2015Annual Report.pdf

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An IDACORP CompanyftECT IVED
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LISA D. NORDSTROM
Lead Counsel
I [e-mail]
April 19,2016
Ms. Jean D. Jewell
Secretary
ldaho Public Utilities Commission
PO Box 83720
Boise, lD 83720-0074
Re: ldaho Power Company's 2015 Annual FERC Form 1 Report
Dear Ms. Jewell:
Per ldaho Code 61405, Idaho Power Company herewith transmits for electronic filing
its FERC Form 1 report and Idaho supplement for the year ending December 31, 2015.
Also included is the IDACORP 2015 Annual Report. These reports will also be provided
electronically.
If you have any questions, please contact Regulatory Analyst Kelley Noe at 208-
388-5736 or [e-mail].
Very truly yours,
A {,)L/l , /(/ )t2.u H / | 0, El ff/.i
-
v,I
Lisa D. Nordstroni
LDN:kkt
Enclosures
Form 1 ApprovedTHISFILINGIS
OMB No.1 902-0021
(Expires 11/30/2016)
Form 1 -F Approved
OMB No.1 902-0029
(Expires 11/30/2016)
Item 1 :0 An Initial (Original)
Submission
OR ?Resubmission No.
Form 3-Q Approved
OMB No.1 902-0205
(Expires 11/30/2016)
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FERC FINANCIAL REPORT
FERC FORM No.1 :Annual Report of
Major Electric Utilities,Licensees
and Others and Supplemental
Form 3-Q:Quarterly Financial Report
These reports are mandatory under the Federal Power Act,Sections 3,4(a),304 and 309,and
18 CFR 141.1 and 141.400.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 these reports to be of confidential nature
Exact Legal Name of Respondent (Company)
Idaho Power Company
Year/Period of Report
End of 2015/Q4
FERC FORM No.1/3-Q (REV.02-04)
This Page Intentionally Left Blank
FERC FORM NO.1/3-Q:
REPORT OF MAJOR ELECTRIC UTILITIES.LICENSEES AND OTHER
IDENTIFICATION
01 Exact Legal Name of Respondent
Idaho Power Company
02 Year/Period of Report
2Q15/Q4Endof
03 Previous Name and Date of Change (if name changed during year)
//
04 Address of Principal Office at End of Period (Street,City,State,Zip Code)
1221 W Idaho St,P.O.Box 70 Boise,Id 83707-0070
05 Name of Contact Person
Ken Petersen
06 Title of Contact Person
VP,Controller and CAO
07 Address of Contact Person (Street,City,State,Zip Code)
1221 W Idaho St,P.O.Box 70 Boise,Id 83707-0070
08 Telephone of Contact Person,Including 09 This Report Is
Area Code
[phone]
10 Date of Report
(Mo,Da,Yr)
04/15/2016
(1)(X]An Original (2)?A Resubmission
ANNUAL CORPORATE OFFICER CERTIFICATION
The undersigned officer certifies that:
I have examined this report and to the best of my knowledge,information,and belief all statements of fact contained in this report are correct statements
of the business affairs of the respondent and the financial statements,and other financial information contained in this report,conform in all material
respects to the Uniform System of Accounts.
01 Name
Ken Petersen
03 Signature 04 Date Signed
(Mo,Da,Yr)
02 Title
Vice President,Controller &CAO Ken Petersen 04/15/2016
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.1/3-Q (REV.02-04)Page 1
Name of Respondent
Idaho Power Company
This Report Is:
(1)fx]An Original
(2)||A Resubmission
LIST OF SCHEDULES (Electric Utility)
Date of Report
(Mo,Da,Yr)
04/15/2016
Year/Period of Report
2015/Q4Endof
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.
(b)(c)(a)
1 General Information 101
2 Control Over Respondent 102
3 Corporations Controlled by Respondent 103
4 Officers 104
1055Directors
6 Information on Formula Rates 106(a)(b)
7 Important Changes During the Year 108-109
8 Comparative Balance Sheet 110-113
Statement of Income for the Year 114-1179
1 0 Statement of Retained Earnings for the Year 118-119
11 Statement of Cash Flows 120-121
12 Notes to Financial Statements 122-123
13 Statement of Accum Comp Income,Comp Income,and Hedging Activities 122(a)(b)
14 Summary of Utility Plant &Accumulated Provisions for Dep,Amort &Dep 200-201
N/A15NuclearFuelMaterials202-203
16 Electric Plant in Service 204-207
N/A17ElectricPlantLeasedtoOthers213
18 Electric Plant Held for Future Use 214
19 Construction Work in Progress-Electric 216
20 Accumulated Provision for Depreciation of Electric Utility Plant 219
Investment of Subsidiary Companies21 224-225
22 Materials and Supplies 227
228(ab)-229(ab)N/A23Allowances
N/A24ExtraordinaryPropertyLosses230
N/A25UnrecoveredPlantandRegulatoryStudyCosts230
26 Transmission Service and Generation Interconnection Study Costs 231
27 Other Regulatory Assets 232
28 Miscellaneous Deferred Debits 233
29 Accumulated Deferred Income Taxes 234
30 Capital Stock 250-251
31 Other Paid-in Capital 253
32 Capital Stock Expense 254
256-25733Long-Term Debt
34 Reconciliation of Reported Net Income with Taxable Inc for Fed Inc Tax 261
35 Taxes Accrued,Prepaid and Charged During the Year 262-263
266-26736AccumulatedDeferredInvestmentTaxCredits
Page 2FERCFORMNO.1 (ED.12-96)
Name of Respondent
Idaho Power Company
This Report Is:
(1)[x]An Original
(2)A Resubmission
LIST OF SCHEDULES (Electric Ulility)(continued)
Date of Report
(Mo,Da,Yr)
04/15/2016
Year/Period of Report
2015/Q4Endof
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
Page No.
Remarks
No.
(a)(b)(c)
Other Deferred Credits37 269
38 Accumulated Deferred Income Taxes-Accelerated Amortization Property N/A272-273
39 Accumulated Deferred Income Taxes-Other Property 274-275
40 Accumulated Deferred Income Taxes-Other 276-277
41 Other Regulatory Liabilities 278
42 Electric Operating Revenues 300-301
43 Regional Transmission Service Revenues (Account 457.1 )N/A302
44 Sales of Electricity by Rate Schedules 304
45 Sales for Resale 310-311
46 Electric Operation and Maintenance Expenses 320-323
Purchased Power47 326-327
48 Transmission of Electricity for Others 328-330
49 Transmission of Electricity by ISO/RTOs 331 N/A
50 Transmission of Electricity by Others 332
Miscellaneous General Expenses-Electric51 335
52 Depreciation and Amortization of Electric Plant 336-337
Regulatory Commission Expenses53 350-351
54 Research,Development and Demonstration Activities 352-353
55 Distribution of Salaries and Wages 354-355
56 Common Utility Plant and Expenses N/A356
Amounts included in ISO/RTO Settlement Statements N/A57397
58 Purchase and Sale of Ancillary Services 398
59 Monthly Transmission System Peak Load 400
60 Monthly ISO/RTO Transmission System Peak Load 400a N/A
61 Electric Energy Account 401
Monthly Peaks and Output62 401
63 Steam Electric Generating Plant Statistics 402-403
64 Hydroelectric Generating Plant Statistics 406-407
65 Pumped Storage Generating Plant Statistics 408-409 N/A
66 Generating Plant Statistics Pages 410-411
Page 3FERCFORMNO.1 (ED.12-96)
Name of Respondent
Idaho Power Company
This Report Is:
(1)|X|An Original
(2)||A Resubmission
LIST OF SCHEDULES (Electric Utility)(continued)
Date of Report
(Mo,Da,Yr)
04/15/2016
Year/Period of Report
2015/Q4Endof
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 RemarksReference
Page No.No,
(a)(b)(c)
67 Transmission Line Statistics Pages 422-423
68 Transmission Lines Added During the Year 424-425
69 Substations 426-427
70 Transactions with Associated (Affiliated)Companies 429
71 Footnote Data 450
Stockholders'Reports Check appropriate box:
PC|Two copies will be submitted
]No annual report to stockholders is prepared
Page 4FERCFORMNO.1 (ED.12-96)
Name of Respondent
Idaho Power Company
Year/Period of ReportThisReportIs:
(1)[X]An Original
(2)?A Resubmission
Date of Report
(Mo,Da,Yr)
04/15/2016 2015/Q4Endof
GENERAL INFORMATION
1 .Provide name 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.
Ken Petersen Vice President,Controller and CAO,Idaho Power Company
1221 W.Idaho Street,P.O.Box 70,Boise,Idaho 83707-0070
2.Provide the name of the State under the laws of which respondent is incorporated,and date of incorporation.
If incorporated under a special law,give reference to such law.If not incorporated,state that fact and give the type
of organization and the date organized.
Idaho,June 30,1989
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
4.State the classes or utility and other services furnished by respondent during the year in each State in which
the respondent operated.
Class of Utility Service
Electric
Electric
State
Idaho
Oregon
5.Have you 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 )Q Yes...Enter the date when such independent accountant was initially engaged:
(2)(X]No
FERC FORM No.1 (ED.12-87)PAGE 101
Year/Period of ReportNameofRespondent
Idaho Power Company
This Report Is:
(1)[X]An Original
(2)?A Resubmission
Date of Report
(Mo,Da,Yr)
04/15/2016 2015/Q4Endof
CONTROL OVER RESPONDENT
1 .If any corporation,business trust,or similar organization or a combination of such organizations jointly held
control over the repondent at the end of the year,state name of controlling corporation or organization,manner in
which control was held,and extent of control.If control was in a holding company organization,show the chain
of ownership or control to the main parent company or organization.If control was held by a trustee(s),state
name of trustee(s),name of beneficiary or beneficiearies for whom trust was maintained,and purpose of the trust.
Idaho Power Company is a subsidiary of IDACORP,INC
IDACORP owns 100%of Idaho Power Company's Common Stock.
IDACORP is a public utility Holding Company incorporated effective 10-1-1998
FERC FORM NO.1 (ED.12-96)Page 102
Year/Period of Report
2015/Q4
Date of Report
{Mo,Da,Yr)
04/15/2016
This Report Is:
(1)[X]An Original
(2)||A Resubmissi
Name of Respondent
Idaho Power Company End of
on
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.
FootnoteKindofBusinessPercentVoting
Stock Owned
Name of Company ControlledLine
Ref,No.
(d)(b)(c)(a)
Direct Control1
100%Coal mining and mineral2IdahoEnergyResourcesCompany
development3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
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25
26
27
Page 103FERCFORMNO.1 (ED.12-96)
Date of Report
{Mo,Da,Yr)
04/15/2016
Year/Period of Report
2015/Q4
This Report Is:
(1)[x]An Original
(2)||A Resubmission
Name of Respondent
Idaho Power Company End of
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
respondent includes its president,secretary,treasurer,and vice president in charge of a principal business unit,division or function
(such as sales,administration or finance),and any other person who performs similar policy making functions.
2.If a change was made during the year in the incumbent of any position,show name and total remuneration of the previous
incumbent,and the date the change in incumbency was made.
Salary
for Year
Title Name of OfficerLine
No.(c)(b)(a)
1
675,000DarrelT.Anderson2President&Chief Executive Officer
3
460,0004ExecutiveVicePresident&Chief Operating Officer Dan Minor
5
350,0006SeniorVicePresident&General Counsel Rex Blackburn
7
345,000StevenKeenSeniorVicePresident,CFO &Treasurer8
9
320,000LisaGrowSeniorVicePresident,Power Supply10
11
260,000JeffreyMalmenVicePresident,Public Affairs12
13
260,000SeniorVicePresident,Customer Operations Vern Porter14
15
250,000VicePresident,Fluman Resources,Admin Services,&CIO Lonnie Krawl16
17
242,000LoriSmithVicePresident,&Chief Risk Officer18
19
235,000KenPetersenVicePresident,Corporate Controller &CAO20
21
217,000GregorySaidVicePresidentofRegulatoryAffairs22
23
188,000PatrickHarringtonCorporateSecretary24
25
Warren Kline (1)159,750SeniorVicePresident,Customer Operations26
27
127,307LuciMcDonald(2)Vice President,Human Resources &Corporate Services28
29
(1)Retirement effective 6/30/15.Base shows YTD wages30
(2)Retirement effective 5/31/15.Base shows YTD wages31
32
33
34
35
36
37
38
39
40
41
42
43
44
Page 104FERCFORMNO.1 (ED.12-96)
Year/Period of Report
2015/Q4
Name of Respondent
Idaho Power Company
This Report Is:
(1)[xj An Original
(2)||A Resubmission
DIRECTORS
Date of Report
(Mo,Da,Yr)
04/15/2016
End of
1 .Report below the information called for concerning each director of the respondent who held office at any time during the year.Include in column (a),abbreviated
titles of the directors who are officers of the respondent,
2.Designate members of the Executive Committee by a triple asterisk and the Chairman ofthe Executive Committee by a double asterisk.
LiiTe Principal Business AddressName(and Title;of DirectorNo.(b)(a)
1
10446 E.Palo Brea Dr.,Scottsdale,Arizona 852622JudithA.Johansen
3
8527 East Old Field Rd4ChristineKing'
Scottsdale,Arizona 852665
6
2719 North Woodview place,Boise Idaho 837027ThomasCarlile
8
900 W.Bogus View Drive,Eagle,Idaho 836169JanB.Packwood (1)
10
Idaho Power Company,1221 W.Idaho Street,Darrel T.Anderson President &CEO,11
P.O.Box 70,Boise,Idaho 83707-007012
13
481 North Strata Via Way,Boise Idaho 8371214J.LaMont Keen
15
16
2309 S.W.First Avenue,No.1141,Portland,Oregon 97201JoanSmith(2)17
18
4433 W.Quail Point Court,Boise,Idaho 8370319RobertA.Tinstman ***
20
1504 Warm Springs AvenueThomasWilford(3)21
Boise,Idaho 8371222
23
Richard Dahl ***60 Laiki PI.24
Kailua,Hawaill 9673425
26
United Heritage Life Insurance27DennisL.Johnson
707 E.United Heritage Ct.,Ste 130,Meridian,Idaho 8364228
29
Questar Corporation30RonaldW.Jibson
333 South State Street,Salt Lake City,Utah 84145-043331
32
1256 E.Candleridge Ct.,Boise,Idaho 8371233RichardJ.Navarro (4)
34
(1)Retired on May 21,201535
(2)Retired on May 21,201536
37 (3)Retired on May 21,2015
38 (4)Appointed to Board February 10,2015
39
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Page 105FERCFORMNO.1 (ED.12-95)
Year/Period of Report
End of 2015/Q4
Name of Respondent
Idaho Power Company
This Report Is:
(1)[X]An Original
(2)||A Resubmission
INFORMATION ON FORMULA RATES
Oale of Report
(Mo.Da,Yr)
04/15/2016
FERC Rate Schedule/Tariff Number FERC Proceeding
Does the respondent have formula rates?fX|Yes
?No
1.Please list the Commission accepted formula rates including FERC Rate Schedule or Tariff Number and FERC proceeding (i.e.Docket No)
accepting the rate(s)or changes in the accepted rate.
Line
No.FERC Rate Schedule or Tariff Number FERC Proceeding
1 FERC Electric Tariff
2
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5
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FERC FORM NO.1 (NEW.12-08)Page 106
Name of Respondent
Idaho Power Company
This Report Is:
(1)[X]An Original
(2)|—|A Resubmission
INFORMATION ON FORMULA RATES
Date of Report
(Mo.Da,Yr)
04/15/2016
Year/Period of Report
End of 2015/Q4
FERC Rate Schedule/Tariff Number FERC Proceeding
Does the respondent file with the Commission annual (or more frequent)
filings containing the inputs to the formula rate(s)?
|"Xj Yes
?No
2.If yes,provide a listing of such filings as contained on the Commission's eLibrary website
Document
Date
\Filed Date
Formula Rate FERC Rate
Schedule Number or
Tariff Number
Line
No.Accession No.DescriptionDocketNo.
201508285322 08/28/2015 ER09-1641-000 Idaho Power Companj FERC Electirc Tariff1
2 2015 Annua
3 Informational Fillinc
under ER-09-1 641-00C4
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FERC FORM NO.1 (NEW.12-08)Page 106a
Name of Respondent
Idaho Power Company
This Report Is;
(1)[X]An Original
(2)||A Resubmission
INFORMATION ON FORMULA RATES
Date of Report
(Mo.Da,Yr)
04/15/2016
Year/Period of Report
End of 2015/Q4
Formula Rate Variances
1 .If a respondent does not submit such filings then indicate in a footnote to the applicable Form 1 schedule where formula rate inputs differ from
amounts reported in the Form 1 .
2.The footnote should provide a narrative description explaining how the "rate"(or billing)was derived if different from the reported amount in the
Form 1.
3.The footnote should explain amounts excluded from the ratebase or where labor or other allocation factors,operating expenses,or other items
impacting formula rate inputs differ from amounts reported in Form 1 schedule amounts.
4.Where the Commission has provided guidance on formula rate inputs,the specific proceeding should be noted in the footnote.
Line
No.Column Line NoPageNo(s).Schedule
1
2
3
4
5
6
7
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FERC FORM NO.1 (NEW.12-08)Page 106b
Year/Period of Report
End of 2015/Q4
Name of Respondent
Idaho Power Company
This Report Is:
(1)[X]An Original
(2)Q A Resubmission
Date of Report
04/15/2016
IMPORTANT CHANGES DURING THE QUARTER/YEAR
Give particulars (details)concerning the matters indicated below.Make the statements explicit and precise,and number them in
accordance with the inquiries.Each inquiry should be answered.Enter "none,""not applicable,"or "NA"where applicable.If
information which answers an inquiry is given elsewhere in the report,make a reference to the schedule in which it appears.
1 .Changes in and important additions to franchise rights:Describe the actual consideration given therefore and state from whom the
franchise rights were acquired.If acquired without the payment of consideration,state that fact.
2.Acquisition of ownership in other companies by reorganization,merger,or consolidation with other companies:Give names of
companies involved,particulars concerning the transactions,name of the Commission authorizing the transaction,and reference to
Commission authorization.
3.Purchase or sale of an operating unit or system:Give a brief description of the property,and of the transactions relating thereto,
and reference to Commission authorization,if any was required.Give date journal entries called for by the Uniform System of Accounts
were submitted to the Commission.
4.Important leaseholds (other than leaseholds for natural gas lands)that have been acquired or given,assigned or surrendered:Give
effective dates,lengths of terms,names of parties,rents,and other condition.State name of Commission authorizing lease and give
reference to such authorization.
5.Important extension or reduction of transmission or distribution system:State territory added or relinquished and date operations
began or ceased and give reference to Commission authorization,if any was required.State also the approximate number of
customers added or lost and approximate annual revenues of each class of service.Each natural gas company must also state major
new continuing sources of gas made available to it from purchases,development,purchase contract or otherwise,giving location and
approximate total gas volumes available,period of contracts,and other parties to any such arrangements,etc.
6.Obligations incurred as a result of issuance of securities or assumption of liabilities or guarantees including issuance of short-term
debt and commercial paper having a maturity of one year or less.Give reference to FERC or State Commission authorization,as
appropriate,and the amount of obligation or guarantee.
7.Changes in articles of incorporation or amendments to charter:Explain the nature and purpose of such changes or amendments.
8.State the estimated annual effect and nature of any important wage scale changes during the year.
9.State briefly the status of any materially important legal proceedings pending at the end of the year,and the results of any such
proceedings culminated during the year.
10.Describe briefly any materially important transactions of the respondent not disclosed elsewhere in this report in which an officer,
director,security holder reported on Page 104 or 105 of the Annual Report Form No.1 ,voting trustee,associated company or known
associate of any of these persons was a party or in which any such person had a material interest.
11.(Reserved.)
12.If the important changes during the year relating to the respondent company appearing in the annual report to stockholders are
applicable in every respect and furnish the data required by Instructions 1 to 1 1 above,such notes may be included on this page.
13.Describe fully any changes in officers,directors,major security holders and voting powers of the respondent that may have
occurred during the reporting period.
14.In the event that the respondent participates in a cash management program(s)and its proprietary capital ratio is less than 30
percent please describe the significant events or transactions causing the proprietary capital ratio to be less than 30 percent,and the
extent to which the respondent has amounts loaned or money advanced to its parent,subsidiary,or affiliated companies through a
cash management program(s).Additionally,please describe plans,if any to regain at least a 30 percent proprietary ratio.
PAGE 108 INTENTIONALLY LEFT BLANK
SEE PAGE 109 FOR REQUIRED INFORMATION.
FERC FORM NO.1 (ED.12-96)Page 108
Date of Report Year/Period of Report
(Mo,Da,Yr)
04/15/2016
Name of Respondent This Report is:
(1)X An Original
(2)_A Resubmission 2015/Q4IdahoPowerCompany
IMPORTANT CHANGES DURING THE QUARTER/YEAR (Continued)
1.None
2 .None
To enhance the abilities of Idaho Power and PacifiCorp to serve their respective
customers,on October 24,2014,Idaho Power and PacifiCorp executed a Joint Ownership and
Operating Agreement (Joint Operating Agreement)applicable to certain transmission-related
equipment to be exchanged by Idaho Power and PacifiCorp.The exchange was made pursuant to
the terms of a Joint Purchase and Sale Agreement,also dated October 24,2014,between
Idaho Power and PacifiCorp,under which each party agreed to transfer to the other
specified transmission-related equipment with an estimated year-end 2014 net book value of
approximately $43 million,subject to true-up as of the closing date.The transaction also
provided for the termination and amendment of a number of legacy long-term agreements
related to the ownership and operation of jointly-owned facilities and transmission
services between Idaho Power and PacifiCorp.Idaho Power received FERC approval of the
transaction on June 17,2015 (See:Idaho Power Co.,PacifiCorp,151 FERC 1 61,233 (2015).
FERC Docket No.EC15-54-000J .As a condition of approval,FERC required Idaho Power and
PacifiCorp to submit final accounting for the transaction within six months of the
transaction's closing.(See:Idaho Power Co.,PacifiCorp,Order Authorizing Acquisition
and Disposition of Jurisdictional Facilities,151 FERC 1 61,233 (2015).The transaction
closed on October 30,2015 and final accounting will be submitted to FERC on or before
3.
April 30,2016.
4 .None
5.None
6.Disclosed in Financial Statement footnotes,see pages 123.13 to 123.14
7 .None
Effective 01/03/2015 a 3.0%general wage adjustment was implemented8.
9.Disclosed in Financial Statement footnotes,see pages 123.18 to 123.19
All of the below related person transactions were reviewed and approved by the
Idaho Power Board of Directors and the Corporate Governance and Nominating Committee.
10.
Steven R.Keen,Idaho Power's Senior Vice President,Chief Financial Officer
and Treasurer is the brother of J.LaMont Keen,a member of Idaho Power's
board of directors.
Rex Blackburn is the Sr.Vice President and General Counsel of Idaho power.
His brother-in-law,Gary Betts,is also an employee of Idaho Power.
Patrick A.Harrington is the Corporate Secretary of Idaho Power.His brother,
Jamie Harrington,is also an employee of Idaho Power.
Lori D.Smith was the Vice President and Chief Risk Officer of Idaho Power in
2015.Her husband,Matt Smith,was also an employee of Idaho Power in 2015.
11.None
12.None
13.Director Changes in 2015:
?Richard J.Navarro appointed to Board 2/11/2015
»Jan B.Packwood,Joan H.Smith,and Thomas J.Wilford retired from the Board
5/21/2015
Officer Changes in 2015:
'Warren Kline retired as Sr.Vice President-Customer Operations effective
FERC FORM NO.1 (ED.12-96)Page 109.1
Date of Report Year/Period of ReportThisReportis:
(1)X An Original
(2)_A Resubmission
IMPORTANT CHANGES DURING THE QUARTER/YEAR (Continued)
Name of Respondent
(Mo,Da,Yr)
2015/Q404/15/2016IdahoPowerCompany
6/30/2015
McDonald retired as Vice President-Human Resources and CorporateLuciK.
Services effective 5/31/2015
•N.Vern Porter title changed from "Vice President"to "Sr.Vice President of
Customer Operations"effective 4/1/2015
•Lonnie G.Krawl title changed from "Vice President and Chief Information
Officer"to "Vice President of Human Resources,Administrative Services and
Chief Information Officer"effective 4/1/2015
Officer changes approved in 2015 but not effective until 2016:
•Daniel B.Minor title change from "Executive Vice President and Chief
Operating Officer"to "Executive Vice President"
•Lisa A.Grow title change from "Sr.Vice President-Power Supply to "Sr.Vice
President of Operations"
•N.Vern Porter title change from "Sr.Vice President of Customer Operations"
to "Vice President of Customer Operations"
•Lonnie G.Krawl title change from "Vice President and Chief Information
Officer"to "Sr.Vice President of Administrative Services and Chief
Information Officer"
•Tessia R.Park new appointment to "Vice President of Power Supply"
•Jeffrey S.Glenn new appointment to "Vice President of Information Technology"
Idaho Power and its unregulated parent,IDACORP have separate cash management
programs (separate bank accounts,liquidity facilities,short-term debt and investment
programs).No money has been loaned or advanced from Idaho Power to IDACORP through a cash
management program.
14 .
FERC FORM NO.1 (ED.12-96)Page 109.2
Year/Period of ReportDateofReport
(Mo,Da,Yr)
04/15/2016
Name of Respondent
Idaho Power Company
This Report Is:
(1)g|An Original
End Of 2015/Q4(2)?A Resubmission
COMPARATIVE BALANCE SHEET (ASSETS AND OTHER DEBITS)
Prior Year
End Balance
12/31
Current Year
End of Quarter/Year
Balance
Line Ref.No.Page No.Title of Account
(d)(c)(b)(a)
1 UTILITY PLANT
5,255,302,7625,492,554,138200-2012UtilityPlant(101-106,114)
401,929,509200-201 396,931,3723ConstructionWorkinProgress(107)
5,657,232,2715,889,485,510TOTALUtilityPlant(Enter Total of lines 2 and 3)4
2,021,073,827(Less)Accum.Prov.for Depr.Amort.Depl.(108,110,111,115)2,097,432,010200-2015
3,636,158,4443,792,053,500NetUtilityPlant(Enter Total of line 4 less 5)6
0NuclearFuelinProcessofRef.,Conv.,Enrich.,and Fab.(120.1)202-203 07
0NuclearFuelMaterialsandAssemblies-Stock Account (120.2)08
00NuclearFuelAssembliesinReactor(120.3)9
0 010SpentNuclearFuel(120.4)
0011NuclearFuelUnderCapitalLeases(120.6)
0(Less)Accum.Prov.for Amort,of Nucl.Fuel Assemblies (120.5)012202-203
00NetNuclearFuel(Enter Total of lines 7-11 less 12)13
3,636,158,4443,792,053,500NetUtilityPlant(Enter Total of lines 6 and 13)14
0 015UtilityPlantAdjustments(116)
0GasStoredUnderground-Noncurrent (117)016
17 OTHER PROPERTY AND INVESTMENTS
1,555,4801,555,480NonutilityProperty(121)18
00(Less)Accum.Prov.for Depr.and Amort.(122)19
00InvestmentsinAssociatedCompanies(123)20
84,137,401 83,477,460InvestmentinSubsidiaryCompanies(123.1)224-22521
(For Cost of Account 123.1 ,See Footnote Page 224,line 42)22
0 0228-22923NoncurrentPortionofAllowances
64741624OtherInvestments(124)
00SinkingFunds(125)25
00DepreciationFund(126)26
00AmortizationFund-Federal (127)27
24,560,677 45,082,33528OtherSpecialFunds(128)
0 0SpecialFunds(Non Major Only)(129)29
126,480 63,323Long-Term Portion of Derivative Assets (175)30
0 0Long-Term Portion of Derivative Assets -Hedges (176)31
130,179,245TOTALOtherPropertyandInvestments(Lines 18-21 and 23-31)110,380,45432
CURRENT AND ACCRUED ASSETS33
00CashandWorkingFunds(Non-major Only)(130)34
100,745,383 46,581,57835Cash(131)
1,637,072 1,079,26036SpecialDeposits(132-134)
13,60010,600WorkingFund(135)37
100,00010,000,000TemporaryCashInvestments(136)38
0 039NotesReceivable(141)
75,650,719 85,040,915CustomerAccountsReceivable(142)40
23,486,155 14,677,44141OtherAccountsReceivable(143)
4,650,829(Less)Accum.Prov.for Uncollectible Acct.-Credit (144)1 ,355,04242
1,156,202 2,053,197NotesReceivablefromAssociatedCompanies(145)43
0 0AccountsReceivablefromAssoc.Companies (146)44
55,170,48222761,818,25745FuelStock(151)
599046FuelStockExpensesUndistributed(152)227
00Residuals(Elec)and Extracted Products (153)22747
50,305,47952,445,228PlantMaterialsandOperatingSupplies(154)22748
0 022749Merchandise(155)
0 0OtherMaterialsandSupplies(156)22750
202-203/227 0 0NuclearMaterialsHeldforSale(157)51
0 0228-22952Allowances(158.1 and 158.2)
FERC FORM NO.1 (REV.12-03)Page 110
Year/Period of ReportDateofReport
(Mo,Da,Yr)
04/15/2016
Name of Respondent
Idaho Power Company
This Report Is:
(1)[X|An Original
End of 2015/04(2)?A Resubmission
COMPARATIVE BALANCE SHEET (ASSETS AND OTHER DEBITS()Continued)
Prior Year
End Balance
12/31
Current Year
End of Quarter/Year
Balance
Line Ref.No.Page No,Title of Account
(d)(b)(c)(a)
0053(Less)Noncurrent Portion of Allowances
5,098,7604,478,320StoresExpenseUndistributed(163)22754
00GasStoredUnderground-Current (164.1)55
0LiquefiedNaturalGasStoredandHeldforProcessing(164.2-164.3)056
18,355,58917,845,551Prepayments(165)57
0058AdvancesforGas(166-167)
0InterestandDividendsReceivable(171)059
0RentsReceivable(172)060
56,269,64265,804,60861AccruedUtilityRevenues(173)
Miscellaneous Current and Accrued Assets (174)0062
634,183405,239DerivativeInstrumentAssets(175)63
63,323(Less)Long-Term Portion of Derivative Instrument Assets (175)126,48064
0065DerivativeInstrumentAssets-Hedges (176)
0(Less)Long-Term Portion of Derivative Instrument Assets -Hedges (176 066
330,666,573414,001,81267TotalCurrentandAccruedAssets(Lines 34 through 66)
68 DEFERRED DEBITS
15,815,91016,539,636UnamortizedDebtExpenses(181)69
0230a070ExtraordinaryPropertyLosses(182.1)
0UnrecoveredPlantandRegulatoryStudyCosts(182.2)230b 071
1,237,823,7242321,355,572,12872OtherRegulatoryAssets(182.3)
873,9391,17773Prelim.Survey and Investigation Charges (Electric)(183)
0074PreliminaryNaturalGasSurveyandInvestigationCharges183.1)
Other Preliminary Survey and Investigation Charges (183.2)0075
1,053,3241,650,91076ClearingAccounts(184)
00TemporaryFacilities(185)77
45,564,713MiscellaneousDeferredDebits(186)233 66,701,29578
0Def.Losses from Disposition of Utility Pit.(187)079
0Research,Devel.and Demonstration Expend.(188)352-353 080
12,799,88829,731,07281UnamortizedLossonReaquiredDebt(189)
270,188,395 289,103,58423482AccumulatedDeferredIncomeTaxes(190)
0083UnrecoveredPurchasedGasCosts(191)
1,603,035,0821,740,384,61384TotalDeferredDebits(lines 69 through 83)
5,700,039,3446,056,820,379TOTALASSETS(lines 14-16,32,67,and 84)85
FERC FORM NO.1 (REV.12-03)Page 111
Name of Respondent
Idaho Power Company
This Report is:
(1)[x]An Original
(2)?A Resubmission
Date of Report
(mo,da,yr)
04/15/2016
Year/Period of Report
2015/Q4endof
COMPARATIVE BALANCE SHEET (LIABILITIES AND OTHER CREDITS)
Current Year
End of Quarter/Year
Balance
Prior Year
End Balance
12/31
Line Ref.No.Title of Account Page No.
(a)(b)(c)(d)
PROPRIETARY CAPITAL1
Common Stock Issued (201)2 250-251 97,877,030 97,877,030
3 Preferred Stock Issued (204)250-251 00
4 Capital Stock Subscribed (202,205)0 0
5 Stock Liability for Conversion (203,206)0 0
Premium on Capital Stock (207)6 712,257,435 712,257,435
Other Paid-in Capital (208-211)7 253 00
8 Installments Received on Capital Stock (212)252 00
9 (Less)Discount on Capital Stock (213)254 0 0
10 (Less)Capital Stock Expense (214)254b 2,096,925 2,096,925
11 Retained Earnings (215,215.1,216)118-119 1,045,751,377 952,335,875
12 Unappropriated Undistributed Subsidiary Earnings (216.1)118-119 81,014,36681,674,308
13 (Less)Reaquired Capital Stock (217)250-251 0 0
14 Noncorporate Proprietorship (Non-major only)(218)0 0
Accumulated Other Comprehensive Income (219)15 122(a)(b)-21,275,735 -24,157,999
16 Total Proprietary Capital (lines 2 through 15)1,914,187,490 1,817,229,782
LONG-TERM DEBT17
18 Bonds (221)256-257 1,725,460,000 1,595,460,000
19 (Less)Reaquired Bonds (222)256-257 0 0
20 Advances from Associated Companies (223)256-257 0 0
21 Other Long-Term Debt (224)256-257 22,012,273 23,075,909
22 Unamortized Premium on Long-Term Debt (225)0 0
(Less)Unamortized Discount on Long-Term Debt-Debit (226)23 4,458,587 3,034,022
24 Total Long-Term Debt (lines 18 through 23)1,743,013,686 1,615,501,887
25 OTHER NONCURRENT LIABILITIES
26 Obligations Under Capital Leases -Noncurrent (227)00
27 Accumulated Provision for Property Insurance (228.1)00
28 Accumulated Provision for Injuries and Damages (228.2)1,994,9721,873,877
29 Accumulated Provision for Pensions and Benefits (228.3)394,131,877 403,474,921
30 Accumulated Miscellaneous Operating Provisions (228.4)0 3,865,254
31 Accumulated Provision for Rate Refunds (229)87,689,554 72,974,757
32 Long-Term Portion of Derivative Instrument Liabilities 0 0
33 Long-Term Portion of Derivative Instrument Liabilities -Hedges 0 0
34 Asset Retirement Obligations (230)26,152,620 21,930,049
35 Total Other Noncurrent Liabilities (lines 26 through 34)504,239,953509,847,928
36 CURRENT AND ACCRUED LIABILITIES
37 Notes Payable (231)0 0
38 Accounts Payable (232)119,524,930 113,979,552
39 Notes Payable to Associated Companies (233)0 0
40 Accounts Payable to Associated Companies (234)2,027,2201,058,872
41 Customer Deposits (235)4,731,724 1,568,822
42 Taxes Accrued (236)262-263 5,192,418 -10,635,253
43 Interest Accrued (237)22,387,590 22,670,165
44 Dividends Declared (238)00
45 Matured Long-Term Debt (239)0 0
FERC FORM NO.1 (rev.12-03)Page 112
Date of Report
(mo,da,yr)
04/15/2016
Year/Period of ReportNameofRespondent
Idaho Power Company
This Report is:
(1)0 An Original
(2)?A Resubmission 2015/Q4endof
COMPARATIVE BALANCE SHEET (LIABILITIES AND OTHER CREDI"K&)itinued)
Prior Year
End Balance
12/31
Current Year
End of Quarter/Year
Balance
Line Ref.No.Title of Account Page No.
(b)(c)(d)(a)
Matured Interest (240)0 046
Tax Collections Payable (241)1,921,386 2,599,09947
53,364,600 40,889,48048MiscellaneousCurrentandAccruedLiabilities(242)
49 Obligations Under Capital Leases-Current (243)0 0
50 Derivative Instrument Liabilities (244)4,972,600 3,960,704
(Less)Long-Term Portion of Derivative Instrument Liabilities 0 051
Derivative Instrument Liabilities -Hedges (245)0 052
53 (Less)Long-Term Portion of Derivative Instrument Liabilities-Hedges 0 0
54 Total Current and Accrued Liabilities (lines 37 through 53)213,154,120 177,059,789
DEFERRED CREDITS55
Customer Advances for Construction (252)4,678,929 3,303,55356
79,654,930 79,162,831AccumulatedDeferredInvestmentTaxCredits(255)266-26757
58 Deferred Gains from Disposition of Utility Plant (256)0 0
Other Deferred Credits (253)269 11,757,998 1 1 ,635,64259
Other Regulatory Liabilities (254)67,711,655 64,843,26960278
Unamortized Gain on Reaquired Debt (257)0 061
Accum.Deferred Income Taxes-Accel.Amort.(281)0 062272-277
1,349,907,020 1,248,630,36163Accum.Deferred Income Taxes-Other Property (282)
178,432,27764Accum.Deferred Income Taxes-Other (283)162,906,623
65 Total Deferred Credits (lines 56 through 64)1,676,617,155 1,586,007,933
66 TOTAL LIABILITIES AND STOCKHOLDER EQUITY (lines 16,24,35,54 and 65)6,056,820,379 5,700,039,344
FERC FORM NO.1 (rev.12-03)Page 113
?ate of Report
(Mo,Da,Yr)
04/15/2016
Year/Period of Report
2015/Q4
Name of Respondent
Idaho Power Company
This Report Is:
(1)[X]An Original
(2)||A Resubmission
STATEMENT OF INCOME
End of
Quarterly
1 .Report in column (c)the current year to date balance.Column (c)equals the total of adding the data in column (g)plus the data in column (i)plus the
data in column (k).Report in column (d)similar data for the previous year.This information is reported in the annual filing only.
2.Enter in column (e)the balance for the reporting quarter and in column (f)the balance for the same three month period for the prior year.
3.Report in column (g)the quarter to date amounts for electric utility function;in column (i)the quarter to date amounts for gas utility,and in column (k)
the quarter to date amounts for other utility function for the current year quarter.
4.Report in column (h)the quarter to date amounts for electric utility function;in column (j)the quarter to date amounts for gas utility,and in column (I)
the quarter to date amounts for other utility function for the prior year quarter.
5.If additional columns are needed,place them in a footnote.
Annual or Quarterly if applicable
5.Do not report fourth quarter data in columns (e)and (f)
6.Report amounts for accounts 412 and 413,Revenues and Expenses from Utility Plant Leased to Others,in another utility columnin a similar manner to
a utility department.Spread the amount(s)over lines 2 thru 26 as appropriate.Include these amounts in columns (c)and (d)totals.
7.Report amounts in account 414,Other Utility Operating Income,in the same manner as accounts 412 and 413 above.
Current 3 Months
Ended
Quarterly Only
No 4th Quarter
Prior 3 Months
Ended
Quarterly Only
No 4th Quarter
Total
CurrentYearto
Date Balance for
Quarter/Year
Total
Prior Year to
Date Balance for
Quarter/Year
Line
No.
(Ref.)
Page No.Title of Account
(e)(f)(b)(c)(d)(a)
II1UTILITYOPERATINGINCOME
1,266,201,447 1,277,640,9772OperatingRevenues(400)300-301
3 Operating Expenses
4 Operation Expenses (401)320-323 731,125,349 780,281,536
320-323 69,399,154 68,283,3045MaintenanceExpenses(402)
6 Depreciation Expense (403)130,382,128 125,245,540336-337
549,017 495,0297DepreciationExpenseforAssetRetirementCosts(403.1 )336-337
7,172,3828Amort.&Depl.of Utility Plant (404-405)336-337 7,095,926
9 Amort,of Utility Plant Acq.Adj.(406)336-337
10 Amort.Property Losses,Unrecov Plant and Regulatory Study Costs (407)
1 1 Amort,of Conversion Expenses (407)
12 Regulatory Debits (407.3)82,611 73,650
1 3 (Less)Regulatory Credits (407.4)
14 Taxes Other Than IncomeTaxes (408.1)32,808,301 31,748,230262-263
12,593,365 -7,413,73315IncomeTaxes-Federal (409.1)262-263
5,986,110 6,908,58316-Other (409.1)262-263
152,963,21717ProvisionforDeferredIncomeTaxes(410.1)234,272-277 86,269,807
18 (Less)Provision forDeferred Income Taxes-Cr.(411.1)234,272-277 58,085,989 134,837,097
19 Investment Tax Credit Adj.-Net(411 .4)492,099 41,541266
20 (Less)Gains from Disp.of Utility Plant (41 1.6)
21 Losses from Disp.of Utility Plant (411 .7)
22 (Less)Gains from Disposition of Allowances (41 1 .8)97,422 186,382
23 Losses from Disposition of Allowances (411 .9)
24 Accretion Expense (411.10)232,049 309,716
1,018,832,505 1,031,085,51625TOTALUtilityOperatingExpenses(Enter Total of lines 4 thru 24)
26 Net Util Oper Inc (Enter Tot line 2 less 25)Carry to Pg117,line 27 247,368,942 246,555,461
FERC FORM NO.1/3-Q (REV.02-04)Page 114
Year/Period of Report
End of
This Report Is:
(1)fx]An Original
(2)||A Resubmission
STATEMENT OF INCOME FOR THE YEAR (Continued)
Date of Report
(Mo,Da,Yr)
04/15/2016
Name of Respondent
Idaho Power Company 2015/Q4
9.Use page 122 for important notes regarding the statement of income for any account thereof.
