant 19,295,689 25,425,849
20 TOTAL Maintenance(Enter Total of Lines 15 thru 19)122,279,729 93,960,563
21 TOTAL Power Production Expenses-Steam Power (Entr Tot lines 13 &20)694,617,745 642,082,031
22 B.Nuclear Power Generation
23 Operation
24 (517)Operation Supervision and Engineering
25 (518)Fuel
26 (519)Coolants and Water
27 (520)Steam Expenses
28 (521)Steam from Other Sources
29 (Less)(522)Steam Transferred-Cr.
30 (523)Electric Expenses
31 (524)Miscellaneous Nuclear Power Expenses
32 (525)Rents
33 TOTAL Operation (Enter Total of lines 24 thru 32)
34 Maintenance
35 (528)Maintenance Supervision and Engineering
36 (529)Maintenance of Structures
37 (530)Maintenance of Reactor Plant Equipment
38 (531)Maintenance of Electric Plant
39 (532)Maintenance of 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
43 Operation
44 (535)Operation Supervision and Engineering 7,695,974 5,981,419
45 (536)Water for Power
46 (537)Hydraulic Expenses 682,757 1,637,098
47 (538)Electric Expenses
48 (539)Miscellaneous Hydraulic Power Generation Expenses 8,586,121 12,859,831
49 (540)Rents 155,029 490,781
50 TOTAL Operation (Enter Total of Lines 44 thru 49)17,119,881 20,969,129
FERC FORM NO.1 (ED.12-93)Page 320
Name of Respondent This Re ort Is:Date of Report Year of Report(1)An Original (Mo,Da,Yr)1PacifiCorpDec.31,200(2)A Resubmission //
ELECTRIC OPERATION AND MAINTENANCE EXPENSES (Continued)
If thE amount for previous year is not derived from previously reported figures,explain in footnote.
Line Account Amount for Amount forCurrentYearPrevousYearNo(a)(b)(c)
51 C.Hydraulic Power Generation (Continued)
52 Maintenance
53 (541)Mainentance Supervision and Engineering 98,498 612,130
54 (542)Maintenance of Structures 644,627
55 (543)Maintenance of Reservoirs,Dams,and Waterways 1,777,463
56 (544)Maintenance of Electric Plant 1,919,984 371,495
57 (545)Maintenance of Miscellaneous Hydraulic Plant 1,772,960 2,103,235
58 TOTAL Maintenance (Enter Total of lines 53 thru 57)6,213,532 3,086,860
59 TOTAL Power Production Expenses-Hydraulic Power (tot of lines 50 &58)23,333,413 24,055,989
60 D.Other Power Generation
61 Operation 74
62 (546)Operation Supervision and Engineering
63 (547)Fuel 45,330,542 41,677,406
64 (548)Generation Expenses 5,769,939 7,338,874
65 (549)Miscellaneous Other Power Generation Expenses 1,302,871 1,571,747
66 (550)Rents 348,576 291,156
67 TOTAL Operation (Enter Total of lines 62 thru 66)52,751,928 50,879,183
68 Maintenance 95
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)52,751,928 50,879,183
75 E.Other Power Supply Expenses -~<s
76 (555)Purchased Power 2,260,192,525 1,942,486,285
77 (556)System Control and Load Dispatching 465,245 499,559
78 (557)Other Expenses -67,783,447 32,694,308
79 TOTAL Other Power Supply Exp (Enter Total of lines 76 thru 78)2,192,874,323 1,975,680,152
80 TOTAL Power Production Expenses (Total of lines 21,41,59,74 &79)2,963,577,409 2,692,697,355
81 2.TRANSMISSION EXPENSES
82 Operation
83 (560)Operation Supervision and Engineering 4,384,568 6,931,029
84 (561)Load Dispatching 3,355,000 3,546,270
85 (562)Station Expenses 1,076,839 3,615,734
86 (563)Overhead Lines Expenses 1,937,413 985,181
87 (564)Underground Lines Expenses
88 (565)Transmission of Electricity by Others 94,737,373 78,404,520
89 (566)Miscellaneous Transmission Expenses 1,358,298 1,394,904
90 (567)Rents -170,546 861,040
91 TOTAL Operation (Enter Total of lines 83 thru 90)106,678,945 95,738,678
92 Maintenance
93 (568)Maintenance Supervision and Engineering 4,622 1,964
94 (569)Maintenance of Structures 422,381 203,072
95 (570)Maintenance of Station Equipment 6,935,168 2,354,254
96 (571)Maintenance of Overhead Lines 9,144,298 5,580,227
97 (572)Maintenance of Underground Lines 46 1,637
98 (573)Maintenance of Miscellaneous Transmission Plant 27,732 87,995
99 TOTAL Maintenance (Enter Total of lines 93 thru 98)16,534,247 8,229,149
100 TOTAL Transmission Expenses (Enter Total of lines 91 and 99)123,213,192 103,967,827
101 3.DISTRIBUTION EXPENSES
102 Operation
103 (580)Operation Supervision and Engineering 22,869,598 45,137,742
FERC FORM NO.1 (ED.12-93)Page 321
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001
(2)A Resubmission //
ELECTRIC OPERATION AND MAINTENANCE EXPENSES (Continued)
If the amount for previous year is not derived from previously reported figures,e::plain in footnote.
Line Account Amount for Am.ount forCurrentYearPreviousYearNo.(a)(b)(c)
104 3.DISTRIBUTION Expenses (Continued)Íf¾H
105 (581)Load Dispatching 5,946,416 4,769,203
106 (582)Station Expenses 546,586
107 (583)Overhead Line Expenses 13,882,859 23,846,500
108 (584)Underground Line Expenses 228,725
109 (585)Street Lighting and Signal System Expenses
110 (586)Meter Expenses 4,254,415
111 (587)Customer Installations Expenses 33,665 378,297
112 (588)Miscellaneous Expenses 3,894,696 11,888
113 (589)Rents 2,348,851 399,255
114 TOTAL Operation (Enter Total of lines 103 thru 113)54,005,811 74,542,885
115 Maintenance BÑË MR
116 (590)Maintenance Supervision and Engineering 369,221
117 (591)Maintenance of Structures
118 (592)Maintenance of Station Equipment 8,081,114 1,498,598
119 (593)Maintenance of Overhead Lines 46,976,551 44,988,646
120 (594)Maintenance of Underground Lines 15,207,036 7,121,371
121 (595)Maintenance of Line Transformers
122 (596)Maintenance of Street Lighting and Signal Systems 3,014,379 1,113,495
123 (597)Maintenance of Meters 1,844,240 2,379,893
124 (598)Maintenance of Miscellaneous Distribution Plant -6,973,510 401,838
125 TOTAL Maintenance (Enter Total of lines 116 thru 124)68,519,031 57,503,841
126 TOTAL Distribution Exp (Enter Total of lines 114 and 125)122,524,842 132,046,726
127 4.CUSTOMER ACCOUNTS EXPENSEs Si
128 Operation $$$ÑÑ
129 (901)Supervision 11,666,770 21,075,149
130 (902)Meter Reading Expenses 18,942,399 19,043,633
131 (903)Customer Records and Collection Expenses 36,499,802 24,764,926
132 (904)Uncollectible Accounts 17,152,475 8,163,666
133 (905)Miscellaneous Customer Accounts Expenses 1,507,343 905,966
134 TOTAL CustomerAccounts Expenses (Total of lines 129 thru 133)85,768,789 73,953,340
135 5.CUSTOMER SERVICE AND INFORMATIONAL EXPENSES
136 Operation
137 (907)Supervision 10
138 (908)CustomerAssistance Expenses 24,837,698 26,632,425
139 (909)Informationaland Instructional Expenses 439,738 43,410
140 (910)Miscellaneous Customer Service and Informational Expenses 674,581 1,032,532
141 TOTAL Cust.Service and Information.Exp.(Total lines 137 thru 140)25,952,027 27,708,367
142 6.SALES EXPENSES
143 Operation
144 (911)Supervision 18,197 197,315
145 (912)Demonstrating and Selling Expenses 2,912,712
146 (913)Advertising Expenses 21,669 719
147 (916)Miscellaneous Sales Expenses 950,749 2,043,660
148 TOTAL Sales Expenses (Enter Total of lines 144 thru 147)990 615 5 154 406
149 7.ADMINISTRATIVE AND GENERAL EXPENSES
150 Operation
151 (920)Administrative and General Salaries 95,072,996 84,941,723
152 (921)Office Supplies and Expenses 7,013,390 251,668
153 (Less)(922)Administrative Expenses Transferred-Credit 31,421,183 10,709,386
FERC FORM NO.1 (ED.12-93)Page 322
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
ELECTRIC OPERATION AND MAINTENANCE EXPENSES (Continued)
If thE amount for previous year is not derived from previously reported figures,explain in footnote.
Line Account Amount for Am.ount forCurrentYearPreviousYearNo(a)(b)(c)
154 7.ADMINISTRATIVEAND GENERAL EXPENSES (Continued)WѾ
155 (923)Outside Services Employed 52,066,532 39,145,149
156 (924)Property Insurance 7,780,842 7,943,105
157 (925)Injuries and Damages 12,556,429 8,137,061
158 (926)EmployeePensions and Benefits -2,334,451 -1,930,073
159 (927)Franchise Requirements
160 (928)Regulatory Commission Expenses 8,439,902 8,517,445
161 (929)(Less)Duplicate Charges-Cr.2,747,993 2,329,943
162 (930.1)General Advertising Expenses 4,021,479 2,678,307
163 (930.2)Miscellaneous General Expenses 24,172,211 -40,519,532
164 (931)Rents 3,077,285 3,811,255
165 TOTAL Operation (Enter Total of lines 151 thru 164)177,697,439 99,936,779
167 (935)Maintenance of General Plant 2,931,117 422,926
168 TOTAL Admin &General Expenses (Total of lines 165 thru 167)180,628,556 100,359,705
169 TOTAL Elec Op and Maint Expn (Tot 80,100,126,134,141,148,168)3,502,655,430 3,135,887,726
NUMBER OF ELECTRIC DEPARTMENT EMPLOYEES
1.The data on numberof employees should be reported construction employees in a footnote.
for the payroll period ending nearest to October 31,or any 3.The number of employees assignable to the electric
payroll period ending 60 days before or after October 31.department from joint functions of combination utilities may
2.If the respondent's payroll for the reporting period be determined by estimate,on the basis of employee equi-
includes any special construction personnel,include such valents.Show the estimated number of equivalent employees
employes on line 3,and show the number of such special attributed to the electric departmentfrom joint functions.
1.Payroll Period Ended (Date)12/25/2001
2.Total Regular Full-TimeEmployees 6,256
3.Total Part-Timeand Temporary Employees 639
4.Total Employees 6,895
FERC FORM NO.1 (ED.12-93)Page 323
Name of Respondent This Re ort Is:Date of Report Year of Report
PacifiCorp (1)X An Original (Mo,Da,Yr)Dec.31,2001
(2)A Resubmission //
PURCHASED POWER (Account 555)(Includmg power excnanges)
1.Report all power purchases made during the year.Also report exchanges of electricity (i.e.,transactions involvinga 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 senrice).This category should not be used for long-term firm service firm senrice
which meets the definition of RQ service.For all transaction identified as LF,provide in a footnote the termination date of the contract
defined as the earliest date that either buyer or seller can unilaterally get out of the contract.
IF -for intermediate-term firm service.The same as LF service expect that "intermediate-term"means longer than one year but less
than five years.
SF -for short-term service.Use this category for all firm services,where the duration of each period of commitment for service is one
year or less.
LU -for long-term service from a designated generating unit."Long-term"means five years or longer.The availability and reliability of
service,aside from transmission constraints,must match the availability and reliability of the designated unit.
lU -for intermediate-term service from a designated generating unit.The same as LU service expect that "intermediate-term"means
longer than one year but less than five years.
EX -For exchanges of electricity.Use this category for transactions involving a balancing of debits and credits for energy,capacity,etc.
and any settlements for imbalanced exchanges.
OS -for other service.Use this category only for those services which cannot be placed in the above-defined categories,such as all
non-firm service regardless of the Length of the contract and service from designated units of Less than one year.Describe the nature
of the service in a footnote for each adjustment.
Line Name of Company or Public Authority Statistical FERC Rate Average Actual De nand (MW)
Classifi-Schedule or Monthly Billing Average AverageNo.(Footnote Affiliations)cation Tariff Number Demand (MW)Monthly NCP Demant Monthly CP Demand
(a)(b)(c)(d)(e)(f)
1 Power Purchases
2 Allegheny Energy Supply Co.SF NA NA NA
3 American Electric Power OS NA NA NA
4 American Electric Power SF NA NA NA
5 American Electric Power AD NA NA NA
6 Anaheim,City of OS NA NA NA
7 Anaheim,City of SF NA NA NA
8 Aquila Power Corp.OS NA NA NA
9 Aquila Power Corp.SF NA NA NA
10 Aquila Power Corp.LF NA NA NA
11 Aquila Power Corp.AD NA NA NA
12 Arizona Public Service Co.LF NA NA NA
13 Arizona PublicService Co.OS NA NA NA
14 Arizona PublicService Co.SF NA NA NA
Total
FERC FORM NO.1 (ED.12-90)Page 326
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)X An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
PU <cHASED POWEk(Account 555)(continued)(Including power exchanges)
AD -for out-of-period adjustment.Use this code for any accounting adjustments or "true-ups"for service provided in prior 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 involvingdemand 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 explanatonyfootnote.
8.The data in column (g)through (m)must be totalled on the last line of the schedule.The total amount in column (g)must be
reported as Purchases on Page 401,line 10.The total amount in column (h)must be reported as Exchange Received on Page 401,
line 12.The total amount in column (i)must be reported as Exchange Delivered on Page 401,line 13.
9.Footnote entries as required and provide explanations following all required data.
POWER EXCHANGES COST/SETTLEMENT OF POWERMegaWattHours I ine
Purchased MegaWatt Hours MegaWatt Hours Demand Charges Energy Charges Other Charges Total (j+k+l)No.Received Delivered ($)($)($)of Settlement ($)
(g)(h)(i)(j)(k)(I)(m)
67,825 2,380,281 96,000 2,476,281 2
155 7,30C 7,300 3
418,635 38,307,997 38,307,997 4
92 -5,520 -5,520 5
38C 45,575 45,575 6
136,483 42,221,93E 42,221,935 7
125 4,02E 4,025 8
394,29E 54,336,99E 54,336,995 9
437,503 437,503 10
472 33,338 33,338 11
434,06C 18,265,90E 18,265,908 12
205,99E 15,153,19E 250 15,153,446 13
427,524 72,095,231 76,800 72,172,031 14
24,202,778 7,960,551 7,443,777 128,685,249 2,336,835,101 -205,327,825 2,260,192,52E
FERC FORM NO.1 (ED.12-90)Page 327
Name of Respondent This Re ort Is:Date of Report Year of Report
PacifiCorp (1)X An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
PURCHASED POWER (Account 555)(including power excnanges)
1.Report all power purchases made during the year.Also report exchanges of electricity (i.e.,transactions involvinga 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,providein 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 senrice 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
sentice,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 senrice 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 Billmg Average AverageNo.(Footnote Affiliations)cation Tariff Number Demand (MW)Monthly NCP Demant Monthly CP Demand
(a)(b)(c)(d)(e)(f)
1 Arizona Public Service Co.AD NA NA NA
2 Avista Corp.AD NA NA NA
3 Avista Corp.LF 150 150 136
4 Avista Corp.OS NA NA NA
5 Avista Corp.SF NA NA NA
6 Avista Energy,Inc.SF NA NA NA
7 Axia Energy,LP SF NA NA NA
8 Beaver City LF NA NA NA
9 Bell Mountain Power LU 0.2 0.2 0.2
10 Benton County Public Utility Distri SF NA NA NA
11 Biomass One,L.P.LU 22.5 25.2 21.2
12 Birch Creek Hydro LU 2.1 2.4 2.1
13 Black Hills Power &Light Company LU NA 20.3 0.4
14 Black Hills Power &Light Company SF NA NA NA
Total
FERC FORM NO.1 (ED.12-90)Page 326.1
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)X An Original (Mo,Da,Yr)Dec.31,2001
(2)A Resubmission //
PU ACHASED POWl-R(Account 555)(contmued)(Includmg 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 involvingdemand 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 negativeamount.If the settlement amount (l)
include credits or charges other than incremental generation expenses,or (2)excludes certain credits or charges covered by the
agreement,provide an explanatory footnote.
8.The data in column (g)through (m)must be totalled on the last line of the schedule.The total amount in column (g)must be
reported as Purchases on Page 401,line 10.The total amount in column (h)must be reported as Exchange Received on Page 401,
line 12.The total amount in column (i)must be reported as Exchange Delivered on Page 401,line 13.
9.Footnote entries as required and provide explanations following all required data.
POWER EXCHANGES COST/SETTLEMENT OF POWERMegaWattHolirs Line
Purchased MegaWattHours MegaWatt Hours Demand Charges Energy Charges Other Charges Total (j+k+l)No.Received Delivered ($)($)($)of Settlement ($)
(g)(h)(i)(j)(k)(I)(m)
-25 20,121 20,121 1
-313,500 -313,500 2
109,756 2,616,000 9,742,12C 12,358,120 3
106,750 106,750 4
45,676 4,110,671 4,110,671 5
257,747 17,575,894 17,575,894 6
19,20C 3,224,40C 3,224,400 7
67 5,256 5,255 8
1,57E 58,910 22,112 81,022 9
10C 1,80C 1,800 10
185,376 2,111,400 17,802,75E 19,914,159 11
18,17E 734,063 254,49C 988,553 12
1,882 600,000 719,040 1,319,040 13
66,235 2,765,392 2,765,392 14
24,202,778 7,960,551 7,443,777 128,685,249 2,336,835,101 -205,327,825 2,260,192,525
FERC FORMNO.1 (ED.12-90)Page 327.1
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)DXAn Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
PURCHASED POWER (Account 555)(Includmg power excnanges)
1.Report all power purchases made during the year.Also report exchanges of electricity (i.e.,transactions involving a balancing of
debits and credits for energy,capacity,etc.)and any settlements for imbalanced exchanges.
2.Enter the name of the seller or other party in an exchange transaction in column (a).Do not abbreviate or truncate the name or use
acronyms.Explain in a footnote any ownership interest or affiliation the respondent has with the seller.
3.In column (b),enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows:
RQ -for requirements service.Requirements service is service which the supplier plans to provide on an ongoing basis (i.e.,the
supplier includes projects load for this senrice 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 senrice
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 senrice.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 Black Hills Power &Light Company AD NA NA NA
2 Black Hills Power &Light Company OS NA NA NA
3 Bogus Creek LU NA NA NA
4 Boise Cascade Corporation SF NA NA NA
5 Boise Cascade Corporation AD NA NA NA
6 Bonneville Power Administration IF 925 925 888
7 Bonneville Power Administration SF NA NA NA
8 Bonneville Power Administration LU NA NA NA
9 Bonneville Power Administration LF 9.4 8.0 5.4
10 Boston Power LU 0.08 0.04 0.04
11 Boyd,James LU 0.3 0.4 0.2
12 BP Energy Company IU NA NA NA
13 BP Energy Company SF NA NA NA
14 Burbank,City of SF NA NA NA
Total
FERC FORM NO.1 (ED.12-90)Page 326.2
Name of Respondent This Re ort Is:Date of Report Year of Report
PacifiCorp (1)X An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
PU <cHASED POWEk(Account 555)(Continued)(Including power e×changes)
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,providean 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 provideexplanations following all required data.
I POWER EXCHANGES I COST/SETTLEMENT OF POWER -MegaWatt Holire I i l.ine
Purchased MegaWatt Hours MegaWatt Hours Demand Charges Energy Charges Other Charges Total (j+k+I)No.Received Delivered ($)($)($)of Settlement ($)
(g)(h)(i)(j)(k)(I)(m)
73,948 73,948 1
5,12C 304,265 304,265 2
1,22E 34,983 34,983 3
31,915 3,964,768 3,964,768 4
-191,564 -191,564 5
61,299,750 61,299,750 6
290,98E 35,591,266 35,591,265 7
6,844 246,384 246,384 8
51,672 51,672 9
31E 3,219 22,35E 25,575 10
1,93C 18,751 134,904 153,655 11
281,446 17,133,73E 17,133,738 12
75,922 13,701,846 13,701,846 13
18,892 589,096 589,099 14
24,202,778 7,960,551 7,443,777 128,685,249 2,336,835,101 -205,327,825 2,260,192,525
FERC FORM NO.1 (ED.12-90)Page 327.2
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)X An Original (Mo,Da,Yr)Dec.31,2001
(2)A Resubmission //
PURCHASED POWER (Account 555)(Including power excnanges)
1.Report all power purchases made during the year.Also report exchanges of electricity (i.e.,transactions involvinga 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 semice.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 senrice 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 categony 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 Burbank,City of OS NA NA NA
2 California Dept.of Water Resources SF NA NA NA
3 California Power Exchange SF NA NA NA
4 California Power Exchange AD NA NA NA
5 CDM Hydro LU 2.2 3.3 2.1
6 Central Oregon Irrigation District LU 4.4 3.4 2.4
7 Chelan County Public Utility Distri LU NA NA NA
8 Chelan County Public Utility Distri SF NA NA NA
9 Chelan County Public Utility Distri AD NA NA NA
10 Chelan County Public Utility Distri OS NA NA NA
11 Cinergy Services,Inc.SF NA NA NA
12 City of Buffalo LU 0.2 0.2 0.2
13 Colorado Springs Utilities OS NA NA NA
14 Colorado Springs Utilities SF NA NA NA
Total
FERC FORM NO.1 (ED.12-90)Page 326.3
Name of Respondent This Re ort is:Date of Report Year of Report
PacifiCorp (1)X An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
PU (CHASED POWER(Account 555)(continued)(Including power exchanges)
AD -for out-of-period adjustment.Use this code for any accounting adjustments or "true-ups"for service provided in prior 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.
POWER EXCHANGES COST/SETFLEMENT OF POWERMegaWVtHoure Line
Purchased MegaWatt Hours MegaWatt Hours Demand Charges Energy Charges Other Charges Total (j+k+l)No.Received Delivered ($)($)($)of Settlement ($)
(g)(h)(i)(j)(k)(I)(m)
472 25,08E 25,086 1
TOC 6,00C 6,000 2
4,66E 914,171 84,631 998,802 3
37C 5,000 5,000 4
19,062 763,646 266,865 1,030,511 5
21,04E 455,109 1,603,933 2,059,042 6
234,23E 3,010,393 3,010,393 7
11,40C 579,60C 579,600 8
117,797 117,797 9
340 340 10
61,60C 7,638,40C 7,638,400 11
1,79E 19,380 41,827 61,207 12
32 765 765 13
6,862 1,352,025 1,352,025 14
24,202,778 7,960,551 7,443,777 128,685,249 2,336,835,101 -205,327,825 2,260,192,52E
FERC FORMNO.1 (ED.12-90)Page 327.3
Name of Respondent This Re ort Is.Date of Report Year of Report
PacifiCorp (1)X An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
PURCHASED POWER (Account 555)(Including power excnanges)
1.Report all power purchases made during the year.Also report exchanges of electricity (i.e.,transactions involving a balancing of
debits and credits for energy,capacity,etc.)and any settlements for imbalanced exchanges.
2.Enter the name of the seller or other party in an e×change 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 senrice 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 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 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 Columbia Storage Power Exchange LF NA NA NA
2 Commercial Energy Management LU 0.2 0.3 0.2
3 ConAgra Energy Services,Inc.SF NA NA NA
4 Constellation Power Source,Inc.AD NA NA NA
5 Constellation Power Source,Inc.OS NA NA NA
6 Constellation Power Sourœ,Inc.SF NA NA NA
7 Coral Power OS NA NA NA
8 Coral Power SF NA NA NA
9 Curtiss Livestock LU NA NA NA
10 Davis County Waste Management LU NA NA NA
11 Davis County Waste Management AD NA NA NA
12 Deschutes Valley Water District LU 4.6 3.3 2.9
13 Deseret Generation &Transmission OS NA NA NA
14 Deseret Generation &Transmission LF NA NA NA
Total
FERC FORM NO.1 (ED.12-90)Page 326.4
Name of Respondent This Re ort Is:Date of Report Year of Report(1)An Original (Mo,Da,Yr)PacifiCorp Dec.31,2001
(2)A Resubmission //
PU <cHASED POWEk(Account 555)(Continued)(Including power exchanges)
AD -for out-of-period adjustment.Use this code for any accounting adjustments or "true-ups"for service provided in prior 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.
POWER EXCHANGES COST/SETTLEMENT OF POWERMR0aWattHours I.ine
Purchased MegaWatt Hours MegaWatt Hours Demand Charges Energy Charges Other Charges Total (j+k+l)No.Received Delivered ($)($)(S)of Settlement ($)
(g)(h)(i)(j)(k)(I)(m)
81,125 1
1,416 60,270 12,46C 72,730 2
79,77E 8,034,750 8,034,750 3
SC 2,750 2,750 4
232 4,95C 4,950 5
647,55E 116,388,252 116,388,252 6
5C 25C 250 7
18,846 1,209,574 1,209,574 8
112 6,596 6,596 9
2,334 57,601 57,601 10
30,645 30,645 11
24,945 449,892 2,150,272 2,600,165 12
37,46C 4,750,899 4,750,899 13
253,241 14,991,462 228,060 15,219,523 14
24,202,778 7,960,551 7,443,777 128,685,249 2,336,835,101 -205,327,825 2,260,192,526
FERC FORM NO.1 (ED.12-90)Page 327.4
Name of Respondent This Re ort Is:Date of Report Year of Report
PacifiCorp (1)X An Original (Mo,Da,Yr)Dec.31,2001
(2)A Resubmission //
PURCHASED POWER (Account 555)(Including power excnanges)
1.Report all power purchases made during the year.Also report exchanges of electricity (i.e.,transactions involvinga 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 senrice."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 senrice 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 Deseret Generation &Transmission LF NA NA NA
2 Deseret Generation &Transmission SF NA NA NA
3 Douglas County Public Utility Dist.LU NA NA NA
4 Douglas County Public Utility Dist.OS NA NA NA
5 Douglas County Public Utility Dist.AD NA NA NA
6 Douglas County Public Utility Dist.SF NA NA NA
7 DR Johnson Lumber Co.LU 8.6 9.7 7.0
8 Duke Energy Trading OS NA NA NA
9 Duke Energy Trading AD NA NA NA
10 Duke Energy Trading SF NA NA NA
11 Dynegy Power Marketing,Inc.OS NA NA NA
12 Dynegy Power Marketing,Inc.SF NA NA NA
13 Eagle Point Irrigation District LU 0.4 0.5 0.3
14 El Paso Merchant Energy,L.P.SF NA NA NA
Total
FERC FORM NO.1 (ED.12-90)Page 326.5
Name of Respondent This Re ort Is:Date of Report Year of Report
PacifiCorp (1)X An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
PU <CHASEDPOWER(Account 555)(Continued)(including power exchanges)
AD -for out-of-period adjustment.Use this code for any accounting adjustments or "true-ups"for service provided in prior 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 involvingdemand 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.
POWER EXCHANGES COST/SETTLEMENT OF POWERMegaWattHours I.ine
Purchased MegaWatt Hours MegaWatt Hours Demand Charges Energy Charges Other Charges Total (j+k+l)No.Received Delivered ($)($)($)of Settlement($)
(g)(h)(i)(j)(k)(I)(m)
-8,393 -662,537 -662,537 1
9,75E 1,640,00C -1,519,000 121,000 2
174,55C 1,999,540 1,999,540 3
40,226 546,43C 546,430 4
13,920 13,920 5
2,696 583,89C 583,890 6
71,77E 783,495 5,699,24C 6,482,735 7
1,096 78,045 78,045 8
-61,596 -61,596 9
691,312 80,980,65C 80,980,650 10
125 15,00C 15,000 11
180,406 30,459,52E 30,459,525 12
2,71E 36,269 244,922 281,191 13
491,811 77,495,204 77,495,204 14
24,202,778 7,960,551 7,443,777 128,685,249 2,336,835,101 -205,327,825 2,260,192,52E
FERC FORM NO.1 (ED.12-90)Page 327.5
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)X An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
PURCHASED POWER (Account 555)(Includmg power excnanges)
1.Report all power purchases made during the year.Also report exchanges of electricity (i.e.,transactions involvinga 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 senrice 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 senrice
which meets the definition of RQ service.For all transaction identified as LF,providein 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 senrice 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 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 Name of Company or Public Authority Statistical FERC Rate Average Actual De Tiand (MW)
Classifi-Schedule or Monthly Billing Average AverageNo.(Footnote Affiliations)cation Tariff Number Demand (MW)Monthly NCP Demant Monthly CP Demand
(a)(b)(c)(d)(e)(f)
1 Enron Power Marketing,Inc.OS NA NA NA
2 Enron Power Marketing,Inc.AD NA NA NA
3 Enron Power Marketing,Inc.SF NA NA NA
4 EugeneWater &Electric Board OS NA NA NA
5 Eugene Water &Electric Board SF NA NA NA
6 Exelon Power Team SF NA NA NA
7 Exelon Power Team OS NA NA NA
8 Falls Creek LU 2.0 3.3 1.2
9 Farmers Irrigation District LU 3.1 3.1 2.1
10 Fery,Loyd LU NA NA NA
11 Fillmore City LF NA NA NA
12 Galesville Dam LU 0.3 0.3 0.1
13 Galesville Dam AD NA NA NA
14 Garland Canal LU 1.3 1.3 1.0
Total
FERC FORM NO.1 (ED.12-90)Page 326.6
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)DX An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
ÞU (CHASED POWEk(Account SSS)(Continued)(including power exchanges)
AD -for out-of-period adjustment.Use this code for any accounting adjustments or "true-ups"for service provided in prior 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 senrice,as
identified in column (b),is provided.
5.For requirements RQ purchases and any type of service involvingdemand 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 reponed as Exchange Received on Page 401,
line 12.The total amount in column (i)must be reported as Exchange Delivered on Page 401,line 13.
9.Footnote entries as required and provide explanations following all required data.
POWER EXCHANGES COST/SETTLEMENT OF POWERMegaWattHolire I ineMegaWattHoursMegaWattHoursDemandChargesEnergyChargesOtherChargesTotal(j+k+l)No.urchased Received Delivered ($)($)($)of Settlement ($)
(g)(h)(i)(j)(k)(!)(m)
63,312 7,369,86E 7,369,868 1
-602 -67,126 -67,126 2
3,393,40C 365,986,25E 365,986,255 3
20C 10,25C 10,250 4
35,93C 4,739,796 4,739,795 5
6,516 822,83E 822,835 6
526 16,82E 16,825 7
11,302 154,517 931,084 1,085,601 8
20,242 271,329 1,684,14E 1,955,477 9
264 15,426 15,425 10
182 19,68C 19,680 11
1,516 37,486 145,68E 183,175 12
-6E -6,401 -6,401 13
8,445 98,699 261,71E 360,417 14
24,202,778 7,960,551 7,443,777 128,685,249 2,336,835,101 -205,327,825 2,260,192,525
FERC FORMNO.1 (ED.12-90)Page 327.6
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)X An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
PURCHASED POWER (Account 555)(Including power excnanges)
1.Report all power purchases made during the year.Also report exchanges of electricity (i.e.,transactions involvinga 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 senrice from a designated generating unit.The same as LU service expect that "intermediate-term"means
longer than one year but less than five years.
EX -For exchanges of electricity.Use this category for transactions involving a balancing of debits and credits for energy,capacity,etc.
and any settlements for imbalanced exchanges.
OS -for other service.Use this category only for those services which cannot be placed in the above-defined categories,such as all
non-firm service regardless of the Length of the contract and service from designated units of Less than one year.Describe the nature
of the service in a footnote for each adjustment.
Line Name of Company or Public Authority Statistical FERC Rate Average Actual 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 General Chemical Corporation OS NA NA NA
2 Geneva Steel SF NA NA NA
3 Georgetown Power LU 0.2 0.2 0.1
4 Glendale,City of OS NA NA NA
5 Glendale,City of SF NA NA NA
6 Grand Valley Power LF NA NA NA
7 Grant County Public Utility Distric AD NA NA NA
8 Grant County Public Utility Distric LF NA NA NA
9 Grant County Public Utility Distric SF NA NA NA
10 Grant County Public Utility Distric LU NA NA NA
11 Grant County Public Utility Distric OS NA NA NA
12 Grant County Public Utility Distric LU NA NA NA
13 Great Salt Lake Minerals LU NA NA NA
14 Great Salt Lake Minerals AD NA NA NA
Total
FERC FORM NO.1 (ED.12-90)Page 326.7
Name of Respondent This Re ort Is:Date of Report Year of Report(1)An Original (Mo,Da,Yr)2 1PacifiCorpDec.31,00(2)A Resubmission //
PU (CHASED POWEk(Account 555)(continued)(Including power exchanges)
AD -for out-of-period adjustment.Use this code for any accounting adjustments or "true-ups"for service provided in prior 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 (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.
POWER EXCHANGES COST/SETTLEMENT OF POWERMegaWattHnnro I.ine
Purchased MegaWatt Hours MegaWatt Hours Demand Charges Energy Charges Other Charges Total (j+k+l)No.Received Delivered ($)($)($)of Settlement ($)
(g)(h)(i)(j)(k)(I)(m)
1,421 21,172 21,173 1
58,00C 3,943,90E 3,943,908 2
1,54E 60,408 21,677 82,085 3
11 8E 88 4
1,322 238,00C 238,000 5
10E 10,584 10,584 6
-118,372 -118,372 7
87,60C 3,593,086 3,593,085 8
59,63E 5,495,50E 5,495,506 9
410,18E 4,218,792 4,218,792 10
8,500 8,500 11
614,80E 6,890,580 6,890,580 12
30,79€3,189,95E 3,189,959 13
4,28E 235,895 235,895 14
24,202,778 7,960,551 7,443,777 128,685,249 2,336,835,101 -205,327,825 2,260,192,525
FERC FORM NO.1 (ED.12-90)Page 327.7
Name of Respondent This Re ort Is:Date of Report Year of Report
PacifiCorp (1)X An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
PURCHASED POWER (Account 555)(Including power excnanges)
1.Report all power purchases made during the year.Also report exchanges of electricity (i.e.,transactions involvinga 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 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 Green Mountain.com AD NA NA NA
2 HeberLight&Power LF NA NA NA
3 Hermiston Generating Company,L.P.LU 246 246 234
4 Hermiston Generating Company,L.P.AD NA NA NA
5 Hinson Power Company,LLC IF NA NA NA
6 Hurricane,City of LF NA NA NA
7 Hurricane,City of AD NA NA NA
8 Idaho Falls,City of LU NA NA NA
9 Idaho Falls,City of AD NA NA NA
10 Idaho Power Company OS NA NA NA
11 IdahoPowerCompany SF NA NA NA
12 Idaho Power Company AD NA NA NA
13 Ingram Warm Springs Ranch LU 0.2 0.3 0.2
14 Intermountain Power Project LU NA NA NA
Total
FERC FORM NO.1 (ED.12-90)Page 326.8
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)X An Original (Mo,Da,Yr)Dec.31,2001
(2)A Resubmission //
PU (CHASE-DPOWEk(Account 555)(continued)(Including power exchanges)
AD -for out-of-period adjustment.Use this code for any accounting adjustments or "true-ups"for service provided in prior 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 senrice,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 e×change.
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.
POWER EXCHANGES COSTISETTLEMENT OF POWERMegaWattHolirs I ine
Purch d MegaWatt Hours MegaWatt Hours Demand Charges Energy Charges Other Charges Total (j+k+I)No.ase Received Delivered ($)($)($)of Settlement ($)
(g)(h)(i)(j)(k)(1)(m)
14 -119,295 -119,295 1
3,234 233,456 233,456 2
1,949,376 33,176,997 43,593,557 175,651 76,946,205 3
121,483 121,483 4
15,945 2,812,338 2,812,338 5
1,065 34,07C 34,070 6
46 1,536 1,536 7
34,297 2,322,000 2,322,000 8
-221,279 -221,279 9
1,21E 74,822 24,950 99,773 10
537,57E 91,329,77E 91,329,775 11
2,342 215,236 215,236 12
1,87C 75,731 26,185 101,916 13
544,334 22,784,672 22,784,673 14
24,202,778 7,960,551 7,443,777 128,685,249 2,336,835,101 -205,327,825 2,260,192,526
FERC FORM NO.1 (ED.12-90)Page 327.8
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)X An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
PURCHASED POWER (Account 555)(Including power exchanges)
1.Report all power purchases made during the year.Also report exchanges of electricity (i.e.,transactions involving a balancing of
debits and credits for energy,capacity,etc.)and any settlements for imbalanced exchanges.
2.Enter the name of the seller or other party in an exchange transaction in column (a).Do not abbreviate or truncate the name or use
acronyms.Explain in a footnote any ownership interest or affiliation the respondent has with the seller.
3.In column (b),enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows:
RQ -for requirements service.Requirements service is service which the supplier plans to provide on an ongoing basis (i.e.,the
supplier includes projects load for this service in its system resource planning).In addition,the reliability of requirement service must
be the same as,or second only to,the supplier's service to its own ultimate consumers.
LF -for long-term firm service."Long-term"means five years or longer and "firm"means that service cannot be interrupted for
economic reasons and is intended to remain reliable even under adverse conditions (e.g.,the supplier must attempt to buy emergency
energy from third parties to maintain deliveries of LF service).This category should not be used for long-term firm service firm service
which meets the definition of RQ service.For all transaction identified as LF,providein 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 Kennecott SF NA NA NA
2 Kennecott AD NA NA NA
3 Lacomb Irrigation LU NA NA NA
4 Lake Siskiyou LU 2.7 3.9 1.0
5 Los Angeles Dept.Of Water &Power OS NA NA NA
6 Los Angeles Dept.Of Water &Power SF NA NA NA
7 Luckey,Paul LU NA NA NA
8 Marsh Valley Hydro &Electric Compa LU 0.4 0.7 0.3
9 Merrill Lynch Capital Services SF NA NA NA
10 Middlefork Irrigation District LU 2.7 2.5 2.2
11 MIECO,Inc.SF NA NA NA
12 Mink Creek Hydro LU 0.7 0.7 0.6
13 Mirant Americas Energy Marketing,L SF NA NA NA
14 Modesto Irrigation District SF NA NA NA
Total
FERC FORM NO.1 (ED.12-90)Page 326.9
Name of Respondent This Re ort is:Date of Report Year of Report
PacifiCorp (1)X An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
PU <cHASED POWEk(Account 555)(contmued)(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 involvingdemand 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 e×penses,or (2)excludes certain credits or charges covered by the
agreement,provide an explanatory footnote.
8.The data in column (g)through (m)must be totalled on the last line of the schedule.The total amount in column (g)must be
reported as Purchases on Page 401,line 10.The total amount in column (h)must be reported as Exchange Received on Page 401,
line 12.The total amount in column (i)must be reported as Exchange Delivered on Page 401,line 13.
9.Footnote entries as required and provide explanations following all required data.
POWER EXCHANGES COSTISETTLEMENT OF POWERMegaWattHoura I.ine
Purchased MegaWatt Hours MegaWatt Hours Demand Charges Energy Charges Other Charges Total (j+k+I)No.Received Delivered ($)($)($)of Settlement ($)
(g)(h)(i)(j)(k)(I)(m)
1,988,918 1,988,918 1
442,305 442,305 2
4,895 1,002,992 1,002,992 3
14,373 252,841 1,270,25E 1,523,100 4
8,815 737,125 4,800 741,925 5
73,576 14,606,505 14,606,505 6
30C 21,53C 21,530 7
3,337 135,119 46,71E 181,838 8
57,60C 13,172,000 13,172,000 9
18,416 162,333 1,478,38E 1,640,718 10
9,80C 211,35C 211,350 11
5,845 219,189 81,832 301,022 12
649,31E 87,882,79E 87,882,796 13
9,142 2,036,98C 2,036,980 14
24,202,778 7,960,551 7,443,777 128,685,249 2,336,835,101 -205,327,825 2,260,192,525
FERC FORM NO.1 (ED.12-90)Page 327.9
Name of Respondent This Re ort Is:Date of Report Year of Report
PacifiCorp (1)X An Original (Mo,Da,Yr)Dec.31,2001
(2)A Resubmission I /
PURCHASED POWER (Account 565)(Includmg power excnanges)
1.Report all power purchases made during the year.Also report exchanges of electricity (i.e.,transactions involvinga 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 senrice in its system resource planning).In addition,the reliability of requirement service must
be the same as,or second only to,the supplier's service to its own ultimate consumers.
LF -for long-term firm service."Long-term"means five years or longer and "firm"means that service cannot be interrupted for
economic reasons and is intended to remain reliable even under adverse conditions (e.g.,the supplier must attempt to buy emergency
energy from third parties to maintain deliveries of LF service).This category should not be used for long-term firm service firm service
which meets the definition of RQ service.For all transaction identified as LF,provide in a footnote the termination date of the contract
defined as the earliest date that either buyer or seller can unilaterally get out of the contract.
IF -for intermediate-term firm service.The same as LF service expect that "intermediate-term"means longer than one year but less
than five.years.
SF -for short-term service.Use this category for all firm services,where the duration of each period of commitment for service is one
year or less.
LU -for long-term service from a designated generating unit."Long-term"means five years or longer.The availability and reliability of
service,aside from transmission constraints,must match the availability and reliability of the designated unit.
IU -for intermediate-term sentice from a designated generating unit.The same as LU service expect that "intermediate-term"means
longer than one year but less than five years.
EX -For exchanges of electricity.Use this categoryfor 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 Monsanto OS NA NA NA
2 Morgan City LF NA NA NA
3 Morgan Stanley Capital Group,Inc.OS NA NA NA
4 Morgan Stanley Capital Group,Inc.SF NA NA NA
5 Municipal Energy Agency of Nebraska OS NA NA NA
6 Municipal Energy Agency of Nebraska SF NA NA NA
7 Municipal Energy Agency of Nebraska AD NA NA NA
8 Murray City LF NA NA NA
9 Nephi City LF NA NA NA
10 NevadaPowerCompany OS NA NA NA
11 NevadaPowerCompany SF NA NA NA
12 Nicholson Sunnybar Ranch LU 0.2 0.2 0.2
13 North Fork Sprague LU 0.2 0.8 0.03
14 Northern California Power Agency SF NA NA NA
Total
FERC FORM NO.1 (ED.12-90)Page 326.10
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)X An Original (Mo,Da,Yr)Dec.31,2001
(2)A Resubmission //
PU RCHASEDÞoWi-R(Account 555)(Continued)(including power exchanges)
AD -for out-of-periodadjustment.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-periodadjustments,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 negativeamount.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,providean explanatory footnote.
8.The data in column (g)through (m)must be totalled on the last line of the schedule.The total amount in column (g)must be
reported as Purchases on Page 401,line 10.The total amount in column (h)must be reported as Exchange Received on Page 401,
line 12.The total amount in column (i)must be reported as Exchange Delivered on Page 401,line 13.
9.Footnote entries as required and provide explanations following all required data.
POWER EXCHANGES I COST/SETTLEMENT OF POWERMgaWettHourc:I Line
Purchased MegaWatt Hours MegaWatt Hours Demand Charges Energy Charges Other Charges Total (j+k+I)No.
Received Delivered ($)($)($)of Settlement ($)
(g)(h)(i)(j)(k)(1)(m)
2,049,725 2,049,725 1
41 1,017 1,017 2
E 9C 90 3
587,454 105,253,437 105,253,437 4
12C 15,00C 15,000 S
9,08E 1,161,36C 1,161,360 6
2E 4,375 4,375 7
67 3.482 3,482 8
1E 1,82E 1,829 9
182,88E 15,369,293 15,369,293 10
255,27C 64,580,95C 64,580,950 11
1,992 78,845 27,902 106,747 12
926 23,834 82,74E 106,583 13
5,04C 1,008,00C 1,008,000 14
24,202,778 7,960,551 7,443,777 128,685,249 2,336,835,101 -205,327,825 2,260,192,525
FERC FORM NO.1 (ED.12-90)Page 327.10
Name of Respondent This Re ort Is:Date of Report Year of Report
PacifiCorp (1)X An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
PURCHASED POWER (Account 555)(Including power exchanges)
1.Report all power purchases made during the year.Also report exchanges of electricity (i.e.,transactions involving a balancing of
debits and credits for energy,capacity,etc.)and any settlements for imbalanced exchanges.
2.Enter the name of the seller or other party in an exchange transaction in column (a).Do not abbreviate or truncate the name or use
acronyms.Explain in a footnote any ownership interest or affiliation the respondent has with the seller.
3.In column (b),enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows:
RQ -for requirements service.Requirements service is service which the supplier plans to provide on an ongoing basis (i.e.,the
supplier includes projects load for this service in its system resource planning).In addition,the reliability of requirement service must
be the same as,or second only to,the supplier's service to its own ultimate consumers.
LF -for long-term firm service."Long-term"means five years or longer and "firm"means that service cannot be interrupted for
economic reasons and is intended to remain reliable even under adverse conditions (e.g.,the supplier must attempt to buy emergency
energy from third parties to maintain deliveries of LF service).This category should not be used for long-term firm service firm service
which meets the definition of RQ senrice.For all transaction identified as LF,providein 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 semice 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 senrices 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 Nucor Corporation IF NA NA NA
2 O.J.Power Company LU 0.05 0.07 0.05
3 Odell Creek LU 0.03 0.05 0.02
4 Oregon Metallurgical Company SF NA NA NA
5 Pacific Northwest Generating Co.SF NA NA NA
6 PacifiCorp Power Marketing OS NA NA NA
7 PacifiCorp Power Marketing AD NA NA NA
8 Pancheri,Inc.LU 0.01 0.01 0.01
9 Payson City Corp.LF NA NA NA
10 Platte River Power Authority OS NA NA NA
11 Portland General Electric Co.AD NA NA NA
12 Portland General Electric Co.OS NA NA NA
13 Portland General Electric Co.SF NA NA NA
14 Portland General Electric Co.LF NA NA NA
Total
FERC FORM NO.1 (ED.12-90)Page 326.11
Name of Respondent This Re ort IS:Date of Report Year of Report
PacifiCorp (1)X An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
PU (CHASED PO\NEk(Account 555)(Continued)(including power exchanges)
AD -for out-of-period adjustment.Use this code for any accounting adjustments or "true-ups"for service provided in prior 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 repod 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 provideexplanations following all required data.
POWER EXCHANGES COST/SETTLEMENT OF POWERMegaWattHolirs I ine
Purchased MegaWatt Hours MegaWatt Hours Demand Charges Energy Charges Other Charges Total (j+k+l)No.Reœived Delivered ($)($)(S)of Settlement ($)
(g)(h)(i)(j)(k)(I)(m)
969,827 969,827 1
477 15,642 6,672 22,314 2
145 2,243 10,77C 13,013 3
8,736 215,71E 215,719 4
417 9,81E 9,818 5
784 75,180 75,180 6
8,156 667,309 667,309 7
42 1,390 59C 1,980 8
1E 2,082 2,083 9
131 19,65C 19,650 10
-5,229 -5,229 11
2,895 86,55E 20,800 107,355 12
515,511 56,538,382 56,538,383 13
23,572 227,533 227,533 14
24,202,778 7,960,551 7,443,777 128,685,249 2,336,835,101 -205,327,825 2,260,192,52E
FERC FORM NO.1 (ED.12-90)Page 327.11
Name of Respondent This Re ort Is:Date of Report Year of Report
PacifiCorp (1)X An Original (Mo,Da,Yr)Dec.31,2001
(2)A Resubmission //
PURCHASED POWER (Account 565)(Includmg 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 categony 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 Powerex OS NA NA NA
2 Powerex SF NA NA NA
3 Powerex AD NA NA NA
4 PPL Montana,LLC AD NA NA NA
5 PPL Montana,LLC OS NA NA NA
6 PPL Montana,LLC SF NA NA NA
7 Preston City Hydro LU 0.3 0.3 0.3
8 Provo City LF NA NA NA
9 Public Service Company of Colorado OS NA NA NA
10 Public Service Company of Colorado SF NA NA NA
11 Public Service Company of New Mexic OS NA NA NA
12 Public Service Company of New Mexic SF NA NA NA
13 Public Service Company of New Mexic AD NA NA NA
14 Puget Sound Energy SF NA NA NA
Total
FERC FORM NO.1 (ED.12-90)Page 326.12
Name of Respondent This Re ort Is:Date of Report Year of Report
PacifiCorp (1)X An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
PU <cHASED POWEk(Account 555)(Continued)(Including power exchanges)
AD -for out-of-period adjustment.Use this code for any accounting adjustments or "true-ups"for service provided in prior 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 averagebilling 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.
POWER EXCHANGES COST/SETTLEMENT OF POWERMegaWattHours Line
Purchased MegaWatt Hours MegaWatt Hours Demand Charges Energy Charges Other Charges Total (j+k+l)No.Received Delivered ($)($)($)of Settlement ($)
(g)(h)(i)(j)(k)(l)(m)
4,406 209,522 209,522 1
270,097 48,226,904 48,226,904 2
-44,813 -44,813 3
-2E -125 -125 4
33C 21,60C 21,600 5
12,374 755,707 755,707 6
2,37E 83,320 33,287 116,607 7
12E 10,776 10,778 8
3,734 209,573 209,573 9
216,016 24,742,394 198,600 24,940,994 10
153,52C 9,893,76E 9,893,765 11
406,01C 59,935,617 59,935,617 12
-10C -14,750 -14,750 13
256,12C 27,621,399 27,621,399 14
24,202,778 7,960,551 7,443,777 128,685,249 2,336,835,101 -205,327,825 2,260,192,525
FERC FORM NO.1 (ED.12-90)Page 327.12
Name of Respondent This Re ort Is:Date of Report Year of Report
PacifiCorp (1)X An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission I /
PURCHASED POWER (Account 555)(Includmg power excnanges)
1.Report all power purchases made during the year.Also report exchanges of electricity (i.e.,transactions involving a balancing of
debits and credits for energy,capacity,etc.)and any settlements for imbalanced exchanges.
2.Enter the name of the seller or other party in an exchange transaction in column (a).Do not abbreviate or truncate the name or use
acronyms.Explain in a footnote any ownership interest or affiliation the respondent has with the seller.
3.In column (b),enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows:
RQ -for requirements service.Requirements service is service which the supplier plans to provide on an ongoing basis (i.e.,the
supplier includes projects load for this service in its system resource planning).In addition,the reliability of requirement service must
be the same as,or second only to,the supplier's service to its own ultimate consumers.
LF -for long-term firm service."Long-term"means five years or longer and "firm"means that service cannot be interrupted for
economic reasons and is intended to remain reliable even under adverse conditions (e.g.,the supplier must attempt to buy emergency
energy from third parties to maintain deliveries of LF service).This category should not be used for long-term firm service firm service
which meets the definition of RQ senrice.For all transaction identified as LF,providein 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 e×changes 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 senrice.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 senrice 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 Puget Sound Energy OS NA NA NA
2 Ralphs Ranch,Inc.LU NA NA NA
3 Redding,City of LF NA NA NA
4 Redding,City of SF NA NA NA
5 Redding,City of OS NA NA NA
6 Reliant Energy Services,Inc.OS NA NA NA
7 Reliant Energy Services,Inc.SF NA NA NA
8 Riverside,City of OS NA NA NA
9 Riverside,City of SF NA NA NA
10 Rocky Mountain Generation Cooperati OS NA NA NA
11 Rocky Mountain Generation Cooperati SF NA NA NA
12 Roseburg Forest Products SF NA NA NA
13 Roseburg Forest Products AD NA NA NA
14 Roush,Neil LU NA NA NA
Total
FERC FORM NO.1 (ED.12-90)Page 326.13
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)OX An Original (Mo,Da,Yr)Dec.31,2001
(2)A Resubmission //
PU <cHASED POWEk(Account 555)(continued)(including power exchanges)
AD -for out-of-period adjustment.Use this code for any accounting adjustments or "true-ups"for service provided in prior 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 involvingdemand 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 repod 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.
POWER EXCHANGES COSTISETTLEMENT OF POWERMP0aWattHolire Line
Purchased MegaWatt Hours MegaWatt Hours Demand Charges Energy Charges Other Charges Total (j+k+l)No.Received Delivered ($)($)($)of Settlement ($)
(g)(h)(i)(j)(k)(I)(m)
38,710 38,710 1
342 24,575 24,575 2
-363,888 -363,888 3
2,63C 153,286 153,286 4
172 7,67C 7,670 5
367 94,775 94,775 6
439,88C 75,621,12E 100,000 75,721,125 7
7,14E 338,994 338,994 8
5,317 571,294 571,294 9
34,88E 2,182,46E 2,182,469 10
586 58,80C 58,800 11
51,083 8,008,82E 8,008,828 12
-1 92,229 92,229 13
30E 17,99C 17,990 14
24,202,778 7,960,551 7,443,777 128,685,249 2,336,835,101 -205,327,825 2,260,192,52E
FERC FORM NO.1 (ED.12-90)Page 327.13
Name of Respondent This Re ort is:Date of Report Year of Report
PacifiCorp (1)X An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
PURCHASED POWER (Account 555)(Including power excnanges)
1.Report all power purchases made during the year.Also report exchanges of electricity (i.e.,transactions involvinga balancing of
debits and credits for energy,capacity,etc.)and any settlements for imbalanced exchanges.
2.Enter the name of the seller or other party in an exchange transaction in column (a).Do not abbreviate or truncate the name or use
acronyms.Explain in a footnote any ownership interest or affiliation the respondent has with the seller.
3.In column (b),enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows:
RQ -for requirements service.Requirements service is service which the supplier plans to provide on an ongoing basis (i.e.,the
supplier includes projects load for this service in its system resource planning).In addition,the reliability of requirement service must
be the same as,or second only to,the supplier's service to its own ultimate consumers.
LF -for long-term firm service."Long-term"means five years or longer and "firm"means that service cannot be interrupted for
economic reasons and is intended to remain reliable even under adverse conditions (e.g.,the supplier must attempt to buy emergency
energy from third parties to maintain deliveries of LF service).This category should not be used for long-term firm service firm service
which meets the definition of RQ service.For all transaction identified as LF,provide in a footnote the termination date of the contract
defined as the earliest date that either buyer or seller can unilaterally get out of the contract.
IF -for intermediate-term firm service.The same as LF service expect that "intermediate-term"means longer than one year but less
than five years.
SF -for short-term service.Use this category for all firm services,where the duration of each period of commitment for service is one
year or less.
LU -for long-term service from a designated generating unit."Long-term"means five years or longer.The availability and reliability of
service,aside from transmission constraints,must match the availability and reliability of the designated unit.
lU -for intermediate-term service from a designated generating unit.The same as LU service expect that "intermediate-term"means
longer than one year but less than five years.
EX -For exchanges of electricity.Use this category for transactions involving a balancing of debits and credits for energy,capacity,etc.
and any settlements for imbalanced exchanges.
OS -for other service.Use this category only for those services which cannot be placed in the above-defined categories,such as all
non-firm service regardless of the Length of the contract and service from designated units of Less than one year.Describe the nature
of the service in a footnote for each adjustment.
Line Name of Company or Public Authority Statistical FERC Rate Average Actual De nand (MW)
Classifi-Schedule or Monthly Billing Average AverageNo.(Footnote Affiliations)cation Tariff Number Demand (MW)Monthly NCP Demant Monthly CP Demand
(a)(b)(c)(d)(e)(f)
1 Sacramento Municipal Utility Distri SF NA NA NA
2 Salt River Project SF NA NA NA
3 Salt River Project OS NA NA NA
4 San Diego Gas &Electric OS NA NA NA
5 San Diego Gas &Electric SF NA NA NA
6 Santa Clara,City of SF NA NA NA
7 Santiam Water Control District LU 0.2 0.2 0.2
8 Seattle City Light OS NA NA NA
9 Seattle City Light SF NA NA NA
10 Sempra Energy Trading Corp.SF NA NA NA
11 SF Phosphates Limited Company lU NA NA NA
12 Sierra Pacific Power Company SF NA NA NA
13 Sierra Pacific Power Company OS NA NA NA
14 Slate Creek AD NA NA NA
Total
FERC FORM NO.1 (ED.12-90)Page 326.14
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)DX An Original (Mo,Da,Yr)Dec.31,2001
(2)A Resubmission I /
PU <CHASED POWER(Account 555)(Continued)(including power exchanges)
AD -for out-of-period adjustment.Use this code for any accounting adjustments or "true-ups"for service provided in prior 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.
POWER EXCHANGES COST/SETTLEMENT OF POWERMegaWattHoure Lme
Purchased MegaWatt Hours MegaWatt Hours DemandCharges Energy Charges Other Charges Total (j+k+I)No.Received Delivered ($)($)($)of Settlement ($)
(g)(h)(i)(j)(k)(I)(m)
20,022 5,423,99E 5,423,995 1
93,126 7,524,624 7,524,624 2
222,61E 24,198,30E 24,198,309 3
37 37C 370 4
4,00C 126,90C 126,900 5
16,29C 883,08E 883,085 6
1,50E 13,632 109,367 122,999 7
8,700 8,700 8
6,17C 563,74E 563,745 9
271,84C 37,400,642 37,400,642 10
52,361 9,091,805 9,091,805 11
205,707 40,691,65C 40,691,650 12
6,66C 284,13E 284,138 13
116,692 116,692 14
24,202,778 7,960 551 7,443,777 128,685,249 2,336,835,101 -205,327,825 2,260,192,525
FERC FORM NO.1 (ED.12-90)Page 327.14
Name of Respondent This Re ort Is:Date of Report Year of Report
PacifiCorp (1)X An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
PURCHASED POWER (Account 555)(Including power excnanges)
1.Report all power purchases made during the year.Also repon exchanges of electricity (i.e.,transactions involvinga 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
longerthan 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 Slate Creek LU 1.4 2.1 0.5
2 Snohomish Public Utility District SF NA NA NA
3 Snohomish Public Utility District AD NA NA NA
4 Snohomish Public Utility District OS NA NA NA
5 Southern California Edison Company LF 422 NA NA
6 Southern California Edison Company AD NA NA NA
7 Spanish Fork City LF NA NA NA
8 Springfield Utility Board SF NA NA NA
9 Springville City LF NA NA NA
10 Stauffer Dry Creek LU 0.7 1.4 0.6
11 Strawberry Electric Service Distric LF NA NA NA
12 Sunnyside Cogeneration Associates LU 52.2 52 41.2
13 Tacoma,City of SF NA NA NA
14 Thayn Ranch Hydro LU 0.1 0.2 0.1
Total
FERC FORM NO.1 (ED.12-90)Page 326.15
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)X An Original (Mo,Da,Yr)Dec.31,2001
(2)A Resubmission //
PU (CHASED POWER(Account 555)(Continued)(Including power exchanges)
AD -for out-of-period adjustment.Use this code for any accounting adjustments or "true-ups"for service provided in prior 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.