10.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 material refund to the utility with respect to power or gas purchases.State for each year effected
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 or gas purchases.
1 1 Give concise explanations concerning significant amounts of any refunds made or received during the year resulting from settlement of any rate
proceeding affecting revenues received or costs incurred for power or gas purches,and a summary of the adjustments made to balance sheet,income,
and expense accounts.
12.If any notes appearing in the report to stokholders are applicable to the Statement of Income,such notes may be included at page 122.
13.Enter on page 122 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 appropriate dollar effect of such changes.
14.Explain in a footnote if the previous year's/quarter's figures are different from that reported in prior reports.
15.If the columns are insufficient for reporting additional utility departments,supply the appropriate account titles report the information in a footnote to
this schedule.
OTHER UTILITYGASUTILITYELECTRICUTILITY
LineCurrentYeartoDate
(in dollars)
Previous Year to Date
(in dollars)
Previous Year to Date
(in dollars)
Current Year to Date
(in dollars)
Previous Year to Date
(in dollars)
Current Year to Date
(in dollars)No.
(I)(i)G)(k)(g)(h)
1
21,277,640,9771,266,201,447
3
4731,125,349 780,281,536
569,399,154 68,283,304
6125,245,540130,382,128
495,029 7549,017
87,172,3827,095,926
9
10
11
1282,611 73,650
13
1431,748,23032,808,301
1512,593,365 -7,413,733
165,986,110 6,908,583
1786,269,807 152,963,217
1858,085,989 134,837,097
1941,541492,099
20
21
2297,422 186,382
23
24309,716232,049
251,018,832,505 1,031,085,516
26247,368,942 246,555,461
Page 115FERCFORMNO.1 (ED.12-96)
Year/Period of Report
End of
Date of Report
(Mo,Da,Yr)
04/15/2016
This Report Is:
(1)[X]An Original
(2)_n
Name of Respondent
Idaho Power Company 2015/Q4
A Resubmission
STATEMENT OF INCOME FOR THE YEAR (continued)
Prior 3 Months
Ended
Quarterly Only
No 4th Quarter
Current3 Months
Ended
Quarterly Only
Current Year Previous Year No 4th Quarter
TOTALLine
No.
(Ref.)
Page No.Title ofAccount
(f)(e)(b)(c)(a)(d)
246,555,46127NetUtilityOperatingIncome(Carried forward from page 1 14)
28 Other Income and Deductions
29 Other Income
30 Nonutilty Operating Income
1,009,9101,304,08531RevenuesFromMerchandising,Jobbing and Contract Work (415)
1,485,862 1,136,66932(Less)Costs and Exp,of Merchandising,Job.&Contract Work (416)
33,733 37,54733RevenuesFromNonutilityOperations(417)
10,586 22,82834(Less)Expenses of Nonutility Operations (417.1)
-527-79135NonoperatingRentalIncome(418)
7,092,8871196,659,94236EquityinEarningsofSubsidiaryCompanies(418.1)
3,039,556 2,704,62037InterestandDividendIncome(419)
21,785,246 17,930,89838AllowanceforOtherFundsUsedDuringConstruction(419.1)
2,453,9472,365,84239MiscellaneousNonoperatingIncome(421)
4,240-2040GainonDispositionofProperty(421.1)
30,065,54533,691,14541TOTALOtherIncome(Enter Total of lines 31 thru 40)
42 Other Income Deductions
2,15643LossonDispositionofProperty(421 .2)
44 Miscellaneous Amortization (425)
750,960 747,09445Donations(426.1)
-1,164,064-1,738,80446LifeInsurance(426.2)
27,10648,30547Penalties(426.3)
1,561,9211,477,63348Exp,forCertain Civic,Political &Related Activities (426.4)
8,332,4319,937,00049OtherDeductions(426.5)
9,506,64410,475,09450TOTALOtherIncomeDeductions(Total of lines 43 thru 49)
51 Taxes Applic.to Other Income and Deductions
21,055 24,797262-26352TaxesOtherThanIncomeTaxes(408.2)
353,061 -914,126262-26353IncomeTaxes-Federal (409.2)
-41,215262-263 69,36254IncomeTaxes-Other (409.2)
1,085,673234,272-277 5,911,61355ProvisionforDeferredInc.Taxes (410.2)
2,008,392234,272-277 8,478,30056(Less)Provision for Deferred Income Taxes-Cr.(411.2)
57 InvestmentTax CreditAdj.-Net (411.5)
58 (Less)InvestmentTax Credits (420)
-2,123,209 -1,853,26359TOTALTaxesonOtherIncomeandDeductions(Total of lines 52-58)
22,412,16425,339,26060NetOtherIncomeandDeductions(Total of lines 41 ,50,59)
61 Interest Charges
83,055,805 80,561,92062InterestonLong-Term Debt (427)
1,556,825 1,610,77363Amort,ofDebt Disc,and Expense (428)
1,521,812 1,060,58564AmortizationofLossonReaquiredDebt(428.1)
65 (Less)Amort,of Premium on Debt-Credit (429)
66 (Less)Amortization of Gain on Reaquired Debt-Credit (429.1)
6,859 10,52467InterestonDebttoAssoc.Companies (430)
5,627,193 4,800,93968OtherInterestExpense(431)
10,043,775 8,464,10969(Less)Allowance for Borrowed Funds Used During Construction-Cr.(432)
79,580,63281,724,71970NetInterestCharges(Total of lines 62 thru 69)
190,983,483 189,386,99371IncomeBeforeExtraordinaryItems(Total oflines 27,60 and 70)
72 Extraordinary Items
73 Extraordinary Income (434)
74 (Less)Extraordinary Deductions (435)
75 Net Extraordinary Items (Total of line 73 less line 74)
262-26376IncomeTaxes-Federal and Other(409.3)
77 Extraordinary Items AfterTaxes (line 75 less line 76)
190,983,483 189,386,99378NetIncome(Total of line 71 and 77)
Page 117FERCFORMNO.1/3-Q (REV.02-04)
6
This Page Intentionally Left Blank
This Report Is:
(1)[x]An Original
(2)||A Resubmission
Date of Report
(Mo,Da,Yr)
04/15/2016
Year/Period of Report
End of
Name of Respondent
Idaho Power Company 2015/Q4
STATEMENT OF RETAINED EARNINGS
1 .Do not report Lines 49-53 on the quarterly version.
2.Report all changes in appropriated retained earnings,unappropriated retained earnings,year to date,and unappropriated
undistributed subsidiary earnings for the year.
3.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)
4.State the purpose and amount of each reservation or appropriation of retained earnings.
5.List first account 439,Adjustments to Retained Earnings,reflecting adjustments to the opening balance of retained earnings.Follow
by credit,then debit items in that order.
6.Show dividends for each class and series of capital stock.
7.Show separately the State and Federal income tax effect of items shown in account 439,Adjustments to Retained Earnings.
8.Explain in a footnote the basis for determining the amount reserved or appropriated.If such reservation or appropriation is to be
recurrent,state the number and annual amounts to be reserved or appropriated as well as the totals eventually to be accumulated.
9.If any notes appearing in the report to stockholders are applicable to this statement,include them on pages 122-123.
Current
Quarter/Year
Year to Date
Balance
Previous
Quarter/Year
Year to Date
Balance
Contra Primary
Account AffectedItemLine
(c)(d)(a)(b)No.
UNAPPROPRIATED RETAINED EARNINGS (Account 216)
836,965,502939,062,7691Balance-Beginning of Period
2 Changes
3 Adjustments to Retained Earnings (Account 439)
4
5
6
7
8
9 TOTAL Credits to Retained Earnings (Acct.439)
10
11
12
13
14
15 TOTAL Debits to Retained Earnings (Acct.439)
182,294,106184,323,54116BalanceTransferredfromIncome(Account 433 less Account 418.1)
1 7 Appropriations of Retained Earnings (Acct.436)
6,613,580)18
19
20
21
(6,613,580)22 TOTAL Appropriations of Retained Earnings (Acct.436)
23 Dividends Declared-Preferred Stock (Account 437)
24
25
26
27
28
29 TOTAL Dividends Declared-Preferred Stock (Acct.437)
30 Dividends Declared-Common Stock (Account 438)
88,583,259)-96,908,03931
32
33
34
35
(88,583,259)36 TOTAL Dividends Declared-Common Stock (Acct.438)-96,908,039
15,000,0006,000,00037TransfersfromAcct216.1,Unapprop.Undistrib.Subsidiary Earnings
939,062,76938Balance-End of Period (Total 1,9,15,16,22,29,36,37)1,032,478,271
APPROPRIATED RETAINED EARNINGS (Account 21 5)
FERC FORM NO.1/3-Q (REV.02-04)Page 118
Year/Period of Report
End of
Name of Respondent
Idaho Power Company
This Report Is:
(1)fx]An Original
(2)|—|AResubmi
STATEMENT OF RETAINED EARNINGS
?ate of Report
(Mo,Da,Yr)
04/15/2016
2015/Q4
ssion
1 .Do not report Lines 49-53 on the quarterly version.
2.Report all changes in appropriated retained earnings,unappropriated retained earnings,year to date,and unappropriated
undistributed subsidiary earnings for the year.
3.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)
4.State the purpose and amount of each reservation or appropriation of retained earnings.
5.List first account 439,Adjustments to Retained Earnings,reflecting adjustments to the opening balance of retained earnings.Follow
by credit,then debit items in that order.
6.Show dividends for each class and series of capital stock.
7.Show separately the State and Federal income tax effect of items shown in account 439,Adjustments to Retained Earnings.
8.Explain in a footnote the basis for determining the amount reserved or appropriated.If such reservation or appropriation is to be
recurrent,state the number and annual amounts to be reserved or appropriated as well as the totals eventually to be accumulated.
9.If any notes appearing in the report to stockholders are applicable to this statement,include them on pages 122-123.
Current
Quarter/Year
Year to Date
Balance
Previous
Quarter/Year
Year to Date
Balance
Contra Primary
Account AffectedItemLine
(d)(c)(a)(b)No.
39
40
41
42
43
44
45 TOTAL Appropriated Retained Earnings (Account 215)
APPROP.RETAINED EARNINGS -AMORT.Reserve,Federal (Account 215.1)
13,273,10646TOTALApprop.Retained Earnings-Amort.Reserve,Federal (Acct.215.1)13,273,106
13,273,10647TOTALApprop.Retained Earnings (Acct.215,215.1)(Total 45,46)13,273,106
952,335,87548TOTALRetainedEarnings(Acct.215,215.1,216)(Total 38,47)(216.1)1,045,751,377
UNAPPROPRIATED UNDISTRIBUTED SUBSIDIARY EARNINGS (Account
Report only on an Annual Basis,no Quarterly
88,921,47981,014,36649Balance-Beginning of Year (Debit or Credit)
7,092,88750EquityinEarningsforYear(Credit)(Account 418.1)6,659,942
15,000,00051(Less)Dividends Received (Debit)6,000,000
52
81,014,36653Balance-End of Year (Total lines 49 thru 52)81,674,308
FERC FORM NO.1/3-Q (REV.02-04)Page 119
Date of Report
(Mo.Da,Yr)
04/15/2016
Year/Period of Report
2015/Q4
Name of Respondent
Idaho Power Company
This Report Is:
(1)pg An Original
(2)|—|A Resubmission
STATEMENT OF CASH FLOWS
End of
(1 )Codes to be used:(a)Net Proceeds or Payments;(b)Bonds,debentures and other long-term debt;(c)Include commercial paper;and (d)Identify separately such items as
investments,fixed assets,intangibles,etc.
(2)Information about noncash investing and financing activities must be provided in the Notes to the Financial statements.Also provide a reconciliation between "Cash and Cash
Equivalents at End of Period"with related amounts on the Balance Sheet.
(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 in the Notes to the Financials the amounts of interest paid (net of amount capitalized)and income taxes paid.
(4)Investing Activities:Include at Other (line 31 )net cash outflow to acquire other companies.Provide a reconciliation of assets acquired with liabilities assumed in the Notes to
the Financial Statements.Do not include on this statement the dollar amount of leases capitalized per the USofA General Instruction 20;instead provide a reconciliation of the
dollar amount of leases capitalized with the plant cost.
Current Year to Date
Quarter/Year
Previous Year to Date
Quarter/Year
Description (See Instruction No.1 for Explanation of Codes)Line
No.
(a)(b)(c)
1 Net Cash Flow from Operating Activities:
190,983,483 189,386,9932NetIncome(Line 78(c)on page 117)
3 Noncash Charges (Credits)to Income:
125,245,540130,382,1284DepreciationandDepletion
11,590,185 11,250,9015Amortizationof(detail in footnote):
6
7
17,218,2768DeferredIncomeTaxes(Net)25,793,350
26,6659InvestmentTaxCreditAdjustment(Net)315,879
22,570,5403,988,71910Net(Increase)Decrease in Receivables
-8,079,325 -15,385,70211Net(Increase)Decrease in Inventory
12 Net (Increase)Decrease in Allowances Inventory
17,501,301 -18,687,81813NetIncrease(Decrease)in Payables and Accrued Expenses
16,794,04114Net(Increase)Decrease in Other Regulatory Assets 1,465,215
15,341,86115NetIncrease(Decrease)in Other Regulatory Liabilities 12,233,990
17,930,89821,785,24616(Less)Allowance for Other Funds Used During Construction
659,942 -7,907,11317(Less)Undistributed Earnings from Subsidiary Companies
-18,199,440 4,789,85518Other(provide details in footnote):
19
20
21
358,527,36722NetCashProvidedby(Used in)Operating Activities (Total 2 thru 21)345,530,297
23
24 Cash Flows from Investment Activities:
25 Construction and Acquisition of Plant (including land):
-315,753,782 -291,841,49526GrossAdditionstoUtilityPlant(less nuclear fuel)
27 Gross Additions to Nuclear Fuel
28 Gross Additions to Common Utility Plant
29 Gross Additions to Nonutility Plant
-21,785,246 -17,930,89830(Less)Allowance for Other Funds Used During Construction
13,456,680 3,551,44331Other(provide details in footnote):
32
33
-280,511,856 -270,359,15434CashOutflowsforPlant(Total of lines 26 thru 33)
35
36 Acquisition of Other Noncurrent Assets (d)
37 Proceeds from Disposal of Noncurrent Assets (d)
38
-15,317,37939InvestmentsinandAdvancestoAssoc.and Subsidiary Companies 896,996
40 Contributions and Advances from Assoc.and Subsidiary Companies
41 Disposition of Investments in (and Advances to)

42 Associated and Subsidiary Companies
43
-8,000,000-44,105,63844PurchaseofInvestmentSecurities(a)
45 Proceeds from Sales of Investment Securities (a)34,243,180
FERC FORM NO.1 (ED.12-96)Page 120
Year/Period of Report
End of
Name of Respondent
Idaho Power Company
This Report Is:
(1)[X]An Original
(2)|—|A Resubmission
STATEMENT OF CASH FLOWS
Date of Report
(Mo,Da,Yr)
04/15/2016
2015/Q4
(1)Codes to be used:(a)Net Proceeds or Payments;(b)Bonds,debentures and other long-term debt;(c)Include commercial paper;and (d)Identify separately such items as
investments,fixed assets,intangibles,etc,
(2)Information about noncash investing and financing activities must be provided in the Notes to the Financial statements.Also provide a reconciliation between "Cash and Cash
Equivalents at End of Period"with related amounts on the Balance Sheet,
(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 in the Notes to the Financials the amounts of interest paid (net of amount capitalized)and income taxes paid.
(4)Investing Activities:Include at Other (line 31 )net cash outflow to acquire other companies.Provide a reconciliation of assets acquired with liabilities assumed in the Notes to
the Financial Statements.Do not include on this statement the dollar amount of leases capitalized per the USofA General Instruction 20;instead provide a reconciliation ofthe
dollar amount of leases capitalized with the plant cost.
Previous Year to Date
Quarter/Year
Current Year to Date
Quarter/Year
Description (See Instruction No.1 for Explanation of Codes)Line
No.
(a)(b)M
46 Loans Made or Purchased
47 Collections on Loans
48
50,20849Net(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
-1,374,426 4,906,08553Other(provide details in footnote):
54
55
56 Net Cash Provided by (Used in)Investing Activities
-290,851,744 -288,720,24057Totaloflines34thru55)
58
59 Cash Flows from Financing Activities:
60 Proceeds from Issuance of:
250,000,00061Long-Term Debt (b)
62 Preferred Stock
63 Common Stock
64 Other (provide details in footnote);
65
66 Net Increase in Short-Term Debt (c)
67 Other (provide details in footnote):
68
69
70 Cash Provided by Outside Sources (Total 61 thru 69)250,000,000
71
72 Payments for Retirement of:
-1,063,63673Long-term Debt (b)-121,063,637
74 Preferred Stock
75 Common Stock
-22,646,07276Other(provide details in footnote):
77
78 Net Decrease in Short-Term Debt (c)
79
80 Dividends on Preferred Stock
-96,908,039 -88,583,259DividendsonCommonStock81
82 Net Cash Provided by (Used in)Financing Activities
-89,646,8959,382,25283(Total of lines 70 thru 81)
84
85 Net Increase (Decrease)in Cash and Cash Equivalents
64,060,805 -19,839,76886(Total of lines 22,57 and 83)
87
46,695,178 66,534,94688CashandCashEquivalentsatBeginningofPeriod
89
110,755,983 46,695,17890CashandCashEquivalentsatEndofperiod
FERC FORM NO.1 (ED.12-96)Page 121
This Page Intentionally Left Blank
Name of Respondent Date of Report Year/Period of ReportThisReportis:
(1)X An Original (Mo,Da,Yr)
(2)A Resubmission 2015/Q4IdahoPowerCompany04/15/2016
FOOTNOTE DATA
Schedule Page:120 Line No.:5 Column:b
Amortization
Plant
Unamortized debt expense
Unamortized discount
Water rights
Other
7,095,926
3,090,337
290,435
1,042,009
71.478
11,590,185
Schedule Page:120 Line No.:13 Column:b
Cash paid during the period for:
Income taxes
Interest (net of amount capitalized)
3,547,630
79,225,751
Schedule Page:120 Line No.:18 Column:b
Cash Flow from Operating Activities (Other)
Pension and postretirement benefit plan expense
Contributions to pension and postretirement benefit plans
Unbilled revenues
Prepayments
Company owned life insurance
Deposits from third parties
Other
30,185,123
(42,821 ,074)
(7,691,484)
922,055
5,327,068
5,309,053
(9,430,181)
(18,199,440)
]Schedule Page:120 Line No.:26 Column:b
Non-cash investing activities:
Additions to PP&E in accounts payable 23,839,605
Schedule Page:120 Line No.:31 Column:b
Other Cash Flows from Plant
Sale of utility property 71,180
11,377,277
2,008,223
Payments received from joint funding partners
Sale of emission allowances and renewable energy certificates
13,456,680
Schedule Page:120 Line No.:53 Column:b
Other Investing Cash Flows
EDC plan investments
Feasibility study costs
Miscellaneous other investing activities
32,308
(1,406,964)
230
(1,374,426)
Schedule Page:120 Line No.:76 Column:b
Other Financing Cash Flows
Make-whole premium on retirement of long-term debt
Debt issuance costs
Discount on debt issuance
(17,871,600)
(3,059,472)
(1,715,000)
(22,646,072)
FERC FORM NO.1 (ED.12-87)Page 450.1
Date of Report
(Mo,Da,Yr)
04/15/2016
Year/Period of Report
End of 2015/Q4
Name of Respondent
Idaho Power Company
This Report Is:
(1)[Xj An Original
(2)||A Resubmission
STATEMENTS OF ACCUMULATED COMPREHENSIVE INCOME,COMPREHENSIVE INCOME,AND HEDGING ACTIVITIES
1.Report in columns (b),(c),(d)and (e)the amounts of accumulated other comprehensive income items,on a net-of-tax basis,where appropriate.
2.Report in columns (f)and (g)the amounts of other categories of other cash flow hedges.
3.For each category of hedges that have been accounted for as "fair value hedges",report the accounts affected and the related amounts in a footnote.
4.Report data on a year-to-date basis.
Other
Adjustments
Foreign Currency
Hedges
Unrealized Gains and
Losses on Available-
for-Sale Securities
Minimum Pension
Liability adjustment
(net amount)
ItemLine
No.
(e)(d)(c)(a)(b)
1 Balance of Account 219 at Beginning of
Preceding Year (16,553,375)
2 Preceding Qtr/Yr to Date Reclassifications
from Acct 219 to Net Income 1,728,379
3 Preceding Quarter/Year to Date Changes in
Fair Value (9,333,003)
(7,604,624)4 Total (lines 2 and 3)
5 Balance of Account 219 at End of
Preceding Quarter/Year (24,157,999)
6 Balance of Account 219 at Beginning of
Current Year (24,157,999)
7 Current Qtr/Yr to Date Reclassifications
from Acct 219 to Net Income 2,667,521
8 Current Quarter/Year to Date Changes in
Fair Value 214,743
2,882,2649Total(lines 7 and 8)
10 Balance of Account 219 at End of Current
Quarter/Year (21,275,735)
FERC FORM NO.1 (NEW 06-02)Page 122a
Date of Report
(Mo,Da,Yr)
04/15/2016
Year/Period of Report
End of 2015/Q4
Name of Respondent
Idaho Power Company
This Report Is:
(1)[x]An Original
(2)||A Resubmission
STATEMENTS OF ACCUMULATED COMPREHENSIVE INCOME,COMPREHENSIVE INCOME,AND HEDGING ACTIVITIES
Total
Comprehensive
Income
Totals for each
category of items
recorded in
Account 219
Net Income (Carried
Forward from
Page 117,Line 78)
Other Cash Flow
Hedges
Interest Rate Swaps
Other Cash Flow
Hedges
[Specify]
Line
No.
0)0)(h)(f)(g)
(16,553,375)1
2 1,728,379
(9,333,003)3
(7,604,624)181,782,369189,386,9934
(24,157,999)5
(24,157,999)6
2,667,5217
214,7438
193,865,7472,882,264 190,983,4839
(21,275,735)10
FERC FORM NO.1 (NEW 06-02)Page 122b
Name of Respondent
Idaho Power Company
This Report Is:
(1)[X]An Original
(2)?A Resubmission
NOTES TO FINANCIAL STATEMENTS
Date of Report Year/Period of Report
End of 2015/Q404/15/2016
1.Use the space below for important notes regarding the Balance Sheet,Statement of Income for the year,Statement of Retained
Earnings for the year,and Statement of Cash Flows,or any account thereof.Classify the notes according to each basic statement,
providing a subheading for each statement except where a note is applicable to more than one statement.
2.Furnish particulars (details)as to any significant contingent assets or liabilities existing at end of year,including a brief explanation of
any action initiated by the Internal Revenue Service involving possible assessment of additional income taxes of material amount,or of a
claim for refund of income taxes of a material amount initiated by the utility.Give also a brief explanation of any dividends in arrears on
cumulative preferred stock.
3.For Account 116,Utility Plant Adjustments,explain the origin of such amount,debits and credits during the year,and plan of
disposition contemplated,giving references to Cormmission orders or other authorizations respecting classification of amounts as plant
adjustments and requirements as to disposition thereof
4.Where Accounts 189,Unamortized Loss on Reacquired Debt,and 257,Unamortized Gain on Reacquired Debt,are not used,give an
explanation,providing the rate treatment given these items.See General Instruction 17 of the Uniform System of Accounts
5.Give a concise explanation of any retained earnings restrictions and state the amount of retained earnings affected by such
restrictions.
6.If the notes to financial statements relating to the respondent company appearing in the annual report to the stockholders are
applicable and furnish the data required by instructions above and on pages 1 14-121,such notes may be included herein,
7.For the 3Q disclosures,respondent must provide in the notes sufficient disclosures so as to make the interim information not
misleading.Disclosures which would substantially duplicate the disclosures contained in the most recent FERC Annual Report may be
omitted.
8.For the 3Q disclosures,the disclosures shall be provided where events subsequent to the end of the most recent year have occurred
which have a material effect on the respondent.Respondent must include in the notes significant changes since the most recently
completed year in such items as:accounting principles and practices;estimates inherent in the preparation of the financial statements;
status of long-term contracts;capitalization including significant new borrowings or modifications of existing financing agreements;and
changes resulting from business combinations or dispositions.However were material contingencies exist,the disclosure of such matters
shall be provided even though a significant change since year end may not have occurred.
9.Finally,if the notes to the financial statements relating to the respondent appearing in the annual report to the stockholders are
applicable and furnish the data required by the above instructions,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
Date of Report Year/Period of Report
(Mo,Da,Yr)
04/15/2016
Name of Respondent This Report is:
(1)X An Original
(2)_A Resubmission
NOTES TO FINANCIAL STATEMENTS (Continued)
2015/Q4IdahoPowerCompany
IDAHO POWER COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
1.SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
Idaho Power Company (Idaho Power)is the principal operating subsidiary ofIDACORP Inc.(IDACORP),a holding company
formed in 1998.Idaho Power is an electric utility with a service area covering approximately 24,000 square miles in southern Idaho
and eastern Oregon.Idaho Power is regulated primarily by the Federal Energy Regulatory Commission (FERC)and the state
regulatory commissions of Idaho and Oregon.Idaho Power is the parent of Idaho Energy Resources Co.(IERCo),a joint venturer in
Bridger Coal Company (BCC),which mines and supplies coal to the Jim Bridger generating plant owned in part by Idaho Power.
Basis of Reporting
The financial statements include the assets,liabilities,revenues and expenses of Idaho Power and have been prepared in accordance
with the accounting requirements of the FERC as set forth in the applicable Uniform System of Accounts and published accounting
releases,which is a comprehensive basis ofaccounting other than accounting principles generally accepted in the United States of
America (U.S.GAAP).As required by the FERC,Idaho Power accounts for its investments in its majority-owned subsidiary on the
equity method rather than consolidating the assets,liabilities,revenues and expenses of the subsidiary as required by U.S GAAP.The
accompanying financial statements include Idaho Power's proportionate share ofthe utility plant and related operations resulting from
its interest in jointly-owned plants.In addition,under the requirements ofthe FERC,there are differences from U.S.GAAP in the
presentation of (I)current portion of long-term debt,(2)assets and liabilities for cost of removal ofassets,(3)regulatory assets and
liabilities,(4)deferred income taxes,(5)income tax expense ,(6)non-utility revenues,(7)accrued taxes and (8)debt issue costs.
Management Estimates
Management makes estimates and assumptions when preparing these financial statements.These estimates and assumptions include
those related to rate regulation,retirement benefits,contingencies,litigation,asset impairment,income taxes,unbilled revenues,and
bad debt.These estimates and assumptions affect the reported amounts of assets and liabilities and the disclosure of contingent assets
and liabilities at the date ofthe financial statements,and the reported amounts of revenues and expenses during the reporting period.
These estimates involve judgments with respect to,among other things,future economic factors that are difficult to predict and are
beyond management's control.As a result,actual results could differ from those estimates.
System of Accounts
The accounting records of Idaho Power conform to the Uniform System of Accounts prescribed by the FERC and adopted by the
public utility commissions ofIdaho,Oregon,and Wyoming.
Regulation of Utility Operations
As a regulated utility,many of Idaho Power's fundamental business decisions are subject to the approval ofgovernmental agencies,
including the prices that Idaho Power is authorized to charge for its electric service.These approvals are a critical factor in
determining Idaho Power's results of operations and financial condition.
Idaho Power's financial statements reflect the effects ofthe different ratemaking principles followed by the jurisdictions regulating
Idaho Power.The application ofaccounting principles related to regulated operations sometimes results in Idaho Power recording
expenses and revenues in a different period than when an unregulated enterprise would record such expenses and revenues.In these
instances,the amounts are deferred or accrued as regulatory assets or regulatory liabilities on the balance sheet and recorded on the
income statement when recovered or returned in rates.Additionally,regulators can impose regulatory liabilities upon a regulated
company for amounts previously collected from customers that are expected to be refunded.The effects ofapplying these regulatory
accounting principles to Idaho Power's operations are discussed in more detail in Note 3.
FERC FORM NO.1 (ED.12-88)Page 123.1
Date of Report Year/Period of Report
(Mo,Da,Yr)
04/15/2016
This Report is:
(1)X An Original
(2)_A Resubmission
Name of Respondent
2015/Q4IdahoPowerCompany
NOTES TO FINANCIAL STATEMENTS (Continued)
Cash and Cash Equivalents
Cash and cash equivalents include cash on-hand and highly liquid temporary investments that mature within 90 days of the date of
acquisition.
Receivables and Allowance for Uncollectible Accounts
Customer receivables are recorded at the invoiced amounts and do not bear interest.A late payment fee of one percent may be
assessed on account balances after 30 days.An allowance is recorded for potential uncollectible accounts.The allowance is reviewed
periodically and adjusted based upon a combination of historical write-off experience,aging ofaccounts receivable,and an analysis
ofspecific customer accounts.Adjustments are charged to income.Customer accounts receivable balances that remain outstanding
after reasonable collection efforts are written off.
Other receivables,primarily notes receivable from business transactions,are also reviewed for impairment periodically,based upon
transaction-specific facts.When it is probable that Idaho Power will be unable to collect all amounts due according to the contractual
terms ofthe agreement,an allowance is established for the estimated uncollectible portion ofthe receivable and charged to income.
There were no impaired receivables without related allowances at December 3 1,2015 and 2014.Once a receivable is determined to
be impaired,any further interest income recognized is fully reserved.
Derivative Financial Instruments
Financial instruments such as commodity futures,forwards,options,and swaps are used to manage exposure to commodity price risk
in the electricity and natural gas markets.All derivative instruments are recognized as either assets or liabilities at fair value on the
balance sheet unless they are designated as normal purchases and normal sales.With the exception of forward contracts for the
purchase ofnatural gas for use at Idaho Power's natural gas generation facilities and a nominal number of power transactions,Idaho
Power's physical forward contracts are designated as normal purchases and normal sales.Because of Idaho Power's regulatory
accounting mechanisms,Idaho Power records the changes in fair value of derivative instruments related to power supply as regulatory
assets or liabilities.
Revenues
Operating revenues related to Idaho Power's sale of energy are recorded when service is rendered or energy is delivered to
customers.Idaho Power accrues estimated unbilled revenues for electric services delivered to customers but not yet billed at
year-end.In addition,regulatory mechanisms in place in Idaho and Oregon affect the reported amount of revenue.See Note 3 for
additional discussion ofcertain of the following mechanisms:
•energy efficiency riders to fund energy efficiency program expenditures.Expenditures funded through the rider are reported
as an operating expense with an equal amount ofrevenues recorded in other revenues;
•a fixed cost adjustment mechanism that results in recording additional or reduced revenue based on the allowed and actual
fixed costs recovered through current rates;
•a sharing mechanism providing for refunds to customers for earnings above stated returns on equity in Idaho;
•franchise fees and similar taxes related to energy consumption.None ofthese collections are reported on the income
statement;and
•collection in base rates of a portion ofthe allowance for funds used during construction (AFUDC)related to its Hells Canyon
Complex (HCC)relicensing project.Cash collected under this ratemaking mechanism is not recorded as revenue but is
instead deferred as a regulatory liability.
Property,Plant and Equipment and Depreciation
The cost of utility plant in service represents the original cost of contracted services,direct labor and material,AFUDC,and indirect
charges for engineering,supervision,and similar overhead items.Repair and maintenance costs associated with planned major
maintenance are expensed as the costs are incurred,as are maintenance and repairs ofproperty and replacements and renewals of
FERC FORM NO.1 (ED.12-88)Page 123.2
Date of Report Year/Period of Report
(Mo,Da,Yr)
04/15/2016
Name of Respondent This Report is:
(1)X An Original
(2)_A Resubmission 2015/Q4IdahoPowerCompany
NOTES TO FINANCIAL STATEMENTS (Continued)
items determined to be less than units of property.For utility property replaced or renewed,the original cost plus removal cost less
salvage is charged to accumulated provision for depreciation,while the cost of related replacements and renewals is added to
property,plant and equipment.
All utility plant in service is depreciated using the straight-line method at rates approved by regulatory authorities.Annual
depreciation provisions as a percent ofaverage depreciable utility plant in service approximated 2.68 percent in 2015 and 2014.
During the period of construction,costs expected to be included in the final value ofthe constructed asset,and depreciated once the
asset is complete and placed in service,are classified as construction work in progress on the consolidated balance sheets.Ifthe
project becomes probable of being abandoned,such costs are expensed in the period such determination is made.Idaho Power may
seek recovery of such costs in customer rates,although there can be no guarantee such recovery would be granted.
Long-lived assets are periodically reviewed for impairment when events or changes in circumstances indicate that the carrying
amount of an asset may not be recoverable.If the sum of the undiscounted expected future cash flows from an asset is less than the
carrying value of the asset,impairment is recognized in the financial statements.There were no material impairments of long-lived
assets in 2015 or 2014.
Allowance for Funds Used During Construction
AFUDC represents the cost of financing construction projects with borrowed funds and equity funds.With one exception,as
discussed above for the HCC relicensing project,cash is not realized currently from such allowance;it is realized under the
ratemaking process over the service life of the related property through increased revenues resulting from a higher rate base and
higher depreciation expense.The component ofAFUDC attributable to borrowed funds is included as a reduction to total interest
expense.Idaho Power's weighted-average monthly AFUDC rate was 7.6 percent for 2015 and 7.7 percent for 2014.
Income Taxes
Idaho Power accounts for income taxes under the asset and liability method,which requires the recognition of deferred tax assets and
liabilities for the expected future tax consequences of events that have been included in the financial statements.Under this method
(commonly referred to as normalized accounting),deferred tax assets and liabilities are determined based on the differences between
the financial statements and tax basis of assets and liabilities using enacted tax rates in effect for the year in which the differences are
expected to reverse.In general,deferred income tax expense or benefit for a reporting period is recognized as the change in deferred
tax assets and liabilities from the beginning to the end ofthe period.The effect of a change in tax rates on deferred tax assets and
liabilities is recognized in income in the period that includes the enactment date unless Idaho Power's primary regulator,the Idaho
Public Utilities Commission (IPUC),orders direct deferral ofthe effect ofthe change in tax rates over a longer period of time.
Consistent with orders and directives ofthe IPUC,unless contrary to applicable income tax guidance,Idaho Power does not provide
deferred income taxes for certain income tax temporary differences and instead recognizes the tax impact currently (commonly
referred to as flow-through accounting)for rate making and financial reporting.Therefore,Idaho Power's effective income tax rate is
impacted as these differences arise and reverse.Regulated enterprises are required to recognize such adjustments as regulatory assets
or liabilities if it is probable that such amounts will be recovered from or returned to customers in future rates.
In compliance with the federal income tax requirements for the use of accelerated tax depreciation,Idaho Power provides deferred
income taxes related to its plant assets for the difference between income tax depreciation and book depreciation used for financial
statement purposes.Deferred income taxes are provided for other temporary differences unless accounted for using flow-through.
The state of Idaho allows a three percent investment tax credit on qualifying plant additions.Investment tax credits earned on
regulated assets are deferred and amortized to income over the estimated service lives ofthe related properties.Credits earned on
non-regulated assets or investments are recognized in the year earned.
Income taxes are discussed in more detail in Note 2,
FERC FORM NO.1 (ED.12-88)Page 123.3
Date of Report Year/Period of Report
(Mo,Da,Yr)
04/15/2016
Name of Respondent This Report is:
(1)X An Original
(2)_A Resubmission 2015/Q4IdahoPowerCompany
NOTES TO FINANCIAL STATEMENTS (Continued)
Other Accounting Policies
Debt discount,expense,and premium are deferred and amortized over the terms ofthe respective debt issues.Losses on reacquired
debt and associated costs are amortized over the life of the associated replacement debt,as allowed under regulatory accounting.
Supplemental Cash Flows Information
In 2015,Idaho Power executed an agreement to exchange property with another electric utility.Under the terms of the agreement,
each party transferred to the other transmission-related equipment with a book value of approximately $44 million.Idaho Power
received an immaterial amount of cash,representing the difference in the book value of the assets exchanged.
Also in 2015,Idaho Power executed a long-term service agreement and transferred to the service provider approximately $22 million
of spare parts in partial exchange for future services.No cash was exchanged in the 2015 transfer transaction.
Recently Issued Accounting Pronouncements
In May 2014,the FASB issued ASU 2014-09,Revenuefrom Contracts with Customers (Topic 606).ASU 2014-09 is intended to
enable users of financial statements to better understand and consistently analyze an entity's revenue across industries,transactions,
and geographies.Under the ASU,recognition of revenue occurs when a customer obtains control of promised goods or services.In
addition,the ASU requires disclosure ofthe nature,amount,timing,and uncertainty of revenue and cash flows arising from contracts
with customers.The amendments in ASU 2014-09 are effective for annual reporting periods beginning after December 15,2017,
including interim periods,with early adoption permitted one year earlier.The guidance permits two implementation approaches,one
requiring retrospective application of the new standard with restatement of prior years and one requiring prospective application of
the new standard including a cumulative-effect adjustment with disclosure of results under old standards.Idaho Power is currently
evaluating the impact of ASU 2014-09 on its financial statements.
In February 2015,the FASB issued ASU 2015-02,Consolidation (Topic 810)-Amendments to the Consolidation Analysis,which
revises the consolidation model that reporting entities use when determining what entities are to be consolidated.The amendments
focus on limited partnerships and similar legal entities,and are effective for interim and annual reporting periods beginning after
December 31,2015.Idaho Power does not believe the impact of ASU 2015-02 on its financial statements will be significant.
In January 2016,the FASB issued ASU 2016-01,Financial Instruments—Overall (Subtopic 825-10):Recognition and Measurement
ofFinancial Assets and Financial Liabilities,which revises the accounting related to the classification and measurement of
investments in equity securities and the presentation ofcertain fair value changes for financial liabilities measured at fair value.It
also amends certain disclosure requirements associated with the fair value of financial instruments.The new standard is effective for
fiscal years beginning after December 15,2017,including interim periods.Idaho Power is currently evaluating the impact ofASU
2016-01 on its financial statements.
Subsequent Events
Management has evaluated the impact of events occurring after December 3 1,2015 up to February 18,2016,the date that Idaho
Power Company's U.S.GAAP financial statements were issued and has updated such evaluation for disclosure purposes through
April 15,2016.These financial statements include all necessary adjustments and disclosures resulting from these evaluations.
FERC FORM NO.1 (ED.12-88)Page 123.4
Date of Report Year/Period of Report
(Mo,Da,Yr)
04/15/2016
Name of Respondent This Report is:
(1)X An Original
(2)_A ResubmissionIdahoPowerCompany 2015/Q4
NOTES TO FINANCIAL STATEMENTS (Continued)
2.INCOME TAXES
A reconciliation between the statutory federal income tax rate and the effective tax rate is as follows:
2015 2014
$82,633 $71,810Federalincometaxexpenseat35%statutory
rate
Change in taxes resulting from:
Equity earnings of subsidiary companies (2,331)
(11,140)
2,693
(2,963)
(4,807)
(8,750)
(28,700)
(6,459)
(2,483)
(9,238)
2,278
(3,002)
(3,656)
(8,750)
(26,250)
AFUDC
Capitalized interest
Investment tax credits
Removal costs
Capitalized overhead costs
Capitalized repair costs
Bond redemption costs
Tax method change -capitalized repairs
State income taxes,net of federal benefit
Depreciation
Other,net
Total income tax expense
(24,516)
5,334
16,040
(1,783)
7,503
17,149
283
$45,111 $15,784
Effective tax rate 19.10%7.70%
The items comprising income tax expense are as follows:
2015 2014
(thousands of dollars)
Income taxes current:
Federal
State
$$(8,328)
6,867
12,946
6,056
Total 0,461)19,002
Income taxes deferred:
Federal
State
23,624
(6,421)
17,203
28,103
(2,486)
25,617Total
Investment tax credits:
Deferred
Restored
3,455
(2,963)
3,044
(3,002)
Total
Total income tax expense $
492 42
45,111 $15,784
FERC FORM NO.1 (ED.12-88)Page 123.5
Date of Report Year/Period of Report
(Mo,Da,Yr)
04/15/2016
Name of Respondent This Report is:
(1)X An Original
(2)_A Resubmission
NOTES TO FINANCIAL STATEMENTS (Continued)
2015/Q4IdahoPowerCompany
The components of the net deferred tax liability are as follows:
2015 2014
(thousands of dollars)
Deferred tax assets:
Regulatory liabilities
Deferred compensation
Deferred revenue
Tax credits
Retirement benefits
Other
Total
$51,131 $
27,489
34,282
30,223
126,885
10.745
55,490
25,240
28,529
26,768
132,571
14.553
280,755 283,151
Deferred tax liabilities:
Property,plant and
equipment
Regulatory assets
Power cost adjustments
Retirement benefits
Other
474,879 451,118
802,188
23,192
122,360
22,252
875,028
18,489
126,090
28,895
Total 1,523,381 1,421,110
$1,242,626 $1,137,959Netdeferredtaxliabilities
IDACORP's tax allocation agreement provides that each member ofits consolidated group compute its income taxes on a separate
company basis.Amounts payable or refundable are settled through IDACORP.See Note 1 for further discussion of accounting
policies related to income taxes.
Uncertain Tax Positions
Idaho Power believes that they have no material income tax uncertainties for 2015 and prior tax years.The Company recognizes
interest accrued related to unrecognized tax benefits as interest expense and penalties as other expense.
Idaho Power is subject to examination by their major tax jurisdictions -U.S.federal and the State of Idaho.The open tax years for
examination are 2015 for federal and 2012-2015 for Idaho.In May 2009,IDACORP formally entered the U.S.Internal Revenue
Service (IRS)Compliance Assurance Process (CAP)program for its 2009 tax year and has remained in the CAP program for all
subsequent years.The CAP program provides for IRS examination and issue resolution throughout the current year with the
objective of return filings containing no contested items.In 2015,the IRS completed its examination of IDACORP's 2014 tax year
with no unresolved income tax issues.
Tax Accounting Method Changes for Repair-Related Expenditures
In the fourth quarter of 2014,Idaho Power finalized an income tax accounting method change for its 2014 tax year associated with the
electric generation property portion of its capitalized repairs tax method it adopted in fiscal year 2010.As a result of the change,
Idaho Power recorded an $8.8 million tax benefit related to the cumulative method change adjustment for years prior to 2014 and
reversed a related $4.6 million tax expense estimate it had recorded in 2013 (discussed below),for a total adjustment of $13.4 million.
The method change was pursuant to Revenue Procedure 2013-24 and brought Idaho Power's existing method into alignment with the
Revenue Procedure's safe harbor unit-of-property definitions for electric generation property.The change also incorporated
provisions ofthe final tangible property regulations issued by the U.S.Treasury Department and IRS in 2013 that addressed the
deduction or capitalization of expenditures related to tangible property.Following the automatic consent procedures provided for in
the Revenue Procedure,Idaho Power adopted this method with the filing of IDACORP's 2014 consolidated federal income tax return
in September 2015.The IRS approved the method change prior to the filing ofthe return as part of IDACORP's 2014 CAP
examination.
FERC FORM NO.1 (ED.12-88)Page 123.6
Date of Report Year/Period of Report
(Mo,Da,Yr)
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Name of Respondent This Report is:
(1)X An Original
(2)_A Resubmission 2015/Q4IdahoPowerCompany
NOTES TO FINANCIAL STATEMENTS (Continued)
In 2014 Idaho Power,in coordination with the IRS through IDACORP's CAP examination process,implemented aspects of the final
tangible property regulations and other technical interpretations ofthese rules into its existing capitalized repairs tax accounting
method for generation,transmission and distribution assets.These technical interpretations were received from the IRS in 2014.An
$11.1 million tax benefit related to the portion ofthe 2013 capitalized repairs deduction based on these modifications was recorded in
the third quarter of 2014.Idaho Power finalized these changes with the filing of IDACORP's 2013 consolidated federal income tax
return in September 2014.The IRS approved the repairs method modifications prior to the filing ofthe return as part of IDACORP's
2013 CAP examination.
FERC FORM NO.1 (ED.12-88)Page 123.7
Date of Report Year/Period of Report
(Mo,Da,Yr)
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This Report is:
(1)X An Original
(2)_,A Resubmission
NOTES TO FINANCIAL STATEMENTS (Continued)
Name of Respondent
2015/Q4IdahoPowerCompany
3.REGULATORY MATTERS
Idaho Power's financial statements reflect the effects of the different ratemaking principles followed by the jurisdictions regulating
Idaho Power.Included below is a summary of Idaho Power's regulatory assets and liabilities,as well as a discussion of notable
regulatory matters.
Regulatory Assets and Liabilities
The application of accounting principles related to regulated operations sometimes results in Idaho Power recording expenses and
revenues in a different period than when an unregulated enterprise would record such expenses and revenues.Regulatory assets
represent incurred costs that have been deferred because it is probable they will be recovered from customers through future rates.
Regulatory liabilities represent obligations to make refunds to customers for previous collections,or represent amounts collected in
advance of incurring an expense.The following table presents a summary of Idaho Power's regulatory assets and liabilities (in
thousands of dollars):
As of December 31,
2015
Total as of December 31,Not EarningRemaining
Amortization
Period
Earning
Description
20142015aReturn/1)a Return
Regulatory Assets:
Income taxes S$$875,027 875,027 802,188$
264,548
63,644
4,690
59,189
23,737
17,309
251,762
23,148
251,762
85,790
4,482
47,220
36,820
14,410
4,973
30,225
Unfunded postretirement benefits®
Pension expense deferrals
Energy efficiency program costs®
Power supply costs®
Fixed cost adjustment®
Asset retirement obligations®
Mark-to-market liabilities®
Long-term service agreement®
Other
62,642
4,482
47,220
36,820
Varies
2016-2017
14,410
4,973
11,633
3,961
18,5922043
3,1211,096 3,704 4,8002016-2021
170.852 $1,183.573 $1,355.509 S 1.242.387STotal
Regulatory Liabilities:
Income taxes
Energy efficiency program costs®
Power supply costs®
Settlement agreement sharing
mechanism®
Mark-to-market assets®
Other
$51,131 $55,490
6,554
$S 51,131
6,554
1
3,159 7,9993,1592016-2017
1,880405405
6,399 4,0365,219 1,180
14.932 $52.716 $67.648 $$69.406Total
(1)Earning a return includes either interest or a return on the investment as a component of rate base at the allowed rate of return.
®Represents the unfunded obligation ofIdaho Power's pension and postretirement benefit plans,which are discussed in Note 10.
(3)The 2015 energy efficiency asset represents the Oregon jurisdiction balance and the liability represents the Idaho jurisdiction balance.Both jurisdictions'balances
were assets at December 31,2014.
(4)These items are discussed in more detail in this Note 3
®Asset retirement obligations are discussed in Note 12.
®Mark-to-market assets and liabilities are discussed in Note 15
®A portion not earning a return as ofDecember 31,201 5 will be eligible to earn a return as ofJanuary 1,2018.
Idaho Power's regulatory assets and liabilities are typically amortized over the period in which they are reflected in customer rates.In
the event that recovery of Idaho Power's costs through rates becomes unlikely or uncertain,regulatory accounting would no longer
apply to some or all of Idaho Power's operations and the items above may represent stranded investments.If not allowed full
recovery ofthese items,Idaho Power would be required to write offthe applicable portion,which could have a materially adverse
financial impact.
FERC FORM NO.1 (ED.12-88)Page 123.8
Name of Respondent This Report is:
(1)X An Original
(2)__A Resubmission
Date of Report Year/Period of Report
(Mo,Da,Yr)
04/15/2016IdahoPowerCompany 2015/Q4
NOTES TO FINANCIAL STATEMENTS (Continued)
Power Cost Adjustment Mechanisms and Deferred Power Supply Costs
In both its Idaho and Oregonjurisdictions,Idaho Power's power cost adjustment (PCA)mechanisms address the volatility ofpower
supply costs and provide for annual adjustments to the rates charged to its retail customers.The PCA mechanisms compare Idaho
Power's actual net power supply costs (primarily fuel and purchased power less off-system sales)against net power supply costs being
recovered.Under the PCA mechanisms,certain differences between actual net power supply costs incurred by Idaho Power and the
costs are recorded as a deferred charge or credit on the balance sheets for future recovery or refund.The power supply costs deferred
primarily result from changes in contracted power purchase prices and volumes,changes in wholesale market prices and transaction
volumes,fuel prices,and the levels of Idaho Power's own generation.
Idaho Jurisdiction Power Cost Adjustment Mechanism:In the Idaho jurisdiction,the annual PCA adjustment consists of (a)a
forecast component,based on a forecast of net power supply costs in the coming year as compared with net power supply costs
included in base rates;and (b)a true-up component,based on the difference between the previous year's actual net power supply
costs and the previous year's forecast.The latter component also includes a balancing mechanism so that,over time,the actual
collection or refund ofauthorized true-up dollars matches the amounts authorized.The Idaho PCA mechanism also includes:
•a cost or benefit sharing ratio that allocates the deviations in net power supply expenses between customers (95 percent)and
shareholders (5 percent),with the exceptions of expenses associated with PURPA power purchases and demand response
incentive payments,which are allocated 100 percent to customers;and
•a sales-based adjustment intended to ensure that power supply expense recovery resulting solely from sales changes does not
distort the results ofthe mechanism.
The table below summarizes the three most recent Idaho PCA rate adjustments,all of which also include non-PCA-related rate
adjustments as ordered by the IPUC:
Effective
Date $Change (millions)Notes
June 1,2015 $The net decrease in Idaho PCA rates included the application of (a)a customer rate credit
of S8.0 million for sharing ofrevenues with customers for the year 2014 under the terms of
the December 201 1 settlement stipulation,and (b)$4.0 million ofsurplus Idaho energy
efficiency rider funds.
2014 PCA rates are net of (a)$20.0 million of surplus Idaho energy efficiency rider funds,
and (b)$7.6 million of customer revenue sharing under a regulatory settlement stipulation.
In addition,on June 1,2014,there was an increase in base net power supply costs that
shifted $99.3 million in power supply expenses from recovery via the PCA mechanism to
recovery via base rates.The shifting of base net power supply costs is discussed in more
detail below.
(11.6)
June 1,2014 $(88.2)
In March 2014,the IPUC issued an order approving Idaho Power's application requesting an increase of approximately $106
million in the normalized or "base level"net power supply expense on a total-system basis to be used to update base rates and in the
determination ofthe PCA rate that became effective June 1,2014.Approval of the order removed the Idaho-jurisdictional portion of
those expenses (approximately $99 million)from collection via the Idaho PCA mechanism and instead results in collecting that
portion through base rates.
In July 2014,the IPUC opened a docket pursuant to which Idaho Power,the IPUC Staff,and other interested parties further evaluated
Idaho Power's application ofthe true-up component of the PCA mechanism and whether a deferral balance adjustment was
appropriate.While the IPUC's docket was closed in August 2014 with no adjustment to the PCA true-up revenue amount,Idaho
Power subsequently met with the IPUC Staff to explore approaches to increasing the accuracy ofthe actual cost recovery under the
PCA mechanism.In May 2015,the IPUC approved a settlement stipulation that resulted in the replacement of the existing load-based
adjustment used for determining the power cost deferrals under the PCA mechanism with a similar sales-based adjustment.The
sales-based adjustment functions in the same manner as the previous load-based adjustment but measures deviations between
Idaho-specific test year sales and actual Idaho sales rather than deviations between test year loads and actual loads.The approved
FERC FORM NO.1 (ED.12-88)Page 123.9
Date of Report Year/Period of Report
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This Report is:
(1)X An Original
(2)_A Resubmission
Name of Respondent
2015/Q4IdahoPowerCompany
NOTES TO FINANCIAL STATEMENTS (Continued)
settlement stipulation implemented the new methodology as ofJanuary 1,2015.
Oregon Jurisdiction Power Cost Adjustment Mechanism:Idaho Power's power cost recovery mechanism in Oregon has two
components:an annual power cost update (APCU)and a power cost adjustment mechanism (PCAM).The APCU allows Idaho
Power to reestablish its Oregon base net power supply costs annually,separate from a general rate case,and to forecast net power
supply costs for the upcoming water year.The PCAM is a true-up filed annually in February.The filing calculates the deviation
between actual net power supply expenses incurred for the preceding calendar year and the net power supply expenses recovered
through the APCU for the same period.Under the PCAM,Idaho Power is subject to a portion of the business risk or benefit
associated with this deviation through application ofan asymmetrical deadband (or range of deviations)within which Idaho Power
absorbs cost increases or decreases.For deviations in actual power supply costs outside of the deadband,the PCAM provides for
90/10 sharing of costs and benefits between customers and Idaho Power.However,collection by Idaho Power will occur only to the
extent that Idaho Power's actual Oregon-jurisdictional return on equity (ROE)for the year is no greater than 1 00 basis points below
Idaho Power's last authorized ROE.A refund to customers will occur only to the extent that Idaho Power's actual ROE for that year
is no less than 100 basis points above Idaho Power's last authorized ROE.Oregon jurisdiction power supply cost changes under the
APCU and PCAM during each of 2015,and 2014,are summarized in the table that follows:
Year and Mechanism APCU or PCAM Adjustment
Actual net power supply costs were within the deadband,resulting in no deferral.
A rate decrease of$0.7 million annually took effect June 1,2015.
Actual net power supply costs were within the deadband,resulting in no deferral.
A rate increase of $0.4 million annually took effect June 1,2014.
2015 PCAM
2015 APCU
2014 PCAM
2014 APCU
Notable Idaho Regulatory Matters
Idaho Base Rate Changes:Idaho base rates were most recently established in 2012,and adjusted in 2014.Effective January 1,
2012,Idaho Power implemented new Idaho base rates resulting from IPUC approval of a settlement stipulation that provided for a
7.86 percent authorized overall rate of return on an Idaho-jurisdiction rate base of approximately $2.36 billion.The settlement
stipulation resulted in a 4.07 percent,or $34.0 million,overall increase in Idaho Power's annual Idaho-jurisdiction base rate revenues.
Idaho base rates were subsequently adjusted again in 2012,in connection with Idaho Power's completion of the Langley Gulch power
plant.In June 2012,the IPUC issued an order approving a $58.1 million increase in annual Idaho-jurisdiction base rates,effective
July 1,2012.The order also provided for a $335.9 million increase in Idaho rate base.Neither the settlement stipulation nor the
IPUC orders adjusting base rates specified an authorized rate of return on equity or imposed a moratorium on Idaho Power filing a
general rate case at a future date.
As noted above in this Note 3,the IPUC also issued a March 2014 order approving Idaho Power's request for an increase in the
normalized or "base level"net power supply expense to be used to update base rates and in the determination ofthe Idaho PCA rate
that became effective June 1,2014.
December 2011 Idaho Settlement Stipulation:In December 201 1 ,the IPUC issued an order,separate from the general rate case
proceeding,approving a settlement stipulation that provided as follows:
•If Idaho Power's actual Idaho-jurisdiction return on year-end equity (Idaho ROE)for 2012,2013,or 2014 was less than 9.5
percent,then Idaho Power may amortize up to a total of$45 million of additional accumulated deferred investment tax
credits (ADITC)to help achieve a minimum 9.5 percent Idaho ROE in the applicable year.
•If Idaho Power's actual Idaho ROE for 2012,2013,or 2014 exceeded 10.0 percent,the amount of Idaho Power's
Idaho-jurisdiction earnings exceeding a 10.0 percent and up to and including a 10.5 percent Idaho ROE for the applicable
year would be shared equally between Idaho Power and its Idaho customers in the form of a rate reduction to become
effective at the time of the subsequent year's PCA mechanism adjustment.
»If Idaho Power's actual Idaho ROE for 2012,2013,or 2014 exceeded 10.5 percent,the amount of Idaho Power's Idaho
jurisdictional earnings exceeding a 10.5 percent Idaho ROE for the applicable year would be allocated 75 percent to Idaho
Power's Idaho customers as a reduction to the pension regulatory asset and 25 percent to Idaho Power.
As Idaho Power's Idaho ROE exceeded 10.5 percent for each of 2012,2013,and 2014,Idaho Power did not amortize additional
ADITC for those years,but instead shared a portion ofits Idaho-jurisdiction earnings with Idaho customers.The amounts Idaho
FERC FORM NO.1 (ED.12-88)Page 123.10
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Name of Respondent This Report is:
(1)X An Original
(2)A Resubmission
NOTES TO FINANCIAL STATEMENTS (Continued)
2015/Q4IdahoPowerCompany
Power recorded in 2014 for sharing with customers under the December 201 1 Idaho regulatory settlement stipulation was $8 million
as refunds to customers and $16.7 million as pre-tax charges to pension expenses.
October 2014 Idaho Settlement Stipulation:In October 2014,the IPUC issued an order approving an extension,with modifications,
ofthe terms of the December 201 1 Idaho settlement stipulation for the period from 2015 through 2019,or until the terms are
otherwise modified or terminated by order of the IPUC or the full $45 million of additional ADITC contemplated by the settlement
stipulation has been amortized.The provisions of the new settlement stipulation are as follows:
•If Idaho Power's annual Idaho ROE in any year is less than 9.5 percent,then Idaho Power may amortize up to $25 million of
additional ADITC to help achieve a 9.5 percent Idaho ROE for that year,and may amortize up to a total of $45 million of
additional ADITC over the 2015 through 2019 period.
•IfIdaho Power's annual Idaho ROE in any year exceeds 10.0 percent,the amount of earnings exceeding a 10.0 percent Idaho
ROE and up to and including a 10.5 percent Idaho ROE will be allocated 75 percent to Idaho Power's Idaho customers as a
rate reduction to be effective at the time of the subsequent year's power cost adjustment and 25 percent to Idaho Power.
•If Idaho Power's annual Idaho ROE in any year exceeds 10.5 percent,the amount ofearnings exceeding a 10.5 percent Idaho
ROE will be allocated 50 percent to Idaho Power's Idaho customers as a rate reduction to be effective at the time of the
subsequent year's power cost adjustment,25 percent to Idaho Power's Idaho customers in the form of a reduction to the
pension expense deferral regulatory asset (to reduce the amount to be collected in the future from Idaho customers),and 25
percent to Idaho Power.
•If the full $45 million ofadditional ADITC contemplated by the settlement stipulation has been amortized the sharing
provisions would terminate.
•In the event the IPUC approves a change to Idaho Power's Idaho-jurisdictional allowed return on equity as part of a general
rate case proceeding seeking a rate change effective prior to January 1,2020,the Idaho ROE thresholds (9.5 percent,10.0
percent,and 10.5 percent)will be adjusted prospectively.
Neither the settlement stipulation nor the associated IPUC order impose a moratorium on Idaho Power filing a general rate case or
other form of rate proceeding during the term of the settlement stipulation.
Idaho Power recorded no additional ADITC amortization and a $3.2 million provision against current revenue for sharing with
customers for 2015 under the October 2014 Idaho settlement stipulation,as its Idaho ROE for 2015 was above 10.0 percent.
Fixed Cost Adjustment:The Idaho jurisdiction fixed cost adjustment (FCA)mechanism is designed to remove Idaho Power's
financial disincentive to invest in energy efficiency programs by separating (or decoupling)the recovery offixed costs from the
variable kilowatt-hour charge and linking it instead to a set amount per customer.The FCA mechanism is adjusted each year to
collect,or refund,the difference between the authorized fixed-cost recovery amount and the actual fixed costs recovered by Idaho
Power during the year.The annual change in the FCA recovery is capped at no more than 3 percent ofbase revenue,with any excess
deferred for collection in a subsequent year.The following table summarizes FCA amounts approved for collection in the prior three
FCA years:
FCA
Year Period Rates in Effect Annual Amount
(in millions)
$16.92014June1,2015-May 31,2016
June 1,2014-May 31,2015
June 1,2013-May 31,2014
$14.92013
$8.92012
In July 2014,the IPUC opened a docket to allow Idaho Power,the IPUC Staff,and other interested parties to further evaluate the
IPUC Staffs concerns regarding the application ofthe FCA mechanism (including weather-normalization,customer count
methodology,rate adjustment cap,and cross-subsidization issues)and whether the FCA is effectively removing Idaho Power's
disincentive to aggressively pursue energy efficiency programs.In May 2015,the IPUC approved a settlement stipulation that
modified the FCA mechanism by replacing weather-normalized billed sales with actual billed sales in the calculation of the FCA,
applicable for the entirety of calendar year 2015 and thereafter,and reflected in FCA charges effective June 1,2016.
FERC FORM NO.1 (ED.12-88)Page 123.11
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Name of Respondent This Report is:
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(2)_A Resubmission 2015/Q4IdahoPowerCompany
NOTES TO FINANCIAL STATEMENTS (Continued)
Notable Oregon Regulatory Matters
Oregon Base Rate Changes:Oregon base rates were most recently established in a general rate case in 2012.In February 2012,the
OPUC issued an order approving a settlement stipulation that provided for a $1.8 million base rate increase,a return on equity of 9.9
percent,and an overall rate of return of 7.757 percent in the Oregon jurisdiction.New rates in conformity with the settlement
stipulation were effective March 1,2012.Subsequently,in September 2012,the OPUC issued an order approving an approximately
$3.0 million increase in annual Oregon jurisdiction base rates,effective October 1,2012,for inclusion of the Langley Gulch power
plant in Idaho Power's Oregon rate base.
Federal Regulatory Matters -Open Access Transmission Tariff Rates
Idaho Power uses a formula rate for transmission service provided under its OATT,which allows transmission rates to be updated
annually based primarily on financial and operational data Idaho Power files with the FERC.Idaho Power's OATT rates submitted to
the FERC in Idaho Power's three most recent annual OATT Final Informational Filings were as follows:
Applicable Period
October 1,2015 to September 30,2016 $
October 1,2014 to September 30,2015 $
October 1,2013 to September 30,2014 $
OATT Rate (per kW-year)
23.43
22.48
22.80
Idaho Power's current OATT rate is based on a net annual transmission revenue requirement of $121.3 million,which represents the
OATT formulaic determination of Idaho Power's net cost ofproviding OATT-based transmission service.
FERC FORM NO.1 (ED.12-88)Page 123.12
Date of Report Year/Period of Report
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Name of Respondent This Report is:
(1)X An Original
(2)A Resubmission 2015/Q4IdahoPowerCompany
NOTES TO FINANCIAL STATEMENTS (Continued)
4.LONG-TERM DEBT
The following table summarizes Idaho Power's long-term debt at December 31 (in thousands of dollars):
2015 2014
First mortgage bonds:
$$6.025%Series due 2018 120,000
100,000
130,000
100,000
75,000
75,000
100,000
70,000
50,000
55,000
60,000
140,000
100,000
100,000
75,000
75,000
6.15%Series due 2019
4.50%Series due 2020
3.40%Series due 2020
2.95%Series due 2022
2.50%Series due 2023
100,000
130,000
100,000
75,000
75,000
100,000
70,000
50,000
55,000
60,000
140,000
100,000
100,000
75,000
75,000
250,000
6%Series due 2032
5.50%Series due 2033
5.50%Series due 2034
5.875%Series due 2034
5.30%Series due 2035
6.30%Series due 2037
6.25%Series due 2037
4.85%Series due 2040
4.30%Series due 2042
4.00%Series due 2043
3.65%Series Due 2045
Total first mortgage bonds
Pollution control revenue bonds:
1,555,000 1,425,000
5.15%Series due2024O)
5.25%Series due2026O)
Variable Rate Series 2000 due 2027
49,800
116,300
4,360
49,800
116,300
4,360
Total pollution control revenue
bonds
American Falls bond guarantee
Milner Dam note guarantee
Unamortized discounts
170,460 170,460
19,885
2,127
(4,459)
19,885
3,191
(3,034)
Total Idaho Power outstanding
debt(2)$1,743,013 $1,615,502
(')Humboldt County and Sweetwater County Pollution Control Revenue Bonds are secured by the first mortgage,bringing the total first mortgage bonds outstanding at
December 31,2015 to$l 721 billion.
(2)At December 31,2015 and 2014,the overall effective cost ofIdaho Power's outstanding debt was 4 96 percent and 5 19 percent,respectively.
At December 31,2015,the maturities for the aggregate amount ofIdaho Power's long-term debt outstanding were as follows (in
thousands of dollars):
Thereafter20162017201820192020
$230,000 $1,415,344$1,064 $1,064 $—$100,000
Long-Term Debt Issuances,Maturities,and Availability
On March 6,2015,Idaho Power issued $250 million in principal amount of3.65%first mortgage bonds,secured medium-term notes,
Series J,maturing on March 1,2045.On April 23,2015,Idaho Power redeemed,prior to maturity,$120 million in principal amount
FERC FORM NO.1 (ED.12-88)Page 123.13
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NOTES TO FINANCIAL STATEMENTS (Continued)
of 6.025%first mortgage bonds,medium-term notes,Series H due July 2018.In accordance with the redemption provisions ofthe
notes,the redemption included Idaho Power's payment of a make-whole premium to the holders ofthe redeemed notes in the
aggregate amount of approximately $17.9 million.Idaho Power used a portion ofthe net proceeds from the March 2015 sale of first
mortgage bonds,medium-term notes to effect the redemption.
In April 2013,Idaho Power received orders from the IPUC,OPUC,and Wyoming Public Service Commission (WPSC)authorizing
Idaho Power to issue and sell from time to time up to $500 million in aggregate principal amount of debt securities and first mortgage
bonds,subject to conditions specified in the orders.Authority from the IPUC was through April 9,2015.On April 1,2015,the IPUC
approved a two-year extension through April 9,2017,continuing Idaho Power's authorization to issue and sell from time to time debt
securities and first mortgage bonds.The OPUC's and WPSC's orders do not impose a time limitation for issuances,but the OPUC
order does impose a number of other conditions,including a maximum interest rate limit ofseven percent.
On May 22,2013,IDACORP and Idaho Power filed ajoint shelf registration statement with the SEC,which became effective upon
filing,for the offer and sale of,in the case of Idaho Power,an unspecified principal amount ofits first mortgage bonds and debt
securities.On July 12,2013,Idaho Power entered into a Selling Agency Agreement with eight banks named in the agreement in
connection with the potential issuance and sale from time to time ofup to $500 million aggregate principal amount offirst mortgage
bonds,secured medium term notes,Series J (Series J Notes),under Idaho Power's Indenture of Mortgage and Deed ofTrust,dated as
ofOctober 1,1937,as amended and supplemented (Indenture).Also on July 12,2013,Idaho Power entered into the Forty-seventh
Supplemental Indenture,dated as of July 1,2013,to the Indenture.The Forty-seventh Supplemental Indenture provides for,among
other items,the issuance ofup to $500 million in aggregate principal amount of Series J Notes pursuant to the Indenture.As of
December 31,2015,$250 million in principal amount of Series J Notes remained available for issuance under the Indenture.
In March 2016,Idaho Power issued $120 million in principal amount of 4.05%first mortgage bonds,secured medium-term notes,
Series J,maturing on March 1,2046.On March 10,2016,Idaho Power issued a notice of redemption to redeem,prior to maturity,its
$100 million in principal amount of 6.15%first mortgage bonds,medium-term notes,Series H due April 2019,with the redemption
effective April 1 1,2016.In accordance with the redemption provisions ofthe notes,the redemption included Idaho Power's payment
ofa make-whole premium to the holders ofthe redeemed notes in the aggregate amount of approximately $14 million.Idaho Power
used a portion ofthe net proceeds from the March 2016 sale of first mortgage bonds,medium-term notes to effect the redemption.
Mortgage:As of December 31,2015,Idaho Power could issue under its Indenture approximately $1.5 billion of additional first
mortgage bonds based on retired first mortgage bonds and total unfunded property additions.These amounts are further limited by
the maximum amount of first mortgage bonds set forth in the Indenture.
The mortgage ofthe Indenture secures all bonds issued under the Indenture equally and ratably,without preference,priority,or
distinction.First mortgage bonds issued in the future will also be secured by the mortgage of the Indenture.The lien constitutes a
first mortgage on all the properties of Idaho Power,subject only to certain limited exceptions including liens for taxes and
assessments that are not delinquent and minor excepted encumbrances.Certain ofthe properties of Idaho Power are subject to
easements,leases,contracts,covenants,workmen's compensation awards,and similar encumbrances and minor defects and clouds
common to properties.The mortgage of the Indenture does not create a lien on revenues or profits,or notes or accounts receivable,
contracts or chooses in action,except as permitted by law during a completed default,securities,or cash,except when pledged,or
merchandise or equipment manufactured or acquired for resale.The mortgage ofthe Indenture creates a lien on the interest of Idaho
Power in property subsequently acquired,other than excepted property,subject to limitations in the case ofconsolidation,merger,or
sale of all or substantially all ofthe assets of Idaho Power.The Indenture requires Idaho Power to spend or appropriate 15 percent of
its annual gross operating revenues for maintenance,retirement,or amortization of its properties.Idaho Power may,however,
anticipate or make up these expenditures or appropriations within the five years that immediately follow or precede a particular year.
On February 17,2010,Idaho Power entered into the Forty-fifth Supplemental Indenture,dated as of February 1,2010,to the
Indenture for the purpose of increasing the maximum amount of first mortgage bonds issuable by Idaho Power from $1 .5 billion to
$2.0 billion.The amount issuable is also restricted by property,earnings,and other provisions ofthe Indenture and supplemental
indentures to the Indenture.Idaho Power may amend the Indenture and increase this amount without consent of the holders ofthe
first mortgage bonds.The Indenture requires that Idaho Power's net earnings be at least twice the annual interest requirements on all
outstanding debt of equal or prior rank,including the bonds that Idaho Power may propose to issue.Under certain circumstances,the
net earnings test does not apply,including the issuance of refunding bonds to retire outstanding bonds that mature in less than two
FERC FORM NO.1 (ED.12-88)Page 123.14
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NOTES TO FINANCIAL STATEMENTS (Continued)
2015/Q4IdahoPowerCompany
years or that are of an equal or higher interest rate,or prior lien bonds.
5.NOTES PAYABLE
Credit Facilities
On November 6,2015,Idaho Power entered into Credit Agreements replacing the existing Second Amended and Restated Credit
Agreements,dated October 26,201 1,to provide credit facilities that may be used for general corporate purposes and commercial
paper backup.Idaho Power's credit facility consists of a revolving line of credit,through the issuance of loans and standby letters of
credit,not to exceed the aggregate principal amount at any one time outstanding of $300 million,including swingline loans in an
aggregate principal amount at any time outstanding not to exceed $30 million,and letters of credit in an aggregate principal amount at
any time outstanding not to exceed $100 million.Idaho Power has the right to request an increase in the aggregate principal amount
ofthe facilities to $450 million,subject to certain conditions.
The Idaho Power credit facility has similar terms and conditions.The interest rates for any borrowings under the facilities are based
on either (1)a floating rate that is equal to the highest ofthe prime rate,federal funds rate plus 0.5 percent,or LIBOR rate plus 1.0
percent,or (2)the LIBOR rate,plus,in each case,an applicable margin,provided that the federal funds rate and LIBOR rate will not
be less than 0.0 percent.The margin is based on Idaho Power's,as applicable;senior unsecured long-term indebtedness credit rating
by Moody's Investors Service,Inc.,Standard and Poor's Ratings Services,and Fitch Rating Services,Inc.,as set forth on a schedule to
the credit agreements.Under their respective credit facilities,the companies pay a facility fee on the commitment based on the
respective company's credit rating for senior unsecured long-term debt securities.The credit facilities mature on November 6,2020,
though Idaho Power may request up to two one-year extensions ofthe credit agreements,subject to certain conditions.
At December 31,2015 and December 31,2014 no loans or commercial paper were outstanding under Idaho Power's facility.At
December 31,2015,Idaho Power had regulatory authority to incur up to $450 million in principal amount ofshort-term indebtedness
at any one time outstanding.
6.COMMON STOCK
No contributions were made to Idaho Power in 2015 or 2014,and no additional shares of Idaho Power common stock were issued.
Restrictions on Dividends
Idaho Power's ability to pay dividends on its common stock held by IDACORP is limited to the extent payment of such dividends
would violate the covenants in their respective credit facilities or Idaho Power's Revised Code of Conduct.A covenant under Idaho
Power's credit facility requires Idaho Power to maintain a leverage ratio ofconsolidated indebtedness to consolidated total
capitalization,as defined therein,of no more than 65 percent at the end of each fiscal quarter.At December 31,2015,the leverage
ratio for Idaho Power was 48 percent.Based on these restrictions,Idaho Power's dividends were limited to $980 million,at
December 3 1,2015.There are additional facility covenants,subject to exceptions,that prohibit or restrict the sale or disposition of
property without consent and any agreements restricting dividend payments to the company from any material subsidiary.At
December 31,2015,Idaho Power was in compliance with those covenants.
Idaho Power's Revised Policy and Code of Conduct relating to transactions between and among Idaho Power,IDACORP,and other
affiliates,which was approved by the IPUC in April 2008,provides that Idaho Power will not pay any dividends to IDACORP that
will reduce Idaho Power's common equity capital below 35 percent ofits total adjusted capital without IPUC approval.At
December 31,2015,Idaho Power's common equity capital was 52 percent of its total adjusted capital.Further,Idaho Power must
obtain approval from the OPUC before it can directly or indirectly loan funds or issue notes or give credit on its books to IDACORP,
Idaho Power's articles of incorporation contain restrictions on the payment ofdividends on its common stock if preferred stock
dividends are in arrears.As ofthe date ofthis report,Idaho Power has no preferred stock outstanding.
In addition to contractual restrictions on the amount and payment of dividends,the Federal Power Act prohibits the payment of
dividends from "capital accounts."The term "capital account"is undefined in the Federal Power Act or its regulations,but Idaho
FERC FORM NO.1 (ED.12-88)Page 123.15
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NOTES TO FINANCIAL STATEMENTS (Continued)
Power does not believe the restriction would limit Idaho Power's ability to pay dividends out of current year earnings or retained
earnings.
In accordance with Section 10(d)ofthe Federal Power Act,Idaho Power has $13.3 million of amortization reserves established for
certain of its licensed hydroelectric facilities.
7.STOCK-BASED COMPENSATION
Through its parent company IDACORP,Idaho Power has two share-based compensation plans —the 2000 Long-Term Incentive and
Compensation Plan (LTICP)and the 1994 Restricted Stock Plan (RSP).These plans are intended to align employee and shareholder
objectives related to IDACORP's long-term growth.
The LTICP (for officers,key employees,and directors)permits the grant of stock options,restricted stock,performance shares,and
several other types of stock-based awards.The RSP (for officers and key employees)permits only the grant ofrestricted stock or
performance-based restricted stock.At December 3 1 ,20 1 5,the maximum number of shares available under the LTICP and RSP were
1,043,542 and 15,796,respectively,excluding (i)issued but unvested performance-based restricted shares and (ii)issued but unvested
time-based restricted shares.
Stock Awards:Restricted stock awards have three-year vesting periods and entitle the recipients to dividends and voting rights.
Unvested shares are restricted as to disposition and subject to forfeiture under certain circumstances.The fair value ofthese awards is
based on the closing market price ofcommon stock on the grant date and is charged to compensation expense over the vesting period,
based on the number ofshares expected to vest.
Performance-based restricted stock awards have three-year vesting periods and entitle the recipients to voting rights.Unvested shares
are restricted as to disposition,subject to forfeiture under certain circumstances,and subject to the attainment of specific performance
conditions over the three-year vesting period.The performance conditions are two equally-weighted metrics,cumulative earnings per
share (CEPS)and total shareholder return (TSR)relative to a peer group.Depending on the level ofattainment of the performance
conditions and the year issued,the final number of shares awarded can range from zero to 150 percent of the target award for awards
granted prior to 2015 and from zero to 200 percent of the target award for awards granted in 2015.Dividends are accrued during the
vesting period and paid out based on the final number ofshares awarded.
The grant-date fair value ofthe CEPS portion is based on the closing market value at the date ofgrant,reduced by the loss in
time-value of the estimated future dividend payments.The fair value ofthis portion of the awards is charged to compensation
expense over the requisite service period,based on the number of shares expected to vest.The grant-date fair value ofthe TSR
portion is estimated using the market value at the date ofgrant and a statistical model that incorporates the probability ofmeeting
performance targets based on historical returns relative to the peer group.The fair value of this portion of the awards is charged to
compensation expense over the requisite service period,provided the requisite service period is rendered,regardless of the level of
TSR metric attained.
A summary of restricted stock and performance share activity is presented below.Share amounts represent the portion ofIDACORP
common stock:
Weighted-Average
Grant Date
Fair Value
Number of
Shares
250,396 $
115,863
(10,413)
(127,056)
43.91
54.05
55.63
36.84
Nonvested shares at January 1,2015
Shares granted
Shares forfeited
Shares vested
Nonvested shares at December 31,228,790 $52.44
2015
FERC FORM NO.1 (ED.12-88)Page 123.16
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NOTES TO FINANCIAL STATEMENTS (Continued)
The total fair value of shares vested during the years ended December 31,2015 and 2014 was $8.3 million and $6.6 million,
respectively.At December 3 1,2015,Idaho Power had $4.7 million oftotal unrecognized compensation cost related to nonvested
share-based compensation that was expected to vest.These costs are expected to be recognized over a weighted-average period of
1.68 years.IDACORP uses original issue and/or treasury shares for these awards.
In 2015,a total of 15,324 of IDACORP common stock shares were awarded to directors of IDACORP and Idaho Power at a grant
date fair value of $62.62 per share.Directors elected to defer receipt of 3,831 ofthese shares,which are being held as deferred stock
units with dividend equivalents reinvested in additional stock units.
Compensation Expense:The following table shows the compensation cost recognized in income and the tax benefits resulting from
these plans,as well as the amounts allocated to Idaho Power for those costs associated with Idaho Power's employees (in thousands
ofdollars):
2015 2014
$$5,458
2,134
Compensation cost
Income tax benefit
5,221
2,042
No equity compensation costs have been capitalized.
8.COMMITMENTS
Purchase Obligations
At December 31,2015,Idaho Power had the following long-term commitments relating to purchases of energy,capacity,transmission
rights,and fuel (in thousands of dollars):
2017 2018 2019 2020 Thereafter2016
Cogeneration and power
production $234,772
9,169
$234,316
8,833
$3,592,891
114,417
$199,156
60,122
$233,197 $241,356
43,276 16,206Fuel
As ofDecember 31,2015,Idaho Power had 784 MW nameplate capacity of PURPA-related projects on-line,with an additional 448
MW nameplate capacity ofprojects projected to be on-line by June 1,2017.Ofthe 448 MW nameplate capacity of projected
PURPA-related projects at the end of 2015,as of February 5,2016,three contracts with solar projects with a combined nameplate
capacity of 25 MW had terminated.Termination of the agreements reduced Idaho Power's contractual payment obligations by
approximately $74 million over the 20-year lives ofthe terminated contracts.The power purchase contracts for these projects have
original contract terms ranging from one to 35 years.Idaho Power's expenses associated with PURPA-related projects were
approximately $131 million in 2015 and $145 million in 2014.
Idaho Power also has the following long-term commitments for lease guarantees,equipment,maintenance and services,and industry
related fees (in thousands ofdollars):
2016 2017 2018 2019 2020 Thereafter
$233 $971 $985
48,707 11,703 14,869
$1,062 $897
9,214 12,095
$12,625
83,721
Operating leases
Equipment,maintenance,and service
agreements
FERC and other industry-related fees 12,894 12,746 12,746 8,632 5,942 29,708
Idaho Power's expense for operating leases was approximately $4.4 million in 2015 and $5.9 million in 2014.
Guarantees
Through a self-bonding mechanism,Idaho Power guarantees its portion of reclamation activities and obligations at BCC,of which
FERC FORM NO.1 (ED.12-88)Page 123.17
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NOTES TO FINANCIAL STATEMENTS (Continued)
Name of Respondent
2015/Q4IdahoPowerCompany
IERCo owns a one-third interest.This guarantee,which is renewed annually with the Wyoming Department of Environmental
Quality,was $73 million at December 31,2015,representing IERCo's one-third share of BCC's total reclamation obligation.BCC
has a reclamation trust fund set aside specifically for the purpose ofpaying these reclamation costs.At December 31,2015,the value
of the reclamation trust fund was $70 million.During 2015,the reclamation trust fund distributed approximately $6 million for
reclamation activity costs associated with the BCC surface mine.BCC periodically assesses the adequacy of the reclamation trust
fund and its estimate of future reclamation costs.To ensure that the reclamation trust fund maintains adequate reserves,BCC has the
ability to add a per-ton surcharge to coal sales,all of which are made to the Jim Bridger plant.Starting in 2010,BCC began applying
a nominal surcharge to coal sales in order to maintain adequate reserves in the reclamation trust fund.Because ofthe existence of the
fund and the ability to apply a per-ton surcharge,the estimated fair value ofthis guarantee is minimal.
Idaho Power enters into financial agreements and power purchase and sale agreements that include indemnification provisions
relating to various forms of claims or liabilities that may arise from the transactions contemplated by these agreements.Generally,a
maximum obligation is not explicitly stated in the indemnification provisions and,therefore,the overall maximum amount ofthe
obligation under such indemnification provisions cannot be reasonably estimated.Idaho Power periodically evaluates the likelihood
of incurring costs under such indemnities based on their historical experience and the evaluation ofthe specific indemnities.As of
December 31,2015,management believes the likelihood is remote that Idaho Power would be required to perform under such
indemnification provisions or otherwise incur any significant losses with respect to such indemnification obligations.Idaho Power
has not recorded any liability on its consolidated balance sheet with respect to these indemnification obligations.
9.CONTINGENCIES
Idaho Power has in the past and expects in the future to become involved in various claims,controversies,disputes,and other
contingent matters,including the items described in this Note 9.Some of these claims,controversies,disputes,and other contingent
matters involve litigation and regulatory or other contested proceedings.The ultimate resolution and outcome of litigation and
regulatory proceedings is inherently difficult to determine,particularly where (a)the remedies or penalties sought are indeterminate,
(b)the proceedings are in the early stages or the substantive issues have not been well developed,or (c)the matters involve complex
or novel legal theories or a large number ofparties.In accordance with applicable accounting guidance,Idaho Power establishes an
accrual for legal proceedings when those matters proceed to a stage where they present loss contingencies that are both probable and
reasonably estimable.In such cases,there may be a possible exposure to loss in excess of any amounts accrued.Idaho Power
monitors those matters for developments that could affect the likelihood of a loss and the accrued amount,if any,and adjust the
amount as appropriate.If the loss contingency at issue is not both probable and reasonably estimable,Idaho Power does not establish
an accrual and the matter will continue to be monitored for any developments that would make the loss contingency both probable
and reasonably estimable.As ofthe date of this report,Idaho Power's accruals for loss contingencies are not material to the financial
statements as a whole;however,future accruals could be material in a given period.Idaho Power's determination is based on
currently available information,and estimates presented in financial statements and other financial disclosures involve significant
judgment and may be subject to significant uncertainty.For matters that affect Idaho Power's operations,Idaho Power intends to
seek,to the extent permissible and appropriate,recovery through the ratemaking process ofcosts incurred.