POWER EXCHANGES COST/SETTLEMENT OF POWERMegaWattHonr I ine
Purchased MegaWatt Hours MegaWatt Hours Demand Charges Energy Charges Other Charges Total (j+k+l)No.Received Delivered ($)($)($)of Settlement ($)
(g)(h)(i)(j)(k)(1)(m)
8,625 123,776 658,092 781,869 1
25,412 3,185,21E 3,185,215 2
25 5,000 5,000 3
1,04E 286,25C 286,250 4
4,681.960 4,681,960 5
3,168,211 3,168,211 6
52 4,58E 4,589 7
63,20C 2,888,00C 2,888,000 8
42 4,31C 4,310 9
6,456 221,929 90,43C 312,359 10
1E 1,663 1,663 11
386,837 10,039,209 42,848,49E 52,887,704 12
18,531 492,606 492,609 13
722 8,960 26,942 35,903 14
24,202,778 7,960,551 7.443,777 128,685,249 2,336,835,101 -205,327,825 2,260,192,52E
FERC FORM NO.1 (ED.12-90)Page 327.15
Name of Respondent This Re ort Is:Date of Report Year of Report
PacifiCorp (1)X An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission I /
PURCHASED POWER (Account 555)(includmg power excnanges)
1.Report all power purchases made during the year.Also report exchanges of electricity (i.e.,transactions involving a balancing of
debits and credits for energy,capacity,etc.)and any settlements for imbalanced exchanges.
2.Enter the name of the seller or other party in an exchange transaction in column (a).Do not abbreviate or truncate the name or use
acronyms.Explain in a footnote any ownership interest or affiliation the respondent has with the seller.
3.In column (b),enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows:
RQ -for requirements service.Requirements service is service which the supplier plans to provide on an ongoing basis (i.e.,the
supplier includes projects load for this seivice 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 semice.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 natureoftheserviceinafootnoteforeachadjustment.
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 The Power Company of America AD NA NA NA
2 Tractebel Energy Marketing,Inc.SF NA NA NA
3 TransAlta Energy Marketing Corp.SF NA NA NA
4 TransAlta Energy Marketing Corp.LF NA NA NA
5 TransAlta Energy Marketing Corp.AD NA NA NA
6 Tri-State Generation &Transmission OS NA NA NA
7 Tri-State Generation &Transmission SF NA NA NA
8 Tri-State Generation &Transmission LF 50 48.8 44
9 Tucson Electric Power SF NA NA NA
10 Tucson Electric Power OS NA NA NA
11 United States Bureau of Reclamation AD NA NA NA
12 Utah Assoc.MunicipalPower Systems OS NA NA NA
13 Utah Municipal Power Agency SF NA NA NA
14 UtiliCorp United,Inc.SF NA NA NA
Total
FERC FORM NO.1 (ED.12-90)Page 326.16
Name of Respondent This Re ort Is:Date of Report Year of Report
PacifiCorp (1)X An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
PU <cHASED ÞOWER(Account 555)(continued)(including power exchanges)
AD -for out-of-period adjustment.Use this code for any accounting adjustments or "true-ups"for service provided in prior 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 involvingdemand 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 ma×imum 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 (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.
I POWER EXCHANGES I COST/SETTLEMENT OF POWERMegaWattHnnrii Line
Purchased MegaWatt Hours MegaWatt Hours Demand Charges Energy Charges Other Charges Total (j+k+l)No.Received Delivered ($)($)($)of Settlement ($)
(g)(h)(i)(j)(k)(I)(m)
-1,428,080 -1,428,080 1
32,40C 935,78C 935,780 2
489,246 53,543,213 200,000 53,743,213 3
2,176,425 77,742,376 77,742,379 4
12C 12,506 12,506 5
107,251 11,536,997 11,536,997 6
47,66E 5,335,441 5,335,441 7
274,247 6,432,000 3,938,725 10,370,725 8
2,985 369,85C 369,850 9
48,44E 3,861,817 3,861,817 10
934 15,295 15,295 11
1,69E 145,100 145,100 12
646 97,00C 97,000 13
6C 1,02C 1,020 14
24,202,778 7,960,551 7,443,777 128,685,249 2,336,835,101 -205,327,825 2,260,192,525
FERC FORM NO.1 (ED.12-90)Page 327.16
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)DXAn Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
PURCHASED POWER (Account 555)(Including power exchanges)
1.Report all power purchases made during the year.Also report exchanges of electricity (i.e.,transactions involving a balancing of
debits and credits for energy,capacity,etc.)and any settlements for imbalanced exchanges.
2.Enter the name of the seller or other party in an exchange transaction in column (a).Do not abbreviate or truncate the name or use
acronyms.Explain in a footnote any ownership interest or affiliation the respondent has with the seller.
3.In column (b),enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows:
RQ -for requirements service.Requirements service is service which the supplier plans to provide on an ongoing basis (i.e.,the
supplier includes projects load for this service in its system resource planning).In addition,the reliability of requirement service must
be the same as,or second only to,the supplier's service to its own ultimate consumers.
LF -for long-term firm service."Long-term"means five years or longer and "firm"means that service cannot be interrupted for
economic reasons and is intended to remain reliable even under adverse conditions (e.g.,the supplier must attempt to buy emergency
energy from third parties to maintain deliveries of LF service).This category should not be used for long-term firm senrice 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 senrice.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 Walla Walla,City of LU 2.0 1.8 1.4
2 Warm Springs Forest Products LU NA NA NA
3 Warm Springs Power Enterprises LU 19.6 12.6 8.0
4 Washington City LF NA NA NA
5 Western Area Power Administration SF NA NA NA
6 Western Area Power Administration OS NA NA NA
7 Western Area Power Administration AD NA NA NA
8 Whitney,A.C.LU NA NA NA
9 Wiggins,Duane LU NA NA NA
10 Willamette Industries OS NA NA NA
11 Williams Energy Market &Trading Co SF NA NA NA
12 Yakima Tieton LU 1.0 0.6 0.5
13 Accrual Adj.NA NA NA
14
Total
FERC FORM NO.1 (ED.12-90)Page 326.17
Name of Respondent This Re ort Is:Date of Report Year of Report
PacifiCorp (1)X An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
PU <cHASI-D POWER(Account 555)(contmued)(includmg 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 involvingdemand 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 repoded 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,providean explanatory footnote.
8.The data in column (g)through (m)must be totalled on the last line of the schedule.The total amount in column (g)must be
reported as Purchases on Page 401,line 10.The total amount in column (h)must be reported as Exchange Received on Page 401,
line 12.The total amount in column (i)must be reported as Exchange Delivered on Page 401,line 13.
9.Footnote entries as required and provide explanations following all required data.
POWER EXCHANGES COST/SETTLEMENT OF POWER .MegaWatt Hours Line
Purchased MegaWatt Hours MegaWatt Hours Demand Charges Energy Charges Other Charges Total (j+k+l)No.Received Delivered ($)($)($)of Settlement ($)
(g)(h)(i)(j)(k)(I)(m)
14,326 139,736 1,506,604 1,646,340 1
15,235 1,403,554 1,403,554 2
75,503 2,048,592 5,298,69E 7,347,291 3
4C 2,27E 2,279 4
2,412 384,22E 384,225 5
56,266 4,037,45E 22,325 4,059,784 6
694 56,590 56,590 7
1 42 43 8
24 1,61E 1,615 9
1,396,598 1,396,598 10
530,621 81,535,891 47,520 81,583,411 11
7,021 63,706 697,226 760,932 12
-227,909,904 -227,909,904 13
14
24,202,778 7,960,551 7,443,777 128,685,249 2,336,835,101 -205,327,825 2,260,192,52E
FERC FORM NO.1 (ED.12-90)Page 327.17
Name of Respondent This Report is:Date of Report Year of Report
PacifiCorp (1)X An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
PURCHASED POWER (Account 565)(Including power excnanges)
1.Report all power purchases made during the year.Also report exchanges of electricity (i.e.,transactions involvinga 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 senrice 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 Power Exchanges
2 Arizona Public Service Co.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 (17)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 326.18
Name of Respondent This Report is:Date of Report Year of Report
PacifiCorp (1)X An Original (Mo,Da,Yr)Dec.31 2001
(2)A Resubmission //
PU <cHASED POWEk(Account 555)(continued)(including power exchanges)
AD -for out-of-period adjustment.Use this code for any accounting adjustments or "true-ups"for senrice 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 negativeamount.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.
POWER EXCHANGES COST/SETTLEMENT OF POWERMgaWattHnnrs Line
Purchased MegaWatt Hours MegaWatt Hours Demand Charges Energy Charges Other Charges Total (j+k+I)No.Received Delivered ($)($)($)of Settlement ($)
(g)(h)(i)(j)(k)(I)(m)
1
573,067 571,975 2,185,893 2,185,893 2
2,037 161 67,566 67,566 3
27,600 23,500 -922,700 -922,700 4
2,083 5
131 6
257 -3,855 -3,855 7
87,852 32,646 1,814,565 1,814,565 8
50,000 50,000 -8,363 -8,363 9
-592 -592 10
1,280 14,581 -249,658 -249,658 11
2,473,529 2,473,529 -36,390,476 -36,390,476 12
112,004 110,105 -1,128,233 -1,128,233 13
2,893,855 2,893,515 -1,130,000 -1,130,000 14
24,202,778 7,960,551 7,443,777 128,685,249 2,336,835,101 -205,327,825 2,260,192,526
FERC FORM NO.1 (ED.12-90)Page 327.18
Name of Respondent This Re ort Is:Date of Report Year of Report
PacifiCorp (1)X An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
PURCHASED POWER (Account 555)(Including power excnanges)
1.Report all power purchases made during the year.Also report exchanges of electricity (i.e.,transactions involving a balancing of
debits and credits for energy,capacity,etc.)and any settlements for imbalanced exchanges.
2.Enter the name of the seller or other party in an exchange transaction in column (a).Do not abbreviate or truncate the name or use
acronyms.Explain in a footnote any ownership interest or affiliation the respondent has with the seller.
3.In column (b),enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows:
RQ -for requirements service.Requirements service is service which the supplier plans to provide on an ongoing basis (i.e.,the
supplier includes projects load for this service in its system resource planning).In addition,the reliability of requirement service must
be the same as,or second only to,the supplier's service to its own ultimate consumers.
LF -for long-term firm service."Long-term"means five years or longer and "firm"means that service cannot be interrupted for
economic reasons and is intended to remain reliable even under adverse conditions (e.g.,the supplier must attempt to buy emergency
energy from third parties to maintain deliveries of LF service).This category should not be used for long-term firm service firm service
which meets the definition of RQ service.For all transaction identified as LF,provide in a footnote the termination date of the contract
defined as the earliest date that either buyer or seller can unilaterally get out of the contract.
IF -for intermediate-term firm service.The same as LF service expect that "intermediate-term"means longer than one year but less
than five years.
SF -for short-term service.Use this category for all firm services,where the duration of each period of commitment for service is one
year or less.
LU -for long-term service from a designated generating unit."Long-term"means five years or longer.The availability and reliability of
sentice,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 Deman<Monthly CP Demand
(a)(b)(c)(d)(e)(f)
1 California ISO EX OV-12 NA NA NA
2 Chelan County Public Utility Dist.EX 160 NA NA NA
3 Clark County Public Utility Distric EX 417 NA NA NA
4 Colockum Transmission Company EX 160 NA NA NA
5 Cowlitz County Public Utility Dist.EX 160 NA NA NA
6 Douglas County Public Utility Dist.EX 160 NA NA NA
7 Emerald Peoples Utility District EX 351 NA NA NA
8 EugeneWater &Electric Board EX OV-12 NA NA NA
9 Flathead Electric Cooperative EX OV-12 NA NA NA
10 Grant County Public Utility Dist.N EX 160 NA NA NA
11 IdahoPowerCompany EX 380 NA NA NA
12 Montana Power Company EX 160 NA NA NA
13 Portland General Electric Co.EX 160 NA NA NA
14 Public Service Company of Colorado EX OV-12 NA NA NA
Total
FERC FORM NO.1 (ED.12-90)Page 326.19
Name of Respondent This Re ort Is:Date of Report Year of Report
PacifiCorp (1)X An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
PU <cHASED POWER(Account 555)(Continued)(Including power exchanges)
AD -for out-of-period adjustment.Use this code for any accounting adjustments or "true-ups"for service provided in prior 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 (1).Report in column (m)
the total charge shown on bills received as settlement by the respondent.For power exchanges,report in column (m)the settlement
amount for the net receipt of energy.If more energy was delivered than received,enter a negative amount.If the settlement amount (l)
include credits or charges other than incremental generation expenses,or (2)excludes certain credits or charges covered by the
agreement,provide an explanatory footnote.
8.The data in column (g)through (m)must be totalled on the last line of the schedule.The total amount in column (g)must be
reported as Purchases on Page 401,line 10.The total amount in column (h)must be reported as Exchange Received on Page 401,
line 12.The total amount in column (i)must be reported as Exchange Delivered on Page 401,line 13.
9.Footnote entries as required and provide explanations following all required data.
POWER EXCHANGES I COST/SETTLEMENT OF POWERMegaWattHnnrei Line
Purchased MegaWatt Hours MegaWatt Hours Demand Charges Energy Charges Other Charges Total (j+k+l)No.Received Delivered ($)($)($)of Settlement ($)
(g)(h)(i)(j)(k)(I)(m)
126,694 85,041 12,150 12,150 1
13,960 2
464,647 31,684,208 31,684,208 3
165 190,781 -31,443 -31,443 4
188,209 158,539 5
2,988 6
82 -2,036 -2,036 7
20,855 20,300 13,333 13,333 8
11,843 981 8,688 8,688 9
6,907 58,668 10
366,250 246,260 11
11,545 12
134,280 133,181 13
71,075 74,199 -806,297 -806,297 14
24,202,778 7,960,551 7,443,777 128,685,249 2,336,835,101 -205,327,825 2,260,192,525
FERC FORM NO.1 (ED.12-90)Page 327.19
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)X An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
PURCHASEDPOWER (Account 555)(Including power excnanges)
1.Report all power purchases made during the year.Also report exchanges of electricity (i.e.,transactions involvinga 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 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 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 Public Service Company of Colorado EX 319 NA NA NA
2 Redding,City of EX 364 NA NA NA
3 Seawest EX 554 NA NA NA
4 Sierra Pacific Power Company EX OV-12 NA NA NA
5 Southern California Edison Company 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 Western Area Power Administration EX WSPP NA NA NA
9 System Deviation NA NA NA NA
10
11
12
13
14
Total
FERC FORM NO.1 (ED.12-90)Page 326.20
Name of Respondent This Report is:Date of Report Year of Report
PacifiCorp (1)X An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
PU (CHAshb POWEk(Account 555)(contmued)(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 (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.
POWER EXCHANGES COST/SETTLEMENT OF POWERMegaWattHours Line
Purchased MegaWatt Hours MegaWatt Hours Demand Charges Energy Charges Other Charges Total (j+k+l)No.Received Delivered ($)($)($)of Settlement (S)
(g)(h)(i)(j)(k)(I)(m)
5,990 1
110,574 127,723 -2,772,352 -2,772,352 2
28,028 904,472 904,472 3
90 259 -6,760 -6,760 4
38,205 5
149,598 154,080 -3,955,390 -3,955,390 6
5,000 7
2,158 1,466 8
4,732 9
10
11
12
13
14
24,202,778 7,960,551 7,443,777 128,685,249 2,336,835,101 -205,327,825 2,260,192,525
FERC FORM NO.1 (ED.12-90)Page 327.20
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)DX An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456)(Including transactions referred to as 'wheeling')
1.Report all transmission of electricity,i.e.,wheeling,provided for other electric utilities,cooperatives,municipalities,other public
authorities,qualifying facilities,non-traditional utility suppliers and ultimate customers.
2.Use a separate line of data for each distinct type of transmission service involvingthe entities listed in column (a),(b)and (c).
3.Report in column (a)the company or public authority that paid for the transmission service.Repon 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 Aquila Power Corporation SF
2 Aquila Power Corporation OS
3 Basin Electric Power Co-op Western Area Power Admin.LF
4 Basin Electric Power Co-op Western Area Power Admin.LF
5 Basin Electric Power Co-op OS
6 Black Hills Power &Light Co.PacifiCorp Merchant Montana-Dakota Utility LF
7 Black Hills Power &Light Co.PacifiCorp Merchant Black Hills Power &Light Co.LF
8 Black Hills Power &Light Co.PacifiCorp Merchant Bonneville Power Admin.SF
9 Black Hills Power &Light Co.PacifiCorp Merchant Bonneville Power Admin.OS
10 Bonneville Power Administration Bonneville Power Admin Bonneville Power Admin.LF
11 Bonneville Power Administration Bonneville Power Admin Bonneville Power Admin.LF
12 Bonneville Power Administration Bonneville Power Admin Bonneville Power Admin.LF
13 Bonneville Power Administration Bonneville Power Admin Bonneville Power Admin.LF
14 Bonneville Power Administration Bonneville Power Admin Bonneville Power Admin.LF
15 Bonneville Power Administration PacifiCorp Merchant Bonneville Power Admin.SF
16 Bonneville Power Administration Bonneville Power Admin PacifiCorp Merchant LF
17 Calpine Energy Services OS
TOTAL
FERC FORM NO.1 (ED.12-90)Page 328
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)X An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
TRANSMISSIOW OF ELECTRICITY FOR OTHERS (Account 456)(Continued)(including transactions reffered to as 'wheeling')
OS -for other service.Use this category only for those senrices 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 MegaWatt Hours MegaWatt Hours No.Tariff Number Designation)Designation)(MW)Received Delivered
(e)(f)(g)(h)(i)(j)
OV-11 Red Butte,UT Mona,UT 55,200 55,20C 1
OV-11 Various Various 400,209 400,20E 2
OV-11 Yellowtail,WY Sheridan,WY 3
4 Yellowtail,WY Sheridan,WY 4
OV-11 Dave Johnston,WY Dave Johnston,WY 6,970 6,97C 5
42 Various Sheridan,WY 6
236 Various Wyodak 42 7
OV-11 Various Various 1,200 1,20C 8
OV-11 Various Various 6,520 6,52C 9
324 Lost Creek Proj Reston Substation 169,762 169,762 10
299 Bingham,ID Various 166 1,302,202 1,302,202 11
237 Various Various 283 12
256 Various Various 359 13
OV-11 Ashland,OR Alvey,OR 18 14
OV-11 Various Hermiston,OR 15
OV-11 Alvey,OR Gazley Substation 16
OV-11 Various Various 1,512 1,512 17
2,338 17,535,183 17,535,183
FERC FORM NO.1 (ED.12-90)Page 329
Blank Page
(Next Page is:330)
Name of Respondent This Re ort Is:Date of Report Year of Report
PacifiCorp (1)X An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456)(Continued)(Including transactions reffered to as 'wheeling')
8.Report in column (i)and (j)the total megawatthours received and delivered.
9.In column (k)through (n),report the revenue amounts as shown on bills or vouchers.In column (k),provide revenues from demand
charges related to the billing demand reported in column (h).In column (I),provide revenues from energy charges related to the
amount of energy transferred.In column (m),provide the total revenues from all other charges on bills or vouchers rendered,including
out of period adjustments.Explain in a footnote all components of the amount shown in column (m).Report in column (n)the total
charge shown on bills rendered to the entity Listed in column (a).If no monetary settlement was made,enter zero (11011)in column
(n).Provide a footnote explaining the nature of the non-monetary settlement,including the amount and type of energy or service
rendered.
10.Provide total amounts in column (i)through (n)as the last Line.Enter "TOTAL"in column (a)as the Last Line.The total amounts
in columns (i)and (j)must be reported as Transmission Received and Delivered on Page 401,Lines 16 and 17,respectively.
11.Footnote entries and provide explanations following all required data.
REVENUE FROM TRANSMISSIC N OF ELECTRICITY FOR OTHERS
Demand Charges Energy Charges (Other Charges)Total Revenues ($)Line
($)($)($)(k+l+m)No.
(k)(l)(m)(n)
151,875 738,398 890,273 1
1,143,317 1,143,317 2
388,046 388,046 3
-293,913 -293,913 4
22,652 22,652 5
786,725 786,725 6
777,600 777,600 7
4,650 4,650 8
1,168 1,168 9
312,276 312,276 10
1,710,441 215,604 1,926,045 11
3,881,632 74,124 3,955,756 12
4,987,545 32,477 5,020,022 13
360,187 105,827 466,014 14
177,621 177,621 15
54,017 54,017 16
7,367 2,713 10,080 17
33,146,221 36,178,083 34,290,847 103,615,151
FERC FORM NO.1 (ED.12-90)Page 330
Name of Respondent This Re ort Is:Date of Report Year of Report(1)An Original (Mo,Da,Yr)PacifiCorp Dec.31,2001(2)A Resubmission //
TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456)(Including transactions referred to as 'wheeling')
1.Report all transmission of electricity,i.e.,wheeling,providedfor 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 involvingthe 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 (Companyof Public Authority)(Company of Public Authority)(Company of Public Authority)Classifi-
(Footnote Affiliation)(Footnote Affiliation)(Footnote Affiliation)cation
(a)(b)(c)(d)
1 Cargill-Alliant,LLC L.A.Dept.of Water &Power Idaho Power Company SF
2 Cargill-Alliant,LLC Nevada Power Company Idaho Power Company SF
3 Cargill-Alliant,LLC OS
4 Cheyenne Light,Fuel &Power OS
5 Cheyenne Light,Fuel &Power SF
6 Constellation Power Sourœ Inc.OS
7 Constellation Power Source Inc.SF
8 Deseret Generation &Trans.Deseret Generation &Trans.Deseret Generation &Trans.LF
9 Deseret Generation &Trans.OS
10 Dynegy Power Marketing OS
11 El Paso Merchant Energy L.A.Dept.of Water &Power SF
12 El Paso Merchant Energy OS
13 Enron Power Marketing OS
14 Enron Power Marketing PacifiCorp Merchant Enron Power Marketing SF
15 Fall River Rural Electric Corp.Fall River Rural Elect Idaho Power Company LF
16 Flathead Electric Cooperative Inc.Deseret Generation &Trans.Flathead Electric Co-op LF
17 Flathead Electric Cooperative Inc.Western Area Power Admin.Western Area Power Admin.LF
TOTAL
FERC FORM NO.1 (ED.12-90)Page 328.1
Name of Respondent This Re ort Is:Date of Report Year of Report
PacifiCorp (1)X An Original (Mo,Da,Yr)Dec.31,2001
(2)A Resubmission //
TRANSMISSIOld OF ELECTRICITY FOR OTHERS (Account 456)(Continued)(Including transactions reffered to as 'wheeling')
OS -for other service.Use this category only for those services which cannot be placed in the above-defined categories,such as 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 providedin 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 MegaWatt Hours MegaWatt Hours No.Tariff Number Designation)Designation)(MW)Received Delivered(e)(f)(g)(h)(i)(j)
OV-11 Mona,UT Borah-Brady 25 1
OV-11 Red Butte,UT Borah-Brady 25 2
OV-11 Various Various 223,673 223,672 3
OV-11 Dave Johnston,WY Various 12,451 12,451 4
OV-11 Dave Johnston,WY Dave Johnston,WY 47,875 47,875 5
OV-11 Various Various 236,034 236,034 6
OV-11 Mona,UT Various 97,729 97,726 7
280 Various Various 53 71,488 71,48E 8
OV-11 Flaming Gorge,WY Mona,UT 3,279 3,27E 9
OV-11 Mona,UT Various 1,536 1,53E 10
OV-11 Various Mona,UT 48 4E 11
OV-11 Various Various 112 112 12
OV-11 Various Various 42,707 42,707 13
OV-11 Various Various 75,950 75,95C 14
322 Fall River Inter.Goshen Substation 9 15
OV-11 Mona,UT Flathead,MT 16
4 Yellowtail,WY Big Horn Basin,WY 17
2,338 17,535,183 17,535,183
FERC FORM NO.1 (ED.12-90)Page 329.1
Blank Page
(Next Page is:330.1)
Name of Respondent This Re ort Is:Date of Report Year of Report
PacifiCorp (1)X An Original (Mo,Da,Yr)Dec.31,2001
(2)A Resubmission //
TRANSMISSION OF ELECTRICITY FOR OT HERS (Account 456)(Continued)(Including transactions reffered to as 'wheeling')
8.Report in column (i)and (j)the total megawatthours received and delivered.
9.In column (k)through (n),report the revenue amounts as shown on bills or vouchers.In column (k),provide revenues from demand
charges related to the billing demand reported in column (h).In column (I),provide revenues from energy charges related to the
amount of energy transferred.In column (m),provide the total revenues from all other charges on bills or vouchers rendered,including
out of period adjustments.Explain in a footnote all components of the amount shown in column (m).Report in column (n)the total
charge shown on bills rendered to the entity Listed in column (a).If no monetary settlement was made,enter zero (11011)in column
(n).Provide a footnote explaining the nature of the non-monetary settlement,including the amount and type of energy or service
rendered.
10.Provide total amounts in column (i)through (n)as the last Line.Enter "TOTAL"in column (a)as the Last Line.The total amounts
in columns (i)and (j)must be reported as Transmission Received and Delivered on Page 401,Lines 16 and 17,respectively.
11.Footnote entries and provide explanations following all required data.
REVENUE FROM TRANSMISSICN OF ELECTRICITY FOR OTHERS
Demand Charges Energy Charges (Other Charges)Total Revenues ($)Line
($)($)($)(k+1+m)No.
(k)(1)(m)(n)
253,125 16,854 269,979 1
253,125 16,854 269,979 2
759,580 600,538 1,360,118 3
55,275 55,275 4
131,625 131,625 5
707,643 707,643 6
286,853 858,728 1,145,581 7
1,193,754 1,193,754 8
19,149 1,336 20,485 9
6,387 11,268 17,655 10
186 124 310 11
654 654 12
276,121 276,121 13
211,981 552,301 764,282 14
151,308 151,308 15
232,538 232,538 16
-1,321,048 -1,321,048 17
33,146,221 36,178,083 34,290,847 103,615,151
FERC FORM NO.1 (ED.12-90)Page 330.1
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)X An Original (Mo,Da,Yr)Dec.31 2001(2)A Resubmission //'
TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456)(Including transactions referred to as 'wheeling')
1.Report all transmission of electricity,i.e.,wheeling,provided for other electric utilities,cooperatives,municipalities,other public
authorities,qualifying facilities,non-traditional utility suppliers and ultimate customers.
2.Use a separate line of data for each distinct type of transmission service involvingthe 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 senrice."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 Idaho Power Company Deseret Generation &Trans.Nevada Power Company LF
2 Idaho Power Company Idaho Power Company Idaho Power Company LF
3 Idaho Power Company California ISO LF
4 Idaho Power Company L.A.Dept.of Water &Power LF
5 Idaho Power Company Nevada Power Company LF
6 Idaho Power Company Deseret Generation &Trans.LF
7 Idaho Power Company L.A.Dept.of Water &Power LF
8 Idaho Power Company Western Area Power Admin.LF
9 Idaho Power Company SF
10 Idaho Power Company OS
11 Mirant Americas Energy Marketing SF
12 Mirant Americas Energy Marketing OS
13 Montana Power Company Western Area Power Admin.OS
14 Moon Lake Electric Assoc.Moon Lake Electric Assoc.Moon Lake Electric Assoc.LF
15 Morgan Stanley Capital Group SF
16 Morgan Stanley Capital Group OS
17 PacifiCorp Power Marketing OS
TOTAL
FERC FORM NO.1 (ED.12-90)Page 328.2
Name of Respondent This Report is:Date of Report Year of Report
PacifiCorp (1)QX An Original (Mo,Da,Yr)Dec.31,2001(2)[¯]A Resubmission //
I RANSMlssloN 01-ELECI RICI \Y EOk 0 1 HERS (Account 456)(Contmued)(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-periodadjustment.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 MegaWatt Hours MegaWatt Hours NoTariffNumberDesignation)Designation)(MN Received Delivered(e)(f)(g)(h)(i)(j)
OV-11 Mona,UT Harry Allen,NV 25 1
OV-11 Gonder,UT Harry Allen,NV 10 2
OV-11 Craig Enterprise,OR 30 3
OV-11 Various Borah-Brady 100 4
OV-11 Red Butte,UT Borah-Brady 75 5
OV-11 Mona,UT Jim Bridger,WY 75 6
OV-11 Various Jim Bridger,WY 15 7
OV-11 Jim Bridger,WY Dave Johnston,WY 30 8
OV-11 Various Various 2,609,090 2,609,09C 9
OV-11 Various Various 635,991 635,991 10
OV-11 Malin,OR Malin,OR 36,000 36,00C 11
OV-11 Various Various 201,307 201,307 12
WSPP Yellowtail,WY Bridger,WY 66,240 66,24C 13
302 Duchesne,UT Duchesne,UT 2 14
OV-11 Gonder,UT Mona,UT 110,400 110,40C 15
OV-11 Various Various 24,576 24,57E 16
OV-11 Various Various 57,503 57,502 17
2,338 17,535,183 17,535,182
FERC FORM NO.1 (ED.12-90)Page 329.2
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(Next Page is:330.2)
Name of Respondent This Re ort Is:Date of Report Year of Report
PacifiCorp (1)X An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456)(Continued)(Including transactions reffered to as 'wheeling')
8.Report in column (i)and (j)the total megawatthours received and delivered.
9.In column (k)through (n),report the revenue amounts as shown on bills or vouchers.In column (k),provide revenues from demand
charges related to the billing demand reported in column (h).In column (1),provide revenues from energy charges related to the
amount of energy transferred.In column (m),providethe total revenues from all other charges on bills or vouchers rendered,including
out of period adjustments.Explain in a footnote all components of the amount shown in column (m).Report in column (n)the total
charge shown on bills rendered to the entity Listed in column (a).If no monetary settlement was made,enter zero (11011)in column
(n).Provide a footnote explaining the nature of the non-monetary settlement,including the amount and type of energy or service
rendered.
10.Provide total amounts in column (i)through (n)as the last Line.Enter "TOTAL"in column (a)as the Last Line.The total amounts
in columns (i)and (j)must be reported as Transmission Received and Delivered on Page 401,Lines 16 and 17,respectively.
11.Footnote entries and provide explanations following all required data.
REVENUE FROM TRANSMISSIC N OF ELECTRICITY FOR OTHERS
DemandCharges Energy Charges (Other Charges)Total Revenues ($)Line
($)($)($)(k+I+m)No.
(k)(1)(m)(n)
607,500 464,885 1,072,385 1
243,000 243,000 2
486,000 486,000 3
1,012,500 1,012,500 4
759,375 759,375 5
911,250 911,250 6
182,250 182,250 7
243,000 243,000 8
6,963,945 8,552,678 15,516,623 9
2,251,013 30 2,251,043 10
110,550 110,550 11
741,874 495,753 1,237,627 12
182,250 182,250 13
19,691 19,691 14
303,750 55,819 359,569 15
62,847 62,847 16
279,184 279,184 17
33,146,221 36,178,083 34,290,847 103,615,151
FERC FORM NO.1 (ED.12-90)Page 330.2
Name of Respondent This Re ort Is:Date of Report Year of Report
PacifiCorp (1)X An Original (Mo,Da,Yr)Dec.31,2001
(2)A Resubmission //
TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456)(Including transactions referred to as 'wheeling')
1.Report all transmission of electricity,i.e.,wheeling,provided for other electric utilities,cooperatives,municipalities,other public
authorities,qualifying facilities,non-traditional utility suppliers and ultimate customers.
2.Use a separate line of data for each distinct type of transmission service involving the entities listed in column (a),(b)and (c).
3.Report in column (a)the company or public authority that paid for the transmission service.Report in column (b)the company or
public authority that the energy was received from and in column (c)the company or public authority that the energy was delivered to.
Provide the full name of each company or public authority.Do not abbreviate or truncate name or use acronyms.Explain in a footnote
any ownership interest in or affiliation the respondent has with the entities listed in columns (a),(b)or (c)
4.In column(d)enter a Statistical Classification code based on the original contractual terms and conditions of the service as follows:
LF -for Long-term firm transmission service."Long-term"means one year or longer and "firm"means that service cannot be
interrupted for economic reasons and is intended to remain reliable even under adverse conditions.For all transactions identified as
LF,provide in a footnote the termination date of the contract defined as the earliest date that either buyer or seller can unilaterally get
out of the contract.
SF -for short-term firm transmission service.Use this category for all firm services,where the duration of each period of commitment
for service is less than one year.
Line Payment By Energy Received From Energy Delivered To Statistical
(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 PacifiCorp Power Marketing SF
2 Pacific Gas &Energy Trading OS
3 Portland General Electric Co.PacifiCorp Merchant OS
4 Powerex OS
5 Powerex SF
6 Powerex L.A.Dept.of Water &Power Idaho Power Company LF
7 Powerex Powerex Powerex LF
8 PPL Montana,LLC OS
9 PSC of Colorado SF
10 PSC of Colorado OS
11 PSC of Colorado Deseret Generation &Trans.Nevada Power Company LF
12 PSC of Colorado Deseret Generation &Trans.Montana Power Company LF
13 Seawest Windpower,Inc.PacifiCorp Merchant LF
14 Sempra Energy Trading Corp.OS
15 Sierra Pacific Power Co.OS
16 Sierra Pacific Power Co.SF
17 State of South Dakota State of South Dakota State of South Dakota LF
TOTAL
FERC FORM NO.1 (ED.12-90)Page 328.3
Name of Respondent This Re ort Is.Date of Report Year of Report
PacifiCorp (1)X An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
T RANSMISSIOWOF ELECTRICITY FOR OTHERS (Account 456)(Continued)(Including transactions reffered to as 'wheeling')
OS -for other service.Use this category only for those services which cannot be placed in the above-definedcategories,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 MegaWatt Hours MegaWatt Hours No.TariffNumber Designation)Designation)(MW)Received Delivered(e)(f)(g)(h)(i)(j)
OV-11 Various Various 95,854 95,854 1
OV-11 Four Corners,UT Borah-Brady 100 10C 2
OV-11 Various Mid-Columbia 75 75 3
OV-11 Various Various 1,640,392 1,640,392 4
OV-11 Malin,OR Malin,OR 97,870 97,87C 5
OV-11 Various Borah-Brady 50 6
OV-11-Various Cal ISO,CA 80 7
OV-11 Various Various 5,585 5,58E 8
OV-11 Various Various 562,800 562,80C 9
OV-11 Various Various 3,271,112 3,271,112 10
OV-11 Mona,UT Harry Allen,NV 25 11
OV-11 Mona,UT Borah-Brady 42 12
OV-11 Various Various 25 13
OV-11 Various Various 9,060 9,06C 14
OV-11 Various Various 873,672 873,672 15
OV-11 Various Various 598,080 598,08C 16
OV-11 Yellowtail,WY Wyodak,WY 4 17
2,338 17,535,183 17,535,183
FERC FORM NO.1 (ED.12-90)Page 329.3
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(Next Page is:330.3)
Name of Respondent This Re ort is:Date of Report Year of Report
(1)An Original (Mo,Da,Yr)PacifiCorp Dec.31,2001
(2)A Resubmission //
TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456)(Contmued)(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),providerevenues from energy charges related to the
amount of energy transferred.In column (m),provide the total revenues from all other charges on bills or vouchers rendered,including
out of period adjustments.Explain in a footnote all components of the amount shown in column (m).Report in column (n)the total
charge shown on bills rendered to the entity Listed in column (a).If no monetary settlement was made,enter zero (11011)in column
(n).Provide a footnote explaining the nature of the non-monetary settlement,including the amount and type of energy or service
rendered.
10.Provide total amounts in column (i)through (n)as the last Line.Enter "TOTAL"in column (a)as the Last Line.The total amounts
in columns (i)and (j)must be reported as Transmission Received and Delivered on Page 401,Lines 16 and 17,respectively.
11.Footnote entries and provide explanations following all required data.
REVENUE FROM TRANSMISSICN OF ELECTRICITY FOR OTHERS
Demand Charges Energy Charges (Other Charges)Total Revenues (S)Line
($)($)($)(k+I+m)No.
(k)(I)(m)(n)
350,643 350,643 1
584 927 1,511 2
657 657 3
4,561,064 -838 4,560,226 4
272,550 2,498,552 2,771,102 5
560,925 560,925 6
1,944,000 69,079 2,013,079 7
32,032 23,642 55,674 8
1,567,950 11,257,684 12,825,634 9
9,467,173 4,684 9,471,857 10
607,500 607,500 11
652,050 652,050 12
541,296 541,296 13
53,056 101,407 154,463 14
3,364,503 3,364,503 15
1,708,150 6,525,340 8,233,490 16
97,200 97,200 17
33,146,221 36,178,083 34,290,847 103,615,151
FERC FORM NO.1 (ED.12-90)Page 330.3
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)DX An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission I /
TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456)(Including transactions referred to as 'wheeling')
1.Report all transmission of electricity,i.e.,wheeling,provided for other electric utilities,cooperatives,municipalities,other public
authorities,qualifying facilities,non-traditional utility suppliers and ultimate customers.
2.Use a separate line of data for each distinct type of transmission service involvingthe 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 TransAlta Energy Marketing Co.OS
2 Tri-State Generation &Trans.OS
3 Tri-State Generation &Trans.Tri-State Generation &Trans.Tri-State Generation &Trans.LF
4 United States Bureau of Recl.United States Bureau of Recl.United States Bureau of Recl.LF
5 Utah Associated Municipal Power Idaho Power Company Utah Associated Municipal Power LF
6 Utah Municipal Power Agency LF
7 Utah Municipal Power Agency Utah Municipal Power Agency Utah Municipal Power Agency LF
8 Utah Municipal Power Agency PacifiCorp Merchant OS
9 Western Area Power Administration LF
10 Western Area Power Administration Western Area Power Admin.Western Area Power Admin.LF
11 Western Area Power Administration Western Area Power Admin.Western Area Power Admin.LF
12 Western Area Power Administration Western Area Power Admin.Western Area Power Admin.LF
13 Western Area Power Administration Western Area Power Admin.Western Area Power Admin.LF
14 Western Area Power Administration Western Area Power Admin.LF
15 Western Area Power Administration OS
16 Western Area Power Administration Western Area Power Admin.Weber Basin LF
17 Willams Energy Market OS
TOTAL
FERC FORM NO.1 (ED.12-90)Page 328.4
Name of Respondent This Report is:Date of Report Year of Report
PacifiCorp (1)X An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456)(Continued)(Including transactions reffered to as 'wheeling')
OS -for other service.Use this category only for those services which cannot be placed in the above-defined categories,such as 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 deliverylocations 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)reponthe 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 MegaWatt Hours MegaWatt Hours No.TariffNumber Designation)Designation)(MW)Received Delivered(e)(f)(g)(h)(i)(j)
OV-11 Various Various 8,680 8,68C 1
OV-11 Jim Bridger,WY Dave Johnston,WY 370 37C 2
123 Various Various 29 18,963 18,962 3
67 Redmond,OR Various 3 5,000 5,00C 4
297 Various Various 294 1,729,312 1,729,312 5
4 Various Various 6
279 Various Various 54 329,842 329,842 7
OV-11 Various Mona,UT 2,455 2,456 8
4 Various Various 9
45 Various Various 4 10
262 Various Various 328 1,757,401 1,757,401 11
263 Various Various 8 12
OV-11 Yellowtail,WY Dave Johnston,WY 50 13
OV-11 Various Various 14
OV-11 Dave Johnston,WY Yellowtail,WY 15
286 Various Various 30,971 30,971 16
OV-11 Four Corners,UT Borah-Brady 25 25 17
2,338 17,535,183 17,535,182
FERC FORM NO.1 (ED.12-90)Page 329.4
Blank Page
(Next Page is:330.4)
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)X An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456)(Continued)(including transactions reffered to as 'wheeling')
8.Report in column (i)and (j)the total megawatthours received and delivered.
9.In column (k)through (n),report the revenue amounts as shown on bills or vouchers.In column (k),provide revenues from demand
charges related to the billing demand reported in column (h).In column (I),provide revenues from energy charges related to the
amount of energy transferred.In column (m),provide the total revenues from all other charges on bills or vouchers rendered,including
out of period adjustments.Explain in a footnote all components of the amount shown in column (m).Report in column (n)the total
charge shown on bills rendered to the entity Listed in column (a).If no monetary settlement was made,enter zero (11011)in column
(n).Provide a footnote explaining the nature of the non-monetary settlement,including the amount and type of energy or service ,
rendered.
10.Provide total amounts in column (i)through (n)as the last Line.Enter "TOTAL"in column (a)as the Last Line.The total amounts
in columns (i)and (j)must be reported as Transmission Received and Delivered on Page 401,Lines 16 and 17,respectively.
11.Footnote entries and provide explanations following all required data.
REVENUE FROM TRANSMISSIC N OF ELECTRICITY FOR OTHERS
Demand Charges Energy Charges (Other Charges)Total Revenues ($)Line
($)(S)($)(k+l+m)No.
(k)(l)(m)(n)
50,247 86,607 136,854 1
2,161 1,906 4,067 2
73,513 18,963 4,210 96,686 3
8,530 1,000 581 10,111 4
5,195,258 259,080 5,454,338 5
-76,523 -76,523 6
1,204,240 107,340 1,311,580 7
14,337 14,337 8
434,097 434,097 9
182,250 -214,185 -31,935 10
2,772,845 24,447 2,797,292 11
58,331 58,331 12
1,215,000 1,215,000 13
50,646 50,646 14
-409 -409 15
30,971 30,971 16
146 146 17
33,146,221 36,178,083 34,290,847 103,615,151
FERC FORM NO.1 (ED.12-90)Page 330.4
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001
(2)A Resubmission //
TRANSklSSION OF ELECTRICITY BY OTHERS (Account 565)
(Including transactions referred to as "wheeling")
1.Report all transmission,i.e.,wheeling of electricity piovidedto 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 FOR TRANSMISSION OF ELECTRICITY BY OTHERS
No.Authority (Footnote Affiliations)Magawatt-Magawatt-Demand Energy Uther Total Cost ofliourshoursChargesChargesChargesTranissionReceivedDelivered(S)($)($)(a)(b)(c)(d)(e)(f)
1 Arizona Public Service 483,726 483,726 2,072,000 1,400,110 139,239 3,611,349
2 Avista Corporation 116,644 111,666 297,073 291,052 56,015 644,140
3 Big Horn Rurl Elec Coop 36,328 36,328
4 Blanding City 2,233 2,233 13,399 13,399
5 Bonneville Power Admin 4,382,321 4,337,161 40,900,927 1,110,353 296,157 42,307,437
6 California ISO 1,499,124 1,499,124 2,251,163 742,983 2,994,146
7 Deseret Gen &Tran Coop 383 383 2,842 2,842
8 Flowell Electric Assoc.234 234 423 423
9 Hermiston Gen Co,L.P.141,878 141,878
10 Idaho Power Company 686,086 637,632 1,258,675 8,892,604 10,151,279
11 Los Angeles Dept of W&P 3,441,160 3,441,160 16,859,174 4,041,730 20,900,904
12 Mid Area Cont.Pwr Pool 16,857 16,857
13 Montana Power Company 97,289 85,714 463,279 743,982 1,207,261
14 Moon Lake Elec.Assoc.72,369 -12 72,357
15 Navajo Tribal Utility 1,591 1,591
16 Nevada Power Company 3,255 3,255 7,595 13,697 21,292
TOTAL 12,476,087 12,307,796 57,764,372 24,566,962 12,406,039 94,737,373
FERC FORM NO.1 (ED.12-90)Page 332
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001
(2)A Resubmission //
TRANSW ISSION OF ELECTRICITY BY OTHEAS (Account 565)(Including transactions referred to as "wheeling")
1.Report all transmission,i.e.,wheeling of electricity piovidedto 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 providetransmission 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 ("O")column (g).Provide a footnote explaining the nature of the non-monetary settlement,
including the amount and type of energy or service rendered.
6.Enter "TOTAL"in column (a)as the last Line.Provide a total amount in columns (b)through (g)as the last Line.Energy provided by
the respondent for the wheeler's transmission tosses should be reported on the Electric Energy Account,Page 401.If the respondent
received power from the wheeler,energy provided to account for Losses should be reported on Line 19.Transmission By Others
Losses,on Page 401.Otherwise,Losses should be reported on line 27,Total Energy Losses,Page 401.
7.Footnote entries and provide explanations following all required data.
Line Name of Company or Public TRANSFER OF ENERGY EXPENSES FOR TRANSMISSION OF ELECTRICITY BY OTHERS
No.Authority (Footnote Affiliations)Magawatt-Magawatt-Demand Energy Uther Total Cost ofhourslioursChargesChargesChargesTransissionReceivedDelivered($)($)($)(a)(b)(c)(d)(e)(f)(g)
1 Portland General Elec.643,472 642,375 143,369 143,369
2 Public Ser.Co.Colorado 209,266 203,344 754,637 754,637
3 PugentSound Energy 652 652 502 274 776
4 Sierra Pacific Power Co 168,298 168,298 849,338 40,648 889,986
5 Snohomish PUD 9,335 9,335 19,332 19,332
6 S.California Edison Co 446,276 407,299 3,744,000 32,619 3,776,619
7 Sprinfield Utility 324,514 324,514
8 Surprise Valley Elec.10,111 10,111
9 City of Tacoma 27 27 78 78
10 Tri State G&T 285,845 273,717 1,814,117 38,290 1,852,407
11 Western Area Power Ad 461 461 7,784,735 1,357 457,395 8,243,487
12 Accrual Adjustment -3,401,426 -3,401,426
13
14
15
16
TOTAL 12,476,087 12,307,796 57,764,372 24,566,962 12,406,039 94,737,373
FERC FORM NO.1 (ED.12-90)Page 332.1
Name of Respondent This ort Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31 2001(2)A Resubmission //'
MISCELLANEOUS GENERAL EXPENSES (Account 930.2)(ELECTRIC)
Line Description AmountNo.(a)(b)
1 Industry Association Dues 732,003
2 Nuclear Power Research Expenses
3 Other Experimental and General Research Expenses
4 Pub &Dist Info to Stkhldrs...expn servicing outstanding Securities 439,570
5 Oth Expn >=5,000 show purpose,recipient,amount.Group if <$5,000
6
7 Directors Fees 316,191
8
9 Bank Charges &Fees
10 Bank of New York 15,496
11 Bank One 65,492
12 US Bank 456,688
13 Wachovia Bank 210,162
14 Wells Fargo Bank 45,531
15 Other 1,663
16
17 Corporate Memberships &Subscriptions
18 Business for Social Responsibility 5,000
19 Cambridge Energy Research Assoc.84,000
20 Economic Development for Central Oregon 5,000
21 General Electric International Inc.30,000
22 Greater Yakima Chamber of Commerce 5,000
23 Harvard University 100,000
24 Intermountian Electrical Assoc.30,000
25 Laramie Economic Development Corp.5,000
26 Nature Conservancy 157,567
27 Olympic Torch Relay Task Force 5,000
28 Oregon Business Council 8,636
29 Pacific NW Utilities Conference 21,819
30 Portland Chamber of Commerce 52,531
31 Salt Lake Area Chamber of Commerce 22,691
32 United Telecom Council 25,861
33 Utah Foundation 25,000
34 Utah Manufactures Association 5,964
35 Utah Taxpayers Association 20,000
36 Western Systems Coordinating Council 124,550
37 Other 222,160
38
39 Economic &Community Development
40 City of Klamath Falls 5,000
41 Oregon Economic &Development Dept.5,000
42 Portland Development Commission 5,000
43 South Cost Development Commission 10,000
44 Southern Oregon Regional Economic 5,000
45 Sunnyside Inc.15,000
46 TOTAL 24,172,211
FERC FORM NO.1 (ED.12-94)Page 335
Name of Respondent This ort Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31 2001 I(2)A Resubmission //'
MISCELLANEOUS GENERAL EXPENSES (Account 930.2)(ELECTRIC)
Line Description AmountNo.(a)(b)
6 Utah Society for Environmental Education 25,000
7 Wallowa Business Facilitation 5,000
8 West Valley City 7,500
9 Westside Alliance 10,000
10 Other 17,000
11
12 General
13 1997 Software Write-Off Utah 85,727
14 1999 Software Write-Off Utah 61,170
15 Accrue Additional CWIP Reserve 5,800,000
16 BSIPISAP Utah 2,880,852
17 BSIP/SAP Re-Engineering 1998 200,866
18 BSIP/SAP Re-Engineering 1999 176,024
19 Cascade Direct Inc.7,333
20 Comp Mainframe Writedown Utah 843,274
21 Early Retirement Utah 3,683,020
22 Expenses Moved To Capital 69,815
23 Glenrock Mine Excluding Reclamation Utah -20,830,356
24 Glenrock Mine Reclamation Utah 2,300,787
25 Intercompany Transfers In/(Out)178,129
26 Lloyd Center Tower Operations 230,434
27 Transition Plan 20,671,052
28 Transition Team Costs Utah 80,984
29 Deferred Pension Utah 3,159,014
30 Y2K Expenses Oregon 268,659
31 Y2K Expenses Utah 942,315
32 Other 15,037
33
34
35
36
37
38
39
40
41
42
43
44
45
46 TOTAL 24,172,211
FERC FORM NO.1 (ED.12-94)Page 335.1
Name of Respondent This Report is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001
(2)A Resubmission //
DEPRECIATION AND AMORTIZATION OF ELECTRIC PLANT (Account 403,404,405)
(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.Identify at the bottom of Section C the type of plant
included in any sub-account used.
In column (b)report all depreciable plant balances to which rates are applied showing subtotals by functional Classifications and
showing composite total.Indicate at the bottom of section C the manner in which column balances are obtained.If average balances,
state the method of averaging used.
For columns (c),(d),and (e)report available information for each plant subaccount,account or functional classification Listed in column
(a).If plant mortality studies are prepared to assist in estimating average service Lives,show in column (f)the type mortality curve
selected as most appropriate for the account and in column (g),if available,the weighted average remaining life of surviving plant.If
composite depreciation accounting is used,report available information called for in columns (b)through (g)on this basis.
4.If provisions for depreciation were made during the year in addition to depreciation provided by application of reported rates,state at
the bottom of section C the amounts and nature of the provisions and the plant items to which related.
A.Summary of Depreciation and Amortization Charges
Line Decreciation Amortization of Amortization ofFunctionalClassificationExpenseLimitedTermElec-Other Electric TotalNo(Account 403)tric Plant (Acc 404)Plant (Acc 405)(a)(b)(c)(d)(e)
1 Intangible Plant 39,927,996 1,758,796 41,686,792
2 Steam Product Plant 111,300,892 111,300,892
3 Nuclear Production Plant
4 Hydraulic Production Plant-Conventional 10,979,761 25,565 11,005,326
5 Hydraulic Production Plant-Pumped Storage
6 Other Production Plant 2,406,500 2,406,500
7 Transmission Plant 44,193,108 44,193,108
8 Distribution Plant 139,267,539 139,267,539
9 General Plant 41,844,727 2,355,063 44,199,790
10 Common Plant-Electric
11 TOTAL 349,992,527 42,308,624 1,758,796 394,059,947
B.Basis for Amortization Charges
The amortization of Limited-Term Electric 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 PacifiCorp and Utah Power &Light Company.Amortization is
straight-line over a 15 year period.