Western Energy Proceedings
High prices for electricity,energy shortages,and blackouts in California and in the western wholesale markets during 2000 and 2001
caused numerous purchasers of electricity in those markets to initiate proceedings to consider requiring refunds and other forms of
disgorgement from energy sellers.Some ofthese proceedings remain pending before the FERC or are on appeal to the United States
Court of Appeals for the Ninth Circuit,and thus there remains some uncertainty about the ultimate outcome ofthe proceedings.Idaho
Power and IESCo (as successor to IDACORP Energy L.P.)believe that the current state ofthe FERC's orders,if maintained,and the
settlement releases they have obtained,will restrict potential claims that might result from the pending proceedings.As a result,Idaho
Power predicts that these matters will not have a material adverse effect on the results of operations or financial condition.However,
if unanticipated orders are issued by the FERC or by the Ninth Circuit Court of Appeals or other courts,exposure to indirect claims in
the proceedings could exist.These indirect claims would consist of so-called "ripple claims,"which involve potential claims for
refunds in the Pacific Northwest markets from an upstream seller of power based on a finding that its downstream buyer was liable for
refunds as a seller of power during the relevant period.Given the speculative nature of ripple claims and in light ofIdaho Power's
and IESCo participating in the market as both a buyer and seller of energy,Idaho Power and IESCo are unable to estimate the
possible loss or range of loss that could result from the proceedings and have no amount accrued relating to the proceedings.To the
FERC FORM NO.1 (ED.12-88)Page 123.16
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NOTES TO FINANCIAL STATEMENTS (Continued)
extent the availability ofany ripple claims materializes,Idaho Power and IESCo will continue to vigorously defend their positions in
the proceedings.
Hoku Corporation Bankruptcy Claims
On June 26,2015,the trustee in the Hoku Corporation chapter 7 bankruptcy case (In Re:Hoku Corporation,United States
Bankruptcy Court,District of Idaho,Case No.13-40838 JDP)filed a complaint against Idaho Power,alleging that specified payments
made by Hoku Corporation to Idaho Power in the six years prior to Hoku Corporation's bankruptcy filing in July 2013 should be
recoverable by the trustee as constructive fraudulent transfers.Hoku Corporation was the parent entity of Hoku Materials,Inc.,with
which Idaho Power had an electric service agreement approved by the IPUC in March 2009.Under the electric service agreement,
Idaho Power agreed to provide electric service to a polysilicon production facility under construction by Hoku Materials in the state of
Idaho.Idaho Power also had agreements with Hoku Materials pertaining to the design and construction ofapparatus for the provision
of electric service to the polysilicon plant.The trustee's complaint against Idaho Power includes alternative causes of action for
constructive fraudulent transfer under the federal bankruptcy code,Idaho law,and federal law,with requests for recovery from Idaho
Power in amounts up to approximately $36 million.The complaint alleges that the payments made by Hoku Corporation to Idaho
Power are subject to recovery by the trustee on the basis that Hoku Corporation was insolvent at the time ofthe payments and did not
have any legal or equitable title in the polysilicon plant or liability for Hoku Materials'debts,and thus did not receive reasonably
equivalent value for the payments it made for or on behalf of Hoku Materials.
As of the date ofthis report,the proceedings are in preliminary stages and it is not possible to determine Idaho Power's potential
liability,if any,or to reasonably estimate a possible loss or range ofpossible loss,ifany,within the trustee's alternative prayers for
relief.Idaho Power intends to vigorously defend against the claims.
Other Proceedings
Idaho Power is party to legal claims and legal and regulatory actions and proceedings in the ordinary course of business that are in
addition to those discussed above and,as noted above,record an accrual for associated loss contingencies when they are probable and
reasonably estimable.As of the date of this report the company believes that resolution of those matters will not have a material
adverse effect on the consolidated financial statements.Idaho Power is also actively monitoring various pending environmental
regulations that may have a significant impact on its future operations.Given uncertainties regarding the outcome,timing,and
compliance plans for these environmental matters,Idaho Power is unable to estimate the financial impact ofthese regulations.
However,Idaho Power does believe that future capital investment for infrastructure and modifications to its electric generating
facilities could be significant to comply with these regulations.
10.BENEFIT PLANS
Idaho Power sponsors defined benefit and other postretirement benefit plans that cover the majority of its employees.Idaho Power
also sponsors a defined contribution 40 1 (k)employee savings plan and provides certain post-employment benefits.
Pension Plans
Idaho Power has two pension plans-a noncontributory defined benefit pension plan (pension plan)and a nonqualified defined benefit
pension plan for certain senior management employees called the Security Plan for Senior Management Employees (SMSP).Idaho
Power also has a nonqualified defined benefit pension plan for directors that were frozen in 2002.Remaining vested benefits from
that plan are included with the SMSP in the disclosures below.The benefits under these plans are based on years ofservice and the
employee's final average earnings.
Idaho Power's funding policy for the pension plan is to contribute at least the minimum required under the Employee Retirement
Income Security Act of 1974 (ERISA)but not more than the maximum amount deductible for income tax puiposes.In 2015,and
2014 Idaho Power elected to contribute more than the minimum required amounts in order to bring the pension plan to a more funded
position,to reduce future required contributions,and to reduce Pension Benefit Guaranty Corporation premiums.
FERC FORM NO.1 (ED.12-88)Page 123.19
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(2)_A Resubmission
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NOTES TO FINANCIAL STATEMENTS (Continued)
The following table summarizes the changes in benefit obligations and plan assets ofthese plans (in thousands of dollars):
SMSPPensionPlan
2014201520142015
Change in projected benefit obligation:
Benefit obligation at January I
Service cost
Interest cost
Actuarial (gain)loss
Benefits paid
Projected benefit obligation at December 31
94,410 $
1,689
3,868
(352)
(4.226)
695,093 $
25,292
35,415
114,496
(25.484)
77,773
1,645
3,856
15,324
(4,188)
$844,812 S
33,164
35,171
(47,952)
(29.672)
94,41095,389844.812835,523
Change in plan assets:
Fair value at January 1
Actual return on plan assets
Employer contributions
Benefits paid
Fair value at December 31
559,719
(9,431)
39,000
(29.672)
545,092
10,111
30,000
(25,484)
559.719559.616
(275,907)g (285,093.)$(95,389)$(94,410)iFundedstatusatendofyear
Amounts recognized in the statement of financial position consist of:
Other current liabilities $(4,423)$
(90,966)
(4,193)
(90,217)
$$
(285.093)(275.907)NoncurTent liabilities
(94,410)(95,389)(285.093)(275,907)Net amount recognized
Amounts recognized in accumulated other comprehensive income consist of:
Net loss
Prior service cost
38,80834,260253,212 263,350
673 85774295
39,66534,933253,286
(253,286)
263.645
(263,645)
Subtotal
Less amount recorded as rtgulalory asset
Net amount recognized in accumulated oilier comprehensive income
.Accumulated benefit ohligation
$34,933 t 39.665I$
714,994 $719,617 $86.838 S 84,684$
As a non-qualified plan,the SMSP has no plan assets.However,Idaho Power has a Rabbi trust designated to provide funding for
SMSP obligations.The Rabbi trust holds investments in marketable securities and corporate-owned life insurance.The recorded
value of these investments was approximately $69.3 million and $65.0 million at December 31,2015 and 2014,respectively,and is
reflected in Investments and in Company-owned life insurance on the consolidated balance sheets.
The following table shows the components ofnet periodic benefit cost for these plans (in thousands of dollars).For purposes of
calculating the expected return on plan assets,the market-related value of assets is equal to the fair value ofthe assets.
SMSPPensionPlan
2014201420152015
$1,645
3,856
$25,292 $1,689
35,415 3,868
(42,289)
3,911 4,195
$33,164
35,171
(42,310)
13,927
Service cost
Interest cost
Expected return on assets
Amortization of net loss 2,618
220185347221Amortizationofpriorservicecost
8,3399,93740,173
(21,173)
22,676
12,124
Net periodic pension cost
Adjustments due to the effects of regulation!1 )
Net periodic benefit cost recognized for financial
reporting $34,800 $9,937 $8.339$19,000
(1)Net periodic benefit costs for the pension plan are recognized for financial reporting based upon the authorization ofeach regulatory jurisdiction in which Idaho
Power operates Under IPUC order,income statement recognition ofpension plan costs is deferred until costs are recovered through rates
FERC FORM NO.1 (ED.12-88)Page 123.20
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(1)X An Original
(2)_A Resubmission
Name of Respondent
2015/Q4IdahoPowerCompany
NOTES TO FINANCIAL STATEMENTS (Continued)
The following table shows the components ofother comprehensive income for the plans (in thousands of dollars):
SMSPPension
Plan
2014201420152015
353 $(15,324)$(3,790)$(146,674)$Actuarial (loss)gain during the year
Reclassification adjustments for:
Amortization ofnet loss 2,6184,19513,927 3,911
220347185221Amortizationofpriorservicecost
Adjustment for deferred tax effects
Adjustment due to the effects ofregulation
Other comprehensive income recognized related to pension benefit $
4,88155,678
86,738
0,851)(4,050)
(6,308)
$2,882 $(7,605)$
plans
In 2016,Idaho Power expects to recognize as components of net periodic benefit cost $17.3 million from amortizing amounts
recorded in accumulated other comprehensive income (or as a regulatory asset for the pension plan)as of December 31,2015,relating
to the pension plan and SMSP.This amount consists of $13.5 million ofamortization of net loss and $0.1 million ofamortization of
prior service cost for the pension plan,and $3.5 million ofamortization ofnet loss and $0.2 million ofamortization ofprior service
cost for the SMSP.
The following table summarizes the expected future benefit payments ofthese plans (in thousands ofdollars):
2021-202520192020201720182016
$241,079$30,086 $32,529 $35,156 $37,795 $40,527Pension
Plan
25,6594,9644,582 4,371 4,5474,516SMSP
As ofDecember 31,2015,Idaho Power's minimum required contributions to the pension plan are estimated to be zero in 2016,
though Idaho Power plans to contribute at least $20 million to the pension plan during 2016 in order to help balance the regulatory
collection of these expenditures with the amount and timing of contributions and to mitigate the cost of being in an underfunded
position.
Postretirement Benefits
Idaho Power maintains a defined benefit postretirement benefit plan (consisting ofhealth care and death benefits)that covers all
employees who were enrolled in the active-employee group plan at the time of retirement as well as their spouses and qualifying
dependents.Retirees hired on or after January 1,1999 have access to the standard medical option at full cost,with no contribution by
Idaho Power.Benefits for employees who retire after December 31,2002 are limited to a fixed amount,which has limited the growth
of Idaho Power's future obligations under this plan.
FERC FORM NO.1 (ED.12-88)Page 123.21
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(1)X An Original
(2)_A Resubmission 2015/Q4IdahoPowerCompany
NOTES TO FINANCIAL STATEMENTS (Continued)
The following table summarizes the changes in benefit obligation and plan assets (in thousands of dollars):
20142015
Change in accumulated benefit obligation:
Benefit obligation at January 1
Service cost
Interest cost
$65,999 $57,341
1,0111,235
2,841
7,026
(2,220)
2,678
(5,008)
(2,511)
Actuarial (gain)loss
Benefits paidU)
Benefit obligation at December 3 1
Change in plan assets:
Fair value of plan assets at January 1
Actual return on plan assets
Employer contributions'^')
Benefits paid(l)
Fair value of plan assets at December 31
Funded status at end ofyear (included in noncurrent
liabilities)
(!)Contributions and benefits paid are each net of $3,518 thousand and $3,379 thousand ofplan participant contributions,and $330 thousand and $344 thousand of
Medicare Part D subsidy receipts for201 5 and 2014,respectively
65,99962.393
37,111
3,888
(404)
(2,220)
38,375
85
(383)
(2,511)
38,37535,566
$(26,827)$(27,624)
Amounts recognized in accumulated other comprehensive income consist of the following (in thousands of dollars):
20142015
$(1,654)$759Net(gain)loss
Prior service cost
Subtotal
Less amount recognized in regulatory assets
Net amount recognized in accumulated other comprehensive
income
130 145
(1,524)
1,524
904
(904)
$$
The net periodic postretirement benefit cost was as follows (in thousands ofdollars):
2015 2014
$1,235
2,678
(2,680)
$1,011
2,841
(2,595)
Service cost
Interest cost
Expected return on plan assets
Amortization of prior service cost 15 183
$1,248 $1,440Netperiodicpostretirementbenefit
cost
The following table shows the components of other comprehensive income for the plan (in thousands of dollars):
20142015
$2,413 $(5,733)Actuarial gain (loss)during the year
Reclassification adjustments for:
Amortization of prior service cost
Adjustment for deferred tax effects
Adjustment due to the effects ofregulation
Other comprehensive income related to postretirement benefit
plans
15 183
(949)
(1,479)
2,170
3,380
$$
FERC FORM NO.1 (ED.12-88)Page 123.22
Date of Report Year/Period of Report
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This Report is:
(1)X An Original
(2)_A Resubmission
Name of Respondent
2015/Q4IdahoPowerCompany
NOTES TO FINANCIAL STATEMENTS (Continued)
In 2016,Idaho Power expects to recognize as components ofnet periodic benefit cost $26 thousand from amortizing amounts
recorded in accumulated other comprehensive income as of December 3 1,2015,relating to the postretirement benefit plan.The entire
amount represents $26 thousand of amortization of prior service cost.
MedicareAct:The Medicare Prescription Drug,Improvement and Modernization Act of2003 was signed into law in December
2003 and established a prescription drug benefit under Medicare Part D,as well as a federal subsidy to sponsors ofretiree health care
benefit plans that provide a prescription drug benefit that is at least actuarially equivalent to Medicare's prescription drug coverage.
The following table summarizes the expected future benefit payments of the postretirement benefit plan and expected Medicare Part D
subsidy receipts (in thousands of dollars):
2020 2021-20252018201920162017
$4,010 $4,050 $4,100 $4,150 $4,190 $21,030
3.480
Expected benefit payments
Expected Medicare Part D subsidy receipts 560430470510380
Plan Assumptions
The following table sets forth the weighted-average assumptions used at the end ofeach year to determine benefit obligations for all
Idaho Power-sponsored pension and postretirement benefits plans:
Postretirement
Benefits
Pension Plan SMSP
2014 2015 2014201520152014
4.2%4 6%4.2%4.6%4 6%4 25%Discount rate
Rate ofcompensation
increase!')
Medical trend rate
Dental trend rate
Measurement date
4 5%4 5%4 1 1%4 3%
6 4%9.7%
5%5%
12/31/201412/31/2014 12/31/201512/31/2015 12/31/2014 12/31/2015
0)The 2015 rate ofcompensation increase assumption for the pension plan includes an inflation component of2.50%plus a 1.61%composite merit increase
component that is based on employees'years of service Merit salary increases are assumed to be 8.0%for employees in their first year of service and scale down to 0%
for employees in their fortieth year of service and beyond.
The following table sets forth the weighted-average assumptions used to determine net periodic benefit cost for all Idaho
Power-sponsored pension and postretirement benefit plans:
Pension
Postretirement
Benefits
SMSPPlan
2015 20142014201520142015
4.2%5.1%4.2%5.15%4.25%5.2%Discount rate
Expected long-term rate of return on
assets
Rate of compensation increase
Medical trend rate
Dental trend rate
7.25%7.25%7.5%7.75%
4.11%4.3%4.5%4.5%
9.7%6.4%
5%5%
In October 2014,the Society of Actuaries released a new set of mortality tables referred to as RP-2014.Mortality tables are used by
defined benefit plans to estimate the life expectancy of plan participants and the expected length ofbenefit payments in retirement.
Idaho Power's measurement ofits plan benefit obligations as of December 3 1 ,2015 and 2014,and its net periodic benefit cost for
2015,reflect the adoption ofthe new tables,which was not material.
FERC FORM NO.1 (ED.12-88)Page 123.23
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(1)X An Original
(2)_A Resubmission
Name of Respondent
2015/Q4IdahoPowerCompany
NOTES TO FINANCIAL STATEMENTS (Continued)
The assumed health care cost trend rate used to measure the expected cost of health benefits covered by the postretirement plan was
9.7 percent in 2015 and is assumed to decrease to 8.3 percent in 2016,6.8 percent in 2017,and 5.4 percent in 2018 and to gradually
decrease to 4.8 percent by 2099.The assumed dental cost trend rate used to measure the expected cost of dental benefits covered by
the plan was 5.0 percent,or equal to the medical trend rate iflower,for all years.A one percentage point change in the assumed
health care cost trend rate would have the following effects at December 31,2015 (in thousands of dollars):
One-Percentage-Point
Increase Decrease
407 $(297)
3,719 (2,838)
$Effect on total ofcost components
Effect on accumulated postretirement benefit
obligation
Plan Assets
Pension Asset Allocation Policy:The target allocation and actual allocations at December 31,2015 for the pension asset portfolio by
asset class is set forth below:
Actual
Allocation
Asset Class Target
Allocation
December 31,2015
Debt securities
Equity securities
Real estate
Other plan
assets
Total
25%24%
55%54%
7%6%
13%16%
100%100%
Assets are rebalanced as necessary to keep the portfolio close to target allocations.
The plan's principal investment objective is to maximize total return (defined as the sum of realized interest and dividend income and
realized and unrealized gain or loss in market price)consistent with prudent parameters ofrisk and the liability profile of the
portfolio.Emphasis is placed on preservation and growth of capital along with adequacy ofcash flow sufficient to fund current and
future payments to pensioners.
The three major goals in Idaho Power's asset allocation process are to:
•determine if the investments have the potential to earn the rate ofreturn assumed in the actuarial liability calculations;
•match the cash flow needs of the plan.Idaho Power sets bond allocations sufficient to cover at least five years ofbenefit
payments and cash allocations sufficient to cover the current year benefit payments.Idaho Power then utilizes growth
instruments (equities,real estate,venture capital)to fund the longer-term liabilities ofthe plan;and
•maintain a prudent risk profile consistent with ERISA fiduciary standards.
Allowable plan investments include stocks and stock funds,investment-grade bonds and bond funds,core real estate funds,private
equity funds,and cash and cash equivalents.With the exception ofreal estate holdings and private equity,investments must be
readily marketable so that an entire holding can be disposed of quickly with only a minor effect upon market price.
Rate-of-return projections for plan assets are based on historical risk/return relationships among asset classes.The primary measure is
the historical risk premium each asset class has delivered versus the yield on the Moody's AA Corporate Bond Index.This historical
risk premium is then added to the current yield on the Moody's AA Corporate Bond Index.Additional analysis is performed to
measure the expected range of returns,as well as worst-case and best-case scenarios.Based on the current low interest rate
environment,current rate-of-return expectations are lower than the nominal returns generated over the past 20 years when interest
rates were generally much higher.
FERC FORM NO.1 (ED.12-88)Page 123.24
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(1)X An Original
(2)_A Resubmission
NOTES TO FINANCIAL STATEMENTS (Continued)
2015/Q4IdahoPowerCompany
Idaho Power's asset modeling process also utilizes historical market returns to measure the portfolio's exposure to a "worst-case"
market scenario,to determine how much performance could vary from the expected "average"performance over various time
periods.This "worst-case"modeling,in addition to cash flow matching and diversification by asset class and investment style,
provides the basis for managing the risk associated with investing portfolio assets.
Fair Value ofPlan Assets:Idaho Power classifies its pension plan and postretirement benefit plan investments using the three-level
fair value hierarchy described in Note 15.The following table presents the fair value of the plans'investments by asset category (in
thousands of dollars).Ifthe inputs used to measure the securities fall within different levels of the hierarchy,the categorization is
based on the lowest level input (Level 3 being the lowest)that is significant to the fair value measurement of the security.
Level 2 Level 3 TotalLevel1
Assets at December 31,2015
Pension plan assets:
Cash and cash equivalents
Short-term bonds
Intermediate bonds
Long-term bonds
Equity Securities:Large-Cap
Equity Securities:Mid-Cap
Equity Securities:Small-Cap
Equity Securities:Micro-Cap
Equity Securities:International
Equity Securities:Emerging
Markets
Real estate
Private market investments
Commodities funds
$$$$10,519
11,023
11,499
10,519
11,023
104,241
21,747
73,489
64,397
47,777
22,186
67,485
32,846
92,742
21,747
73,489
64,397
47,777
22,186
7,698
9,679
59,787
23,167
39,035
37,316
39,035
37,316
27,55527,555
$258,267 $224,998 $76,351 $559,616Totalpensionassets
Postretirement plan assetsW 16 $35,550 $$35,566$
Assets at December 31,2014
Pension plan assets:
Cash and cash equivalents
Short-term bonds
Intermediate bonds
Long-term bonds
Equity Securities:Large-Cap
Equity Securities:Mid-Cap
Equity Securities:Small-Cap
Equity Securities:Micro-Cap
Equity Securities:International
Equity Securities:Emerging
Markets
Real estate
Private market investments
Commodities funds
$$$$19,190 19,190
10,991
101,867
21,615
66,151
68,974
50,972
22,962
64,260
31,544
10,991
101,867
21,615
66,151
68,974
50,972
22,962
6,555
8,629
57,705
22,915
33,996
37,118
33,996
37,118
30,07930,079
$243,433 $245,172 $71,114 $559,719Totalpensionassets
Postretirement plan assets^)$38,364 $$38,375$11
(')The postretirement benefits assets are primarily life insurance contracts.
For the year ended December 31,2015,there were no significant transfers into or out of Levels 1,2,or 3.For the year ended
December 31,2014,there were $23.1 million of mid-cap equity security investments that were transferred from Level 2 to Level 1,
FERC FORM NO.1 (ED.12-88)Page 123.25
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Name of Respondent This Report is:
(1)X An Original
(2)_A Resubmission
NOTES TO FINANCIAL STATEMENTS (Continued)
2015/Q4IdahoPowerCompany
The following table presents a reconciliation ofthe beginning and ending balances of the fair value measurements using significant
unobservable inputs (Level 3)(in thousands of dollars):
Private Real Total
Equity Estate
$28,019 $61,728
2,296
$33,709
1,430
(545)
2,434
Beginning balance -January 1,2014
Realized gains
Unrealized (losses)gains
Purchases
Settlements
866
7601,305
3,806 6,240
9090
Ending balance -December 3 1 ,
2014 37,118
1,897
(3,152)
2,255
(802)
33,996 71,114
2,820Realizedgains
Unrealized (losses)gains
Purchases
Sales
923
3,193 41
3,178
(802)
923
Ending balance -December 3 1 ,
$39,035 $76,351$37,3162015
Fair Value Measurement ofLevel 2 and Level 3 Plan Asset Inputs:
Level 2 Bonds.Equity Securities,and Level 2 Commodities:These investments represent U.S.government and agency bonds,
corporate bonds,and commingled funds consisting of publicly traded equity securities or exchange-traded commodity contracts and
other contractual claims to commodity holdings.The U.S.government and agency bonds,as well as the corporate bonds,are not
traded on an exchange and are valued utilizing quoted prices for similar assets or liabilities in active markets.The commingled funds
themselves are not publicly traded,and therefore no publicly quoted market price is readily available.The value ofthese investments
is calculated by the custodian for the fund company on a monthly basis,and is based on market prices of the assets held by the
commingled fund divided by the number of fund shares outstanding.
Level 2 Postretiremein Assets:These assets represent an investment in a life insurance contract and are recorded at fair value,which
is the cash surrender value,less any unpaid expenses.The cash surrender value of this insurance contract is contractually equal to the
insurance contract's proportionate share ofthe market value ofan associated investment account held by the insurer.The investments
held by the insurer's investment account are all instruments traded on exchanges with readily determinable market prices.
Level 3 Real Estate:Real estate holdings represent investments in open-ended commingled real estate funds.As the property
interests held in these real estate funds are not frequently traded,establishing the market value of the property interests held by the
fund,and the resulting unit value of fund shareholders,is based on unobservable inputs including property appraisals by the fund
company,property appraisals by independent appraisal firms,analysis of the replacement cost of the property,discounted cash flows
generated by property rents and changes in property values,and comparisons with sale prices of similar properties in similar markets.
These open-ended real estate funds also furnish annual audited financial statements that are also used to further validate the
information provided.
Level 3 Private Market Investments:Private market investments represent two categories:fund of hedge funds and venture capital
funds.These funds are valued by the fund company based on the estimated fair value ofthe underlying fund holdings divided by the
fund shares outstanding.Some hedge fund strategies utilize securities with readily available market prices,while others utilize less
liquid investment vehicles that are valued based on unobservable inputs including cost,operating results,recent funding activity,or
comparisons with similar investment vehicles.Venture capital fund investments are valued by the fund company based on estimated
fair value of the underlying fund holdings divided by the fund shares outstanding.Some venture capital investments have progressed
to the point that they have readily available exchange-based market valuations.Early stage venture investments are valued based on
unobservable inputs including cost,operating results,discounted cash flows,the price of recent funding events,or pending offers
from other viable entities.These private market investments furnish annual audited financial statements that are also used to further
FERC FORM NO.1 (ED.12-88)Page 123 26
Date of Report Year/Period of Report
(Mo,Da,Yr)
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Name of Respondent This Report is:
(1)X An Original
(2)_A Resubmission 2015/Q4IdahoPowerCompany
NOTES TO FINANCIAL STATEMENTS (Continued)
validate the information provided.
The fair value of the Level 3 assets is determined based on pricing provided or reviewed by third-party vendors to our investment
managers.While the input amounts used by the pricing vendors in determining fair value are not provided,and therefore unavailable
for Idaho Power's review,the asset results are reviewed and monitored to ensure the fair values are reasonable and in line with market
experience in similar assets classes.Additionally,the audited financial statements ofthe funds are reviewed at the time they are
issued.
Employee Savings Plan
Idaho Power has a defined contribution plan designed to comply with Section 401(k)ofthe Internal Revenue Code and that covers
substantially all employees.Idaho Power matches specified percentages ofemployee contributions to the plan.Matching annual
contributions were approximately $7 million each year from 2014 to 2015.
Post-employment Benefits
Idaho Power provides certain benefits to former or inactive employees,their beneficiaries,and covered dependents after employment
but before retirement,in addition to the health care benefits required under the Consolidated Omnibus Budget Reconciliation Act.
These benefits include salary continuation,health care and life insurance for those employees found to be disabled under Idaho
Power's disability plans,and health care for surviving spouses and dependents.Idaho Power accrues a liability for such benefits.The
post employment benefit amounts included in other deferred credits on Idaho Power's consolidated balance sheet at both
December 31,2015 and 2014 were $2.0 million.
11.PROPERTY,PLANT AND EQUIPMENT AND JOINTLY-OWNED PROJECTS
The following table presents the major classifications ofIdaho Power's utility plant in service,annual depreciation provisions as a
percent ofaverage depreciable balance,and accumulated provision for depreciation for the years 2015 and 2014 (in thousands of
dollars):
2015 2014
Avg Rate Balance
2.46%
2.01%
2.72%
5.62%
Avg Rate
2.48%
2.03%
2.72%
5.49%
Balance
$2,422,175
1,077,065
1,578,445
407,779
$2,316,941
1,016,207
1,516,933
398,131
Production
Transmission
Distribution
General and Other
Total in service
Accumulated provision for
depreciation
In service -net
5,485,464 2.68%5,248,212 2.68%
(2,097,432)(2,021,074)
$3,388,032 $3,227,138
Idaho Power's ownership interest in three jointly-owned generating facilities is included in the table above.Under the joint operating
agreements for these facilities,each participating utility is responsible for financing its share of construction,operating,and leasing
costs.Idaho Power's proportionate share of operating expenses for each facility is included in the Consolidated Statements of Income.
Thesejointly-owned facilities,including balance sheet amounts and the extent of Idaho Power's participation,were as follows at
December 31,2015 (in thousands ofdollars):
FERC FORM NO.1 (ED.12-88)Page 123.27
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Name of Respondent This Report is:
(1)X An Original
(2)_A Resubmission 2015/Q4IdahoPowerCompany
NOTES TO FINANCIAL STATEMENTS (Continued)
Accumulated Ownership %MW(')
Provision for
Utility Plant
in Service
Construction
Work in
Progress
Name of Plant Location
Depreciation
641,382 $46,094 $296,671JimBridgerUnits1-4 Rock Springs,$77133
WY
6410Boardman
Valmy Units 1 and 2
Boardman,OR
Winnemucca,
81,252
402,276
113 63,715
184,604 2841,135 50
NV
(U Idaho Power's share ofnameplate capacity.
IERCo,Idaho Power's wholly-owned subsidiary,is ajoint venturer in BCC.Idaho Power's coal purchases from the joint venture
were $93 million in 2015 and $79 million in 2014.
Idaho Power has contracts to purchase the energy from four PURPA qualified facilities that are 50 percent owned by Ida-West.Idaho
Power's power purchases from these facilities were $8 million in 2015 and $9 million in 2014.
12.ASSET RETIREMENT OBLIGATIONS (ARO)
The guidance relating to accounting for AROs requires that legal obligations associated with the retirement ofproperty,plant,and
equipment be recognized as a liability at fair value when incurred and when a reasonable estimate ofthe fair value ofthe liability can
be made.Under the guidance,when a liability is initially recorded,the entity increases the carrying amount of the related long-lived
asset to reflect the future retirement cost.Over time,the liability is accreted to its estimated settlement value and paid,and the
capitalized cost is depreciated over the useful life ofthe related asset.If,at the end of the asset's life,the recorded liability differs
from the actual obligations paid,a gain or loss would be recognized.As a rate-regulated entity,Idaho Power records regulatory assets
or liabilities instead of accretion,depreciation,and gains or losses,as approved by the IPUC.The regulatory assets recorded under
this order do not earn a return on investment.Beginning June 1,2012,accretion,depreciation,and gains or losses related to the
Boardman generating facility have been exempted from such regulatory treatment as Idaho Power is now collecting amounts related
to the decommissioning of Boardman in rates.
Idaho Power's recorded AROs relate to the removal ofpolychlorinated biphenyl-contaminated equipment at its distribution facilities
and the reclamation and removal costs at its jointly-owned coal-fired generation facilities.In 2015,changes in estimates at its
distribution facilities and at the coal-fired generation facilities resulted in a net increase of $5.0 million in the recorded AROs.The
increase in the AROs in 2015 is primarily related to the impact of new coal combustion residual regulations on the Bridger generating
facility.
Idaho Power also has additional AROs associated with its transmission system,hydroelectric facilities,natural gas-fired generation
facilities,and jointly owned coal-fired generation facilities;however,due to the indeterminate removal date,the fair value ofthe
associated liabilities currently cannot be estimated and no amounts are recognized in the consolidated financial statements.
The following table presents the changes in the carrying amount ofAROs (in thousands of dollars):
20142015
$21,930 $25,765Balanceatbeginningofyear
Accretion expense
Revisions in estimated cash
flows
Liability settled
Balance at end of year
993 1,061
5,043 (4,140)
(756)(1,813)
$26,153 $21,930
FERC FORM NO.1 (ED.12-88)Page 123.28
Date of Report Year/Period of Report
(Mo,Da,Yr)
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Name of Respondent This Report is:
(1)X An Original
(2)_A Resubmission 2015/Q4IdahoPowerCompany
NOTES TO FINANCIAL STATEMENTS (Continued)
13.INVESTMENTS
The table below summarizes Idaho Power's investments as ofDecember 3 1 (in thousands ofdollars):
2015 2014
Idaho Power investments:
$84,137
24,459
$83,477
44,942
IERCO
Exchange traded short-term bond funds and cash
equivalents
Executive deferred compensation plan investments
Other investments
141102
I
Total Idaho Power investments 108,698 128,561
Investments in Equity Securities
Investments in securities classified as available-for-sale securities are reported at fair value.Any unrealized gains or losses on
available-for-sale securities are included in income,as the fair value option has been elected for these instruments.Unrealized gains
and losses on available-for-sale securities were immaterial at December 31,2015 and December 31,2014.The following table
summarizes sales of available-for-sale securities (in thousands of dollars):
2015 2014
$34,243 $Proceeds from sales
Gross realized gains from sales
Gross realized losses from
sales
At the end of each reporting period,Idaho Power analyzes securities in loss positions to determine whether they have experienced a
decline in market value that is considered other-than-temporary.At December 31,2015 and December 31,2014,there were no
indicators of other-than-temporary impairment related to Idaho Power's investments.
14.DERIVATIVE FINANCIAL INSTRUMENTS
Commodity Price Risk
Idaho Power is exposed to market risk relating to electricity,natural gas,and other fuel commodity prices,all of which are heavily
influenced by supply and demand.Market risk may be influenced by market participants'nonperformance oftheir contractual
obligations and commitments,which affects the supply ofor demand for the commodity.Idaho Power uses derivative instruments,
such as physical and financial forward contracts,for both electricity and fuel to manage the risks relating to these commodity price
exposures.The primary objectives of Idaho Power's energy purchase and sale activity are to meet the demand of retail electric
customers,maintain appropriate physical reserves to ensure reliability,and make economic use of temporary surpluses that may
develop.
All of Idaho Power's derivative instruments have been entered into for the purpose ofeconomically hedging forecasted purchases and
sales,though none ofthese instruments have been designated as cash flow hedges.Idaho Power offsets fair value amounts
recognized on its balance sheet and applies collateral related to derivative instruments executed with the same counterparty under the
same master netting agreement.Idaho Power does not offset a counterparty's current derivative contracts with the counterparty's
long-term derivative contracts,although Idaho Power's master netting arrangements would allow current and long-term positions to be
offset in the event of default.Also,in the event of default,Idaho Power's master netting arrangements would allow for the offsetting
of all transactions executed under the master netting arrangement.These types oftransactions may include non-derivative
instruments,derivatives qualifying for scope exceptions,receivables and payables arising from settled positions,and other forms of
non-cash collateral (such as letters of credit).These types oftransactions are excluded from the offsetting presented in the derivative
fair value and offsetting table below.
FERC FORM NO.1 (ED.12-88)Page 123.29
Date of Report Year/Period of Report
(Mo,Da,Yr)
04/15/2016
This Report is:
(1)X An Original
(2)__A Resubmission
Name of Respondent
2015/Q4IdahoPowerCompany
NOTES TO FINANCIAL STATEMENTS (Continued)
The table below presents the gains and losses on derivatives not designated as hedging instruments for the years ended December 31,
2015 and 2014 (in thousands of dollars):
Gain/(Loss)on Derivatives
Recognized in IncomeO
Location of Realized Gain/(Loss)
on Derivatives Recognized in
Income
20142015
$(4,119)
(1,416)
3,862
(158)
$Off-system sales
Purchased power
Fuel expense
Other operations and maintenance
Off-system sales
2,882Financialswaps
Financial swaps
Financial swaps
Financial swaps
Forward
contracts
Forward
contracts
Forward
contracts
748
(6,045)
(50)
277
(279)(6)Purchased power
9454Fuelexpense
(1)Excludes unrealized gains or losses on derivatives,which are recorded on the balance sheet as regulatory assets or regulatory liabilities.
Settlement gains and losses on electricity swap contracts are recorded on the income statement in off-system sales or purchased power
depending on the forecasted position being economically hedged by the derivative contract.Settlement gains and losses on contracts
for natural gas are reflected in fuel expense.Settlement gains and losses on diesel derivatives are recorded in other operations and
maintenance expense.See Note 15 for additional information concerning the determination of fair value for Idaho Power's assets and
liabilities from price risk management activities.
FERC FORM NO.1 (ED.12-88)Page 123.30
Date of Report Year/Period of Report
(Mo,Da,Yr)
04/15/2016
Name of Respondent This Report is:
(1)X An Original
(2)_A Resubmission 2015/Q4IdahoPowerCompany
NOTES TO FINANCIAL STATEMENTS (Continued)
Derivative Instrument Summary
The table below presents the fair values and locations of derivative instruments not designated as hedging instruments recorded on the
balance sheets and reconciles the gross amounts ofderivatives recognized as assets and as liabilities to the net amounts presented in
the balance sheets at December 31,2015 and 2014 (in thousands of dollars):
Liability
DerivativesAssetDerivatives
AmountsBalanceSheet
Location
Gross Fair
Value Net LiabilitiesAmountsOffsetNetAssetsGrossFairValueOffset
December 31,
2015
Current:
Financial swaps Other current assets
Other current
Financial swaps liabilities
Forward contracts Other current assets
Other current
Forward contracts liabilities
$(785)$$(785)$214 $785999$
(177)4,9695,146177(177)
6464
33
Long-term:
Financial swaps Other assets 148 mi 126 22 (22)
$(984)S$1,388 $(984.)$404 S 5.956 4,972Total
December 31,
2014
Current:
Financial swaps Other current assets $
Other current
Financial swaps liabilities
Forward contracts Other current assets
Other current
Forward contracts liabilities
Long-term:
Forward coniracts Other assets
Total
$(756)S(2,002)$507 S2,509 $756
4,335 (379)3,956379(379)
64 64
5 5
6363
S (1,135)$$3.015 I (2,381)5 634 S 5,096 3,%I
(1)Current asset and current liability derivative amounts offset include $0 9 million of collateral receivable and $1 2 million ofcollateral payable and for the periods
ending December 31,2015 and 2014,respectively.
The table below presents the volumes of derivative commodity forward contracts and swaps outstanding at December 3 1,2015 and
2014 (in thousands of units):
December
31,
2015 2014Commodity
Electricity purchases
Electricity sales
Natural gas
purchases
Natural gas sales
Diesel purchases
Units
MWh
MWh
357 115
120 238
11,597
6,913
78 409
1,068 243
MMBtu
MMBtu
Gallons
Credit Risk
At December 3 1,2015,Idaho Power did not have material credit risk exposure from financial instruments,including derivatives.
Idaho Power monitors credit risk exposure through reviews of counterparty credit quality,corporate-wide counterparty credit
exposure,and corporate-wide counterparty concentration levels.Idaho Power manages these risks by establishing credit and
concentration limits on transactions with counterparties and requiring contractual guarantees,cash deposits,or letters of credit from
counterparties or their affiliates,as deemed necessary.Idaho Power's physical power contracts are commonly under Western Systems
FERC FORM NO.1 (ED.12-88)Page 123.31
Date of Report Year/Period of Report
(Mo,Da,Yr)
04/15/2016
Name of Respondent This Report is:
(1)X An Original
(2)_A Resubmission
NOTES TO FINANCIAL STATEMENTS (Continued)
2015/Q4IdahoPowerCompany
Power Pool agreements,physical gas contracts are usually under North American Energy Standards Board contracts,and financial
transactions are usually under International Swaps and Derivatives Association,Inc.contracts.These contracts contain adequate
assurance clauses requiring collateralization if a counterparty has debt that is downgraded below investment grade by at least one
rating agency.
Credit-Contingent Features
Certain of Idaho Power's derivative instruments contain provisions that require Idaho Power's unsecured debt to maintain an
investment grade credit rating from Moody's Investors Service and Standard &Poor's Ratings Services.If Idaho Power's unsecured
debt were to fall below investment grade,it would be in violation ofthese provisions,and the counterparties to the derivative
instruments could request immediate payment or demand immediate and ongoing full overnight collateralization on derivative
instruments in net liability positions.The aggregate fair value ofall derivative instruments with credit-risk-related contingent features
that were in a liability position at December 3 1,2015,was $5.7 million.Idaho Power posted $0.9 million cash collateral related to
this amount.Ifthe credit-risk-related contingent features underlying these agreements were triggered on December 31,2015,Idaho
Power would have been required to post an additional $9.0 million of cash collateral to its counterparties.
15.FAIR VALUE MEASUREMENTS
Idaho Power has categorized its financial instruments into a three-level fair value hierarchy,based on the priority ofthe inputs to the
valuation technique.The fair value hierarchy gives the highest priority to quoted prices in active markets for identical assets or
liabilities (Level 1)and the lowest priority to unobservable inputs (Level 3).If the inputs used to measure the financial instruments
fall within different levels of the hierarchy,the categorization is based on the lowest level input that is significant to the fair value
measurement ofthe instrument.
Financial assets and liabilities recorded on the consolidated balance sheets are categorized based on the inputs to the valuation
techniques as follows:
*Level 1:Financial assets and liabilities whose values are based on unadjusted quoted prices for identical assets or liabilities
in an active market that Idaho Power has the ability to access.
•Level 2:Financial assets and liabilities whose values are based on the following:
a)quoted prices for similar assets or liabilities in active markets;
b)quoted prices for identical or similar assets or liabilities in non-active markets;
c)pricing models whose inputs are observable for substantially the full term of the asset or liability;and
d)pricing models whose inputs are derived principally from or corroborated by observable market data through
correlation or other means for substantially the full term of the asset or liability.
Idaho Power Level 2 inputs are based on quoted market prices adjusted for location using corroborated,observable market
data.
•Level 3:Financial assets and liabilities whose values are based on prices or valuation techniques that require inputs that are
both unobservable and significant to the overall fair value measurement.These inputs reflect management's own
assumptions about the assumptions a market participant would use in pricing the asset or liability.
Idaho Power's assessment of a particular input's significance to the fair value measurement requiresjudgment and may affect the
valuation of fair value assets and liabilities and their placement within the fair value hierarchy.An item recorded at fair value is
reclassified among levels when changes in the nature of valuation inputs cause the item to no longer meet the criteria for the level in
which it was previously categorized.There were no transfers between levels or material changes in valuation techniques or inputs
during the years ended December 31,2015 and 2014.
FERC FORM NO.1 (ED.12-88)Page 123.32
Date of Report Year/Period of Report
(Mo,Da,Yr)
04/15/2016
This Report is:
(1)X An Original
(2)_A Resubmission
NOTES TO FINANCIAL STATEMENTS (Continued)
Name of Respondent
2015/Q4IdahoPowerCompany
The following table presents information about Idaho Power's assets and liabilities measured at fair value on a recurring basis as of
December 31,2015 and 2014 (in thousands of dollars):
DecemberDecember
31,201431,2015
Level 1 Level 2 Level 3 TotalTotalLevel1Level2Level3
Assets:
-Money market funds
Derivatives
Trading securities:Equity
securities
Available-for-sale securities:ETFs
Liabilities:
Derivatives
10010,000 10010,000
63440450612834064
141102
141102
44,94224,459 44,94224,459
$4,972 $17 $3,944 $$3.961$286 $4.686 $
Idaho Power's derivatives are contracts entered into as part of its management of loads and resources.Electricity derivatives are
valued on the Intercontinental Exchange (ICE)with quoted prices in an active market.Natural gas and diesel derivative valuations
are performed using New York Mercantile Exchange (NYMEX)and ICE pricing,adjusted for location basis,which are also quoted
under NYMEX and ICE pricing.Trading securities consist of employee-directed investments held in a Rabbi Trust and are related to
an executive deferred compensation plan.Available-for-sale securities are exchange-traded short-term bond and money market funds
related to the SMSP and are held in a Rabbi Trust.
The table below presents the carrying value and estimated fair value of financial instruments that are not reported at fair value,as of
December 31,2015 and 2014,using available market information and appropriate valuation methodologies (in thousands of dollars):
December 31,2014December31,2015
Estimated Fair ValueEstimatedFairValueCarryingAmountCarryingAmount
Liabilities:
1,615,502 $1,813,243 $1,726,474 $1,788,197$Long-term debtO)
(1 long-term debt is categorized as Level 3 and Level 2,respectively,ofthe fair value hierarchy,as defined earlier in this Note 15
Long-term debt is not traded on an exchange and is valued using quoted rates for similar debt in active markets.Carrying values for
cash and cash equivalents,deposits,customer and other receivables,notes payable,accounts payable,interest accrued,and taxes
accrued approximate fair value.
FERC FORM NO.1 (ED.12-88)Page 123.33
Date of Report Year/Period of Report
(Mo,Da,Yr)
04/15/2016
Name of Respondent This Report is:
(1)X An Original
(2)_A Resubmission
NOTES TO FINANCIAL STATEMENTS (Continued)
2015/Q4IdahoPowerCompany
16.CHANGES IN ACCUMULATED OTHER COMPREHENSIVE INCOME
The table below presents amounts reclassified out of components of AOCI and the income statement location ofthose amounts
reclassified during the years ended December 31,2015,and 2014,(in thousands of dollars).Items in parentheses indicate increases
to net income.
Amount Reclassified from AOCI
Year Ended December 31,
2015 2014
Unrealized gains on available-for-sale
securities
Realized gain on sale of securities,before
taxO)$S
Tax benefit(2)
Net oftax
Amortization of defined benefit pension
items(3)
Prior service cost
Net loss
185 220
4,195 2,618
4,380 2,838
(1,712)(1,110)
Total before tax
Tax benefit*?)
Net oftax 2,668 1,728
2,668 $1,728$Total reclassification for the period
(1)The realized gain is included in Idaho Power's consolidated income statement in other income (expense),net.
(2)The tax benefit is included in incometax expense (benefit)in the consolidated income statements ofIdaho Power.
(3)Amortization of these items is included in Idaho Power's consolidated income statement in other expense,net.
17.RELATED PARTY TRANSACTIONS
IDACORP:Idaho Power performs corporate functions such as financial,legal,and management services for IDACORP and its
subsidiaries.Idaho Power charges IDACORP for the costs of these services based on service agreements and other specifically
identified costs.For these services Idaho Power billed IDACORP $0.9 million in 2015 and $1.4 million in 2014.
Ida-West:Idaho Power purchases all ofthe power generated by four of Ida-West's hydroelectric projects located in Idaho.Idaho
Power paid Ida-West $8 million in 2015 and $9 million in 2014.
FERC FORM NO.1 (ED.12-88)Page 123.34
Year/Period of Report
End of 2015/Q4
Date of Report
(Mo,Da,Yr)
04/15/2016
I his ReportIs:
(1)fx)An Original
(2)||A Resubmission
Name of Respondent
Idaho Power Company
SUMMARY OF UTILITY PLANT AND ACCUMULATED PROVISIONS
FOR DEPRECIATION.AMORTIZATION AND DEPLETION
Report in Column (c)the amount for electric function,in column (d)the amount for gas function,in column (e),(f),and (g)report other (specify)and in
column (h)common function.
Total Company for the
Current Year/Quarter Ended
ElectricClassificationLine
(c)No.(b)(a)
1 Utility Plant
2 In Service
5,485,463,7075,485,463,7073PlantinService(Classified)
4 Property Under Capital Leases
5 Plant Purchased or Sold
6 Completed Construction not Classified
7 Experimental Plant Unclassified
5,485,463,7075,485,463,7078Total(3 thru 7)
9 Leased to Others
7,090,4317,090,43110HeldforFutureUse
396,931,372396,931,37211ConstructionWorkinProgress
12 Acquisition Adjustments
5,889,485,5105,889,485,51013TotalUtilityPlant(8 thru 12)
2,097,432,0102,097,432,01014AccumProvforDepr,Amort,&Depl
3,792,053,5003,792,053,50015NetUtilityPlant(13 less 14)
16 Detail of Accum Prov for Depr,Amort &Depl
17 In Service:
2,071,784,2762,071,784,27618Depreciation
19 Amort &Depl of Producing Nat Gas Land/Land Right
20 Amort of Underground Storage Land/Land Rights
25,647,73425,647,73421AmortofOtherUtilityPlant
2,097,432,0102,097,432,01022TotalInService(18 thru 21)
23 Leased to Others
24 Depreciation
25 Amortization and Depletion
26 Total Leased to Others (24 &25)
27 Held for Future Use
28 Depreciation
29 Amortization
30 Total Held for Future Use (28 &29)
31 Abandonment of Leases (Natural Gas)
32 Amort of Plant Acquisition Adj
2,097,432,0102,097,432,01033TotalAccumProv(equals 14)(22,26,30,31,32)
Page 200FERCFORMNO.1 (ED.12-89)
Name of Respondent
Idaho Power Company
This Report Is:
(1)|x]An Original
(2)A Resubmission
ELECTRIC PLANT IN SERVICE (Account 101,102.103 and 106)
Date of Report
(Mo,Da,Yr)
04/15/2016
Year/Period of Report
End of 2015/Q4
1 .Report below the original cost of electric plant in service according to the prescribed accounts.
2.In addition to Account 101 ,Electric Plant in Service (Classified),this page and the next include Account 102,Electric Plant Purchased or Sold;
Account 103,Experimental Electric Plant Unclassified;and Account 106,Completed Construction Not Classified-Electric.
3.Include in column (c)or (d),as appropriate,corrections of additions and retirements for the current or preceding year.
4.For revisions to the amount of initial asset retirement costs capitalized,included by primary plant account,increases in column (c)additions and
reductions in column (e)adjustments.
5.Enclose in parentheses credit adjustments of plant accounts to indicate the negative effect of such accounts.
6.Classify Account 106 according to prescribed accounts,on an estimated basis if necessary,and include the entries in column (c).Also to be included
in column (c)are entries for reversals of tentative distributions of prior year reported in column (b).Likewise,if the respondent has a significant amount
of plant retirements which have not been classified to primary accounts at the end of the year,include in column (d)a tentative distribution of such
retirements,on an estimated basis,with appropriate contra entry to the account for accumulated depreciation provision.Include also in column (d)
AdditionsBalance
Beginning of Year
Line Account
No.(a)(b)M
1.INTANGIBLE PLANT1
5,7032(301)Organization
3 (302)Franchises and Consents 29,296,781 462,901
4 (303)Miscellaneous Intangible Plant
5 TOTAL Intangible Plant (Enter Total of lines 2,3,and 4)
3,479,89129,627,507
58,929,991 3,942,792
6 2.PRODUCTION PLANT
7 A.Steam Production Plant
8 (310)Land and Land Rights 1,712,208 18,263
9 (311)Structures and Improvements 150,084,364 3,911,857
10 (312)Boiler Plant Equipment 595,163,147 100,272,650
11 (313)Engines and Engine-Driven Generators
12 (314)Turbogenerator Units
13 (315)Accessory Electric Equipment
14 (316)Misc.Power Plant Equipment
159,336,727 13,999,188
70,043,047 816,126
15,934,815 2,104,268
15 (317)Asset Retirement Costs for Steam Production 6,372,118 7,557,943
16 TOTAL Steam Production Plant (Enter Total of lines 8 thru 15)998,646,426 128,680,295
17 B.Nuclear Production Plant
18 (320)Land and Land Rights
19 (321)Structures and Improvements
20 (322)Reactor Plant Equipment
21 (323)Turbogenerator Units
22 (324)Accessory Electric Equipment
23 (325)Misc.Power Plant Equipment
24 (326)Asset Retirement Costs for Nuclear Production
25 TOTAL Nuclear Production Plant (Enter Total of lines 18 thru 24)
26 C.Hydraulic Production Plant
27 (330)Land and Land Rights 31,188,341 35,573
28 (331)Structures and Improvements 175,002,423 1,215,068
29 (332)Reservoirs.Dams,and Waterways 262,578.901 7,483,596
30 (333)Water Wheels,Turbines,and Generators 207,190,561 5,110,769
31 (334)Accessory Electric Equipment
32 (335)Misc.Power PLant Equipment
33 (336)Roads,Railroads,and Bridges
56,827,891 1,778,270
21,769,922 1.140.922
9,584,640 1,295,862
34 (337)Asset Retirement Costs for Hydraulic Production
35 TOTAL Hydraulic Production Plant (Enter Total of lines 27 thru 34)764,142,679 18,060,060
36 D.Other Production Plant
37 (340)Land and Land Rights 2,690,006
38 (341)Structures and Improvements 140.902.354 1.808.711
39 (342)Fuel Holders.Products,and Accessories 10,452,547
40 (343)Prime Movers 238,896,447 858,744
41 (344)Generators 66,355,256 176,620
42 (345)Accessory Electric Equipment 88,607,565 2,591,423
43 (346)Misc.Power Plant Equipment 6,247,393 -236,918
44 (347)Asset Retirement Costs for Other Production
45 TOTAL Other Prod.Plant (Enter Total of lines 37 thru 44)554,151,568 5,198,580
46 TOTAL Prod.Plant (Enter Total of lines 16,25,35,and 45)2,316,940,673 151,938,935
FERC FORM NO.1 (REV.12-05)Page 204
Name of Respondent
Idaho Power Company
This Report Is:
(1)[xjAn Original
(2)QA Resubmission
ELECTRIC PLANT IN SERVICE (Account 101,102,103 and 106)(Continued)
Date of Report
(Mo,Da,Yr)
04/15/2016
Year/Period of Report
End of 2015/Q4
distributions of these tentative classifications in columns (c)and (d),including the reversals of the prior years tentative account distributions of these
amounts.Careful observance of the above instructions and the texts of Accounts 101 and 1 06 will avoid serious omissions of the reported amount of
respondent's plant actually in service at end of year.
7.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.
8.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.
9.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
Retirements Adjustments Transfers Balance at
End ^>f Year
Line
No.(d)(f)(e)
1
25,703
29,759,682 3
428.493.7994,613,599
54.613,599 58,259,184
6
7
81,730,471
153,408,729 9587,492
10682,889,15012,546,647
11
162,544,079 1210,791,836
1370.701,789157,384
1417,503,886535,197
13,930,061 15
161.102.708.16524,618,556
17
18
19
20
21
22
23
24
25
26
31,223,914 27
175.996,371 28221,i;
29269,959,842102,655
30211,679,356621,974
58,474,318 31131,843
3222,796,263114,581
3310,880,502
34
781,010,566 351,192,173
36
2,690,006 37
142,711,065 38
3910,452,547
40218,960.89220,794,299
66,531,876 41
91,098,988 42100,000
436,010,475
44
45538,455,84920,894,299
2,422,174,580 4646,705,028
FERC FORM NO.1 (REV.12-05)Page 205
Year/Period of Report
End of 2015/Q4
Date of Report
(Mo,Da,Yr)
04/15/2016
Name of Respondent
Idaho Power Company
This Report Is:
(1)mAn Original
(2)jA Resubmission
ELECTRIC PLANT IN SERVICE (Account 101,102,103 and 106)(Continued)
Balance
Beginning of Year
AdditionsLineAccount
No.(b)(c)(a)
47 3.TRANSMISSION PLANT
36,146,124 232,95548(350)Land and Land Rights
5,128,19472,737,99149(352)Structures and Improvements
11,017,730399,787,96850(353)Station Equipment
16,612,039168,186,85251(354)Towers and Fixtures
16,669,245142,597,65552(355)Poles and Fixtures
16,587,047196,360,60053(356)Overhead Conductors and Devices
54 (357)Underground Conduit
55 (358)Underground Conductors and Devices
390,26656(359)Roads and Trails
57 (359.1)Asset Retirement Costs for Transmission Plant
66,247,2101,016,207,45658TOTALTransmissionPlant(Enter Total of lines 48 thru 57)
59 4.DISTRIBUTION PLANT
125,3935,175,13160(360)Land and Land Rights
33,716,699 493,83761(361)Structures and Improvements
16,141,880202,030,20062(362)Station Equipment
63 (363)Storage Battery Equipment
8,202,243241,088,37964(364)Poles,Towers,and Fixtures
3,488,928128,008,02465(365)Overhead Conductors and Devices
1,240,18147,294,32666(366)Underground Conduit
218,656,607 13,091,09867(367)Underground Conductors and Devices
28,686,286494,614,87668(368)Line Transformers
1,245,76057,867,38569(369)Services
80,528,574 4,777,99970(370)Meters
111,7922,914,52571(371)Installations on Customer Premises
72 (372)Leased Property on Customer Premises
73 (373)Street Lighting and Signal Systems 4,504,500 89,586
-369,521533,71274(374)Asset Retirement Costs for Distribution Plant
77,325,46275TOTALDistributionPlant(Enter Total of lines 60 thru 74)1,516,932,938
76 5.REGIONAL TRANSMISSION AND MARKET OPERATION PLANT
77 (380)Land and Land Rights
78 (381)Structures and Improvements
79 (382)Computer Hardware
80 (383)Computer Software
81 (384)Communication Equipment
82 (385)Miscellaneous Regional Transmission and Market Operation Plant
83 (386)Asset Retirement Costs for Regional Transmission and Market Oper
84 TOTAL Transmission and Market Operation Plant (Total lines 77 thru 83)
85 6.GENERAL PLANT
16,578,58286(389)Land and Land Rights
107,038,338 6,306,65587(390)Structures and Improvements
4,656,97745,902,76288(391)Office Furniture and Equipment
74,214,375 8.247.219
359,137
89 (392)Transportation Equipment
1,936,39790(393)Stores Equipment
602,3857,574,78091(394)Tools.Shop and Garage Equipment
12,652,489 396,75492(395)Laboratory Equipment
13,938,120 1,923,22093(396)Power Operated Equipment
3,488,27853,788,30494(397)Communication Equipment
511,0225,577,12595(398)Miscellaneous Equipment
339,201,272 26,491,64796SUBTOTAL(Enter Total of lines 86 thru 95)
97 (399)Other Tangible Property
98 (399.1 )Asset Retirement Costs for General Plant
99 TOTAL General Plant (Enter Total of lines 96,97 and 98)339,201,272 26,491,647
325,946,0465,248,212,330100TOTAL(Accounts 101 and 106)
101 (102)Electric Plant Purchased (See Instr.8)
102 (Less)(102)Electric Plant Sold (See Instr.8)
103 (103)Experimental Plant Unclassified
5,248,212,330 325.946.046104TOTALElectricPlantinService(Enter Total of lines 100 thru 103)
Page 206FERCFORMNO.1 (REV.12-05)
bate of Report
(Mo,Da,Yr)
04/15/2016
Year/Period of Report
End of 2015/Q4
Name of Respondent
Idaho Power Company
This Report Is:
(1)|x|An Original
(2)|j A Resubmission
ELECTRIC PLANT IN SERVICE (Account 101 ,102.103 and 106)(Continued)
LineTransfersBalanceat
End ^if Year
Retirements Adjustments
No.m(d)(e)
47
36,379,079 48
4977,780,24685,939
407,602,629 503,203,069
184,628,055 51170,836
52158,380,194886,706
53211,904,6571,042,990
54
55
56390,266
57
1,077,065,126 585,389,540
59
605,300,524
34,175,353 6135,183
216,853,729 621,318.351
63
64246,985,6662,304,956
129,331,468 652,165,484
6648,322,609211,898
230,143,168 671,604,537
515,652,279 687.648.883
6958,770,764342,381
85,247,458 7059,115
2,954,458 7171,859
72
4,543,249 7350,837
74164,191
1,578,444,916 7515,813,484
76
77
78
79
80
81
82
83
84
85
16,578,582 86
110,924,656 872,420,337
8846,692,0833,867,656
8975,878,8636,582,731
2,255,403 9040,131
8,021,556 91155,609
12,703,819 92345,424
15,082,035 93779,305
55,415,200 941,861,382
5,967,704 95120,443
96349,519,90116,173,018
97
98
349,519,901 9916,173,018
5,485,463,707 10088,694,669
101
102
103
1045,485,463,70788,694,669
FERC FORM NO.1 (REV.12-05)Page 207
Year/Period of Report
2015/Q4
Date of Report
(Mo,Da,Yr)
04/15/2016
This Report Is:
(1)[x]An Original
(2)A Resubmission
ELECTRIC PLANT HELD FOR FUTURE USE (Account 105)
Name of Respondent
Idaho Power Company End of
1 .Report separately each property held for future use at end of the year having an original cost of $250,000 or more.Group other items of property held
for future use.
2.For property having an original cost of $250,000 or more previously used in utility operations,now held for future use,give in column (a),in addition to
other required information,the date that utility use of such property was discontinued,and the date the original cost was transferred to Account 105.
Balance at
End of Year
Date Originally Included!Date Expected to be used
in This Account in Utility Service
Description and LocationLineOfPropertyNo.(d)(b)(c)
1 Land and Rights:
655,55012/31/822BoiseOperationsCenter
109,9613Production
423,0894TransmissionStations
195,4895TransmissionLines
1,077,2176DistributionStations
465,66212/30/027BeaconLightSubstation
109,4532/29/088HomedaleSubstation
2,630,4121/31/089NorthRiverOperationsCenter
308,0663/31/0910Line#854 500 Kv
11
12
13
14 Column B if no date listed it is various
15
16
17
18
19
20
21 Other Property:
72,78512/31/8222BoiseOperationsCenter
199,06923TransmissionStations
69,94124DistributionStations
217,7972/29/0825HomedaleSubstation
555,94012/30/0226BeaconLightSubstation
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46
7,090,43147Total
FERC FORM NO.1 (ED.12-96)Page 214
Year/Period of Report
End of 2015/Q4
Date of Report
{Mo,Da,Yr)
04/15/2016
Name of Respondent
Idaho Power Company
This Report Is:
(1)[X|An Original
(2)|~|J 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 (1 07)
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 $1,000,000,whichever is less)may be grouped.
Construclion work in progress -
Electric (Account 1 07)
Description of ProjectLine
No.(b)(a)
86,963,920ROLLUPRELICCOSTBROWNLEE1
59,261,154ROLLUPRELICCOSTHELLSCANYON2
37,547,331BRIDGER2011C039JB4SCRSYSD3
29,199,462GATEWAYWEST500KVLINE4
27,524,739ROLLUPRELICCOSTOXBOW5
22,519,224HELLSCANYONRELICENSINGOUTSI6
11,567,064BOARDMAN-HEMINGWAY 500 KV LI7
9,853,267B2HPERMITTING11/1/2011 &FOR8
9,811,096BROWNLEETURBINEREFURBISHMENT9
6,896,703LOWERSALMONRUNNERREPLACEMEN10
6,339,392BROWNLEEUNIT1TURBINEREFURB11
3,816,660HCCWATERSHEDENHANCEMENTPROG12
3,285,241LEGALDEPT.LABOR FOR RELICENS13
3,283,000BRIDGERUNDISTRIBUTEDWORKORD14
2,654,393REL-HCC OREGON REAUTHORIZATION15
2,479,755B2HTLINECONSTRUCTIONCOSTS16
2,362,687MPSNT501-REPLACE FAILED 50017
2,136,864REWINDGENERATORSTATOR#418
1,982,499WQHCC401CERTIFICATIONOPSAN19
1,643,935WDRI-KCHM NEW 138KV20
1,566,482WQHCC401APPLICATION,REVISIO21
1,410,685FALLCHINOOKPROGRAM-REDD SU22
1,405,061HBND-041.ALT LINE ROUTE TO GAR23
1,380,185RELICENSING:BAKER COUNTY SETT24
1,353,368T2167.1 MILES OF 69KV LINE FR25
1,315,646BRIDGER2015C070U4REPLACEFl26
1,260,702REC-BAKER COUNTY SETTLEMENT27
1,233,651HEMINGWAY500KVINANDOUTRE28
1,203,508T4331001-UPGRADE T433 TO 230KV29
1,112,931314DESIGNTEAMS-CAPITAL -C30
1,109,406BULLTROUTPROGRAM-ADMINISTR31
1,079,859METEOROLOGYMODELFOROPERATIO32
1,004,404BROWNLEEUNIT3TURBINEREFURB33
OTHER MINOR PROJECTS UNDER $1,000,000 49,367,09834
35
36
37
38
39
40
41
42
TOTAL43 396,931,372
FERC FORM NO.1 (ED.12-87)Page 216
Date of Report
(Mo,Da,Yr)
04/15/2016
Year/Period of Report
End of 2015/Q4
This Report Is:
(1)[X|An Original
(2)||A Resubmission
ACCUMULATED PROVISION FOR DEPRECIATION OF ELECTRIC UTILITY PLANT (Account 108)
Name of Respondent
Idaho Power Company
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 1 1 ,column (c),and that reported for
electric plant in service,pages 204-207,column 9d),excluding retirements of non-depreciable property.
3.The provisions of Account 108 in the Uniform System of accounts require that retirements of depreciable plant be recorded when
such plant is removed from service.If the respondent has a significant amount of plant retired at year end which has not been recorded
and/or classified to the various reserve functional classifications,make preliminary closing entries to tentatively functionalize the book
cost of the plant retired.In addition,include all costs included in retirement work in progress at year end in the appropriate functional
classifications.
4.Show separately interest credits under a sinking fund or similar method of depreciation accounting.
Section A.Balances and Changes During Year
tlectric Plant held
for Future Use
tlectric PlantLeasedtoOthers(c+§+e)tlectric plant inServiceItemLine
No,(d)(e)(c)(a)(b)
1,997,908,4181,997,908,4181BalanceBeginningofYear
2 Depreciation Provisions for Year,Charged to
130,382,128 130,382,1283(403)Depreciation Expense
549,017549,0174(403.1)Depreciation Expense for Asset
Retirement Costs
5 (413)Exp.of Elec.Pit.Leas,to Others
3,896,0823,896,0826TransportationExpenses-Clearing
7 Other Clearing Accounts
8 Other Accounts (Specify,details in footnote):
102,213102,2139FuelStock
134,929,440 134,929,44010TOTALDeprec.Prov for Year (Enter Total of
lines 3 thru 9)
1 1 Net Charges for Plant Retired:
84,081 ,07084,081,07012BookCostofPlantRetired
13,728,96613,728,96613CostofRemoval
26,189,69926,189,69914Salvage(Credit)
71,620,33715TOTALNetChrgs.for Plant Ret.(Enter Total
of lines 12 thru 14)
71,620,337
10,566,75516OtherDebitorCr.Items (Describe,details in
footnote):
10,566,755
17
18 Book Cost or Asset Retirement Costs Retired
2,071,784,27619BalanceEndofYear(Enter Totals of lines 1,
10,15,16,and 18)
2,071,784,276
Section B.Balances at End of Year According to Functional Classification
540,252,070540,252,07020SteamProduction
21 Nuclear Production
402,629,313402,629,31322HydraulicProduction-Conventional
23 Hydraulic Production-Pumped Storage
90,194,94090,194,94024OtherProduction
337,675,154337,675,15425Transmission
590,665,462590,665,46226Distribution
27 Regional Transmission and Market Operation
110,367,337110,367,33728General
2,071,784,276 2,071,784,27629TOTAL(Enter Total of lines 20 thru 28)
FERC FORM NO.1 (REV.12-05)Page 219
Date of Report Year/Period of Report
(Mo,Da,Yr)
04/15/2016
Name of Respondent This Report is:
(1)X An Original
(2)_A Resubmission 2015/Q4IdahoPowerCompany
FOOTNOTE DATA
Schedule Page:219 Line No.:16 Column:c
ciAC,Reserve Adjustments and Asset Retirement Obligation activity.
FERC FORM NO.1 (ED.12-87)Page 450.1
Year/Period of Report
End of 2015/Q4
Date of Report
(Mo.Da,Yr)
04/15/2016
Name of Respondent
Idaho Power Company
This Report Is:
(1)[x]An Original
(2)Q A Resubmission
INVESTMENTS IN SUBSIDIARY COMPANIES (Account 123,1)
1.Report below investments in Accounts 123.1,investments in Subsidiary Companies.
2.Provide a subheading for each company and List there under the information called for below.Sub -TOTAL by company and give a TOTAL in
columns (e),(f),(g)and (h)
(a)Investment in Securities -List and describe each security owned.For bonds give also principal amount,date of issue,maturity and interest rate.
(b)Investment Advances -Report separately the amounts of loans or investment advances which are subject to repayment,but which are not subject to
current settlement.With respect to each advance show whether the advance is a note or open account.List each note giving date of issuance,maturity
date,and specifying whether note is a renewal.
3.Report separately the equity in undistributed subsidiary earnings since acquisition.The TOTAL in column (e)should equal the amount entered for
Account 418.1.
Amount of Investment at
Beginning of Year
Description of InvestmentLine Date Of
MaturityDateAcquired
No.(d)(b)(a)
1 Idaho Energy Resources Company
50002/01/742CommonStock
2,462,5943Capitalcontributions
81,014,3664Equityinearnings
5
83,477,4606SubtotalIdahoEnergyResourcesCompany
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 iTotal Cost of Account 123.1 $TOTAL 83,477,4602,463,094
FERC FORM NO.1 (ED.12-89)Page 224
Year/Period of Report
End of 2015/Q4
Date of Report
(Mo.Da,Yr)
04/15/2016
Name of Respondent
Idaho Power Company
This Report Is:
(1)fx]An Original
(2)A Resubmission
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 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
Gain or Loss from Investment
Disposed of
Equity in Subsidiary
Earninas of Year
Revenues for Year Amount of Investment at
End Year
Line
fej No.(f)
1
2500
32,462,594
481,674,3076,000,0006,659,942
5
684,137,4016,659,942 6,000,000
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
84,137,4016,000,0006,659,942 42
FERC FORM NO.1 (ED.12-89)Page 225
?ate of Report
(Mo,Da,Yr)
04/15/2016
Year/Period of Report
End of 2015/Q4
Name of Respondent
Idaho Power Company
This Report Is:
(1)[X]An Original
(2)||A Resubmission
MATERIALS AND SUPPLIES
1 .For Account 1 54,report the amount of plant materials and operating supplies under the primary functional classifications as indicated in column (a);
estimates of amounts by function are acceptable.In column (d),designate the department or departments which use the class of material.
2.Give an explanation of important inventory adjustments during the year (in a footnote)showing general classes of material and supplies and the
various accounts (operating expenses,clearing accounts,plant,etc.)affected debited or credited.Show separately debit or credits to stores expense
clearing,if applicable.
Balance
End of Year
Department or
Departments which
Use Material
Line Account Balance
Beginning of YearNo.
(c)(d)(a)(b)
Fuel Stock (Account 151)55,170,482 61,818,257 Electric1
2 Fuel Stock Expenses Undistributed (Account 152)599 Electric
3 Residuals and Extracted Products (Account 153)
4 Plant Materials and Operating Supplies (Account 154)
5 Assigned to -Construction (Estimated)
6 Assigned to -Operations and Maintenance
7 Production Plant (Estimated)17,010,420 17,384,869
8 Transmission Plant (Estimated)11,212,105 11,191,094
9 Distribution Plant (Estimated)20,564,459 21,957,543
10 Regional Transmission and Market Operation Plant
(Estimated)
1 1 Assigned to -Other (provide details in footnote)1,518,495 1,911,722
12 TOTAL Account 154 (EnterTotal of lines 5 thru 11)50,305,479 52,445,228 Electric
1 3 Merchandise (Account 1 55)
14 Other Materials and Supplies (Account 156)
15 Nuclear Materials Held for Sale (Account 157)(Not
applic to Gas Util)
Electric16StoresExpenseUndistributed(Account 163)5,098,760 4,478,320
17
18
19
110,575,320 118,741,80520TOTALMaterialsandSupplies(Per Balance Sheet)
FERC FORM NO.1 (REV.12-05)Page 227
Year/Period of Report
End of 2015/Q4
Date of Report
(Mo,Da,Yr)
04/15/2016
Name of Respondent
Idaho Power Company
This Report Is:
(1)[Xj An Original
(2)A Resubmission
Transmission Service and Generation Interconnection Study Costs
1 .Report the particulars (details)called for concerning the costs incurred and the reimbursements received for performing transmission service and
generator interconnection studies.
2.List each study separately.
3.In column (a)provide the name of the study.
4.In column (b)report the cost incurred to perform the study at the end of period.
5.In column (c)report the account charged with the cost of the study.
6.In column (d)report the amounts received for reimbursement of the study costs at end of period.
7.In column (e)report the account credited with the reimbursement received for performing the study.
Reimbursements
Received During
the Period
Line
Account Credited
With Reimbursement
Costs Incurred During
PeriodNo.Account ChargedDescription
(d)(e)(c)(a)(b)
1 Transmission Studies
(7,270)18662312,245 1866232BPAPNETWORKSIS78318516
8,169 1866233BPAPTRANSSIS80289606186623
7,633 1866234PACPTPSIS803815172,367 186623
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21 Generation Studies
(1,624)186623.00000LAGOONSOLAR#490 1,624 186623.0000022
(11,430)186623.000003,57123LITTLEVALLEYSOLAR491 186623.00000
(5,095)186623.00000ACADIASOLAR#474 5,095 186623.0000024
(15,932)186623.00000ADAPV2-A #482 15,932 186623.0000025
(14,796)186623.00000ADAPV2-B #483 14,796 186623.0000026
(26,415)186623.00000AMERICANFALLSSOLAR#431 35,94127 186623.00000
(13,735)186623.00000AMERICANFALLSSOLARII#433 20,518 186623.0000028
(1,000)186623.00000BAKERSOLAR1#507 1,046 186623.0000029
(1,000)186623.00000BAKERSOLAR2#508 1,047 186623.0000030
85,666 186623.00000BENSONCREEKWINDFARMGl40131186623.00000
(5,024)186623.000005,024 186623.0000032BIGDOGSOLAR#470
(65,289)186623.0000034,164 186623.00000BOISECITYSOLAR#43233
(914)186623.00000BRUSHSOLAR#500 91434 186623.00000
(3,872)186623.00000BUTLERSOLAR#471 3,872 186623.0000035
709)186623.00000(CHERRY LANE SOLAR #462 10MW 70936 186623.00000
(8,086)186623.000009,001CLARK2SOLAR-20MW #43837 186623.00000
(7,993)186623.00000CLARK4SOLAR-20MW #440 8,908 186623.0000038
(4,620)186623.00000CLARKSOLAR1#437 7MW 13,763 186623.0000039
(437)186623.00000CLARKSOLAR3#439 30MW 10,267 186623.0000040
FERC FORM NO.1/1-F/3-Q (NEW.03-07)Page 231
Date of Report
(Mo,Da,Yr)
04/15/2016
Year/Period of Report
End of 2015/Q4
Name of Respondent
Idaho Power Company
This Report Is:
(1)Rn An Original
(2)q A Resubmission
Transmission Service and Generation Interconnection Study Costs (continued)
Reimbursements
Received During
the Period "
Line Account Credited
With Reimbursement
Costs Incurred During
PeriodNo.Account ChargedDescription
(e)(c)(d)(b)(a)
1 Transmission Studies
2
3
4
5
6
7
8
g
10
11
12
13
14
15
16
17
18
19
20
21 Generation Studies
(2,184)186623.000002,184 186623.00000COOPERSOLAR#47822
(1,000)186623.000001,102 186623.00000DAVISSOLAR#50623
(207)186623.0000020724DAVISSOLAR#498 186623.00000
(1,630)186623.000001,630 186623.00000DURKEESOLAR#49625
(43,964)186623.000008,020 186623.00000EVERGREENSOLAR#47526
(12,933)186623.000005,601FAIRWAYSOLAR#49327 186623.00000
(1,568)186623.000001,568 186623.00000FALLSCITYSOLAR#461 10MW28
(2,849)186623.000002,849 186623.00000FOURTHAVE.SOLAR #48129
1,578 186623.00000GRANDVIEWPVSOLARFIVEGl41130186623.00000
186623.0000020,3511,753 186623.00000GROVESOLARCENTER-Gl 41431
(1,000)186623.00000954HUNTINGTONSOLAR1#50532 186623.00000
10,942 186623.000004,177 186623.00000HYLINESOLARCENTER-Gl 41933
(1,025)186623.000001,025 186623.00000IPCLTRANSSIS8091471034
(11,000)186623.000009,446 186623.00000JACKPOTSOLARNORTH#50235
(11,000)186623.000009,631JACKPOTSOLARSOUTH#50336 186623.00000
(5,830)186623.000005,830 186623.00000JAMIESONSOLAR#47237
(44,324)186623.000004,822 186623.00000JOHNDAYSOLAR#48038
(2,794)186623.000002,794 186623.00000KINGMANSOLAR48939
(324)186623.00000324186623.00000LUTHERSOLAR#49240
Page 231.1FERCFORMNO.1/1-F/3-Q (NEW.03-07)
Year/Period of Report
End of 2015/Q4
This Report Is:
(1)[)tj An Original
(2)q A Resubmission
Transmission Service and Generation Interconnection Study Costs (continued)
Date of Report
(Mo,Da,Yr)
04/15/2016
Name of Respondent
Idaho Power Company
Reimbursements
Received During
the Period *
Line Account Credited
With Reimbursement
Costs Incurred During
PeriodNo.Account ChargedDescription
(e)(c)(d)(a)(b)
1 Transmission Studies
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21 Generation Studies
(32,689)186623.00000MAHLHUERRIVERSOLAR#477 5,776 186623.0000022
(11,518)186623.000001,958 186623.00000MERIDIAN/NORTH RD PV1-A23
(1,581)186623.000001,581MERIDIAN/NORTH RD PV1-B #48524 186623.00000
(42,981)186623.000006,610 186623.00000MOORESHOLLOW#47625
(25,075)186623.00000MORTHGOODINGMAINHYDRO#494 3,494 186623.0000026
(47,195)186623.00000MOUTAINHOMESOLAR-20MW #435 29,563 186623.0000027
211)186623.00000(1,211MT.HOME SOLAR #44428 186623.00000
(37,772)186623.0000042,708 186623.00000MURPHYFLATPOWERNORTH#42629
(2,540)186623.00000MURPHYFLATPOWERSOUTH#42730 186623.00000
(44,281)186623.00000OLDFERRYROADSOLAR#473 8,743 186623.0000031
(1,000)186623.000001,013 186623.00000ONTARIOSOLAR#50432
8,737 186623.000001,681OPENRANGESOLARCENTER-Gl 41333 186623.00000
(10,000)186623.00000ORCHARDRANCH2#48834 186623.00000
(52,867)186623.00000ORCHARDRANCHSOLAR-20MW #441 37,093 186623.0000035
(5,750)186623.000005,750 186623.00000OWYHEESOLAR#47936
(33,041)186623.0000015,230 186623.00000POCATELLOSOLAR-20MW #43637
16,063 186623.000009,127 186623.00000RAILROADSOLARCENTER-Gl 42338
13,759 186623.000005,281RAILROADSOLARCENTER-Gl 42439 186623.00000
(534)186623.00000SALMONRIVERCANAL550KW40186623.00000
FERC FORM NO.1/1-F/3-Q (NEW.03-07)Page 231.2
Year/Period of Report
End of 2015/Q4
Name of Respondent
Idaho Power Company
This Report Is:
(1)[X]An Original
Date of Report
(Mo.Da,Yr)
04/15/2016(2)||A Resubmission
Transmission Service and Generation Interconnection Study Costs (continued)
Reimbursements
Received During
the Period
Line Account Credited
With Reimbursement
Costs Incurred During
PeriodNo.Account ChargedDescription
(e)(b)(c)(d)(a)
1 Transmission Studies
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21 Generation Studies
(3,352)186623.00000SIDDOWAYSOLAR#486 3,352 186623.0000022
(1,985)186623.000002,985 186623.0000023SIMCOSOLAR#442
(50,000)186623.000007,192 186623.00000SIMCOESOLAR2#48724
(42,822)186623.00000SIMCOESOLARCENTER#428 37,638 186623.0000025
(11,000)186623.00000SOUTHERNIDAHOSOLIDWASTE#501 1,776 186623.0000026
(10,329)186623.00000SUTTONCREEKSOLAR#495 1,457 186623.0000027
599)186623.00000(1,599 186623.0000028TILLISOLAR#443
12,056 186623.000001,711VALEAIRSOLARCENTER-Gl 41229 186623.00000
(2,697)186623.00000VALLEYLANESOLARPV12,697 186623.0000030
(1,000)186623.00000WEGNERSOLAR#499 32931 186623.00000
(2,463)186623.000003,463 186623.00000WRIGHTPLACESOLAR#44532
(1,694)186623.000001,694 186623.00000ZEHRSOLAR#49733
34
35
36
37
38
39
40
FERC FORM NO.1/1-F/3-Q (NEW.03-07)Page 231.3
Date of Report Year/Period of Report
(Mo,Da,Yr)
04/15/2016
This Report is:Name of Respondent
(1)X An Original
(2)_A Resubmission 2015/Q4IdahoPowerCompany
FOOTNOTE DATA
Schedule Page:231 Line No.:22 Column:d
Amounts represent both reimbursements received and refunds back to the counterparties.
Refunds are initiated when the final expenses exceed the intial deposit received.
IFERC FORM NO.1 (ED.12-87)Page 450.1
Date of Report
(Mo.Da,Yr)
04/15/2016
Name of Respondent
Idaho Power Company
Year/Period of Report
End of 2015/04
This Report Is:
(1)[X]An Original
(2)||A Resubmission
OTHER REGULATORY ASSETS (Account 182.3)
1 .Report below the particulars (details)called for concerning other regulatory assets,including rate order docket number,if applicable.
2.Minor items (5%of the Balance in Account 182.3 at end of period,or amounts less than $100,000 which ever is less),may be grouped
by classes.
3.For Regulatory Assets being amortized,show period of amortization.
Balance at Beginning
of Current
Quarter/Year
CREDITSLineDescriptionandPurposeof
Other Regulatory Assets
Debits Balance at end of
Current Quarter/YearWrittenoffDuring
the Period Amount
No.Written offDuring the
Quarter/YearAccount
Charged(a)(e)(f)(b)(c)
3,216,06017,033,635 363,196 Various 14,180,7711AssetRetirementObligations(182341)
2 IPUC Order#29414-OPUC Order#04-585
3
18,595,015 244 17,583,1193,960,7044ASC815MarktoMarket(182330 &182333)4,972,600
5 IPUC Order#28661
6
802,188,345 87,385,943 382 14,546,806 875,027,4827FAS109Unfunded(182322)
Accum Deferred Income Noncurrent8
g
55,501,66645,412,570 59,429,323 401 49,340,227PCADeferralIdaho-IPUC Order#3330610
(Amort period 06/16 thru 05/17)(182323)11
12
12,535,848 34,627,781 401 47,160,880PCAPriorYearDeferralIdaho-IPUC Order #33049 2,74913
(Amort period 06/15 thru 05/16)(182324)14
15
31,393,901 1823 20,266,96416,811,911 27,938,848FixedCostAdjustment(FCA)(182302)16
IPUC Order #33302 (Amort period 06/16 thru 05/17)17
18
6,925,678 25,831,710 400 24,932,619 7,824,769PriorYearFCAIPUCOrder#33047 (182309)19
(Amort period 6/15 thru 5/16)20
21
903,788 117 2283 2,428,321 -1,524,41622AOCIImpactofUnfundedPostRetirementLiability
IPUC Order #30256 (182306)23
24
611,255 4073 94,9602,750,366 3,266,661OregonPensionExpenseCapitalized(182339)25
OPUC Order #10-064 (Amort period thru 2052)26
27
20,077,507 39,659,896 Various 38,532,812 21,204,591DeferredPensionExpenseNetofContributions28
IPUC Order #30333 (182321)29
30
263,644,763 15,358,1124,999,578 2283 253,286,229AOCIImpactofUnfundedPensionLiability31
IPUC Order#30256 (182320)32
33
(1,055,813)19,463,835 401 20,525,175PCAUnbilledForecast(182325)-2,117,15334
35
2,424,6165,534,507 121,552 401 3,231,44336PCAMOregon2008(182346)
37 OPUC Order#08-238 &#13439 (Amort 1/14 -6/17)
38
(568,429)237,936PCAMInterestReserve2008(182329)-330,49339
40 (Amort 1/14 -6/17)
41
33,645,247 401 35,104,595PCASBAUnbilledAdj(182326)-1,459,34842
43
Page 232FERCFORMNO.1/3-Q (REV.02-04)
This Report Is:
(1)pq An Original
(2)||A Resubmission
OTHER REGULATORY ASSETS (Account 182.3)
1 .Report below the particulars (details)called for concerning other regulatory assets,including rate order docket number,if applicable.