FERC FORMNO.1 (ED.12-88)Page 336
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001
(2)A Resubmission //
DEPRECIATION AND AMORTIZATION OF ELECTRIC PLANT (Continued)
C.Factors Used in Estimt ting Depreciation Ch irges
Line Depreciable E-stimated Net Applied Mortality Average
No.Account No.Plant Base Avg.Service Salvage Depr.rates Curve Remaining
(In Thousands)Life (Percent)(Percent)Type Life
(a)(b)(c)(d)(e)(t)(q)
12 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 197,461 43.05 -5.00 2.47
18 312.00 UT 486,986 41.52 -5.30 2.59
19 314.00 UT 135,308 40.71 -5.70 2.66
20 315.00 UT 96,464 43.31 -4.50 2.43
21 316.00 UT 6,638 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 132,303 41.03 -6.60 2.81
27 312.00 WY 491,288 37.29 -6.90 3.07
28 314.00 WY 121,446 36.05 -7.10 3.18
29 315.00 WY 51,315 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 94,218 41.68 -8.10 2.90
36 312.00 UT 213,934 38.70 -8.40 3.10
37 314.00 UT 76,222 34.89 -8.70 3.38
38 315.00 UT 27,444 41.50 -7.80 2.88
39 316.00 UT 5,068 33.06 -7.60 3.59
40
41 Cholla Plant
42 311.00 AZ 44,914 43.40 -4.30 2.19
43 312.00 AZ 212,928 42.41 -4.70 2.27
44 314.00 AZ 49,771 41.10 -5.00 2.38
45 315.00 AZ 45,553 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 of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
DEPRECIATION AND AMORTIZATION OF ELECTRIC PLANT (Continued)
C.Factors Used in Estimi ting Depreciation Ch irges
Line Deprectable Estimated Net Applied Mortality Average
No Account No.Plant Base Avg.Service Salvage Depr.rates Curve Remaining
(In Thousands)Life (Percent)(Percent)Type Life
(a)(b)(c)(d)(e)(t)(g)
12 310.30 WY 9,701 27.77 3.48
13 311.00 WY 47,008 39.52 -9.00 2.79
14 312.00 WY 247,345 39.91 -9.30 2.80
15 314.00 WY 58,494 40.91 -9.60 2.77
16 315.00 WY 15,813 43.81 -8.70 2.53
17 315.70 WY 174 31.70 -8.70 3.40
18 316.00 WY 2,649 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 48,034 41.98 -3.60 2.79
24 312.00 WY 186,424 38.38 -3.90 3.02
25 314.00 WY 41,489 41.52 -4.20 2.89
26 315.00 WY 19,256 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 55,997 29.44 -8.50 4.71
33 312.00 WY 197,982 29.85 -8.60 4.72
34 314.00 WY 36,908 34.42 -8.80 4.47
35 315.00 WY 16,226 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 55,644 43.54 -3.20 2.23
40 312.00 MT 107,673 42.45 -3.60 2.32
41 314.00 MT 28,908 40.02 -4.00 2.50
42 315.00 MT 8,902 43.59 -2.70 2.21
43 316.00 MT 2,219 37.01 -2.30 2.71
44
45 Craig Plant
46 311.00 CO 35,118 43.53 -4.40 2.47
47 312.00 CO 78,900 42.75 -4.70 2.55
48 314.00 CO 18,420 42.05 -5.10 2.62
49 315.00 CO 16,384 43.38 -4.00 2.46
50 316.00 CO 1,641 40.66 -3.70 2.74
FERC FORM NO.1 (ED.12-95)Page 337.1
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31 2001(2)A Resubmission //'
DEPRECIATION AND AMORTIZATION OF ELECTRIC PLANT (Continued)
C.Factors Used in Estimating Depreciation Ch irges
Line Depreciable Estimated Net Applied Mortality Average
No.Account No.Plant Base Avg.Service Salvage Depr.rates Curve Remaining
(In Thousands)Life (Percent)(Perœnt)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 13,415 31.06 -11.50 4.31
16 312.00 UT 35,418 29.79 -11.60 4.44
17 314.00 UT 12,228 44.02 -11.70 3.76
18 315.00 UT 5,474 34.74 -11.30 4.06
19 316.00 UT 682 22.74 -11.30 5.28
20
21 Carbon Plant
22 310.30 UT 865 34.34 2.42
23 311.00 UT 10,526 36.15 -9.40 3.07
24 312.00 UT 45,246 32.77 -9.60 3.35
25 314.00 UT 15,929 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 11,994 34.90 -2.90 3.15
33 314.00 UT 15,196 35.64 -3.20 3.12
34 315.00 UT 4,672 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 5.41
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 4,045 49.28 -8.50 1.70
45 312.00 CO 49,220 46.28 -8.90 1.89
46 314.00 CO 6,481 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 This Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
DEPRECIATION AND AMORTIZATION OF ELECTRIC PLANT (Continued)
C.=actors Used in Estimt ting Depreciation Charges
Line Depreciable Estimated Net Applied Mortality Average
No Account No.Plant Base Avg.Service Salvage Depr.rates Curve Remaining(In Thousands)Life (Percent)(Percent)Type Life(a)(b)(c)(d)(e)(t)(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 1,670 53.73 -3.50 2.07
19 331.30 WA 908 48.17 -3.50 2.26
20 332.00 WA 37,152 76.12 -3.20 1.57
21 332.30 WA 110 43.93 -3.20 2.42
22 333.00 WA 10,256 66.06 -8.60 1.92
23 334.00 WA 1,164 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 3,484 68.62 -3.50 1.71
32 331.20 WA 14 45.56 -3.50 2.36
33 331.30 WA 2,413 48.27 -3.50 2.25
34 332.00 WA 26,038 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 2,775 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 1,107 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 5,626 58.40 -3.50 1.80
46 331.20 WA 13,532 42.58 -3.50 2.44
47 331.30 WA 1,588 43.35 -3.50 2.40
48 332.00 WA 8,488 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 This Re ort Is:Date of Report Year of Report(1)An Original (Mo,Da,Yr)PacifiCorp Dec.31,2001(2)A Resubmission //
DEPRECIATION AND AMORTIZATION OF ELECTRIC PLANT (Continued)
C.Factors Used in Estimt ting Depreciation Ch irges
Line Depreciable Estimated Net Applied Mortality *Average
No Account No.Plant Base Avg.Service Salvage Depr.rates Curve Remaining
(In Thousands)Life (Percent)(Percent)Type Life
(a)(b)(c)(d)(e)(t)(q)
12 333.00 WA 6,192 71.70 -8.60 1.62
13 334.00 WA 3,331 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 5,011 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 7 49.29 -2.70 2.88
27
28 JC Boyle 18
29 331.00 OR 2,114 58.20 -3.50 1.97
30 331.30 OR 56 45.67 -3.50 2.37
31 332.00 OR 9,551 69.84 -3.20 1.71
32 332.20 OR 869 48.64 -3.20 2.24
33 333.00 OR 4,018 62.57 -8.60 2.02
34 334.00 OR 2,540 48.11 -2.70 2.29
35 334.70 OR 120 62.29 -10.30 3.72
36 335.00 OR 145 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 14,399 61.51 -2.60 2.18
44 332.20 OR 121 72.93 -2.60 2.01
45 333.00 OR 1,639 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 This Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001
(2)A Resubmission I l
DEPRECIATION AND AMORTIZATION OF ELECTRIC PLANT (Continued)
C.Factors Used in Estimt ting Depreciation Charges
Line Depreciable Estimated Net Applied Mortality Average
No Account No.Plant Base Avg.Service Salvage Depr.rates Curve Remaining(In Thousands)Life (Percent)(Percent)Type Life
(a)(b)(c)(d)(e)(t)(g)
12 Iron Gate 610
13 330.20 CA 5 74.00 1.60
14 331.00 CA 1,416 66.34 -3.50 1.86
15 331.20 CA 1,900 53.83 -3.50 2.14
16 331.30 CA 380 54.99 -3.50 2.11
17 332.00 CA 7,575 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 1,140 77.91 -2.40 1.94
41 332.00 ID 7,524 66.51 -2.20 2.09
42 333.00 ID 2,211 53.39 -6.10 2.55
43 334.00 ID 872 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 Cleanuater #2 43
49 331.00 OR 749 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 This Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
DEPRECIATION AND AMORTIZATION OF ELECTRIC PLANT (Continued)
C.Factors Used in EstimLting Depreciation Charges
Line Depreciable Estimated Net Applied Mortality Average
No Account No.Plant Base Avg.Service Salvage Depr.rates Curve Remaining(In Thousands)Life (Percent)(Percent)Type Life(a)(b)(c)(d)(e)(t)(q)
12 332.00 OR 8,926 57.32 -2.60 2.24
13 332.20 OR 5 54.07 -2.60 2.32
14 333.00 OR 925 74.59 -7.20 2.13
15 334.00 OR 198 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 709 69.07 -2.90 1.84
22 332.00 OR 7,517 71.29 -2.60 1.79
23 332.20 OR 2 74.22 -2.60 1.74
24 333.00 OR 1,894 68.84 -7.20 2.00
25 334.00 OR 1,487 46.75 -2.30 2.44
26 334.70 OR 6 39.35 -9.10 3.44
27 335.00 OR 33 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 1,807 60.68 -2.30 2.72
35 332.00 UT 6,756 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 523 59.47 -1.80 2.78
39 335.00 UT 69 36.51 -0.70 3.39
40 336.00 UT 574 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 2,098 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
FERC FORM NO.1 (ED.12-95)Page 337.6
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
DEPRECIATION AND AMORTIZATION OF ELECTRIC PLANT (Continued)
C.=actors Used in Estimi ting Depreciation Ch.arges
Line Depreciable Estimated Net Applied Mortality Average
No Account No.Plant Base Avg.Service Salvage Depr.rates Curve Remaining(In Thousands)Life (Percent)(Percent)Type Life(a)(b)(c)(d)(e)(t)(q)
12
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 2,014 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 4,691 68.65 -2.50 1.93
30 332.20 OR 136 44.60 -2.50 2.55
31 333.00 OR 1,246 57.36 -6.80 2.33
32 334.00 OR 1,253 35.20 -2.10 3.06
33 334.70 OR 80 30.31 -8.60 4.07
34 335.10 OR 16 59.80 1.68
35 336.00 OR 191 53.26 -0.90 2.20
36
37 Prospect #3 (Non)331
38 331.20 OR 11 31.55 -1.90 3.92
39
40 Pioneer 449
41 330.20 UT 9 132.92 1.23
42 330.30 UT 111 133.00 1.23
43 331.00 UT 329 61.16 -2.90 2.07
44 332.00 UT 7,764 43.81 -2.60 2.56
45 333.00 UT 955 51.97 -7.20 2.44
46 334.00 UT 378 47.15 -2.30 2.47
47 335.00 UT 10 41.80 -0.80 2.68
48 336.00 UT 12 51.58 -0.90 2.22
49
50 Lifton 458
FERC FORM NO.1 (ED.12-95)Page 337.7
Name of Respondent This R ort Is:Date of Report Year of Report(1)An Original (Mo,Da,Yr)PacifiCorp Dec.31,2001(2)A Resubmission //
DEPRECIATIONAND AMORTIZATION OF ELECTRIC PLANT (Continued)
C.Factors Used in Estimt ting Depreciation Ch irges
Line Depreciable Estimated Net Appiled Mortality Average
No Account No.Plant Base Avg.Service Salvage Depr.rates Curve Remaining(In Thousands)Life (Percent)(Percent)Type Life(a)(b)(c)(d)(e)(t)(g)
12 330.20 ID 20 115.70 0.97
13 330.30 ID 24 109.25 1.01
14 331.00 ID 1,150 91.06 -4.60 1.31
15 331.30 ID 4 49.54 -4.60 2.12
16 332.00 ID 7,066 72.47 -4.20 1.54
17 333.00 ID 391 100.20 -11.30 1.37
18 334.00 ID 257 63.67 -3.50 1.74
19 335.00 ID 56 52.79 -1.30 2.00
20 336.00 ID 19 113.84 -1.50 1.02
21
22 Oneida 459
23 331.00 ID 1,152 69.60 -3.00 2.02
24 331.30 ID 32 34.41 -3.00 3.05
25 332.00 ID 4,537 64.58 -2.70 2.07
26 333.00 ID 2,145 58.15 -7.50 2.37
27 334.00 ID 696 55.36 -2.30 2.31
28 335.00 ID 6 46.35 -0.90 2.56
29 336.00 ID 381 58.56 -1.00 2.12
30
31 Oneida (Non)559
32 331.00 ID 4 106.04 -3.00 1.06
33 334.00 ID 151 54.86 -2.30 0.75
34
35 Ashton 455
36 331.00 ID 754 48.08 -2.70 2.79
37 331.20 ID 354 32.09 -2.70 3.33
38 332.00 ID 4,490 40.20 -2.50 2.98
39 333.00 ID 1,952 40.09 -6.80 3.16
40 334.00 ID 1,066 38.89 -2.10 3.09
41 334.70 ID 42 29.31 -8.60 4.35
42 335.00 ID 8 46.83 -0.80 2.88
43 336.00 ID 1 101.63 -0.90 2.11
44
45 Copco #1 611
46 330.20 CA 36 113.00 1.04
47 330.40 CA 1 55.00 1.89
48 331.00 CA 1,085 58.13 -3.50 1.93
49 331.30 CA 82 55.70 -3.50 1.99
50 332.00 CA 2,441 92.85 -3.20 1.33
FERC FORM NO.1 (ED.12-95)Page 337.8
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
DEPRECIATION AND AMORTIZATION OF ELECTRIC PLANT (Continued)
C.Factors Used in Estimating Depreciation Ch trges
Line Depreciable Estimated Net Applied Ivlortality Average
No.Account No.Plant Base Avg.Service Salvage Depr.rates Curve Remaining(In Thousands)Life (Percent)(Percent)Type Life(a)(b)(c)(d)(e)(t)(g)
12 333.00 CA 3,758 44.95 -8.60 2.52
13 334.00 CA 939 54.12 -2.70 2.06
14 334.70 CA 59 35.40 -10.30 3.50
15 335.00 CA 1 64.68 -1.00 1.78
16 336.00 CA 105 44.37 -1.10 2.32
17
18 North Umpqua 48
19 331.00 OR 4,803 40.59 -2.90 2.84
20 331.30 OR 27 54.10 -2.90 2.47
21 332.00 OR 92 36.41 -2.60 2.99
22 333.00 OR 40 31.72 -7.20 3.40
23 334.00 OR 142 46.72 -2.30 2.69
24 334.70 OR 424 26.36 -9.10 4.39
25 335.00 OR 1,034 47.22 -0.80 2.68
26 336.00 OR 2,088 62.21 -0.90 2.23
27
28 Soda 461
29 330.20 ID 6 112.35 1.56
30 331.00 ID 572 77.97 -3.00 1.97
31 332.00 ID 4,987 63.98 -2.70 2.14
32 333.00 ID 1,597 57.51 -7.50 2.43
33 334.00 ID 459 62.88 -2.30 2.21
34 335.00 ID 16 45.63 -0.90 2.62
35
36 Soda (Non)561
37 332.00 ID 9 84.65 -2.70 0.62
38
39 Keno
40 330.20 OR 14 87.23 1.64
41 331.20 OR 10 45.56 -3.50 2.47
42 331.30 OR 213 55.15 -3.50 2.22
43 332.00 OR 6,767 65.73 -3.20 2.01
44 332.20 OR 236 68.91 -3.20 1.96
45 334.70 OR 13 32.29 -10.30 3.81
46 336.00 OR 111 69.37 -1.10 1.88
47
48 Fish Creek 45
49 331.00 OR 558 66.38 -2.90 2.15
50 332.00 OR 5,684 56.25 -2.60 2.31
FERC FORM NO.1 (ED.12-95)Page 337.9
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
DEPRECIATION AND AMORTIZATION OF ELECTRIC PLANT (Continued)
C.Factors Used in Estimeting Depreciation Ch trges
Line Depreciable l-stimated Net Applied Mortality Average
No.Account No.Plant Base Avg.Service Salvage Depr.rates Curve Remaining(In Thousands)Life (Percent)(Percent)Type Life
(a)(b)(c)(d)(e)(t)(q)
12 332.20 OR 76 35.78 -2.60 3.00
13 333.00 OR 548 70.26 -7.20 2.24
14 334.00 OR 109 61.91 -2.30 2.26
15 335.00 OR 7 62.46 -0.80 2.25
16 336.00 OR 409 58.74 -0.90 2.19
17
18 Copco #2 612
19 331.00 CA 1,563 47.29 -2.40 2.23
20 332.00 CA 2,774 91.66 -2.20 1.19
21 333.00 CA 3,550 60.82 -6.10 1.91
22 334.00 CA 504 48.28 -1.90 2.20
23 334.70 CA 277 30.12 -7.90 3.94
24 335.00 CA 33 35.48 -0.70 2.91
25 336.00 CA 240 40.43 -0.80 2.51
26
27 Prospect #3 33
28 331.00 OR 279 42.25 -1.90 3.46
29 331.30 OR 2 42.02 -1.90 3.47
30 332.00 OR 1,955 48.27 -1.70 3.26
31 332.20 OR 2,022 23.03 -1.70 4.58
32 333.00 OR 1,921 29.21 -4.60 4.22
33 334.00 OR 442 27.79 -1.50 4.21
34 335.00 OR 73 26.42 -0.50 4.33
35 336.00 OR 51 61.63 -0.60 2.93
36
37 Condit 213
38 330.40 WA 3 25.50 3.40
39 331.00 WA 799 39.20 -260.10 31.41
40 331.30 WA 158 19.94 -260.10 33.45
41 332.00 WA 4,073 41.28 -260.00 31.23
42 332.30 WA 209 9.59 -260.00 39.26
43 333.00 WA 1,149 39.17 -261.00 31.58
44 334.00 WA 94 44.10 -260.00 31.42
45 334.70 WA 54 19.36 -260.00 33.89
46 335.00 WA 29 14.20 -259.70 35.93
47 336.00 WA 60 54.06 -259.70 30.68
48
49 Condit -Non 213
50 330.20 WA 26.43 4.95
FERC FORM NO.1 (ED.12-95)Page 337.10
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubrnission //
DEPRECIATION AND AMORTIZATION OF ELECTRIC PLANT (Continued)
C.Factors Used in EstimLting Depreciation Charges
Line Depreciable Estimated Net Applied Mortality Average
No Account No.Plant Base Avg.Service Salvage Depr.rates Curve Remaining(In Thousands)Life (Percent)(Percent)Type Life(a)(b)(c)(d)(e)(t)(g)
12
13 Soda Springs 46
14 331.00 OR 812 70.28 -2.90 1.75
15 332.00 OR 3,467 71.07 -2.60 1.72
16 333.00 OR 614 76.63 -7.20 1.79
17 334.00 OR 403 42.81 -2.30 2.56
18 334.70 OR 30 35.94 -9.10 3.57
19 335.00 OR 2 37.33 -0.80 2.84
20 336.00 OR 26 34.58 -0.90 2.95
21
22 Slide Creek 47
23 331.00 OR 607 62.40 -2.90 2.07
24 332.00 OR 3,753 68.63 -2.60 1.93
25 333.00 OR 684 77.39 -7.20 1.97
26 334.00 OR 415 61.83 -2.30 2.11
27 334.70 OR 59 27.36 -9.10 4.26
28 335.00 OR 5 40.50 -0.80 2.75
29 336.00 OR 17 46.61 -0.90 2.40
30
31 Clearwater #1 42
32 331.00 OR 559 69.71 -2.60 1.66
33 332.00 OR 3,339 75.63 -2.60 1.55
34 332.20 OR 5 76.22 -2.60 1.54
35 333.00 OR 720 73.99 -7.20 1.74
36 334.00 OR 149 71.31 -2.30 1.66
37 334.70 OR 47 29.36 -9.10 4.01
38 335.00 OR 7 56.33 -0.80 1.99
39
40 Klarnath 19
41 330.20 OR 624 40.00 2.57
42 330.40 OR 235 55.00 2.34
43 331.00 OR 9 42.84 -3.50 2.68
44 331.30 OR 11 61.51 -3.50 2.45
45 332.00 OR 2,783 74.21 -3.20 2.33
46 334.00 OR 2 66.07 -2.70 2.47
47 335.00 OR 36 70.18 -1.00 2.48
48
49 Big Fork 410
50 331.00 MT 305 24.39 -0.10 18.88
FERC FORM NO.1 (ED.12-95)Page 337.11
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)g An Original (Mo,Da,Yr)Dec.31,2001
(2)A Resubmission //
DEPRECIATION AND AMORTIZATION OF ELECTRIC PLANT (Continued)
C.Factors Used in Estimating Depreciation Ch irges
Line Depreciable Estimated Net Applied Mortality Average
No Account No.Plant Base Avg.Service Salvage Depr.rates Curve Remaining
(In Thousands)Life (Percent)(Percent)Type Life
(a)(b)(c)(d)(e)(t)(q)
12 331.30 MT 13 35.80 -0.10 18.36
13 332.00 MT 3,747 21.86 -0.10 19.02
14 332.20 MT 88 8.00 -0.10 22.18
15 332.30 MT 2 9.00 -0.10 21.63
16 333.00 MT 1,347 20.07 -0.30 19.29
17 334.00 MT 197 23.56 -0.10 18.94
18 335.10 MT 18 17.90 5.58
19 336.00 MT 4 12.41 20.38
20
21 Prospect #1 31
22 331.00 OR 213 38.39 -2.70 1.37
23 331.30 OR 1 56.09 -2.70 1.73
24 332.00 OR 129 106.15 -2.50 0.78
25 333.00 OR 140 68.86 -6.80 1.51
26 334.00 OR 48 65.77 -2.10 1.44
27 336.00 OR 4 62.63 -0.90 1.45
28
29 Prospect #4 34
30 331.00 OR 51 47.43 -2.70 2.25
31 331.30 OR 9 33.09 -2.70 3.13
32 332.00 OR 49 57.14 -2.50 1.89
33 333.00 OR 53 81.87 -6.80 1.53
34 334.00 OR 22 70.71 -2.10 1.58
35
36 Eastside 16
37 331.00 OR 99 58.08 -0.60 2.19
38 332.00 OR 1,414 48.19 -0.50 2.51
39 333.00 OR 103 81.82 -1.50 1.81
40 334.00 OR 99 31.47 -0.50 3.60
41 334.70 OR 18 13.37 -2.30 8.20
42 335.00 OR 11 81.76 -0.20 1.68
43 336.00 OR 67 20.50 -0.20 5.17
44
45 Westside 17
46 331.00 OR 91 36.38 -0.60 1.67
47 331.30 OR 8 27.44 -0.60 2.68
48 332.00 OR 129 86.90 -0.50 -0.16
49 333.00 OR 26 77.04 -1.50 0.13
50 334.00 OR 29 42.55 -0.50 1.21
FERC FORM NO.1 (ED.12-95)Page 337.12
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
DEPRECIATION AND AMORTIZATION OF ELECTRIC PLANT (Continued)
C.Factors Used in Estimt ting Depreciation Ch trges
Line Deprectable Estimated Net Applied Mortahty Average
No.Account No.Plant Base Avg.Service Salvage Depr.rates Curve Remaining
(In Thousands)Life (Percent)(Percent)T e Life
(a)(b)(c)(d)(e)(q)
12 336.00 OR 62.97 -0.20 0.31
13
14 Fall Creek 613
15 330.40 CA 17 25.00 5.13
16 331.00 CA 119 33.35 -0.60 4.38
17 331.30 CA 3 34.93 -0.60 4.26
18 332.00 CA 469 27.65 -0.50 4.89
19 333.00 CA 136 46.49 -1.50 3.76
20 334.00 CA 32 49.62 -0.50 3.54
21
22 Fall Creek 13
23 330.20 OR 1 103.00 7.33
24 330.40 OR 24.00 8.64
25 332.00 OR 149 19.40 -0.50 9.15
26
27 Naches Drop 214
28 330.20 WA 1 41.00 5.91
29 331.00 WA 44 61.62 -0.60 5.52
30 332.00 WA 178 45.16 -0.50 5.87
31 333.00 WA 169 42.70 -1.50 6.09
32 334.00 WA 22 26.64 -0.50 6.89
33
34 Cove 456
35 331.00 ID 187 77.21 -1.50 2.36
36 332.00 ID 1,894 79.40 -1.30 2.31
37 333.00 ID 360 52.73 -3.70 2.97
38 334.00 ID 323 31.67 -1.20 3.85
39 335.00 ID 3 28.73 -0.40 4.10
40 336.00 ID 9 97.88 -0.50 2.06
41
42 Paris 460
43 331.00 \D 38 42.89 -1.50 2.94
44 332.00 ID 96 64.75 -1.30 2.24
45 333.00 ID 69 43.13 -3.70 3.06
46 334.00 ID 97 34.51 -1.20 3.44
47 335.00 ID 7 27.96 -0.40 4.01
48
49 Wallowa Falls 29
50 331.00 OR 44 36.30 -1.60 3.62
FERC FORM NO.1 (ED.12-95)Page 337.13
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001
(2)A Resubmission //
DEPRECIATIONAND AMORTIZATION OF ELECTRIC PLANT (Continued)
C.Factors Used in Estimtting Depreciation Ch arges
Line Depreciable Estimated Net Applied Mortality Average
No Account No.Plant Base Avg.Service Salvage Depr.rates Curve Remaining
(In Thousands)Life (Perœnt)(Percent)Type Life
(a)(b)(c)(d)(e)(t)(q)
12 331.30 OR 64 23.25 -1.60 4.73
13 332.00 OR 2,057 22.86 -1.40 4.77
14 333.00 OR 56 54.63 -3.90 3.09
15 334.00 OR 196 24.15 -1.20 4.64
16 334.70 OR 55.27 -5.50 3.63
17 336.00 OR 323 22.87 -0.50 4.70
18
19 Ferguson Ridge 292
20 334.70 WA 4 24.96 -5.50 3.59
21
22 St.Anthony 462
23 331.00 ID 86 39.72 -1.60 4.29
24 332.00 ID 571 29.06 -1.40 4.67
25 333.00 ID 497 25.83 -3.90 5.03
26 334.00 ID 161 30.20 -1.20 4.68
27 335.00 ID 41.05 -0.50 4.33
28
29 Olmstead 448
30 331.00 UT 173 85.05 -1.60 2.15
31 334.00 UT 17 18.34 -1.20 5.55
32 335.00 UT 3 37.23 -0.50 3.39
33 336.00 UT 4 32.87 -0.Š0 3.56
34
35 Bend 23
36 331.00 OR 37 56.03 -0.50 1.75
37 331.30 OR 10 36.77 -0.50 2.70
38 332.00 OR 76 82.28 -0.40 1.16
39 332.30 OR 2 36.96 -0.40 2.67
40 333.00 OR 77 63.23 -1.20 1.64
41 334.00 OR 76 25.05 -0.40 3.99
42 334.70 OR 535 17.18 -1.90 6.24
43 336.00 OR 68.98 -0.20 1.33
44
45 Cline Falls 24
46 331.00 OR 116 21.20 -0.50 8.43
47 332.00 OR 59 49.91 -0.40 6.82
48 333.00 OR 47 58.43 -1.20 6.77
49 334.00 OR 11 53.67 -0.40 6.79
50 334.70 OR 33 13.26 -1.90 10.74
FERC FORM NO.1 (ED.12-95)Page 337.14
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
DEPRECIATION AND AMORTIZATION OF ELECTRIC PLANT (Continued)
C.Factors Used in Estimi ting Depreciation Charges
Line Depreciable Estimated Net Applied Mortality Average
No Account No.Plant Base Avg.Service Salvage Depr.rates Curve Remaining(In Thousands)Life (Percent)(Percent)Type Life(a)(b)(c)(d)(e)(t)(g)
12 336.00 OR 1 61.98 -0.20 6.54
13
14 Eagle Point 36
15 330.20 OR 12 53.00 5.00
16 331.00 OR 121 31.32 -1.00 5.78
17 332.00 OR 1,086 25.43 -0.90 6.12
18 332.20 OR 26 37.52 -0.90 5.50
19 333.00 OR 258 42.71 -2.50 5.50
20 334.00 OR 64 37.44 -0.80 5.57
21 336.00 OR 28 23.28 -0.30 6.23
22
23 Weber 454
24 331.00 UT 216 55.63 -2.00 2.76
25 331.30 UT 148 27.49 -2.00 4.02
26 332.00 UT 1,023 65.31 -1.80 2.56
27 333.00 UT 874 35.38 -4.90 3.62
28 334.00 UT 115 44.20 -1.50 3.11
29 335.00 UT 22 34.23 -0.60 3.57
30 336.00 UT 40 25.53 -0.60 4.12
31
32 Gunlock 463
33 331.00 UT 32 54.83 -2.00 2.70
34 332.00 UT 79 75.62 -1.80 2.32
35 333.00 UT 121 36.64 -4.90 3.49
36 334.00 UT 239 30.89 -1.50 3.74
37 335.00 UT 5 41.25 -0.60 3.17
38 336.00 UT 66.40 -0.60 2.38
39
40 Veyo 464
41 331.00 UT 67 38.10 -2.00 3.42
42 332.00 UT 356 38.20 -1.80 3.40
43 333.00 UT 144 64.88 -4.90 2.88
44 334.00 UT 140 35.97 -1.50 3.56
45 335.00 UT 8 40.45 -0.60 3.37
46 336.00 UT 62.15 -0.60 2.68
47
48 Sandcove 465
49 331.00 UT 31 48.54 -2.00 2.88
50 332.00 UT 395 55.99 -1.80 2.66
FERC FORM NO.1 (ED.12-95)Page 337.15
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)p An Original (Mo,Da,Yr)Dec.31,2001(2)p A Resubmission //
DEPRECIATION AND AMORTIZATION OF ELECTRIC PLANT (Continued)
C.Factors Used in Estimi ting Depreciation Ch arges
Line Depreciable Estimated Net Applied Ivlortality Average
No.Account No.Plant Base Avg.Service Salvage Depr.rates Curve Remaining(In Thousands)Life (Percent)(Percent)Type Life(a)(b)(c)(d)(e)(t)(g)
12 333.00 UT 162 31.40 -4.90 3.82
13 334.00 UT 228 25.67 -1.50 4.20
14 336.00 UT 2 93.80 -0.60 2.08
15
16 Stairs 452
17 331.00 UT 155 52.42 -2.40 2.40
18 332.00 UT 335 59.75 -2.20 2.19
19 333.00 UT 513 36.74 -6.10 3.19
20 334.00 UT 151 39.83 -1.90 2.90
21
22 Last Chance 468
23 331.00 ID 423 40.36 -2.40 2.87
24 332.00 ID 819 41.04 -2.20 2.82
25 333.00 ID 1,087 39.99 -6.10 3.03
26 334.00 ID 103 39.87 -1.90 2.91
27 336.00 ID 65 41.70 -0.80 2.72
28
29 American Fork 441
30 331.00 UT 87 61.13 -2.90 1.97
31 331.30 UT 32.97 -2.90 3.15
32 332.00 UT 601 66.22 -2.60 1.85
33 333.00 UT 121 53.51 -7.20 2.32
34 334.00 UT 117 46.74 -2.30 2.42
35 335.00 UT 2 41.64 -0.80 2.63
36 336.00 UT 9 37.12 -0.90 2.79
37
38 Upper Beaver 443
39 331.00 UT 154 76.14 -2.90 1.77
40 332.00 UT 1,820 47.36 -2.60 2.40
41 333.00 UT 118 52.53 -7.20 2.40
42 334.00 UT 401 38.38 -2.30 2.83
43 335.00 UT 10 41.62 -0.80 2.66
44 336.00 UT 2 81.42 -0.90 1.61
45
46 Snake Creek 451
47 331.00 UT 53 48.21 -2.00 2.81
48 332.00 UT 423 44.38 -1.80 2.92
49 333.00 UT 263 35.93 -4.90 3.48
50 334.00 UT 145 37.55 -1.50 3.27
FERC FORMNO.1 (ED.12-95)Page 337.16
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
DEPRECIATION AND AMORTIZATION OF ELECTRIC PLANT (Continued)
C.¯actors Used in Estimiting Depreciation Ch trges
Line Depreciable Estimated Net Applied Mortality Average
No Account No.Plant Base Avg.Service Salvage Depr.rates Curve Remaining(In Thousands)Life (Percent)(Percent)Type Life
(a)(b)(c)(d)(e)(t)(g)
12 335.00 UT 2 32.56 -0.60 3.57
13
14 Viva Naughton 467
15 331.00 WY 386 51.78 -3.80 2.06
16 332.00 WY 104 51.89 -3.50 2.05
17 333.00 WY 486 51.82 -9.50 2.21
18 334.00 WY 159 50.48 -3.00 2.12
19 335.00 WY 21 49.01 -1.10 2.15
20
21 Granite 445
22 331.00 UT 134 63.88 -2.90 1.89
23 332.00 UT 3,490 59.10 -2.60 1.98
24 333.00 UT 676 46.15 -7.20 2.56
25 334.00 UT 174 43.27 -2.30 2.55
26 335.00 UT 1 56.63 -0.80 2.07
27
28 Fountain Green 446
29 331.00 UT 20 57.11 -1.00 8.16
30 332.00 UT 319 19.72 -0.90 8.14
31 333.00 UT 24 75.52 -2.50 8.31
32 334.00 UT 70 25.40 -0.80 8.26
33 335.00 UT 2 23.68 -0.30 8.27
34 336.00 UT 1 77.94 -0.30 7.65
35
36 Skookumchuck 201
37 331.00 WA 1,104 54.36 -4.60 1.92
38 332.10 WA 5,126
39 333.00 WA 1,143 54.38 -11.30 2.06
40 334.00 WA 343 51.47 -3.50 2.01
41 336.00 WA 199 64.50 1.55
42
43 OTHER
44
45 Hermiston Plant
46 341.00 WA 11,020 34.92 -2.00 2.85
47 342.00 WA 3,089 35.00 -2.00 2.83
48 343.00 WA 93,445 35.00 -2.00 2.83
49 344.00 WA 38,055 35.00 -2.00 2.83
50 345.00 WA 9,059 35.00 -2.00 2.83
FERC FORM NO.1 (ED.12-95)Page 337.17
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
DEPRECIATION AND AMORTIZATION OF ELECTRIC PLANT (Continued)
C.Factors Used in Estim;ting Depreciation Ch trges
Line Depreciable Estimated Net Applied Mortality Average
No.Account No.Plant Base Avg.Service Salvage Depr.rates Curve Remaining
(In Thousands)Life (Percent)(Percent)T e Life(a)(b)(c)(d)(e)(g)
12 346.00 WA 497 35.00 -2.00 2.83
13
14
15 Little Mountain
16 341.00 UT 204 27.13 -5.20 4.23
17 342.00 UT 121 29.71 -5.20 3.89
18 343.00 UT 1,275 25.12 -5.20 4.53
19 344.00 UT 2,344 30.94 -5.20 3.76
20 345.00 UT 215 24.61 -5.20 4.62
21 346.00 UT 37 18.19 -5.20 6.81
22
23 High Desert Solar Gen
24 344.00 OR 56 15.00 6.72
25
26 Canyon Lands Dist Serv
27 344.00 UT 36 15.00 6.72
28
29 Green River Solar Gen
30 344.00 UT 55 15.00 6.72
31
32 Foote Creek Wind Gen
33 344.00 WY 40,460 35.00 2.00 2.87
34
35 Transmission Plant
36 350.20 52,465 70.00 1.31
37 352.00 44,787 65.00 -15.00 1.67
38 353.00 663,340 55.00 -5.00 1.83
39 353.70 40,193 15.00 6.03
40 354.00 345,882 65.00 -25.00 1.78
41 355.00 417,326 50.00 -25.00 2.34
42 356.00 537,342 65.00 -45.00 2.09
43 356.20 30,345 70.00 1.26
44 357.00 2,015 50.00 -80.00 2.47
45 358.00 2,316 50.00 -30.00 2.13
46 359.00 10,990 70.00 1.39
47
48 Distribution Plant -UT
49 360.20 UT 8,328 52.00 1.99
50 361.00 UT 13,452 60.00 -10.00 1.87
FERC FORM NO.1 (ED.12-95)Page 337.18
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)QAn Original (Mo,Da,Yr)Dec.31,2001(2)p A Resubmission //
DEPRECIATION AND AMORTIZATION OF ELECTRIC PLANT (Continued)
C.Factors Used in Estimi ting Depreciation Ch-irges
Line Depreciable i-stimated Net Applied Mortality Average
No Account No.Plant Base Avg.Service Salvage Depr.rates Curve Remaining(In Thousands)Life (Percent)(Percent)Type Life(a)(b)(c)(d)(e)(t)(g)
12 362.00 UT 227,625 55.00 -10.00 2.02
13 362.70 UT 8,250 15.00 6.99
14 364.00 UT 264,855 42.00 -105.00 4.75
15 365.00 UT 178,816 42.00 -80.00 4.24
16 366.00 UT 116,279 50.00 -80.00 3.59
17 367.00 UT 325,068 50.00 -20.00 2.42
18 368.00 UT 306,192 40.00 -25.00 3.16
19 369.00 UT 114,269 50.00 -50.00 2.97
20 370.00 UT 89,318 30.00 -5.00 3.64
21 371.00 UT 4,826 15.00 -35.00 9.11
22 372.00 UT 50 25.00 4.54
23 373.00 UT 23,914 18.00 -35.00 7.55
24
25 Distribution Plant -OR
26 360.20 OR 3,556 50.00 2.00
27 361.00 OR 10,868 52.00 -5.00 2.11
28 362.00 OR 144,223 45.00 -10.00 2.55
29 362.70 OR 3,071 12.00 10.01
30 364.00 OR 244,466 35.00 -105.00 6.25
31 365.00 OR 191,885 40.00 -80.00 4.83
32 366.00 OR 62,651 50.00 -5.00 2.20
33 367.00 OR 105,613 40.00 -40.00 3.73
34 368.00 OR 297,440 35.00 -20.00 3.74
35 369.10 OR 47,621 45.00 -30.00 3.15
36 369.20 OR 82,340 40.00 -30.00 3.48
37 370.00 OR 56,109 30.00 -5.00 3.79
38 371.00 OR 2,476 15.00 -10.00 12.68
39 373.00 OR 15,408 35.00 -35.00 4.23
40
41 Distribution Plant -WA
42 360.20 WA 298 50.00 2.14
43 361.00 WA 1,435 50.00 -30.00 2.67
44 362.00 WA 38,428 45.00 -10.00 2.51
45 362.70 WA 534 15.00 7.42
46 364.00 WA 63,995 45.00 -150.00 5.70
47 365.00 WA 46,900 50.00 -80.00 3.70
48 366.00 WA 10,778 60.00 -50.00 2.54
49 367.00 WA 12,435 45.00 -40.00 3.20
50 368.00 WA 69,865 40.00 -80.00 4.69
FERC FORM NO.1 (ED.12-95)Page 337.19
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
DEPRECIATION AND AMORTIZ.ATION OF ELECTRIC PLANT (Continued)
C.Factors Used in Estimating Depreciation Ch trges
Line Depreciable Estimated Net Applied Ivlortality Average
No Account No.Plant Base Avg.Service Salvage Depr.rates Curve Remaining
(In Thousands)Life (Percent)(Percent)Type Life(a)(b)(c)(d)(e)(t)(g)
12 369.10 WA 11,884 50.00 -35.00 2.80
13 369.20 WA 17,061 50.00 -35.00 2.77
14 370.00 WA 13,363 30.00 -5.00 3.63
15 371.00 WA 551 30.00 -85.00 6.57
16 373.00 WA 3,010 30.00 -70.00 5.97
17
18 Distribution Plant -WY
19 360.20 WY 1,939 50.00 1.98
20 361.00 WY 5,227 45.00 -10.00 2.43
21 362.00 WY 82,769 40.00 -10.00 2.73
22 362.70 WY 2,571 15.00 6.51
23 364.00 WY 59,228 43.00 -105.00 4.73
24 365.00 WY 64,847 45.00 -60.00 3.53
25 366.00 WY 7,227 55.00 -30.00 2.35
26 367.00 WY 17,245 40.00 -25.00 3.10
27 368.00 WY 50,701 40.00 -40.00 3.46
28 369.10 WY 7,573 50.00 -50.00 2.98
29 369.20 WY 9,840 50.00 -50.00 2.98
30 370.00 WY 11,072 30.00 -5.00 3.46
31 371.00 WY 739 20.00 -40.00 6.87
32 373.00 WY 5,139 40.00 -50.00 3.72
33
34 Distribution Plant -CA
35 360.20 CA 914 65.00 1.74
36 361.00 CA 1,413 45.00 -5.00 2.45
37 362.00 CA 11,395 55.00 -50.00 2.91
38 362.70 CA 229 15.00 7.66
39 364.00 CA 36,872 45.00 -120.00 5.22
40 365.00 CA 29,322 55.00 -100.00 3.80
41 366.00 CA 13,362 45.00 -25.00 2.91
42 367.00 CA 14,035 40.00 -35.00 3.59
43 368.00 CA 36,482 40.00 -75.00 4.76
44 369.10 CA 6,095 40.00 -30.00 3.42
45 369.20 CA 8,951 50.00 -30.00 2.67
46 370.00 CA 4,005 30.00 -10.00 4.01
47 371.00 CA 266 25.00 -85.00 8.42
48 373.00 CA 634 30.00 -100.00 7.22
49
50 General Plant -OR
FERC FORM NO.1 (ED.12-95)Page 337.20
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
DEPRECIATION AND AMORTIZATION OF ELECTRIC PLANT (Continued)
C.=actors Used in Estimt ting Depreciation Ch trges
Line Depreciable Estimated Net Applied Mortality Average
No Account No.Plant Base Avg.Service Salvage Depr.rates Curve Remaining
(In Thousands)Life (Percent)(Percent)Type Life(a)(b)(c)(d)(e)(t)(q)
12 390.00 OR 53,769 40.00 2.55
13 391.10 OR 5,192 5.00 2.42
14 392.00 OR 135 8.00 10.00 10.78
15 392.01 OR 451 8.00 10.00 10.78
16 392.02 OR 880 8.00 10.00 10.78
17 392.03 OR 79 8.00 10.00 10.78
18 392.04 OR 4,937 14.00 10.00 6.31
19 392.05 OR 4,672 14.00 10.00 6.31
20 392.06 OR 353 14.00 10.00 6.31
21 392.08 OR 547 14.00 10.00 6.31
22 392.09 OR 2,249 35.00 20.00 2.25
23 396.00 OR 804 15.00 35.00 4.25
24 396.01 OR 285 15.00 35.00 4.25
25 396.02 OR 6,502 15.00 35.00 4.25
26 396.03 OR 4,594 15.00 35.00 4.25
27 396.04 OR 1,399 15.00 35.00 4.25
28 396.07 OR 724 15.00 35.00 4.25
29 396.08 OR 7,928 15.00 35.00 4.25
30 397.00 OR 88,048 20.00 -5.00 5.58
31
32 General Plant -WA
33 390.00 WA 9,338 35.00 -15.00 3.12
34 392.00 WA 24 8.00 10.00 12.49
35 392.01 WA 141 8.00 10.00 12.49
36 392.02 WA 146 8.00 10.00 12.49
37 392.04 WA 1,071 15.00 10.00 6.46
38 392.05 WA 1,268 15.00 10.00 6.46
39 392.06 WA 138 15.00 10.00 6.46
40 392.09 WA 410 40.00 15.00 2.30
41 396.01 WA 191 14.00 20.00 6.21
42 396.02 WA 1,810 14.00 20.00 6.21
43 396.03 WA 1,341 14.00 20.00 6.21
44 396.04 WA 489 14.00 20.00 6.21
45 396.07 WA 158 14.00 20.00 6.21
46 396.08 WA 2,051 14.00 20.00 6.21
47 397.00 WA 11,266 25.00 -5.00 3.75
48
49 Mining Operations -WA
50 399.51 8.00 10.00 4.10
FERC FORM NO.1 (ED.12-95)Page 337.21
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001
(2)A Resubmission //
DEPRECIATIONAND AMORTIZATION OF ELECTRIC PLANT (Continued)
C.Factors Used in Estimating Depreciation Ch arges
Line Depreciable Estimated Net Applied Mortality Average
No Account No.Plant Base Avg.Service Salvage Depr.rates Curve Remaining(In Thousands)Life (Percent)(Percent)Type Life(a)(b)(c)(d)(e)(t)(q)
12 399.52 13.00 15.00 5.99
13 399.60 13.00 10.17
14 399.61 10.00 3.06
15
16 General Plant -UT
17 389.20 40 40.00 2.51
18 390.00 87,652 40.00 5.00 2.38
19 392.00 220 12.00 15.00 5.47
20 392.01 2,366 12.00 15.00 5.47
21 392.02 894 12.00 15.00 5.47
22 392.03 97 12.00 15.00 5.47
23 392.04 13,580 12.00 15.00 4.62
24 392.05 14,725 12.00 15.00 4.62
25 392.06 1,648 12.00 15.00 4.62
26 392.08 1,614 12.00 15.00 4.62
27 392.09 7,334 30.00 30.00 1.75
28 396.00 956 15.00 20.00 4.06
29 396.01 5,211 15.00 20.00 4.06
30 396.02 10,430 15.00 20.00 4.06
31 396.03 3,559 15.00 20.00 4.06
32 396.04 4,683 15.00 20.00 4.06
33 396.07 5,040 15.00 20.00 4.06
34 396.08 14,339 15.00 20.00 4.06
35 397.00 65,240 20.00 5.03
36
37 Mining Operations -UT
38 399.30 UT 34,836 25.00 4.46
39 399.45 UT 108,055 11.00 5.00 5.57
40 399.51 UT 1,306 15.00 5.00 4.43
41 399.52 UT 2,556 20.00 1.91
42 399.60 UT 2,383 15.00 4.15
43 399.61 UT 1,828 8.00 18.50
44 399.70 UT 21,892 15.00 6.84
45
46 General Plant -WY
47 390.00 WY 1,824 35.00 -5.00 3.19
48 392.00 WY 129 8.00 15.00 12.75
49 392.01 WY 275 8.00 15.00 12.75
50 392.02 WY 246 8.00 15.00 12.75
FERC FORM NO.1 (ED.12-95)Page 337.22
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)pAn Original (Mo,Da,Yr)Dec.31,2001
(2)A Resubmission //
DEPRECIATION AND AMORTIZATION OF ELECTRIC PLANT (Continued)
C.Factors Used in Estimi ting Depreciation Ch trges
Line Depreciable t-stimated Net Applied Mortality Average
No Account No.Plant Base Avg.Service Salvage Depr.rates Curve Remaining
(In Thousands)Life (Percent)(Percent)T e Life(a)(b)(c)(d)(e)(g)
12 392.04 WY 2,067 12.00 5.00 8.76
13 392.05 WY 2,019 12.00 5.00 8.76
14 392.06 WY 195 12.00 5.00 8.76
15 392.08 WY 257 12.00 5.00 8.76
16 392.09 WY 1,396 30.00 3.55
17 396.00 WY 775 10.00 45.00 6.40
18 396.01 WY 5,442 10.00 45.00 6.40
19 396.02 WY 2,465 10.00 45.00 6.40
20 396.03 WY 1,086 10.00 45.00 6.40
21 396.04 WY 1,505 10.00 45.00 6.40
22 396.07 WY 275 10.00 45.00 6.40
23 396.08 WY 2,450 10.00 45.00 6.40
24 397.00 WY 18,738 20.00 5.34
25
26 General Plant -CA
27 390.00 CA 1,413 45.00 -10.00 1.93
28 392.00 CA 6 8.00 10.00 10.90
29 392.01 CA 22 8.00 10.00 10.90
30 392.04 CA 370 15.00 5.00 6.09
31 392.05 CA 279 15.00 5.00 6.09
32 392.06 CA 58 15.00 5.00 6.09
33 392.09 CA 242 30.00 3.24
34 396.02 CA 692 15.00 15.00 5.45
35 396.03 CA 622 15.00 15.00 5.45
36 396.04 CA 190 15.00 15.00 5.45
37 396.07 CA 48 15.00 15.00 5.45
38 396.08 CA 639 15.00 15.00 5.45
39 397.00 CA 4,013 20.00 3.89
40
41 General Plant -MT
42 390.00 MT 340 30.00 3.32
43 392.01 MT 12.00 15.00 7.09
44 392.04 MT 2 15.00 15.00 5.69
45 392.09 MT 30.00 30.00 2.36
46 396.01 MT 15 12.00 20.00 6.69
47 397.00 MT 2,322 20.00 4.97
48
49 General Plant
50 390.30 10,300 15.00 6.67
FERC FORM NO.1 (ED.12-95)Page 337.23
Name of Respondent This Report is:Date of Report Year of Report
PacifiCorp (1)pAn Original (Mo,Da,Yr)Dec.31,2001
(2)QA Resubmission //
DEPRECIATION AND AMORTIZATION OF ELECTRIC PLANT (Continued)
C.Factors Used in Estimeting Depreciation Ch trges
Line Deprectable Estimated Net Applied Mortality Average
No Account No.Plant Base Avg.Service Salvage Depr.rates Curve Remaining
(In Thousands)Life (Percent)(Percent)T e Life
(a)(b)(c)(d)(e)(q)
12 391.00 32,542 20.00 5.00
13 391.20 67,827 5.00 20.00
14 391.30 2,187 8.00 12.50
15 393.30 9,291 25.00 4.00
16 394.00 44,887 24.00 4.17
17 395.00 32,508 20.00 5.00
18 397.20 7,286 11.00 9.09
19 398.00 4,819 20.00 5.00
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
49
50
FERC FORM NO.1 (ED.12-95)Page 337.24
NameofRespondent ThisRepod Is:DateofRepod YearofRepod
PacifCoga (1)AnOnginal (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
PARTICULARS CONCERNING CERTAIN INCOMEDEDUCTIONS AND INTEREST CHARG IS ACCOUNTS
Report the information specified below,in the order given,for the respective income deduction and interest charges account.Provide a subheading for
each account and a total for the account.Additional columns may be added if deemed appropriate with respect to any account.
(a)Miscellaneous Amortization (Account 425):Describe the nature of items included in this account,the contra account charged,the total of
amortization charges for the year,and the period of amortization.
(b)Miscellaneous Income Deductions:Report the nature,payee,and amountof 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
classeswithintheaboveaccounts.
(c)Interest on Debt to Associated Companies (Account 430)-For each associated company to which interest on debt was incurred during the year,
indicate the amount and interest rate respectively for (a)advances on notes,(b)advances on open account,(c)notes payable,(d)accounts payable,and
(e)other debt,and total interest.Explain the nature of other debt on which interest was incurred during the year.
(d)Other Interest Expense (Account 431)-Report particulars (details)including the amount and interest rate for other interest charges incurred
during theyear.
Line Iteni ArnountNk).(a)(b)
1 Miscellanious Amortization (Account 425)
2 Miscellanious Mine Amortizations 21,769
3
4 TotalAccount425 21,769
5
6 Donations(Account426.1)
7 CCCEndowrnentFund 500,000
8 Olympic Music Ed.Program 145,000
9 OlympicHospitalig 418,804
10 Oregon EnergyAssistance Progranis 225,340
11 OtherDonationsEachUnder5%ofAccountBalanco 1,GG4,684
12
13 TotalAccount426.1 2,333,828
14
15 Life Insurance (Account426.2)
16 Life Insurance -6,393,830
17
18 TotalAccount426.2 45,393,830
19
20 Penalties(Account426.3)
21 Craig Plant-Sierra Club Lawsuit Civil Penalty 96,400
22 StateofCalifornia 41,504
23 Other Penalties Each Under 5%of Account Balance 11,035
24
25 TotalAccount426.3 148,939
26
27 Civic,Political &Related Expenses (Account 426.4)
28 Baker Donelson Beannan &Caldwell 117,141
29 Capital Strategies 58,658
30 Smith &Ke«npton 65,791
31 Thonias E.Ebzegt,P.C.73,470
32 M/esterberig &Associates 79,078
33 Shawm Miller 45,088
34 TheTresidderCompany .42,300
35 Other Each Under5°/o ofAccountBalance 321,261
36
37 TotalAccount426..4 802,787
38
39 OtherDeductions(Account426.5)
40 Legal Settlement Wyoming Joint Powers Water Board 2,700,000
41 OlympicHospitality 399,710
FERC FORM NO.1 (ED.12-87)Page 340
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001
(2)A Resubmission //
PARTICULARS CONCERNING CERTAIN INCOME DEDUCTIONS AND INTEREST CHARG ES ACCOUNTS
Report the information specified below,in the order given,for the respective incomededuction and interest charges account.Provide a subheading for
each account and a total for the account.Additional columns may be added if deemed appropriate with respect to any account.
(a)Miscellaneous Amortization (Account 425):Describe the nature of items included in this account,the contra account charged,the total of
amortization charges for the year,and the period of amortization.
(b)Miscellaneous Income Deductions:Report the nature,payee,and amount of other income deductions for the year as required by Accounts 426.1,
Donations;426.2,Life Insurance;426.3,Penalties;426.4,Expenditures for Certain Civic Political and Related Activities;and 426.5,Other Deductions,of
the Uniform System of Accounts.Amounts of less than 5%of each account total for the year (or $1,000,whichever is greater)may be grouped by
classes within the above accounts.
(c)Interest on Debt to Associated Companies (Account 430)-For each associated company to which interest on debt was incurred during the year,
indicate the amount and interest rate respectively for (a)advances on notes,(b)advances on open account,(c)notes payable,(d)accounts payable,and
(e)other debt,and total interest.Explain the nature of other debt on which interest was incurred during the year.
(d)Other Interest Expense (Account 431)-Report particulars (details)including the amount and interest rate for other interest charges incurred
during the year.
Line Item AmountNo.(a)(b)
1 SERP Trust 1,258,870
2 Reverse 1999 Write-Off of PERCO Cash Account Items 766,797
3 Reverse Montana Sale Reserve -1,858,039
4 Scottish Power Related Expenses -1,814,842
5 Other Each Under 5%of Account Balance 3,301,946
6
7 Total Account 426.5 4,754,442
8
9 Interest on Debt to Assoc.Co.(Account 430)
10 PacifiCorp Group Holding Company 6,419,097
11 PacifiCorp Minerals Inc.841,180
12 PacifiCorp Capital I 8.25%18,456,240
13 PacifiCorp Capital 11 7.70%10,716,552
14
15 Total Account 430 36,433,069
16
17 Other Interest Expense (Account 431)
18 Casper 1 Lease -14.50%88,907
19 Casper 2 Lease -14.50%40,487
20 Clatsop Lease -12.80%101,182
21 Coal Royalty Interest -5.00%8,766
22 Commercial Paper -3.50%to 6.25%10,619,576
23 Corp.Owned Life Insurance Loans -7.22%6,020,056
24 Customer Over Payments -6.00%47,662
25 Deferred Compensation -6.14%to 8.00%808,158
26 Short Term Debt Commitment Fees .09%to .125%1,917,571
27 Electric Purchases 731,177
28 Environmental Liabilities Centralia -1.80%to 6.75%259,199
29 Intemal Revenue Service 1,200,000
30 Misc.Interest 430,824
31 OUC Lease -11.73%1,856,747
32 Centralia Nobs (Pre-Paid Taxes)-3.98%469,254
33 Retail Access -8.62%to 8.71%6,446
34 Security Deposits 127,134
35 Sunnyside Cogen Sec.Dep.-10.20%20,638
36 Utah Life Line Rate Payable -7.23%50,662
37 Weatherization/DSR Loan 642
38 Western Capital Lease -14.81%119,694
39 Willamette Lease -10.38%219,549
40
41 Total Account 431 25,144,331
FERC FORM NO.1 (ED.12-87)Page 340.1
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
REGULATORY COMMISSION EXPENSES
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 Totai .Deferred
No.(Furnish name of regulatory commission or body the Regulatory o Expense for in Account
docket or case number and a description of the case)Commission Utility Curbrent ear Beginn ng3o Year
(a)(b)(c)(d)(e)
1 Before the Public Service Commission of Utah:
2 Annual Fee 2,556,599 2,556,599
3 Other rate case expenses (12 months)577,194 577,194
4
5 Before the Idaho Public Utilities Commission:
6 Annual Fee 353,547 353,547
7 Other rate case expenses (12 months)
8
9 Before the Public Service Commission
10 of Wyoming:
11 Annual Fee 632,787 632,787
12 Other rate case expenses (12 months)427,238 427,238
13
14 Before the Public Utilities Commission
15 of California:
16 Annual Fee 96,144 96,144
17 Other rate case expenses (12 months)
18
19 Before the Public Utility Commission
20 of Oregon:
21 Annual Fee 2,519,811 2,519,811
22 Other rate case expenses (12 months)22,313 22,313
23
24 Before the Washington Utilities and
25 Transportation Commission:
26 Annual Fee 340,413 340,413
27 Other rate case expenses (12 months)2,717 2,717
28
29 Before the Federal Energy Regulatory
30 Commission:
31 Annual Fee 911,139 911,139
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46 TOTAL 7,410,440 1,029,462 8,439,902
FERC FORM NO.1 (ED.12-96)Page 350
Name of Respondent This Re ort Is:Date of Report Year of Report
(1)An Original (Mo,Da,Yr)PacifiCorp Dec.31,2001(2)A Resubmission //
REGULATORYCOMMISSION EXPENSEb (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.
EXPEN3ES INCURRI D DURING YEAR 4MORTIZED DURING Y ¯AR
CURRI NTLY CHARCED TO Deferred to Contra Amount Deferred in LineDepartmentAcountAmountAccount182.3 Account A c unt 8a2.3 No.
(f)(g)(h)(i)(j)(k)(I)
1
Electric 928 2,556,599 2
Electric 928 577,194 3
4
5
Electric 928 353,547 6
Electric 928 7
8
9
10
Electric 928 632,787 11
Electric 928 427,238 12
13
14
15
Electric 928 96,144 16
Electric 928 17
18
19
20
Electric 928 2,519,811 21
Electric 928 22,313 22
23
24
25
Electric 928 340,413 26
Electric 928 2,717 27
28
29
30
Electric 928 911,139 31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
M 8,439,902 46
FERC FORM NO.1 (E D.12-96)Page 351
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
RESEARCH,DEVELOPMENT,AND DEMONS FRATIONACTIVITIES
1.Describe and show below costs incurred and accounts charged during the year for technological research,development,and demonstration (R,D &
D)project initiated,continued or concluded during the year.Report also support given to others during the year for jointly-sponsored projects.(Identify
recipient regardless of affiliation.)For any R,D &D work carried with others,show separately the respondent's cost for the year and cost chargeable to
others (See definition of research,development,and demonstration in Uniform System of Accounts).
2.Indicate in column (a)the applicable classification,as shown below:
Classifications:
A.Electric R,D &D Performed Internally:(3)Transmission
(1)Generation a.Overhead
a.hydroelectric b.Underground
i.Recreation fish and wildlife (4)Distribution
ii Other hydroelectric (5)Environment (other than equipment)
b.Fossil-fuel steam (6)Other (Classify and include items in excess of $5,000.)
c.Internal combustion or gas turbine (7)Total Cost Incurred
d.Nuclear B.Electric,R,D &D Performed Externally:
e.Unconventional generation (1)Research Support to the electrical Research Council or the Electric
f.3iting and heat rejection PONer Research Institute
Line Classification Description
No-(a)(b)
1
2 A.Electric R,D &D performed internally
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 externally 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)Page 352
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001
(2)A Resubmission //
RESEARCH,DEVELOPMENT,AND DEMONSTRATIONACTIVITIES (Continued)
(2)Research Support to Edison Electric Institute
(3)Research Support to Nuclear Power Groups
(4)Research Support to Others (Classify)
(5)Total Cost Incurred
3.Include in column (c)all R,D &D items performed internally and in column (d)those items performed outside the company costing $5,000 or more,
briefly describing the specific area of R,D &D (such as safety,corrosion control,pollution,automation,measurement,insulation,type of appliance,etc.).
Group items under $5,000 by classifications and indicate the number of items grouped.Under Other,(A (6)and B (4))classify items by type of R,D &D
activity.
4.Show in column (e)the account number charged with expenses during the year or the account to which amounts were capitalized during the year,
listing Account 107,Construction Work in Progress,first.Show in column (f)the amounts related to the account charged in column (e)
5.Show in column (g)the total unamortized accumulating of costs of projects.This total must equal the balance in Account 188,Research,
Development,and Demonstration Expenditures,Outstanding at the end of the year.
6.If costs have not been segregated for R,D &D activities or projects,submit estimates for columns (c),(d),and (f)with such amounts identified by
"Est."
7.Report separately research and related testing facilities operated by the respondent.
Costs Incurred Internally Costs Incurred Externally AMOUNTS CHARGED IN CURRENT YEAR Unamortized LineCurrentYearCurrentYearAccountAmountAccumulationNo.(c)(d)(e)(f)(9)
1
2
3
963 506 963 4
577,354 506 577,354 5
6
578,317 578,317 7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
FERC FORM NO.1 (ED.12-87)Page 353
Name of Respondent This Re ort Is Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
DISTRIBUTION OF SALARIES AND NAGES
Report below the distribution of total salaries and wages for the year.Segregate amounts originally charged to clearing accounts to
Utility Departments,Construction,Plant Removals,and Other Accounts,and enter such amounts in the appropriate lines and columns
provided.In determining this segregation of salaries and wages originally charged to clearing accounts,a method of approximation
giving substantially correct results may be used.
Line Classification Direct Payroll Allocation of
Distribution Payroll charged for TotalNo.CleanngAccounts(a)(b)(c)(d)
1 Electric23rodra nn
4 Transmission 7,044,146
6 u
tn
Accounts
7 Customer Service and Informational 2,330,618
nistrative and General 72,9
10 TOTAL Operation (Enter Total of lines 3 thru 9)216,299,416
11 Maintenance
12 Production 23,048,952
13 Transmission 4,107,232
14 Distribution 47,951,544
15 Administrative and General 9 9R>ML
16 TOTAL Maint.(Total of lines 12 thru 15)77,390,561
17 Total Operation and Maintenance
18 Production (Enter Total of lines 3 and 12)104,505,063
19 Transmission (Enter Total of lines 4 and 13)11,151,378
20 Distribution (Enter Total of lines 5 and 14)64,550,872
21 Customer Accounts (Transcribe from line 6)36,680,668
22 Customer Service and Informational (Transcribe from line 7)2,330,618
23 Sales (Transcribe from line 8)-15,423
24 Administrative and General (Enter Total of lines 9 and 15)74,486,801
25 TOTAL Oper.and Maint.(Total of lines 18 thru 24)293,689,977 293,689 977
26 Gas
27 Operation
28 Production-Manufactured Gas
29 Production-Nat.Gas (Including Expl.and Dev.)
30 Other Gas Supply
31 Storage,LNG Terminaling and Processing
32 Transmission
33 Distribution
34 Customer Accounts
35 Customer Service and Informational
36 Sales
37 Administrative and General
38 TOTAL Operation (Enter Total of lines 28 thru 37)
39 Maintenance
40 Production-Manufactured Gas
41 Production-Natural Gas
42 Other Gas Supply
43 Storage,LNG Terminaling and Processing
44 Transmission
45 Distribution
46 Administrative and General
47 TOTAL Maint.(Enter Total of lines 40 thru 46)
FERC FORM NO.1 (ED.12-88)Page 354
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
DISTRIBUTION OF SALARIES AND WAGES (Continued)
Line Classification Direct Payroll Allocation of ToDistributionPayrollchargedfortal
NO.Clearing 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 Customer Accounts (Line 34)
56 Customer Senrice and Informational (Line 35)
.57 Sales (Line 36)
58 Administrative and General (Lines 37 and 46)
59 TOTAL Operation and Maint.(Total of lines 49 thru 58)
60 Other Utility Departments
61 Operation and Maintenance
62 TOTAL All Utility Dept.(Total of lines 25,59,and 61)293,689,977 293 689 977
63 Utility Plant
64 Construction (By Utility Departments)
65 Electric Plant 90,489,304 90,489,304
66 Gas Plant
67 Other
68 TOTAL Construction (Total of lines 65 thru 67)90,489,304 90,489,304
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 29,509,881 29,509,881
76 Misc.Income Deductions 459,219 459,219
77 Misc.Nonoperating/Nonutility Inc.666,689 666,689
78
79
80
81
82
83
84
85
86
87
88
89
90
91
92
93
94
95 TOTAL Other Accounts 30,635,789 30,635,789
96 TOTAL SALARIES AND WAGES 414,815,070 414,815,070
FERC FORM NO.1 (ED.12-88)Page 355
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001
(2)A Resubmission //
ELECTRIC ENERGY ACCOUF T
Report below the information called for concerning the disposition of electric energy generated,purchased,exchanged and wheeled during the year.
Line item MegaWatt Hours Line Item MegaWatt Hours
No.No.(a)(b)(a)(b)
1 SOURCES OF ENERGY 21 DISPOSITION OF ENERGY
2 Generation (Excluding Station Use):22 Sales to Ultimate Consumers (Including 47,708,462
3 Steam 45,435,688 Interdepartmental Sales)
4 Nuclear -342 23 Requirements Sales for Resale (See 202,258
5 Hydro-Conventional 3,058,751 instruction 4,page 311.)
6 Hydro-Pumped Storage 24 Non-Requirements Sales for Resale (See 22,648,640
7 Other 2,264,813 instruction 4,page 311.)
8 Less Energy for Pumping 25 Energy Furnished Without Charge
9 Net Generation (Enter Total of lines 3 50,758,910 26 Energy Used by the Company (Electric 94,919
through 8)Dept Only,Excluding Station Use)
10 Purchases 24,202,778 27 Total Energy Losses 4,655,892
11 Power Exchanges:28 TOTAL (Enter Total of Lines 22 Through 75,310,171
12 Received 7,960,551 27)(MUST EQUAL LINE 20)
13 Delivered 7,443,777
14 Net Exchanges (Line 12 minus line 13)516,774
15 Transmission For Other (Wheeling)
16 Received 17,535,183
17 Delivered 17,535,183
18 Net Transmission for Other (Line 16 minus
line 17)
19 Transmission By Others Losses -168,291
20 TOTAL (Enter Total of lines 9,10,14,18 75,310,171
and 19)
FERC FORM NO.1 (ED.12-90)Page 401a
Nameof Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)X An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
MONTHLY PEAKS AND OUTPUT
1.If the respondent has two or more power systems which are not physically integrated,furnish the required information for each non-integrated system.
2.Report in column (b)the system's energy output for each month such that the total on Line 41 matches the total on Line 20.