2.Minor items (5%of the Balance in Account 182.3 at end of period,or amounts less than $100,000 which ever is less),may be grouped
by classes.
3.For Regulatory Assets being amortized,show period of amortization.
Name of Respondent
Idaho Power Company
Date of Report
(Mo,Da,Yr)
04/15/2016
Year/Period of Report
End of 2015/Q4
Balance at Beginning
of Current
CREDITSLineDescriptionandPurposeof
Other Regulatory Assets
Debits Balance at end of
Current Quarter/YearWrittenoffDuring
the Period Amount
No.Written offDuring the
Quarter/Year AccountQuarter/Year
Charged (e)(f)(a)(b)(c)
25,631,17226,687,947 400 1,056,7751FCACalenderMoAdjIPUCOrder(182306)
2
1,217,507 5,674,701 Various 5,478,565 1,413,6433IdahoBoardmanDecomissioning(182493)
4 IPUC Order#32549 &#32457
5
40,816,708 37,690,655 401 17,188,437 61,318,9266IdahoPensionCashIPUCOrder#32248 (182327)
7 (Amort period beginning 06/11 thrti unknown)
8
1,820,146158,302)1,812,976 401 -165,4722008PCAMUnbilledAmort(182356)9
(Amort period 1/14 thru 6/17)10
11
305,233 43,605 261,628LidarSurveysIPUCOrder#32426 (182361)40212
(Amort period 01/12 thru 12/21)13
14
43,441,968(2,380,650)44,612,555 400,401 -1,210,063PCAUnbilledAmortization(182316)15
(Amort period 06/15 thru 05/16)16
17
43,557261,340 217,783IdahoBoardmanAROIPUCOrder#29414 (182393)4110,403118
(Amort period thru 2020)19
20
941,957 75,471 1,017,428LangleyRevenueAccrualIPUCOrder#12-226 (182398)21
22
133,395800,373 401 666,978OtherRA-PS&I Shoshone Order #29904 (182368)23
24
1,083,701 1,083,701RA-OATT Deferral-IPUC Order#33313 (182350)25
26
272,714 272,714RA-OR CUB Fund Amort 15-399 (182386)27
(Amort period 1/16 thru 5/17)28
29
11,632,907 11,632,907RA-SIEMENS LTP DEF RB 33420 (182410)30
31 (Amort period 1/16 thru 12/42)
32
17,358,63633RA-SIEMENS LTP RB 33420 (18241 1)17,358,636
(Amort period 1/16 thru 12/42)34
35
446,876 446,876RA-SIEMENS LTP DEF RB 15-387 (182412)36
(Amort period 1/16 thru 12/42)37
38
786,315 786,315RA-SIEMENS LTP RB 15-387 (182413)39
(Amort period 1/16 thru 12/42)40
41
74,88774,887BennettMtnMaintenanceIPUCORder#32426 40242
(Amort period 01/12 thru 12/15)(182379)43
Page 232.1FERCFORMNO.1/3-Q (REV.02-04)
Name of Respondent
Idaho Power Company
Date of Report
(Mo,Da,Yr)
04/15/2016
Year/Period of Report
End of 2015/Q4
This Report Is:
(1)[x]An Original
(2)||A Resubmission
OTHER REGULATORY ASSETS (Account 182.3)
1 .Report below the particulars (details)called for concerning other regulatory assets,including rate order docket number,if applicable.
2.Minor items (5%of the Balance in Account 182.3 at end of period,or amounts less than $100,000 which ever is less),may be grouped
by classes.
3.For Regulatory Assets being amortized,show period of amortization.
Balance at Beginning
ofCurrent
CREDITS Balance at end of
Current Quarter/Year
Line DebitsDescriptionandPurposeof
Other Regulatory Assets Written offDuring
the Period Amount
No.Written offDuring the
Quarter/Year Account
Charged
Quarter/Year
(c)(e)(f)(a)(b)
286,732286,732OATTRevenueDeferredReserve(182336)1
2 IPUC Order #30940 (Amortperiod 6/12 thru 5/15)
3
4,482,485 Various 4,482,4854OregonDSMRider-(182405)
5 Advice #05-03
6
312,390 Various 529,414302,932 85,9087MinorItems(36)
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:1,355,572,1281,237,823,724 510,096,987 392,348,583
Page 232.2FERCFORMNO.1/3-Q (REV.02-04)
Year/Period of Report
End of 2015/Q4
Name of Respondent
Idaho Power Company
This Report Is:
(1)[x]An Original
(2)j |A Resubmission
MISCELLANEOUS DEFFERED DEBITS (Account 186)
Date of Report
(Mo,Da,Yr)
04/15/2016
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 $100,000,whichever is less)may be grouped by
classes.
DebitsDescriptionofMiscellaneous
Deferred Debits
CREDITS Balance at
End of Year
Balance at
Beginning of Year
Line
Account
ChargedNo.Amount
(b)(c)(f)(a)(e)
1 Prepaid Credit Facility(186025)
2 (Amort period 1 1/16 thru 1 1/20)
669,396 1.716,012 165,431 1 ,044,4821,340.926
3
4 Prepaid Service Contract 753.8441.659.405 556.171 Various 1.461,732
5 Long Term Portion (186052)
6
7 Long Term (186121)1.130.749 2282,401 61 .090 1,069,659
8 Workers Compensation
9
10 Prepaid ROW (186160)425,944 401 42,970 382,974
1 1 Rents/Easements Long Term
12
13 Long-Term Portfolio (186255)1,791,148 5,070,889 165,402 5,768,411 1,093.626
14
15 OATT Reserve (186350)1,083,701 -1,083,701400
16
1,170,13217AdvancePrepaid(186709)1,241,610 151 71,478
18 Coal Royalties
19
20 Stable Value Life (186719)30,004,99230,004,992
21
22 Security Plan (186720)14.769.99320.059.079 324.769 143.4262 5.613.855
23 Net Insurance Asset
24
147,948 133,39525AmericanFallsBondRef(1 86722)
26 (Amort Period 04/00 thru 02/25)
401 14,553
27
Retiree Medical-COLI (186726)3,834,224 1.171,972 3,791,248281.128,996 143,4262
29
30 American Falls Water Rights
31 (amort 01/06 -02/25)(186727)
10,506,922 401 1,042,009 9,464,913
32
33 Shelf Registration (186732)160,469 2,416,222 181 2,576,691
34
35 Milner Bond Guarantee (186734)3,190,909 253 1,063,636 2,127,273
36 (Amort 02/07 -2/17)
37
38 American Falls -Bond Refinance 487,991 401 47,999 439,992
39 (Amort through 02/25)(186770)
40
41 Power Plant-Bridger (186780)254,793 401 127,396 127,397
42 (Amort thru 06/14 thru 12/16)
43
44 Bridger Coal Study (186781 )3,932,864 107,401 2,527,077 1 ,405,787
45
46 Minor Items (3)4,126 2.777,223 Various 2,776,060 5,289
47 Misc.Work in Progress
Deferred Regulatory Comm.
Expenses (See pages 350 -351)48
49 TOTAL 45,564,713 66,701,295
FERC FORM NO.1 (ED.12-94)Page 233
Name of Respondent
Idaho Power Company
This Report Is:
(1)[X]An Original
(2)||A Resubmission
Date of Report
(Mo,Da,Yr)
04/15/2016
Year/Period of Report
End of 2015/Q4
ACCUMULATED DEFERRED INCOME TAXES (Account 190)
1 .Report the information called for below concerning the respondent's accounting for deferred income taxes,
2.At Other (Specify),include deferrals relating to other income and deductions.
Line Description and Location Balance of Begining
of Year
Balance at End
of YearNo,(a)(b)(c)

1 Electric
2
3
4
5 Other Electric (See footnote)83,181,33897,597,101
6
7 Other (See footnote)169,747,033 163,213,808
8 TOTAL Electric (Enter Total of lines 2 thru 7)267,344,134 246,395,146

9 Gas
10
11
12
13
14
15 Other
16 TOTAL Gas (Enter Total of lines 10 thru 15
17 Other Non Electric See footnote 21,759,450 23,793,249
1 8 TOTAL (Acct 190)(Total of lines 8,1 6 and 17)289,103,584 270,188,395
Notes
Page 234FERCFORMNO.1 (ED.12-88)
Date of Report Year/Period of ReportNameofRespondentThisReportis:
(Mo,Da,Yr)(1)X An Original
(2)_A Resubmission 2015/Q404/15/2016IdahoPowerCompany
FOOTNOTE DATA
Schedule Page:234 Line No.:5 Column:c
Beginning Balance Ending Balance
Prov for Rate Refund-HC Relicensing (AFUDC)
Regulatory Asset-Non Current
28,529,481
18,067,486
17,378,549
10,617,384
5,085,262
3,782,196
3,127,266
2,488,771
2,273,741
1,918,442
1,016,324
919,072
865,690
592,049
568,869
316,603
54,988
31,500
34,282,231
19,624,338
11,343,166
3,814,372
3,813,934
1,235,198
3,008,600
2,273,741
Deferred Idaho ITC
VEBA-Post Retirement Benefits
Incentive Deferral-Profit Sharing-Not in Rates
Stock Based Compensation-FAS 123R
Revenue Sharing
Pension Expense-Oregon
Rate Case Disallowance
Regulatory Liability-Current
Construction Advances
Valmy Union Pacific Contract
Asset Retirement Obligation (ARO)
M &E Reserve
Postretirement Benefits-FAS 112
Bridger Revenue Deferral
Executive Deferred Compensation
Deferred GBC Federal
USBR-American Falls O&M Costs Settlement
Non-VEBA Pension and Benefits
Total Other Electric
1,637,625
1,171,048
486,873
316,603
39,761
31,500
138,920
(36,572)
83,181,338
(36,572)
97,597,101
Schedule Page:234 Line No.:7 Column:c
Ending BalanceBeginningBalance
103,071,920
50,814,726
15,507,051
353,336
99,022,251
51,130,605
13,656,923
(595,971)
163,213,808
Pension-FAS 158
Regulatory Asset-FAS 109
Minimum Pension Liability
Postretirement Plan-FAS 1 58
Total Other 169,747,033
Schedule Page:234 Line No.:17 Column:c
Ending BalanceBeginningBalance
21,402,608
336,836
20,006
23,635,408
153,366
4,475
Senior Management Security Plan
Micron CIAC-Depr Timing Diff
Meridian Gold CIAC-Depr Timing Diff
Total Non Electric 23,793,24921,759,450
FERC FORM NO.1 (ED.12-87)Page 450.1
Year/Period of Report
End of 2015/Q4
Date of Report
(Mo,Da,Yr)
04/15/2016
This Report Is:
(1)[x]An Original
(2)||A Resubmission
Name of Respondent
Idaho Power Company
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.
Call Price at
End of Year
Par or Stated
Value per share
Class and Series of Stock and
Name of Stock Series
Number of shares
Authorized by Charter
Line
No.
(d)(c)(a)(b)
Account 2011
2.5050,000,0002CommonStockallofwhichisheldby
3 IdaCorp,Inc.and not traded
2.5050,000,0004TotalCommonStock
5
6 Account 204 -None
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
FERC FORM NO.1 (ED.12-91)Page 250
Year/Period of Report
End of 2015/Q4
Name of Respondent
Idaho Power Company
This Report Is:
(1)[X]An Original
(2)£"~|A Resubmission
CAPITAL STOCKS (Account 201 and 204){Continued)
Date of Report
(Mo,Da,Yr)
04/15/2016
3.Give particulars (details)concerning shares of any class and series of stock authorized to be issued by a regulatory commission
which have not yet been issued.
4.The identification of each class of preferred stock should show the dividend rate and whether the dividends are cumulative 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.
LineOUTSTANDINGPERBALANCESHEET
(Total amount outstanding without reduction
for amounts held by respondent)
HELD BY RESPONDENT
No.IN SINKING AND OTHER FUNDS
Amount
AS REACQUIRED STOCK (Account 217)
Cost SharesSharesAmountShares
(h)(j)(i)(e)(f)(9)
1
239,150,812 97,877,030
3
439,150,812 97,877,030
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
Page 251FERCFORMNO.1 (ED.12-88)
Year/Period of Report
End of 2015/Q4
This Report Is:
(1)[X|An Original
(2)||A Resubmission
OTHER PAID-IN CAPITAL (Accounts 208-211,inc.)
Date of Report
(Mo,Da,Yr)
04/15/2016
Name of Respondent
Idaho Power Company
Report below the balance at the end of the year and the information specified below for the respective other 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 21 1 )-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.
A7bTntitei
a
Account 208 -Donations received from stockholders -None1
2
3 Account 209 -Reduction in par or stated value of Capital Stock -None
4
5 Account 210 -Gain on reacquired Capital Stock -None
6
7
8 Account 21 1 -Miscellaneous paid-in Capital -None
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
FERC FORM NO.1 (ED.12-87)Page 253
Year/Period of Report
End of 2015/Q4
This Report Is:
(1)fx]An Original
(2)||A Resubmission
CAPITAL STOCK EXPENSE (Accounl 214)
Date of Report
{Mo,Da,Yr)
04/15/2016
Name of Respondent
Idaho Power Company
1 .Report the balance at end of the year of discount on capital stock for each class and series of capital stock.
2.If any change occurred during the year in the balance in respect to any class or series of stock,attach a statement giving particulars
(details)of the change.State the reason for any charge-off of capital stock expense and specify the account charged.
Balance at End of YearClassandSeriesofStockLine
(b)(a)No,
2,096,925CommonStock1
2
3
4
5
6
7
8
9
10 Explanation of Changes during the year:
11
12
13
14
15
16
17
18
19
20
21
2,096,92522TOTAL
FERC FORM NO.1 (ED.12-87)Page 254b
Year/Period of Report
End of 2015/Q4
Name of Respondent
Idaho Power Company
This Report Is:
(1)pq An Original
(2)||A Resubmission
LONG-TERM DEBT (Account 221,222,223 and 224)
Date of Report
(Mo,Da,Yr)
04/15/2016
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.
Principal Amount
Of Debt issued
Total expense,
Premium or Discount
Line Class and Series of Obligation,Coupon Rate
(For new issue,give commission Authorization numbers and dates)No.
(c)(b)(a)
1 Account 221:
2 First Mortgage Bonds:
3 4.50%Series due 2020 130,000,000 1,190,698
234,601 D4
5
728,70165.50%Series due 2033 70,000,000
36,400 D7
8
1,034,90996.15%Series Due 2019 100,000,000
184,949 D10
11
100,000,000 1,159,871123.40%Series due 2020
498,864 D13
14
408,411 D155.30%Series Due 2035 60,000,000
3,802,01916
17
75,000,000 742,017184.00%Series due 2043
193,836 D19
20
1,191,2166.00%Series due 2032 100,000,00021
543,244 D22
23
-585,759245.875%Series due 2034 55,000,000
746,961 D25
26
50,000,000 524,419275.50%Series due 2034
383,322 D28
29
1,284,871304.85%Series Due 2040 100,000,000
169,984 D31
32
33 TOTAL 1 ,877,045,000 31,181,894
FERC FORM NO.1 (ED.12-96)Page 256
Date of Report
{Mo,Da,Yr)
04/15/2016
Year/Period of Report
End of 2015/Q4
This Report Is:
(1)[X]An Original
(2)||A Resubmission
Name of Respondent
Idaho Power Company
LONG-TERM DEBT (Account 221,222,223 and 224)(Continued)
10.Identify separate undisposed amounts applicable to issues which were redeemed in prior years.
1 1 .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.
1 3.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.
Outstanding
(Total amount outstanding without
reduction for amounts held by
p^dent)
LineAMORTIZATIONPERIOD
Interest for Year
Amount
Nominal Date
of Issue
Date of
Maturity No.Date From Date To
0)(d)(e)(f)(g)
1
2
5,850,000 3130,000,00011/20/09 3/1/20 11/20/09 3/1/20
4
5
3,850,000 670,000,00004/01/33 05/01/03 03/31/3305/01/03
7
8
100,000,000 6,150,000 94/1/194/1/09 4/1/19 4/1/09
10
11
3,400,000 12100,000,0005/1/2020 11/1/10 5/1/2011/1/10
13
14
1560,000,000 3,180,00008/26/3508/26/05 08/26/35 08/26/05
16
17
3,000,000 1875,000,0004/1/2043 4/8/2013 4/1/20434/8/2013
19
20
6,000,000 21100,000,00011/15/02 11/15/32 11/15/02 11/15/32
22
23
2455,000,000 3,231,25008/16/3408/16/04 08/16/34 08/16/04
25
26
2,750,000 2750,000,00003/26/04 03/15/3403/26/04 03/15/34
28
29
100,000,000 4,850,000 308/15/402/15/10 8/15/40 2/15/10
31
32
3383,055,8051,747,472,273
FERC FORM NO.1 (ED.12-96)Page 257
This Report Is:
(1)fx]An Original
(2)||A Resubmission
LONG-TERM DEBT (Account 221,222,223 and 224)
Year/Period of Report
End of 2015/Q4
Name of Respondent
Idaho Power Company
Date of Report
(Mo.Da,Yr)
04/15/2016
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 ofthe 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.
Class and Series of Obligation,Coupon Rate
(For new issue,give commission Authorization numbers and dates)
Principal Amount
Of Debt issued
Total expense,
Premium or Discount
Line
No.
(c)(b)(a)
140,000,000 1,495,7996.30%Series due 20371
278,367 D2
3
100,000,000 1,141,48946.25%Series due 2037
267,677 D5
6
4,360,000 188,5457PortofMorrowVariabledue2027
8
49,800,000 1,697,8569HumboldtVariabledue2024
10
116,300,000 3,026,12211SweetwaterVariabledue2026
12
75,000,000 648,267132.50%Series due 2023
371,854 D14
15
120,000,000 1,630,120166.025 %Series Due 2018
17
75,000,000 802,240184.30%Series Due 2042
49,417 D19
20
75,000,000 708,4902.95%Series Due 202221
127,607 D22
23
250,000,000 2,559,510243.68%Series Due 2045
1,715,000 D25
26
1,845,460,000 31,181,89427SubtotalAccount221
28
29 Account 222 -Reaquired Bonds
30
31 Account 223:Advances for Associated Companies
32
TOTAL33 1,877,045,000 31,181,894
FERC FORM NO.1 (ED.12-96)Page 256.1
Year/Period of Report
End of 2015/Q4
This Report Is:
(1)[X]An Original
(2)||A Resubmission
Date of Report
(Mo,Da,Yr)
04/15/2016
Name of Respondent
Idaho Power Company
LONG-TERM DEBT (Account 221,222,223 and 224)(Continued)
10.Identify separate undisposed amounts applicable to issues which were redeemed in prior years.
1 1 .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.
1 5.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.
Outstanding
(Total amount outstanding without
reduction for amounts held by
respondent)
LineAMORTIZATIONPERIOD
Interest for Year
Amount
Date of
Maturity
Nominal Date
of Issue No.Date From Date To
(i)(d)(e)(f)(g)
8,820,000 16/15/37 140,000,0006/22/07 6/15/2037 6/22/07
2
3
6,250,000 410/18/07 10/15/2037 10/18/07 10/15/37 100,000,000
5
6
14,84105/17/00 02/01/27 4,360,000 705/17/00 02/01/27
8
12/01/24 49,800,000 2,564,700 910/22/03 12/01/24 11/01/03
10
116,300,000 6,105,750 1110/3/06 7/15/26 10/3/06 7/15/26
12
1,875,000 134/8/2013 4/1/2023 75,000,0004/8/2013 4/1/2023
14
15
7/15/08 2,249,333 167/10/08 7/15/18 7/10/08
17
3,225,000 184/13/12 4/13/12 4/1/42 75,000,0004/1/42
19
20
4/1/22 75,000,000 2,212,500 214/13/12 4/1/22 4/13/12
22
23
3/1/45 250,000,000 7,477,431 243/6/15 3/1/45 3/6/15
25
26
83,055,805 271,725,460,000
28
29
30
31
32
331,747,472,273 83,055,805
FERC FORM NO.1 (ED.12-96)Page 257.1
Year/Period of Report
End of 2015/Q4
Date of Report
{Wo.Da,Yr)
04/15/2016
Name of Respondent
Idaho Power Company
This Report Is:
(1)[x]An Original
(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.
Total expense,
Premium or Discount
Class and Series of Obligation,Coupon Rate
(For new issue,give commission Authorization numbers and dates)
Principal Amount
Of Debt issued
Line
No.
(c)(b)(a)
1 Account 224:
19,885,0002BondGuarantee-American Falls
11,700,0003NoteGuarantee-Milner Dam
31,585,0004SubtotalAccount224
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
TOTAL 31,181,894331,877,045,000
FERC FORM NO.1 (ED.12-96)Page 256.2
Name of Respondent
Idaho Power Company
Year/Period of Report
End of 2015/Q4
?ate of Report
(Mo,Da,Yr)
04/15/2016
This Report Is:
(1)[X]An Original
(2)n "
LONG-TERM DEBT (Account 221.222,223 and 224)(Continued)
A Resubmission
10.Identify separate undisposed amounts applicable to issues which were redeemed in prior years.
1 1 .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.
"Outstanding
(Total amount outstanding without
reduction for amounts held by
respondent)
LineAMORTIZATIONPERIOD
Interest for Year
Amount
Nominal Date
of Issue
Date of
Maturity
No.Date From Date To
(i)(g)(d)(e)(f)
1
219,885,00004/26/00 2/1/25
32,127,27302/10/92
422,012,273
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
3383,055,8051,747,472,273
FERC FORM NO.1 (ED.12-96)Page 257.2
This Report Is:
(1)pC|An Original
(2)j~|A Resubmission
RECONCILIATION OF REPORTED NET INCOME WITH TAXABLE INCOME FOR FEDERAL INCOME TAXES
Date of Report
(Mo,Da,Yr)
04/15/2016
Year/Period of Report
End of 2015/Q4
Name of Respondent
Idaho Power Company
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 return.State names of group
member,tax assigned to each group member,and basis of allocation,assignment,or sharing of the consolidated tax among the group members.
3.A substitute page,designed to 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.
AmountLineParticulars(Details)
(a)(b)No.
190,983,4831NetIncomefortheYear(Page 1 1 7)
2
3
4 Taxable Income Not Reported on Books
34,015,8465
6
7
8
9 Deductions Recorded on Books Not Deducted for Return
-2,121,81210
11
12
13
14 Income Recorded on Books Not Included in Return
29,665,22515
16
17
18
19 Deductions on Return Not Charged Against Book Income
168,047,55420
21
22
23
24
25
26
25,164,73827FederalTaxNetIncome
28 Show Computation of Tax:
8,807,65829TenativeFederalTax@35%
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
FERC FORM NO.1 (ED.12-96)Page 261
Date of Report Year/Period of Report
(Mo,Da,Yr)
04/15/2016
Name of Respondent This Report is:
(1)X An Original
(2)_A Resubmission 2015/Q4IdahoPowerCompany
FOOTNOTE DATA
Schedule Page:261 Line No.:5 Column:b
4005-AVOIDED COST 7,692,969
1,775,1474003-CONSTRUCTION ADVANCES
(5,362,106)401 3-CIAC -TAXABLE -ACCT 1 07
(109,771)4021 -ENGINEERING FEES -TAXABLE -ACCT 107
451,2084024-RENEWABLE ENERGY CERTIFICATES (REC)SALES
4506-MERIDIAN GOLD CIAC -DEPR TIMING DIFF -NON-OP (39,726)
(469,295)4507-MICRON CIAC -DEPR TIMING DIFF -NON-OP
13,052,859GAINONPACLIKEKINDEXCHANGE
17,024,561GAINONSALEOFSPAREPARTSTOSIEMENS
34,015,846Total
Schedule Page:261 Line No.:10 Column:b
Total Federal and State taxes deducted on books 45,111,128
(2,022,198)5001 -BAD DEBT EXPENSE
500,0005024-NON-DEDUCTIBLE MEALS
1,109,5555504-NON-DEDUCTIBLE POLITICAL EXPENSES
(25,000,000)5022-263A CAPITALIZED OVERHEADS
534,1815070-INCENTIVE DEFERRAL-CRI &RELIABILITY-INCLUDED IN RATES
(209,735)501 0-POSTEMPLOYMENT BENEFITS-SFAS1 12
(21,846,287)5023-PENSION EXPENSE
9,955,5425035-PCA EXPENSE DEFERRAL
(32,425)5046-EXECUTIVE DEFERRED COMP -ST
(6,524)5047-EXECUTIVE DEFERRED COMP -LT
80,9795053-STOCK BASED COMPENSATION -FAS 123R
(13,082,804)5058-FIXED COST ADJUSTMENT
2,072,2975060-OREGON -PCAM
1,329,6585061-PENSION EXPENSE -OREGON
(2,350,868)5065-VALMY UNION PACIFIC CONTRACT
781 ,0665067-ASSET RETIREMENT OBLIGATION (ARO)
5069-M &E RESERVE (1,514,386)
(3,250,774)5071 -INCENTIVE DEFERRAL-PROFIT SHARING-NOT IN RATES
8,5665503-EDC -UNREALIZED GAIN/LOSS FROM RABBI TRUST
5,711,2175505-SMSP -NET
(2,121,812)Total
Schedule Page:261 Line No.:15 Column:b
7501 -REVERSE EQUITY EARNINGS OF SUBSIDIARIES 6,659,942
7509-SMSP -INSURANCE PROCEEDS 1,286,474
21,785,2467502-ALLOWANCE FOR OFUDC
10,043,7757503-ALLOWANCE FOR BFUDC
(14,714,797)7010-PRQV FOR RATE REFUND -HC RELICENSING (AFUDC)
(286,732)701 1-0ATT REVENUE DEFICIENCY
4,839,6677012-REVENUE SHARING
51,6507013-LANGLEY REVENUE ACCRUAL
29,665,225Total
Schedule Page:261 Line No.:20 Column:b
2,776,4668025-MANUFACTURING DEDUCTION
13,735,5828034-REMOVAL COSTS
16,931,1848042-GAl N/LOSS ON REACQUIRED DEBT
FERC FORM NO.1 (ED.12-87)Page 450.1
This Page Intentionally Left Blank
Date of Report Year/Period of ReportNameofRespondentThisReportis:
(1)X An Original (Mo,Da,Yr)
(2)_A Resubmission 2015/Q4IdahoPowerCompany04/15/2016
FOOTNOTE DATA
8073-REPAIRS DEDUCTION 82,000,000
8077-PREPAID INSURANCE &OTHER EXPENSES 256,232
(1,926,786)
638,796
8001 -VEBA -POST RETIREMENT BENEFITS
8020-CONSERVATION EXPENSES
8059-SOFTWARE -LABOR COSTS DEDUCTED -ACCT 107 1,000,000
8072-RELICENSING -LABOR COSTS DEDUCTED -ACCT 107 2,800,000
8009-DEPR TIMING DIFF -OPERATING -FEDERAL 42,953,555
STATE INCOME TAX DEDUCTED ON FEDERAL RETURN 6,882,525
Total 168,047,554
FERC FORM NO.1 (ED.12-87)Page 450.2
Date of Report
(Mo,Da,Yr)
04/15/2016
Year/Period of Report
End of 2015/Q4
Name of Respondent
Idaho Power Company
This Report Is:
(1)fx]An Original
(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 Taxes ,
Charged W
W
BALANCE AT BEGINNING OF YEARKindofTax
(See instruction 5)
Adjust
mentsTaxesAccrued
(Account 236)
Prepaid Taxes
(Include in Account 165)
No.
(c)(d)(f)(e)(a)(b)
1 Federal:
13,222,719 546,9192Income-17,861,172
3 Social Security -(FOAB)-1,179 14,633,862 14,633,217
93,143 93,1434Unemployment
27,949,724 15,273,279SubtotalFederal-17,862,3515
6
7 State of Idaho:
-159,028,370 21,603,531 21,196,8198Property
9 Non-Operating 19,188 20,35011,508
5,454,898 2,799,25910Income-2,913,887
1 ,465,259 1,458,48711KWH86,152
557,29312Unemployment557,293
2,842,55313RegulatoryCommission2,842,553
14 Business License -Sho Ban 150 150
-15SubtotalIdaho6,212,143 31,942,872 28,874,91115
16
1 7 State of Oregon
1,435,643 2,974,336 3,135,49118Property
1,86719Non-Operating Property 918
203,27720Income-171,566 268,067
206,56921RegulatoryCommission206,569
52,232 53,08922Unemployment
205,949 824,997 833,45823Franchise
1,436,561 4,328,068 4,431,88424SubtotalOregon34,383
25
26 State of Montana:
331,295161,411 339,51027Property
339,510 331,29528SubtotalMontana161,411
29
30 State of Nevada:
1,097,236502,346 1,063,27331Property
502,346 1,063,273 1,097,23632SubtotalNevada
33
34 State of Wyoming
4,84335CorporateLicense4,843
802,464 1 ,627,460 1,614,78136Property
1,632,303 1,619,62437SubtotalWyoming802,464
38
39
40
TOTAL41 5,8231,938,907-10,635,253 51,966,919 51,674,868
FERC FORM NO.1 (ED.12-96)Page 262
Year/Period of Report
End of 2015/Q4
Name of Respondent
Idaho Power Company
This Report Is:
(1)[x|An Original
Dale of Report
(Mo.Da,Yr)
04/15/2016(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 (I)the taxes charged to utility plant or other balance sheet accounts.
9.For any tax apportioned to more than one utility department or account,state in a footnote the basis (necessity)of apportioning such tax.
BALANCE AT END OF YEAR DISTRIBUTION OF TAXES CHARGED Line
/Adjustments to Ret.
Earnings (Account 439)
Prepaid Taxes
(Incl.in Account 165)
Extraordinary Items
(Account 409.3)
(Taxes accrued
Accoi^nj 236)
Electric
(Account 408.1,409.1)
No.Other
(k)(I)(h)(i)(D
1
629,354 212,593,365-5,185,372
314,633,862-534
93,143 4
629,354 5-5,185,906 27,320,370
6
7
853 821,602,6789,435,081
19,188 910,346
-201,934 10-258,247 5,656,832
111,465,25992,925
12557,293
132,842,553
14150
-181,893 1532,124,7659.280.105
16
17
143,937 181,596,798 2,830,399
1,867 19948
-9,436 20277,503-106,776
21206,569
2252,232-857
23197,487 824,997
136,368 2489,854 1,597,746 4,191,700
25
26
27339,510169,627
339,510 28169,627
29
30
311,063,273536,309
1,063,273 32536,309
33
34
354,843
361,627,460815,142
37815,142 1,632,303
38
39
40
579,14351,387,776 415.192.418 2,134,055
FERC FORM NO.1 (ED.12-96)Page 263
Date of Report
(Mo.Da,Yr)
04/15/2016
Year/Period of ReportNameofRespondent
Idaho Power Company
This Report Is:
(1)[X]An Original
(2)||A Resubmission
TAXES ACCRUED,PREPAID AND CHARGED DURING YEAR
2015/Q4Endof
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.
cfiarged
w
w
w
Line XU-sBALANCEATBEGINNINGOFYEARKindofTax
(See instruction 5)
Adjust
mentsTaxesAccruedPrepaidTaxes
(Include in Account 165)
No.
(Account 236)
(e)(f)(b)(c)«J)(a)
1 State of Washington
6106102Property
610 6103SubtotalWashington
4
-1,825-17,398 47,0895OtherStatesIncome
-15,336,5306PayrollTaxCredit
47,854 5,8387CanadaGSTtax34,095
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41 TOTAL 5,8231,938,907 51,966,919 51,674,868-10,635,253
FERC FORM NO.1 (ED.12-96)Page 262.1
Year/Period of Report
End of 2015/Q4
Date of Report
(Mo,Da,Yr)
04/15/2016
Name of Respondent
Idaho Power Company
This Report Is:
(1)[X]An Original
n "
TAXES ACCRUED.PREPAID AND CHARGED DURING YEAR (Continued)
A Resubmission
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 (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.
DISTRIBUTION OF TAXES CHARGEDBALANCEATENDOFYEAR Line
Adjustments to Ret.
Earnings (Account 439)
Extraordinary Items
(Account 409.3)
Prepaid Taxes
(Incl.in Account 165)
(Taxes accrued
Acco
Electric
(Account 408.1,409.1)
No.Other
<$236)(I)G)(k)(h)G)
1
2610
3610
4
-4,686 531,516 51,775
6-15,336,530
7-7,920
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
579,143 4151,387,7765,192,418 2,134,055
FERC FORM NO.1 (ED.12-96)Page 263.1
This Page Intentionally Left Blank
Date of Report Year/Period of ReportThisReportis:
(1)X An Original
(2)A Resubmission
Name of Respondent
(Mo,Da,Yr)
04/15/2016 2015/Q4IdahoPowerCompany
FOOTNOTE DATA
Schedule Page:262 Line No.:2 Column:I
Account 409,2
Account 234.020
Account 182.410
$353,061
(1,485,757)
1,762,050
$629,354Total
Schedule Page:262 Line No.:8 Column:f
Miscellaneous Rounding
Schedule Page:262 Line No.:8 Column:I
Account 107
Schedule Page:262
Account 4 08.2
Schedule Page:262
Account 409.2
Account 234.020
$853
Line No.:9 Column:I
19,188
Line No.:10 Column:I
65,362
(267,296)
$
$
$(201,934)Total
Line No.:18 Column:I
$143,937
Line No.:19 Column:I
1,8 67
Line No.:20 Column:I
4,155
(13,591)
Schedule Page:262
Account 107
Schedule Page:262
Account 408.2
Schedule Page:262
Account 409.2
Account 234.020
$
$
$(9,436)Total
Line No.:5 Column:I
(155)
(4,531)
Schedule Page:262.1
Account 409.2
Account 234.020
$
$(4,686)Total
!Schedule Page:262.1 Line No.:6 Column:i
This amount is an offset to lines 3,4,12 and 22.Each month employer paid taxes flow
into various 408.1 accounts.In that same month these amounts are offset with a different
408.1 account.These payroll taxes are then allocated back to the balance sheet and O&M
accounts based on current month labor charges .
Schedule Page:262.1 Line No.:7 Column:f
Canada GST accrual is an adjustment because the offset account is not a 600 expense
account .
FERC FORM NO.1 (ED.12-87)Page 450.1
Name of Respondent
Idaho Power Company
Year/Period of Report
End of 2015/Q4
This Report Is:
(1)[X]An Original
Date of Report
(Mo.Da,Yr)
04/15/2016(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).lnclude in column (i)
the average period over which the tax credits are amortized.
Allocations to
Current Year's Income
Amount
Line Account
Subdivisions
Balance at Beginning
of Year Deferred for Year AdjustmentsNo.Account No,Amount Account No.(b)(g)(e)(f)(c)(d)
1 Electric Utility
2 3%
56,42834%434,199
4 7%
1,383,541510%19,699,576
26,029611%1,161,824
1,496,9637Other-State 57,867,232 411.4 3,455,060 411.4
2,962,9618TOTAL3,455,06079,162,831
9 Other (List separately
and show 3%,4%,7%,
10%and TOTAL)
10 Line 6 Col A 11%
11
1,496,9633,455,060 411.412StateofIdaho57,867,232 411.4
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46
47
48
Page 266FERCFORMNO.1 (ED.12-89)
Date of Report
{Mo.Da.Yr)
04/15/2016
Year/Period of Report
End of 2015/Q4
This Report Is:
(1)[X]An Original
(2)||A Resubmission
ACCUMULATED DEFERRED INVESTMENT TAX CREDlVs (Account 255)(continued)
Name of Respondent
Idaho Power Company
Average Period
of Allocation
to Income
LineBalanceatEnd
of Year ADJUSTMENT EXPLANATION
No.
(11M
1
2
37.69377,771
4
518,316,035 14.24
61,135,795 44.64
759,825,329 38.66
879,654,930
9
10
11
1259,825,329
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46
47
48
Page 267FERCFORMNO.1 (ED.12-89)
This Page Intentionally Left Blank
Year/Period of Report
End of 2015/Q4
This Report Is:
(1)rx]An Original
(2)|—|A Resubmission
OTHER DEFFERED CREDITS {Account 253)
Date of Report
(Mo,Da,Yr)
04/15/2016
Name of Respondent
Idaho Power Company
1 .Report below the particulars (details)called for concerning other deferred credits.
2.For any deferred credit being amortized,show the period of amortization.
3.Minor items (5%of the Balance End of Year for Account 253 or amounts less than $100,000,whichever is greater)may be grouped by classes.
Balance at
End of Year
DEBITSDescriptionandOther
Deferred Credits
Balance at
Beginning of Year
Line
CreditsContra
Account
AmountNo.
(b)(f)(e)(o)(d)(a)
2,058,7258,854,688 9,625,463PointtoPointTransStudy(253201)1,287,950 186,2421
2
2,466,6662,866,666 400 400,0003FTV(253202)
4 (Amort Period Mar 1998-Feb 2023)
5
187,5006ShoBanTransROW(253480)202,500 242 15,000
7 (Amort Period Jan 2005-Dec 2027)
8
88,641 1,293,25366,7769OperationsAccrual(253550)1,271,388 232,401
10 (amort period 1 year for dues)
11
1,237,096 713,831667,185 186 1,190,45012MilnerFallingWater(253953)
1 3 Amort Period (Feb 1 992 -Feb 201 7)
14
1,245,3581,245,35815PostretirementBenefits(253960)1,455,093 253,401 1,455,093
16
324,206 3,789,3473,883,100 131 417,95917DirectorsDeferredCompensation
18 (253980-253999)
19
60,961 3,31859,40320MinorItems(1)253042 1,760 Various
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
12,581,725 11,757,99811,635,642 12,459,36947TOTAL
Page 269FERCFORMNO.1 (ED.12-94)
Year/Period of Report
End of 2015/Q4
This Report Is:
(1)[X]An Original
(2)|—|A Resubmission
ACCUMULATED DEFFERED INCOME TAXES -OTHER PROPERTY {Account 282}
?ate of Report
(Mo,Da,Yr)
04/15/2016
Name of Respondent
Idaho Power Company
1 .Report the information called for below concerning the respondent's accounting for deferred income taxes rating to property not
subject to accelerated amortization
2.For other (Specify),include deferrals relating to other income and deductions.
CHANGES DURING YEAR
Line Balance at
Beginning of Year
Account Amounts Credited
to Account 41 1.1
Amounts Debited
to Account 410.1
No.
(d)(b)(c)(a)
1 Account 282
18,235,83741,997,682451,117,6922Electric
3 Gas
4 Other
18,235,83741,997,682451,117,6925TOTAL(Enter Total of lines 2 thru 4)
6 Non-Operating Property
797,512,6697Other-Regulatory Asset
8 Like Kind Exchange-Reclass No
18,235,83741,997,6821,248,630,3619TOTALAccount282(Enter Total of lines 5 thru
10 Classification of TOTAL
18,118,54641,671,9311,071,548,84011FederalIncomeTax
117,291325,751177,081,52112StateIncomeTax
13 Local Income Tax
NOTES
FERC FORM NO.1 (ED.12-96)Page 274
Date of Report
(Mo.Da,Yr)
04/15/2016
Year/Period of Report
End of 2015/Q4
Name of Respondent
Idaho Power Company
This Report Is:
(1)[x|An Original
(2)|—|A Resubmission
ACCUMULATED DEFERRED INCOME TAXES -OTHER PROPERTY (Account 282)(Continued)
3.Use footnotes as required.