3.Report in column (c)a monthly breakdown of the Non-Requirements Sales For Resale reported on Line 24.include in the monthly amounts 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 maximum megawatt 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 6,575,461 1,789,682 7,693 17 0800 PST
30 February 5,946,153 1,667,641 7,595 13 0800 PST
31 March 5,988,182 1,679,663 7,126 1 0800 PST
32 April 5,952,474 1,845,326 6,959 9 0800 PST
33 May 6,020,250 1,674,371 7,310 24 1700 PDT
34 June 5,867,067 1,577,824 7,595 21 1700 PDT
35 July 6,643,528 2,032,195 7,854 3 1500 PDT
36 August 6,786,657 2,095,653 7,899 7 1400 PDT
37 September 6,324,692 2,139,597 7,301 4 1600 PDT
38 October 6,145,143 1,996,803 6,689 1 1600 PST
39 November 6,328,369 2,157,455 7,418 29 1800 PST
40 December 6,732,195 1,994,126 7,688 10 1800 PST
41 TOTAL 75,310,171 22,650,336
FERC FORM NO.1 (ED.12-90)Page 401b
Name of Respondent This Report Is:Date of Report Year of Report(1)An Original (Mo,Da,Yr)PacifiCorp (2)A Resubmission //Dec.31,2001
STEAM-ELECTRIC GENERATING PLANT STATISTICS (Large Plants)
1.Report data for plant in Service only.2.Large plants are steam plants with installed capacity (name plate rating)of 25,000 Kw or more.Report in
this page gas-turbine and 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 burned (Line 40)must be consistent with charges to expense accounts 501 and 547 (Line 41)as show on Line 19.8.If more than one
fuel is burned in a plant fumish only the composite heat rate for all fuels burned.
Line Item Plant Plant
No.Name:Carbon Name:Cholla
(a)(b)(c)
1 Kind of Plant (Internal Comb,Gas Turb,Nuclear Steam Steam
2 Type of Constr (Conventional,Outdoor,Boiler,etc)Outdoor Boiler Full Outdoor
3 Year Originally Constructed 1954 1981
4 Year Last Unit was Installed 1957 1981
5 Total Installed Cap (Max Gen Name Plate Ratings-MW)188.60 414.00
6 Net Peak Demand on Plant -MW (60 minutes)181 383
7 Plant Hours Connected to Load 8742 8160
8 Net Continuous Plant Capability (Megawatts)0 0
9 When Not Limited by Condenser Water 175 380
10 When Limited by Condenser Water 0 0
11 Average Number of Employees 79 81
12 Net Generation,Exclusive of Plant Use -KWh 1372715000 2779088000
13 Cost of Plant:Land and Land Rights 956546 1178241
14 Structures and Improvements 10526349 44913884
15 Equipment Costs 65600601 311213232
16 Total Cost 77083496 357305357
17 Cost per KW of Installed Capacity (line 5)408.7142 863.0564
18 Production Expenses:Oper,Supv,&Engr 259931 1228256
19 Fuel 9289475 37287290
20 Coolants and Water (Nuclear Plants Only)0 0
21 Steam Expenses 18645 2293168
22 Steam From Other Sources O 0
23 Steam Transferred (Cr)0 0
24 Electric Expenses O 981822
25 Misc Steam (or Nuclear)Power Expenses 4350207 783339
26 Rents 15150 56676
27 Allowances O O
28 Maintenance Supervision and Engineering 0 1968269
29 Maintenance of Structures 155043 405616
30 Maintenance of Boiler (or reactor)Plant 1731574 3815122
31 Maintenance of Electric Plant 516174 440834
32 Maintenance of Misc Steam (or Nuclear)Plant 1204483 1527718
33 Total Production Expenses 17540682 50788110
34 Expenses per Net KWh 0.0128 0.0183
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 623905 1822 0 1518787 2888 0
38 Avg Heat Cont -Fuel Burned (btu/indicate if nuclear)12226 140000 0 10069 140131 0
39 Avg Cost of Fuellunit,as Delvd f.o.b.during year 14.373 41.597 0.000 23.259 45.586 0.000
40 Average Cost of Fuel per Unit Burned 14.768 41.597 0.000 24.464 45.586 0.000
41 Average Cost of Fuel Burned per Million BTU 0.604 7.074 0.000 1.215 7.746 0.000
42 Average Cost of Fuel Burned per KWh Net Gen 0.007 0.000 0.000 0.013 0.000 0.000
43 Average BTU per KWh Net Generation 11121.523 0.000 0.000 11011.647 0.000 0.000
ERC =ORM NO.1 (ED.12-95)Fage 402
Name of Respondent This Report Is:Date of Report Year of Report(1)An Original (Mo,Da,Yr)PacifiCorp (2)A Resubmission //Dec.31,2001
STEAM-ELECTRIC GENERATING PLANT STATISTICS (Large Plants)(Continued)
9.Items under Cost of Plant are based on U.S.of A.Accounts.Production expenses do not include Purchased Power,System Control and 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,intemal 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
Name:Colstrip Name:Craig Name:Dave Johnston No.
(d)(e)(f)
Steam Steam Steam 1
Conventional Outdoor Boiler Semi-Outdoor 2
1984 1979 1959 3
1986 1980 1972 4
155.61 172.13 816.70 5
151 165 778 6
8754 8758 8760 7
0 0 0 8
144 165 762 9
0 0 0 10
208 283 208 11
1078277000 1248157000 5633726000 12
1293387 137086 10417291 13
55644346 35117954 47008149 14
147702272 115345187 324474185 15
204640005 150600227 381899625 16
1315.0826 874.9214 467.6131 17
33220 237762 984092 18
7043599 10477544 39570522 19
0 0 0 20
123160 1190131 201378 21
0 0 0 22
0 0 0 23
-65631 364607 0 24
1914980 1664369 11366394 25
69707 8157 326 26
0 0 0 27
228279 324489 0 28
164013 241406 717475 29
1772816 2449378 8824776 30
328950 1027572 2194480 31
197714 358806 3291956 32
11810807 18344221 67151399 33
0.0110 0.0147 0.0119 34
Coal Oil Coal Oil Coal Oil 35
Tons Barrel Tons Barrel Tons Barrel 36
674511 2991 0 634409 1218 0 3811627 8944 0 37
8490 1410000 0 10038 122360 0 8247 140000 0 38
9.938 45.119 0.000 15.612 45.464 0.000 9.655 45.371 0.000 39
10.242 45.119 0.000 16.428 45.464 0.000 10.275 45.371 0.000 40
0.603 7.619 0.000 0.818 8.846 0.000 0.623 7.716 0.000 41
0.007 0.000 0.000 0.008 0.000 0.000 0.007 0.000 0.000 42
10638.183 0.000 0.000 10208.668 0.000 0.000 11168.551 0.000 0.000 43
FERC FORM NO.1 (ED.12-88)Page 403
Name of Respondent This Report Is:Date of Report Year of Report(1)An Original (Mo,Da,Yr)PacifiCorp (2)A Resubmission //Dec.31,2001
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 burned (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 bumed.
Line Item Plant Plant
No.Name:Hayden Name:Hunter Unit No.1
(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 1965 1978
4 Year Last Unitwas Installed 1976 1978
5 Total Installed Cap (Max Gen Name Plate Ratings-MW)81.25 472.50
6 Net Peak Demand on Plant -MW (60 minutes)78 407
7 Plant Hours Connected to Load 8657 5430
8 Net Continuous Plant Capability(Megawatts)0 0
9 When Not Limitedby Condenser Water 78 430
10 When Limited by CondenserWater 0 0
11 Average Numberof Employees 105 77
12 Net Generation,Exclusive of Plant Use -KWh 624381000 1801376000
13 Cost of Plant:Land and Land Rights 129492 9848778
14 Structures and Improvements 5044708 59991962
15 Equipment Costs 59289350 208945987
16 Total Cost 64463550 278786727
17 Cost per KW of Installed Capacity (line 5)793.3975 590.0248
18 Production Expenses:Oper,Supv,&Engr 195036 -18085
19 Fuel 7340676 17707583
20 Coolants and Water (Nuclear Plants Only)O O
21 Steam Expenses 486756 789248
22 Steam From Other Sources O O
23 Steam Transferred (Cr)0 0
24 Electric Expenses 116767 134952
25 Misc Steam (or Nuclear)Power Expenses 760805 4510852
26 Rents 0 276
27 Allowances O O
28 Maintenance Supervision and Engineering 153245 0
29 Maintenance of Structures 111869 557423
30 Maintenance of Boiler (or reactor)Plant 519867 4531094
31 Maintenance of Electric Plant 135181 112219
32 Maintenance of Misc Steam (or Nuclear)Plant 176282 61060
33 Total Production Expenses 9996484 28386622
34 Expenses per Net KWh 0.0160 0.0158
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 309772 1906 0 794683 6082 0
38 Avg Heat Cont -Fuel Burned (btulindicate if nuclear)10210 132599 O 12006 140000 0
39 Avg Cost of Fuellunit,as Delvd f.o.b.during year 22.051 49.908 0.000 20.707 43.393 0.000
40 Average Cost of Fuel per Unit Burned 23.390 49.908 0.000 21.958 43.393 0.000
41 Average Cost of Fuel Burned per Million BTU 1.145 8.962 0.000 0.915 7.212 0.000
42 Average Cost of Fuel Burned per KWh Net Gen 0.012 0.000 0.000 0.010 0.000 0.000
43 Average BTU per KWh Net Generation 10147.910 0.000 0.000 10612.821 0.000 0.000
0 ERC =ORM NO.1 (ED.12-95)Fage 402.1
Name of Respondent This Report Is:Date of Report Year of Report
(1)An Original (Mo,Da,Yr)PacifiCorp (2)A Resubmission //Dec.31,2001
STEAM-ELECTRIC GENERATING PLANT STATISTICS (Large Plants)(Continued)
9.Items under Cost of Plant are based on U.S.of A.Accounts.Production expenses do not include Purchased Power,System Control and 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,intemal 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:Hunter Unit No.2 Name:Hunter Unit No.3 Name:Hunter No.
(d)(e)(f)
Steam Steam Steam 1
Outdoor Boiler Outdoor Boiler Outdoor Boiler 2
1980 1983 1978 3
1980 1983 1983 4
472.50 495.50 1440.50 5
267 462 1307 6
7831 7629 8699 7
0 0 0 8
430 460 1320 9
0 0 0 10
76 77 230 11
1905194000 3233055000 6939625000 12
9848778 9848778 29546333 13
49197168 88271615 197460746 14
138383936 378066384 725396306 15
197429882 476186777 952403385 16
417.8410 961.0228 661.1617 17
-18085 -18085 -54256 18
18121662 30497486 66326730 19
0 0 0 20
394708 1000041 2183997 21
0 0 0 22
0 0 0 23
98707 98707 332366 24
2070572 4639208 11220632 25
176 2738 3189 26
0 0 0 27
0 0 0 28
497721 550517 1605662 29
3764109 9407727 17702929 30
1196241 1456000 2764460 31
116973 134024 312056 32
26242784 47768363 102397765 33
0.0138 0.0148 0.0148 34
Coal Oil Coal Oil Coal Oil 35
Tons Barrel Tons Barrel Tons Barrel 36
836722 4406 0 1442935 7629 0 3074339 18117 0 37
11910 140000 0 11835 140000 0 11903 140000 0 38
20.707 43.393 0.000 20.707 43.393 0.000 20.707 43.393 0.000 39
21.436 43.393 0.000 20.899 43.393 0.000 21.319 43.393 0.000 40
0.900 7.181 0.000 0.883 7.629 0.000 0.895 7.380 0.000 41
0.010 0.000 0.000 0.009 0.000 0.000 0.010 0.000 0.000 42
10474.846 0.000 0.000 10577.960 0.000 0.000 10561.391 0.000 0.000 43
I ERC FORM NO.1 (ED.12-88)Page 403.1
Name of Respondent This Report Is:Date of Report Year of Report(1)An Original (Mo,Da,Yr)PacifiCorp (2)A Resubmission //Dec.31,2001
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 fumish only the composite heat rate for all fuels burned.
Line Item Plant Plant
No.Name:Huntington Name:Jirn Bridger
(a)(b)(c)
1 Kind of Plant (Internal Comb,Gas Turb,Nuclear Steam Steam
2 Type of Constr (Conventional,Outdoor,Boiler,etc)Outdoor Boiler Semi-Outdoor
3 Year Originally Constructed 1974 1974
4 Year Last Unit was Installed 1977 1979
5 Total Installed Cap (Max Gen Name Plate Ratings-MW)996.00 2311.20
6 Net Peak Demand on Plant -MW (60 minutes)898 1430
7 Plant Hours Connected to Load 8523 8757
8 Net Continuous Plant Capability (Megawatts)O O
9 When Not Limited by Condenser Water 895 2120
10 When Limited by Condenser Water 0 0
11 Average Number of Employees 164 358
12 Net Generation,Exclusive of Plant Use -KWh 6241909000 10468261000
13 Cost of Plant:Land and Land Rights 2405337 1146361
14 Structures and Improvements 94218124 132302948
15 Equipment Costs 322667378 667812545
16 Total Cost 419290839 801261854
17 Cost per KW of Installed Capacity (line 5)420.9747 346.6865
18 Production Expenses:Oper,Supv,&Engr 105967 845388
19 Fuel 45854963 117207103
20 Coolants and Water (Nuclear Plants Only)0 0
21 Steam Expenses 364619 -1696594
22 Steam From Other Sources O O
23 Steam Transferred (Cr)0 0
24 Electric Expenses 0 166139
25 Misc Steam (or Nuclear)Power Expenses 9299028 9253007
26 Rents 77980 174264
27 Allowances O O
28 Maintenance Supervision and Engineering 0 0
29 Maintenance of Structures 653259 5453726
30 Maintenance of Boiler (or reactor)Plant 10237738 13759240
31 Maintenance of Electric Plant 5570761 3110095
32 Maintenance of Misc Steam (or Nuclear)Plant 2724202 4528019
33 Total Production Expenses 74888517 152800387
34 Expenses per Net KWh 0.0120 0.0146
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 2668054 23213 0 5909654 26049 0
38 Avg Heat Cont -Fuel Burned (btulindicate if nuclear)12094 140000 0 9267 140000 0
39 Avg Cost of Fuellunit,as Delvd f.o.b.during year 16.803 42.183 0.000 19.325 44.273 0.000
40 Average Cost of Fuel per Unit Burned 16.820 42.183 0.000 19.638 44.273 0.000
41 Average Cost of Fuel Burned per Million BTU 0.695 7.174 0.000 1.060 7.529 0.000
42 Average Cost of Fuel Burned per KWh Net Gen 0.007 0.000 0.000 0.011 0.000 0.000
43 Average BTU per KWh Net Generation 10360.718 0.000 0.000 10477.289 0.000 0.000
I ERC ·ORM NO.1 (ED.12-95)Fage 402.2
Name of Respondent This R4eort Is:Date of Report Year of Report
PacifiCorp -R ul ission
(Mo,Da,Yr)
Dec.31,2001
STEAM-ELECTRIC GENERATING PLANT STATISTICS (Large Plants)(Continued)
9.Items under Cost of Plant are based on U.S.of A.Accounts.Production expenses do not include Purchased Power,System Control and 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,intemal 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:Naughton Name:Wyodak Name:Gadsby No.
(d)(e)(f)
Steam Steam Steam 1
Outdoor Boiler Conventional Outdoor 2
1963 1978 1951 3
1971 1978 1955 4
707.20 362.00 251.60 5
724 283 224 6
8760 8362 8239 7
0 0 0 8
700 335 235 9
0 0 0 10
163 71 35 11
5349697000 2251817000 987459000 12
458248 210526 1020271 13
55997239 48034185 13415332 14
253228898 248089104 53803281 15
309684385 296333815 68238884 16
437.9021 818.6017 271.2197 17
284671 253867 21326984 18
57855783 19364310 68988431 19
0 0 0 20
2623956 35975 864 21
0 0 0 22
0 0 0 23
0 0 0 24
9522781 3019118 3146605 25
-1644 0 3447 26
0 0 0 27
0 12017 0 28
637326 298405 51650 29
5146383 3566145 834730 30
968418 380358 1244867 31
2430947 1744037 528219 32
79468621 28674232 96125797 33
0.0149 0.0127 0.0973 34
Coal Oil Gas Coal Oil Gas 35
Tons Barrel MCF Tons Barrel MCF 36
2853666 8326 489694 1690683 4382 0 11514747 0 0 37
9897 140000 1050 8072 140000 0 1053 0 0 38
19.363 44.491 0.000 11.221 41.546 0.000 0.000 0.000 0.000 39
19.602 44.491 3.160 11.346 41.546 0.000 5.991 0.000 0.000 40
1.018 7.567 3.011 0.703 7.066 0.000 5.690 0.000 0.000 41
0.011 0.000 0.000 0.009 0.000 0.000 0.070 0.000 0.000 42
10663.932 0.000 0.000 12132.495 0.000 0.000 12277.854 0.000 0.000 43
I ERC FORM NO.1 (ED.12-88)Page 403.2
Name of Respondent This Report Is:Date of Report Year of Report(1)An Original (Mo,Da,Yr)PacifiCorp (2)A Resubmission //Dec.31,2001
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 burned.
Line Item Plant Plant
No.Name:Little Mountain Name:Hermiston
(a)(b)(c)
1 Kind of Plant (Internal Comb,Gas Turb,Nuclear Gas Turbine Steam
2 Type of Constr (Conventional,Outdoor,Boiler,etc)Outdoor Boiler Gas Turbine
3 Year Originally Constructed 1972 1996
4 Year Last Unit was Installed 1972 1996
5 Total Installed Cap (Max Gen Name Plate Ratings-MW)16.00 237.00
6 Net Peak Demand on Plant -MW (60 minutes)16 254
7 Plant Hours Connected to Load 2419 8684
8 Net Continuous Plant Capability (Megawatts)0 0
9 When Not Limited by Condenser Water 14 236
10 When Limited by Condenser Water 0 0
11 Average Number of Employees 6 26
12 Net Generation,Exclusive of Plant Use -KWh 31983000 1939984000
13 Cost of Plant:Land and Land Rights 635 842245
14 Structures and Improvements 204044 11019961
15 EquipmentCosts 3993905 144144955
16 Total Cost 4198584 156007161
17 Cost per KW of Installed Capacity (line 5)262.4115 658.2581
18 Production Expenses:Oper,Supv,&Engr 0 0
19 Fuel 1886021 43446179
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 407760 5362179
25 Misc Steam (or Nuclear)Power Expenses O 6
26 Rents O O
27 Allowances O 0
28 Maintenance Supervision and Engineering 0 0
29 Maintenance of Structures O 0
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 2293781 48808364
34 Expenses per Net KWh 0.0717 0.0252
35 Fuel:Kind (Coal,Gas,Oil,or Nuclear)Gas Gas
36 Unit (Coal-tons/Oil-barrel/Gas-mcf/Nuclear-indicate)MCF MCF
37 Quantity (units)of Fuel Burned 568820 0 0 13744391 0 0
38 Avg Heat Cont -Fuel Burned (btulindicate if nuclear)1053 0 0 1023 0 0
39 Avg Cost of Fuellunit,as Delvd f.o.b.during year 0.000 0.000 0.000 0.000 0.000 0.000
40 Average Cost of Fuel per Unit Burned 3.316 0.000 0.000 3.161 0.000 0.000
41 Average Cost of Fuel Burned per Million BTU 3.149 0.000 0.000 3.090 0.000 0.000
42 Average Cost of Fuel Burned per KWh Net Gen 0.059 0.000 0.000 0.022 0.000 0.000
43 Average BTU per KWh Net Generation 18725.904 0.000 0.000 7247.746 0.000 0.000
ERC =ORM NO.1 (ED.12-95)Fage 402.3
Name of Respondent This Report Is:Date of Report Year of Report(1)An Original (Mo,Da,Yr)PacifiCorp (2)A Resubmission //Dec.31,2001
STEAM-ELECTRIC GENERATING PLANT STATISTICS (Large Plants)(Continued)
9.Items under Cost of Plant are based on U.S.of A.Accounts.Production expenses do not include Purchased Power,System Control and 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,intemal 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;an<'(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:Blundell Name:James River Name:No.
(d)(e)(f)
Steam -Geothermal Steam 1
Indoor Outdoor Boiler 2
1984 1996 3
1984 1996 4
26.00 52.21 0.00 5
25 95 0 6
7966 8637 0 7
0 0 0 8
23 52 0 9
0 0 0 10
13 21 0 11
152742000 339817000 0 12
31026429 0 0 13
6147415 5733734 0 14
33234489 28682437 0 15
70408333 34416171 0 16
2708.0128 659.1873 0.0000 17
34417 0 0 18
0 0 0 19
O O O 20
-3330 0 0 21
3698736 4385373 0 22
0 0 0 23
0 0 0 24
1015406 3640 0 25
11700 0 0 26
0 0 0 27
0 0 0 28
102559 O 0 29
284028 0 0 30
731568 0 0 31
256908 0 0 32
6131992 4389013 0 33
0.0401 0.0129 0.0000 34
35
36
0 0 0 0 0 0 0 0 0 37
0 0 0 0 0 0 0 0 0 38
0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 39
0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 40
0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 41
0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 42
0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 43
ERC FORM NO.1 (ED.12-88)Page 403.3
Name of Respondent This Report Is:Date of Report Year of Report(1)An Original (Mo,Da,Yr)PacifiCorp (2)A Resubmission //Dec.31,2001
HYDROELECTRIC GENERATING PLANT STATISTICS (Large Plants)
1.Large plants are hydro plants of 10,000 Kw or more of installed capacity (name plate ratings)
2.If any plant is leased,operated under a license from the Federal Energy Regulatory Commission,or operated as a joint facility,indicate such facts in
a footnote.If licensed project,give project number.
3.If net peak demand for 60 minutes is not available,give that which is available specifying period.
4.If a group of employees attends more than one generating plan,report on line 11 the approximate average number of employees assignable to each
plant.
Line Item FERC Licensed Project No.2082 FERC Licensed Project No.2082
No.Plant Name:Copco No.1 Plant Name:Copco No.2
(a)(b)(c)
1 Kind of Plant (Run-of-River or Storage)Storage Run-of-Rivet
2 Plant Construction type (Conventional or Outdoor)Conventional Conventional
3 Year Originally Constructed 1918 1925
4 Year Last Unit was Installed 1922 1925
5 Total installed cap (Gen name plate Rating in MW)20.00 27.00
6 Net Peak Demand on Plant-Megawatts (60 minutes)24 30
7 Plant Hours Connect to Load 5,294 5,340
8 Net Plant Capability (in megawatts)HM WARE
9 (a)Under Most Favorable Oper Conditions 25 29
10 (b)Under the Most Adverse Oper Conditions 25 29
11 Average Number of Employees 2 7
12 Net Generation,Exclusive of Plant Use -Kwh 85,241,000 109,113,000
13 Cost of Plant
14 Land and Land Rights 180,375 20,914
15 Structures and Improvements 1,166,705 1,563,284
16 Reservoirs,Dams,and Waterways 2,440,641 2,774,200
17 Equipment Costs 4,757,314 4,364,274
18 Roads,Railroads,and Bridges 105,442 240,200
19 TOTAL cost (Total of 14 thru 18)8,650,477 8,962,872
20 Cost per KW of Installed Capacity (line 5)432.5239 331.9582
21 Production Expenses
22 Operation Supervision and Engineering 137,131 185,127
23 Water for Power 0 0
24 Hydraulic Expenses 162 218
25 Electric Expenses O O
26 Misc Hydraulic Power Generation Expenses 312,100 343,298
27 Rents 1,630 3,840
28 Maintenance Supervision and Engineering 1,412 1,906
29 Maintenance of Structures 5,542 6,424
30 Maintenance of Reservoirs,Dams,and Waterways 157,033 50,324
31 Maintenance of Electric Plant 56,909 89,460
32 Maintenance of Misc Hydraulic Plant 76,146 102,607
33 Total Production Expenses (total 22 thru 32)748,065 783,204
34 Expenses per net KWh 0.0088 0.0072
ERC ¯ORM NO.1 (ED.12-88)>age 406
Name of Respondent This Report Is:Date of Report Year of Report(1)An Original (Mo,Da,Yr)PacifiCorp (2)A Resubmission //Dec.31,2001
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.1927 FERC Licensed Project No.1927 FERC Licensed Project No.2420 Line
Plant Name:Clearwater No.1 Plant Name:Clearwater No.2 Plant Name:Cutler No.
(d)(e)(f)
Run-of-River Run-of-River Storage 1
Outdoor Outdoor Conventional 2
1953 1953 1927 3
1953 1953 1927 4
15.00 26.00 30.00 5
15 20 17 6
7,576 8,295 2,792 7
0 0 0 8
15 26 29 9
15 26 29 10
0 0 4 11
44,387,000 39,815 35,902,000 12
0 0 13
0 0 3,512,464 14
559,122 755,831 1,807,217 15
3,344,156 8,930,840 7,032,421 16
923,214 1,152,265 1,701,970 17
0 219,901 573,738 18
4,826,492 11,058,837 14,627,810 19
321.7661 425.3399 487.5937 20
0 0 0 21
133,614 231,598 439,011 22
0 0 0 23
999 1,732 243 24
0 0 0 25
116,383 151,973 321,420 26
-95 -165 904 27
2.860 4,958 9,898 28
3,410 8,645 4,129 29
10,720 24,090 41,422 30
55,143 33,341 160,442 31
25,379 46,418 47,898 32
348,413 502,590 1,025,367 33
0.0078 12.6231 0.0286 34
FERC FORM NO.1 (ED.12-88)Page 407
Name of Respondent This Re ort Is:Date of Report Year of Report
PacifiCorp (R u
malssion (Mo/,Da,Yr)
Dec.31,2001
HYDROELECTRIC GENERATING PLANT STATISTICS (Large Plants)
1.Large plants are hydro plants of 10,000 Kw or more of installed capacity (name plate ratings)
2.If any plant is leased,operated under a license from the Federal Energy Regulatory Commission,or operated as a joint facility,indicate such facts in
a footnote.If licensed project,give project number.
3.If net peak demand for 60 minutes is not available,give that which is available specifying period.
4.If a group of employees attends more than one generating plan,report on line 11 the approximate average number of employees assignable to each
plant.
Line Item FERC Licensed Project No.1927 FERC Licensed Project No.2401No-Plant Name:Fish Creek Plant Name:Grace
(a)(b)(c)
1 Kind of Plant (Run-of-River or Storage)Run-of River Storage
2 Plant Construction type (Conventional or Outdoor)Outdoor Conventional
3 Year Originally Constructed 1952 1908
4 Year Last Unit was Installed 1952 1923
5 Total installed cap (Gen name plate Rating in MW)11.00 33.00
6 Net Peak Demand on Plant-Megawatts (60 minutes)13 33
7 Plant Hours Connect to Load 4,422 8,470
8 Net Plant Capability (in megawatts)WO
9 (a)Under Most Favorable Oper Conditions 12 33
10 (b)Under the Most Adverse Oper Conditions 12 33
11 Average Number of Employees 0 18
12 Net Generation,Exclusive of Plant Use -Kwh 33,910,000 90,476,000
13 Cost of Plant
14 Land and Land Rights 0 50,393
15 Structures and Improvements 557,744 1,139,582
16 Reservoirs,Dams,and Waterways 5,759,697 7,523,470
17 Equipment Costs 664,512 3,180,032
18 Roads,Railroads,and Bridges 409,412 43,134
19 TOTAL cost (Total of 14 thru 18)7,391,365 11,936,611
20 Cost per KW of Installed Capacity (line 5)671.9423 361.7155
21 Production Expenses
22 Operation Supervision and Engineering 97,984 473,619
23 Water for Power 0 0
24 Hydraulic Expenses 733 267
25 Electric Expenses O 0
26 Misc Hydraulic Power Generation Expenses 87,412 481,287
27 Rents 755 22,181
28 Maintenance Supervision and Engineering 2,098 5,706
29 Maintenance of Structures 1,646 31,605
30 Maintenanœ of Reservoirs,Dams,and Waterways 635 169,434
31 Maintenanæ of Electric Plant 7,529 6,353
32 Maintenance of Misc Hydraulic Plant 19,091 71,256
33 Total Production Expenses (total 22 thru 32)217,883 1,261,708
34 Expenses per net KWh 0.0064 0.0139
FERC i ORM NO.1 (ED.12-88)l*age 406.1
Name of Respondent This Report Is:Date of Report Year of Report(1)An Original (Mo,Da,Yr)PacifiCorp (2)A Resubmission //Dec.31,2001
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.2082 FERC Licensed Project No.2082 FERC Licensed Project No.1927 Line
Plant Name:Iron Gate Plant Name:JC Boyle Plant Name:Lemolo No.1 No.(d)(e)(f)
Storage Storage Run-of River 1
Outdoor Outdoor Outdoor 2
1962 1958 1955 3
1962 1958 1955 4
18.00 79.80 29.00 5
20 88 28 6
8,678 6,476 8,475 7
O 8
20 90 29 9
20 84 28 10
1 6 0 11
112,396,000 234,066,000 103,529,000 12
0 0 0 13
341,706 54,984 0 14
3,696,196 2,170,421 709,257 15
8,363,789 10,419,715 7,518,900 16
1,362,897 6,822,474 3,420,189 17
638,679 604,730 407,171 18
14,403,267 20,072,324 12,055,517 19
800.1815 251.5329 415.7075 20
21
123,418 407,967 258,321 22
0 0 0 23
146 647 1,932 24
0 0 0 25
181,901 491,604 209,530 26
1,467 5,511 -184 27
1,271 9,975 5,530 28
4,904 29,816 4,288 29
9,492 16,327 42,384 30
53,107 119,313 60,818 31
69,296 95,621 51,799 32
445,002 1,176,781 634,418 33
0.0040 0.0050 0.0061 34
"ERC FORM NO.1 (ED.12-88)Page 407.1
Name of Respondent This Re ort Is:Date of Report Year of Report
PacifiCorp R su
malssion (Mo,Da,Yr)Dec.31,2001
HYDROELECTRICGENERATING PLANT STATISTICS (Large Plants)
1.Large plants are hydro plants of 10,000 Kw or more of installed capacity (name plate ratings)
2.If any plant is leased,operated under a license from the Federal Energy Regulatory Commission,or operated as a joint facility,indicate such facts in
a footnote.If licensed project,give project number.
3.If net peak demand for 60 minutes is not available,give that which is available specifying period.
4.If a group of employees attends more than one generating plan,report on line 11 the approximate average number of employees assignable to each
plant.
Line Item FERC Liœnsed Project No.1927 FERC Licensed Project No.935
No.Plant Name:Lemolo No.2 Plant Name:Merwin
(a)(b)(c)
1 Kind of Plant (Run-of-River or Storage)Run-of River Storage
2 Plant Construction type (Conventional or Outdoor)Outdoor Conventional
3 Year Originally Constructed 1956 1931
4 Year Last Unit was Installed 1956 1958
5 Total installed cap (Gen name plate Rating in MW)33.00 135.00
6 Net Peak Demand on Plant-Megawatts (60 minutes)36 148
7 Plant Hours Connect to Load 8,598 8,758
8 Net Plant Capability (in megawatts)
9 (a)Under Most Favorable Oper Conditions 35 144
10 (b)Under the Most Adverse Oper Conditions 34 141
11 Average Number of Employees O 33
12 Net Generation,Exclusive of Plant Use -Kwh 128,629,000 353,415,000
13 Cost of Plant
14 Land and.Land Rights O 985,071
15 Structures and Improvements 688,448 20,746,522
16 Reservoirs,Dams,and Waterways 14,520,644 9,222,186
17 Equipment Costs 1,946,869 10,491,734
18 Roads,Railroads,and Bridges 993,032 384,270
19 TOTAL cost (Total of 14 thru 18)18,148,993 41,829,783
20 Cost per KW of Installed Capacity (line 5)549.9695 309.8502
21 Production Expenses
22 Operation Supervision and Engineering 293,952 691,506
23 Water for Power 0 0
24 Hydraulic Expenses 2,198 174,615
25 Electric Expenses O O
26 Misc Hydraulic Power Generation Expenses 186,604 1,158,150
27 Rents -60 19,055
28 Maintenance Supervision and Engineering 6,293 545
29 Maintenance of Structures 4,879 111,432
30 Maintenance of Reservoirs,Dams,and Waterways 11,422 22,967
31 Maintenance of Electric Plant 19,231 43,336
32 Maintenance of Misc Hydraulic Plant 63,278 175,240
33 Total Production Expenses (total 22 thru 32)587,797 2,396,846
34 Expenses per net KWh 0.0046 0.0068
F ERC ORM NO.1 (ED.12-88)age 406.2
Name of Respondent This Report is:Date of Report Year of Report(1)An Original (Mo,Da,Yr)PacifiCom (2)A Resubmission //Dec.31,2001
HYDROELECTRICGENERATING 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.1927 FERC Licensed Project No.472 FERC Licensed Project No.2630 Line
Plant Name:Toketee Plant Name:Oneida Plant Name:Prospect No.2 No.
(d)(e)(f)
Conventional Storage Run-of River 1
Outdoor Conventional Conventional 2
1950 1915 1928 3
1950 1920 1928 4
42.30 30.00 -32.00 5
44 36 38 6
8,758 8,730 8,729 7
0 0 0 8
45 28 34 9
45 28 34 10
0 2 2 11
173,461,000 37,277,000 189,985,000 12
0 0 13
0 36,698 105,168 14
1,429,228 1,188,094 2,021,045 15
6,271,942 4,537,738 4,827,191 16
2,581,358 2,998,897 2,595,768 17
111,245 381,105 191,385 18
10,393,773 9,142,532 9,740,557 19
245.7157 304.7511 304.3924 20
0 0 0 21
378,583 430,563 158,392 22
0 0 0 23
2,831 243 259 24
0 0 0 25
220,522 267,914 201,871 26
-120 19,875 2,328 27
8,105 5,187 6,837 28
6,741 0 57,792 29
6,022 276 198,083 30
161,051 36,852 199,865 31
71,966 66,916 55,330 32
855,701 827,826 880,757 33
0.0049 0.0222 0.0046 34
FERC FORMNO.1 (ED.12-88)Page 407.2
Name of Respondent This Report Is:Date of Report Year of Report
(1)An Original (Mo,Da,Yr)PacifiCorp (2)A Resubmission //Dec.31,2001
HYDROELECTRIC GENERATING PLANT STATISTICS (Large Plants)
1.Large plants are hydro plants of 10,000 Kw or more of installed capacity (name plate ratings)
2.If any plant is leased,operated under a license from the Federal Energy Regulatory Commission,or operated as a joint facility,indicate such facts in
a footnote.If licensed project,give project number.
3.If net peak demand for 60 minutes is not available,give that which is available specifying period.
4.If a group of employees attends more than one generating plan,report on line 11 the approximate average number of employees assignable to each
plant.
Line Item FERC Licensed Project No.1927 FERC Licensed Project No.20
No.Plant Name:Slide Creek Plant Name:Soda
(a)(b)(c)
1 Kind of Plant (Run-of-River or Storage)Run-of-River Storage
2 Plant Construction type (Conventional or Outdoor)Outdoor Conventional
3 Year Originally Constructed 1951 1924
4 Year Last Unit was Installed 1951 1924
5 Total installed cap (Gen name plate Rating in MW)18.00 14.00
6 Net Peak Demand on Plant-Megawatts (60 minutes)20 8
7 Plant Hours Connect to Load 8,012 4,689
8 Net Plant Capability (in megawatts)Ni#0
9 (a)Under Most Favorable Oper Conditions 18 14
10 (b)Under the Most Adverse Oper Conditions 18 14
11 Average Number of Employees O O
12 Net Generation,Exclusive of Plant Use -Kwh 63,277,000 16,151,000
13 Cost of Plant
14 Land and Land Rights 0 504,056
15 Structures and Improvements 607,138 572,786
16 Reservoirs,Dams,and Waterways 3,753,383 4,996,525
17 Equipment Costs 1,163,415 2,072,224
18 Roads,Railroads,and Bridges 16,778 0
19 TOTAL cost (Total of 14 thru 18)5,540,714 8,145,591
20 Cost per KW of Installed Capacity (line 5)307.8174 581.8279
21 Production Expenses
22 Operation Supervision and Engineering 160,337 200,929
23 Water for Power 0 0
24 Hydraulic Expenses 1,199 113
25 Electric Expenses O 0
26 Misc Hydraulic Power Generation Expenses 113,643 179,115
27 Rents -114 9,275
28 Maintenance Supervision and Engineering 3,433 2,421
29 Maintenance of Structures 21,722 0
30 Maintenance of Reservoirs,Dams,and Waterways 2,264 3,996
31 Maintenance of Electric Plant 107,463 2,943
32 Maintenance of Misc Hydraulic Plant 35,889 25,635
33 Total Production Expenses (total 22 thru 32)445,836 424,427
34 Expenses per net KWh 0.0070 0.0263
i ERC ¯ORM NO.1 (ED.12-88)>age 406.3
Name of Respondent This Repon Is:Date of Report Year of Report(1)An Original (Mo,Da,Yr)PacifiCorp (2)A Resubmission //Dec.31,2001
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.1927 FERC Liœnsed Project No.2111 FERC Licensed Project No.2071 Line
Plant Name:Soda Springs Plant Name:Swift No.1 Plant Name:Yale No.(d)(e)(f)
Run-of-River Storage Storage 1
Outdoor Conventional Conventional 2
1952 1958 1953 3
1952 1958 1953 4
11.00 240.00 134.00 5
13 230 166 6
8,650 4,378 4,191 7
0 0 û 8
12 264 134 9
11 263 134 10
2 0 0 11
48,189,000 429,974,000 395,931,000 12
0 13
0 7,813,808 1,434,708 14
811,726 5,539,138 5,911,118 15
3,467,419 37,261,887 26,061,908 16
1,048,515 12,338,165 13,751,078 17
25,845 395,145 1,107,253 18
5,353,505 63,348,143 48,266,065 19
486.6823 263.9506 360.1945 20
.0 0 0 21
97,984 1,217,030 679,509 22
0 0 0 23
733 308,143 172,047 24
0 0 0 25
97,060 237,510 49,157 26
-70 33,348 18,673 27
2,098 962 537 28
2,571 166,093 99,305 29
26,509 23,532 3,855 30
6,969 131,879 16,753 31
20,505 269,145 147,544 32
254,359 2,387,642 1,187,380 33
0.0053 0.0056 0.0030 34
FERC FORM NO.1 (ED.12-88)Page 407.3
Name of Respondent This Report Is:Date of Report Year of Report(1)An Original (Mo,Da,Yr)PacifiCorp (2)A Resubmission //Dec.31,2001
HYDROELECTRIC GENERATING PLANT STATISTICS (Large Plants)
1.Large plants are hydro plants of 10,000 Kw or more of installed capacity (name plate ratings)
2.If any plant is leased,operated under a license from the Federal Energy Regulatory Commission,or operated as a joint facility,indicate such facts in
a footnote.If licensed project,give project number.
3.If net peak demand for 60 minutes is not available,give that which is available specifying period.
4.If a group of employees attends more than one generating plan,report on line 11 the approximate average number of employees assignable to each
plant.
Line Item FERC Licensed Project No.O FERC Licensed Project No.O
No.Plant Name:Plant Name:
(a)(b)(c)
1 Kind of Plant (Run-of-River or Storage)
2 Plant Construction type (Conventional or Outdoor)
3 Year Originally Constructed
4 Year Last Unit was Installed
5 Total installed cap (Gen name plate Rating in MW)0.00 -0.00
6 Net Peak Demand on Plant-Megawatts (60 minutes)O O
7 Plant Hours Connect to Load 0 0
8 Net Plant Capability (in megawatts)
9 (a)Under Most Favorable Oper Conditions O O
10 (b)Under the Most Adverse Oper Conditions O O
11 Average Number of Employees O O
12 Net Generation,Exclusive of Plant Use -Kwh 0 0
13 Cost of Plant
14 Land and Land Rights O O
15 Structures and Improvements O O
16 Reservoirs,Dams,and Waterways O O
17 Equipment Costs O O
18 Roads,Railroads,and Bridges O O
19 TOTAL cost (Total of 14 thru 18)0 0
20 Cost per KW of Installed Capacity (line 5)0.0000 0.0000
21 Production Expenses
22 Operation Supervision and Engineering 0 0
23 Water for Power 0 0
24 Hydraulic Expenses O 0
25 Electric Expenses 0 0
26 Misc Hydraulic Power Generation Expenses O O
27 Rents O O
28 Maintenance Supervision and Engineering 0 0
29 Maintenance of Structures O 0
30 Maintenance of Reservoirs,Dams,and Waterways O O
31 Maintenance of Electric Plant 0 0
32 Maintenance of Misc Hydraulic Plant 0 0
33 Total Production Expenses (total 22 thru 32)0 0
34 Expenses per net KWh 0.0000 0.0000
F ERC ORM NO.1 (ED.12-88)>age 406.4
Name of Respondent This Report Is:Date of Report Year of Report(1)An Original (Mo,Da,Yr)PacifiCorp (2)A Resubmission //Dec.31,2001
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 FERC Licensed Project No.O FERC Licensed Project No.O Line
Plant Name: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 8
0 0 0 9
0 0 0 10
0 0 0 11
0 0 0 12
0 0 0 13
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 21
0 0 0 22
0 0 0 23
0 0 0 24
0 0 0 25
0 0 0 26
0 0 0 27
0 0 0 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
FERC FORM NO.1 (ED.12-88)Page 407.4
Name of Respondent This Re ort Is:Date of Report Year of Report
PacifiCorp (1)X An Original (Mo,Da,Yr)Dec.31,2001
(2)A Resubmission //
GENERATING PLANT STATISTICS (Small Plants)
1.Snall generating plants are steam plants of,less than 25,000 Kw;internal combustion and gas turbine-plants,conventionaf hydro plants and pumped
storage plants of less than 10,000 Kw installed capacity (name plate rating).2.Designate any plant leased from others,operated under a license from
the 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.
L.Year Installed Ca acity Net Peak Net GenerationineNameofPlantOrig.Name Plate atint Demand Excluding Cost of Plant
No.Const-(In My MW Plant Use
(a)(b)(c)(60 in.)(e)(f)
1 Hydro Plants:Licensed Proj.No.
2 American Fork 696 1907 0.90 0.9 5,479 936,920
3 Ashton 2381 1917 6.80 6.9 33,841 8,761,386
4 Beaver -Upper 814 1907 2.50 2.1 8,354 2,507,548
5 Bend 2643 1913 1.00 1.0 3,675 825,371
6 Skookumchuck 1990 1.00 8,657,150
7 Big Fork 2652 1910 4.10 5.0 17,729 4,032,282
8 Cline Falls 1913 1.00 1.7 2,291 266,366
9 Condit 2342 1913 9.60 16.0 53,682 6,777,752
10 Cove 2401 1917 7.50 7.5 18,594 2,788,148
11 Drop Plant 1914 1.40 1.4 5,291 381,176
12 EaglePoint 1957 2.80 4.0 15,904 1,695,896
13 East Side 2082 1924 3.20 4.0 11,612 1,822,733
14 Fall Creak 2082 1903 2.10 2.0 10,296 967,760
15 Frountain Green 1922 0.10 0.2 761 440,817
16 Granite 1896 2.00 1.2 5,354 4,466,780
17 Gunlock 1917 0.70 0.5 1,630 481,400
18 Last Chance 4580 1983 1.60 1.6 3,884 4,242,017
19 Naches 1909 6.30 6.0 21,046 9,774,067
20 Paris 703 1910 0.70 0.7 1,125 309,081
21 Pioneer 2722 1897 5.00 5.1 9,713 9,569,960
22 Powerdale 2659 1923 6.00 6.0 11,123 13,587,469
23 Prospect #1 2630 1912 3.70 5.0 22,714 539,021
24 Prospect #3 2337 1932 7.20 7.0 24,276 6,799,394
25 Prospect #4 2630 1944 1.00 1.0 4,093 184,246
26 Sand Cove 1926 0.80 0.5 1,328 842,890
27 Snake Creek 1910 1.00 0.7 2,302 886,912
28 Stairs 597 1895 1.00 1.3 4,081 1,156,616
29 St.Anthony 2381 1915 0.50 0.6 2,791 1,320,281
30 Veyo 1920 0.50 0.3 1,241 719,316
31 Viva Naughton 1986 0.60 -86 1,154,968
32 Wallowa Falls 308 1921 1.10 1.3 4,640 2,742,113
33 Weber 1744 1911 3.80 3.7 10,203 2,448,164
34 West Side 2082 1908 0.60 1.0 2,854 321,524
35 Keno Regulating Dam 7,468,183
36 Uper Klamath Lake 3,703,971
37 North Umpqua 8,641,470
38
39 Pumping Plant
40 Lifton 1917 -5,415 10,486,610
41
42
43
44
45
46
FERC FORM NO.1 (ED.12-87)Page 410
Name of Respondent This Re ort Is:Date of Report Year of Report
PacifiCorp (1)X An Original (Mo,Da,Yr)Dec.31,2001
(2)A Resubmission //
GENERATING PLANT STATISTICS (Small Plants)(Continued)
3.List plants appropriately under subheadings for steam,hydro,nuclear,internal combustion and gas turbine plants.For nuclear,see instruction 11,
Page 403.4.If net peak demand for 60 minutes is not available,give the which is available,specifying period.5.If any plant is equipped with
combinations of steam,hydro internal combustion or gas turbine equipment,report each as a separate plant.However,if the exhaust heat from the gas
turbine is utilized in a steam turbine regenerative feed water cycle,or for preheated combustion air in a boiler,report as one plant.
Plant Cost Per MW Operation Production Expenses Fuel Costs (in cents
Inst Capacity Exc'I.Fuel Fuel Maintenance Kind of Fuel (per Million Btu)
(g)(h)(i)(j)(k)(!)
1
1,041,022 59,729 5,009 2
1,288,439 303,496 33,241 3
1,003,019 157,241 39,149 4
825,371 46,386 3,731 5
6
983,483 193,928 91,594 7
266,366 16,176 9,749 8
706,016 286,549 90,186 9
371,753 257,002 68,787 10
272,269 11
605,677 65,621 135,556 12
569,604 118,716 484,308 13
460,838 103,312 30,115 14
4,408,167 14,966 987 15
2,233,390 152,853 3,725 16
687,714 45,718 10,700 17
2,651,260 152,852 123,900 18
1,551,439 169,394 92,669 19
441,545 31,528 36,545 20
1,913,992 226,375 40,014 21
2,264,578 276,714 -54,802 22
145,681 57,276 60,060 23
944,360 113,257 162,034 24
184,246 24,600 30,832 25
1,053,613 48,965 3,520 26
886,912 61,476 2,917 27
1,156,616 119,688 6,371 28
2,640,562 73,577 11,171 29
1,438,632 58,488 5,187 30
1,924,946 31
2,492,830 11,060 83,722 32
644,254 226,672 70,706 33
535,874 56,528 9,150 34
10,342 31,435 35
20,874 22,890 36
37
38
39
202,550 47,812 40
41
42
43
44
45
46
FERC FORM NO.1 (ED.12-87)Page 411
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
TRANSMISSION LINE STATIST CS
1.Report information concerning transmission lines,cost of lines,and expenses for year.List each transmission line having nominal voltage of 132
kilovolts or greater.Report transmission lines below these voltages in group totals only for each voltage.
2.Transmission lines include all lines covered by the definition of transmission system plant as given in the 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.Repod
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 e×penses repoded for the line designated.
Line DEŠlÓNATIÓN VOLTAÓE (KV)LENGTH 'Pole miles)(Indicate where Type of (In the base of NumberNo.other than undergrc und imes
60 cycle,3 ph ise)Supporting report cir:uit miles)Of
Un Structure Un Structures CircuitsFromToOperatingDesignedStructureof.Line of AnotherDesignatedLme(a)(b)(c)(d}(e)(f)(g)(h)
1 Malin,Oregon Indian Springs.,CA 500.0C 500.00 Steel Tower 47.00 1
2 Midpoint,Idaho Malin,Oregon 500.0C 500.00 Steel Tower 446.00 1
3 Malin,Oregon Medford,Oregon 500.0C 500.00 Steel Tower 83.00 1
4 Alvey Sub,Oregon Dixonville Sub,Oregon 500.00 500.00 Steel Tower 58.00 1
5 Malin,Oregon Captain Jack,OR 500.00 500.00 Steel Tower 7.00 1
6 Dixonville,Oregon Meridian,OR 500.00 500.00 Steel Tower 74.00 1
7 Ben Lomond Sub.,Utah Borah Substation,Idaho 345.0C 345.00 Steel-H 134.00 1
8 Ben Lomond Sub.,Utah Terminal Substation,UT 345.0C 345.00 Steel-D 47.00 2
9 Spanish Fork Sub.,Utah Camp Williams Sub.,Utah 345.0C 345.00 Steel-SP 35.00 2
10 Huntington Plant,Utah Sigurd Substation,Utah 345.0C 345.00 Steel-H 86.00 1
11 Huntington PIt.Sub.,UT Spanish Fork Sub.,Utah 345.0C 345.00 Steel-H 78.00 1
12 Terminal Substation,UT Ninety South Sub.,Utah 345.OC 345.00 Steel-SP 15.00 2
13 Emery Substation,Utah Sigurd Substation,Utah 345.0C 345.00 Steel-H 68.00 1
14 Sigurd Substation,Utah Camp Williams Sub.,Utah 345.0C 345.00 Steel-H-P 116.00 1
15 Camp Williams Sub.,Utah Ninety South Sub.,Utah 345.00 345.00 Steel -SP 8.00 2
16 Terminal Substation,UT Camp Williams Sub.,Utah 345.00 345.00 Steel-D 25.00 1
17 Emery Substation,Utah Camp Williams Sub.,Utah 345.00 345.00 Steel-H 86.00 1
18 Newcastle,Utah Utah -Nevada Border 345.00 345.00 Steel-D 54.00 1
19 Sigurd Substation,Utah Newcastle,Utah 345.0C 345.00 Steel-D 137.00 1
20 Goshen Substation,Idaho Kinport Substation,ID 345.0C 345.00 Steel-H 41.00 1
21 Pinto Substation,Utah Four Corners Sub.,NM 345.0C 345.00 Wood -U 55.00 1
22 Camp Williams Sub.,Utah Huntington Plant,Utah 345.0C 345.00 Wood -U 152.00 1
23 Huntington Plant,Utah Pinto Substation,Utah 345.OC 345.00 Wood-U 156.00 1
24 Camp Williams Sub.,Utah Sigurd Substation,Utah 345.0C 345.00 Wood -U 111.00 1
25 Jim Bridger Plant #3,WY Borah Substation,Idaho 345.00 345.00 Steel Tower 240.00 1
26 Jim Bridger Plant #2,WY Kinport Substation,1D 345.0C 345.00 Steel Tower 234.00 1
27 Fairview,Oregon Isthmus,Oregon 230.0C 230.00 H Frame Wood 12.00 1
28 Antelope Sub.,Idaho Lost River 230kV Line,ID 230.0C 230.00 Wood -H 20.00 1
29 Walla Walla,Washington Hells Canyon,ID 230.0C 230.00 H Frame Wood 72.00 1
30 Bethel,Oregon Fry,Oregon 230.0C 230.00 H Frame Wood 26.00 1
31 Fry,Oregon Dixonville,Oregon 230.0C 230.00 H Frame Wood 44.00 1
32 Alvey,Oregon Dixonville,Oregon 230.0C 230.00 H Frame Wood 59.00 1
33 Troutdale,Oregon Linneman,Oregon 230.0C 230.00 SteelTower 6.00 1
34 Troutdale,Oregon Gresham,Oregon 230.0C 230.00 Steel Tower 6.00 1
35 McNary,Washington Walla Walla,Washington 230.0C 230.00 H Frame Wood 56.00 1
36 TOTAL 14,876.00 100.00 191
FERC FORM NO.1 (ED.12-87)Page 422
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)pAn Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
TRANSMISSION LINE STATISTICS (Continued)
7.Do not report the same transmission line structure twice.Report Lower voltage Lines and higher voltage lines as one line.Designate in a footnote if
you do not include Lower voltage lines with higher voltage lines.If two or more transmission line structures support lines of the same voltage,report the
pole miles of the primary structure in column (f)and the pole miles of the other line(s)in column (g)
8.Designate any transmission line or portion thereof for which the respondent is not the sole owner.If such property is leased from another company,
give name of lessor,date and terms of Lease,and amount of rent for year.For any transmission line other than a leased line,or portion thereof,for
which the respondent is not the sole owner but which the respondent operates or shares in the operation of,furnish a succinct statement explaining the
arrangement and giving particulars (details)of such matters as perœnt 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 (1)on the book cost at end of year.
ÓÔ$T ÓF LINE (Include in Óolumn (j)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)(I)(m)(n)(0)(p)No.
2-1852 134,35E 4,416,172 4,550,528 1
1272.0 3,109,688 150,607,169 153,716,857 2
1272.0 2,907,175 38,193,891 41,101,066 3
1272.0 1,425,18[19,293,946 20,719,126 4
1272.0 9,22E 1,455,664 1,464,893 5
1272.0 4,912,244 26,247,803 31,160,047 6
954.0 5,298,306 35,010,252 40,308,560 7
1272.0 10,057,36E 21,789,991 31,847,357 8
1272.0 6,069,82E 10,158,595 16,228,424 9
954.0 318,831 20,042,861 20,361,692 10
954.0 791,811 17,665,937 18,457,748 11
1272.0 2,615,56C 7,457,557 10,073,117 12
954.0 281,834 13.580,607 13,862,441 13
954.0 510,490 19,733,876 20,244,366 14
1272.0 495,842 3,895,713 4,391,556 15
1272.0 4,357,23E 7,964,678 12,321,916 16
954.0 926,251 27,916,136 28,842,387 17
954.0 2,320,872 50,597,495 52,918,368 18
954.0 56,05C 13,548,519 13,604,569 19
795.0 313,477 2,565,555 2,879,032 20
954.0 117,662 2,618,232 2,735,894 21
795.0 887,90C 18,252,347 19,140.247 22
795.0 23
795.0 84,95E 9,808,227 9,893,186 24
1272.0 1,128,222 26,192,950 27,321,172 25
1272.0 1,099,796 27,995,064 29,094,860 26
954.0 285,322 1,509,733 1,795,055 27
795.0 12,92E 1,195,831 1,208,760 28
1272.0 69,394 7,815,590 7,884,984 29
1272.0 351,982 1,136,646 1,488,628 30
1272.0 485,89E 3,215,605 3,701,501 31
954.0 1,428,247 13,293,103 14,721,350 32
954.0 413,491 413,491 33
954 .0 368,84E 574,074 942,920 34
1272.0 200,967 2,697,624 2,898,591 35
79,506,609 1,318.178,273 1,397.684,882 36
FERC FORM NO.1 (ED.12-87)Page 423
Name of Respondent This Report is:Date of Report Year of Repoit
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
TRANSMISSION LINE STATISTICS
1.Report information concerning transmission lines,cost of lines,and expenses for year.List each transtnission 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 DEŠlGNATIÓN VOLTAGE (KV)LENGTH 'Pole miles)(Indicate where Type of (la the base of NumberNo.other than undergrc una lines
60 cycle,3 ph ise)Supporting report cir:uit miles)Of
Un Structure Un Structures CircuitsFromToOperatingDesignedStructureofLineofAnotherDesignatedLine(a)(b)(c)(d)(e)(f)(g)(h)
1 BPA Heppner,Oregon Dalred Substation,Orego 230.0C 230.00 H Frame Wood 1
2 Sigurd Substation,Utah Garfield,Utah 230.0C 230.00 Wood -U 118.00 1
3 Dixonville,Oregon Reston,Oregon 230.0C 230.00 H Frame Wood 17.00 1
4 Yamsey,Oregon Klamath Falls,Oregon 230.0C 230.00 H Frame Wood 56.00 1
5 Yamsey,Oregon Klamath Falls,Oregon 230.0C 230.00 Steel Tower 6.00 1
6 Dixonville,Oregon Lone Pine,Oregon 230.0C 230.00 H Frame Wood 5.00 1
7 Klamath Falls,Oregon Medford,Oregon 230.0C 230.00 H Frame Wood 76.00 1
8 Klamath Falls,Oregon Malin,Oregon 230.0C 230.00 H Frame Wood 35.00 1
9 Table Rock,SW Station,OR Grants Pass,Oregon 230.0C 230.00 H Frame Wood 35.00 1
10 Grants Pass,Oregon Days Creek,Oregon 230.0C 230.00 H Frame Wood 71.00 1
11 Dixonville,Oregon Dixonville,Oregon 230.0C 230.00 Wood 1.00
12 Sigurd Substation,Utah Pavant Substation,Utah 230.0C 230.00 Wood -U 43.00 1
13 Pavant Substation,Utah Nevada -Utah State line 230.0C 230.00 Wood -U 98.00 1
14 Bannack Pass,Idaho Antelope Sub.,Idaho 230.0C 230.00 Wood -U 76.00 1
15 Brady Substation,Idaho Treasureton Sub.,Idaho 230.0C 230.00 Wood -U 66.00 1
16 Ben Lomond Sub.,Utah Naughton Pit.#1,WY 230.0(230.00 Wood -U 88.00 1
17 Sigurd Substation,Utah Arizona -Utah State line 230.00 230.00 Wood -U 149.00 1
18 Birch Creek Sub.,WY Railroad Substation,WY 230.0C 230.00 Wood -HSW 12.00 1
19 Birch Creek Sub.,WY Railroad Substation,WY 230.0C 230.00 Wood -HSW 7.00 1
20 Ben Lomond Sub.,Utah Naughton Pit.#2,WY 230.0C 230.00 Wood -U 50.00 1
21 Ben Lomond Sub.,Utah Naughton Plt.#2,WY 230.0C 230.00 Wood -U 29.00 1
22 Chappel Creek,WY Naughton Plant,WY 230.0C 230.00 Wood Tower 46.00 1
23 Ben Lomond Sub.,Utah Terminal Substation,UT 230.0C 230.00 Steel -D-P 46.00 1
24 Naughton Plant,Wyoming Treasureton Sub.,Idaho 230.0C 230.00 Wood -U 78.00 1
25 Naughton Plant,Wyoming Treasureton Sub.,Idaho 230.0C 230.00 Wood -U 1.00 1
26 Swift Plant #1,WA Cowlitz Co.Line,WA 230.0C 230.00 H Frame Wood 2.00 1
27 Swift Plant #2,WA BPA Woodland,WA 230.00 230.00 H Frame Wood 23.00 1
28 Union Gap,Washington BPA Midway,WA 230.00 230.00 H Frame Wood 39.00 1
29 Walla Walla,Washington Lewiston,ID 230.0C 230.00 H Frame Wood 45.00 1
30 Walla Walla,Washington Wanapum,Washington 230.00 230.00 H Frame Wood 33.00 1
31 Pomona,Washington Wanapum,Washington 230.0C 230.00 H Frame Wood 37.00 1
32 Centralia,Washington BPA Tap,Washington 230.0C 230.00 H Frame Wood 3.00 1
33 Pomona,Washington Wanapum,Washington 230.0C 230.00 H Frame Wood 8.00 1
34 Billings,Montana Yellowtail,Montana 230.0C 230.00 H Frame Wood 39.00 1
35 Yellowtail,Montana Muddy Ridge,Wyoming 230.0E 230.00 H Frame Wood 176.00 1
36 TOTAL 14,876.00 100.00 191
FERC FORM NO.1 (ED.12-87)Page 422.1
Name of Respondent This Report Is.Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001
(2)A Resubmission //
TRANSMISSION LINE STATISTICS (Continued)
7.Do not report the same transmission line structure twice.Report Lower voltage Lines and higher voltage lines as one line.Designate in a footnote if
you do not include Lower voltage lines with higher voltage lines.If two or more transmission line structures support lines of the same voltage,report the
pole miles of the primary structure in column (f)and the pole miles of the other line(s)in column (g)
8.Designate any transmission line or portion thereof for which the respondent is not the sole owner.If such property is leased from another company,
give name of lessor,date and terms of Lease,and amount of rent for year.For any transmission line other than a leased line,or portion thereof,for
which the respondent is not the sole owner but which the respondent operates or shares in the operation of,furnish a succinct statement explaining 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.