ADJUSTMENTSCHANGESDURINGYEAR
LineBalanceat
End of Year
Amounts Credited
to Account 41 1 .2
Amounts Debited
to Account 410.2
Debits Credits No.AmountAccount
Credited
Amount Account
Debited (j)(f)(e)(k)(g)(h)01
1
2469,103,7515,706,531282.111 69,255
3
4
469,103,751 55,706,531 69,255
6
875,027,483 777,514,814182
5,775,786 869,2555,706,531 282100
91,349,907,02069,255 77,584,0695,706,531 5,706,531
10
1,156,602,661 1161,569,6915,706,531 69,2555,706,531
193,304,359 1216,014,378
13
NOTES (Continued)
FERC FORM NO.1 (ED.12-96)Page 275
This Page Intentionally Left Blank
Date of Report Year/Period of ReportThisReportis:Name of Respondent
(Mo,Da,Yr)(1)X An Original
(2)_A Resubmission 2015/Q404/15/2016IdahoPowerCompany
FOOTNOTE DATA
Schedule Page:274 Line No.:2 Column:b
2015AdjustmentsDebitsChangesduringYear2015
CR toCRtoDRto EndingAcct.Beginning
BalancecreditAmount411.1 411.2Balance410.1LineAccount
ed
h kfdMbNo.ac
453,391,72469,255282.37,566,234 18,176,936Line2:Depreciation Timing Diff-Operating 439,778,212 5,706,531
111
18,348,619965,708Intangible-Labor Costs
Deducted-Acct 1 07
CIAC-Taxable-Acct 107
Valmy Capitalized Items
Software-Labor Costs
Deducted-Acct 1 07
17,382,911
(3,287,799)
63,560
1,051,482
(6,010,733)2,722,934
121,766
347,096 704,386
58,206
(463,835)(501,560)69538,420EngineeringFees-Taxable-Acct
107
469,103,75169,2555,706,531451,117,692 41,997,682 18,235,837TOTALLine2
FERC FORM NO.1 (ED.12-87)Page 450.1
Year/Period of Report
End of 2015/Q4
Date of Report
(Mo,Da,Yr)
04/15/2016
Name of Respondent
Idaho Power Company
This Report Is:
(1)[X|An Original
(2)||A Resubmission
ACCUMULATED DEFFERED INCOME TAXES -OTHER (Account 283)
1 .Report the information called for below concerning the respondent's accounting for deferred income taxes relating to amounts
recorded in Account 283.
2.For other (Specify),include deferrals relating to other income and deductions.
CHANGES DURING YEAR
Balance at
Beginning of Year
Line Amounts Debited
to Accopijt 410.1
Amounts Credited
to AccoLjjjt 41 1 .1
Account
No.(b)(a)
1 Account 283
—-
2 Electric
—
3 Other Electric —See Note 25,283,30574,155,896 15,289,514
4
5
6
8 103,425,257Other-See Note
9 TOTAL Electric (Total of lines 3 thru 8)25,283,305177,581,153 15,289,514
10 Gas
11
12
13
14
15
16
17 TOTAL Gas (Total of lines 11 thru 16)
18 851,124Other-See Note
19 TOTAL (Acct 283)(Enter Total of lines 9,17 and 18)15,289,514 25,283,305178,432,277
20 Classification of TOTAL
21 Federal Income Tax 21,209,00312,825,671149,678,643
22 State Income Tax 4,074,30228,753,634 2,463,843
23 Local Income Tax
NOTES
FERC FORM NO.1 (ED.12-96)Page 276
Date of Report
(Mo.Da,Yr)
04/15/2016
Year/Period of Report
End of 2015/Q4
Name of Respondent
Idaho Power Company
This Report Is:
(1)[X]An Original
(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.
ADJUSTMENTSCHANGESDURINGYEAR
Amounts Debited Amounts Credited
to Account 410.2 to Account 41 1 .2
LineCreditsDebitsBalanceat
End of YearAmountAccount
Debited
AmountAccount No.
Cr|d|ted (k)(i)(f)M (J)(e)
1
2
364,162,105
4
5
6
7
898,426,2824,998,975190
9162,588,3874,998,975
10
11
12
13
14
15
16
17
186,080 318,236538,968
196,080 162,906,6234,998,975538,968
20
215,100 136,654,8844,193,411452,116
2226,251,739980805,56486,852
23
NOTES (Continued)
FERC FORM NO.1 (ED.12-96)Page 277
Date of Report Year/Period of Report
(Mo,Da,Yr)
04/15/2016
This Report is:Name of Respondent
(1)X An Original
(2)_A Resubmission 2015/Q4IdahoPowerCompany
FOOTNOTE DATA
Schedule Page:276 Line No.:3 Column:b
Changes during Year 20152015
CR to
411.1
Ending
Balance
Beginning
Balance
DR to
410.1AccountLine
b d kNo.M c
27,664,003
17,419,329
1,733,392
14,394,933
Pension Expense
PCA Expense
Conservation Expenses
Fixed Cost Adjustment
Regulatory Asset-Current
Oregon PCAM
Regulatory Liability-Non Current
Boardman Decommission
Oregon Excess Power Costs
OATT Revenue Deficiency
Renewable Energy Certificates
(REC)Sales
Langley Revenue Accrual
2011 LIDAR Surveys Deferral
Bennett Mtn Maint Deferral
Intervenor Funding Orders
OPUC Grid West Loans
Emission Allowances
Delivery Accruals
18,934,259
21,311,448
1,789,468
9,280,211
18,067,486
1,942,270
1,918,442
484,201
(61,888)
112,098
(228,084)
8,729,744Line3:
3,892,119
305,813249,737
5,114,722
(0)18,067,486
810,947
1,918,442
1,131,323
0
484,201
(61,888)0
0112,098
176,400 745,8591,150,343
370,974
119,331
29,277
121,344
350,781
119,331
29,277
121,344
20,193
0
0
92592500
9,1023,722
(19,395)
5,380
19,395 (0)
64,162,10574,155,896 15,289,514 25,283,305TOTALLine3
Schedule Page:276 Line No.:8 Column:b
2015Adjustments
Debits
2015 Changes during Year
EndingCRtoDRCRtoAcct.Beginning DR to
to
credited Amount BalanceBalance410.1 411.1 410.411.2LineAccount
2
f h k(a)b dNo.ace
190 4,049,669 99,022,252103,071,921Line8:Pension-FAS 158
(595,970)190 949,306PostretirementPlan-FAS 1 58 353,336
98,426,28204,998,975103,425,257 0 0 0TOTALLine8
Schedule Page:276 Line No.:18 Column:b
Adjustments
Debits
20152015ChangesduringYear
Ending
Balance
CR to
411.2
Acct.
credited
Beginning
Balance
DR to
410.1
CR to
411.1
DR to
410.2 AmntLineAccount
kfhMbdNo.ace
538,610 4,420LineEDC-Unrealized Gain/Loss From
18:Rabbit Trust
SMSP-Unrealized Gain/Loss From
Rabbi Trust
Royalty Income
Oregon Non-Op Prop Tax Adj
543,030
(41,951)(41,951)
355,4085,721349,687
359359358358
538,968 0 318,236851,124 0 0 6,080TOTALLine18
FERC FORM NO.1 (ED.12-87)Page 450.1
Name of Respondent
Idaho Power Company
Date of Report
(Mo,Da,Yr)
04/15/2016
Year/Period of ReportThisReportIs:
(1)(x|An Original
(2)||A Resubmission
OTHER REGULATORY LIABILITIES (Account 254)
2015/Q4Endof
1 .Report below the particulars (details)called for concerning other regulatory liabilities,including rate order docket number,if
applicable.
2.Minor items (5%of the Balance in Account 254 at end of period,or amounts less than $100,000 which ever is less),may be grouped
by classes.
3.For Regulatory Liabilities being amortized,show period of amortization.
Balance at End
of Current
Quarter/Year
Balance at Begining
of Current
Quarter/Year
DEBITSDescriptionandPurposeof
Other Regulatory Liabilities
Line
CreditsAccount
Credited
AmountNo.
(f)(d)(e)(a)(b)(c)
1 Market to Market Short Term -(254001)4,763,0496,301,3171,617,027 276.759175
2 IPUC Order #28661
3
4 FAS 1 33 -Market to Market -(254203)442,08263,322 378,924 126,480175
5 IPUC Order#28661
6
7 Unfunded Accum Def Income Tax (254966)378,735 694,61450,814,726 51,130,605Various
8
9 Idaho DSM Rider (254201)45,247,78137,911,476782,231)6,554,074Various
10 Order #29026
11
12 Oregon Solar Pilot -(254005)554,880 1,194,5332,400,864 3,040,517Various
13 Order #10-198
14
15 Green Tags Oregon (254415)78,074132,831 137,928 72,9771823,254
16 Order#11 -086
17
18 Regulatory Unfunded Accum Def Income Tax (254419)5,341,917 666,2404,675,677 1823
19
20 Revenue Sharing (254101)11,026,832 6,187,1657,999,145 3,159,4781823,400
21 IPUC Order #33149
22
23 BPA Credit Residential Idaho (254401)3,862,855643,903 2,481,690 2,025,068142
24 Advice #11-03 (ID)#11-15 (OR)
25
26 WAQC Carryover (254901)112,536 48,688112,536 48,688401
27 IPUC Order #29505
28
29 Bridger Depreciation #12-296 -(254800)321,839809,830 1,131,669
30
31 Oregon DSM Rider -(254202)3,907,536(3,907,536)
32 Advice #05-03
33
34 Minor Items (7)674,011593,84663,175 143,340Various
35
36
37
38
39
40
41 TOTAL 65,220,081 68,088,467 67,711,65564,843,269
Page 278FERCFORMNO.1/3-Q (REV 02-04)
Name of Respondent
Idaho Power Company
Date of Report
(Mo,Da,Yr)
04/15/2016
Year/Period of Report
End of 2015/Q4
This Report Is:
(1)[x]An Original
(2)||A Resubmission
ELECTRIC OPERATING REVENUES (Account 400)
1 .The following instructions generally apply to the annual version of these pages.Do not report quarterly data in columns (c),(e),(f),and (g).Unbilled revenues and MWH
related to unbilled revenues need not be reported separately as required in the annual version of these pages.
2.Report below operating revenues for each prescribed account,and manufactured gas revenues in total.
3.Report number of customers,columns (f)and (g),on the basis of meters,in addition to the numberof 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 oftwelve figures at the close of
each month.
4.If increases or decreases from previous period (columns (c),(e),and (g)),are not derived from previously reported figures,explain any inconsistencies in a footnote.
5.Disclose amounts of $250,000 or greater in a footnote for accounts 451 ,456,and 457.2.
Operating Revenues Year
to Date Quarterly/Annual
Operating Revenues
Previous year (no Quarterly)
Line Title of Account
No.
M (c)(a)
1 Sales of Electricity
512,068,335 500,194,7262(440)Residential Sales
3 (442)Commercial and Industrial Sales
453,982,5934Small(or Comm.)(See Instr.4)466,541,569
182,675,2245Large(or Ind.)(See Instr.4)182,254,287
4,039,381 4,133,6236(444)Public Street and Highway Lighting
7 (445)Other Sales to Public Authorities
8 (446)Sales to Railroads and Railways
9 (448)Interdepartmental Sales
1,164,903,572 1,140,986,16610TOTALSalestoUltimateConsumers
77,164,88730,887,26111(447)Sales for Resale
1,218,151,053
18,348,408
12 TOTAL Sales of Electricity 1,195,790,833
13,865,51813(Less)(449.1)Provision for Rate Refunds
1,199,802,6451,181,925,31514TOTALRevenuesNetofProv.for Refunds
15 Other Operating Revenues
16 (450)Forfeited Discounts
4,119,479 3,780,23917(451)Miscellaneous Service Revenues
18 (453)Sales of Water and Water Power
24,852,979 23,695,29119(454)Rent from Electric Property
20 (455)Interdepartmental Rents
31.174.302 27,734,88621(456)Other Electric Revenues
24,129,372 22,627,91622(456.1)Revenues from Transmission of Electricity of Others
23 (457.1)Regional Control Service Revenues
24 (457.2)Miscellaneous Revenues
25
84,276,132 77,838,33226TOTALOtherOperatingRevenues
1,266,201,447 1,277,640,97727TOTALElectricOperatingRevenues
FERC FORM NO.1/3-Q (REV.12-05)Page 300
Year/Period of Report
End of 2015/Q4
Name of Respondent
Idaho Power Company
This Report Is:
(1)[X]An Original
(2)||A Resubmission
ELECTRIC OPERATING REVENUES (Account 400)
Date of Report
(Mo,Da,Yr)
04/15/2016
6.Commercial and industrial Sales,Account442,may be classified according to the basis of classification (Small or Commercial,and Large or Industrial)regularly used by the
respondent if such basis ofclassification is not generally greater than 1 000 Kw of demand.(See Account 442 ofthe Uniform System of Accounts.Explain basis of classification
in a footnote.)
7 See pages 108-109,Important Changes During Period,for important new territory added and important rate increase or decreases.
8.For Lines 2,4,5,and 6,see Page 304 for amounts relating to unbilled revenue by accounts.
9.Include unmetered sales.Provide details of such Sales in a footnote.
MEGAWATT HOURS SOLD AVG.NO.CUSTOMERS PER MONTH Line
No.Year to Date Quarterly/Annual Amount Previous year (no Quarterly)Current Year (no Quarterly)Previous Year (no Quarterly)
(e)(9)(d)(f)
1
425,036 24,977,176 4,965,076 432,275
3
84,425 46,059,428 5,877,580 85,560
3,217,070 119 1163,195,786 5
32,103 32,641 2,592 2,380 6
7
8
9
511,95714,264,493 14,092,367 520,546 10
111,254,136 2,220,419
520,546 511,957 1215,518,629 16,312,786
13
511,957 1415,518,629 16,312,786 520,546
Line 12,column (b)includes $
Line 12,column (d)includes
7,691,485
97,949
of unbilled revenues.
MWH relating to unbilled revenues
FERC FORM NO.1/3-Q (REV.12-05)Page 301
Name of Respondent Date of Report Year/Period of ReportThisReportis:
(1)X An Original
(2)_A Resubmission
FOOTNOTE DATA
(Mo,Da,Yr)
Idaho Power Company 04/15/2016 2015/Q4
1SchedulePage:300 Line No.:17 Column:b
This amount consists of:
Service Establishment/Connection Charges
(Includes late and after hour charges)
Misc.Under $250,000
$3,991,239
128,240
$4,119,479TotalAccount451
Schedule Page:300 Line No.:21 Column:b
This amount consists of:
Alternate Distribution Service
DSM Activity
Misc.Under $250,000
$321,995
30,531,891
320,416
$31,174,302TotalAccount456
FERC FORM NO.1 (ED.12-87)Page 450.1
This Page Intentionally Left Blank
This Page Intentionally Left Blank
Date of Report
(Mo.Da,Yr)
04/15/2016
Year/Period of ReportNameofRespondent
Idaho Power Company
This Report Is:
(1)pg An Original
(2)||A Resubmission
SALES OF ELECTRICITY BY RATE SCHEDULES
2015/Q4Endof
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 310-31 1 .
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.
Number and I itle of Kate schedule MWh Sold Revenue Average Number
of Customers
KWh of Sales
Per Customer
Ft,§venue PerLine
No.(f)
1
1 1 ,395
177,955
16,711
0.0988
0.0944
0.0955
0.2449
0.1004
2
3
4
5
6
0.102911,5148
9
1
4,860
2,228,695
98,088
1,479,750
0.1214
0.0647
0.0732
0.0722
0.1779
0.0579
0.0636
0.0584
0.0793
0.0861
0.0513
0.0647
11
12
13
14
15
19,820,482
6,409,000
44,359,667
101,548
1 1 ,745
280,700,000
16
17
18
19
20
21
22
23
108,022 0.070124
25
26
2,456
17,503
5,353
0.0863
0.1314
0.0629
0.1631
27
28
29
30
31
12,385 0.125832
33
34
35
36
37
38
39
40
41 27,215 0.0817
0.0785
0.0817
042
43 27,403
FERC FORM NO.1 (ED.12-95)Page 304
^
This Report Is:
s
Year/Period of Report
End of 2015/Q4
Name of Respondent
Idaho Power Company
Date of Report
(Mo,Da,Yr)
04/15/2016
(1)An Original
(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 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.
Actual Demand (MW)
Average Average
Monthly NCP Demand Monthly CFTDemand
FERC Rate
Schedule or
Tariff Number
Average
Monthly Billing
Demand (MW)
Statistical
Classifi
cation
Name of Company or Public Authority
(Footnote Affiliations)
Line
No.
(e)(f)(a)(b)(c)(d)
n/a n/aOSn/a1ADMInvestorServices,Inc.
n/a n/aSFWSPPn/a2ArizonaPublicServiceCo.
n/a n/aWSPPn/a3AvistaCorp.SF
n/aWSPPn/a n/a4BasinElectricPowerCooperativeSF
n/a n/a n/aSFWSPP5BlackHillsPowerInc.
OS n/a n/a n/aWSPP6BlackHillsPowerInc.
n/a n/aSFWSPPn/a7BonnevillePowerAdministration
n/a n/aSFWSPPn/a8BPEnergyCompany
n/a n/aSFWSPPn/a9CalpineEnergyServices,L.P.
n/aWSPPn/a n/a10CargillPowerMarketsLLCSF
OS n/a n/a n/a11CargillPowerMarketsLLCWSPP
OS n/a n/a12CargillPowerMarketsLLCISDAn/a
n/a n/aWSPPn/a13CityofAnaheimSF
n/a n/aWSPPn/a14ClatskaniePUDSF
0 00SubtotalRQ
0 0Subtotalnon-RQ 0
0 0 0Total
Page 310FERCFORMNO.1 (ED.12-90)
This Report Is:
(1)[x]An Original
(2)f-)A Resubmission
SALES FOR RESALE (Account 447)(Continued)
Year/Period of Report
End of 2015/Q4
Name of Respondent
Idaho Power Company
Date of Report
(Mo,Da,Yr)
04/15/2016
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.
REVENUE LineMegaWattHoursTotal($)
(h+i+j)Other ChargesEnergyChargesDemandCharges No.Sold ($)($)($)
(i)(k)(g)(h)iil
1-861,190 -861,190
264,00064,0004,400
31,230,08572,813 1,230,085
454,0302,118 54,030
516,80584516,805
61,200 1,200150
7653,025653,02532,888
862,46462,4642,400
94,5004,500300
1038,2451,810 38,245
1117,690 17,6902,353
121,128,634 1,128,634
13919,472919,47237,200
143,1341603,134
0 0000
30,887,26126,516,513 4,370,7481,254,136 0
4,370,748 30,887,2611,254,136 0 26,516,513
Page 311FERCFORMNO.1 (ED.12-90)
This Report Is:
[X]An Original
(2)[~~1 A Resubmission
SALES FOR RESALE (Accounl 447)
Name of Respondent
Idaho Power Company
Date of Report
(Mo,Da,Yr)
04/15/2016
Year/Period of Report
(1)2015/Q4Endof
1 .Report all sales for resale (i.e.,sales to purchasers other than ultimate consumers)transacted on a settlement basis other than
power exchanges during the year.Do not report exchanges of electricity (i.e.,transactions involving a balancing of debits and credits
for energy,capacity,etc.)and any settlements for imbalanced exchanges on this schedule.Power exchanges must be reported on the
Purchased Power schedule (Page 326-327).
2.Enter the name of the purchaser in column (a).Do note abbreviate or truncate the name or use acronyms.Explain in a footnote any
ownership interest or affiliation the respondent has with the purchaser.
3.In column (b),enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows:
RQ -for requirements service.Requirements service is service which the supplier plans to provide on an ongoing basis (i.e.,the
supplier includes projected load for this service in its system resource planning).In addition,the reliability of requirements service must
be the same as,or second only to,the supplier's service to its own ultimate consumers.
LF -for tong-term service."Long-term"means five years or Longer and "firm"means that service cannot be interrupted for economic
reasons and is intended to remain reliable even under adverse conditions (e.g.,the supplier must attempt to buy emergency energy
from third parties to maintain deliveries of LF service).This category should not be used for Long-term firm service which meets the
definition of RQ service.For all transactions identified as LF,provide in a footnote the termination date of the contract defined as the
earliest date that either buyer or setter can unilaterally get out of the contract.
IF -for intermediate-term firm service.The same as LF service except that "intermediate-term"means longer than one year but Less
than five years.
SF -for short-term firm service.Use this category for all firm services where the duration of each period of commitment for service is
one year or less.
LU -for Long-term service from a designated generating unit."Long-term"means five years or Longer.The availability and reliability of
service,aside from transmission constraints,must match the availability and reliability of designated unit.
IU -for intermediate-term service from a designated generating unit.The same as LU service except that "intermediate-term"means
Longer than one year but Less than five years.
Actual Demand (MW)
Average Average
Monthly NCP Demanr Monthly CPlDemand
FERC Rate
Schedule or
Tariff Number
Average
Monthly Billing
Demand (MW)
Statistical
Classifi
cation
Name of Company or Public Authority
(Footnote Affiliations)
Line
No.
(d)(e)(f)(b)(c)(a)
n/an/aWSPPn/a1EDFTradingNorthAmerica,LLC SF
n/an/aWSPPn/a2EnergyKeepersSF
n/a n/aWSPPn/aSF3EugeneElectricBoard
n/an/a n/a4ExelonGenerationCompany.LLC SF WSPP
n/an/a n/a5GrantCountyPublicUtilityDistrict#2 SF WSPP
n/an/a n/aSFWSPP6IberdrolaRenewables,Inc.
n/an/a n/aOS7IberdrolaRenewables,Inc.
n/an/a n/aOSWSPP8IberdrolaRenewables,Inc.
n/an/aOSn/a9JeffriesBache
n/an/a n/a10LosAngelesDepartmentofWater&Power SF WSPP
n/an/a n/aOSISDA11MacquarieEnergyLLC
n/an/a n/aOSWSPP12MacquarieEnergyLLC
n/an/a n/aISDA13MorganStanleyCapitalGroupInc.SF
n/a n/aOSn/a14MorganStanleyCapitalGroupInc.ISDA
0 00SubtotalRQ
000Subtotalnon-RQ
0 00Total
Page 310.1FERCFORMNO.1 (ED.12-90)
This Report Is:
(1)fx]An Original
(2)||A Resubmission
SALES FOR RESALE (Account 4-17}(Continued)
Date of Report
(Mo,Da,Yr)
04/15/2016
Year/Period of Report
End of 201 5/Q4
Name of Respondent
Idaho Power Company
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 Jine 24.
10.Footnote entries as required and provide explanations following all required data.
REVENUE LineMegaWattHoursTotal($)
(h+i+j)Other ChargesEnergyChargesDemandCharges No.Sold ($)($)($)
(i)(k)(g)(h)(j)
11,438,7601,438,76051,000
222022010
373,38473,3843,437
43,412,5863,412,586153,345
550,60650,6062,163
6305,566305,56613,600
717,11317,113
816,47216,472
92,361,4742,361,474
104,362,2004,362,200148,400
11215,438215,438
12272272
13833,497833,49743,627
145,3595,359401
00000
30,887,2614,370,748026,516,5131,254,136
30,887,2614,370,74826,516,5131,254,136 0
Page 311.1FERCFORMNO.1 (ED.12-90)
This Report Is:
(1)m An Original
(2)[~|A Resubmission
SALES FOR RESALE {Account 447)
Year/Period of Report
End of 2015/Q4
Date of Report
(Mo.Da,Yr)
04/15/2016
Name of Respondent
Idaho Power Company
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 sen/ice 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.
Actual Demand (MW)
Average "Average
Monthly NCP Deman<Monthly CPTOemand
FERC Rate
Schedule or
Tariff Number
Average
Monthly Billing
Demand (MW)
Statistical
Classifi
cation
Name of Company or Public Authority
(Footnote Affiliations)
Line
No.
(f)(d)(e)(a)(b)(c)
n/a n/aOSn/aWSPP1MorganStanleyCapitalGroupInc.
n/an/a n/aSFWSPP2NevadaPowerCompany,dba NVEnergy
n/an/a n/aOSWSPP3NevadaPowerCompany,dba NVEnergy
n/an/a n/aOSWSPP4NevadaPowerCompany,dba NX/Energy
n/a n/an/aSFWSPP5NorthwesternEnergy
n/a n/aOSn/aWSPP6NorthwesternEnergy
n/a n/an/aSFWSPP7PacifiCorpInc.
n/a n/aOSn/aWSPP8PacifiCorpInc.
n/an/a n/aOS9PacifiCorpInc.T-7
n/an/a n/aWSPP10PortlandGeneralElectricCompanySF
n/a n/aOSn/a11PortlandGeneralElectricCompanyWSPP
n/a n/aOSn/aT-712PortlandGeneralElectricCompany
n/a n/aOSn/aWSPP13PortlandGeneralElectricCompany
n/an/a n/aWSPP14PowerexCorp.SF
000SubtotalRQ
000Subtotalnon-RQ
000Total
Page 310.2FERCFORMNO.1 (ED.12-90)
This Report Is:
XjAn Original
Year/Period of Report
End of 2015/Q4
Name of Respondent
Idaho Power Company
Date of Report
(Mo,Da,Yr)
04/15/2016
(1)
^)A Resubmission(2)
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.
REVENUE LineMegaWattHours
Sold
Total ($)
(h+i+j)Other ChargesEnergyChargesDemandCharges No.
($)($)($)
0)(k)(h)(9)JO.
1574,949 574,949
2299,299299,29918,161
3191,688191,68814,846
410,766 10,766
568,0223,428 68,022
627,490 27,4903,375
7173.8629,544 173,862
85,6005,600400
91,8051,80587
101,311,42257,704 1,311,422
1126,420 26,4201,672
1272724
1320,13020,130
14119,981119,9819,610
0 0000
30,887,26126,516,513 4,370,7481,254,136 0
4,370,748 30,887,2611,254,136 0 26,516,513
Page 311.2FERCFORMNO.1 (ED.12-90)
?ate of Report
(Mo,Da,Yr)
04/15/2016
This Report Is:
(1)[x]An Original
(2)[~~|A Resubmission
SALES FOR RESALE (Account 447)
Year/Period of Report
End of 2015/Q4
Name of Respondent
Idaho Power Company
1 .Report all sales for resale (i.e.,sales to purchasers other than ultimate consumers)transacted on a settlement basis other than
power exchanges during the year.Do not report exchanges of electricity (i.e.,transactions involving a balancing of debits and credits
for energy,capacity,etc.)and any settlements for imbalanced exchanges on this schedule.Power exchanges must be reported on the
Purchased Power schedule (Page 326-327).
2.Enter the name of the purchaser in column (a).Do note abbreviate or truncate the name or use acronyms.Explain in a footnote any
ownership interest or affiliation the respondent has with the purchaser.
3.In column (b),enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows:
RQ -for requirements service.Requirements service is service which the supplier plans to provide on an ongoing basis (i.e.,the
supplier includes projected load for this service in its system resource planning).In addition,the reliability of requirements service must
be the same as,or second only to,the supplier's service to its own ultimate consumers.
LF -for tong-term service."Long-term"means five years or Longer and "firm"means that service cannot be interrupted for economic
reasons and is intended to remain reliable even under adverse conditions (e.g.,the supplier must attempt to buy emergency energy
from third parties to maintain deliveries of LF service).This category should not be used for Long-term firm service which meets the
definition of RQ service.For all transactions identified as LF,provide in a footnote the termination date of the contract defined as the
earliest date that either buyer or setter can unilaterally get out of the contract.
IF -for intermediate-term firm service.The same as LF service except that "intermediate-term"means longer than one year but Less
than five years.
SF -for short-term firm service.Use this category for all firm services where the duration of each period of commitment for service is
one year or less.
LU -for Long-term service from a designated generating unit."Long-term"means five years or Longer.The availability and reliability of
service,aside from transmission constraints,must match the availability and reliability of designated unit.
IU -for intermediate-term service from a designated generating unit.The same as LU service except that "intermediate-term"means
Longer than one year but Less than five years.
Actual Demand (MW)FERC Rate
Schedule or
Tariff Number
Average
Monthly Billing
Demand (MW)
Statistical
Classifi
cation
Name of Company or Public Authority
(Footnote Affiliations)
Line Average Average
Monthly NCP Demand Monthly CP DemandNo.
(f)(e)(c)(d)(b)(a)
n/an/aOSWSPPn/a1PowerexCorp,
n/an/an/aSFWSPP2PugetSoundEnergy,Inc.
n/an/an/aOST-73PugetSoundEnergy,Inc.
n/a n/an/aSFWSPP4RainbowEnergyMarketingCorporation
n/an/a n/aWSPP5SeattleCityLightSF
n/an/aOSWSPPn/a6SeattleCityLight
n/an/aWSPPn/a7ShellEnergyNorthAmerica(US),L.P,SF
n/an/aOSWSPPn/a8ShellEnergyNorthAmerica(US),L.P.
n/an/aOSn/aWSPP9ShellEnergyNorthAmerica(US),L.P.
n/a n/an/aOST-710SierraPacificPowerCo.,dba NV Energy
n/an/a n/aWSPP11SnohomishCountyPUDSF
n/an/aWSPPn/aSF12TalenEnergyMarketing,LLC
n/an/aOSWSPPn/a13TalenEnergyMarketing,LLC
n/an/an/aOSWSPP14TalenEnergyMarketing,LLC
000SubtotalRQ
000Subtotalnon-RQ
000Total
Page 310.3FERCFORMNO.1 (ED.12-90)
This Report Is:
[XjAn Original
Year/Period of Report
End of 2015/Q4
Name of Respondent
Idaho Power Company
Date of Report
(Mo,Da,Yr)
04/15/2016
(1)
(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 (NOP)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.
REVENUE LineMegaWattHoursTotal($)
(h+i+j)Other ChargesEnergyChargesDemandCharges No.Sold ($)($)($)
(i)(k)(h)(g)(j)
129,34529,34510,358
2303,898303,89814,746
339439422
469,80069,8004,200
5274,040274.04011,628
62,825 2,825425
76,048,1706,048,170301,897
815015025
9476,119476,119
101,1451,14558
1133,75233,7521,081
1231,60331,6031,863
137,2327,232
141,9501,950350
00000
30,887,2614,370,748026,516,5131,254,136
30,887,2614,370,748026,516,5131,254,136
Page 311.3FERCFORMNO.1 (ED.12-90)
This Report is:
(1)fx]An Original
(2)J~jA Resubmission
SALES FOR RESALE (Account 447)
Date of Report
(Mo,Da,Yr)
04/15/2016
Year/Period of Report
End of 2015/Q4
Name of Respondent
Idaho Power Company
1 .Report all sales for resale (i.e.,sales to purchasers other than ultimate consumers)transacted on a settlement basis other than
power exchanges during the year.Do not report exchanges of electricity (i.e.,transactions involving a balancing of debits and credits
for energy,capacity,etc.)and any settlements for imbalanced exchanges on this schedule.Power exchanges must be reported on the
Purchased Power schedule (Page 326-327).
2.Enter the name of the purchaser in column (a).Do note abbreviate or truncate the name or use acronyms.Explain in a footnote any
ownership interest or affiliation the respondent has with the purchaser.
3.In column (b),enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows:
RQ -for requirements service.Requirements service is service which the supplier plans to provide on an ongoing basis (i.e.,the
supplier includes projected load for this service in its system resource planning).In addition,the reliability of requirements service must
be the same as,or second only to,the supplier's service to its own ultimate consumers.
LF -for tong-term service."Long-term"means five years or Longer and "firm"means that service cannot be interrupted for economic
reasons and is intended to remain reliable even under adverse conditions (e.g.,the supplier must attempt to buy emergency energy
from third parties to maintain deliveries of LF service).This category should not be used for Long-term firm service which meets the
definition of RQ service.For all transactions identified as LF,provide in a footnote the termination date of the contract defined as the
earliest date that either buyer or setter can unilaterally get out of the contract.
IF -for intermediate-term firm service.The same as LF service except that "intermediate-term"means longer than one year but Less
than five years.
SF -for short-term firm service.Use this category for all firm services where the duration of each period of commitment for service is
one year or less.
LU -for Long-term service from a designated generating unit."Long-term"means five years or Longer.The availability and reliability of
service,aside from transmission constraints,must match the availability and reliability of designated unit.
IU -for intermediate-term service from a designated generating unit.The same as LU service except that "intermediate-term"means
Longer than one year but Less than five years.
Actual Demand (MW)FERC Rate
Schedule or
Tariff Number
Average
Monthly Billing
Demand (MW)
Statistical
Classifi
cation
Name of Company or Public Authority
(Footnote Affiliations)
Line Average Average
Monthly NCP Demand Monthly CP DemandNo.
(f)(d)(e)(a)(b)(c)
n/an/a n/aTenaskaPowerServicesCo.SF WSPP1
n/an/a n/aOSWSPP2TenaskaPowerServicesCo.
n/an/a n/aOSWSPP3TenaskaPowerServicesCo.
n/an/a n/aWSPP4TheEnergyAuthority,Inc.SF
n/an/aOSn/a5TheEnergyAuthority,Inc.WSPP
n/a n/aOSn/aWSPP6TheEnergyAuthority,Inc.
n/a n/an/a7TransAltaEnergyMarketing(U.S.)Inc.SF WSPP
n/an/a n/a8TransAltaEnergyMarketing(U.S.)Inc.OS WSPP
n/an/a n/aAD9PriorYearAdjustments
n/an/a n/aAD10TransmissionPenaltyDistribution
11
12
13
14
000SubtotalRQ
000Subtotalnon-RQ
000Total
Page 310.4FERCFORMNO.1 (ED.12-90)
This Report Is:
(1)[X]An Original
(2)|A Resubmission
SALES FOR RESALE (Account <147)(Continued)
Year/Period of Report
End of 2015/Q4
Date of Report
(Mo,Da,Yr)
04/15/2016
Name of Respondent
Idaho Power Company
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 (NOP)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.
REVENUE LineMegaWattHours
Sold
Total ($)
(h+i+j)Other ChargesEnergyChargesDemandCharges No.
($)($)($)
(i)(k)(g)(h)m
1178,846178,8467,511
240040050
31,7691,769
43,261,5453,261,545173,226
51.625 1,62575
623,13323,133
7819,694819,69434,376
838,53538,535
9194194-6
1024,55024,550
11
12
13
14
00000
30,887,2614,370,74826,516,51301,254,136
30,887,2614,370,74826,516,51301,254,136
Page 311.4FERCFORMNO.1 (ED.12-90)
Date of Report Year/Period of Report
(Mo,Da,Yr)
04/15/2016
Name of Respondent This Report is:
(1)X An Original
(2)_A Resubmission 2015/Q4IdahoPowerCompany
FOOTNOTE DATA
Schedule Page:310 Line No.:1 Column:b
ADM Investor Services,Inc Futures Account Document,dated May _5^ 2015
Schedule Page:310 Line No.:6 Column:b
Non-firm Sales
Schedule Page:310 Line No.:11 Column:b
Non-firm Sales
Schedule Page:310 Line No.:12 Column:b
IS DA Master Agreement with Cargill Power Markets,LLC dated June 13,2011
Schedule Page:310.1 Line No.:7 Column:b
Iberdrola Renewables,Inc,Capacity Agreement,dated January 16,2015
Schedule Page:310.1 Line No.:8 Column:b
Financial Transmission Losses _
Schedule Page:310.1 Line No.:9 Column:b
Prudential Bache Commodities (Jeffries Bache),LLC Futures Account Document,dated
September 4,2008
Schedule Page:310.1 Line No.:11 Column:b
I SPA Master Agreement with Mucqua r i e Energy,LLC dated Apr i I 12,2011
Schedule Page:310.1 Line No.:12 Column:b
Financial Transmission Losses
—I
Schedule Page:310.1 Line No.:14 Column:b
Non-firm Sales
Schedule Page:310.2 Line No.:J[Column:b
Financial Transmission Losses
Schedule Page:310.2 Line No.:3 Column:b
Non-firm Sales
Schedule Page:310.2 Line No.:4 Column:b
Financial Transmission Losses
Schedule Page:310.2 Line No.:6 Column:b
Non-firm Sales
Schedule Page:310.2 Line No.:8 Column:b
Non-firm Sales
Schedule Page:310.2 Line No.:9 Column:b
Spinning-or Operating Reserves
Schedule Page:310.2 Line No.:11 Column:b
Non-firm Sales
Schedule Page:310.2 Line No.:12 Column:b
Spinning or Operating Reserves
Schedule Page:310.2 Line No.:13 Column:b
Financial Transmission Losses
Schedule Page:310.3 Line No.:1 Column:b
Non-firm Sales
Schedule Page:310.3 Line No.:3 Column:b
Spinning or Operating Reserves
{Schedule Page:310.3 Line No.:6 Column:b
Non-firm Sales
Schedule Page:310.3 Line No.:8 Column:b
Non-firm Sales
Schedule Page:310.3 Line No.:9 Column:b
Financial Transmission Losses
Schedule Page:310.3 Line No.:10 Column:b
Spinning or Operating Reserves
Schedule Page:310.3 Line No.:13 Column:b
Financial Transmission Losses
Schedule Page:310.3 Line No.:14 Column:b
FERC FORM NO.1 (ED.12-87)Page 450.1
Date of Report Year/Period of Report
(Mo,Da,Yr)
04/15/2016
Name of Respondent This Report is:
(1)X An Original
(2)_A Resubmission 2015/Q4IdahoPowerCompany
FOOTNOTE DATA
Non-firm Sales
Schedule Page:310.4 Line No.:2 Column:b
Non-firm Sales
Schedule Page:310.4 Line No.:3 Column:b
Financial Transmission Losses
Schedule Page:310.4 Line No.:5 Column:b
Non-firm Sales
Schedule Page:310.4 Line No.:6 Column:b
Financial Transmission Losses
Schedule Page:310.4 Line No.:8 Column:b
Financial Transmission Losses
Schedule Page:310.4 Line No.:9 Column:b
Prior Year Adjustments
Schedule Page:310.4 Line No.:10 Column:b
Transmission Penalty Distribution
FERC FORM NO.1 (ED.12-87)Page 450.2
Name of Respondent
Idaho Power Company
This Report Is:
(1)[X]An Original
(2)||A Resubmission
Date of Report
(Mo,Da,Yr)
04/15/2016
Year/Period of Report
End of 2015/Q4
ELECTRIC OPERATION AND MAINTENANCE EXPENSES
If the amount for previous year is not derived from previously reported figures,explain in footnote.
Amount for
Previous Year
Line tfor
Yea
Account &,moun
urrentNo,(c)(a)(b)
1.POWER PRODUCTION EXPENSES1
2 A.Steam Power Generation
I3Operation
1,376,7094(500)Operation Supervision and Engineering
5 (501)Fuel
1,287,887
156,172,175131,286,356
6 (502)Steam Expenses 9,791,612 8,741,266
7 (503)Steam from Other Sources
8 (Less)(504)Steam Transferred-Cr,
9 (505)Electric Expenses 1,262,175 1,599,507
10 (506)Miscellaneous Steam Power Expenses 6,676,269 9,598,723
530,52011(507)Rents 432,038
12 (509)Allowances
13 TOTAL Operation (Enter Total of Lines 4 thru 12)150,736,337 178,018,900
14 Maintenance
277,88615(510)Maintenance Supervision and Engineering
16 (51 1)Maintenance of Structures
126,993
878,071 708,308
17 (512)Maintenance of Boiler Plant 13,861,559 10,923,064
6,044,95418(513)Maintenance of Electric Plant 5,412,553
6,923,251 5,806,41519(514)Maintenance of Miscellaneous Steam Plant
20 TOTAL Maintenance (Enter Total of Lines 15 thru 19)27,202,427 23,760,627
201,779,52721TOTALPowerProductionExpenses-Steam Power (Entr Tot lines 1 3 &20)177,938,764
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
5,700,46044(535)Operation Supervision and Engineering
45 (536)Water for Power
5,798,402
9,070,347 7,316,134
46 (537)Hydraulic Expenses
47 (538)Electric Expenses
14,907,949 14,097,825
1,530,4531,623,508
5,675,338 5,732,59148(539)Miscellaneous Hydraulic Power Generation Expenses
235,266 259.70549(540)Rents
50 TOTAL Operation (Enter Total of Lines 44 thru 49)37,310,810 34,637,168
51 C.Hydraulic Power Generation (Continued)
52 Maintenance
53 (541)Mainentance Supervision and Engineering 120,335 122,182
1,120,484 1,387,36954(542)Maintenance of Structures
575,444 366,30755(543)Maintenance of Reservoirs,Dams,and Waterways
2,279,58456(544)Maintenance of Electric Plant 2,655,929
2,860,095 2,554,63857(545)Maintenance of Miscellaneous Hydraulic Plant
6,710,08058TOTALMaintenance(Enter Total of lines 53 thru 57)7,332,287
59 TOTAL Power Production Expenses-Hydraulic Power (tot of lines 50 &58)44,643,097 41,347,248
Page 320FERCFORMNO.1 (ED.12-93)
Name of Respondent
Idaho Power Company
Date of Report
(Wo,Da,Yr)
04/15/2016
Year/Period of Report
End of 2015/Q4
This Report Is:
(1)pg An Original
(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.