ÓÓŠT ÓF LINE (Include in Óolumn (j)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)(!)(m)(n)(o)(p)No.
195.0 108,274 108,274 1
195.0 390,87E 7,597,210 7,988,088 2
39,971 942,039 982,010 3
195.0 4
795.0 247,092 3,490,135 3,737,228 5
795.0 397,687 2,880,498 3,278,185 6
795.0 173,608 5,671.169 5,844,777 7
1272.0 115,442 1,544,163 1,659,611 8
954.0 191,124 3,807,998 3,999,122 9
1272.0 379,961 10.711,424 11,091,385 10
1272.0 385,577 385,577 11
795.0 41,49E 4,295.321 4,336,820 12
795.0 13
1272.0 5,102 2,402,452 2,407,555 14
795.0 72,118 1,853,261 1,925,379 15
795.0 420,40E 3,436,856 3,857,265 16
954.0 22,642 4,391,967 4.414,610 17
954.0 165,054 1,277.573 1,442,627 18
954.0 181,047 1,487,637 1,668,684 19
1272.0 736,03C 4,318,606 5,054,636 20
1272.0 5,717 1,290,738 1,296,455 21
954.0 170,967 5.900.151 6,071,118 22
1272.0 572,458 9,753,573 10,326,032 23
954.0 56,49E 2,814,460 2,870,958 24
954.0 565 27,749 28,318 25
954.0 1,292 174,634 175,927 26
954.0 103,532 1,828,196 1,931,728 27
1272.0 172,451 1,525,982 1,698,433 28
1272.0 366.29C 4,881,457 5,247,747 29
954.0 235,532 1,353,911 1,589,443 30
1780.0 207,123 2,640,020 2,847,143 31
954.0 21,50C 105,180 126,680 32
556.5 16E 1,334,252 1,334,421 33
1272.0 32,99E 1,457,833 1,490,831 34
1272.0 120,94E 5,053,830 5,174,779 35
79,506,609 1,318,178,273 1,397,684,882 36
FERC FORM NO.1 (ED.12-87)Page 423.1
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001
(2)A Resubmission //
TRANSMISSION LINE STATISTICS
1.Report information conœrning 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 DÊŠlÓNATIÓN VÓLTAÓE (KV)LE (Pole iles)(Indicate where Type of base NumberNo.other than u rgrouna l nes
60 cycle,3 ph ise)Supporting report circuit miles)Of
Un Structure Un Structures CircuitsFromToOperatingDesignedStructureofLineofAriotherDesianatedLine(a)(b)(c)(d)(e)(f)(g)(h)
1 Sheridan,Wyoming Decker,Montana 230.00 230.00 H Frame Wood 14.00 1
2 Dave Johnston Plant,WY Casper,Wyoming 230.0C 230.00 H Frame Wood 31.00 1
3 Yellowtail,Montana Casper,Wyoming 230.0C 230.00 H Frame Wood 169.00 1
4 Rock Springs,Wyoming Kemmerer,Wyoming 230.0C 230.00 H Frame Wood 71.00 1
5 Rock Springs,Wyoming Atlantic City,Wyoming 230.0C 230.00 H Frame Wood 69.00 1
6 Thermopolis,Wyoming Riverton,Wyoming 230.0C 230.00 H Frame Wood 51.00 1
7 Casper,Wyoming Riverton,Wyoming 230.0C 230.00 H Frame Wood 110.00 1
8 Dave Johnston Plant,WY Rock Springs,Wyoming 230.0C 230.00 H Frame Wood 233.00 1
9 Dave Johnston Plant,WY Spence,Wyoming 230.0C 230.00 H Frame Wood 31.00 1
10 Riverton,Wyoming Atlantic City,Wyoming 230.0C 230.00 H Frame Wood 50.00 1
11 Rock Springs,Wyoming Flaming Gorge,Utah 230.0C 230.00 H Frame Wood 48.00 1
12 Palisades,Wyoming Green River,Wyoming 230.00 230.00 H Frame Wood 9.00 1
13 Buffalo,Wyoming Gillette,Wyoming 230.0C 230.00 H Frame Wood 68.00 1
14 Jim Bridger Plant,WY Point of Rocks,Wyoming 230.0E 230.00 H Frame Wood 4.00 1
15 Jim Bridger Plant,WY Point of Rocks,Wyoming 230.00 230.00 H Frame Wood 5.00
16 Dave Johnston Plant,WY Yellowcake,Wyoming 230.0E 230.00 H Frame Wood 69.00 1
17 Wyodak,WY Sub.Tie Line,WY 230.00 230.00 H Frame Wood 1
18 Jim Bridger Plant,WY Point of Rocks Ln 2,WY 230.00 230.00 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 230.00 230.00 H Frame Wood 13.00 1
21 Firehole,Wyoming Mansface,Wyoming 230.00 230.00 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 Spence Sub.,WY Jim Bridger Plant,WY 230.00 H Frame Wood
25 Jim Bridger Plant,WY Mustang Sub.,Wyoming 230.0C 230.00 H Frame Wood 73.00 1
26 Spence Sub.,Wyoming Mustang Sub.,Wyoming 230.0C 230.00 H Frame Wood 77.00 1
27 Rock Springs,Wyoming Flaming Gorge,Utah 230.0C 230.00 Šteel Tower 7.00 1
28 Line 59,CA Copco II,CA 230.0C 230.00 H Frame Wood 5.00 1
29 Arizona/Utah State Line Glen Canyon Sub.,Arizon 230.0C 230.00 H Frame Wood 10.00 1
30 Montana-ldaho State line Grace Plant,Idaho 161.0C 161.00 Wood -H 57.00 90.00 1
31 Goshen Substation,Idaho Rigby Substation,Idaho 161.0C 161.00 Wood-H 29.00 1
32 Goshen Substation,Idaho Antelope Substation,ID 161.0C 161.00 Wood -H 45.00 1
33 Goshen Substation,Idaho Sugar Mill Substation,ID 161.0C 161.00 Wood -SP 16.00 1
34 Sugar Mill Sub.,Idaho Rigby Substation,Idaho 161.0C 161.00 Wood -SP 17.00 1
35 Goshen Substation,Idaho Bonneville Sub.,Idaho 161.0C 161.00 Wood -SP-H 23.00 1
36 TOTAL 14,876.00 100.00 191
FERC FORM NO.1 (ED.12-87)Page 422.2
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
TRANSMISSION LINE STATISTICS (Continued)
7.Do not report the same transmission line structure twice.Report Lower voltage Lines and higher voltage lines as one line.Designate in a footnote if
you do not include Lower voltage lines with higher voltage lines.If two or more transmission line structures support lines of the same voltage,report the
pole miles of the primary structure in column (f)and the pole miles of the other line(s)in column (g)
8.Designate any transmission line or portion thereof for which the respondent is not the sole owner.If such property is leased from another company,
give name of lessor,date and terms of Lease,and amount of rent for year.For any transmission line other than a leased line,or portion thereof,for
which the respondent is not the sole owner but which the respondent operates or shares in the operation of,furnish a succinct statement explaining 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 (1)on the book cost at end of year.
ÓÓŠT ÓF LINE (include in Óolumn (j)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)(°)(p)No.
1272.0 26,092 569,722 595,815 1
795.0 14,92E 846,933 861,861 2
1271.0 130,197 5,595,406 5,725,603 3
1271.0 52,906 2,131,926 2,184,832 4
954.0 31,85E 1,644,995 1,676,854 5
1272.0 57,112 1,657,693 1,714,805 6
954.0 67,857 3,324,451 3,392,308 7
1272.0 58,102 8,372,050 8,430,152 8
1272 17,91C 2,673,996 2.691,906 9
1271.0 48,281 1,811,818 1,860,099 10
1272.0 30,765 1,876,598 1,907,367 11
1272.0 11 627,422 627,433 12
1272.0 14,426 4,195,868 4,210,296 13
1272.0 4,80C 134,061 138,861 14
1272.0 130,166 130,166 15
1272.0 294,29C 5,933,408 6,227,698 16
1272.0 15,463 15,463 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
1272.0 170,295 170,295 24
1272.0 9,760,523 9,760,523 25
1272.0 9,508,067 9,508,067 26
1272.0 4,482 320,874 325,356 27
4,336 795,396 799,735 28
430,671 430,671 29
397.5 18,976 1,083,716 1,102,694 30
397.5 27,52C 462,741 490,261 31
397.5 8,857 2,197,100 2,205.957 32
397.5 48,227 802,255 850,482 33
397.5 27,536 913,945 941,481 34
954.0 362,27E 2,804,992 3,167,271 35
79,506,609 1,318,178,273 1 397.684,882 36
FERC FORM NO.1 (ED.12-87)Page 423.2
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
TRANSMISSION LINE STATISTICS
1.Report information conærning 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 DËŠlÓNATIÓN VÓLTAGE (KV)LE GTH 'Pole miles)(Indicate where Type of the base of NumberNo.other than u ergrc und lines
60 cycle,3 ph ise)Supporting report circuit miles)Of
Un Structure Un Structures CircuitsFromToOperatingDesignedStructureofLineofAriotherDesignatedLine(a)(b)(c)(d)(e)(f)(g)(h)
1 Billings,Montana Yellowtail,Montana 161.0C 161.00 H Frame Wood 46.00 1
2 Big Grassy Sub.,ID Idaho Power Line,ID 161.00 161.00 Wood -H 1
3 Rigby Sub.,Idaho Jefferson Roberts,Idaho 161.00 161.00 Wood -SP 18.00 1
4 Naughton Plant,Wyoming Evanston Substation,WY 138.0C 138.00 Wood -H 56.00 1
5 Evanston Substation,WY Anschutz Substation,WY 138.0C 138.00 Wood -H 5.00 1
6 Evanston Substation,WY Anschutz Substation,WY 138.00 138.00 Wood -H 10.00 1
7 Naughton Plant,Wyoming Carter Creek Sub.,WY 138.00 138.00 Wood -H 26.00 1
8 Railroad Sub.,Wyoming Carter Creek Sub.,WY 138.0C 138.00 Wood -H 26.00 1
9 Painter Substation,WY Natural Gas Sub.,WY 138.0C 138.00 Wood -H 5.00 1
10 Grace Plant,Idaho Terminal Sub.,UT(103-104 138.0C 138.00 Steel-S 42.00 2
11 Grace Point,ID Terminal Sub,UT (103-10 138.0C 138.00 Wood -H 110.00 2
12 Grace Plant,Idaho Terminal Sub.,UT (105)138.0C 138.00 Wood -H 138.00 2
13 Grace Plant,Idaho Soda Plant,Idaho 138.00 138.00 Wood -H 6.00 4.00 2
14 Oneida Plant,Idaho Ovid Substation,Idaho 138.00 138.00 Wood -H 23.00 1
15 Antelope Substation,ID Scoville Sub.,Idaho 138.0C 138.00 Wood -H 1.00 1
16 Soda Plant,Idaho Monsanto Sub.,Idaho 138.0C 138.00 Wood -H 7.00 1
17 Caribou Substation,ID Grace Plant,Idaho 138.00 138.00 Wood -H 12.00 1
18 Caribou Substation,ID Becker Substation,Idaho 138.00 138.00 Wood -H 5.00 1
19 Treasureton Sub.,ID Franklin Sub.,Idaho 138.00 138.00 Wood -H &SP 10.00 1
20 Franklin Substation,ID Smithfield Sub.,Utah 138.0C 138.00 Wood-H 21.00 1
21 Midvalley Substation,UT Thirty South Sub.,UT 138.00 138.00 Wood -H 1
22 Angel Substation,UT Smith's UT 138.0C 138.00 Wood -H 1
23 Terminal Substation,UT Kennecott Sub.,Utah 138.0C 138.00 Steel-S 11.00 2
24 Terminal Substation,UT 30 South Switch Rack,UT 138.0C 138.00 Steel-S 7.00 1
25 Jordan,UT Terminal Substation,UT 138.0C 138.00 Wood -H 6.00 1
26 Wheelon Substation,Utah American Falls Sub.,UT 138.0C 138.00 Wood -H 82.00 1
27 Cutler Plant,UT Wheelon Substation,UT 138.0C 138.00 Wood -H 1
28 Terminal Substation,UT Helper Substation,Utah 138.0C 138.00 Wood -H 116.00 1
29 Hale Plant,Utah Nebo Substation,Utah 138.00 138.00 Wood -H 48.00 1
30 Carbon Plant,Utah Helper Substation,Utah 138.0C 138.00 Wood -H 2.00 1
31 Terminal Substation,UT Tooele Substation,Utah 138.0C 138.00 Wood -H 23.00 1
32 Wheelon Substation,Utah Smithfield Sub.,Utah 138.0C 138.00 Wood -H 18.00 1.00 2
33 Helper Substation,Utah Moab Substation,Utah 138.0C 138.00 Wood -H 115.00 1
34 Ninetieth South Sub,Utah Carbon Plant,Utah 138.0C 138.00 Wood -H 72.00 2
35 Terminal Substation,UT Ninetieth South Sub,UT 138.0C 138.00 Wood -H 16.00 2
36 TOTAL 14,876.00 100.00 191
FERC FORM NO.1 (ED.12-87)Page 422.3
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001
(2)A Resubmission //
TRANSMISSION LINE STATISTICS (Continued)
7.Do not report the same transmission line structure twice.Report Lower voltage Lines and higher voltage lines as one line.Designate in a footnote if
you do not include Lower voltage lines with higher voltage lines.If two or more transmission line structures support lines of the same voltage,report the
pole miles of the primary structure in column (f)and the pole miles of the other line(s)in column (g)
8.Designate any transmission line or portion thereof for which the respondent is not the sole owner.If such property is leased from another company,
give name of lessor,date and terms of Lease,and amount of rent for year.For any transmission line other than a leased line,or portion thereof,for
which the respondent is not the sole owner but which the respondent operates or shares in the operation of,furnish a succinct statement explaining 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
ather pany 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.
ÓÓ$T ÓF LINE (include in Column (j)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)(!)(m)(n)(0)(p)No.
556.5 23,36E 1,196,316 1,219,684 1
556.5 26,208 26208 2
556.5 76,306 1.205,029 1,281,335 3
795.0 146,646 3,875,641 4,022,286 4
795.0 129,130 473,050 602,180 5
795.0 3,381 290,803 294,184 6
795.0 41,411 3,110,678 3,152,089 7
795.0 72,622 3,810,587 3,883,209 8
795.0 -12,424 -278,836 -291,260 9
795.0 696,52E 8,210,981 8,907,510 10
795.0 11
250.0 132,96C 9,056,971 9,189,931 12
795.0 3.28E 146,357 149,646 13
336.0 4,817 410,976 415,793 14
397.5 14E 390 538 15
397.5 2,55E 109,052 111,607 16
795.0 18,284 421,186 439,470 17
397.5 14,424 145,941 160,365 18
795.0 39,101 509,109 548,210 19
397.5 47,612 1,042,458 1,090,071 20
193,583 193,583 21
20,229 20,229 22
250.0 4,65E 346,819 351,477 23
500.0 1,837 960,134 961,971 24
666,572 1,764,997 2,431,570 25
250.0 118,18C 4,170,719 4,288,899 26
250.0 69,072 69,072 27
250.0 458,79E 6,043,825 6,502,624 28
397.5 27,546 4,202,746 4,230,291 29
954.0 786 98,978 99,764 30
397.5 4,801 984,417 989,218 31
397.5 188,01E 737,230 925,248 32
397.5 33,96E 2,370,410 2,404,378 33
795.0 345,835 3,861,196 4,207,031 34
1272.0 429,192 881,715 1,310,907 35
79,506,609 1,318,178,273 1,397,684,882 36
FERC FORM NO.1 (ED.12-87)Page 423.3
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
TRANSMISSION LINE STATISTICS
1.Report information concerning transmission lines,cost of lines,and expenses for year.List each transmission line having nominal voltage of 132
kilovolts or greater.Report transmission lines below these voltages in group totals only for each voltage.
2.Transmission lines include all lines covered by the definition of transmission system plant as given in the Uniform System of Accounts.Do not report
substation costs and expenses on this page.
3.Report data by individual lines for all voltages if so required by a State commission.
4.Exclude from this page any transmission lines for which plant costs are included in Account 121,Nonutility Property.
5.Indicate whether the type of supporting structure reported in column (e)is:(1)single pole wood or steel;(2)H-frame wood,or steel poles;(3)tower
or (4)underground construction If a transmission line has more than one type of supporting structure,indicate the mileage of each type of construction
by the use of brackets and extra lines.Minor portions of a transmission line of a different type of construction need not be distinguished from the
remainder of the line.
6.Report in columns (f)and (g)the total pole miles of each transmission line.Show in column (f)the pole miles of line on structures the cost of which is
reported for the line designated;conversely,show in column (g)the pole miles of line on structures the cost of which is reported for another line.Report
pole miles of line on leased or partly owned structures in column (g).In a footnote,explain the basis of such occupancy and state whether expenses with
respect to such structures are included in the expenses reported for the line designated.
Line DEŠlŠNATlÓN VÓLTAGE (KV)LENGTH 'Pole miles)(Indicate where Type of (la the base of NumberNo.other than undergrc und lines
60 cycle,3 phase)Supporting ,
report cir :uit miles)Of
Un Structure Un Structures CircuitsFromToOperatingDesignedStructureofLineofAnotherDesignatedLine(a)(b)(c)(d)(e)(f)(g)(h)
1 30 South Switch Rack,UT McClelland Sub.,Utah 138.0C 138.00 Wood -SP 6.00 1
2 Moab Substation,Utah Pinto Substation,Utah 138.0C 138.00 Wood -H 58.00 1
3 Pinto Substation,Utah Abajo,UT 138.0C 138.00 Wood -H 44.00 1
4 Carbon Plant,Utah Ashley Substation,Utah 138.0C 138.00 Wood -H 91.00 1
5 McClelland Sub.,Utah Cottonwood Sub.,Utah 138.0C 138.00 Wood -SP 5.00 1
6 Ashley Substation,Utah Vernal Substation,Utah 138.00 138.00 Wood-H 12.00 1
7 Sigurd Substation,Utah West Cedar Substation,U 138.0C 138.00 Wood -H 115.00 1
8 Ben Lomond Sub.,Utah El Monte Substation,UT 138.00 138.00 Wood -H 13.00 1
9 Cottonwood Sub.,Utah Ninetieth South Sub,Uta 138.00 138.00 Wood-SP 11.00 1
10 Terminal Substation,UT Rowley Substation,Utah 138.00 138.00 Wood-H 56.00 1
11 Huntington Plant,Utah McFadden Substation,UT 138.0C 138.00 Wood -H 7.00 1
12 Ben Lomond Sub.,Utah El Monte Substation,UT 138.00 138.00 Wood -H 6.00 1
13 Cottonwood Sub.,Utah Silvercreek Sub.,Utah 138.0C 138.00 Wood -SP 30.00 1
14 Ninetieth South Sub,Utah Taylorsville Sub.,Utah 138.0C 138.00 Wood -SP 7.00 1
15 Gadsby Plant,Utah McClelland Sub.,Utah 138.0C 138.00 Wood -SP 4.00 1
16 Ninetieth South Sub,Utah Oguirrh Substation,Utah 138.00 138.00 Wood -SP 7.00 2
17 Nebo,UT Jerusalem,UT 138.0C 138.00 Wood Tower 24.00 1
18 Ben Lomond Sub.,Utah Western Zircon Sub.,UT 138.OC 138.00 Wood -H 14.00 1
19 Tooele Substation,Utah Oguirrh Substation,Utah 138.0C 138.00 Wood -SP 22.00 1
20 Wheelon Substation,Utah Nucor Steel Sub.,Utah 138.0C 138.00 Wood -H 6.00 4.00 1
21 Nebo Substation,Utah Martin-Marietta Sub.,UT 138.0C 138.00 Wood -H 30.00 1
22 West Cedar Sub.,Utah Middleton Substation.,UT 138.0C 138.00 Wood -H 80.00 1
23 Gadsby Plant,Utah Terminal Substation,UT 138.0C 138.00 Wood-H 12.00 1
24 Oguirrh Substation,Utah Kennecott Sub.,Utah 138.0C 138.00 Wood -H 4.00 1
25 Oguirrh Substation,Utah Barney Substation,Utah 138.0C 138.00 Wood -HS 3.00 2
26 West Cedar Sub.,Utah Pepcon Substation,Utah 138.0C 138.00 Wood -SP 14.00 1
27 Taylorsville Substation,U Mid-Valley Substation,U 138.0C 138.00 Steel-SP 5.00 1
28 Warren Substation,Utah Kimberly Clark Sub.,UT 138.0C 138.00 Wood -HP 1.00 1
29 Honeyville,Utah Promontory,Utah 138.0C 138.00 Wood Tower 22.00 1
30 Ninetieth South Sub,Utah Hale Plant,Utah 138.00 138.00 Wood Tower 32.00 1
31 Dumas,UT Bimple,UT 138.0C 138.00 Wood Tower 5.00
32 Columbia Sub,Utah Sunnyside Co.Gen.,Utah 138.00 138.00 Wood Tower 2.00 1
33 Syracuse Sub,Utah Ben Lomond Sub,Utah 138.0C 138.00 Steel-D-P 1
34 Hale Plant,Utah Midway Sub,Utah 138.0C 138.00 Wood -H 15.00 1
35 Jordan 138 kv,UT Fifth West 138 kv,UT 138.0C 138.00 Steel Tower 1.00 1
36 TOTAL 14,876.00 100.00 191
FERC FORM NO.1 (ED.12-87)Page 422.4
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
RANSMISSION LINE STATISTICS (Continued)
7.Do not report the same transmission line structure twice.Report Lower voltage Lines and higher voltage lines as one line.Designate in a footnote if
you do not include Lower voltage lines with higher voltage lines.If two or more transmission line structures support lines of the same voltage,report the
pole miles of the primary structure in column (f)and the pole miles of the other line(s)in column (g)
8.Designate any transmission line or portion thereof for which the respondent is not the sole owner.If such property is leased from another company,
give name of lessor,date and terms of Lease,and amount of rent for year.For any transmission line other than a leased line,or portion thereof,for
which the respondent is not the sole owner but which the respondent operates or shares in the operation of,furnish a succinct statement explaining 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.
COŠT ÓF LINE (Include in Óolumn (j)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)(I)(m)(n)(0)(p)No.
795.0 62,181 1,549,710 1,611,891 1
397.5 40,115 996.661 1,036,776 2
397.5 43,002 1,927,208 1,970,210 3
397.5 47,374 1,601,383 1,648,757 4
795.0 13,732 239,547 253,280 5
397.5 5,54E 255,095 260,641 6
397.5 52,28C 2,545,115 2,597,395 7
795.0 18,845 619,381 638,226 8
795.0 549,064 1,582,952 2,132,016 9
795.0 222,286 2,232,291 2,454,577 10
397.5 264 218,455 218,719 11
795.0 24,901 433,607 458,508 12
397.5 177,824 2,848,763 3,026,587 13
795.0 5,176 435,845 441,023 14
795.0 56,75E 925,859 982,618 15
795.0 291,996 1,247,050 1,539,048 16
397.5 253,53E 2,134,351 2,387,890 17
250.0 96,457 966,828 1,063,285 18
795.0 252,891 3,023,817 3.276,708 19
795.0 46,947 909,120 956,067 20
397.5 66,452 1,753,775 1,820,227 21
397.5 25,14E 1,467,913 1,493,061 22
1272.0 668,771 810,473 1,479,244 23
795.0 201,459 201,459 24
795.0 16,66E 427,998 444,666 25
195.0 43,59C 1,085,024 1,128,614 26
1272.0 33,466 2,452,332 2,485,798 27
297.5 14,722 141,422 156,144 28
397.5 475,682 2,874,162 3,349,844 29
397.5 146,426 5,418,579 5,565,004 30
397.5 3,136,585 3,136,585 31
397.5 -41 2 -39 32
1272.0 353,104 353,104 33
397.5 246,502 3,894,983 4,141,486 34
1272.0 16 733,316 733,332 35
79,506,609 1,318,178,273 1,397,684,882 36
FERC FORM NO.1 (ED.12-87)Page 423.4
Name of Respondent This Report is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001
(2)A Resubmission I /
TRANSMISSION LINE STATIST CS
1.Report information concerning transmission lines,cost of lines,and expenses for year.List each transmission line having nominal voltage of 132
kilovolts or greater.Report transmission lines below these voltages in group totals only for each voltage.
2.Transmission lines include all lines covered by the definition of transmission system plant as given in the 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 DESIÓNATIÓN VOLTAGE (KV)LE GTH 'Pole miles)(Indicate where Type of (the base of NumberNo.other than un ergrt und lines
60 cycle,3 phase)Supporting report cir:uit miles)Of
Un Structure Un Structures CircuitsFromToOperatingDesignedStructureofLineofAriotherDesignatedLine(a)(b)(c)(d)(e)(f)(g)(h)
1 Gadsby 138 kv,UT Jordan 138 kv,UT 138.0C 138.00 Steel Tower 1.00 1
2 2-138 kv Riverdale Sub,UT 2-138 kv Riverdale Sub,138.0C 138.00 Steel Tower 1.00 2
3 Panther,UT Willo Creek,UT 138.0C 138.00 Wood Tower 1.00 1
4 Hamer Substaion,UT Butterville Substation,138.0C 138.00 Wood Tower
5 Midway Substation,UT Silver Creek Sub,UT 138.0C 138.00 Wood Tower
6 Midway Substation,UT Cottonwood Sub,UT 138.0C 138.00 Wood Tower
7 Pavant Substaion,UT Delta,UT 138.0C 138.00 Wood Tower 26.00 1
8 Blundell Substation,UT Milford Substation,UT 138.0C 138.00 Wood Tower 13.00 1
9
10
11 All These 115 kV lines 115.0C 115.00 Wood &Steel 1,427.00
12 AII These 69 kV lines 69.0C 69.00 Wood &Steel 2,972.00 1.00
13 All These 57 kV lines 57.0C 57.00 Wood &Steel 118.00
14 All These 46 kV lines 46.OC 46.00 Wood &Steel 2,506.00
15
16
17 Expense Excpt Dep.&Tax
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36 TOTAL 14,876.00 100.00 191
FERC FORM NO.1 (ED.12-87)Page 422.5
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001
(2)A Resubmission //
TRANSMISSION LINE STATISTICS (Continued)
7.Do not report the same transmission line structure twice.Report Lower voltage Lines and higher voltage lines as one line.Designate in a footnote if
you do not include Lower voltage lines with higher voltage lines.If two or more transmission line structures support lines of the same voltage,report the
pole miles of the primary structure in column (f)and the pole miles of the other line(s)in column (g)
8.Designate any transmission line or portion thereof for which the respondent is not the sole owner.If such property is leased from another company,
give name of lessor,date and terms of Lease,and amount of rent for year.For any transmission line other than a leased line,or portion thereof,for
which the respondent is not the sole owner but which the respondent operates or shares in the operation of,furnish a succinct statement explaining 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.
ÓÓŠT ÓF LINE (Include in Óolumn (j)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)(I)(m)(n)(0)(p)No.
1272.0 756 381,900 382.655 1
795.0 76,205 76.205 2
397.5 40,890 40,890 3
188,391 3,385,359 3,573,750 4
2,713,501 2,713,501 5
5,380,733 5,380,733 6
55,43E 1,140,316 1,195,755 7
22,50C 771,201 793,701 8
9
10
3,511,36E 97,195,548 100,706,917 11
3,130,232 161,746,566 164,876,798 12
41,234 6,356,783 6,398,017 13
4,400,54E 139,861,798 144,262,347 14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
79,506,609 1,318,178,273 1,397,684,882 36
FERC FORM NO.1 (ED.12-87)Page 423.5
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001
(2)A Resubmission //
TRANSMISSION LINES ADDED DURING YEAR
1.Repod below the information called for concerning Transmission lines added or altered during the year.It is not necessary to report
mincr revisions of lines.
2.P ovide separate subheadings for overhead and under-g ound construction and show etch transmission line separately.If actual
cost::of competed construction E re not readily available for reporting columns (I)to (o),it is permissible to re;ort in these columns the
Line LINE DEE IGNATION Line SUPPORTINÓ STRUCTURE CIRCUITS PER STRUCTUR ·
Length AverageNo.From To in Type Number per Present UltimateMilesMiles
(a)(b)(c)(d)(e)(f)(g)
1 Pilot Butte Sub Cleveland Ave.Sub 4.50 Steel Dbl.Ck.16.00 2
2 Rose Park Riverdale 25.50 Steel Dbl.Ck.9.00 2
3 Glen Canyon Switchyard Arizona-Utah Border 10.40 Wood H-Frame 6.00 1
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 40.40 31.00 5
ERC FORM NO.1 (ED.12-86)>age 424
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001
(2)A Resubmission //
TRANSMISSION LINES ADDED DURING YEAR (Continued)
costs.Designate,however,if estimated amounts are reported.Include costs of Clearing Land and Rights-of-Way,and Roads and
Trails,in column (I)with appropriate footnote,and costs of Underground Conduit in column (m).
3.If design voltage differs from operating voltage,indicate such fact by footnote;also where line is other than 60 cycle,3 phase,
indicate such other characteristic.
CONDUÓTÓRG Voltage LINE ÓŠŠT 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)(I)(m)(n)(0)
795KCM ACSR Verticall8'115 5,000 500,000 150,000 655,000 1
795/954 ACSR TG-275/10'138 7,000 5,010,000 926,600 5,943,600 2
954 MCM ACSR Horiz.20'230 178,642 252,029 430,671 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
12,00C 5,688,642 1,328,629 7,029,271 44
FERC FORM NO.1 (ED.12-86)Page 425
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
SUBSTATIONS
1.Report below the information called for concerning substations of the respondent as of the-end of the year.
2.Substations which serve only one industrial or street railway customer should not be listed below.
3.Substations with capacities of Less than 10 MVa except those serving customers with energy for resale,may be grouped according
to functional character,but the number of such substations must be shown.
4.Indicate in column (b)the functional character of each substation,designating whether transmission or distribution and whether
attended or unattended.At the end of the page,summarize according to function the capacities reported for the individual stations in
column (f).
Line VOLTAGE (In M Ja)
No.Name and Location of Substation Character of Substation Primary Secondary Tertiary
(a)(b)(c)(d)(e)
1 CALIFORNIA
2 BIG SPRINGS Distribution -Unat 69.00 12.50 1.00
3 CANBY #2 Distribution -Unat 69.00 2.40 1.00
4 CLEAR LAKE Distribution -Unat 69.00 12.50 1.00
5 CRESCENT CITY Distribution -Unat 12.00 4.16 2.00
6 FILKINS Distribution -Unat 12.00 4.00 2.00
7 GASQUET Distribution -Unat 69.00 4.16 1.00
8 GOOSE LAKE Distribution -Unat 69.00 2.40 1.00
9 HAMBURG Distribution -Unat 69.00 2.40 1.00
10 HAPPY CAMP Distribution -Unat 69.00 12.50 1.00
11 HORNBROOK Distribution -Unat 69.00 12.00 1.00
12 LAKE EARL Distribution -Unat 69.00 12.50 1.00
13 LITTLE SHASTA Distribution -Unat 69.00 7.20 1.00
14 LUCERNE Distribution -Unat 69.00 12.00 1.00
15 MACDOEL Distribution -Unat 69.00 20.80 2.00
16 MILLER REDWOOD Distribution -Unat 69.00 13.20 1.00
17 MONTAGUE Distribution -Unat 69.00 12.50 1.00
18 NUTGLADE Distribution -Unat 69.00 2.40 1.00
19 PATRICKS CREEK Distribution -Unat 69.00 7.20 1.00
20 PEREZ Distribution -Unat 69.00 12.50 1.00
21 SCOTT BAR Distribution -Unat 69.00 12.00 1.00
22 SEIAD Distribution -Unat 69.00 12.50 1.00
23 SHASTINA Distribution -Unat 115.00 20.80 1.00
24 SHOTGUN CREEK Distribution -Unat 69.00 12.50 1.00
25 SIMONSON Distribution -Unat 69.00 12.50 1.00
26 SMITH RIVER Distribution -Unat 69.00 12.50 1.00
27 SNOW BRUSH Distribution -Unat 69.00 7.20 1.00
28 SOUTH DUNSMUIR Distribution -Unat 69.00 4.16 1.00
29 TULELAKE Distribution -Unat 69.00 12.50 1.00
30 WALKER-BRYAN Distribution -Unat 69.00 12.00 1.00
31 YUBA Distribution -Unat 69.00 12.50 1.00
32 TOTAL 2002.00 300.48 33.00
33 NUMBER OF SUBSTATIONS DISTRIBUTION -30
34
35 COPCO #2 T/D -Attended 6.60 115.00 2.00
36 ALTURAS T/D -Unattended 115.00 69.00 2.00
37 BELMONT T/D -Unattended 69.00 12.50 1.00
38 CASTELLA T/D -Unattended 69.00 2.40 1.00
39 DOG CREEK T/D -Unattended 69.00 2.40 1.00
40 DORRIS T/D -Unattended 69.00 12.00 1.00
FERC FORM NO.1 (ED.12-96)Page 426
Name of Respondent This Re ort Is:Date of Report Year of Report
PacifiCorp (1)X An Original (Mo,Da,Yr)Dec.31,2001
(2)A Resubmission //
SUBSTATIONS (Continued)
5.Show in columns (l),(j),and (k)special equipment such as rotary converters,rectifiers,condensers,etc.and auxiliary equipment for
increasing capacity.
6.Designate substations or major items of equipment leased from others,jointly owned with others,or operated otherwise than 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 padies,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 SPECIAL EDUIPMENT Line
(in Service)(In MVa)Transfeoreers TranSsoar
ers Type of Equipment Number of Units Tot CMapaacityNo.
(f)(g)(h)(i)(j)(k)
1
1 1 2
1 1 3
1 1 4
2 2 5
2 2 6
1 1 7
1 1 8
1 1 9
1 1 10
1 1 11
1 1 12
1 1 13
1 1 14
2 2 15
1 1 16
1 1 17
1 1 18
1 1 19
1 1 20
1 1 21
1 1 22
1 1 23
1 1 24
1 1 25
1 1 26
1 1 27
1 1 28
1 1 29
1 1 30
1 1 31
33 33 32
33
34
2 2 35
2 2 36
1 1 37
1 1 38
1 1 39
1 1 40
FERC FORM NO.1 (ED.12-96)Page 427
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)X An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
SUBSTATIONS
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 M /a)
No.Name and Location of Substation Character of Substation Primary Secondary Tertiary
(a)(b)(c)(d)(e)
1 FT.JONES T/D -Unattended 69.00 12.00 1.00
2 GREEN HORN T/D -Unattended 69.00 12.50 1.00
3 MC CLOUD T/D -Unattended 2.40 12.50 2.00
4 MT SHASTA T/D -Unattended 69.00 12.50 2.00
5 NEWELL T/D -Unattended 69.00 12.50 1.00
6 NORTH DUNSMUIR T/D -Unattended 69.00 12.00 2.00
7 NORTHCREST T/D -Unattended 69.00 12.50 2.00
8 REDWOOD T/D -Unattended 69.00 12.50 1.00
9 TUNNEL T/D -Unattended 69.00 12.50 2.00
10 WEED TID -Unattended 69.00 12.50 1.00
11 YREKA TID -Unattended 115.00 69.00 2.00
12 TOTAL 1136.00 406.30 25.00
13 NUMBER OF SUBSTATIONS T/D -17
14
15 FALL CREEK Transmission -Atte 2.40 69.00 1.00
16 AGER Transmission -Unat 115.00 69.00 1.00
17 COPCO II 230 KV Transmission -Unat 230.00 115.00 1.00
18 CRAG VIEW Transmission -Unat 115.00 69.00 1.00
19 DEL NORTE Transmission -Unat 115.00 69.00 2.00
20 INTERNATIONAL PAPER Transmission -Unat 69.00 2.30 1.00
21 WEED JUNCTION Transmission -Unat 115.00 69.00 1.00
22 TOTAL 761.40 462.30 8.00
23 NUMBER OF SUBSTATIONS TRANSMISSION -7
24
25 IDAHO
26 MUD LAKE Distribution 69.00 12.00 1.00
27 LAVA Distribution -Atte 46.00 12.50 1.00
28 ALEXANDER Distribution-Unat 46.00 12.50 1.00
29 AMMON Distribution -Unat 69.00
30 ANDERSON Distribution-Unat 69.00
31 ARCO Distribution-Unat 69.00 12.47 1.00
32 ARIMO Distribution -Unat 43.80 12.50 1.00
33 BANCROFT Distribution -Unat 46.00 12.50 1.00
34 BELSON Distribution -Unat 69.00 12.47 1.00
35 BERENICE Distribution -Unat 69.00 25.00 1.00
36 CAMAS Distribution -Unat 69.00 12.47 1.00
37 CANYON CREEK Distribution -Unat 69.00 24.94 1.00
38 CHESTERFIELD Distribution -Unat 46.00 12.50 1.00
39 CLIFTON Distribution -Unat 46.00 12.50 1.00
40 DOWNEY Distribution -Unat 46.00 12.50 1.00
FERC FORM NO.1 (ED.12-96)Page 426.1
Name of Respondent This Re ort Is:Date of Report Year of Report
PacifiCorp (1)X An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
SUBSTATIONS (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 CONVERSION APPARATUS AND SPECIAL E]UIPMENT Line
(In Service)(In MVa)Transfeoeers TranSarmers Type of Equipment Number of Units Tot CMapaacityNo.
(f)(g)(h)(i)(j)(k)
1 1 1
1 1 2
2 2 3
2 2 4
1 1 5
2 2 6
2 2 7
1 1 8
2 2 9
1 1 10
2 2 11
25 25 12
13
14
1 1 15
1 1 16
1 1 17
1 1 18
2 2 19
1 1 20
1 1 21
8 8 22
23
24
25
1 1 26
1 1 27
1 1 28
29
30
1 1 31
1 1 32
1 1 33
1 1 34
1 1 35
1 1 36
1 1 37
1 1 38
1 1 39
1 1 40
FERC FORM NO.1 (ED.12-96)Page 427.1
Name of Respondent This Re ort Is:Date of Report Year of Report
PacifiCorp (1)X An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
SUBSTATIONS
1.Report below the information called for concerning substations of the respondent as of the end of the year.
2.Substations which serve only one industrial or street railway customer should not be listed below.
3.Substations with capacities of Less than 10 MVa except those serving customers with energy for resale,may be grouped according
to functional character,but the number of such substations must be shown.
4.Indicate in column (b)the functional character of each substation,designating whether transmission or distribution and whether
attended or unattended.At the end of the page,summarize according to function the capacities reported for the individual stations in
column (f).
Line V3LTAGE (In M Ja)
No Name and Location of Substation Character of Substation Primary Secondary Tertiary
(a)(b)(c)(d)(e)
1 DUBOIS Distribution -Unat 69.00 12.47 1.00
2 EASTMONT Distribution -Unat 69.00 12.47 1.00
3 EGIN Distribution -Unat 69.00 12.47 1.00
4 GEORGETOWN Distribution -Unat 69.00 12.50 1.00
5 GRACE CITY Distribution -Unat 46.00 12.50 1.00
6 HAMER Distribution -Unat 69.00 12.47 1.00
7 HAYES Distribution -Unat 69.00 12.47 1.00
8 HENRY Distribution -Unat 46.00 12.47 2.00
9 HOLBROOK Distribution -Unat 69.00 12.50 1.00
10 HOOPES Distribution -Unat 69.00 12.47 1.00
11 IDAHO FALLS Distribution -Unat 46.00 12.50 1.00
12 INDIAN CREEK Distribution -Unat 69.00 12.47 1.00
13 JEFFCO Distribution -Unat 69.00 24.94 1.00
14 KETTLE·Distribution -Unat 69.00 24.94 1.00
15 LIFTON PUMPING STATION Distribution -Unat 69.00 2.30 2.00
16 LUND Distribution -Unat 46.00 12.50 1.00
17 MCCAMMON Distribution -Unat 46.00 12.47 1.00
18 MENAN Distribution -Unat 69.00 12.47 1.00
19 MERRILL Distribution -Unat 69.00 12.47 1.00
20 MILLER Distribution -Unat 69.00 12.47 1.00
21 MONTPELIER Distribution -Unat 46.00 12.50 1.00
22 MOODY Distribution -Unat 69.00 12.47 1.00
23 NEWDALE Distribution -Unat 69.00 12.47 1.00
24 OSGOOD Distribution -Unat 69.00 12.47 1.00
25 PRESTON Distribution -Unat 46.00 12.50 1.00
26 RAYMOND Distribution -Unat 69.00 12.50 1.00
27 RENO Distribution -Unat 69.00 12.47 1.00
28 REXBURG Distribution -Unat 69.00 12.47 2.00
29 RIGBY Distribution -Unat 69.00 12.50 1.00
30 RIRIE Distribution -Unat 69.00 12.47 1.00
31 ROBERTS Distribution -Unat 69.00 12.47 1.00
32 RUBY Distribution -Unat 69.00 12.47 1.00
33 SAND CREEK Distribution -Unat 69.00 12.50 2.00
34 SANDUNE Distribution -Unat 69.00 24.94 1.00
35 SHELLEY Distribution -Unat 46.00 12.47 1.00
36 SMITH Distribution -Unat 69.00 12.47 1.00
37 SOUTH FORK Distribution -Unat 69.00 12.50 1.00
38 SUGAR CITY Distribution -Unat 69.00 12.47 1.00
39 TANNER Distribution -Unat 46.00 12.50 1.00
40 TARGHEE Distribution -Unat 46.00 12.47 1.00
FERC FORM NO.1 (ED.12-96)Page 426.2
Name of Respondent This Re ort Is:Date of Report Year of Report
PacifiCorp (1)X An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
SUBSTATIONS (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 CONVERSION APPARATUS AND SPECIAL E3UIPMENT Line
(in Service)(In MVa)Transfeo rs TranSsoar
ers Type of Equipment Number of Units Tot CMapaacityNo.
(f)(9)(h)(i)(j)(k)
1 1 1
1 1 2
1 1 3
1 1 4
1 1 5
1 1 6
1 1 7
2 2 8
1 1 9
1 1 10
1 1 11
1 1 12
1 1 13
1 1 14
2 2 15
1 1 16
1 1 17
1 1 18
1 1 19
1 1 20
1 1 21
1 1 22
1 1 23
1 1 24
1 1 25
1 1 26
1 1 27
2 2 28
1 1 29
1 1 30
1 1 31
1 1 32
2 2 33
1 1 34
1 1 35
1 1 36
1 1 37
1 1 38
1 1 39
1 1 40
FERC FORM NO.1 (ED.12-96)Page 427.2
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)X An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
SUBSTATIONS
1.Report below the information called for concerning substations of the respondent as of the end of the year.
2.Substations which serve only one industrial or street railway customer should not be listed below.
3.Substations with capacities of Less than 10 MVa except those senting 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 M Ja)
No Name and Location of Substation Character of Substation Primary Secondary Tertiary
(a)(b)(c)(d)(e)
1 THORNTON AREA Distribution -Unat 69.00 12.47 1.00
2 UCON Distribution -Unat 69.00 12.47 1.00
3 WATKINS Distribution -Unat 69.00 12.47 1.00
4 WEBSTER Distribution -Unat 69.00 12.47 1.00
5 WESTON Distribution -Unat 46.00 12.50 1.00
6 TOTAL 3723.80 775.63 62.00
7 NUMBER OF SUBSTATIONS DISTRIBUTION -60
8
9 GOSHEN (IDAHO)Transmission -Atte 345.00 161.00 6.00
10 AMPS Transmission -Unat 230.00 69.00 1.00
11 ANTELOPE Transmission -Unat 230.00 138.00 3.00
12 BONNEVILLE Transmission -Unat 161.00 69.00 1.00
13 CARIBOU Transmission -Unat 138.00 46.00 1.00
14 CONDA Transmission -Unat 138.00 46.00 1.00
15 FISH CREEK Transmission -Unat 161.00 46.00 1.00
16 FRANKLIN Transmission -Unat -138.00 46.00 1.00
17 JEFFERSON Transmission -Unat 161.00 69.00 2.00
18 MALAD Transmission -Unat 138.00 69.00 2.00
19 SCOVILLE Transmission -Unat 138.00 69.00 1.00
20 SUGAR MILL Transmission -Unat 161.00 69.00 3.00
21 TREASURETON Transmission -Unat 230.00 138.00 2.00
22 TOTAL 2369.00 1035.00 25.00
23 NUMBER OF SUBSTATIONS TRANSMISSION -13
24
25 OREGON
26 CHINA HAT Distribution -Atte 115.00 12.50 1.00
27 WEST SIDE Distribution -Atte 69.00 12.50 2.00
28 26TH STREET Distribution -Unat 20.80 4.10 1.00
29 35TH STREET Distribution -Unat 20.80 4.10 2.00
30 ARLINGTON Distribution -Unat 69.00 12.50 1.00
31 BANDON Distribution -Unat 20.80 12.00 1.00
32 BEACON Distribution -Unat 69.00 12.50 1.00
33 BEATTY Distribution -Unat 69.00 12.50 1.00
34 BLALOCK Distribution -Unat 69.00 12.50 1.00
35 BLY Distribution -Unat 69.00 12.50 1.00
36 BOISE CASCADE Distribution -Unat 69.00 2.30 1.00
37 BONANZA Distribution -Unat 69.00 12.50 1.00
38 BROWNSVILLE Distribution -Unat 69.00 20.80 1.00
39 CANNON BEACH Distribution -Unat 115.00 12.50 1.00
40 CASEBEER Distribution -Unat 69.00 20.80 1.00
FERC FORM NO.1 (ED.12-96)Page 426.3
Name of Respondent This Re ort Is:Date of Report Year of Report
PacifiCorp (1)X An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
SUBSTATIONS (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)
1 1 1
1 1 2
1 1 3
1 1 4
1 1 5
62 62 6
7
8
6 6 9
1 1 10
3 3 11
1 1 12
1 1 13
1 1 14
1 1 15
1 1 16
2 2 17
2 2 18
1 1 19
3 3 20
2 2 21
25 25 22
23
24
25
1 1 26
2 2 27
1 1 28
2 2 29
1 1 30
1 1 31
1 1 32
1 1 33
1 1 34
1 1 35
1 1 36
1 1 37
1 1 38
1 1 39
1 1 40
FERC FORM NO.1 (ED.12-96)Page 427.3
Name of Respondent This Re ort Is:Date of Report Year of Report(1)An Original (Mo,Da,Yr)PacifiCorp Dec.31,2001(2)A Resubmission //
SUBSTATIONS
1.Report below the information called for concerning substations of the respondent as of the end of the year.
2.Substations which serve only one industrial or street railway customer should not be listed below.
3.Substations with capacities of Less than 10 MVa except those serving customers with energy for resale,may be grouped according
to functional character,but the number of such substations must be shown.
4.Indicate in column (b)the functional character of each substation,designating whether transmission or distribution and whether
attended or unattended.At the end of the page,summarize according to function the capacities reported for the individual stations incolumn(f).
Line VOLTAGE (In MVa)
No Nameand Location of Substation Character of Substation Primary Secondary Tertiary
(a)(b)(c)(d)(e)
1 CHILOQUIN MARKET Distribution -Unat 69.00 12.50 1.00
2 CLEARWATER #2 Distribution -Unat 11.50 6.90 1.00
3 CLEARWATER #1 Distribution -Unat 7.20 115.00 1.00
4 COLUMBIA Distribution -Unat 115.00 12.47 1.00
5 CROOKED RIVER RANCH Distribution -Unat 69.00 20.80 1.00
6 CUTLER CITY Distribution -Unat 20.80 4.16 1.00
7 DEE Distribution -Unat 69.00 2.40 1.00
8 DOUGLAS-VENEER Distribution -Unat 69.00 12.00 1.00
9 FIELDER CREEK Distribution -Unat 115.00 20.80 1.00
10 FOOTHILLS Distribution -Unat 69.00 12.50 2.00
11 FRALEY Distribution -Unat 69.00 12.00 1.00
12 GARDENVALLEY Distribution -Unat 69.00 20.80 1.00
13 GAZLEY Distribution -Unat 69.00 12.50 1.00
14 GEARHART Distribution -Unat 12.50 4.16 1.00
15 GLENEDEN Distribution -Unat 20.80 4.16 1.00
16 GLIDE Distribution -Unat 115.00 12.50 1.00
17 GORDON HOLLOW Distribution -Unat 69.00 20.80 1.00
18 GRASS VALLEY Distribution -Unat 20.00 7.20 2.00
19 GROVE Distribution -Unat 12.00 4.16 1.00
20 HAMAKER Distribution -Unat 69.00 12.50 1.00
21 HAZELWOOD Distribution -Unat 12.00 20.00 1.00
22 HENLEY Distribution -Unat 69.00 12.50 1.00
23 HENRY STREET Distribution -Unat 20.80 2.40 1.00
24 HILL STREET Distribution -Unat 12.50 2.30 1.00
25 HINKLE Distribution -Unat 69.00 12.50 1.00
26 HOOD RIVER Distribution -Unat 69.00 12.50 2.00
27 JORDAN POINT Distribution -Unat 115.00 12.50 2.00
28 JOSEPH Distribution -Unat 20.80 12.50 1.00
29 K STREET Distribution -Unat 66.00 12.50 1.00
30 KENWOOD Distribution -Unat 69.00 12.50 1.00
31 KINGSLEY FIELD Distribution -Unat 69.00 2.40 2.00
32 KNAPPA SVENSEN Distribution -Unat 115.00 12.47 1.00
33 LAKEVIEW Distribution -Unat 69.00 12.00 1.00
34 LANCASTER Distribution -Unat 69.00 20.80 1.00
35 MAPLE STREET Distribution -Unat 20.00 2.40 1.00
36 MEDCO Distribution -Unat 115.00 12.50 1.00
37 MINAM Distribution -Unat 69.00 12.50 1.00
38 MODOC Distribution -Unat 69.00 12.50 1.00
39 MORO Distribution -Unat 20.80 2.40 1.00
40 MYRTLE POINT Distribution -Unat 115.00 20.80 1.00
FERC FORM NO.1 (ED.12-96)Page 426.4
Name of Respondent This Re ort is:Date of Report Year of Report
PacifiCorp (1)X An Original (Mo,Da,Yr)Dec.31,2001
(2)A Resubmission //
SUBSTATIONS (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 CONVERSION APPARATUS AND SPECIALEDUIPMENT 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)
1 1 1
1 1 2
1 1 3
1 1 4
1 1 5
1 1 6
1 1 7
1 1 8
1 1 9
2 2 10
1 1 11
1 1 12
1 1 13
1 1 14
1 1 15
1 1 16
1 1 17
2 2 18
1 1 19
1 1 20
1 1 21
1 1 22
1 1 23
1 1 24
1 1 25
2 2 26
2 2 27
1 1 28
1 1 29
1 1 30
2 2 31
1 1 32
1 1 33
1 1 34
1 1 35
1 1 36
1 1 37
1 1 38
1 1 39
1 1 40
FERC FORM NO.1 (ED.12-96)Page 427.4
Name of Respondent This Re ort Is:Date of Report Year of Report
PacifiCorp (1)X An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
SUBSTATIONS
1.Report below the information called for concerning substations of the respondent as of the end of the year.
2.Substations which serve only one industrial or street railway customer should not be listed below.
3.Substations with capacities of Less than 10 MVa except those serving customers with energy for resale,may be grouped according
to functional character,but the number of such substations must be shown.
4.Indicate in column (b)the functional character of each substation,designating whether transmission or distribution and whether
attended or unattended.At the end of the page,summarize according to function the capacities repoded 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 NELSCOTT Distribution -Unat 20.80 4.16 1.00
2 OAKLAND Distribution -Unat 115.00 12.50 1.00
3 ORCHARD STREET Distribution -Unat 12.50 4.00 1.00
4 OROMITE Distribution -Unat 69.00 12.47 1.00
5 PACIFIC PLYWOOD Distribution -Unat 69.00 4.16 1.00
6 PROVOLT Distribution -Unat 69.00 12.50 1.00
7 RED BLANKET Distribution -Unat 69.00 4.16 1.00
8 RICH MFG.Distribution -Unat 57.00 11.00 1.00
9 RIDDLE-VENEER Distribution -Unat 69.00 12.00 1.00
10 ROGUE RIVER Distribution -Unat 69.00 20.80 2.00
11 ROSS AVENUE Distribution -Unat 69.00 12.50 1.00
12 RUCH Distribution -Unat 69.00 12.50 1.00
13 SELMA Distribution -Unat 69.00 12.50 1.00
14 SHASTA WAY Distribution -Unat 12.50 4.00 1.00
15 SIMTAG BOOSTER PUMP Distribution -Unat 34.50 4.16 2.00
16 SOUTH DUNES Distribution -Unat 115.00 12.50 1.00
17 SPRAGUE RIVER Distribution -Unat 69.00 12.50 1.00
18 STAYTON CITY Distribution -Unat 20.80 2.40 1.00
19 STEAMBOAT STATION Distribution -Unat 115.00 7.20 1.00
20 SUTHERLIN Distribution -Unat 115.00 12.47 1.00
21 TEXUM Distribution -Unat 69.00 12.50 2.00
22 TILLER Distribution -Unat 115.00 12.00 1.00
23 TOLO Distribution -Unat 69.00 12.50 1.00
24 TOM CREEK Distribution -Unat 69.00 2.40 1.00
25 TONGUE POINT Distribution -Unat 22.00 2.40 1.00
26 TURKEY HILL Distribution -Unat 69.00 12.50 1.00
27 U.S.PLYWOOD Distribution -Unat 20.80 2.40 2.00
28 UMAPINE Distribution -Unat 69.00 12.50 1.00
29 WARRENTON Distribution -Unat 115.00 12.50 2.00
30 WASCO Distribution -Unat 20.80 4.16 1.00
31 WECOMA BEACH Distribution -Unat 20.00 4.10 1.00
32 WINSTON Distribution -Unat 69.00 12.50 1.00
33 YOUNGS BAY Distribution -Unat 115.00 22.00 3.00
34 TOTAL 5526.80 1044.82 102.00
35 NUMBER OF SUBSTATIONS DISTRIBUTION -88
36
37 ALBINA T/D -Attended 115.00 69.00 3.00
38 BLOSS T/D -Attended 115.00 12.50 2.00
39 CLEVELAND AVE.T/D -Attended 69.00 12.50 2.00
40 FERNHILL T/D -Attended 115.00 12.47 1.00
FERC FORM NO.1 (ED.12-96)Page 426.5
Name of Respondent This Re ort Is:Date of Report Year of Report(1)X An Original (Mo,Da,Yr)PacifiCorp Dec.31,2001
(2)A Resubmission //
SUBSTATIONS (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 CONVERSION APPARATUS AND SPECIAL EDUIPMENT Line
(in Service)(In MVa)Tran
e
cee TranŠsoarmers Type of Equipment Number of Units Tot CMapaacityNo.
(f)(g)(h)(i)(j)(k)
1 1 1
1 1 2
1 1 3
1 1 4
1 1 5
1 1 6
1 1 7
1 1 8
1 1 9
2 2 10
1 1 11
1 1 12
1 1 13
1 1 14
2 2 15
1 1 16
1 1 17
1 1 18
1 1 19
1 1 20
2 2 21
1 1 22
1 1 23
1 1 24
1 1 25
1 1 26
2 2 27
1 1 28
2 2 29
1 1 30
1 1 31
1 1 32
3 3 33
102 102 34
35
36
3 3 37
2 2 38
2 2 39
1 1 40
FERC FORM NO.1 (ED.12-96)Page 427.5
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)X An Original (Mo,Da,Yr)Dec.31,2001
(2)A Resubmission //
SUBSTATIONS
1.Report below the information called for concerning substations of the respondent as of the end of the year.
2.Substations which serve only one industrial or street railway customer should not be listed below.
3.Substations with capacities of Less than 10 MVa except those serving customers with energy for resale,may be grouped according
to functional character,but the number of such substations must be shown.
4.Indicate in column (b)the functional character of each substation,designating whether transmission or distribution and whether
attended or unattended.At the end of the page,summarize according to function the capacities reported for the individual stations in
column (f).
Line V3LTAGE(In MVa)
No Nameand Location of Substation Character of Substation Primary Secondary Tertiary
(a)(b)(c)(d)(e)
1 GREEN T/D -Attended 69.00 20.80 1.00
2 STEVENS ROAD T/D -Attended 115.00 20.80 1.00
3 VILAS ROAD T/D -Attended 115.00 12.50 1.00
4 AGNESS AVENUE T/D -Unattended 115.00 12.50 1.00
5 ALDERWOOD T/D -Unattended 115.00 12.50 1.00
6 AMERICAN CAN T/D -Unattended 69.00 12.50 2.00
7 APPLEGATE T/D -Unattended 115.00 69.00 2.00
8 ASHLAND T/D -Unattended 115.00 69.00 2.00
9 ATHENA T/D -Unattended 69.00 12.50 1.00
10 BELKNAP T/D -Unattended 69.00 12.50 2.00
11 BROOKHURST T/D -Unattended 69.00 12.50 2.00
12 BRYANT T/D -Unattended 69.00 12.50 2.00
13 BUCHANAN T/D -Unattended 115.00 20.80 2.00
14 BUCKAROO T/D -Unattended 69.00 12.50 2.00
15 CAMPBELL T/D -Unattended 115.00 12.50 1.00
16 CARNES T/D -Unattended 69.00 12.50 1.00
17 CAVE JUNCTION T/D -Unattended 115.00 69.00 2.00
18 CAVEMAN T/D -Unattended 115.00 12.50 1.00
19 CHERRY LANE T/D -Unattended 69.00 12.00 1.00
20 CHILOQUIN T/D -Unattended 230.00 115.00 2.00
21 CIRCLE BOULEVARD T/D -Unattended 115.00 20.80 2.00
22 CLOAKE T/D -Unattended 69.00 20.80 1.00
23 COBURG T/D -Unattended 69.00 20.80 1.00
24 COLUMBIA T/D -Unattended 57.00 11.00 4.00
25 COOS RIVER T/D -Unattended 115.00 20.80 1.00
26 COQUILLE T/D -Unattended 115.00 20.80 2.00
27 CROWFOOT T/D -Unattended 115.00 20.80 1.00
28 CULLY T/D -Unattended 115.00 12.50 1.00
29 CULVER T/D -Unattended 69.00 12.50 1.00
30 DAIRY T/D -Unattended 69.00 12.50 1.00
31 DALLAS T/D -Unattended 115.00 20.80 2.00
32 DESCHUTES T/D -Unattended 69.00 12.50 1.00
33 DEVILS LAKE T/D -Unattended 115.00 20.00 2.00
34 DIXON T/D -Unattended 115.00 4.16 1.00
35 DODGE BRIDGE T/D -Unattended 69.00 20.80 1.00
36 EASY VALLEY T/D -Unattended 115.00 12.50 2.00
37 EMPIRE NEW T/D -Unattended 115.00 20.80 1.00
38 ENTERPRISE T/D -Unattended 69.00 20.80 2.00
39 FREEWATER T/D -Unattended 69.00 7.20 1.00
40 GLENDALE T/D -Unattended 230.00 12.50 2.00
FERC FORM NO.1 (ED.12-96)Page 426.6
Name of Respondent This Report Is:Date of Report Year of Report(1)OX An Original (Mo,Da,Yr)PacifiCorp Dec.31,2001(2)A Resubmission //
SUBSTATIONS(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 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 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 APPARATL S AND SPECIAL E]UIPMENT Line
(In Service)(In MVa)Transfeor rs TranSsoar
ers Type of Equipment Number of Units Tot CMapaacityNo.
(f)(g)(h)(i)(j)(k)
1 1 1
1 1 2
1 1 3
1 1 4
1 1 5
2 2 6
2 2 7
2 2 8
1 1 9
2 2 10
2 2 11
2 2 12
2 2 13
2 2 14
1 1 15
1 1 16
2 2 17
1 1 18
1 1 19
2 2 20
2 2 21
1 1 22
1 1 23
4 4 24
1 1 25
2 2 26
1 1 .27
1 1 28
1 1 29
1 1 30
2 2 31
1 1 32
2 2 33
1 1 34
1 1 35
2 2 36
1 1 37
2 2 38
1 1 39
2 2 40
FERC FORM NO.1 (ED.12-96)Page 427.6
Name of Respondent This Report Is:Date of Report Year of Repod
PacifiCorp (1)X An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
SUBSTATIONS
1.Report below the information called for concerning substations of the respondent as of the-end of the year.
2.Substations which serve only one industrial or street railway customer should not be listed below.
3.Substations with capacities of Less than 10 MVa except those serving customers with energy for resale,may be grouped according
to functional character,but the number of such substations must be shown.
4.Indicate in column (b)the functional character of each substation,designating whether transmission or distribution and whether
attended or unattended.At the end of the page,summarize according to function the capacities reported for the individual stations in
column (f).
Line VOLTAGE (In MVa)
No Name and Location of Substation Character of Substation Primary Secondary Tertiary
(a)(b)(c)(d)(e)
1 GOLD HILL T/D -Unattended 69.00 12.50 1.00
2 GOSHEN (OREGON)T/D -Unattended 115.00 20.80 1.00
3 GRANT T/D -Unattended 115.00 20.80 2.00
4 GRIFFIN CREEK T/D -Unattended 115.00 12.50 1.00
5 HARRISBURG T/D -Unattended 69.00 20.80 1.00
6 HERMISTON T/D -Unattended 69.00 12.50 2.00
7 HILLVIEW T/D -Unattended 115.00 20.00 2.00
8 HOLLADAY T/D -Unattended 115.00 11.00 3.00
9 HOLLYWOOD T/D -Unattended 115.00 12.50 2.00
10 HORNET T/D -Unattended 69.00 12.50 1.00
11 INDEPENDENCE T/D -Unattended 69.00 20.80 1.00
12 JACKSONVILLE T/D -Unattended 115.00 69.00 2.00
13 JEFFERSON T/D -Unattended 69.00 20.80 1.00
14 JEROME PRAIRIE T/D -Unattended 115.00 12.50 1.00
15 JUNCTION CITY T/D -Unattended 69.00 20.80 2.00
16 KILLINGSWORTH T/D -Unattended 69.00 12.50 2.00
17 KNOTT T/D -Unattended 115.00 57.00 4.00
18 LAKEPORT T/D -Unattended 69.00 12.50 2.00
19 LEBANON T/D -Unattended 115.00 20.80 2.00
20 LEMOLO #1 T/D -Unattended 11.50 115.00 1.00
21 LINCOLN T/D -Unattended 115.00 12.47 3.00
22 LOCKHART T/D -Unattended 115.00 20.80 2.00
23 LYONS (NEW)T/D -Unattended 69.00 12.00 2.00
24 MADRAS T/D -Unattended 69.00 12.50 2.00
25 MALLORY T/D -Unattended 115.00 12.47 1.00
26 MARYS RIVER T/D -Unattended 115.00 20.80 1.00
27 MEDFORD T/D -Unattended 115.00 69.00 6.00
28 MERLIN T/D -Unattended 115.00 12.50 2.00
29 MERRILL T/D -Unattended 69.00 12.50 2.00
30 MILE-HI T/D -Unattended 115.00 69.00 2.00
31 MURDER CREEK TID -Unattended 115.00 20.00 4.00
32 MYRTLE CREEK T/D -Unattended 69.00 12.00 1.00
33 NORTH BEND PLANT T/D -Unattended 115.00 12.00 3.00
34 OAK KNOLL T/D -Unattended 115.00 12.50 2.00
35 O'BRIEN (NEW)T/D -Unattended 115.00 12.50 1.00
36 OREMET T/D -Unattended 115.00 20.80 3.00
37 OVERPASS T/D -Unattended 69.00 12.50 2.00
38 PALLETTE T/D -Unattended 40.00 20.00 1.00
39 PARK STREET T/D -Unattended 115.00 12.50 2.00
40 PARKROSE T/D -Unattended 57.00 12.50 2.00
FERC FORM NO.1 (ED.12-96)Page 426.7
Name of Respondent This Re ort Is:Date of Report Year of Report
PacifiCorp (1)X An Original (Mo,Da,Yr)Dec.31,2001
(2)A Resubmission //
SUBSTATIONS(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 CONVERSION APPARATUS AND SPECIAL EQUIPMENT LineTransformersSpare(In Service)(In MVa)In Service Transformers Type of Equipment Number of Units Total Capacity No.
(In MVa)
(f)(g)(h)(i)(j)(k)
1 1 1
1 1 2
2 2 3
1 1 4
1 1 5
2 2 6
2 2 7
3 3 8
2 2 9
1 1 10
1 1 11
2 2 12
1 1 13
1 1 14
2 2 15
2 2 16
4 4 17
2 2 18
2 2 19
1 1 20
3 3 21
2 2 22
2 2 23
2 2 24
1 1 25
1 1 26
6 6 27
2 2 28
2 2 29
2 2 30
4 4 31
1 1 32
3 3 33
2 2 34
1 1 35
3 3 36
2 2 37
1 1 38
2 2 39
2 2 40
FERC FORM NO.1 (ED.12-96)Page 427.7
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)X An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
SUBSTATIONS
1.Report below the information called for concerning substations of the respondent as of the end of the year.
2.Substations which serve only one industrial or street railway customer should not be listed below.
3.Substations with capacities of Less than 10 MVa except those serving customers with energy for resale,may be grouped according
to functional character,but the number of such substations must be shown.
4.Indicate in column (b)the functional character of each substation,designating whether transmission or distribution and whether
attended or unattended.At the end of the page,summarize according to function the capacities reported for the individual stations in
column (f).
Line VOLTAGE (In M /a)
No.Name and Location of Substation Character of Substation Primary Secondary Tertiary
(a)(b)(c)(d)(e)
1 PENDLETON T/D -Unattended 69.00 12.50 6.00
2 PILOT ROCK T/D -Unattended 69.00 12.50 2.00
3 POWELL BUTTE T/D -Unattended 115.00 12.50 1.00
4 PRINEVILLE T/D -Unattended 115.00 12.50 2.00
5 QUEEN AVE T/D -Unattended 69.00 20.80 2.00
6 RIDDLE T/D -Unattended 69.00 12.50 1.00
7 ROSEBURG T/D -Unattended 69.00 20.80 2.00
8 RUSSELLVILLE T/D -Unattended 115.00 12.50 2.00
9 SAGE RD T/D -Unattended 115.00 12.50 2.00
10 SCENIC T/D -Unattended 115.00 69.00 3.00
11 SCIO TID -Unattended 69.00 12.00 1.00
12 SEASIDE T/D -Unattended 115.00 12.50 3.00
13 SODA SPRINGS T/D -Unattended 6.55 115.00 2.00
14 SOUTH GATE T/D -Unattended 69.00 20.80 1.00
15 STATE STREET T/D -Unattended 115.00 20.80 2.00
16 STAYTON T/D -Unattended 69.00 20.80 2.00
17 SWEET HOME T/D -Unattended 115.00 20.80 2.00
18 TAKELMA T/D -Unattended 115.00 20.80 1.00
19 TALENT T/D -Unattended 69.00 12.50 1.00
20 TUCKER T/D -Unattended 115.00 69.00 2.00
21 UMATILLA T/D -Unattended 69.00 12.50 2.00
22 VERNON TID -Unattended 69.00 12.47 2.00
23 VILLAGE GREEN T/D -Unattended 115.00 20.80 2.00
24 VINE STREET T/D -Unattended 20.80 69.00 1.00
25 WALLOWA TID -Unattended 69.00 12.50 1.00
26 WARM SPRINGS T/D -Unattended 20.80 69.00 1.00
27 WESTERN KRAFT T/D -Unattended 115.00 12.50 2.00
28 WESTON NEW T/D -Unattended 69.00 12.50 2.00
29 WEYERHAEUSER T/D -Unattended 69.00 12.50 2.00
30 WHITE CITY T/D -Unattended 115.00 12.50 3.00
31 WILLOW COVE T/D -Unattended 34.50 4.16 3.00
32 WINCHESTER T/D -Unattended 115.00 69.00 3.00
33 TOTAL 10782.15 2739.70 210.00
34 NUMBER OF SUBSTATIONS T/D -116
35
36 BEND Transmission -Atte 69.00 12.47 2.00
37 DIXONVILLE 230KV Transmission -Atte 230.00 115.00 4.00
38 DIXONVILLE 500KV Transmission -Atte 500.00 230.00 1.00
39 KLAMATH FALLS Transmission -Atte 230.00 69.00 2.00
40 LONE PINE (NEW)Transmission -Atte 230.00 115.00 3.00
FERC FORM NO.1 (ED.12-96)Page 426.8
Name of Respondent This Re ort Is.Date of Report Year of Report(1)X An Original (Mo,Da,Yr)1PacifiCorpDec.31,200(2)A Resubmission //
SUBSTATIONS (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 APPARATL S AND SPECIAL EDUIPMENT Line
(In Service)(In MVa)Tran
e
ceeæ TranSarrreers Type of Equipment Number of Units Tot CMapaacityNo.
(f)(g)(h)(i)(j)(k)
6 6 1
2 2 2
1 1 3
2 2 4
2 2 5
1 1 6
2 2 7
2 2 8
2 2 9
3 3 10
1 1 11
3 3 12
2 2 13
1 1 14
2 2 15
2 2 16
2 2 17
1 1 18
1 1 19
2 2 20
2 2 21
2 2 22
2 2 23
1 1 24
1 1 25
1 1 26
2 2 27
2 2 28
2 2 29
3 3 30
3 3 31
3 3 32
210 210 33
34
35
2 2 36
4 4 37
1 1 38
2 2 39
3 3 40
FERC FORM NO.1 (ED.12-96)Page 427.8
Name of Respondent This Re ort is:Date of Report Year of Report
PacifiCorp (1)X An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
SUBSTATIONS
1.Report below the information called for concerning substations of the respondent as of the end of the year.
2.Substations which serve only one industrial or street railway customer should not be listed below.
3.Substations with capacities of Less than 10 MVa except those serving customers with energy for resale,may be grouped according
to functional character,but the number of such substations must be shown.
4.Indicate in column (b)the functional character of each substation,designating whether transmission or distribution and whether
attended or unattended.At the end of the page,summarize according to function the capacities reported for the individual stations in
column (f).
Line V3LTAGE (In MVa)
No.Name and Location of Substation Character of Substation Primary Secondary Tertiary
(a)(b)(c)(d)(e)
1 LONE PINE (OLD)Transmission -Atte 115.00 69.00 3.00
2 MALIN Transmission -Atte 500.00 230.00 2.00
3 PROSPECT CENTRAL Transmission -Atte 2.30 69.00 2.00
4 TOKETEE Transmission -Atte 6.90 115.00 3.00
5 BROOKS-SCANLON LBR Transmission -Unat 12.50 69.00 1.00
6 CALAPOOYA Transmission -Unat 230.00 69.00 1.00
7 COLD SPRINGS Transmission -Unat 230.00 69.00 1.00
8 COVE Transmission -Unat 230.00 69.00 3.00
9 DALREED Transmission -Unat 230.00 34.50 4.00
10 DAYS CREEK Transmission -Unat 115.00 69.00 1.00
11 DIAMOND HILL Transmission -Unat 230.00 69.00 1.00
12 FISH CREEK Transmission -Unat 6.55 115.00 1.00
13 FISHHOLE Transmission -Unat 115.00 69.00 1.00
14 FRY Transmission -Unat 230.00 115.00 2.00
15 GRANTS PASS Transmission -Unat 230.00 115.00 5.00
16 GREEN SPRINGS PLANT Transmission -Unat .125.00 71.00 1.00
17 HAZELWOOD Transmission -Unat 115.00 69.00 2.00
18 HURRICANE Transmission -Unat 230.00 69.00 1.00
19 ISTHMUS Transmission -Unat 230.00 115.00 1.00
20 KENNEDY Transmission -Unat 69.00 57.00 1.00
21 MERIDIAN 500 KV Transmission -Unat 500.00 230.00 1.00
22 MONPAC Transmission -Unat 115.00 69.00 1.00
23 PILOT BUTTE Transmission -Unat 230.00 69.00 3.00
24 PONDEROSA Transmission -Unat 230.00 115.00 1.00
25 REDMOND Transmission -Unat 12.50 115.00 2.00
26 ROBERTS CREEK Transmission -Unat 115.00 69.00 1.00
27 ROUNDUP Transmission -Unat 230.00 69.00 1.00
28 SLIDE CREEK Transmission -Unat 6.55 115.00 1.00
29 TROUTDALE Transmission -Unat 230.00 115.00 3.00
30 WILLOW CREEK Transmission -Unat 69.00 34.50 1.00
31 TOTAL 6249.30 3268.47 64.00
32 NUMBER OF SUBSTATIONS TRANSMISSIONS -35
33
34 UTAH
35 EAST MILL CREEK Distribution 43.80 12.47 1.00
36 MCCORNICK IRRIGATION Distribution 46.00 12.50 1.00
37 MYTON Distribution 69.00 12.50 1.00
38 ALTAVIEW Distribution -Unat 46.00 12.00 2.00
39 AMALGA Distribution -Unat 46.00 12.47 1.00
40 AMERICAN FORK Distribution -Unat 43.80 12.47 1.00
FERC FORM NO.1 (ED.12-96)Page 426.9
Name of Respondent This Re ort Is:Date of Report Year of Report(1)An Original (Mo,Da,Yr)PacifiCorp Dec.31,2001(2)A Resubmission //
SUBSTATIONS (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 SPECIAL EDUIPMENT Line
(In Service)(In MVa)Transfeoeers TranSsoarrreers Type of Equipment Number of Units Tot CMapacity No.
(f)(g)(h)(i)(j)(k)
3 3 1
2 2 2
2 2 3
3 3 4
1 1 5
1 1 6
1 1 7
3 3 8
4 4 9
1 1 10
1 1 11
1 1 12
1 1 13
2 2 14
5 5 15
1 1 16
2 2 17
1 1 18
1 1 19
1 1 20
1 1 21
1 1 22
3 3 23
1 1 24
2 2 25
1 1 26
1 1 27
1 1 28
3 3 29
1 1 30
64 64 31
32
33
34
1 1 35
1 1 36
1 1 37
2 2 38
1 1 39
1 1 40
FERC FORM NO.1 (ED.12-96)Page 427.9
Name of Respondent This Re ort is:Date of Report Year of Report
PacifiCorp (1)X An Original (Mo,Da,Yr)Dec.31,2001
(2)A Resubmission //
SUBSTATIONS
1.Report below the information called for concerning substations of the respondent as of the end of the year.
2.Substations which serve only one industrial or street railway customer should not be listed below.
3.Substations with capacities of Less than 10 MVa except those serving customers with energy for resale,may be grouped according
to functional character,but the number of such substations must be shown.
4.Indicate in column (b)the functional character of each substation,designating whether transmission or distribution and whether
attended or unattended.At the end of the page,summarize according to function the capacities reported for the individual stations in
column (f).
Line V3LTAGE (In MVa)
No Name and Location of Substation Character of Substation Primary Secondary Tertiary
(a)(b)(c)(d)(e)
1 ARAGONITE Distribution -Unat 138.00 12.47 1.00
2 AURORA Distribution -Unat 42.90 12.40
3 BEAR RIVER Distribution -Unat 43.80 12.47 2.00
4 BENJAMIN Distribution -Unat 44.00 12.47
5 BINGHAM Distribution -Unat 43.80 12.47
6 BLUE CREEK Distribution -Unat 46.00 12.47
7 BLUFF Distribution -Unat 69.00 12.47 3.00
8 BLUFFDALE Distribution -Unat 43.80 12.47 1.00
9 BOTHWELL Distribution -Unat 42.90 12.47 1.00
10 BOX ELDER Distribution -Unat 42.90 12.47 2.00
11 BRIAN HEAD Distribution -Unat 34.50 12.47 1.00
12 BRICKYARD Distribution -Unat 43.80 12.47 1.00
13 BRIGHTON Distribution -Unat 43.80 24.90 1.00
14 BROOKLAWN CREAMERY Distribution -Unat 46.00 12.47 1.00
15 BRUNSWICK Distribution -Unat 43.80 12.47 3.00
16 BUSH Distribution -Unat 43.80 12.47 1.00
17 BUTLERVILLE Distribution -Unat 43.80 12.47 2.00
18 CAMERON Distribution -Unat 138.00 46.00 1.00
19 CAMP WILLIAMS Distribution -Unat 138.00 12.47 1.00
20 CANNON Distribution -Unat 43.80 12.47 1.00
21 CANYONLANDS Distribution -Unat 69.00 12.47 3.00
22 CAPITOL Distribution -Unat 43.80 12.47 1.00
23 CARBlDE Distribution -Unat 67.00 12.50 1.00
24 CARBONVILLE Distribution -Unat 43.80 12.47 1.00
25 CASTO Distribution -Unat 43.80 12.47 1.00
26 CEDAR NORTH Distribution -Unat 34.50 4.20 1.00
27 CENTENNIAL Distribution -Unat 138.00 12.47 1.00
28 CENTERVILLE Distribution -Unat 43.80 12.47 1.00
29 CENTRAL Distribution -Unat 42.90 12.47
30 CHAPARRAL Distribution -Unat 46.00 2.40
31 CHERRYWOOD Distribution -Unat 132.00 12.47
32 CIRCLEVILLE Distribution -Unat 67.00 12.47 1.00
33 CLEAR CREEK Distribution -Unat 43.80 12.47 1.00
34 CLEAR LAKE Distribution -Unat 44.00 12.50 3.00
35 CLEARFIELD Distribution -Unat 43.80 12.47 2.00
36 CLINTON Distribution -Unat 132.00 12.70 1.00
37 CLIVE Distribution -Unat 42.90 12.47 1.00
38 COALVILLE Distribution -Unat 43.80 24.90 2.00
39 COLLEGE Distribution -Unat 42.90 24.00 2.00
40 COLTON WELL Distribution -Unat 46.00 12.50 3.00
FERC FORM NO.1 (ED.12-96)Page 426.10
Name of Respondent This Re ort Is:Date of Report Year of Report
PacifiCorp (1)X An Original (Mo,Da,Yr)Dec.31,2001 i(2)A Resubmission //
SUBSTATIONS (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 othenNÍSe 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 APPARATES AND SPECIAL EDUIPMENT Line
(In Service)(In MVa)Trlansfeorreers TranSsoar
ers Type of Equipment Number of Units Tot CMapacity No.
(f)(g)(h)(i)(j)(k)
1 1 1
2
2 2 3
4
5
6
3 3 7
1 1 8
1 1 9
2 2 10
1 1 11
1 1 12
1 1 13
1 1 14
3 3 15
1 1 16
2 2 17
1 1 18
1 1 19
1 1 20
3 3 21
1 1 22
1 1 23
1 1 24
1 1 25
1 1 26
1 1 27
1 1 28
29
30
31
1 1 32
1 1 33
3 3 34
2 2 35
1 1 36
1 1 37
2 2 38
2 2 39
3 3 40
FERC FORM NO.1 (ED.12-96)Page 427.10
Name of Respondent This Re ort Is:Date of Report Year of Report
PacifiCorp (1)X An Original (Mo,Da,Yr)Dec.31,2001
(2)A Resubmission //
SUBSTATIONS
1.Report below the information called for concerning substations of the respondent as of the end of the year.
2.Substations which serve only one industrial or street railway customer should not be listed below.
3.Substations with capacities of Less than 10 MVa except those serving customers with energy for resale,may be grouped according
to functional character,but the number of such substations must be shown.
4.Indicate in column (b)the functional character of each substation,designating whether transmission or distribution and whether
attended or unattended.At the end of the page,summarize according to function the capacities reported for the individual stations in
column (f).
Line V3LTAGE (In M Ja)
No.Name and Location of Substation Character of Substation Primary Secondary Tertiary
(a)(b)(c)(d)(e)
1 COLUMBIA Distribution -Unat 138.00 45.00 1.00
2 CORINNE Distribution -Unat 42.90 12.47
3 COVE FORT Distribution -Unat 43.80 12.47 3.00
4 CRESCENT JUNCTION Distribution -Unat 46.00 12.50 1.00
5 CUDAHY Distribution -Unat 132.00 12.47
6 DAIRY FORK Distribution -Unat 46.00 12.50 1.00
7 DAMMERON VALLEY Distribution -Unat 67.00 12.47
8 DECKER LAKE Distribution -Unat 138.00 12.47 1.00
9 DELLE Distribution -Unat 43.80 12.47 1.00
10 DELTA Distribution -Unat 43.80 12.47
11 DESERET Distribution -Unat 42.90 4.16 1.00
12 DEWEYVILLE Distribution -Unat 42.90 12.47 1.00
13 DIMPLE DELL Distribution -Unat 138.00 12.50 1.00
14 DIXIE DEER Distribution -Unat 34.50 12.47 1.00
15 DOG VALLEY Distribution -Unat 46.00 12.50
16 DRAGERTON Distribution -Unat 43.80 12.47 1.00
17 DRAPER Distribution -Unat 43.80 12.47 2.00
18 DUMAS Distribution -Unat 138.00 12.47 1.00
19 EAST BENCH Distribution -Unat 43.80 4.16 1.00
20 EAST HYRUM Distribution -Unat 43.80 12.47 1.00
21 EAST PROVO Distribution -Unat 46.00 12.50 3.00
22 EDEN Distribution -Unat 43.80 12.47 2.00
23 EL MONTE Distribution -Unat 132.00 45.00
24 ELBERTA Distribution -Unat 46.00 12.50 1.00
25 ELK MEADOWS Distribution -Unat 42.90 12.40 3.00
26 ELSINORE Distribution -Unat 44.00 12.47 1.00
27 EMERY CITY Distribution -Unat 69.00 12.47 3.00
28 EMIGRATION Distribution -Unat 43.80 12.47 3.00
29 EMMA PARK Distribution -Unat 132.00 12.47 1.00
30 ENTERPRISE VALLEY Distribution -Unat
31 EUREKA Distribution -Unat 46.00 12.50 3.00
32 FARMINGTON Distribution -Unat 43.80 12.47 3.00
33 FAYETTE Distribution -Unat 43.80 12.47 2.00
34 FERRON Distribution -Unat 69.00 12.50 3.00
35 FIDDLER'S CANYON Distribution -Unat 34.50 12.50
36 FIELDING Distribution -Unat 44.00 12.47 1.00
37 FIFTH WEST Distribution -Unat 132.00 12.47 1.00
38 FLUX Distribution -Unat 42.90 12.47 1.00
39 FOOL CREEK Distribution -Unat 42.90 12.47 1.00
40 FOUNTAIN GREEN Distribution -Unat
FERC FORM NO.1 (ED.12-96)Page 426.11
Name of Respondent This Report is:Date of Report Year of Report
(1)[¯]XAn Original (Mo,Da,Yr)PacifiCorp Dec.31,2001
(2)[¯]A Resubmission //
SUBSTATIONS (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 padies,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 APPARATES AND SPECIAL EDUIPMENT Line
(In Service)(in MVa)Transfe ceers TranSsoarrreers Type of Equipment Number of Units Tot CMapaacityNo.
(f)(g)(h)(i)(j)(k)
1 1 1
2
3 3 3
1 1 4
5
1 1 6
7
1 1 8
1 1 9
10
1 1 11
1 1
12
1 1 13
1 1 14
15
1 1 16
2 2 17
1 1 18
1 1 19
1 1 20
3 3 21
2 2 22
23
1 1 24
3 3 25
1 1 26
3 3 27
3 3 28
1 1 29
30
3 3 31
3 3 32
2 2 33
3 3 34
35
1 1 36
1 1 37
1 1 38
1 1 39
40
FERC FORM NO.1 (ED.12-96)Page 427.11
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)X An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
SUBSTATIONS
1.Report below the information called for concerning substations of the respondent as of the end of the year.
2.Substations which serve only one industrial or street railway customer should not be listed below.
3.Substations with capacities of Less than 10 MVa except those serving customers with energy for resale,may be grouped according
to functional character,but the number of such substations must be shown.
4.Indicate in column (b)the functional character of each substation,designating whether transmission or distribution and whetherattendedorunattended.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 FREEDOM Distribution -Unat 45.00 12.47
2 FREEPORT Distribution -Unat 46.00 7.20 3.00
3 FRUIT HEIGHTS Distribution -Unat 43.80 12.47 1.00
4 GARDEN CITY Distribution -Unat 67.00 12.47 1.00
5 GARKANE INTERTIE Distribution -Unat 68.50 46.00
6 GATEWAY Distribution -Unat 69.00 34.50
7 GENEVA Distribution -Unat 132.00 13.80
8 GOSHEN (UTAH)Distribution -Unat 46.00 12.47 1.00
9 GRANTSVILLE Distribution -Unat 43.80 12.47 1.00
10 GRAVEL PIT Distribution -Unat 46.00 12.47
11 GREEN CANYON Distribution -Unat 132.00 45.00
12 GREEN RIVER Distribution -Unat 46.00 12.50 2.00
13 GRINDING Distribution -Unat 138.00 13.80
14 GROW Distribution -Unat 132.00 46.00
15 GUNNISON Distribution -Unat 45.00 50.00
16 HALE Distribution -Unat 43.80 12.47 1.00
17 HAMILTON FORT Distribution -Unat 34.00 12.47
18 HAMMER Distribution -Unat 138.00 12.47
19 HATCH Distribution -Unat 138.00 69.00
20 HAVASU Distribution -Unat 69.00 24.94 3.00
21 HELPER Distribution -Unat 120.00 45.00
22 HELPER CITY Distribution -Unat 45.00 4.16 3.00
23 HENEFER Distribution -Unat 43.50 12.47 3.00
24 HIAWATHA Distribution -Unat 44.00 24.00 3.00
25 HINKLEY Distribution -Unat 43.80 12.47
26 HOGGARD Distribution -Unat 132.00 12.47 1.00
27 HOGLE Distribution -Unat 43.80 12.47 1.00
28 HONEYVILLE Distribution -Unat 132.00 46.00 1.00
29 HURRICANE BENCH Distribution -Unat 69.00 12.50
30 HURRICANE FIELDS Distribution -Unat 34.20 12.00 1.00
31 IRONTON Distribution -Unat 46.00 12.47 3.00
32 IVINS Distribution -Unat 34.40 12.47
33 JUAB Distribution -Unat 43.50 12.47 3.00
34 JUNCTION Distribution -Unat 69.00 12.47 3.00
35 KAIBAB Distribution -Unat 67.00 12.47
36 KAMAS Distribution -Unat 43.80 12.47 1.00
37 KANARAVILLE Distribution -Unat 34.40 12.47 3.00
38 KEARNS Distribution -Unat 43.80 12.47 2.00
39 KENSINGTON Distribution -Unat 43.80 4.16 1.00
40 KYUNE Distribution -Unat 46.00 7.20 2.00
FERC FORM NO.1 (ED.12-96)Page 426.12
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
SUBSTATIONS (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 EDUIPMENT Line
(in Service)(In MVa)Transfeoeers TranS ar
ers Type of Equipment Number of Units Tot CMapaacityNo.
(f)(g)(h)(i)(j)(k)
1
3 3 2
1 1 3
1 1 4
5
6
7
1 1 8
1 1 9
10
11
2 2 12
13
14
15
1 1 16
17
18
19
3 3 20
21
3 3 22
3 3 23
3 3 24
25
1 1 26
1 1 27
1 1 28
29
1 1 30
3 3 31
32
3 3 33
3 3 34
35
1 1 36
3 3 37
2 2 38
1 1 39
2 2 40
FERC FORM NO.1 (ED.12-96)Page 427.12
Name of Respondent This Re ort Is:Date of Report Year of Report
PacifiCorp (1)X An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
SUBSTATIONS
1.Report below the information called for concerning substations of the respondent as of the end of the year.
2.Substations which serve only one industrial or street railway customer should not be listed below.
3.Substations with capacities of Less than 10 MVa except those serving customers with energy for resale,may be grouped according
to functional character,but the number of such substations must be shown.
4.Indicate in column (b)the functional character of each substation,designating whether transmission or distribution and whether
attended or unattended.At the end of the page,summarize according to function the capacities reported for the individual stations in
column (f).
Line V3LTAGE (In M Ja)
No Nameand Location of Substation Character of Substation Primary Secondary Tertiary
(a)(b)(c)(d)(e)
1 LAKE POINT Distribution -Unat 42.90 12.47 1.00
2 LAKEPARK Distribution -Unat 132.00 12.47
3 LAMPO Distribution -Unat 138.00 46.00
4 LARK Distribution -Unat 42.90 12.47 1.00
5 LASAL Distribution -Unat 67.00 12.50 1.00
6 LAYTON Distribution -Unat 43.80 12.47 2.00
7 LA-Z-BOY Distribution -Unat 43.80 12.47 1.00
8 LE GRANDE Distribution -Unat 43.80 12.47 3.00
9 LEWISTON Distribution -Unat 43.80 12.47 1.00
10 LINDON Distribution -Unat 46.00 12.47 1.00
11 LISBON Distribution -Unat 67.00 12.50 1.00
12 LOAFER Distribution -Unat 46.00 12.50 1.00
13 LOGAN CANYON Distribution -Unat 46.00 7.20 1.00
14 LONETREE Distribution -Unat 34.50 19.90
15 LOST CREEK Distribution -Unat 46.20 7.20 1.00
16 LOWER BEAVER Distribution -Unat 44.00 12.00 3.00
17 LYNNDYL Distribution -Unat 43.90 12.50 1.00
18 MAESER Distribution -Unat 67.00 12.47 1.00
19 MANTUA Distribution -Unat 45.00 24.00 3.00
20 MAPLETON Distribution -Unat 46.00 12.50 3.00
21 MARRIOTT Distribution -Unat 46.00 12.50 1.00
22 MARYSVALE Distribution -Unat 43.70 9.10 3.00
23 MATHIS Distribution -Unat 43.80 12.47 1.00
24 MCKAY Distribution -Unat 43.80 12.47 1.00
25 MEADOWBROOK Distribution -Unat 46.00 12.00 1.00
26 MEDICAL Distribution -Unat 46.00 12.00 4.00
27 MELLING Distribution -Unat 34.40 4.20 1.00
28 MIDVALE Distribution -Unat 43.80 12.47 1.00
29 MIDWAY Distribution -Unat 132.00 45.00
30 MILFORD Distribution -Unat 42.90 12.47
31 MILFORD Distribution -Unat 46.00 7.20
32 MILLS Distribution -Unat 44.00 7.20 2.00
33 MILLVILLE Distribution -Unat 43.80 12.47 1.00
34 MINERAL PRODUCTS Distribution -Unat 69.00 46.00
35 MINERSVILLE Distribution -Unat 44.00 12.47 3.00
36 MOAB CITY Distribution -Unat 67.00 12.50
37 MONTEZUMA Distribution -Unat 69.00 12.40 1.00
38 MOORE Distribution -Unat 69.00 12.50 1.00
39 MORGAN Distribution -Unat 42.90 12.47 3.00
40 MORONI Distribution -Unat 43.80 12.47 1.00
FERC FORM NO.1 (ED.12-96)Page 426.13
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)X An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
SUBSTATIONS (Continued)
5.Show in columns (l),(j),and (k)special equipment such as rotary converters,rectifiers,condensers,etc.and auxiliary equipment for
increasing capacity.
6.Designate substations or major items of equipment leased from others,jointly owned with others,or operated otherwise than 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 E]UIPMENT Line
(In Service)(In MVa)Transfeo rs TranSsoarrreers Type of Equipment Number of Units Tot CMapacity No.
(f)(g)(h)(i)(j)(k)
1 1 1
2
3
1 1 4
1 1 5
2 2 6
1 1 7
3 3 8
1 1 9
1 1 10
1 1 11
1 1 12
1 1 13
14
1 1 15
3 3 16
1 1 17
1 1 18
3 3 19
3 3 20
1 1 21
3 3 22
1 1 23
1 1 24
1 1 25
4 4 26
1 1 27
1 1 28
29
30
31
2 2 32
1 1 33
34
3 3 35
36
1 1 37
1 1 38
3 3 39
1 1 40
FERC FORM NO.1 (ED.12-96)Page 427.13
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)§An Original (Mo,Da,Yr)Dec.31,2001
(2)A Resubmission I /
SUBSTATIONS
1.Report below the information called for concerning substations of the respondent as of the end of the year.
2.Substations which serve only one industrial or street railway customer should not be listed below.
3.Substations with capacities of Less than 10 MVa except those serving customers with energy for resale,may be grouped according
to functional character,but the number of such substations must be shown.
4.Indicate in column (b)the functional character of each substation,designating whether transmission or distribution and whether
attended or unattended.At the end of the page,summarize according to function the capacities reported for the individual stations in
column (f).
Line V3LTAGE (In MVa)
No Name and Location of Substation Character of Substation Primary Secondary Tertiary
(a)(b)(c)(d)(e)
1 MOSS JUNCTION Distribution -Unat 42.00 12.47 3.00
2 MOUNTAIN DELL Distribution -Unat 43.80 12.40 1.00
3 MOUNTAIN GREEN Distribution -Unat 43.80 12.47 1.00
4 NEBO Distribution -Unat 138.00 46.00 1.00
5 NEW HARMONY Distribution -Unat 69.00 12.47 1.00
6 NEW LAVERKIN Distribution -Unat 69.00 12.47
7 NEWGATE Distribution -Unat 43.80 12.47 1.00
8 NEWTON Distribution -Unat 43.80 12.47 1.00
9 NIBLEY Distribution -Unat 43.80 12.47 1.00
10 NORTH BENCH Distribution -Unat 43.80 12.47 3.00
11 NORTH FIELDS Distribution -Unat 42.90 12.47 1.00
12 NORTH HOLDEN IRRIGATION Distribution -Unat 46.00 12.47 1.00
13 NORTH LOGAN Distribution -Unat 43.80 12.47 1.00
14 NORTH OGDEN Distribution -Unat 43.80 12.47 1.00
15 NORTH SALT LAKE Distribution -Unat 43.80 12.47 1.00
16 NORTHEAST Distribution -Unat 41.80 12.47
17 NORTHRIDGE Distribution -Unat 46.00 12.47 1.00
18 OAK SPRINGS Distribution -Unat 46.00 7.22
19 OAKLAND AVENUE Distribution -Unat 43.80 12.47 2.00
20 OAKLEY Distribution -Unat 42.90 12.47 1.00
21 OCKEY Distribution -Unat 46.00 7.20 1.00
22 OLYMPUS Distribution -Unat 43.80 12.47 1.00
23 OPHIR Distribution -Unat 42.90 12.47 1.00
24 ORANGE Distribution -Unat 43.80 12.47 3.00
25 ORANGEVILLE Distribution -Unat 69.00 12.47 1.00
26 OREM Distribution -Unat 43.80 12.47 2.00
27 PANGUITCH Distribution -Unat 67.00 12.47 1.00
28 PARIETTE Distribution -Unat 43.80 25.00 1.00
29 PARK CITY Distribution -Unat 43.80 12.47 2.00
30 PARKWAY Distribution -Unat 132.00 12.47 1.00
31 PARLEYS Distribution -Unat 43.80 12.47 2.00
32 PARRISH Distribution -Unat 138.00 46.00
33 PARRY Distribution -Unat 44.00 4.16 4.00
34 PELICAN POINT Distribution -Unat 46.00 12.50 3.00
35 PINE CREEK Distribution -Unat 43.90 12.47 1.00
36 PINNACLE Distribution -Unat 46.00 12.47 1.00
37 PLEASANT GROVE Distribution -Unat 43.10 12.47 1.00
38 PLEASANT VIEW Distribution -Unat 43.80 12.47 1.00
39 PRICE Distribution -Unat 43.80 72.00 4.00
40 PROLER Distribution -Unat 46.00 2.40 1.00
FERC FORM NO.1 (ED.12-96)Page 426.14
Name of Respondent This Re ort Is:Date of Report Year of Report(1)X An Original (Mo,Da,Yr)20 1PacifiCorpDec.31,O(2)A Resubmission //
SUBSTATIONS (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 EDUIPMENT LineIance
ic )
Transfeo rs TranSsoar
ers Type of Equipment Number of Units Total CMapaacityNo.
(f)(g)(h)(i)(j)(k)
3 3 1
1 1 2
1 1 3
1 1 4
1 1 5
6
1 1 7
1 1 8
1 1 9
3 3 10
1 1 11
1 1 12
1 1 13
1 1 14
1 1 15
16
1 1 17
18
2 2 19
1 1 20
1 1 21
1 1 22
1 1 23
3 3 24
1 1 25
2 2 26
1 1 27
1 1 28
2 2 29
1 1 30
2 2 31
32
4 4 33
3 3 34
1 1 35
1 1 36
1 1 37
1 1 38
4 4 39
1 1 40
FERC FORM NO.1 (ED.12-96)Page 427.14
Name of Respondent This Re ort Is:Date of Report Year of Report
PacifiCorp (1)X An Original (Mo,Da,Yr)Dec.31,2001
(2)A Resubmission //
SUBSTATIONS
1.Report below the information called for concerning substations of the respondent as of the end of the year.
2.Substations which serve only one industrial or street railway customer should not be listed below.
3.Substations with capacities of Less than 10 MVa except those serving customers with energy for resale,may be grouped according
to functional character,but the number of such substations must be shown.
4.Indicate in column (b)the functional character of each substation,designating whether transmission or distribution and whether
attended or unattended.At the end of the page,summarize according to function the capacities reported for the individual stations in
column (f).
Line V3LTAGE (in MVa)
No.Name and Location of Substation Character of Substation Primary Secondary Tertiary
(a)(b)(c)(d)(e)
1 PROMONTORY Distribution -Unat 44.00 12.47 3.00
2 QUAIL CREEK Distribution -Unat 34.50 12.47
3 QUARRY Distribution -Unat 46.00 12.47 2.00
4 QUITCHAPA Distribution -Unat 34.50 12.47 3.00
5 RAINS#2 Distribution -Unat 45.00 7.20 3.00
6 RANDOLPH Distribution -Unat 44.00 12.50 1.00
7 RASMUSSON Distribution -Unat 44.00 12.47 3.00
8 RATTLESNAKE Distribution -Unat 67.00 24.94 1.00
9 RED BUTTE Distribution -Unat 69.00 12.50
10 RED NARROWS Distribution -Unat 46.00 12.50 1.00
11 RED ROCK Distribution -Unat 69.00 4.16 1.00
12 RESEARCH PARK Distribution -Unat 43.80 12.47 1.00
13 RICH Distribution -Unat 67.00 12.47 1.00
14 RICHFIELD Distribution -Unat 43.80 12.47 2.00
15 RICHMOND Distribution -Unat 43.80 12.47 1.00
16 RIDGELAND Distribution -Unat .138.00 12.47 2.00
17 RIDING RECEIVING Distribution -Unat 138.00 46.00
18 RITER Distribution -Unat 43.80 12.47 1.00
19 ROSE PARK Distribution -Unat 43.80 12.47 3.00
20 ROUND VALLEY Distribution -Unat 46.00 7.20
21 ROWLEY Distribution -Unat 132.00 13.80 1.00
22 ROYAL Distribution -Unat 46.00 12.50 3.00
23 SALINA Distribution -Unat 43.80 12.47 3.00
24 SANDY Distribution -Unat 43.80 12.47 1.00
25 SANPITCH Distribution -Unat 45.00 7.20
26 SANTAQUIN Distribution -Unat 46.00 12.50 1.00
27 SARATOGA Distribution -Unat 43.80 12.47 1.00
28 SCIPIO Distribution -Unat 42.00 7.20 3.00
29 SCOFIELD Distribution -Unat 46.00 12.50 3.00
30 SCOFIELD RESERVOIR Distribution -Unat 46.00 12.50 1.00
31 SECOND STREET Distribution -Unat 43.80 12.47 2.00
32 SEVENMILE Distribution -Unat 69.00 12.47 3.00
33 SEVIER Distribution -Unat 132.00 7.20
34 SHARON Distribution -Unat 43.80 12.47 1.00
35 SILVER CREEK Distribution -Unat 134.50 46.00 1.00
36 SINK Distribution -Unat 44.00 6.60 1.00
37 SKULL VALLEY Distribution -Unat 41.80 12.47 1.00
38 SMITHFIELD Distribution -Unat 132.00 45.00
39 SNARR Distribution -Unat 43.80 12.47 3.00
40 SNYDERVILLE Distribution -Unat 43.80 12.47 1.00
FERC FORM NO.1 (ED.12-96)Page 426.15
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)DX An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
SUBSTATIONS (Continued)
5.Show in columns (l),(j),and (k)special equipment such as rotary converters,rectifiers,condensers,etc.and auxiliary equipment for
increasing capacity.
6.Designate substations or major items of equipment leased from others,jointly owned with others,or operated otherwise than 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 APPARATES AND SPECIAL EDUIPMENT Line
(in Service)(In MVa)Tran
e
cee TranS arœers Type of Equipment Number of Units Tot CMapaacityNo.
(f)(g)(h)(i)(j)(k)
3 3 1
2
2 2 3
3 3 4
3 3 5
1 1 6
3 3 7
1 1 8
9
1 1 10
1 1 11
1 1 12
1 1 13
2 2 14
1 1 15
2 2 16
17
1 1 18
3 3 19
20
1 1 21
3 3 22
3 3 23
1 1 24
25
1 1 26
1 1 27
3 3 28
3 3 29
1 1 30
2 2 31
3 3 32
33
1 1 34
1 1 35
1 1 36
1 1 37
38
3 3 39
1 1 40
FERC FORM NO.1 (ED.12-96)Page 427.15
Name of Respondent This Re ort Is:Date of Report Year of Report
PacifiCorp (1)X An Original (Mo,Da,Yr)Dec.31,2001
(2)A Resubmission //
SUBSTATIONS
1.Report below the information called for concerning substations of the respondent as of the end of the year.
2.Substations which serve only one industrial or street railway customer should not be listed below.
3.Substations with capacities of Less than 10 MVa except those serving customers with energy for resale,may be grouped according
to functional character,but the number of such substations must be shown.
4.Indicate in column (b)the functional character of each substation,designating whether transmission or distribution and whether
attended or unattended.At the end of the page,summarize according to function the capacities reported for the individual stations in
column (f).
Line VOLTAGE (In MVa)
No Name and Location of Substation Character of Substation Primary Secondary Tertiary
(a)(b)(c)(d)(e)
1 SOLDIER SUMMIT Distribution -Unat 46.00 12.50 2.00
2 SOUTH GRANGER Distribution -Unat 43.80 12.47
3 SOUTH MILFORD IRRIGATION Distribution -Unat 43.80 12.47 1.00
4 SOUTH MOUNTAIN Distribution -Unat 138.00 12.47
5 SOUTH OGDEN Distribution -Unat 43.80 12.47 2.00
6 SOUTH YARD Distribution -Unat 46.00 4.16 1.00
7 SOUTHEAST Distribution -Unat 46.50 12.47 4.00
8 SOUTHPARK Distribution -Unat 43.80 12.47 1.00
9 SOUTHWEST Distribution -Unat 43.80 12.47 1.00
10 SPANISH VALLEY Distribution -Unat 69.00 12.50 1.00
11 SPRINGDALE Distribution -Unat 34.50 12.47
12 ST.JOHN Distribution -Unat 42.90 12.47 1.00
13 STANSBURY Distribution -Unat 43.80 12.47 3.00
14 SUMMIT PARK Distribution -Unat 43.80 12.47 3.00
15 SUNSTONE Distribution -Unat 43.80 7.20
16 SUPERIOR Distribution -Unat 67.00 12.40 1.00
17 SUTHERLAND Distribution -Unat 43.80 24.90 1.00
18 SWISS Distribution -Unat 44.00 12.47 1.00
19 TABIONA Distribution -Unat 66.00 11.95 1.00
20 TAYLOR Distribution -Unat 43.80 12.47 1.00
21 THIEF CREEK Distribution -Unat 132.00 25.00 1.00
22 THIRD WEST Distribution -Unat 43.80 12.47 2.00
23 THIRTEENTH SOUTH Distribution -Unat 41.80 12.47 2.00
24 THISTLE Distribution -Unat 46.00 12.47 1.00
25 THOMPSON Distribution -Unat 45.00 7.20 1.00
26 TIMP Distribution -Unat 130.00 46.00
27 TWENTY THIRD STREET OGDEN Distribution -Unat 43.80 4.16 3.00
28 UINTAH Distribution -Unat 43.80 12.47 2.00
29 UNION Distribution -Unat 43.80 12.47 2.00
30 UNIVERSITY Distribution -Unat 43.80 12.47 5.00
31 UPALCO Distribution -Unat 138.00 69.00
32 UTE Distribution -Unat 69.00 7.20 1.00
33 VALLEY CENTER Distribution -Unat 43.80 12.47 1.00
34 VERMILLION Distribution -Unat 46.00 12.47 1.00
35 VERNAL Distribution -Unat 67.00 12.47 2.00
36 VICKERS Distribution -Unat 44.00 12.47 1.00
37 VINEYARD Distribution -Unat 46.00 12.47 1.00
38 WALLSBURG Distribution -Unat 132.00 12.47 1.00
39 WARREN Distribution -Unat 132.00 12.47
40 WASATCH Distribution -Unat 41.80 12.74 1.00
FERC FORM NO.1 (ED.12-96)Page 426.16
Name of Respondent This Report is:Date of Report Year of Report
PacifiCorp (1)X An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
SUBSTATIONS (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 CONVERSION APPARATL S AND SPECIAL E3UIPMENT Line
(In Service)(In MVa)Transfe ceers TranSsoar
ers Type of Equipment Number of Units IDI Mapaacity No.
(f)(g)(h)(i)(j)(k)
2 2 1
2
1 1 3
4
2 2 5
1 1 6
4 4 7
1 1 8
1 1 9
1 1 10
11
1 1 12
3 3 13
3 3 14
15
1 1 16
1 1 17
1 1 18
1 1 19
1 1 20
1 1 21
2 2 22
2 2 23
1 1 24
1 1 25
26
3 3 27
2 2 28
2 2 29
5 5 30
31
1 1 32
1 1 33
1 1 34
2 2 35
1 1 36
1 1 37
1 1 38
39
1 1 40
FERC FORM NO.1 (ED.12-96)Page 427.16
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)X An Original (Mo,Da,Yr)Dec.31,2001
(2)A Resubmission //
SUBSTATIONS
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 M Ja)
No Name and Location of Substation Character of Substation Primary Secondary Tertiary
(a)(b)(c)(d)(e)
1 WASHAKIE Distribution -Unat 132.00 4.16 1.00
2 WELBY Distribution -Unat 43.80 12.47 2.00
3 WELFARE Distribution -Unat 46.00 12.50 3.00
4 WELLINGTON Distribution -Unat 46.00 12.50 3.00
5 WEST COMMERCIAL Distribution -Unat 43.80 12.50 2.00
6 WEST JORDAN Distribution -Unat 138.00 12.47 1.00
7 WEST OGDEN Distribution -Unat 132.00 12.47 1.00
8 WEST ROY Distribution -Unat 43.80 12.47 1.00
9 WEST TEMPLE Distribution -Unat 43.80 4.16 2.00
10 WHITE MESA Distribution -Unat 67.00 12.47 1.00
11 WINKLEMAN Distribution -Unat 45.00 7.20 1.00
12 WOLF CREEK Distribution -Unat 69.00 12.50 1.00
13 WOODRUFF Distribution -Unat 44.00 12.47 3.00
14 WOODS CROSS Distribution -Unat 43.80 12.47 1.00
15 WOODSIDE Distribution -Unat 46.00 12.50 1.00
16 WYUTA Distribution -Unat 43.80 12.47 1.00
17 TOTAL 18020.30 4450.32 392.00
18 NUMBER OF SUBSTATIONS DISTRIBUTION -302
19
20 HOLLADAY T/D -Unattended 43.80 12.47 2.00
21 LINCOLN T/D -Unattended 43.80 12.47 1.00
22 REDWOOD T/D -Unattended 43.80 12.47 2.00
23 TOTAL 131.40 37.41 5.00
24 NUMBER OF SUBSTATIONS T/D -3
25
26 HUNTER Transmission 345.00 138.00 3.00
27 PAVANT Transmission 230.00 46.00 2.00
28 SIGURD Transmission 345.00 230.00 4.00
29 SPANISH FORK Transmission 345.00 138.00
30 WEST CEDAR Transmission 230.00 138.00 1.00
31 ABAJO Transmission -Atte 138.00 69.00 1.00
32 ANGEL Transmission -Atte 138.00 46.00 2.00
33 ASHLEY Transmission -Atte 135.00 69.00 2.00
34 BARNEY Transmission -Atte 138.00 44.00 1.00
35 BEN LOMOND Transmission -Atte 345.00 230.00 5.00
36 BLACKHAWK Transmission -Atte 67.00 45.00
37 BOOK CLIFFS Transmission -Atte 69.00 44.00 3.00
38 COLEMAN Transmission -Atte 138.00 69.00 3.00
39 COTTONWOOD Transmission -Atte 132.00 46.00 4.00
40 HIGHLAND Transmission -Atte 138.00 46.00 2.00
FERC FORM NO.1 (ED.12-96)Page 426.17
Name of Respondent This Re ort is Date of Report Year of Report
PacifiCorp (1)X An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
SUBSTATIONS (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 CONVERSION APPARATUS AND SPECIAL EDUIPMENT Line
(In Service)(In MVa)TransfeoNreers TranSsoarmers Type of Equiprnent Number of Units Tot CMapaacityNo.
(f)(g)(h)(i)(j)(k)
1 1 1
2 2 2
3 3 3
3 3 4
2 2 5
1 1 6
1 1 7
1 1 8
2 2 9
1 1 10
1 1 11
1 1 12
3 3 13
1 1 14
1 1 15
1 1 16
392 392 17
18
19
2 2 20
1 1 21
2 2 22
5 5 23
24
25
3 3 26
2 2 27
4 4 28
29
1 1 30
1 1 31
2 2 32
2 2 33
1 1 34
5 5 35
36
3 3 37
3 3 38
4 4 39
2 2 40
FERC FORM NO.1 (ED.12-96)Page 427.17
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)[¯]X An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
SUBSTATIONS
1.Report below the information called for concerning substations of the respondent as of the end of the year.
2.Substations which sente 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 V')LTAGE(In MVa)
No Name and Location of Substation Character of Substation Primary Secondary Tertiary
(a)(b)(c)(d)(e)
1 HORSESHOE Transmission -Atte 132.00 43.80 1.00
2 HUNTINGTON CITY Transmission -Atte 67.00 43.80 2.00
3 JORDAN Transmission -Atte 138.00 46.00
4 LAVERKIN Transmission -Atte 138.00 69.00 1.00
5 MCFADDEN Transmission -Atte 138.00 69.00 1.00
6 MIDDLETON Transmission -Atte 138.00 69.00 3.00
7 MOAB Transmission -Atte 132.00 69.00 4.00
8 NINETY SOUTH Transmission -Atte 345.00 138.00 6.00
9 OQUIRRH Transmission -Atte 138.00 46.00 1.00
10 PAROWAN VALLEY Transmission -Atte 230.00 138.00 1.00
11 PINTO Transmission -Atte 345.00 138.00 3.00
12 RIVERDALE Transmission -Atte 132.00 45.00 2.00
13 SlXTH SOUTH Transmission -Atte 138.00 43.80 1.00
14 SNOWVILLE Transmission -Atte 69.00 43.80 1.00
15 SPHINX Transmission -Atte 115.00 45.00 3.00
16 SYRACUSE Transmission -Atte 138.00 46.00 3.00
17 TAYLORSVILLE Transmission -Atte 138.00 46.00 1.00
18 TERMINAL Transmission -Atte 345.00 230.00 1.00
19 TOOELE Transmission -Atte 132.00 45.00 2.00
20 WESTWATER Transmission -Atte 67.00 43.00 3.00
21 WINCHESTER HILLS Transmission -Atte 34.50 34.50
22 HURRICANE Transmission -Unat 67.00 12.47 1.00
23 JERUSALEM Transmission -Unat 138.00 46.00 1.00
24 MCCLELLAND Transmission -Unat 132.00 12.47 3.00
25 MID-VALLEY Transmission -Unat 345.00 138.00 1.00
26 PONDEROSA Transmission -Unat 44.00 6.60 1.00
27 WILLOW CREEK Transmission -Unat 44.00 12.47 1.00
28 TOTAL 6952.50 3117.71 81.00
29 NUMBER OF SUBSTATIONS TRANSMISSION -42
30
31 WASHINGTON
32 CENTRALIA COAL HANDLING Distribution -Unat 34.50 4.16 1.00
33 TOTAL 34.50 4.16 1.00
34 NUMBER OF SUBSTATIONS DISTRIBUTION -1
35
36 UNION GAP T/D -Attended 230.00 115.00 5.00
37 VOELKER T/D -Attended 115.00 12.50 1.00
38 ATTALIA T/D -Unattended 69.00 12.50 1.00
39 BOWMAN STREET T/D -Unattended 69.00 12.50 2.00
40 CASCADE KRAFT T/D -Unattended 69.00 12.47 6.00
FERC FORM NO.1 (ED.12-96)Page 426.18
Name of Respondent This Report Is:Date of Report Year of Report(1)DXAn Original (Mo,Da,Yr)PacifiCorp Dec.31,2001(2)A Resubmission //
SUBSTATIONS (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 othenNiSe 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 padies,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 TranSsoarœers Type of Equipment Number of Units Tot CMapaacityNo.
(f)(g)(h)(i)(j)(k)
1 1 1
2 2 2
3
1 1 4
1 1 5
3 3 6
4 4 7
6 6 8
1 1 9
1 1 10
3 3 11
2 2 12
1 1 13
1 1 14
3 3 15
3 3 16
1 1 17
1 1 18
2 2 19
3 3 20
21
1 1 22
1 1 23
3 3 24
1 1 25
1 1 26
1 1 27
81 81 28
29
30
31
1 1 32
1 1 33
34
35
5 5 36
1 1 37
1 1 38
2 2 39
6 6 40
FERC FORM NO.1 (ED.12-96)Page 427.18
Name of Respondent This Report Is.Date of Report Year of Report
PacifiCorp (1)DXAn Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
SUBSTATIONS
1.Report below the information called for concerning substations of the respondent as of theend 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 V')LTAGE(In MVa)
No Name and Location of Substation Character of Substation Primary Secondary Tertiary
(a)(b)(c)(d)(e)
1 CLINTON TID -Unattended 115.00 13.20 1.00
2 DAYTON TID -Unattended 69.00 7.20 1.00
3 DODD RD TID -Unattended 69.00 20.80 2.00
4 GRANDVIEW TID -Unattended 115.00 12.50 2.00
5 HOPLAND T/D -Unattended 115.00 12.50 2.00
6 MILL CREEK T/D -Unattended 69.00 12.50 3.00
7 NOB HILL TID -Unattended 115.00 12.50 2.00
8 NORTH PARK T/D -Unattended 115.00 12.50 2.00
9 ORCHARD T/D -Unattended 115.00 12.50 2.00
10 PACIFIC TID -Unattended 115.00 12.50 3.00
11 PASCO TID -Unattended 115.00 69.00 3.00
12 POMEROY T/D -Unattended 69.00 12.50 1.00
13 PROSPECT POINT T/D -Unattended 69.00 12.50 2.00
14 PUNKIN CENTER T/D -Unattended 115.00 12.50 2.00
15 RIVER ROAD T/D -Unattended 115.00 12.50 4.00
16 SELAH T/D -Unattended 115.00 12.50 2.00
17 SULPHER CREEK TID -Unattended 115.00 12.50
18 SUNNYSIDE T/D -Unattended 115.00 12.50 2.00
19 TIETON T/D -Unattended 115.00 34.50 2.00
20 TOPPENISH T/D -Unattended 115.00 12.50 2.00
21 TOUCHET T/D -Unattended 69.00 12.50 1.00
22 WAITSBURG T/D -Unattended 69.00 7.20 1.00
23 WAPATO T/D -Unattended 115.00 12.50 2.00
24 WENAS T/D -Unattended 115.00 12.50 1.00
25 WHITE SWAN T/D -Unattended 69.00 12.50 2.00
26 WILEY T/D -Unattended 115.00 12.50 2.00
27 TOTAL 3174.00 566.87 64.00
28 NUMBER OF SUBSTATIONS TID -31
29
30 WALLA WALLA Transmission -Atte 230.00 69.00 2.00
31 CENTRAL Transmission -Unat 69.00 12.00 2.00
32 CENTRALIA COAL MINE Transmission -Unat 230.00 34.50 1.00
33 OUTLOOK Transmission -Unat 230.00 115.00 1.00
34 POMONA HEIGHTS Transmission -Unat 230.00 115.00 2.00
35 WALLULA Transmission -Unat 230.00 69.00 2.00
36 TOTAL 1219.00 414.50 10.00
37 NUMBER OF SUBSTATIONS TRANSMISSION -6
38
39 WYOMING
40 DRY FORK Distribution -Atte 69.00 4.00 1.00
FERC FORM NO.1 (ED.12-96)Page 426.19
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)X An Original (Mo.Da,Yr)Dec.31,2001(2)A Resubmission //
SUBSTATIONS (Continued)
5.Show in columns (l),(j),and (k)special equipment such as rotary converters,rectifiers,condensers,etc.and auxiliary equipment for
increasing capacity.
6.Designate substations or major items of equipment leased from others,jointly owned with others,or operated otherwise than 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 E]UIPMENT 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)
1 1 1
1 1 2
2 2 3
2 2 4
2 2 5
3 3 6
2 2 7
2 2 8
2 2 9
3 3 10
3 3 11
1 1 12
2 2 13
2 2 14
4 4 15
2 2 16
17
2 2 18
2 2 19
2 2 20
1 1 21
1 1 22
2 2 23
1 1 24
2 2 25
2 2 26
64 64 27
28
29
2 2 30
2 2 31
1 1 32
1 1 33
2 2 34
2 2 35
10 10 36
37
38
39
1 1 40
FERC FORM NO.1 (ED.12-96)Page 427.19
Name of Respondent This Re ort Is:Date of Report Year of Report
PacifiCorp (1)X An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
SUBSTATIONS
1.Report below the information called for concerning substations of the respondent as of the end of the year.
2.Substations which serve only one industrial or street railway customer should not be listed below.
3.Substations with capacities of Less than 10 MVa except those serving customers with energy for resale,may be grouped according
to functional character,but the number of such substations must be shown.
4.Indicate in column (b)the functional character of each substation,designating whether transmission or distribution and whether
attended or unattended.At the end of the page,summarize according to function the capacities reported for the individual stations in
column (f).
Line V3LTAGE (In M Ja)
No.Name and Location of Substation Character of Substation Primary Secondary Tertiary
(a)(b)(c)(d)(e)
1 EMIGRANT Distribution -Atte 115.00 12.47 1.00
2 FORT CASPER Distribution -Atte 69.00 12.50 1.00
3 HANNA Distribution -Atte 34.50 13.20 1.00
4 LA BONTE Distribution -Atte 13.80 2.40 1.00
5 STANDARD OIL Distribution -Atte 69.00 2.40 2.00
6 VETERANS Distribution -Atte 34.50 13.20 2.00
7 AIR BASE Distribution -Unat 12.50 4.16 1.00
8 ALKALI ANTICLINE Distribution -Unat 34.50 4.16 1.00
9 ANTELOPE MINE Distribution -Unat 230.00 34.50 1.00
10 BAILEY DOME Distribution -Unat 34.50 13.80
11 BAIROIL Distribution -Unat 115.00 57.00 3.00
12 BAR X Distribution -Unat 230.00 34.50 1.00
13 BELLAMY NO.2 Distribution -Unat 115.00 34.50
14 BIG MUDDY Distribution -Unat 69.00 12.50
15 BLACKS FORK Distribution -Unat 230.00 34.50 2.00
16 BLUFF #1 Distribution -Unat 34.50 4.16 1.00
17 BRYAN Distribution -Unat 115.00 12.50 1.00
18 BUFFALO-TOWN Distribution -Unat 20.80 2.40 1.00
19 BYRON Distribution -Unat 34.50 4.10 1.00
20 CASSA Distribution -Unat 57.00 20.80 2.00
21 CENTER STREET Distribution -Unat 115.00 4.16 1.00
22 CHATHAM Distribution -Unat 34.50 4.16 1.00
23 CHUKAR Distribution -Unat 12.50 4.00 1.00
24 COLTER Distribution -Unat 34.50 2.40 1.00
25 COLUMBIA-GENEVA STL Distribution -Unat 230.00 13.20 2.00
26 COLUMBINE Distribution -Unat 20.80 2.40 1.00
27 COMMUNITY PARK Distribution -Unat 69.00 12.50 2.00
28 COWLEY-DEAVER (DEAVER TOWN)Distribution -Unat 34.50 4.10 1.00
29 CROOKS GAP Distribution -Unat 34.50 13.80 1.00
30 DEER CREEK Distribution -Unat 69.00 12.50 1.00
31 DOUGLAS Distribution -Unat 57.00 4.00 1.00
32 EVANS Distribution -Unat 69.00 13.20
33 FAIRGROUNDS Distribution -Unat 69.00 12.00 1.00
34 FARMERS UNION Distribution -Unat 34.50 4.16 1.00
35 FETTERMAN Distribution -Unat 13.20 2.40 1.00
36 FORT SANDERS Distribution -Unat 115.00 13.20 1.00
37 FRONT STREET Distribution -Unat 13.80 2.40 1.00
38 GALLUP Distribution -Unat 34.50 2.40 1.00
39 GLENDO Distribution -Unat 57.00 4.00 1.00
40 GLENROCK Distribution -Unat 69.00 4.10 1.00
FERC FORM NO.1 (ED.12-96)Page 426.20
Name of Respondent This Report is:Date of Report Year of Report
PacifiCorp (1)X An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
SUBSTATIONS (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 CONVERSION APPARATES AND SPECIAL E]UIPMENT 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)
1 1 1
1 1 2
1 1 3
1 1 4
2 2 5
2 2 6
1 1 7
1 1 8
1 1 9
10
3 3 11
1 1 12
13
14
2 2 15
1 1 16
1 1 17
1 1 18
1 1 19
2 2 20
1 1 21
1 1 22
1 1 23
1 1 24
2 2 25
1 1 26
2 2 27
1 1 28
1 1 29
1 1 30
1 1 31
32
1 1 33
1 1 34
1 1 35
1 1 36
1 1 37
1 1 38
1 1 39
1 1 40
FERC FORM NO.1 (ED.12-96)Page 427.20
Name of Respondent This Re ort Is:Date of Report Year of Report
PacifiCorp (1)X An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
SUBSTATIONS
1.Report below the information called for concerning substations of the respondent as of the end of the year.
2.Substations which serve only one industrial or street railway customer should not be listed below.
3.Substations with capacities of Less than 10 MVa except those serving customers with energy for resale,may be grouped according
to functional character,but the number of such substations must be shown.
4.Indicate in column (b)the functional character of each substation,designating whether transmission or distribution and whether
attended or unattended.At the end of the page,summarize according to function the capacities reported for the individual stations in
column (f).
Line V3LTAGE(In MVa)
No Name and Location of Substation Character of Substation Primary Secondary Tertiary
(a)(b)(c)(d)(e)
1 GREAT DIVIDE Distribution -Unat 115.00 34.50 1.00
2 GREEN RIVER Distribution -Unat 34.50 4.16 1.00
3 GREYBULL Distribution -Unat 34.50 4.16 1.00
4 JACKALOPE Distribution -Unat 115.00 12.50 1.00
5 LANDER Distribution -Unat 34.50 12.50 1.00
6 LARAMIE Distribution -Unat 115.00 13.20 1.00
7 LARAMIE PLANT Distribution -Unat 13.20 2.40 1.00
8 LINCH Distribution -Unat 69.00 13.80 1.00
9 LOVELL (LOVELL TOWN)Distribution -Unat 34.50 4.16 1.00
10 MANDERSON Distribution -Unat 34.50 2.40 1.00
11 MEDICINE WHEEL Distribution -Unat 34.50 4.16 1.00
12 MILL IRON Distribution -Unat 34.50 13.09 1.00
13 MILLS Distribution -Unat 12.50 4.16 1.00
14 MOXA Distribution -Unat 69.00 2.40 1.00
15 MURPHY DOME Distribution -Unat 34.50 12.50 1.00
16 ORIN Distribution -Unat .57.00 7.20 1.00
17 ORPHA Distribution -Unat 57.00 7.20 1.00
18 PAC.FRUIT EXPRESS Distribution -Unat 13.20 2.40 1.00
19 PARCO Distribution -Unat 34.50 13.20 1.00
20 PARK STREET Distribution -Unat 34.50 4.10 1.00
21 PITCHFORK Distribution -Unat 69.00 24.90 2.00
22 PLATTE PIPE NATURAL Distribution -Unat 57.00 2.40 1.00
23 PLATTE RIVER DJ Distribution -Unat 69.00 7.20 1.00
24 POISON SPIDER Distribution -Unat 69.00 2.40 1.00
25 POPLAR STEET Distribution -Unat 12.50 4.00 1.00
26 RAINBOW Distribution -Unat 230.00 34.50 1.00
27 RED BUTTE Distribution -Unat 69.00 12.50 1.00
28 REFINERY Distribution -Unat 115.00 12.50 2.00
29 RELIANCE Distribution -Unat 34.50 2.40 1.00
30 RESERVOIR Distribution -Unat 12.50 4.00 1.00
31 RIVER DOME Distribution -Unat 34.50 4.00 1.00
32 SAGE HILL Distribution -Unat 34.50 13.80 1.00
33 SERVICE PIPE-MIDWEST HT'S Distribution -Unat 69.00 2.40 1.00
34 SERVICE PIPE IND STA Distribution -Unat 34.50 2.40
35 SHOSHONI Distribution -Unat 34.50 2.40 1.00
36 SINCLAIR Distribution -Unat 34.50 2.40 1.00
37 SOUTH CODY Distribution -Unat 69.00 25.00 1.00
38 SOUTH ELK BASIN Distribution -Unat 34.50 7.20 2.00
39 SPRING CREEK Distribution -Unat 115.00 13.20 1.00
40 SVILAR Distribution -Unat 34.50 2.40 1.00
FERC FORM NO.1 (ED.12-96)Page 426.21
Name of Respondent This Report Is:Date of Report Year of Report i
PacifiCorp (1)X An Original (Mo,Da,Yr)Dec.31,2001
(2)A Resubmission I /
SUBSTATIONS (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 CONVERSION APPARATL S AND SPECIAL EQUIPMENT Line
(In Service)(In MVa)Transfe ceers TranSsoarœers Type of Equipment Number of Units Tot CMapaacityNo.
(f)(9)(h)(i)(j)(k)
1 1 1
1 1 2
1 1 3
1 1 4
1 1 5
1 1 6
1 1 7
1 1 8
1 1 9
1 1 10
1 1 11
1 1 12
1 1 13
1 1 14
1 1 15
1 1 16
1 1 17
1 1 18
1 1 19
1 1 20
2 2 21
1 1 22
1 1 23
1 1 24
1 1 25
1 1 26
1 1 27
2 2 28
1 1 29
1 1 30
1 1 31
1 1 32
1 1 33
34
1 1 35
1 1 36
1 1 37
2 2 38
1 1 39
1 1 40
FERC FORM NO.1 (ED.12-96)Page 427.21
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)X An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
SUBSTATIONS
1.Report below the information called for concerning substations of the respondent as of the end of the year.
2.Substations which serve only one industrial or street railway customer should not be listed below.
3.Substations with capacities of Less than 10 MVa except those serving customers with energy for resale,may be grouped according
to functional character,but the number of such substations must be shown.
4.Indicate in column (b)the functional character of each substation,designating whether transmission or distribution and whether
attended or unattended.At the end of the page,summarize according to function the capacities reported for the individual stations in
column (f).
Line V3LTAGE (In M Ja)
No Name and Location of Substation Character of Substation Primary Secondary Tertiary
(a)(b)(c)(d)(e)
1 TEAPOT Distribution -Unat 69.00 12.50 1.00
2 TEN MILE Distribution -Unat 69.00 34.50 1.00
3 THERMOPOLIS TOWN Distribution -Unat 34.50 4.00 1.00
4 WAMSUTTER Distribution -Unat 34.50 2.40 1.00
5 WARM SPRINGS SPL.Distribution -Unat 115.00 2.40
6 WELCH Distribution -Unat 57.00 2.40 1.00
7 WERTZ-SINCLAIR Distribution -Unat 57.00 13.80 2.00
8 WEST ADAMS Distribution -Unat 34.50 4.16 1.00
9 WORLAND Distribution -Unat 115.00 34.50 1.00
10 WORLAND TOWN Distribution -Unat 34.50 4.16 1.00
11 TOTAL 5756.30 939.84 97.00
12 NUMBER OF SUBSTATIONS DISTRIBUTION -91
13
14 ASTLE T/D -Unattended 34.50 13.20 1.00
15 BRIDGER PUMP T/D -Unattended 230.00 34.50 4.00
16 MANSFACE T/D -Unattended 230.00 34.50 1.00
17 MIDWEST TID -Unattended 230.00 69.00 4.00
18 MINERS T/D -Unattended 230.00 115.00 3.00
19 ROCK SPRINGS PLANT TID -Unattended 34.50 13.80 2.00
20 TOTAL 989.00 280.00 15.00
21 NUMBER OF SUBSTATIONS T/D -6
22
23 ELK BASIN Transmission -Atte 7.20 34.50 1.00
24 HILLTOP Transmission -Atte 115.00 34.50 2.00
25 BUFFALO Transmission -Unat 230.00 20.80 1.00
26 CASPER Transmission -Unat 230.00 115.00 6.00
27 D.J.COAL MINE Transmission -Unat 69.00 34.50 1.00
28 FIREHOLE Transmission -Unat 230.00 34.50 1.00
29 FRANNIE Transmission -Unat 230.00 34.50 2.00
30 GARLAND Transmission -Unat 230.00 34.50 2.00
31 GLENDO-AUTO Transmission -Unat 69.00 57.00 1.00
32 GRASS CREEK Transmission -Unat 230.00 34.50 1.00
33 LITTLE MOUNTAIN Transmission -Unat 230.00 34.50 1.00
34 MUSTANG Transmission -Unat 230.00 115.00 2.00
35 OREGON BASIN Transmission -Unat 230.00 34.50 3.00
36 PLATTE Transmission -Unat 230.00 115.00 4.00
37 POINT OF ROCKS Transmission -Unat 230.00 34.50 1.00
38 RIVERTON Transmission -Unat 230.00 34.50 3.00
39 ROCK SPRINGS Transmission -Unat 230.00 34.50 2.00
40 SALT CREEK PAN AM Transmission -Unat 69.00 34.50 2.00
FERC FORM NO.1 (ED.12-96)Page 426.22
Name of Respondent This Re ort Is:Date of Report Year of Report
PacifiCorp (1)X An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
SUBSTATIONS (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 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 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 EDUlPMENT Line
(In Service)(In MVa)Transfeo ers TranSs'oarrreers Type of Equipment Number of Units Total CMapacity No.
(f)(g)(h)(i)(j)(k)
1 1 1
1 1 2
1 1 3
1 1 4
5
1 1 6
2 2 7
1 1 8
1 1 9
1 1 10
97 97 11
12
13
1 1 14
4 4 15
1 1 16
4 4 17
3 3 18
2 2 19
15 15 20
21
22
1 1 23
2 2 24
1 1 25
6 6 26
1 1 27
1 1 28
2 2 29
2 2 30
1 1 31
1 1 32
1 1 33
2 2 34
3 3 35
4 4 36
1 1 37
3 3 38
2 2 39
2 2 40
FERC FORM NO.1 (ED.12-96)Page 427.22
Name of Respondent This Re ort Is:Date of Report Year of Report
PacifiCorp (1)X An Original (Mo,Da,Yr)Dec.31,2001
(2)A Resubmission I /
SUBSTATIONS
1.Report below the information called for concerning substations of the respondent as of the end of the year.
2.Substations which serve only one industrial or street railway customer should not be listed below.
3.Substations with capacities of Less than 10 MVa except those serving customers with energy for resale,may be grouped according
to functional character,but the number of such substations must be shown.
4.Indicate in column (b)the functional character of each substation,designating whether transmission or distribution and whether
attended or unattended.At the end of the page,summarize according to function the capacities reported for the individual stations in
column (f).
Line V3LTAGE (In MVa)
No Name and Location of Substation Character of Substation Primary Secondary Tertiary
(a)(b)(c)(d)(e)
1 SOUTH TRONA Transmission -Unat 230.00 34.50 2.00
2 WESTVACO Transmission -Unat 230.00 34.50 3.00
3 WYOPO Transmission -Unat 230.00 34.50 1.00
4 YELLOWCAKE Transmission -Unat 230.00 34.50 1.00
5 TOTAL 4239.20 1009.30 43.00
6 NUMBER OF SUBSTATIONS TRANSMISSION -22
7
8 CALIFRONIA
9 DISTRIBUTION -30
10 T/D -17
11 TRANSMISSION -7
12
13 IDAHO
14 DISTRIBUTION -60
15 T/D -0
16 TRANSMISSION -13
17
18 OREGON
19 DISTRIBUTION -88
20 T/D -116
21 TRANSMISSION -35
22
23 UTAH
24 DISTRIBUTION -302
25 TID -3
26 TRANSMISSION -42
27
28 WASHINGTON
29 DISTRIBUTION -1
30 T/D -31
31 TRANSMISSION -6
32
33 WYOMING
34 DISTRIBUTION -91
35 T/D -6
36 TRANSMISSION -22
37
38
39
40
FERC FORM NO.1 (ED.12-96)Page 426.23
Name of Respondent This Re ort Is:Date of Report Year of Report
PacifiCorp (1)X An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
SUBSTATIONS (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 CONVERSION APPARATL S AND SPECIAL EDUIPMENT Line
(In Service)(in MVa)Transfeo eers TranSsoar
ers Type of Equipment Number of Units Tot CMapacity No.
(f)(g)(h)(i)(j)(k)
2 2 1
3 3 2
1 1 3
1 1 4
43 43 5
6
7
8
136 33 9
266 25 10
248 8 11
12
13
599 62 14
15
1397 25 16
17
18
638 102 19
2535 210 20
3908 64 21
22
23
138 392 24
5 25
1354 81 26
27
28
1 1 29
691 64 30
412 10 31
32
33
602 97 34
107 15 35
700 43 36
37
38
39
40
FERC FORM NO.1 (ED.12-96)Page 427.23
Name of Respondent This Report Is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
ELECTR C DISTRIBUTION METERS AND LINE TRANSFORMERS
1.Report below the information called for concerning distribution watt-hour meters and line transformers.
2.Include watt-hour demand distribution meters,but not external demand meters.
3.Show in a footnote the number of distribution watt-hour meters or line transformers held by the respondent under lease from others,
jointly owned with others,or held othenvise 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 Total capacity (in (MVa)(a)(b)(c)(d)
1 Number at Beginning of Year 1,681,146 432,717 14,673
2 Additions During Year
3 Purchases 53,656 42,878 1,454
4 Associated with Utility Plant Acquired
5 TOTAL Additions (Enter Total of lines 3 and 4)53,656 42,878 1,454
6 Reductions During Year
7 Retirements 28,100 6,628 225
8 Associated with Utility Plant Sold 4,699 1,722 58
9 TOTAL Reductions (Enter Total of lines 7 and 8)32,799 8,350 283
10 Number at End of Year (Lines 1 +5 -9)1,702,003 467,245 15,844
11 In Stock 31,282 8,448 286
12 Locked Meters on Customers'Premises
13 Inactive Transformers on System
14 In Customers'Use 1,670,721 458,797 15,558
15 In Company's Use
16 TOTAL End of Year (Total 11 to 15.This should equal line 10)1,702,003 467,245 15,844
FERC FORMNO.1 (ED.12-88)Page 429
Narne of Respondent This Report is:Date of Report Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001(2)A Resubmission //
ENVIRONMENTAL PROTECTION FACILITIES
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 January1,1969,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 providedbelow 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 DURING YEAR Balance at Actual Cost
No-Additions Retirements Adjustments End of Year
(a)(b)(c)(d)(e)(f)
1 Air Pollution Control Facilities 9,013,506 4,982,403 855,774,889 855,774,889
2 Water Pollution Control Facilities 368,328 19,702 96,953,851 96,953,851
3 Solid Waste Disposal Costs 1,382,235 163,071 177,417,430 177,417,430
4 Noise Abatement Equipment 8,414 273,273 273,273
5 Esthetic Costs 1,236,000 59,248,868 43,315,759
6 Additional Plant Capacity 339,607 84,864,390 84,864,390
7 Miscellaneous (Identify significant)7,136,232 7,136,232
8 TOTAL (Total of lines 1 thru 7)12,348,090 5,165,176 1,281,668,933 1,265,735,824
9 Construction Work in Progress 6,204,042 6,204,042
FERC FORM NO.1 (ED.12-88)Page 430
Name of Respondent This Report Is:Date of Repoit Year of Report
PacifiCorp (1)An Original (Mo,Da,Yr)Dec.31,2001
(2)A Resubmission //
ENVIRONMENTAL PROTECTION EXPENSES
1.Show below expenses incurred in connection with the use of environmental protection facilities,the cost of which are reported on
Page 430.Where it is necessary that allocations and/or estimates of costs be made,state the basis or method used.
2.Include below the costs incurred due to the operation of environmental protection equipment,facilities,and programs.
3.Report expenses under the subheadings listed below.
4.Under 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 Item 8 licensing and similar fees on such facilities.
7.In those instances where expenses are composed of both actual supportable data and estimates of costs,specify in column (c)the
actual expenses that are included in column (b).
Line Ölassification of Expenses Amount Actual Ëxpenses
No (a)(b)(c)
1 Depreciation 24,733,039
2 Labor,Maint,Mtrls,&Supplies Cost Related to Env Fac &Programs 2,282,593 2,282,593
3 Fuel Related Costs
4 Operation of Facilities 6,377,133 6,377,133
5 Fly Ash and Sulfur Sludge Removal 14,404,128 14,404,128
6 Difference in Cost of Environmentally Clean Fuels
7 Replacement Power Costs 23,641,881
8 Taxes and Fees 3,583,937
9 Administrative and General 4,071,452 4,071,452
10 Other (Identify significant)17,731,533 17,731,533
11 TOTAL 96,825,696 44,866,839
ERC I ORM NO.1 (ED.12-88)Page 431
NanvaofRespondent ThisRepodis:DateofRepod YearofRepod
(1)X An Original (Mo,Da,Yr)
PacifiCorp (2)A Resubmission //Dec 31,2001
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.:9 Column:a
On December 31,2001 PacifiCorp Group Holding Company transfered to PacifiCorp Holdings,
Inc.a fully owned subsidiary of Scottish Power.
Schedule Page:103 Line No.:9 Column:b
For unregulated businesses.
Schedule Page:103 Line No.:10 Column:a
On December 31,2001 PacifiCorp Financial Services,Inc.transfered to PacifiCorpHoldings,Inc.a fully owned subsidiary of Scottish Power.
Schedule Page:103 Line No.:11 Column:a
On December 31,2001 PacifiCorp International Group Holdings Co.transfered to PacifiCorpHoldings,Inc.a fully owned subsidiary of Scottish Power.
Schedule Page:103 Line No.:13 Column:a
PPM transfered to PacifiCorp Holdings,Inc.a parent of respondent and an indirectwholly-owned subsidiary of Scottish Power,on 3/30/2001
Schedule Page:103 Line No.:14 Column:a
PKE transfered to PacifiCorp Holdings,Inc.a fully owned subsidiary of Scottish Power,on
3/30/2001
Schedule Page:103 Line No.:14 Column:b
Pacific Klamath Energy,Inc.is the operator of the Co-Gen project.
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 I /Dec 31,2001
FOOTNOTE DATA
Schedule Page:104 Line No.:2 Column:b
Resigned as President and CEO on 6/04/2001 to become Chairman of the Board
Schedule Page:104 Line No.:4 Column:b
Resigned as Sr.VP on 6/04/2001
Schedule Page:104 Line No.:6 Column:b
Elected EVP on 6/04/2001
Schedule Page:104 Line No.:10 Column:b
Elected on 6/04/2001
Schedule Page:104 Line No.:16 Column:b
Resigned on 7/31/2001
Schedule Page:104 Line No.:18 Column:b
Elected on 7/02/2001
Schedule Page:104 Line No.:20 Column:b
Resigned on 3/30/2001
Schedule Page:104 Line No.:22 Column:b
Elected on 6/04/2001
Schedule Page:104 Line No.:24 Column:bResignedon3/1/2001
Schedule Page:104 Line No.:26 Column:b
Resigned on 2/01/2001
Schedule Page:104 Line No.:30 Column:bResignedon2/01/2001
Schedule Page:104 Line No.:32 Column:bResignedon9/20/2001
Schedule Page:104 Line No.:34 Column:b
Elected February 16,2000
Schedule Page:104 Line No.:36 Column:b
Elected May 15,2000
Schedule Page:104 Line No.:38 Column:b
Elected on 6/04/2001
Schedule Page:104 Line No.:40 Column:b
Elected on 6/04/2001
Schedule Page:104 Line No.:42 Column:b
Elected on 8/06/2001
Schedule Page:104 Line No.:44 Column:b
Elected on 10/12/2001
Schedule Page:104.1 Line No.:2 Column:b
Elected 7/2/2001
Schedule Page:104.1 Line No.:4 Column:b
Elected 8/6/2001
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 31,2001
FOOTNOTE DATA
Schedule Page:105 Line No.:3 Column:a
Resigned on 1/31/2001
Schedule Page:105 Line No.:6 Column:aResignedon8/06/2001
Schedule Page:105 Line No.:10 Column:a
Appointed Chairman on 6/04/2001 resigned on 12/31/2001
Schedule Page:105 Line No.:19 Column:a
Appointed Chairman on 2/01/2001 resigned on 6/04/2001
Schedule Page:105 Line No.:25 Column:a
Resigned 8/06/2001
Schedule Page:105 Line No.:28 Column:a
Resigned 9/20/2001
Schedule Page:105 Line No.:34 Column:aResigned3/30/2001
Schedule Page:105 Line No.:40 Column:a
Resigned 6/04/2001
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 31,2001
FOOTNOTE DATA
Schedule Page:106 Line No.:12 Column:b
There was no annual meeting for PacifiCorppreferredshareholders.
Schedule Page:106 Line No.:14 Column:b
There was no annual meeting for PacifiCorppreferredshareholders.
Schedule Page:106 Line No.:16 Column:b
There was no annual meeting for PacifiCorppreferredshareholders.
Schedule Page:106 Line No.:18 Column:b
There was no annual meeting for PacifiCorp preferredshareholders.
Schedule Page:106 Line No.:20 Column:b
There was no annual meeting for PacifiCorp preferredshareholders.
Schedule Page:106 Line No.:23 Column:b
There was no annual meeting for PacifiCorppreferredshareholders.
Schedule Page:106 Line No.:25 Column:b
There was no annual meeting for PacifiCorppreferredshareholders.
Schedule Page:106 Line No.:27 Column:b
There was no annual meeting for PacifiCorp preferredshareholders.
Schedule Page:106 Line No.:29 Column:b
There was no annual meeting for PacifiCorp preferredshareholders.
Schedule Page:106 Line No.:31 Column:b
There was no annual meeting for PacifiCorp preferredshareholders.
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 31,2001
FOOTNOTE DATA
Schedule Page:110 Line No.:25 Column:d
The balance of this account (134),should be in account 131.
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 31,2001
FOOTNOTEDATA
Schedule Page:114 Line No.:48 Column:c
See footnotes for page 262 -263 column L other for account 409.2
Schedule Page:114 Line No.:49 Column:c
10,848 page 272-277
28,712 page 234 part of the balance on line 17.
39,560
Schedule Page:114 Line No.:50 Column:c
882,564 page 272 -277 account 411.2
29,052 page 234 part of the balance on line 17.169,778 page 272 -277 account 411.1
1,081,394
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 31,2001
FOOTNOTE DATA
Schedule Page:118 Line No.:16 Column:c
This line does not balance to the FERC Form 1 cross check of page 117 line 72 column (c)
less page 117 line 34 column (c).This is due to FAS 133,see reconciliation for detail.
Net Income (Page 117,Line 72,Column c)$328,632,870LessEquityinEarningsofSubsidiaryCompanieS(Page 117,Line 34,Column c)138,589,499190,043,371
Balance Transferred from Income (Acct.433 Less 418.1)$77,245,256
Cumul.Effc.of Change in Acctg.Princ.(EAS 133)$112,798,115
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 31,2001
FOOTNOTEDATA
Schedule Page:120 Line No.:2 Column:b
Net Income does not balance to page 117 line 72 (Net Income)due to the cumulative effectofachangeinaccountingprinc(Net of Tax)FAS 133.
Net Income $328,632,870.00
Less:Cumul.Effc.of Change in Acctg.Princ.112,798,115.00$215,834,755.00
Schedule Page:120 Line No.:5 Column:b
Amount Account
Amortization of Organization Costs 1,758,797 404AmortizationofSoftwareDevelopment38,025,159 404AmortizationofOtherIntangibleAssets4,283,464 404
Amortization of Electric Plant Acq.Adj.-Common 5,571,724 406.1AmortizationofRegulatoryAssets-Debits 95,844 407.3AmortizationofUnrecoveredPlant-Trojan 1,901,678 407.31AmortizationofRegulatoryLiabilities-Credits -3,248,605 407.4
Amortization of Tax Sale Costs 1,349 42548,389,410
Schedule Page:120 Line No.:18 Column:b
Amount AccountCumul.Effc.of Change in Acctg.Prin.(Net of Tax)FAS 133 112,798,117 439
FAS 133 Derivative Adjustments -173,985,402 182.3/216/242/253/283CoalDeprc.&Deplet.Included in Fuel Costs 12,995,864 151(Gain)/Loss on Sale of Property -7,617,054 254/411.6/411.7AccumulatedProvisionforMergerCredits-7,282,683 242StampTaxAccrual(Merger Cost)-100,000 232AccumulatedProvisionforPension&Benefits -17,506,340 228.32Regulatoryasset-2000 Utah &Oregon Rate Orders -18,248,156 182.3
OR,UT,WY &ID Orders -Def.Excess Net Power Costs -260,148,936 182.3AccumulatedProvisionforReorg.&Restructuring -21,443,086 228.3MiningAccrualsandOtherDeferredCredits-13,903,391 228/253AccumultatedProvisionforMining/Enviro./Decom.-21,463,710 228/253PMIEquityEarningsIncl.in Cost of Fuel -15,189,187 151Other5,386,982-425,706,982
Schedule Page:120 Line No.:53 Column:b
Amount AccountCustomerAdvancesforConstruction3,552,298 252OtherInvestments/Special Funds 5,997,851 124/128
9,550,149
Schedule Page:120 Line No.:67 Column:b
Amount AccountContributedCap.Parent(PacifiCorp Holdings,Inc.)66,928,054 211
Schedule Page:120 Line No.:76 Column:b
Amount AccountInter-Company Borrowing (Note Agreements)-74,164,845 233
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 31,2001
FOOTNOTE DATA
Schedule Page:204 Line No.:82 Column:g
Acct.Description APC FY start Acquisition Retirement Transfer Current APC
399.21 LAND OWNED IN FEE 2,643,634 (10,998)0 2,280 2,634,916
399.22 LAND RIGHTS 33,095,038 0 (2,733,671)0 30,361,367
399.23 LOCATION VALUE 6,561,429 0 (6,561,429)0
399.30 STRUCTURES 72,857,102 0 (25,872,854)0 46,984,248
399.41 SURFACE -PLANT EQUIPMENT 5,301,702 0 (522,052)O 4,779,650
399.42 SURFACE -DRAGLINE 7,433,469 0 0 0 7,433,469
399.43 SURFACE -RAILROAD EQUIPMENT 1,464,867 0 0 0 1,464,867399.44 SURFACE -ELECTRIC POWER FACIL 1,210,167 0 0 0 1,210,167399.45 UNDERGROUND -COAL MINE EQUIPM 138,555,979 1,751,019 (32,252,110)0 108,054,888
399.51 VEHICLES 2,109,062 118,764 (44,290)0 2,183,536
399.52 HEAVY CONSTRUCTION EQUIPMENT 25,294,369 0 (2,113,287)0 23,181,082399.60 MISCELLANEOUS GENERAL 3,994,982 203,797 (235,137)O 3,963,642EQUIPMEN
399.61 COMPUTERS -MAINFRAME 3,357,632 29,794 (138,627)0 3,248,799399.70 MINE DEVELOPMENT AND ROAD EXTE 43,812,644 400,900 (21,794,485)0 22,419,059
399.411 CENTRALIA:PREP PLANT-CMM FAC 0 0 0 0 0
399.412 CENTRALIA:PREP PLANT -JIG 0 0 0 0 0
399.413 CENTRALIA:PREP PLANT-HEAVY-ME O O 0 0 0
399.421 CENTRALIA MINE (DRAGLINE 101)0 0 0 0 0
399.422 CENTRALIA MINE (DRAGLINE 106)0 0 0 0 0399.423 CENTRALIA MINE (DRAGLINE 111)O O O O 0
399.701 CENTRALIA MINE DEVELOPMENT (N O O O O O
399.702 KOPIAH COAL FIELD 0 0 0 0 0
399.703 WEST PACKWOOD DEVELP 0 0 0 0 0
347,692,078 2,493,275 (92,267,942)2,280 257,919,691
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 31,2001
FOOTNOTE DATA
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 not
determined.
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 31,2001
FOOTNOTEDATA
Schedule Page:219 Line No.:3 Column:c
The amount from account 108 charged to account 403,combined with the reduction of
$14,432,838 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:b
Account 503.1 Blundell Depletion 974,792
Account 421 Depreciation for Future Use 3,231
Total Other Accounts 978,023
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 Report is:Date of Report Year of Report
(1)X An Original (Mo,Da,Yr)
Pacificorp (2)A Resubmission //Dec 31,2001
FOOTNOTE DATA
Schedule Page:224 Line No.:32 Column:f
PPM transfered to PacifiCorp Holdings,Inc.a parent of respondent and an indirectwholly-owned subsidiary of Scottish Power,on 3/30/2001
Schedule Page:224 Line No.:41 Column:f
PKE transfered to PacifiCorp Holdings,Inc.a fully owned subsidiary of Scottish Power,on3/30/2001
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 31,2001
FOOTNOTE DATA
Schedule Page:234 Line No.:7 Column:a
Line 7 -Other:Beg.Balance End.Balance
Supplemental Executive Retirement Plan (SERP)4,026,575 10,064,439
Long-Term incentive Plan (717,698)O
Sales of Emission Allowances (16,917)(123,489)
Federal Income Tax Interest 9,296,694 9,698,524
Sick Leave,Vacation &PT (3,945,564)2,283,210
Injuries &Damages 5,399,296 5,300,132
PPL 1985 Prepaid Pension 0 0
Delta Land &Water Rights Writedown (3,135)0
Terracor Properties Writedown 0 0
Trojan Decommissioning 338,379 (3,163,673)
Other M-1 Line 4 &5 Differences 2,464,509 (119,661,535)
NW Power Act (186,983)(186,983)
Deferred Revenues (944,986)0
Noncash Pension,Bonus &Severance 14,738,420 (302,049)
Utility Asset Writedowns 24,612,813 18,755,998
Property Tax Litigation Accrual (5,246)2,122,848
Bonus Liability 10,800,965 4,249,435
Glenrock 263A (477,720)999,362
Rate Case O O
Exchange Tulana Farms 295,695 295,695
Sec 174 R &E Expenditures (737,165)8,283,621
PMI Deferred Tax Adjustments 11,747,457 13,203,578
Centralia Mining Company 5,808,550 6,643,875
Monsanto Contract 1,264,997 1
Redding Contract 3,130,890 2,922,147
Glenrock Overburden Amort 8,488 (3,447,242)
95 Pension Expense O O
Disallowed Coal Strip 416,599 0
Utah Rate Case Refund 78,834,359 59,047,141
Sale of Montana Assets O O
CA/MT Asset Writeoff 2,177,092 (110,621)
University of WY Contract 1,001,671 333,891
Centralia Sale Accruals 2,979,075 0
WY Deferred Net Power Costs 6,079,565 0
Total 178,386,675 17,208,305
Schedule Page:234 Line No.:17 Column:a
Line 17 -Other:Beg.Balance End.Balance
Malin Line 13,821,531 13,821,871
Uranium Property Writedowns 91,402 0
Roosevelt Land Writedown 354,841 0
30 South Substation Site Writedown 196,435 166,923
NonutilityAsset Writedown 83,084 142,666
Ontario Water Rights Sale O O
Centralia Mining Reclamation-NOB's (2,127,315)(3,841,550)
Deferred Gain on Sale of Telephone Property O 0
Total 12,419,978 10,289,910
FERC FORM NO.1 (ED.12-87)Page 450
NanvaofRespondent ThisRepodis:DateofRepod YearofRepod
(1)X An Original -(Mo,Da,Yr)
PacifiCorp (2)_A Resubmission //Dec 31,2001
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.:34 Column:a
Capital stock authorized but not yet issued as of
December 31,2001 is as follows:
Authorizations for the issuance of common stock (15,000,000
shares authorized;6,210,000 available as of December 31,2001)
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
Name of Respondent This Report is:Date of Report Year of Report
(1)X An Original (Mo,Da,Yr)
Pacificorp (2)_A Resubmission //Dec 31,2001
FOOTNOTE DATA
Schedule Page:253 Line No.:1 Column:b
Sale Proceeds Trans.of Investment Chang.in Cont.Cap.End.Bal.Contributed Capital 69,643,863 (2,715,808)66,928,055InvestmentinPPM(2,373,234)2,373,234 0InvestmentinPKE5,101,224 (5,101,224)0
Total 72,371,853 66,928,055
FERC FORM NO.1 (ED.12-87)Page 450
NameofRespondent ThisRepodis:DateofRepod YearofRepon
(1)X An Original (Mo,Da,Yr)
PacifiCorp (2)_A Resubmission //Dec 31,2001
FOOTNOTEDATA
Schedule Page:256.4 Line No.:18 Column:a
Pollution Control Obligations Secured by Pledged First MortgageBonds:
Issue Amount Pledgee
Var.rate Series 1994 $40,655,000 Moffat County,CO
Var.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,UT
Var.rate Series 1994 9,365,000 Carbon County,UTVar.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:256.5 Line No.:31 Column:a
Footnote Linked.See note on 256.4,Row:18,col/item:a
Schedule Page:256.6 Line No.:20 Column:a
Long-ter.m debt authorized but not yet issued as of December 31,2001 is as follows:
Authorizations for the issuance of $1,600,000,000 of long-term debt of which $800,000,000
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.Washington Utilities and Transportation Commission,Docket No.UE-991745,dated December
8,1999.
Idaho Public Utilities Commission,Docket No.PAC-E-01-12,Order No.28806,dated August7,2001.
Authorizations for the issuance of pollution control revenue bonds ($125,000,000authorized;$79,225,000 available as of December 31,2001)are as follows:
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-E5-95-95,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
Name of Respondent This Report is:Date of Report Year of Report
(1)X_An Original (Mo,Da,Yr)
PacifiCorp (2)_A Resubmission //Dec 31,2001
FOOTNOTE DATA
Schedule Page:261 Line No.:13 Column:b
Description TOTAL
Bk Amort Bond Loss-Postmerger O
Bk Amort Bond Loss-PPL Premerger 0
Bk Amort Bond Loss-UPL Premerger 0
Bonus Liability (16,045,906)
Book Depletion (Cost)1,435,411
Post Merger Loss-Reacquired Debt 5,118,613
Amort Pollution Control Facility 335,823
Avoided Costs 6,632,497
BSIP /SAP Writeoff 1,785,587
CMC Sale Accrual (4,918,584)
Coal Costs -Deferred Debits (3,470,862)
Coal M&S InventoryWrite-Off 10,661,772
Customer Service /Weatherization 16,429,245
Deferred Regulatory Asset 1,299,870
Development30%Amort 286,272
Extraction Tax Paid /Accrued 75,000
Federal Income Tax Interest 1,058,840
FAS 133 Derivatives 7,800,444
Final Reclamation 1,474,509
Glenrock 263A 5,470,862
Injuries and Damages Reserve (2,223,017)
Legal Fee Accrual 0
Misc -Deferred Tax Debits 18,296,893
Misc -Contracts /Deposits 7,428,028
Miscellaneous Accrual (2,758,044)
Non -Deductible Expenses 1,940,324
Ontario Water Rights (Install Sale)O
Pension -Retirement 28,879,526
R&E -Sec 174 7,458,383
SERP 15,514,198
Special Assessment -DOE 67,596
Trojan Decomissioning Costs 400,068
University of WY Contract Amort.(439,908)
Book Depreciation 431,120,254
Capitalized Depreciation 6,876,750
Tax Depreciation (365,451,265)
Other 9,670,037
192,209,216
Schedule Page:261 Line No.:26 Column:b
Description TOTAL
Ta× Depletion (6,000,003)
Tax Depletion -Deer Creek (1,000,003)
Tax Depletion -Trail Mountain (1,500,000)
Amort of Projects-Klamath Engineering (96,324)
Bad Debts Allowance 4,008,827
BSIP /SAP Writeoff 0
CA /MT Writeoff 291,492
Cholla GE Safe Harbor Lease (770,364)
Cholla Plt Transact Costs-APS Amort 545,418
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 31,2001
FOOTNOTE DATA
Coal Mine Development (419,498)
Coal Mine Receding Face (Extension)0
Coal Pile InventoryAdjustment (675,003)
CMC -Inventory Overburden (4,918,584)
Deferred Comp Plan Benefits-PPL 19,460
Employee Benefit Programs (1,856,098)
Miscellaneous Deferred Regulatory Assets (328,717,782)
FAS 106 Accruals (1,593,896)
Injuries &Damages Reserve (499,403)
Malin MidpointAdjustment (2,798,103)
M&S Inventory Write-off (25,318)
Miscellaneous -Deferred Credits (1,293,000)
MiscellaneousAdditions (4,086,503)
Miscellaneous Deductions 326,250
Preferred Dividend -PPL (381,876)
Prepaid Taxes (3,203,518)
R &E -Sec.174 0
Reclamation Liability -NOB's O
Sick Leave,Vacation &Personal Time (8,806,329)
Suppl.Exec.Retirement Plan (SERP)OUniversityofWyomingContractAmort(1,319,724)
UT Deferred Comp COLI (6,686,574)
(371,713,502)
Schedule Page:261 Line No.:28 Column:b
Federal Income Tax at 35.00%($84,316,283)
2000/2001 Federal Accrual to Return Adjustments
2001 PMI Federal Tax Accrual
1994 -1998 IRS Audit Adjustments
Rounding
PMI /GCC /DSR 1999 &2000 Fed.Accrual to Return Adj.
Total ($84,316,283)
Reconciliation:
Account 570001 Federal Income Tax Exp.-Utility ($83,954,282)
Account 570002 Federal Income Tax Exp.-Non-Utility (362,000)
Total ($84,316,283)
FERC FORM NO.1 (ED.12-87)Page 450.1
Narne of Respondent This Report is:Date of Report Year of Report
(1)X An Original (Mo,Da,Yr)
PacifiCorp (2)_A Resubmission //Dec 31,2001
FOOTNOTE DATA
Schedule Page:262 Line No.:2 Column:f
Credit to account 409.1
Schedule Page:262 Line No.:2 Column:IAdjustmentbetween409.11,409.2,410.1 &411.1
Schedule Page:262 Line No.:6 Column:I
Account 184
Schedule Page:262 Line No.:7 Column:I
Account 151
Schedule Page:262 Line No.:15 Column:I
Account 409.2
Schedule Page:262 Line No.:23 Column:I
Leased property taxes that are set against rent expense.
Schedule Page:262 Line No.:26 Column:I
Account 409.2
Schedule Page:262 Line No.:27 Column:I
Accounts 401 &402
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.:29 Column:I
Accounts 184
Schedule Page:262 Line No.:36 Column:I
Leased property taxes that are set against rent expense.
Schedule Page:262.1 Line No.:2 Column:I
Leased property taxes that are set against rent expense.
Schedule Page:262.1 Line No.:3 Column:I
Account 409.2
Schedule Page:262.1 Line No.:6 Column:I
Accounts 401 &402
Schedule Page:262.1 Line No.:8 Column:I
Account 184
Schedule Page:262.1 Line No.:15 Column:I
Leased property taxes that are set against rent expense.
Schedule Page:262.1 Line No.:17 Column:I
Account 409.2
Schedule Page:262.1 Line No.:38 Column:I
Leased property taxes that are set against rent expense.
Schedule Page:262.2 Line No.:1 Column:I
Accounts 401 &402
Schedule Page:262.2 Line No.:2 Column:I
Adjustment between accounts 409.11,409.2,410.1,&411.1
Schedule Page:262.2 Line No.:3 Column:I
Account 409.2
Schedule Page:262.2 Line No.:4 Column:I
Account 184
Schedule Page:262.2 Line No.:11 Column:I
Leased property taxes that are set against rent expense.
Schedule Page:262.2 Line No.:12 Column:I
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 31,2001
FOOTNOTEDATA
Account 409.2
Schedule Page:262.2 Line No.:14 Column:I
Accounts 401 &402
Schedule Page:262.2 Line No.:16 Column:I
Accounts 184
Schedule Page:262.2 Line No.:17 Column:f
Reflects sales and use taxes not included in columns (d)and (e)in accordance with
instruction 1.
Schedule Page:262.2 Line No.:25 Column:I
Leased property taxes that are set against rent expense.
Schedule Page:262.2 Line No.:27 Column:I
Account 151
Schedule Page:262.2 Line No.:29 Column:I
Account 401 &402
Schedule Page:262.2 Line No.:30 Column:f
Reflects sales and use taxes not included in columns (d)and (e)in accordance with
instruction 1.
Schedule Page:262.2 Line No.:34 Column:I
Account 184
Schedule Page:262.3 Line No.:4 Column:I
Leased property taxes that are set against rent expense.
Schedule Page:262.3 Line No.:6 Column:I
Accounts 401 &402
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.
Schedule Page:262.3 Line No.:10 Column:I
Accounts 184
Schedule Page:262.3 Line No.:26 Column:i
Tax SAP Acct.Amount
Extraction Tax 583450 891,066
Federal Reclamation Tax 583500 252,945
Government Royalties 584100 3,069,129
Franchise Tax -Mines 578001 12,928
Property Tax -Mines 579001 19,333PayrollTaxExpense-Mines 580501 27,271PayrollTaxExpenseUnemployment-Mines 580701 3,441PayrollTaxExpense-Mines 580501 129,320PayrollTaxExpenseUnemployment-Mines 580701 9,458
Extraction Tax 583451 389,684
Federal Reclamation Tax -Mines 583501 57,936
Government Royalties 584101 529,243
Other Royalties 584201 106,100
Total 5,497,854
These tax items should have been offset to the cost of fuel consumed.
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 I /Dec 31,2001
FOOTNOTE DATA
Schedule Page:276 Line No.:8 Column:a
CHANGES DURING YEAR ADJUSTMENTS
Balance at Amounts Amounts Debits Credits
SAP Beginning Debited to Credited to Accounts Account Balance at
Account Account of Year Account 410.1 Account 411.1 Credited Amount Debited Amount End of Year
(a)No.(b)(c)(d)(g)(h)(i)(j)(k)
Line 8 -Other:
Purchase Power 287501 (362,553)1,275,409 4,094,345 190 682,512 (3,864,001
Agreement Settlement
Other M-1 287503 6,193,474 2,518,271 2,169,891 190 10,105,036 0 (3,563,182
Differences
Hermiston Breakage 2,612,080 2,612,08C
Fee
Special Assessment 287505 198,981 25,652 190 85,380 87,946
FAS 106 287507 (2,038,819)1,378,782 8,584,569 190 (9,244,606
Regulatory Asset 287509 (1,830,237)190 513,045 (1,317,192
Coalpile 287511 446,078 256,164 190 852,155 1,554,397
Inventory Adj.
APS Abandonment 287519 153,330 22,999 190 176,329 C
Weatherization 287521 13,650,206 1,167,250 7,402,148 190 11,903,176 19,318,48A
Customer Service
Idaho Customer 287523 (128,081)190 128,081 C
Balancing Account
Prepaid Taxes 287525 (1,395,670)3,493,096 2,277,361 190 10,293,724 10,113,786
Trust Income 287527 (617,064)(617,064
&Expense
Agnew Advance 287529 (242,241)190 242,241 C
Royalty Payment
Hazardous Waste 287531 (7,090,938)1,093,603 1,208,026 190 156,502 (7,361,863
Extraction Tax 287533 800,488 28,462 1,112,918 (340,892
Garfield Advance 287535 0 C
Royalties
83 -88 IRS 287537 (4,242,887)190 1,300,049 (5,542,936
Settlement
Glenrock Inventroy 287539 0 C
AdjMine Road 287541 39,783 190 39,783 0 C
Relocation
Section 453 287543 0 C
Installment interest
Amort of Pollution 287545 1,679,247 127,445 190 564 1,552,366
Control Liability
R &E -Solar Il 287547 398,820 190 398,820 C
Project
Software Write-off 287549 (990,597)677,630 190 148,486 (1,519,741
PMI Deferred Tax 287551 967,793 967,793
Adjustments
CMC Inventory Adj 287556 (1,350,573)3,733,206 190 516,030 1,866,603
GCC Deferred Tax 287558 (107,326)190 57,010 (164,336
Adjustments
Electric Mutual 287561 (327,631)190 327,631 C
Insurance Receivable
FAS133 Derivatives 287561 0 78,101,393 12,073,932 211 83,045,654 (17,018,193
6,415,663 93,040,173 38,669,461 97,676,023 24,409,103 (12,480,545
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 31,2001
FOOTNOTE DATA
Schedule Page:276 Line No.:18 Column:b
CHANGES DURING YEAR ADJUSTMENTS
Balance at Amounts Amounts Debits Credits
SAP Beginning Debited to Credited to Accounts Account Balance at
Account Account of Year Account 410.1 Account 411.1 Credited Amount Debited Amount End of Year
(a)No.(b)(c)(d)(g)(h)(i)(j)(k)
Line 18 -Other:
Investments 287801 4,468 4,468
4,468 4,468
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 31,2001
FOOTNOTE DATA
Schedule Page:278 Line No.:7 Column:b
440.1
442.1
442.2
442.3
444.1
Schedule Page:278 Line No.:9 Column:b
4 4 9.12
449.13
4 4 9.14
Schedule Page:278 Line No.:11 Column:b
442.15
442.12
442.14
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 31,2001
FOOTNOTE DATA
Schedule Page:310 Line No.:9 Column:jPriorPeriodAdjustment
Schedule Page:310 Line No.:12 Column:jAccrualAdjustment
Schedule Page:310.1 Line No.:3 Column:bSecondary,Economy and/or non-firm sales,including some hourly firm transactions.
Schedule Page:310.1 Line No.:5 Column:b
Secondary,Economy and/or non-firm sales,including some hourly firm transactions.
Schedule Page:310.1 Line No.:7 Column:bSecondary,Economy and/or non-firm sales,including some hourly firm transactions.
Schedule Page:310.1 Line No.:10 Column:jPriorPeriodAdjustment
Schedule Page:310.1 Line No.:11 Column:b
Secondary,Economy and/or non-firm sales,including some hourly firm transactions.
Schedule Page:310.1 Line No.:11 Column:jOperatingReserves
Schedule Page:310.1 Line No.:13 Column:j
Prior Period Adjustment
Schedule Page:310.2 Line No.:7 Column:b
Black Hills Power &Light Company -FERC 236 -Contract termination date December 31,2023.
Schedule Page:310.2 Line No.:8 Column:b
Black Hills Power &Light Company -FERC 246 -Contract termination date June 30,2012.
Schedule Page:310.2 Line No.:9 Column:b
Black Hills Power &Light Company -FERC 424 -Contract termination date March 31,2002.
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.:11 Column:b
Secondary,Economy and/or non-firm sales,including some hourly firm transactions.
Schedule Page:310.2 Line No.:12 Column:b
Secondary,Economy and/or non-firm sales,including some hourly firm transactions.
Schedule Page:310.3 Line No.:2 Column:b
Bonneville Power Administration -WSPP -Contract termination date:September 30,2006.
Schedule Page:310.3 Line No.:3 Column:b
Bonneville Power Administration -T-12 -Contract termination date:April 22,2024.
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.:7 Column:j
Prior Period Adjustment
Schedule Page:310.3 Line No.:9 Column:j
Prior Period Adjustment
FERC FORM NO.1 (ED.12-87)Page 450
Narne of Respondent This Report is:Date of Report Year of Report
(1)X_An Original (Mo,Da,Yr)
PaciñCorp (2)__AResubmission //Dec31,2001
FOOTNOTEDATA
Schedule Page:310.3 Line No.:11 Column:j
Prior Period Adjustment
Schedule Page:310.3 Line No.:14 Column:b
Clark County PUD #1 -FERC 428 -Contract termination:November 30,2002.
Schedule Page:310.4 Line No.:1 Column:b
Clark County PUD #1 -FERC T-12 -Contract Termination date:December 12,2007.
Schedule Page:310.4 Line No.:4 Column:b
Secondary,Economy and/or non-firm sales,including some hourly firm transactions.
Schedule Page:310.4 Line No.:7 Column:b
Cowlitz County PUD -FERC T-12 -Contract Termination date:April 30,2002.
Schedule Page:310.4 Line No.:8 Column:b
Deseret Generation &Transmission Cooperative -FERC 462 -Contract Termination July 25,
2003.
Schedule Page:310.4 Line No.:8 Column:j
Prior Period Adjustment
Schedule Page:310.4 Line No.:9 Column:j
Prior Period Adjustment
Schedule Page:310.4 Line No.:10 Column:b
Deseret Generation &Transmission Cooperative -FERC 462 -Contract Termination July 25,
2003.
Schedule Page:310.4 Line No.:11 Column:b
Secondary,Economy and/or non-firm sales,including some hourly firm transactions.
Schedule Page:310.4 Line No.:12 Column:b
Secondary,Economy and/or non-firm sales,including some hourly firm transactions.
Schedule Page:310.5 Line No.:1 Column:j
Prior Period Adjustment
Schedule Page:310.5 Line No.:5 Column:j
Prior Period Adjustment
Schedule Page:310.5 Line No.:6 Column:jPriorPeriodAdjustment
Schedule Page:310.5 Line No.:7 Column:b
Secondary,Economy and/or non-firm sales,including some hourly firm transactions.
Schedule Page:310.5 Line No.:7 Column:jOperatingReserves
Schedule Page:310.5 Line No.:10 Column:b
Flathead Electric Cooperative,Inc./Energy Northwest Inc.-FERC T-12 -Contract
Termination date:September 30,2006
Schedule Page:310.5 Line No.:13 Column:j
Prior Period Adjustment
Schedule Page:310.5 Line No.:14 Column:j
Wind Attributes
Schedule Page:310.6 Line No.:1 Column:j
Prior Period Adjustment
Schedule Page:310.6 Line No.:3 Column:b
Hurricane,City of -FERC T-12 -Contract Termination date:August 31,2007
Schedule Page:310.6 Line No.:4 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 31,2001
FOOTNOTE DATA
Prior Period Adjustment
Schedule Page:310.6 Line No.:5 Column:b
Secondary,Economy and/or non-firm sales,including some hourly firm transactions.
Schedule Page:310.6 Line No.:8 Column:b
Secondary,Economy and/or non-firm sales,including some hourly firm transactions.
Schedule Page:310.6 Line No.:13 Column:b
Secondary,Economy and/or non-firm sales,including some hourly firm transactions.
Schedule Page:310.7 Line No.:2 Column:b
Secondary,Economy and/or non-firm sales,including some hourly firm transactions.
Schedule Page:310.7 Line No.:4 Column:b
Secondary,Economy and/or non-firm sales,including some hourly firm transactions.
Schedule Page:310.7 Line No.:6 Column:b
secondary,Economy and/or non-firm sales,including some hourly firm transactions.
Schedule Page:310.7 Line No.:9 Column:b
Secondary,Economy and/or non-firm sales,including some hourly firm transactions.
Schedule Page:310.7 Line No.:13 Column:b
Secondary,Economy and/or non-firm sales,including some hourly firm transactions.
Schedule Page:310.7 Line No.:13 Column:jOperatingReserves
Schedule Page:310.8 Line No.:1 Column:jPriorPeriodAdjustment
Schedule Page:310.8 Line No.:2 Column:b
Secondary,Economy and/or non-firm sales,including some hourly firm transactions.
Schedule Page:310.8 Line No.:4 Column:b
Public Service Company of Colorado -FERC 320 -Contract termination date October 31,
2022.
Schedule Page:310.8 Line No.:4 Column:jPriorPeriodAdjustment
Schedule Page:310.8 Line No.:5 Column:b
Public Service Company of Colorado -FERC 320 -Contract termination date October 31,
2022 .
Schedule Page:310.8 Line No.:6 Column:b
Secondary,Economy and/or non-firm sales,including some hourly firm transactions.
Schedule Page:310.8 Line No.:7 Column:b
Secondary,Economy and/or non-firm sales,including some hourly firm transactions.
Schedule Page:310.8 Line No.:7 Column:jOperatingReserves
Schedule Page:310.8 Line No.:10 Column:j
Prior Period Adjustment
Schedule Page:310.8 Line No.:11 Column:b
Secondary,Economy and/or non-firm sales,including some hourly firm transactions.
Schedule Page:310.8 Line No.:11 Column:jOperatingReserves
Schedule Page:310.8 Line No.:14 Column:b
Public Utility District No.1 of Okanagon County -FERC T-12 -Contract Termination date:
FERC FORM NO.1 (ED.12-87)Page 450.2
NanosofRespondent ThisRepodis:DateofRepod YearofRepod
(1)X An Original (Mo,Da,Yr)
PacifiCorp (2)_A Resubmission //Dec 31,2001
FOOTNOTEDATA
September 30,2001
Schedule Page:310.9 Line No.:2 Column:b
Puget Sound Power &Light Company -FERC 254 -Contract termination date October 31,2003.
Schedule Page:310.9 Line No.:2 Column:jPriorPeriodAdjustment
Schedule Page:310.9 Line No.:3 Column:b
Puget Sound Power &Light Company -FERC 254 -Contract termination date October 31,2003.
Schedule Page:310.9 Line No.:4 Column:b
Secondary,Economy and/or non-firm sales,including some hourly firm transactions.
Schedule Page:310.9 Line No.:5 Column:b
Secondary,Economy and/or non-firm sales,including some hourly firm transactions.
Schedule Page:310.9 Line No.:5 Column:jOperatingReserves
Schedule Page:310.9 Line No.:8 Column:b
City of Redding -FERC 364 -Contract termination date May 31,2014.
Schedule Page:310.9 Line No.:8 Column:j
Prior Period Adjustment
Schedule Page:310.9 Line No.:9 Column:b
City of Redding -FERC 364 -Contract termination date November 30,2015.
Schedule Page:310.9 Line No.:9 Column:jPriorPeriodAdjustment
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.:14 Column:b
Sacramento Municipal Utility District -FERC 250 -Contract termination date December 31,
2014.
Schedule Page:310.9 Line No.:14 Column:jPriorPeriodAdjustment
Schedule Page:310.10 Line No.:1 Column:b
Sacramento Municipal Utility District -FERC 250 -Contract termination date December 31,
2014.
Schedule Page:310.10 Line No.:2 Column:b
Secondary,Economy and/or non-firm sales,including some hourly firm transactions.
Schedule Page:310.10 Line No.:4 Column:b
Secondary,Economy and/or non-firm sales,including some hourly firm transactions.
Schedule Page:310.10 Line No.:6 Column:jPriorPeriodAdjustment
Schedule Page:310.10 Line No.:10 Column:b
Secondary,Economy and/or non-firm sales,including some hourly firm transactions.
Schedule Page:310.10 Line No.:12 Column:b
Sierra Pacific Power Company -FERC 258 -Contract termination date February 28,2009.
Schedule Page:310.10 Line No.:12 Column:j
Prior Period Adjustment
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 31,2001
FOOTNOTE DATA
Schedule Page:310.10 Line No.:13 Column:b
Sierra Pacific Power Company -FERC 267 -Contract termination date April 30,2021.
Schedule Page:310.10 Line No.:13 Column:j
Prior Period Adjustment
Schedule Page:310.10 Line No.:14 Column:b
Sierra Pacific Power Company -FERC 258 -Contract termination date February 28,2009.
Schedule Page:310.11 Line No.:1 Column:b
Secondary,Economy and/or non-firm sales,including some hourly firm transactions.
Schedule Page:310.11 Line No.:4 Column:b
Southern California Edison Company -FERC 248 -Contract termination date September 30,
2006.
Schedule Page:310.11 Line No.:5 Column:b
Springfield Utility Board -FERC 423 -Contract termination date July 31,2015.
Schedule Page:310.11 Line No.:7 Column:b
State of California -FERC 311 -Contract termination date December 31,2004.
Schedule Page:310.11 Line No.:7 Column:j
Prior Period Adjustment
Schedule Page:310.11 Line No.:8 Column:b
State of California -FERC 311 -Contract termination date December 31,2004.
Schedule Page:310.11 Line No.:12 Column:b
secondary,Economy and/or non-firm sales,including some hourly firm transactions.
Schedule Page:310.11 Line No.:14 Column:b
Secondary,Economy and/or non-firm sales,including some hourly firm transactions.
Schedule Page:310.11 Line No.:14 Column:jOperatingReserves
Schedule Page:310.12 Line No.:2 Column:b
Secondary,Economy and/or non-firm sales,including some hourly firm transactions.
Schedule Page:310.12 Line No.:4 Column:b
Secondary,Economy and/or non-firm sales,including some hourly firm transactions.
Schedule Page:310.12 Line No.:6 Column:b
Utah Municipal Power Agency -FERC 433 -Contract termination date July 1,2005.
Schedule Page:310.12 Line No.:7 Column:b
Utah Municipal Power Agency -FERC 433 -Contract termination date June 30,2017.
Schedule Page:310.12 Line No.:8 Column:b
Secondary,Economy and/or non-firm sales,including some hourly firm transactions.
Schedule Page:310.12 Line No.:10 Column:b
WaferTech -FERC T-12 -Contract Termination date:November 30,2002
Schedule Page:310.12 Line No.:11 Column:b
Western Area Power Administration -FERC 313 -Contract termination date December 31,
2004.
Schedule Page:310.12 Line No.:12 Column:b
secondary,Economy and/or non-firm sales,including some hourly firm transactions.
Schedule Page:310.12 Line No.:14 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 31,2001
FOOTNOTE DATA
Prior Period Adjustment
Schedule Page:310.13 Line No.:2 Column:j
Accrual 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 31,2001
FOOTNOTE DATA
Schedule Page:326 Line No.:2 Column:I
Premium for physical call option.
Schedule Page:326 Line No.:3 Column:b
Non-Firm.
Schedule Page:326 Line No.:5 Column:b
Prior period adjustment.
Schedule Page:326 Line No.:5 Column:I
Prior Period Adjustment -True-up of Estimate
Schedule Page:326 Line No.:6 Column:b
Non-Firm.
Schedule Page:326 Line No.:8 Column:b
Non-Firm.
Schedule Page:326 Line No.:10 Column:b
Aquila Power Corp.-Contract Termination Date:September 30,2006.
Schedule Page:326 Line No.:10 Column:I
Premium for physical call option.
Schedule Page:326 Line No.:11 Column:b
Prior period adjustment
Schedule Page:326 Line No.:11 Column:I
Prior Period Adjustment -True-up of Estimate
Schedule Page:326 Line No.:12 Column:b
Arizona Public Service -Contract Termination Date:October 31,2020.
Schedule Page:326 Line No.:13 Column:b
Non-Firm.
Schedule Page:326 Line No.:13 Column:I
Operating reservation.
Schedule Page:326 Line No.:14 Column:I
Premium for physical call option.
Schedule Page:326.1 Line No.:1 Column:b
Prior period adjustment.
Schedule Page:326.1 Line No.:1 Column:I
Prior Period Adjustment -True-up of Estimate
Schedule Page:326.1 Line No.:2 Column:b
Prior period adjustment.
Schedule Page:326.1 Line No.:2 Column:I
Prior Period Adjustment -True-up of Estimate
Schedule Page:326.1 Line No.:3 Column:b
Avista Corp.-Contract Termination Date:September 15,2003.
Schedule Page:326.1 Line No.:4 Column:b
Non-Firm.
Schedule Page:326.1 Line No.:4 Column:I
Operating reservation.
Schedule Page:326.1 Line No.:8 Column:b
Under Electric Service Agreement subject to termination upon timely notification.
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 31,2001
FOOTNOTE DATA
Schedule Page:326.1 Line No.:13 Column:I
Operation and maintenance expense associated with the combustion turbine located in Rapid City,South Dakota.
Schedule Page:326.2 Line No.:1 Column:b
Prior period adjustment.
Schedule Page:326.2 Line No.:1 Column:I
Prior Period Adjustment -True-up of Estimate
Schedule Page:326.2 Line No.:2 Column:b
Non-Firm.
Schedule Page:326.2 Line No.:5 Column:b
Prior period adjustment.
Schedule Page:326.2 Line No.:5 Column:I
Prior Period Adjustment -True-up of Estimate
Schedule Page:326.2 Line No.:9 Column:b
Bonneville PowerAdministration -Contract Termination Date:March 31,2003.
Schedule Page:326.3 Line No.:1 Column:b
Non-Firm.
Schedule Page:326.3 Line No.:3 Column:I
Prior Period Adjustment -True-up of Estimate
Schedule Page:326.3 Line No.:4 Column:b
Prior period adjustment.
Schedule Page:326.3 Line No.:4 Column:I
Imbalance energy expense.
Schedule Page:326.3 Line No.:7 Column:I
Operating expense,bond interest,amortizationand taxes.
Schedule Page:326.3 Line No.:9 Column:b
Prior period adjustment.
Schedule Page:326.3 Line No.:9 Column:I
Prior Period Adjustment -True-up of Estimate
Schedule Page:326.3 Line No.:10 Column:b
Non-Firm.
Schedule Page:326.3 Line No.:10 Column:I
Operating reservation.
Schedule Page:326.3 Line No.:13 Column:b
Non-Firm.
Schedule Page:326.4 Line No.:1 Column:b
Columbia Storage Power Exchange -Contract Termination Date:March 31,2003.
Schedule Page:326.4 Line No.:4 Column:b
Prior period adjustment.
Schedule Page:326.4 Line No.:4 Column:I
Prior Period Adjustment -True-up of Estimate
Schedule Page:326.4 Line No.:5 Column:b
Non-Firm.
Schedule Page:326.4 Line No.:7 Column:b
Non-Firm.
Schedule Page:326.4 Line No.:11 Column:b
Prior period 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 31,2001
FOOTNOTE DATA
Schedule Page:326.4 Line No.:11 Column:I
Prior Period Adjustment -True-up of Estimate
Schedule Page:326.4 Line No.:13 Column:b
Non-Firm.
Schedule Page:326.4 Line No.:13 Column:I
Prior Period Adjustment -True-up of Estimate
Schedule Page:326.4 Line No.:14 Column:b
Deseret Generation &Transmission Coop.-Contract Termination Date:July 25,2003.
Schedule Page:326.4 Line No.:14 Column:I
Damages for improper curtailment and dispatch.
Schedule Page:326.5 Line No.:1 Column:b
Deseret Generation &Transmission Coop.-Contract Termination Date:July 25,2003.
Schedule Page:326.5 Line No.:1 Column:I
Prior Period Adjustment -True-up of Estimate
Schedule Page:326.5 Line No.:2 Column:I
Prior Period Adjustment -True-up of Estimate
Schedule Page:326.5 Line No.:3 Column:I
Operating expense,bond interest,amortization and taxes.
Schedule Page:326.5 Line No.:4 Column:b
Non-Firm.
Schedule Page:326.5 Line No.:5 Column:b
Prior period adjustment.
Schedule Page:326.5 Line No.:5 Column:I
Prior Period Adjustment -True-up of Estimate
Schedule Page:326.5 Line No.:8 Column:b
Non-Firm.
Schedule Page:326.5 Line No.:9 Column:b
Prior period adjustment.
Schedule Page:326.5 Line No.:9 Column:I
Prior Period Adjustment -True-up of Estimate
Schedule Page:326.5 Line No.:11 Column:b
Non-Firm.
Schedule Page:326.6 Line No.:1 Column:b
Non-Firm.
Schedule Page:326.6 Line No.:2 Column:b
Prior period adjustment.
Schedule Page:326.6 Line No.:2 Column:I
Prior Period Adjustment -True-up of Estimate
Schedule Page:326.6 Line No.:4 Column:b
Non-Firm.
Schedule Page:326.6 Line No.:7 Column:b
Non-Firm.
Schedule Page:326.6 Line No.:11 Column:b
Under Electric Service Agreement subject to termination upon timely notification.
Schedule Page:326.6 Line No.:13 Column:b
Prior period adjustment.
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 31,2001
FOOTNOTE DATA
Schedule Page:326.6 Line No.:13 Column:I
Prior Period Adjustment -True-up of Estimate
Schedule Page:326.7 Line No.:1 Column:b
Non-Firm.
Schedule Page:326.7 Line No.:4 Column:b
Non-Firm.
Schedule Page:326.7 Line No.:6 Column:b
Under Electric ServiceAgreement subject to termination upon timely notification.
Schedule Page:326.7 Line No.:7 Column:b
Prior period adjustment.
Schedule Page:326.7 Line No.:7 Column:I
Prior Period Adjustment -True-up of Estimate
Schedule Page:326.7 Line No.:8 Column:b
Grant County PUD No.2 -Contract Termination Date:2 years written notice.
Schedule Page:326.7 Line No.:10 Column:I
Operating expense,bond interest,amortization and taxes.
Schedule Page:326.7 Line No.:11 Column:b
Non-Firm.
Schedule Page:326.7 Line No.:11 Column:I
Operating reservation.
Schedule Page:326.7 Line No.:12 Column:I
Operating expense,bond interest,amortization and taxes.
Schedule Page:326.7 Line No.:14 Column:b
Prior period adjustment.
Schedule Page:326.7 Line No.:14 Column:I
Prior Period Adjustment -True-up of Estimate
Schedule Page:326.8 Line No.:1 Column:b
Prior periodadjustment.
Schedule Page:326.8 Line No.:1 Column:I
Prior Period Adjustment -True-up of Estimate
Schedule Page:326.8 Line No.:2 Column:b
Under Electric ServiceAgreement subject to termination upon timely notification.
Schedule Page:326.8 Line No.:3 Column:I
On peak incentive,supplemental dispatch efficiency expense,start-up charges,committee settlements and prior period
adjustment.
Schedule Page:326.8 Line No.:4 Column:b
Prior period adjustment.
Schedule Page:326.8 Line No.:4 Column:I
Prior Period Adjustment -True-up of Estimate
Schedule Page:326.8 Line No.:5 Column:I
Charge for hourly load shaping.
Schedule Page:326.8 Line No.:6 Column:b
Hurricane,City of -Contract Termination Date:August 31,2007.
Schedule Page:326.8 Line No.:7 Column:b
Prior period adjustment.
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 31,2001
FOOTNOTE DATA
Schedule Page:326.8 Line No.:7 Column:I
Prior Period Adjustment -True-up of Estimate
Schedule Page:326.8 Line No.:9 Column:b
Prior period adjustment.
Schedule Page:326.8 Line No.:9 Column:I
Prior Period Ad ustment -True-up of Estimate
Schedule Page:326.8 Line No.:10 Column:b
Non-Firm.
Schedule Page:326.8 Line No.:10 Column:I
Operating reservation.
Schedule Page:326.8 Line No.:12 Column:b
Prior period adjustment.
Schedule Page:326.8 Line No.:12 Column:I
Prior Period Adjustment -True-up of Estimate
Schedule Page:326.9 Line No.:1 Column:I
Load curtailment.
Schedule Page:326.9 Line No.:2 Column:b
Prior period adjustment.
Schedule Page:326.9 Line No.:2 Column:I
Prior Period Adjustment -True-up of Estimate
Schedule Page:326.9 Line No.:5 Column:b
Non-Firm.
Schedule Page:326.9 Line No.:5 Column:I
Operating reservation.
Schedule Page:326.10 Line No.:1 Column:b
Non-Firm.
Schedule Page:326.10 Line No.:1 Column:I
Operating reservation.
Schedule Page:326.10 Line No.:2 Column:b
Under Electric Service Agreement subject to termination upon timely notification.
Schedule Page:326.10 Line No.:3 Column:b
Non-Firm.
Schedule Page:326.10 Line No.:5 Column:b
Non-Firm.
Schedule Page:326.10 Line No.:7 Column:b
Prior period adjustment.
Schedule Page:326.10 Line No.:7 Column:I
Prior Period Adjustment -True-up of Estimate
Schedule Page:326.10 Line No.:8 Column:b
Under Electric Service Agreement subject to termination upon timely notification.
Schedule Page:326.10 Line No.:9 Column:b
Under Electric Service Agreement subject to termination upon timely notification.
Schedule Page:326.10 Line No.:10 Column:b
Non-Firm.
Schedule Page:326.11 Line No.:1 Column:I
Operating reservation.
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 31,2001
FOOTNOTE DATA
Schedule Page:326.11 Line No.:6 Column:b
Non-Firm.
Schedule Page:326.11 Line No.:6 Column:I
Base charge surcharge for environmental attributesof energy generated by wind resources.
Schedule Page:326.11 Line No.:7 Column:b
Prior period adjustment.
Schedule Page:326.11 Line No.:7 Column:I
Prior Period Adj.-True-up of Estimate
Schedule Page:326.11 Line No.:9 Column:b
Under Electric Service Agreement subject to termination upon timely notification.
Schedule Page:326.11 Line No.:10 Column:b
Non-Firm.
Schedule Page:326.11 Line No.:11 Column:b
Prior period adjustment.
Schedule Page:326.11 Line No.:11 Column:I
Prior Period Adj.-True-up of Estimate
Schedule Page:326.11 Line No.:12 Column:b
Non-Firm.
Schedule Page:326.11 Line No.:12 Column:I
Operating reservation.
Schedule Page:326.11 Line No.:14 Column:b
Portland General Electric Company -Contract Termination Date:no longer generating at Round Butte project.
Schedule Page:326.11 Line No.:14 Column:I
Operation expense plus amortization of unrecovered costs of Cove Project.
Schedule Page:326.12 Line No.:1 Column:b
Non-Firm.
Schedule Page:326.12 Line No.:3 Column:b
Prior period adjustment.
Schedule Page:326.12 Line No.:3 Column:I
Prior Period Adj.-True-up of Estimate
Schedule Page:326.12 Line No.:4 Column:b
Prior period adjustment.
Schedule Page:326.12 Line No.:4 Column:I
Prior Period Adi.-True-up of Estimate
Schedule Page:326.12 Line No.:5 Column:b
Non-Firm.
Schedule Page:326.12 Line No.:8 Column:b
Under Electric Service Agreement subject to termination upon timely notification.
Schedule Page:326.12 Line No.:9 Column:b
Non-Firm.
Schedule Page:326.12 Line No.:10 Column:I
Premium for physical call option.
Schedule Page:326.12 Line No.:11 Column:b
Non-Firm.
Schedule Page:326.12 Line No.:13 Column:b
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 31,2001
FOOTNOTE DATA
Schedule Page:326.12 Line No.:13 Column:I
Prior Period Adj.-True-up of Estimate
Schedule Page:326.13 Line No.:1 Column:b
Non-Firm.
Schedule Page:326.13 Line No.:1 Column:I
Operating reservation.
Schedule Page:326.13 Line No.:3 Column:b
Redding,City of -Contract Termination Date:May 31,2014.
Schedule Page:326.13 Line No.:3 Column:I
Prior Period Adj.-True-up of Estimate
Schedule Page:326.13 Line No.:5 Column:b
Non-Firm.
Schedule Page:326.13 Line No.:6 Column:b
Non-Firm.
Schedule Page:326.13 Line No.:7 Column:I
Premium for physical call option.
Schedule Page:326.13 Line No.:8 Column:b
Non-Firm.
Schedule Page:326.13 Line No.:10 Column:b
Non-Firm.
Schedule Page:326.13 Line No.:13 Column:b
Prior period adjustment.
Schedule Page:326.13 Line No.:13 Column:I
Prior Period Adj.-True-up of Estimate
Schedule Page:326.14 Line No.:3 Column:b
Non-Firm.
Schedule Page:326.14 Line No.:4 Column:b
Non-Firm.
Schedule Page:326.14 Line No.:8 Column:b
Non-Firm.
Schedule Page:326.14 Line No.:8 Column:I
Operating reservation.
Schedule Page:326.14 Line No.:13 Column:b
Non-Firm.
Schedule Page:326.14 Line No.:14 Column:b
Prior period adjustment.
Schedule Page:326.14 Line No.:14 Column:I
Prior Period Adj.-True-up of Estimate
Schedule Page:326.15 Line No.:3 Column:b
Prior period adjustment.
Schedule Page:326.15 Line No.:3 Column:I
Prior Period Adj.-True-up of Estimate
Schedule Page:326.15 Line No.:4 Column:b
Non-Firm.
Schedule Page:326.15 Line No.:5 Column:b
Southern California Edison Co.-Contract Termination Date:March 15,2003.
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 31,2001
FOOTNOTE DATA
Schedule Page:326.15 Line No.:6 Column:b
Prior period adjustment.
Schedule Page:326.15 Line No.:6 Column:I
Prior Period Adj.-True-up of Estimate
Schedule Page:326.15 Line No.:7 Column:b
Under Electric Service Agreement subject to termination upon timely notification.
Schedule Page:326.15 Line No.:9 Column:b
Under Electric Service Agreement subject to termination upon timely notification.
Schedule Page:326.15 Line No.:11 Column:b
Under Electric Service Agreement subject to termination upon timely notification.
Schedule Page:326.16 Line No.:1 Column:b
Prior period adjustment.
Schedule Page:326.16 Line No.:1 Column:I
Prior Period Adj.-True-up of Estimate
Schedule Page:326.16 Line No.:3 Column:I
Premium for physical call option.
Schedule Page:326.16 Line No.:4 Column:b
TransAlta Energy Marketing Corp.-Contract Termination Date:June 30,2007.
Schedule Page:326.16 Line No.:5 Column:b
Prior period adjustment.
Schedule Page:326.16 Line No.:5 Column:I
Prior Period Adj.-True-up of Estimate
Schedule Page:326.16 Line No.:6 Column:b
Non-Firm.
Schedule Page:326.16 Line No.:8 Column:b
Tri-State Generation &Transmission -ContractTermination Date:December 31,2020.
Schedule Page:326.16 Line No.:10 Column:b
Non-Firm.
Schedule Page:326.16 Line No.:11 Column:b
Prior period adjustment.
Schedule Page:326.16 Line No.:11 Column:I
Prior Period Adj.-True-up of Estimate
Schedule Page:326.16 Line No.:12 Column:b
Non-Firm.
Schedule Page:326.17 Line No.:4 Column:b
Under Electric Service Agreement subject to termination upon timely notification.
Schedule Page:326.17 Line No.:6 Column:b
Non-Firm.
Schedule Page:326.17 Line No.:6 Column:I
Operating reservation.
Schedule Page:326.17 Line No.:7 Column:b
Prior period adjustment.
Schedule Page:326.17 Line No.:7 Column:I
Prior Period Adj.-True-up of Estimate
Schedule Page:326.17 Line No.:10 Column:b
Non-Firm.
FERC FORM NO.1 (ED.12-87)Page 450.7
Name of Respondent This Report is:Date of Report Year of Report
(1)X An Original (Mo,Da,Yr)
PacifiCorp (2)_A Resubmission //Dec 31,2001
FOOTNOTE DATA
Schedule Page:326.17 Line No.:10 Column:I
Financial settlement on energy balance at termination of Electric Service Agreement.
Schedule Page:326.17 Line No.:11 Column:I
Premium for physical call option.
Schedule Page:326.17 Line No.:13 Column:I
Accounting Accrual
Schedule Page:326.18 Line No.:2 Column:I
Exchange energy expense.
Schedule Page:326.18 Line No.:3 Column:I
Exchange energy expense.
Schedule Page:326.18 Line No.:4 Column:I
Exchange energy expense.
Schedule Page:326.18 Line No.:7 Column:I
Load factoring and storage e×pense.
Schedule Page:326.18 Line No.:8 Column:I
Exchange energy expense.
Schedule Page:326.18 Line No.:9 Column:I
Exchange energy expense.
Schedule Page:326.18 Line No.:10 Column:I
Exchange energy expense.
Schedule Page:326.18 Line No.:11 Column:I
Load factoring and storage expense.
Schedule Page:326.18 Line No.:12 Column:c
Pacific Northwest Electric Power Planning &Conservation Act,FERC Electric Tariff,Original Volume No.1
Schedule Page:326.18 Line No.:12 Column:h
These megawatt hours represent book entries only.No actual energy transfer took place.
Schedule Page:326.18 Line No.:12 Column:i
These megawatt hours represent book entries only.No actual energy transfer took place.
Schedule Page:326.18 Line No.:12 Column:I
See footnote on line 12,col."c"page 326.18
Schedule Page:326.18 Line No.:13 Column:I
Exchange energyexpense.
Schedule Page:326.18 Line No.:14 Column:I
Exchange energyexpense.
Schedule Page:326.19 Line No.:1 Column:I
Exchange energyexpense.
Schedule Page:326.19 Line No.:3 Column:I
Load factoring and storage expense.
Schedule Page:326.19 Line No.:4 Column:I
Storage charge.
Schedule Page:326.19 Line No.:7 Column:I
Exchange energyexpense.
Schedule Page:326.19 Line No.:8 Column:I
Storage charge.
Schedule Page:326.19 Line No.:9 Column:I
Imbalance energy expense.
FERC FORM NO.1 (ED.12-87)Page 450.8
Name of Respondent This Report is:Date of Report Year of Report
(1)X An Original (Mo,Da,Yr)
PacifiCorp (2)_A Resubmission //Dec 31,2001
FOOTNOTE DATA
Schedule Page:326.19 Line No.:14 Column:I
Storage charge.
Schedule Page:326.20 Line No.:2 Column:I
Exchange energy expense.
Schedule Page:326.20 Line No.:3 Column:I
Storage charge.
Schedule Page:326.20 Line No.:4 Column:I
Exchange energy expense.
Schedule Page:326.20 Line No.:6 Column:I
Exchange energy expense.
Schedule Page:326.20 Line No.:9 Column:b
Not applicable:adjustment for inadvertent interchange.
FERC FORM NO.1 (ED.12-87)Page 450.9
Name of Respondent This Report is:Date of Report Year of Report
(1)X An Original (Mo,Da,Yr)
PacifiCorp (2)_A Resubmission //Dec 31,2001
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:m
Transmission Loss.
Schedule Page:328 Line No.:2 Column:b
Various signatories to the Original Volume 11 Point-to-Point Transmission Tariff.
Schedule Page:328 Line No.:2 Column:c
Various signatories to the Original Volume 11 Point-to-Point Transmission Tariff.
Schedule Page:328 Line No.:2 Column:d
Non-firm.
Schedule Page:328 Line No.:3 Column:c
Various signatories to the Original Volume 11 Point-to-Point Transmission Tariff.
Schedule Page:328 Line No.:3 Column:d
Basin Electric Power Cooperative -OV-11 -Subject to termination upon timely notification.
Schedule Page:328 Line No.:3 Column:m
Network Integration Transmission Service.
Schedule Page:328 Line No.:4 Column:c
Various signatories to the Original Volume 11 Point-to-PointTransmission Tariff.
Schedule Page:328 Line No.:4 Column:d
Basin Electric PowerCooperative -FERC 4 -Contract Termination Date:May 1,2007.
Schedule Page:328 Line No.:4 Column:m
Imbalance Energy.
Schedule Page:328 Line No.:5 Column:b
Various signatories to the Original Volume 11 Point-to-Point Transmission Tariff.
Schedule Page:328 Line No.:5 Column:c
Various signatories to the Original Volume 11 Point-to-Point Transmission Tariff.
Schedule Page:328 Line No.:5 Column:d
Non-firm.
Schedule Page:328 Line No.:6 Column:d
Black Hills Power &Light -FERC 42 -Contract Termination Date:December 31,2006.
Schedule Page:328 Line No.:6 Column:m
Network Integration Transmission Service.
Schedule Page:328 Line No.:7 Column:d
Black Hills Power &Light -FERC 236 -Contract Termination Date:December 31,2023.
Schedule Page:328 Line No.:9 Column:d
Non-firm.
Schedule Page:328 Line No.:10 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.:10 Column:m
Demand dollars plus a fixed cost calculated using plant investment values at various U.S.Government facilities.
Schedule Page:328 Line No.:11 Column:d
Bonneville Power Administration -FERC 299 -Contract Termination Date:Earlier of three years prior written notice,or
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 31,2001
FOOTNOTE DATA
upon termination of all deliveries.
Schedule Page:328 Line No.:11 Column:m
Charges for monitoring,scheduling,load following and spinning reserve.
Schedule Page:328 Line No.:12 Column:d
Bonneville PowerAdministration -FERC 237 -Under transfer agreements subject to termination upon timely notification.
Schedule Page:328 Line No.:12 Column:m
Sole use of facilities charge.
Schedule Page:328 Line No.:13 Column:d
Bonneville PowerAdministration -FERC 256 -Subject to termination upon timely notification.
Schedule Page:328 Line No.:13 Column:m
Prior Period Adj.-True-up of Estimate
Schedule Page:328 Line No.:14 Column:d
Bonneville PowerAdministration -OV-11 -Contract Termination Date:October 4,2005.
Schedule Page:328 Line No.:14 Column:m
Prior Period Adj.-True-up of Estimate
Schedule Page:328 Line No.:15 Column:m
Network Integration Transmission Service.
Schedule Page:328 Line No.:16 Column:d
Bonneville PowerAdministration -OV-11 -Contract Termination Date:September 30,2006.
Schedule Page:328 Line No.:16 Column:m
Network Integration Transmission Service.
Schedule Page:328 Line No.:17 Column:b
Various signatories to the Original Volume 11 Point-to-PointTransmission Tariff.
Schedule Page:328 Line No.:17 Column:c
Various signatories to the Original Volume 11 Point-to-PointTransmission Tariff.
Schedule Page:328 Line No.:17 Column:d
Non-firm.
Schedule Page:328 Line No.:17 Column:m
Transmission Loss.
Schedule Page:328.1 Line No.:1 Column:m
Transmission Loss.
Schedule Page:328.1 Line No.:2 Column:m
Transmission Loss.
Schedule Page:328.1 Line No.:3 Column:b
Various signatories to the Original Volume 11 Point-to-PointTransmission Tariff.
Schedule Page:328.1 Line No.:3 Column:c
Various signatories to the Original Volume 11 Point-to-PointTransmission Tariff.
Schedule Page:328.1 Line No.:3 Column:d
Non-firm.
Schedule Page:328.1 Line No.:3 Column:m
Transmission Loss.
Schedule Page:328.1 Line No.:4 Column:b
Various signatories to the Original Volume 11 Point-to-PointTransmission Tariff.
Schedule Page:328.1 Line No.:4 Column:c
Various signatories to the Original Volume 11 Point-to-PointTransmission Tariff.
Schedule Page:328.1 Line No.:4 Column:d
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 31,2001
FOOTNOTE DATA
Non-firm.
Schedule Page:328.1 Line No.:5 Column:b
Various signatories to the Original Volume 11 Point-to-Point Transmission Tariff.
Schedule Page:328.1 Line No.:5 Column:c
Various signatories to the Original Volume 11 Point-to-Point Transmission Tariff.
Schedule Page:328.1 Line No.:6 Column:b
Various signatories to the Original Volume 11 Point-to-Point Transmission Tariff.
Schedule Page:328.1 Line No.:6 Column:c
Various signatories to the Original Volume 11 Point-to-Point Transmission Tariff.
Schedule Page:328.1 Line No.:6 Column:d
Non-firm.
Schedule Page:328.1 Line No.:7 Column:b
Various signatories to the Original Volume 11 Point-to-Point Transmission Tariff.
Schedule Page:328.1 Line No.:7 Column:c
Various signatories to the Original Volume 11 Point-to-Point Transmission Tariff.
Schedule Page:328.1 Line No.:7 Column:m
Transmission Loss.
Schedule Page:328.1 Line No.:8 Column:d
Deseret Generation&Transmission Coop.-FERC 280 -Contract Termination Date:April 18,2021.
Schedule Page:328.1 Line No.:9 Column:b
Various signatories to the Original Volume 11 Point-to-Point Transmission Tariff.
Schedule Page:328.1 Line No.:9 Column:c
Various signatories to the Original Volume 11 Point-to-Point Transmission Tariff.
Schedule Page:328.1 Line No.:9 Column:d
Non-firm.
Schedule Page:328.1 Line No.:9 Column:m
Transmission Loss.
Schedule Page:328.1 Line No.:10 Column:b
Various signatories to the Original Volume 11 Point-to-Point Transmission Tariff.
Schedule Page:328.1 Line No.:10 Column:c
Various signatories to the Original Volume 11 Point-to-Point Transmission Tariff.
Schedule Page:328.1 Line No.:10 Column:d
Non-firm.
Schedule Page:328.1 Line No.:10 Column:m
Transmission Loss.
Schedule Page:328.1 Line No.:11 Column:c
Various signatoriesto the Original Volume 11 Point-to-Point Transmission Tariff.
Schedule Page:328.1 Line No.:11 Column:m
Transmission Loss.
Schedule Page:328.1 Line No.:12 Column:b
Various signatoriesto the Original Volume 11 Point-to-PointTransmission Tariff.
Schedule Page:328.1 Line No.:12 Column:c
Various signatories to the Original Volume 11 Point-to-PointTransmission Tariff.
Schedule Page:328.1 Line No.:12 Column:d
Non-firm.
Schedule Page:328.1 Line No.:13 Column:b
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 31,2001
FOOTNOTE DATA
Various signatories to the Original Volume 11 Point-to-Point Transmission Tariff.
Schedule Page:328.1 Line No.:13 Column:c
Various signatories to the Original Volume 11 Point-to-Point Transmission Tariff.
Schedule Page:328.1 Line No.:13 Column:d
Non-firm.
Schedule Page:328.1 Line No.:14 Column:m
Transmission Loss.
Schedule Page:328.1 Line No.:15 Column:d
Fall River Rural Electric Coop -FERC 322 -Contract Termination Date:February4,2027.
Schedule Page:328.1 Line No.:16 Column:d
Flathead Electric Coop.,Inc.-FERC Vol.11 -Contract Termination Date:12 months advance notice.
Schedule Page:328.1 Line No.:16 Column:m
Network Integration Transmission Service.
Schedule Page:328.1 Line No.:17 Column:d
FlatheadElectric Cooperative Inc.-OV-11 -Subject to termination upon timely notification.
Schedule Page:328.1 Line No.:17 Column:m
Imbalance Energy.
Schedule Page:328.2 Line No.:1 Column:d
Idaho Power Company -OV-11 -Contract Termination Date:September 30,2002.
Schedule Page:328.2 Line No.:1 Column:m
Transmission Loss.
Schedule Page:328.2 Line No.:2 Column:d
Idaho Power Company -OV-11 -Contract Termination Date:September 30,2002.
Schedule Page:328.2 Line No.:3 Column:c
Various signatories to the Original Volume 11 Point-to-Point Transmission Tariff.
Schedule Page:328.2 Line No.:3 Column:d
Idaho Power Company -OV-11 -Contract Termination Date:May 1,2002.
Schedule Page:328.2 Line No.:4 Column:c
Various signatories to the Original Volume 11 Point-to-Point Transmission Tariff.
Schedule Page:328.2 Line No.:4 Column:d
Idaho Power Company -OV-11 -Contract Termination Date:May 1,2003.
Schedule Page:328.2 Line No.:5 Column:c
Various signatories to the Original Volume 11 Point-to-Point Transmission Tariff.
Schedule Page:328.2 Line No.:5 Column:d
Idaho Power Company -OV-11 -Contract Termination Date:May 31,2003.
Schedule Page:328.2 Line No.:6 Column:c
Various signatories to the Original Volume 11 Point-to-Point Transmission Tariff.
Schedule Page:328.2 Line No.:6 Column:d
Idaho Power Company -OV-11 -Contract Termination Date:December 2,2002.
Schedule Page:328.2 Line No.:7 Column:c
Various signatories to the Original Volume 11 Point-to-Point Transmission Tariff.
Schedule Page:328.2 Line No.:7 Column:d
Idaho Power Company -OV-11 -Contract Termination Date:June 30,2002.
Schedule Page:328.2 Line No.:8 Column:b
Various signatories to the Original Volume 11 Point-to-Point Transmission Tariff.
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 31,2001
FOOTNOTE DATA
Schedule Page:328.2 Line No.:8 Column:d
Idaho Power Company -OV-11 -Contract Termination Date:August 31,2002.
Schedule Page:328.2 Line No.:9 Column:b
Various signatories to the Original Volume 11 Point-to-PointTransmission Tariff.
Schedule Page:328.2 Line No.:9 Column:c
Various signatories to the Original Volume 11 Point-to-PointTransmission Tariff.
Schedule Page:328.2 Line No.:9 Column:m
Transmission Loss.
Schedule Page:328.2 Line No.:10 Column:b
Various signatories to the Original Volume 11 Point-to-PointTransmission Tariff.
Schedule Page:328.2 Line No.:10 Column:c
Various signatories to the Original Volume 11 Point-to-PointTransmission Tariff.
Schedule Page:328.2 Line No.:10 Column:d
Non-firm.
Schedule Page:328.2 Line No.:10 Column:m
Prior Period Adj.-True-up of Estimate
Schedule Page:328.2 Line No.:11 Column:b
Various signatories to the Original Volume 11 Point-to-Point Transmission Tariff.
Schedule Page:328.2 Line No.:11 Column:c
Various signatories to the Original Volume 11 Point-to-Point Transmission Tariff.
Schedule Page:328.2 Line No.:12 Column:b
Various signatories to the Original Volume 11 Point-to-Point Transmission Tariff.
Schedule Page:328.2 Line No.:12 Column:c
Various signatories to the Original Volume 11 Point-to-Point Transmission Tariff.
Schedule Page:328.2 Line No.:12 Column:d
Non-firm.
Schedule Page:328.2 Line No.:12 Column:m
Transmission Loss.
Schedule Page:328.2 Line No.:13 Column:b
Various signatories to the Original Volume 11 Point-to-Point Transmission Tariff.
Schedule Page:328.2 Line No.:13 Column:d
Non-firm.
Schedule Page:328.2 Line No.:14 'Column:d
Moon Lake -FERC 302 -Contract Termination Date:Year to year.
Schedule Page:328.2 Line No.:15 Column:b
Various signatories to the Original Volume 11 Point-to-Point Transmission Tariff.
Schedule Page:328.2 Line No.:15 Column:c
Various signatories to the Original Volume 11 Point-to-Point Transmission Tariff.
Schedule Page:328.2 Line No.:15 Column:m
Transmission Loss.
Schedule Page:328.2 Line No.:16 Column:b
Various signatories to the Original Volume 11 Point-to-PointTransmission Tariff.
Schedule Page:328.2 Line No.:16 Column:c
Various signatories to the Original Volume 11 Point-to-PointTransmission Tariff.
Schedule Page:328.2 Line No.:16 Column:d
Non-firm.
FERC FORM NO.1 (ED.12-87)Page 450.4
Name of Respondent This Reportis:Date of Report Year of Report
(1)X An Original (Mo,Da,Yr)
PacifiCorp (2)_A Resubmission //Dec 31,2001
FOOTNOTE DATA
Schedule Page:328.2 Line No.:17 Column:b
Various signatories to the Original Volume 11 Point-to-Point Transmission Tariff.
Schedule Page:328.2 Line No.:17 Column:c
Various signatories to the Original Volume 11 Point-to-Point Transmission Tariff.
Schedule Page:328.2 Line No.:17 Column:d
Non-firm.
Schedule Page:328.3 Line No.:1 Column:b
Various signatories to the Original Volume 11 Point-to-Point Transmission Tariff.
Schedule Page:328.3 Line No.:1 Column:c
Various signatories to the Original Volume 11 Point-to-Point Transmission Tariff.
Schedule Page:328.3 Line No.:2 Column:b
Various signatories to the Original Volume 11 Point-to-Point Transmission Tariff.
Schedule Page:328.3 Line No.:2 Column:c
Various signatories to the OriginalVolume 11 Point-to-Point Transmission Tariff.
Schedule Page:328.3 Line No.:2 Column:d
Non-firm.
Schedule Page:328.3 Line No.:2 Column:m
Transmission Loss.
Schedule Page:328.3 Line No.:3 Column:c
Various signatories to the OriginalVolume 11 Point-to-Point Transmission Tariff.
Schedule Page:328.3 Line No.:3 Column:d
Non-firm.
Schedule Page:328.3 Line No.:4 Column:b
Various signatories to the OriginalVolume 11 Point-to-Point Transmission Tariff.
Schedule Page:328.3 Line No.:4 Column:c
Various signatories to the OriginalVolume 11 Point-to-Point Transmission Tariff.
Schedule Page:328.3 Line No.:4 Column:d
Non-firm.
Schedule Page:328.3 Line No.:4 Column:m
Prior Period Adj.-True-up of Estimate
Schedule Page:328.3 Line No.:5 Column:b
Various signatories to the OriginalVolume 11 Point-to-Point Transmission Tariff.
Schedule Page:328.3 Line No.:5 Column:c
Various signatories to the OriginalVolume 11 Point-to-Point Transmission Tariff.
Schedule Page:328.3 Line No.:5 Column:m
Transmission Loss.
Schedule Page:328.3 Line No.:6 Column:d
Powerex -OV-11 -Contract Termination Date:May 31,2002.
Schedule Page:328.3 Line No.:7 Column:d
Powerex -OV-11 -Contract Termination Date:October 31,2003.
Schedule Page:328.3 Line No.:7 Column:m
Transmission Loss.
Schedule Page:328.3 Line No.:8 Column:b
Various signatories to the OriginalVolume 11 Point-to-PointTransmissionTariff.
Schedule Page:328.3 Line No.:8 Column:c
Various signatories to the OriginalVolume 11 Point-to-PointTransmissionTariff.
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 31,2001
FOOTNOTE DATA
Schedule Page:328.3 Line No.:8 Column:d
Non-firm.
Schedule Page:328.3 Line No.:8 Column:m
Transmission Loss.
Schedule Page:328.3 Line No.:9 Column:b
Various signatories to the Original Volume 11 Point-to-Point Transmission Tariff.
Schedule Page:328.3 Line No.:9 Column:c
Various signatories to the Original Volume 11 Point-to-Point Transmission Tariff.
Schedule Page:328.3 Line No.:9 Column:m
Transmission Loss.
Schedule Page:328.3 Line No.:10 Column:b
Various signatories to the Original Volume 11 Point-to-Point Transmission Tariff.
Schedule Page:328.3 Line No.:10 Column:c
Various signatoriesto the Original Volume 11 Point-to-Point Transmission Tariff.
Schedule Page:328.3 Line No.:10 Column:d
Non-firm.
Schedule Page:328.3 Line No.:10 Column:m
Prior Period Adj.-True-up of Estimate
Schedule Page:328.3 Line No.:11 Column:d
Public Service Company of Colorado -OV-11 -Contract Termination Date:December 31,2002.
Schedule Page:328.3 Line No.:12 Column:d
Public Service Company of Colorado -OV-11 -Contract Termination Date:December 31,2002.
Schedule Page:328.3 Line No.:13 Column:c
Various signatories to the Original Volume 11 Point-to-Point Transmission Tariff.
Schedule Page:328.3 Line No.:13 Column:d
Seawest Windpower,Inc.-OV-11 -Contract Termination Date:July 31,2014.
Schedule Page:328.3 Line No.:14 Column:b
Various signatories to the OriginalVolume 11 Point-to-Point Transmission Tariff.
Schedule Page:328.3 Line No.:14 Column:c
Various signatories to the OriginalVolume 11 Point-to-Point Transmission Tariff.
Schedule Page:328.3 Line No.:14 Column:d
Non-firm.
Schedule Page:328.3 Line No.:14 Column:m
Transmission Loss.
Schedule Page:328.3 Line No.:15 Column:b
Various signatories to the OriginalVolume 11 Point-to-Point Transmission Tariff.
Schedule Page:328.3 Line No.:15 Column:c
Various signatories to the OriginalVolume 11 Point-to-Point Transmission Tariff.
Schedule Page:328.3 Line No.:15 Column:d
Non-firm.
Schedule Page:328.3 Line No.:16 Column:b
Various signatoriesto the OriginalVolume 11 Point-to-Point Transmission Tariff.
Schedule Page:328.3 Line No.:16 Column:c
Various signatoriesto the OriginalVolume 11 Point-to-Point Transmission Tariff.
Schedule Page:328.3 Line No.:16 Column:m
Transmission Loss.
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 31,2001
FOOTNOTE DATA
Schedule Page:328.3 Line No.:17 Column:d
State of South Dakota -OV-11 -Contract Termination Date:May 31,2002.
Schedule Page:328.4 Line No.:1 Column:b
Various signatoriesto the Original Volume 11 Point-to-Point Transmission Tariff.
Schedule Page:328.4 Line No.:1 Column:c
Various signatoriesto the Original Volume 11 Point-to-Point Transmission Tariff.
Schedule Page:328.4 Line No.:1 Column:d
Non-firm.
Schedule Page:328.4 Line No.:1 Column:m
Transmission Loss.
Schedule Page:328.4 Line No.:2 Column:b
Various signatoriesto the Original Volume 11 Point-to-Point Transmission Tariff.
Schedule Page:328.4 Line No.:2 Column:c
Various signatoriesto the Original Volume 11 Point-to-Point Transmission Tariff.
Schedule Page:328.4 Line No.:2 Column:d
Non-firm.
Schedule Page:328.4 Line No.:2 Column:m
Transmission Loss.
Schedule Page:328.4 Line No.:3 Column:d
Tri-State Generation&Transmission Coop.-FERC 123 -Contact Termination Date:October 1,2014.
Schedule Page:328.4 Line No.:3 Column:m
Prior Period Adj.-True-up of Estimate
Schedule Page:328.4 Line No.:4 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:328.4 Line No.:4 Column:m
Fixed annual charge.
Schedule Page:328.4 Line No.:5 Column:d
Utah Associated Municipal Power -FERC 297 -Contract Termination Date:December 31,2003.
Schedule Page:328.4 Line No.:5 Column:m
Charges for monitoring,scheduling,load following and spinning reserve.
Schedule Page:328.4 Line No.:6 Column:b
Various signatories to the Original Volume 11 Point-to-Point Transmission Tariff.
Schedule Page:328.4 Line No.:6 Column:c
Various signatories to the Original Volume 11 Point-to-Point Transmission Tariff.
Schedule Page:328.4 Line No.:6 Column:d
Utah Municipal Power Agency -FERC 4 -Subject to termination upon 3 year written notice.
Schedule Page:328.4 Line No.:6 Column:m
Imbalance Energy.
Schedule Page:328.4 Line No.:7 Column:d
Utah Municipal Power Agency -FERC 279 -Under transfer agreements subject to termination upon timely notice.
Schedule Page:328.4 Line No.:7 Column:m
Charges for monitoring,scheduling,load following and spinning reserve.
Schedule Page:328.4 Line No.:8 Column:c
Various signatoriesto the Original Volume 11 Point-to-Point Transmission Tariff.
Schedule Page:328.4 Line No.:8 Column:d
FERC FORM NO.1 (ED.12-87)Page 450.7
Name of Respondent This Report is:Date of Report Year of Report
(1)X An Original (Mo,Da,Yr)
Pacificorp (2)_A Resubmission //Dec 31,2001
FOOTNOTE DATA
Non-firm.
Schedule Page:328.4 Line No.:9 Column:b
Various signatories to the Original Volume 11 Point-to-Point Transmission Tariff.
Schedule Page:328.4 Line No.:9 Column:c
Various signatories to the Original Volume 11 Point-to-Point Transmission Tariff.
Schedule Page:328.4 Line No.:9 Column:d
Western Area PowerAdministration -FERC 4 -Subject to termination upon 3 year written notice.
Schedule Page:328.4 Line No.:9 Column:m
Imbalance Energy.
Schedule Page:328.4 Line No.:10 Column:d
Western Area PowerAdministration -FERC 45 -Under transfer agreements subject to termination upon timely
notification.
Schedule Page:328.4 Line No.:10 Column:m
Prior Period Adj.-True-up of Estimate
Schedule Page:328.4 Line No.:11 Column:d
Western Area PowerAdministration -FERC 262/263 -Contract Termination Date:June 1,2047.
Schedule Page:328.4 Line No.:11 Column:m
Prior Period Adj.-True-up of Estimate
Schedule Page:328.4 Line No.:12 Column:d
Western Area Power Administration -FERC 262/263 -Contract Termination Date:June 1,2047.
Schedule Page:328.4 Line No.:13 Column:d
Western Area Power Administration -OV-11 -Contract Termination Date:May 31,2003.
Schedule Page:328.4 Line No.:14 Column:b
Various signatories to the Original Volume 11 Point-to-PointTransmission Tariff.
Schedule Page:328.4 Line No.:14 Column:d
Western Area Power Administration -OV-11 -Contract Termination Date:12 months advance notice.
Schedule Page:328.4 Line No.:14 Column:m
Network Integration Transmission Service.
Schedule Page:328.4 Line No.:15 Column:b
Various signatories to the Original Volume 11 Point-to-PointTransmission Tariff.
Schedule Page:328.4 Line No.:15 Column:c
Various signatories to the Original Volume 11 Point-to-PointTransmission Tariff.
Schedule Page:328.4 Line No.:15 Column:d
Non-firm.
Schedule Page:328.4 Line No.:15 Column:m
Prior Period Adj.-True-up of Estimate
Schedule Page:328.4 Line No.:16 Column:d
Western Area Power Administration -FERC 286 -Contract Termination Date:Four years written notice.
Schedule Page:328.4 Line No.:17 Column:b
Various signatories to the Original Volume 11 Point-to-Point Transmission Tariff.
Schedule Page:328.4 Line No.:17 Column:c
Various signatories to the Original Volume 11 Point-to-Point Transmission Tariff.
Schedule Page:328.4 Line No.:17 Column:d
Non-firm.
FERC FORM NO.1 (ED.12-87)Page 450.8
Name of Respondent This Report is:Date of Report Year of Report
(1)X An Original (Mo,Da,Yr)
PacifiCorp (2)A Resubmission //Dec 31,2001
FOOTNOTE DATA
Schedule Page:332 Line No.:1 Column:f
Prior period adjustment (true-up of estimate)and use of facilities.
Ancillary Services.
Schedule Page:332 Line No.:2 Column:f
Prior Period Adj.-True-up of Estimate
Schedule Page:332 Line No.:3 Column:f
Prior period adjustment (true-up of estimate)and use of facilities.
Schedule Page:332 Line No.:5 Column:f
Ancillary Services.
Prior Period Adj.-True-up of Estimate
Schedule Page:332 Line No.:6 Column:f
Prior Period Adj.-True-up of Estimate
Schedule Page:332 Line No.:9 Column:f
Use of Facilities.
Schedule Page:332 Line No.:10 Column:f
Prior period adjustment (true-up of estimate)and use of facilities.
Respondent's portion of specified costs of certain facilities.
Schedule Page:332 Line No.:11 Column:f
Ancillary Services.
Prior Period Adj.-True-up of Estimate
Schedule Page:332 Line No.:12 Column:f
Transmission service charges and administration fees.
Schedule Page:332 Line No.:13 Column:f
Prior Period Adj.-True-up of Estimate
Respondent's portion of specified costs of certain facilities.
Schedule Page:332 Line No.:14 Column:f
Prior Period Adj.-True-up of Estimate
Schedule Page:332 Line No.:15 Column:f
Use of Facilities.
Schedule Page:332 Line No.:16 Column:f
Ancillary Services.
Respondent's portion of specified costs of cedain facilities.
Schedule Page:332.1 Line No.:1 Column:f
Use of Facilities.
Respondent's portion of specified costs of certain facilities.
Schedule Page:332.1 Line No.:3 Column:f
Ancillary Services.
Prior Period Adj.-True-up of Estimate
Schedule Page:332.1 Line No.:4 Column:f
Ancillary Services.
Prior Period Adj.-True-up of Estimate
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 31,2001
FOOTNOTE DATA
Schedule Page:332.1 Line No.:6 Column:f
Ancillary Services.
Schedule Page:332.1 Line No.:8 Column:f
Use of Facilities.
Schedule Page:332.1 Line No.:11 Column:f
Prior period adjustment (true-up of estimate)and use of facilities.
Ancillary Services.
Settlement of losses.
Schedule Page:332.1 Line No.:12 Column:f
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 31,2001
FOOTNOTE DATA
Schedule Page:336 Line No.:11 Column:b
Account 403 includes a reduction of 14,432,838 for the depreciation of the regulatory
liability "1996 Depreciation Study"in account 254,wich is depreciated over 2 years and
various reclassifications of expense cost.
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 31,2001
FOOTNOTE DATA
Schedule Page:340.1 Line No.:27 Column:a
Based upon weighted average prime rate.
Schedule Page:340.1 Line No.:29 Column:a
Rates vary due to applicable law.
Schedule Page:340.1 Line No.:37 Column:a
Rates vary due to the programs offered,start dates of the loans,and the prime interestrateatthatpointoftime.
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 31,2001
FOOTNOTEDATA
Schedule Page:402 Line No.:-1 Column:c
Cholla Plant is operated by Arizona Public Service Company.Respondent owns Unit No.4plus37.23%of related common facilities.Data reported on lines 5 through 43 representsrespondent's share.
Schedule Page:402 Line No.:-1 Column:dColstripPlantisoperatedbyPPLMontana,LLC and is jointly owned.Data reported on
lines 5 through 43 represents respondent's 10%share of Colstrip Plant Units No.3 and No.
4.
Schedule Page:402 Line No.:-1 Column:e
Craig Plant is operated by Tri-State Generation and Transmission Association and isjointlyowned.Data reported on lines 5 through 43 represents respondent's 19.28%share
of Craig Plant Units No.1 and No.2.
Schedule Page:402.1 Line No.:-1 Column:b
Hayden Plant is operated by Public Service Company of Colorado and is jointly owned.Datareportedonlines5through43representsrespondent'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 common facilities.
Schedule Page:402.1 Line No.:-1 Column:c
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 (c)representsrespondent's share.
Schedule Page:402.1 Line No.:-1 Column:d
Hunter Plant Unit No.2 is owned by respondent,Deseret Power Electric Cooperative,and
Utah Associated Municipal Power Systems,each with undivided interest of 60.31%,25.108%,
and 14.582%respectively.Data reported in column (d)represents respondent's share.
Schedule Page:402.1 Line No.:-1 Column:f
This represents the respondent's share.Hunter Unit No.1 is owned by respondent and
Provo City Corporation with undivided interest of 93.75%and 6.25%respectively.Hunter
Unit No.2 is owned by respondent,Deserete Power Electric Cooperative,and Utah
Associated Municipal Power Systems,each with undivided interest of 60.31%,25.108%,and
14.582%respectively.
Schedule Page:402.2 Line No.:-1 Column:c
Jim Bridger Plant is operated by PacifiCorp and column (c)represents the respondent's
share.Ownership of the plant is as follows:PacifiCorp 66 2/3%,Idaho Power Company 331/3%.
Schedule Page:402.2 Line No.:-1 Column:e
Wyodak Plant is operated by PacifiCorp and column (e)represents the respondent's share.Ownership of the plants is as follows:PacifiCorp 80%,Black Hills Corporation 20%.
Schedule Page:402.3 Line No.:-1 Column:c
Hermiston Plant is operated by PacifiCorp effective 2/01/2001 and is jointly owned.Datareportedonlines5through43representsrespondent's 50.0%share of Hermiston Plant.
Schedule Page:402.3 Line No.:-1 Column:e
PacifiCorp owns the steam turbine generator and associated systems directly related to theoperationofthisunitattheJamesRiverCorporation's Camas,Washington paper mill.
Modifications and upgrades to the existing Camas paper mill were necesary to supply steam
to the turbine and to ensure continued operation of the unit in the event of mill closure.
James River retained ownership of these modifications.James River supplies the fuel and
delivers the steam to PacifiCorp's turbine.None of the facilities are jointly owned.
Each asset is wholly owned,either by PacifiCorp or James River Corporation.
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 31,2001
FOOTNOTE DATA
Schedule Page:406 Line No.:1 Column:b
Pondage for peaking -storage,Upper Klamath Lake
Schedule Page:406 Line No.:1 Column:c
Storage,Upper Klamath Lake
Schedule Page:406 Line No.:1 Column:d
Forebay for peaking.
Schedule Page:406 Line No.:1 Column:e
Forebay for peaking.
Schedule Page:406.1 Line No.:1 Column:bForebayforpeaking.
Schedule Page:406.1 Line No.:1 Column:d
Storage for regulation.
Schedule Page:406.1 Line No.:1 Column:e
Pondage for peaking -storage,Upper Klamath Lake.
Schedule Page:406.1 Line No.:1 Column:f
Storage,Lemolo Lake.
Schedule Page:406.2 Line No.:-1 Column:b
Storage,Lemolo Lake.
Schedule Page:406.2 Line No.:1 Column:d
Pondage for peaking -storage,Lemolo Lake.
Schedule Page:406.2 Line No.:1 Column:f
Forebay for peaking.
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 31,2001
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.:10 Column:a
Licensed Project No.2401 applicable to both Cove and Grace Plants (See page 406 for Graceplant).
Schedule Page:410 Line No.:29 Column:a
Licensed Project No.2381 applicable to both Ashton and St.Anthony plants.
Schedule Page:410 Line No.:35 Column:a
Used in regulating release of water from Klamath Lake and in maintaining proper water
surface level in Klamath River between Klamath Falls and Keno,Oregon.
Schedule Page:410 Line No.:36 Column:a
Storage reservoir for six plants on Klamath River (Copco No.1,Copco No.2,East Side,
West Side,John C.Boyle,and Iron Gate).
Schedule Page:410 Line No.:37 Column:a
Common plant in North Umpqua Project.All common roads,employee houses,controlequipment,etc.are in this account.
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 31,2001
FOOTNOTE DATA
Schedule Page:422 Line No.:23 Column:jIncludedAbove
Schedule Page:422 Line No.:23 Column:k
Included Above
Schedule Page:422 Line No.:23 Column:I
Included Above
Schedule Page:422.1 Line No.:4 Column:jIncludedBelow
Schedule Page:422.1 Line No.:4 Column:k
Included Below
Schedule Page:422.1 Line No.:4 Column:I
Included Below
Schedule Page:422.1 Line No.:13 Column:jIncludedAbove
Schedule Page:422.1 Line No.:13 Column:k
Included Above
Schedule Page:422.1 Line No.:13 Column:I
Included Above
Schedule Page:422.2 Line No.:21 Column:jIncludedBelow
Schedule Page:422.2 Line No.:21 Column:k
Included Below
Schedule Page:422.2 Line No.:21 Column:I
Included Below
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 31,2001
FOOTNOTE DATA
Schedule Page:431 Line No.:10 Column:b
Coal Mine Reclamation Costs $3,285,938
Interest on Pollution Control Bonds 14,506,920
Operation &Maintenance -Hatchery (201,015)Operation &Maintenance -Recreation 139,690
$17,731,533
FERC FORM NO.1 (ED.12-87)Page 450
INDEX
Scheduha Page No.
Accrued and prepaid taxes ...........................262-263AccumulatedDeferredIncomeTaxes..........................234
272-277
Accumulated provisions for depreciation of
common utility plant .........................356utilityplant.........................219utilityplant(swamary)...........................200-201
Advances
from associated companies ........................256-257
Allowances .........................228-229
Amortization
miscellaneous ..........................340ofnuclearfuel.............................202-203AppropriationsofRetainedEarnings..........................118-119
Associated Companies
advances from ...................................256-257
corporations controlled by respondent .........................103controloverrespondent.........................102
interest on debt to ..........................256-257
Attestation ..........................i
Balance sheet
comparative ...........................110-113
notes to ........................122-123
Bonds ........................256-257CapitalStock.........................251
discount ........................254
expense .........................254
installments recived ........................252
premiums ........................252reacquired........................251
subscribed ........................252
Cash flows,statement of ..........................120-121
Changes
important during year .........................108-109
Construction
overheads,electric ..................................217
overhead procedures,general description of ........................218
work in progress -common utility plant .......................356
work in progress -electric ............................216
work in progress -other utility departments ........................200-201
Control
corporations controlled by respondent .......................103
over respondent ............................102
security holders and voting powers ..........................106-107Corporation
controlled by .......................103
incorporated ........................101
CPA,background information on ........................101
CPA Certification,this report form ........................i-ii
FERC FORM NO.1 (ED.12-93)Index 1
INDEX(continued)
Schedule Paqe No.
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
INDEX (continued)
Schedule Paqe Nkl
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 Page No.
Plant -electric
accumulated provision for depreciation ..........................219
construction work in progress .............................216
held for future use ...........................214
in service ..........................204-207
leased to others ...................................................213
Plant -utility and accumulated provisions for depreciation
amortization and depletion (summary).........................201
Pollution control facilities,accumulated deferred
income taxes ...........................234
Power Exchanges ..................................326-327
Premium and discount on long-term debt ...........................256
Premium on capital stock .......................251
Prepaid taxes ...............................262-263
Property -losses,extraordinary .........................230
Pumped storage generating plant statistics ..........................408-409
Purchased power (including power exchanges)..........................326-327
Reacquired capital stock ..........................250
Reacquired long-term debt .........................256-257
Receivers'certificates ..........................................256-257
Reconciliation of reported net income with taxable income
from Federal income taxes ..........................261
Regulatory commission expenses deferred ..........................233
Regulatory commission expenses for year ........................350-351
Research,development and demonstration activities ........................352-353
Retained Earnings
amortization reserve Federal .........................119
appropriated .........................118-119
statement of,for the year ..........................118-119
unappropriated ..........................118-119
Revenues -electric operating ........................300-301
Salaries and wages
directors fees .........................105
distribution of .........................354-355
officers'.....................................104
Sales of electricity by rate schedules .........................304
Sales -for resale .......................310-311
Salvage -nuclear fuel .......................202-203
Schedules,this report form .........................2-4
Securities
exchange registration .......................250-251
holders and voting powers ........................106-107
Statement of Cash Flows .........................120-121
Statement of income for the year ..........................114-117
Statement of retained earnings for the year ........................118-119
Steam-electric generating plant statistics ........................402-403
Stock liability for conversion ..........................252
Substations ..........................426
Supplies -materials and .........................227
FERC FORM NO.1 (ED.12-90)Index 4
INDEX (continued)
Schedule Paqe hk
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