Amount for
Previous YearLineAccountTnoun
urrent
or
earNo.(a)(b)(c)
60 D.Other Power Generation
61 Operation
813,87562(546)Operation Supervision and Engineering 646,633
45,068,83163(547)Fuel 54,944,643
64 (548)Generation Expenses 4,603,907 3,596,219
905,57465(549)Miscellaneous Other Power Generation Expenses
66 (550)Rents
934,376
67 TOTAL Operation (Enter Total of lines 62 thru 66)61,129,559 50,384,499
68 Maintenance
69 (551)Maintenance Supervision and Engineering
70 (552)Maintenance of Structures 363,695 378,067
71 (553)Maintenance of Generating and Electric Plant
72 (554)Maintenance of Miscellaneous Other Power Generation Plant
71,909 86,516
1,391,4281,270,216
1,856,01173TOTALMaintenance(Enter Total of lines 69 thru 72)1,705,820
74 TOTAL Power Production Expenses-Other Power (Enter Tot of 67 &73)62,835,379 52,240,510
75 E.Other Power Supply Expenses
237,121,89976(555)Purchased Power 217,596,604
77 (556)System Control and Load Dispatching
78 (557)Other Expenses
2,436 -1,242
20,615,245 25,139,587
262,260,24479TOTALOtherPowerSupplyExp(Enter Total of lines 76 thru 78)
80 TOTAL Power Production Expenses (Total of lines 21,41,59,74 &79)
238,214,285
523,631,525 557,627,529
2.TRANSMISSION EXPENSES81
82 Operation
83 (560)Operation Supervision and Engineering 4,136,382 4,019,284
84
55,42585(561.1)Load Dispatch-Reliability
86 (561.2)Load Dispatch-Monitor and Operate Transmission System
87 (561.3)Load Dispatch-Transmission Service and Scheduling
1,757,323 1,673,701
926,5551,159,643
88 (561 .4)Scheduling,System Control and Dispatch Services
89 (561.5)Reliability,Planning and Standards Development
90 (561 .6)Transmission Service Studies
91 (561.7)Generation Interconnection Studies 21,585 38,422i
92 (561 .8)Reliability,Planning and Standards Development Services
93 (562)Station Expenses
94 (563)Overhead Lines Expenses
2,633,328 2,458,270
669,240967,338
95 (564)Underground Lines Expenses
96 (565)Transmission of Electricity by Others 6,279,133 6,081,299
18,27497(566)Miscellaneous Transmission Expenses 2,365
3,284,85098(567)Rents 3,084,849
99 TOTAL Operation (Enter Total of lines 83 thru 98)20,041,946 19,225,320
100 Maintenance
169,505101(568)Maintenance Supervision and Engineering
1 02 (569)Maintenance of Structures
157,051
26,64512,690
103 (569.1)Maintenance of Computer Hardware 23,408 9,454
960,142104(569.2)Maintenance of Computer Software 867,398
42,031105(569.3)Maintenance of Communication Equipment
106 (569.4)Maintenance of Miscellaneous Regional Transmission Plant
107 (570)Maintenance of Station Equipment
29,123
3,702,5503,286,329
3,198,420108(571)Maintenance of Overhead Lines 2,935,312
109 (572)Maintenance of Underground Lines
110 (573)Maintenance of Miscellaneous Transmission Plant 1,593
8,110,340111TOTALMaintenance(Total of lines 101 thru 110)7,311,311
112 TOTAL Transmission Expenses (Total of lines 99 and 111)27,353,257 27,335,660
Page 321FERCFORMNO.1 (ED.12-93)
Year/Period of ReportNameofRespondent
Idaho Power Company
This Report Is:
(1)m An Original
(2)A Resubmission
ELECTRIC OPERATION AND MAINTENANCE EXPENSES (Continued)
Date of Report
(Mo,Da,Yr)
04/15/2016
2015/Q4Endof
If the amount for previous year is not derived from previously reported figures,explain in footnote.
Amount forPreviousYear&Line Account moun
urrent
or
earNo.(c)(a)(b)
113 3.REGIONAL MARKET EXPENSES
114 Operation
115 (575.1)Operation Supervision
116 (575.2)Day-Ahead and Real-Time Market Facilitation
117 (575.3)Transmission Rights Market Facilitation
1 1 8 (575.4)Capacity Market Facilitation
119 (575.5)Ancillary Services Market Facilitation
120 (575.6)Market Monitoring and Compliance
121 (575.7)Market Facilitation,Monitoring and Compliance Services
122 (575.8)Rents
123 Total Operation (Lines 115 thru 122)
124 Maintenance
125 (576.1)Maintenance of Structures and Improvements
126 (576.2)Maintenance of Computer Hardware
127 (576.3)Maintenance of Computer Software
128 (576.4)Maintenance of Communication Equipment
129 (576.5)Maintenance of Miscellaneous Market Operation Plant
130 Total Maintenance (Lines 125 thru 129)
131 TOTAL Regional Transmission and Market Op Expns (Total 123 and 130)
132 4.DISTRIBUTION EXPENSES
133 Operation
4,289,300 4,028,859134(580)Operation Supervision and Engineering
135 (581)Load Dispatching 3,643,1333,897,253
1,339,544 1,180,321136(582)Station Expenses
3,968,009 3,138,798137(583)Overhead Line Expenses
2,525,0082,889,346138(584)Underground Line Expenses
87,956 76,902,1 39 (585)Street Lighting and Signal System Expenses
4,769,220 4,424,696140(586)Meter Expenses
784,157 694,859141(587)Customer Installations Expenses
142 (588)Miscellaneous Expenses 6,041,032 5,788,865
466,127262,071143(589)Rents
28,327,888 25,967,568144TOTALOperation(Enter Total of lines 134 thru 143)
145 Maintenance
16,45110,627146(590)Maintenance Supervision and Engineering
1 47 (591 )Maintenance of Structures
3,950,8243,630,618148(592)Maintenance of Station Equipment
14,203,471 13,906,165149(593)Maintenance of Overhead Lines
604,456 630,375150(594)Maintenance of Underground Lines
151 (595)Maintenance of Line Transformers 148,12536,603
486,847 531,740152(596)Maintenance of Street Lighting and Signal Systems
767,987 735,448
418,635
1 53 (597)Maintenance of Meters
289,620154(598)Maintenance of Miscellaneous Distribution Plant
20,337,763155TOTALMaintenance(Total of lines 146 thru 154)20,030,229
48,358,117 46,305,331156TOTALDistributionExpenses(Total of lines 144 and 155)
157 5.CUSTOMER ACCOUNTS EXPENSES
158 Operation
484,451 503,846159(901)Supervision
1,843,348 1,698,642160(902)Meter Reading Expenses
15,508,388 16,630,398161(903)Customer Records and Collection Expenses
3,319,967 6,715,796162(904)Uncollectible Accounts
395 95163(905)Miscellaneous Customer Accounts Expenses
21,156,549 25,548,777164TOTALCustomerAccountsExpenses(Total of lines 159 thru 163)
Page 322FERCFORMNO.1 (ED.12-93)
Year/Period of Report
End of 2015/Q4
Name of Respondent
Idaho Power Company
This Report Is:
(1)[X]An Original
(2)|A Resubmission
ELECTRIC OPERATION AND MAINTENANCE EXPENSES (Continued)
Date of Report
(Mo,Da,Yr)
04/15/2016
If the amount for previous year is not derived from previously reported figures,explain in footnote.
Amount for
Previous Year£VLineAccountmounurrentor
earNo.(c)(a)(b)
165 6.CUSTOMER SERVICE AND INFORMATIONAL EXPENSES
166 Operation
167 (907)Supervision 593,673807,713
34,149,782168(908)Customer Assistance Expenses 37,606,989
374,524169(909)Informational and Instructional Expenses 424,680
696,365735,552170(910)Miscellaneous Customer Service and Informational Expenses
35,814,344171TOTALCustomerServiceandInformationExpenses(Total 167 thru 170)39,574,934
7.SALES EXPENSES172
173 Operation
174 (91 1 )Supervision
175 (912)Demonstrating and Selling Expenses
176 (913)Advertising Expenses
79,720
177 (916)Miscellaneous Sales Expenses
178 TOTAL Sales Expenses (Enter Total of lines 174 thru 177)79,720
179 8.ADMINISTRATIVE AND GENERAL EXPENSES
180 Operation
73,163,83773,062,858181(920)Administrative and General Salaries
17,437,094182(921)Office Supplies and Expenses 14,719,911
26,120,468 27,257,584183(Less)(922)Administrative Expenses Transferred-Credit
4,705,1468,177,858184(923)Outside Services Employed
3,461,411185(924)Property Insurance 3,382,607
6,125,0556,644,800186(925)Injuries and Damages
187 (926)Employee Pensions and Benefits
188 (927)Franchise Requirements
61,971,16945,004,540
3,457,8383,616,257189(928)Regulatory Commission Expenses
190 (929)(Less)Duplicate Charges-Cr.
453,160191(930.1)General Advertising Expenses 618,107
4,907,4155,444,853192(930.2)Miscellaneous General Expenses
176193(931)Rents 2,000
148,424,717134,553,323194TOTALOperation(Enter Total of lines 181 thru 193)
195 Maintenance
7,508,482196(935)Maintenance of General Plant 5,817,078
197 TOTAL Administrative &General Expenses (Total of lines 194 and 196)155,933,199140,370,401
848,564,840198TOTALElecOpandMaintExpns(Total 80,1 12,1 31 ,156,1 64,1 71 ,1 78,1 97)800,524,503
Page 323FERCFORMNO.1 (ED.12-93)
This Report Is:
(1)[xjAn Original
(2)J 'A Resubmission
RCHASED POWER (Account 555)
(Including power exchanges)
Name of Respondent
Idaho Power Company
Date of Report
(Mo.Da,Yr)
04/15/2016
Year/Period of Report
End of 2015/Q4
PU
1 .Report all power purchases made during the year.Also report exchanges of electricity (i.e.,transactions involving a balancing of
debits and credits for energy,capacity,etc.)and any settlements for imbalanced exchanges.
2.Enter the name of the seller or other party in an exchange transaction in column (a).Do not abbreviate or truncate the name or use
acronyms.Explain in a footnote any ownership interest or affiliation the respondent has with the seller.
3.In column (b),enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows:
RQ -for requirements service.Requirements service is service which the supplier plans to provide on an ongoing basis (i.e.,the
supplier includes projects load for this service in its system resource planning).In addition,the reliability of requirement service must
be the same as,or second only to,the supplier's service to its own ultimate consumers.
LF -for long-term firm service."Long-term"means five years or longer and "firm"means that service cannot be interrupted for
economic reasons and is intended to remain reliable even under adverse conditions (e.g.,the supplier must attempt to buy emergency
energy from third parties to maintain deliveries of LF service).This category should not be used for long-term firm service firm service
which meets the definition of RQ service.For all transaction identified as LF,provide in a footnote the termination date of the contract
defined as the earliest date that either buyer or seller can unilaterally get out of the contract.
IF -for intermediate-term firm service.The same as LF service expect that "intermediate-term"means longer than one year but less
than five years.
SF -for short-term service.Use this category for all firm services,where the duration of each period of commitment for service is one
year or less.
LU -for long-term service from a designated generating unit."Long-term"means five years or longer.The availability and reliability of
service,aside from transmission constraints,must match the availability and reliability of the designated unit.
IU -for intermediate-term service from a designated generating unit.The same as LU service expect that "intermediate-term"means
longer than one year but less than five years.
EX -For exchanges of electricity.Use this category for transactions involving a balancing of debits and credits for energy,capacity,etc.
and any settlements for imbalanced exchanges.
OS -for other service.Use this category only for those services which cannot be placed in the above-defined categories,such as all
non-firm service regardless of the Length of the contract and service from designated units of Less than one year.Describe the nature
of the service in a footnote for each adjustment.
Actual Demand (MW)Statistical
Classifi
cation
FERC Rate
Schedule or
Tariff Number
Average
Monthly Billing
Demand (MW)
Name of Company or Public Authority
(Footnote Affiliations)
Line
Average
Monthly NCP Demand Monthly CP Demand
AverageNo.
(a)(b)(c)(d)(e)(f)
1 AgPower Jerome /Double A Digester LU N/A N/A N/A
2 Allan Ravenscroft/Malad River LU .488Mw
3 Baker City Hydro LU N/A N/A N/A
4 Bannock County,Idaho N/A N/ALU N/A
5 Bennett Creek Wind Farm N/ALU N/A N/A
6 Bettencourt DryCreek Biofactory LU N/A N/A N/A
7 Big Sky West Dairy Digester LU N/A N/A N/A
8 Big Wood Canal Company
9 Black Canyon #3 N/ALU N/A N/A
10 Jim Knight LU N/A N/A N/A
1 1 Sagebrush LU N/A N/A N/A
12 Black Canyon Bliss N/A N/ALU N/A
13 Blind Canyon Hydro N/ALU N/A N/A
14 Branchflower/Trout Company LU N/A N/A N/A
Total
Page 326FERCFORMNO.1 (ED.12-90)
This Report Is:
[X]An Original
Year/Period of Report
End of 2015/Q4
Date of Report
(Mo,Da,Yr)
04/15/2016
Name of Respondent
Idaho Power Company (1)
B(2)A Resubmission
PURCHASED POWER(Account 5S5)(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.
COST/SETTLEMENT OF POWERPOWEREXCHANGES LineMegaWattHours
Purchased Total (j+k+l)
of Settlement ($)
Demand Charges Energy Charges Other ChargesMegaWattHours
Received
MegaWatt Hours
Delivered
No.
ffi (?)(?)(m)(I)(h)(i)G)(g)
12,160,8572,160,85725,577
2213,55957,887155,6721,401
310,69510,695278
4434,633434,6338,705
52,210,264 2,210,26435,670
6790,198790,19810,600
7545,582545,5828,739
8
918,42018,420257
1069,79969,799951
1162,07062,070832
121,0941,09442
13184,552184,5523,972
1449,39649,396688
204,436,381 10,345,099 217,596,6042,815,124276,510 162,2393,788,934
Page 327FERCFORMNO.1 (ED.12-90)
This Report is:
[^]An Original
Name of Respondent
Idaho Power Company
Date of Report
(Mo,Da,Yr)
04/15/2016
Year/Period of Report
End of 2015/Q4(1)
(2)||A Resubmission
pumn?ppoMAa™t555)
1 .Report all power purchases made during the year.Also report exchanges of electricity (i.e.,transactions involving a balancing of
debits and credits for energy,capacity,etc.)and any settlements for imbalanced exchanges.
2.Enter the name of the seller or other party in an exchange transaction in column (a).Do not abbreviate or truncate the name or use
acronyms.Explain in a footnote any ownership interest or affiliation the respondent has with the seller.
3.In column (b),enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows:
RQ -for requirements service.Requirements service is service which the supplier plans to provide on an ongoing basis (i.e.,the
supplier includes projects load for this service in its system resource planning).In addition,the reliability of requirement service must
be the same as,or second only to,the supplier's service to its own ultimate consumers.
LF -for long-term firm service."Long-term"means five years or longer and "firm"means that service cannot be interrupted for
economic reasons and is intended to remain reliable even under adverse conditions (e.g.,the supplier must attempt to buy emergency
energy from third parties to maintain deliveries of LF service).This category should not be used for long-term firm service firm service
which meets the definition of RQ service.For all transaction identified as LF,provide in a footnote the termination date of the contract
defined as the earliest date that either buyer or seller can unilaterally get out of the contract.
IF -for intermediate-term firm service.The same as LF service expect that "intermediate-term"means longer than one year but less
than five years.
SF -for short-term service.Use this category for all firm services,where the duration of each period of commitment for service is one
year or less.
LU -for long-term service from a designated generating unit."Long-term"means five years or longer.The availability and reliability of
service,aside from transmission constraints,must match the availability and reliability of the designated unit.
IU -for intermediate-term service from a designated generating unit.The same as LU service expect that "intermediate-term"means
longer than one year but less than five years.
EX -For exchanges of electricity.Use this category for transactions involving a balancing of debits and credits for energy,capacity,etc.
and any settlements for imbalanced exchanges.
OS -for other service.Use this category only for those services which cannot be placed in the above-defined categories,such as all
non-firm service regardless ofthe 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.
Actual Demand (MW)
Average
Statistical
Classifi
cation
FERC Rate
Schedule or
Tariff Number
AverageNameofCompanyorPublicAuthority
(Footnote Affiliations)
Line Monthly Billing
Demand (MW)
Average
Monthly NCP Demand Monthly CP DemandNo.
(e)(f)(a)(b)(c)(d)
LU N/A N/A N/A1BurleyButteWindPark
LU N/A N/A N/A2BypassLimited
N/A N/A N/A3CampReedWindParkLU
N/A N/A4Cargilllnc./B6 Anaerobic Digester LU N/A
N/A N/A5CassiaGulchWindParkLUN/A
6 Cassia Wind Farm LU N/A N/A N/A
N/A N/A N/A7CityofCove,Oregon /Mill Creek LU
N/A N/A8CityofHaileyLUN/A
N/A9CityofPocatelloLUN/A N/A
LU N/A N/A N/A10ClearSpringsFoodInc.
11 Clifton E.Jenson/Birch Creek LU .05 Mw
N/A N/A12ColdSpringsWindfarm,LLC LU N/A
13 Consolidated Hydro Inc./Enel
LU N/A N/A N/A14BarberDam
Total
Page 326.1FERCFORMNO.1 (ED.12-90)
This Report Is:
(1)fx]An Original
(2)I A Resubmission
Name of Respondent
Idaho Power Company
Date of Report
(Mo,Da,Yr)
04/15/2016
Year/Period of Report
End of 2015/Q4
PURCHASED 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 POWER LineMegaWattHours
Purchased MegaWatt Hours
Received
MegaWatt Hours
Delivered
Demand Charges Energy Charges Other Charges Total (j+k+l)
of Settlement ($)No.
($)($)
(i)(j)(k.(I)(m)(g)(h)
12,888,444 2,888,44451,243
21,463,91527,344 1,463,915
34,403,82352,909 4,403,823
4732,5818,474 732,581
5
6978,06120,563 978,061
73,479 244,601 244,601
81,076151,076
984,4731,133 84,473
10332,8953,420 332,895
1117,500 31,56234014,062
123,049,70344,366 3,049,703
13
149,370 485,620 485,620
217,596,6043,788,934 276,510 162,239 2,815,124 204,436,381 10,345,099
Page 327.1FERCFORMNO.1 (ED.12-90)
This Report Is:
(1)f)T|An Original
(2)[A Resubmission
RCHASED POWER (Account 555)
(Including power exchanges)
Name of Respondent
Idaho Power Company
Date of Report
(Mo.Da,Yr)
04/15/2016
Year/Period of Report
End of 2015/Q4
PU
1 .Report all power purchases made during the year.Also report exchanges of electricity (i.e.,transactions involving a balancing of
debits and credits for energy,capacity,etc.)and any settlements for imbalanced exchanges.
2.Enter the name of the seller or other party in an exchange transaction in column (a).Do not abbreviate or truncate the name or use
acronyms.Explain in a footnote any ownership interest or affiliation the respondent has with the seller.
3.In column (b),enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows:
RQ -for requirements service.Requirements service is service which the supplier plans to provide on an ongoing basis (i.e.,the
supplier includes projects load for this service in its system resource planning).In addition,the reliability of requirement service must
be the same as,or second only to,the supplier's service to its own ultimate consumers.
LF -for long-term firm service."Long-term"means five years or longer and "firm"means that service cannot be interrupted for
economic reasons and is intended to remain reliable even under adverse conditions (e.g.,the supplier must attempt to buy emergency
energy from third parties to maintain deliveries of LF service).This category should not be used for long-term firm service firm service
which meets the definition of RQ service.For all transaction identified as LF,provide in a footnote the termination date of the contract
defined as the earliest date that either buyer or seller can unilaterally get out of the contract.
IF -for intermediate-term firm service.The same as LF service expect that "intermediate-term"means longer than one year but less
than five years.
SF -for short-term service.Use this category for all firm services,where the duration of each period of commitment for service is one
year or less.
LU -for long-term service from a designated generating unit."Long-term"means five years or longer.The availability and reliability of
service,aside from transmission constraints,must match the availability and reliability of the designated unit.
IU -for intermediate-term service from a designated generating unit.The same as LU service expect that "intermediate-term"means
longer than one year but less than five years.
EX -For exchanges of electricity.Use this category for transactions involving a balancing of debits and credits for energy,capacity,etc.
and any settlements for imbalanced exchanges.
OS -for other service.Use this category only for those services which cannot be placed in the above-defined categories,such as all
non-firm service regardless of the Length of the contract and service from designated units of Less than one year.Describe the nature
of the service in a footnote for each adjustment.
Actual Demand (MW)
Average
Monthly NCP Demand Monthly CP Demand
Statistical
Classifi
cation
FERC Rate
Schedule or
Tariff Number
Average
Monthly Billing
Demand (MW)
Name of Company or Public Authority
(Footnote Affiliations)
Line
AverageNo.
(a)(c)(f)(b)(d)(e)
1 Dietrich Drop LU N/A N/A N/A
2 GeoBon #2 LU N/A N/A N/A
3 Lowline #2 N/A N/A N/ALU
4 Rock Creek #2 N/A N/ALUN/A
5 Contractors Power Group Inc./Mile 28 N/ALUN/A N/A
6 Crystal Springs Hydro LU N/A N/A N/A
7 Curry Cattle Company LU .084Mw
8 David McCollum/Canyon Springs N/A N/ALUN/A
9 David R Snedigar LU N/A N/A N/A
10 Desert Meadow Wind Farm LU N/A N/A N/A
1 1 Eightmile Hydro Corp N/A N/A N/ALU
12 Faulkner Brothers Hydro Inc.N/A N/ALUN/A
OS13FisheriesDevelopment N/A N/A N/A
14 Fossil Gulch Wind LU N/A N/A N/A
Total
Page 326.2FERCFORMNO.1 (ED.12-90)
Name of Respondent
Idaho Power Company
This Report Is:
(1)fx]An Original
(2)HA Resubmission
Date of Report
{Mo,Da,Yr)
04/15/2016
Year/Period of Report
End of 2015/Q4
D POWERjAccoun^555^^(Continued)PUR'CHA
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 (NOP)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.
COST/SETTLEMENT OF POWERPOWEREXCHANGES LineMegaWattHours
Purchased Demand Charges Energy Charges Other Charges Total (j+k+l)
of Settlement ($)
MegaWatt Hours
Received
MegaWatt Hours
Delivered
No.
($)($)(m)(j)(k:(I)(g)(h)(i)
1802,944 802,94414,262
2228,100 228,1003,031
3537,227537,22710,091
4328,832 328,8326,250
5337,984 337,9844,766
6659,848659,8489,621
757,53774426,796 30,741
88,0748,074482
997,333 97,3331,386
103,531,906 3,531,90651,328
1175,76575,7651,378
12274,398 274,3983,540
1319,937 19,9371,205
141,245,178 1,245,17821,790
204,436,381 10,345,099 217,596,604162,239 2,815,1243,788,934 276,510
Page 327.2FERCFORMNO.1 (ED.12-90)
Name of Respondent
Idaho Power Company
This Report Is:
(1)[XjAn Original
(2)[A Resubmission
PURCHASED POWER (/(Including power excb
?ate of Report
(Mo.Da,Yr)
04/15/2016
Year/Period of Report
End of 2015/Q4
Accoui
anges
rjt 555)
1 .Report all power purchases made during the year.Also report exchanges of electricity (i.e.,transactions involving a balancing of
debits and credits for energy,capacity,etc.)and any settlements for imbalanced exchanges.
2.Enter the name of the seller or other party in an exchange transaction in column (a).Do not abbreviate or truncate the name or use
acronyms.Explain in a footnote any ownership interest or affiliation the respondent has with the seller.
3.In column (b),enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows:
RQ -for requirements service.Requirements service is service which the supplier plans to provide on an ongoing basis (i.e.,the
supplier includes projects load for this service in its system resource planning).In addition,the reliability of requirement service must
be the same as,or second only to,the supplier's service to its own ultimate consumers.
LF -for long-term firm service."Long-term"means five years or longer and "firm"means that service cannot be interrupted for
economic reasons and is intended to remain reliable even under adverse conditions (e.g.,the supplier must attempt to buy emergency
energy from third parties to maintain deliveries of LF service).This category should not be used for long-term firm service firm service
which meets the definition of RQ service.For all transaction identified as LF,provide in a footnote the termination date of the contract
defined as the earliest date that either buyer or seller can unilaterally get out of the contract.
IF -for intermediate-term firm service.The same as LF service expect that "intermediate-term"means longer than one year but less
than five years.
SF -for short-term service.Use this category for all firm services,where the duration of each period of commitment for service is one
year or less.
LU -for long-term service from a designated generating unit."Long-term"means five years or longer.The availability and reliability of
service,aside from transmission constraints,must match the availability and reliability of the designated unit.
IU -for intermediate-term service from a designated generating unit.The same as LU service expect that "intermediate-term"means
longer than one year but less than five years.
EX -For exchanges of electricity.Use this category for transactions involving a balancing of debits and credits for energy,capacity,etc.
and any settlements for imbalanced exchanges.
OS -for other service.Use this category only for those services which cannot be placed in the above-defined categories,such as all
non-firm service regardless of the Length of the contract and service from designated units of Less than one year.Describe the nature
of the service in a footnote for each adjustment.
Actual Demand (MW)Statistical
Classifi
cation
FERC Rate
Schedule or
Tariff Number
Average
Monthly Billing
Demand (MW)
Name of Company or Public Authority
(Footnote Affiliations)
Line
Average Average
Monthly NCP Demand Monthly CP DemandNo.
(d)(e)(f)(a)(b)(c)
N/A N/A1G2EnergyHiddenHollowLUN/A
N/A2GoldenValleyWindParkN/A N/ALU
3 Hammett Hill Windfarm,LLC N/A N/A N/ALU
4 Hazelton B Power Company N/A N/A N/ALU
N/A N/A N/A5HeadofUCanalLU
N/A N/AN/A6HighMesaEnergyLU
7 H.K.Hydro Mud Creek S &S N/A N/A N/ALU
N/A N/A N/A8HorseshoeBendHydroLU
N/A N/A9HorseshoeBendWind/United Materials LU N/A
N/A N/A10HotSpringsWindFarmN/ALU
1 1 Idaho Winds /Sawtooth Wind Project N/A N/A N/ALU
N/A N/A N/A12JRSimplotCo.LU
N/A N/A13J.M.Miller/Sahko Hydro LU N/A
N/A N/A14JamesB.Howell /CHI Elk Creek LU N/A
Total
Page 326.3FERCFORMNO.1 (ED.12-90)
Date of Report
(Mo.Da,Yr)
04/15/2016
This Report Is:
(1)[X|An Original
(2)A Resubmission
Year/Period of Report
End of 2015/Q4
Name of Respondent
Idaho Power Company
SED POWER(Accounl 555)(Contmued)f ncluding power exchanges) PURCHA
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.
COST/SETTLEMENT OF POWERPOWEREXCHANGES LineMegaWattHours
Purchased MegaWatt Hours
Delivered
Demand Charges Energy Charges Other Charges Total (j+k+l)
of Settlement ($)
MegaWatt Hours
Received
No.
($)($)
(I)(m)0)(k:(g)(h)(i)
11,347,228 1,347,22821,162
21,625,86028,758 1,625,860
33,479,3773,479,37750,491
41,651,8241,651,82423,244
5273,969 273,9693,449
63,911,669 3,911,66980,916
7137,200 137,2001,605
83,015,6883,015,68842,403
9881,159 881,15915,404
102,041,07233,111 2,041,072
113,952,3923,952,39249,976
124,288,2634,288,26380,768
1393,768 93,7681,244
14265,983 265,9834,181
217,596,604204,436,381 10,345,099162,239 2,815,1243,788,934 276,510
Page 327.3FERCFORMNO.1 (ED.12-90)
This Report Is:
(1)|x|An Original
(2)||A Resubmission
PURCHASED POWER (Account 555)
(Including power exchanges)
Year/Period of Report
End of 2015/Q4
Date of Report
(Mo,Da,Yr)
04/15/2016
Name of Respondent
Idaho Power Company
1.Report all power purchases made during the year.Also report exchanges of electricity (i.e.,transactions involving a balancing of
debits and credits for energy,capacity,etc.)and any settlements for imbalanced exchanges.
2.Enter the name of the seller or other party in an exchange transaction in column (a).Do not abbreviate or truncate the name or use
acronyms.Explain in a footnote any ownership interest or affiliation the respondent has with the seller.
3.In column (b),enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows:
RQ -for requirements service.Requirements service is service which the supplier plans to provide on an ongoing basis (i.e.,the
supplier includes projects load for this service in its system resource planning).In addition,the reliability of requirement service must
be the same as,or second only to,the supplier's service to its own ultimate consumers.
LF -for long-term firm service."Long-term"means five years or longer and "firm"means that service cannot be interrupted for
economic reasons and is intended to remain reliable even under adverse conditions (e.g.,the supplier must attempt to buy emergency
energy from third parties to maintain deliveries of LF service).This category should not be used for long-term firm service firm service
which meets the definition of RQ service.For all transaction identified as LF,provide in a footnote the termination date of the contract
defined as the earliest date that either buyer or seller can unilaterally get out of the contract.
IF -for intermediate-term firm service.The same as LF service expect that "intermediate-term"means longer than one year but less
than five years.
SF -for short-term service.Use this category for all firm services,where the duration of each period of commitment for service is one
year or less.
LU -for long-term service from a designated generating unit."Long-term"means five years or longer.The availability and reliability of
service,aside from transmission constraints,must match the availability and reliability of the designated unit.
IU -for intermediate-term service from a designated generating unit.The same as LU service expect that "intermediate-term"means
longer than one year but less than five years.
EX -For exchanges of electricity.Use this category for transactions involving a balancing of debits and credits for energy,capacity,etc.
and any settlements for imbalanced exchanges.
OS -for other service.Use this category only for those services which cannot be placed in the above-defined categories,such as all
non-firm service regardless of the Length of the contract and service from designated units of Less than one year.Describe the nature
of the service in a footnote for each adjustment.
Actual Demand (MW)
Average
Statistical
Classifi
cation
FERC Rate
Schedule or
Tariff Number
Average
Monthly Billing
Demand (MW)
Name of Company or Public Authority
(Footnote Affiliations)
Line Average
Monthly NCP Demand Monthly CP DemandNo.
(e)(f)(d)(b)(c)(a)
N/AN/ALUN/A1JohnRLeMoyne
N/AN/AN/A2Kasel&Witherspoon LU
N/AN/AN/A3KootenaiElectricCooperative/Fighti LU
N/AN/A N/ALU4KoyleHydroInc.
N/AN/ALUN/A5Lateral10Ventures
N/AN/AN/A6LemhiHydroPowerCo./Schaffner LU
N/AN/AN/ALU7LimeWind
N/AN/AN/ALU8LittleMacPowerCo./Cedar Draw
N/AN/A N/ALU9LittleWoodRiverIrrigationDistrict
N/AN/AN/ALU10MagicReservoirHydro
N/AN/AN/ALU11MainlineWindfarm
N/AN/A N/ALU12MarcoRancher's Irrigation Inc.
N/AN/A131MarysvilleHydroPartners/Falls River LU N/A
N/AN/AN/A14LUMilnerDamWindPark
Total
Page 326.4FERCFORMNO.1 (ED.12-90)
This Report Is:
X]An Original
Name of Respondent
Idaho Power Company
Year/Period of Report
End of 2015/Q4
Date of Report
(Mo,Da,Yr)
04/15/2016
(1)
PUftCHASlD
(2)A Resubmission
POWER(Account 555)(Continued)(ncluding power exchanges)
AD -for out-of-period adjustment.Use this code for any accounting adjustments or "true-ups"for service provided in prior 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.
COST/SETTLEMENT OF POWERPOWEREXCHANGES LineMegaWattHours
Purchased Total G+k+l)
of Settlement ($)
Demand Charges Energy Charges Other ChargesMegaWattHours
Received
MegaWatt Hours
Delivered
No.
($)($)(m)(I)(j)(k.(g)(h)(i)
135,83635,836644
2307,307307,3073,429
3960,262960,26211,750
4235,927235,9272,494
5383,764383,7645,927
688,57888,5781,188
7448,194448,1946,089
8358,462358,4625,460
9166,850166,8502,298
10279,222279,2225,570
113,328,9703,328,97048,257
12211,453211,4533,021
132,564,1602,564,16040,347
142,640,4932,640,49347,105
217,596,604204,436,381 10,345,099162,239 2,815,1243,788,934 276,510
Page 327.4FERCFORMNO.1 (ED.12-90)
This Report Is:
(1)[x]An Original
(2)[~~|A Resubmission
RCHASED POWER (Account 555)
(Including power exchanges)
Year/Period of Report
End of 2015/Q4
Date of Report
(Mo,Da,Yr)
04/15/2016
Name of Respondent
Idaho Power Company
PU
1 .Report all power purchases made during the year.Also report exchanges of electricity (i.e.,transactions involving a balancing of
debits and credits for energy,capacity,etc.)and any settlements for imbalanced exchanges.
2.Enter the name of the seller or other party in an exchange transaction in column (a).Do not abbreviate or truncate the name or use
acronyms.Explain in a footnote any ownership interest or affiliation the respondent has with the seller.
3.In column (b),enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows:
RQ -for requirements service.Requirements service is service which the supplier plans to provide on an ongoing basis (i.e.,the
supplier includes projects load for this service in its system resource planning).In addition,the reliability of requirement service must
be the same as,or second only to,the supplier's service to its own ultimate consumers.
LF -for long-term firm service."Long-term"means five years or longer and "firm"means that service cannot be interrupted for
economic reasons and is intended to remain reliable even under adverse conditions (e.g.,the supplier must attempt to buy emergency
energy from third parties to maintain deliveries of LF service).This category should not be used for long-term firm service firm service
which meets the definition of RQ service.For all transaction identified as LF,provide in a footnote the termination date of the contract
defined as the earliest date that either buyer or seller can unilaterally get out of the contract.
IF -for intermediate-term firm service.The same as LF service expect that "intermediate-term"means longer than one year but less
than five years.
SF -for short-term service.Use this category for all firm services,where the duration of each period of commitment for service is one
year or less.
LU -for long-term service from a designated generating unit."Long-term"means five years or longer.The availability and reliability of
service,aside from transmission constraints,must match the availability and reliability of the designated unit.
IU -for intermediate-term service from a designated generating unit.The same as LU service expect that "intermediate-term"means
longer than one year but less than five years.
EX -For exchanges of electricity.Use this category for transactions involving a balancing of debits and credits for energy,capacity,etc.
and any settlements for imbalanced exchanges.
OS -for other service.Use this category only for those services which cannot be placed in the above-defined categories,such as all
non-firm service regardless of the Length of the contract and service from designated units of Less than one year.Describe the nature
of the service in a footnote for each adjustment.
Actual Demand (MW)FERC Rate
Schedule or
Tariff Number
Average
Monthly Billing
Demand (MW)
Statistical
Classifi
cation
Name of Company or Public Authority
(Footnote Affiliations)
Line Average
Monthly NCP Demand Monthly CP Demand
AverageNo.
(f)(d)(e)(a)(b)(c)
N/AN/A N/A1MudCreekWhiteHydro,Inc LU
N/AN/AN/A2NewEnergyOne/Rock Creek Dairy LU
N/AN/A N/A3OregonTrailWindParkLU
4 Owyhee Irrigation District
N/AN/A N/A5MitchellButteLU
N/AN/A N/A6OwyheeDamLU
N/AN/AN/ATunnel#1 LU7
N/AN/A N/A8PaynesFerryWindParkLU
1.389Mw9PigeonCovePowerLU
N/AN/AN/A10PilgrimStageStationWindParkLU
N/AN/A N/A11PristineSpringsInc#1 LU
N/AN/A N/A12PristineSpringsInc.#3 LU
N/AN/A N/A13ReynoldsIrrigationDistrictLU
14 Richard Kaster
Total
Page 326.5FERCFORMNO.1 (ED.12-90)
This Report Is:
(1)[x]An Original
(2)I A Resubmission
Date of Report
(Mo,Da,Yr)
04/15/2016
Year/Period of Report
End of 2015/Q4
Name of Respondent
Idaho Power Company
SED POWfERfAccount 555}(Continued)[Including power exchanges)
FUKCFIa
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 (NOP)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 ofthe 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.
COST/SETTLEMENT OF POWERPOWEREXCHANGES LineMegaWattHours
Purchased Demand Charges Energy Charges Other Charges Total (j+k+l)
of Settlement ($)
MegaWatt Hours
Received
MegaWatt Hours
Delivered
No.
($)($)
(I)(m)(h)(')0)(k.(g)
134,652 34,652495
29,546 410,768 410,768
31,701,01530,428 1,701,015
4
533,412 33,4121,076
6215,727 215,7278,507
7
84,335,83351,718 4,335,833
9322,895 809,0458,982 486,150
101,577,456 1,577,45628,014
1146,69446,694766
1275,18875,1881,289
13104,822 104,8221,394
14
2,815,124 204,436,381 10,345,099 217,596,6043,788,934 276,510 162,239
Page 327.5FERCFORMNO.1 (ED.12-90)
This Report is:
[X]An Original
Name of Respondent
Idaho Power Company
Date of Report
(Mo,Da,Yr)
04/15/2016
Year/Period of Report
End of 2015/Q4(1)
(2)[A Resubmission
rtt 555)PURCHASED POWER (/
(Including power excbAccou
anges
1 .Report all power purchases made during the year.Also report exchanges of electricity (i.e.,transactions involving a balancing of
debits and credits for energy,capacity,etc.)and any settlements for imbalanced exchanges.
2.Enter the name of the seller or other party in an exchange transaction in column (a).Do not abbreviate or truncate the name or use
acronyms.Explain in a footnote any ownership interest or affiliation the respondent has with the seller.
3.In column (b),enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows:
RQ -for requirements service.Requirements service is service which the supplier plans to provide on an ongoing basis (i.e.,the
supplier includes projects load for this service in its system resource planning).In addition,the reliability of requirement service must
be the same as,or second only to,the supplier's service to its own ultimate consumers.
LF -for long-term firm service."Long-term"means five years or longer and "firm"means that service cannot be interrupted for ,
economic reasons and is intended to remain reliable even under adverse conditions (e.g.,the supplier must attempt to buy emergency
energy from third parties to maintain deliveries of LF service).This category should not be used for long-term firm service firm service
which meets the definition of RQ service.For all transaction identified as LF,provide in a footnote the termination date of the contract
defined as the earliest date that either buyer or seller can unilaterally get out of the contract.
IF -for intermediate-term firm service.The same as LF service expect that "intermediate-term"means longer than one year but less
than five years.
SF -for short-term service.Use this category for all firm services,where the duration of each period of commitment for service is one
year or less.
LU -for long-term service from a designated generating unit."Long-term"means five years or longer.The availability and reliability of
service,aside from transmission constraints,must match the availability and reliability of the designated unit.
IU -for intermediate-term service from a designated generating unit.The same as LU service expect that "intermediate-term"means
longer than one year but less than five years.
EX -For exchanges of electricity.Use this category for transactions involving a balancing of debits and credits for energy,capacity,etc,
and any settlements for imbalanced exchanges.
OS -for other service.Use this category only for those services which cannot be placed in the above-defined categories,such as all
non-firm service regardless of the Length of the contract and service from designated units of Less than one year.Describe the nature
of the service in a footnote for each adjustment.
Actual Demand (MW)
Average
Statistical
Classifi
cation
FERC Rate
Schedule or
Tariff Number
Average
Monthly Billing
Demand (MW)
Name of Company or Public Authority
(Footnote Affiliations)
Line
Average
Monthly NCP Demand Monthly CP DemandNo.
(a)(b)(c)(d)(e)(f)
1 Box Canyon LU N/A N/A N/A
2 Briggs Creek LU N/A N/A N/A
3 Riverside Hydro/Mora Drop LU N/A N/A N/A
4 Riverside Investments
5 Arena Drop LU N/A N/A N/A
6 Fargo Drop LU N/A N/A N/A
7 Rock Creek #1 Joint Venture LU 1.732Mw
8 Rockland Wind Project N/A N/ALU N/A
9 Rupert Cogeneration Partners/Magic Val LU N/A N/A N/A
10 Ryegrass Windfarm LU N/A N/A N/A
Salmon Falls Wind Park11 LU N/A N/A N/A
12 SE Hazelton A LP N/ALUN/A N/A
13 Shorock Hydro Inc.
14 Shoshone CSPP LU N/A N/A N/A
Total
Page 326.6FERCFORMNO.1 (ED.12-90)
Name of Respondent
Idaho Power Company
This Report Is:
(1)[X]An Original
(2)I |A Resubmission
PURCHASED POWER(Account 555)(Continued)
(including power exchanges)
Date of Report
(Mo,Da,Yr)
04/15/2016
Year/Period of Report
End of 2015/Q4
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 (NOP)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 POWER LineMegaWattHours
Purchased MegaWatt Hours
Received
MegaWatt Hours
Delivered
Other Charges Total (j+k+l)
of Settlement ($)
Demand Charges Energy Charges No.
($)($)
(I)(m)(g)(h)(i)G)(k.
131,593 1131,5931,983
2244,9163,589 244,916
3247,3214,652 247,321
4
5113,516113,5161,501
6194,410 194,4103,498
7991,28810,617 552,508 438,780
813,836,699218,662 13,836,699
95,138,703 5,138,70376,677
103,212,86746,727 3,212,867
112,990,57853,270 2,990,578
121,653,08723,982 1,653,087
13
14116,0181,258 116,018
162,239 2,815,124 204,436,381 10,345,099 217,596,6043,788,934 276,510
Page 327.6FERCFORMNO.1 (ED.12-90)
Name of Respondent
Idaho Power Company
This Report Is:
(1)fx]An Original
(2)||A Resubmission
RCHASED POWER If
(Including power exert
Date of Report
(Mo.Da,Yr)
04/15/2016
Year/Period of Report
End of 2015/Q4
PU Accoui
anges
rit 555)
1 .Report all power purchases made during the year.Also report exchanges of electricity (i.e.,transactions involving a balancing of
debits and credits for energy,capacity,etc.)and any settlements for imbalanced exchanges.
2.Enter the name of the seller or other party in an exchange transaction in column (a).Do not abbreviate or truncate the name or use
acronyms.Explain in a footnote any ownership interest or affiliation the respondent has with the seller.
3.In column (b),enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows:
RQ -for requirements service.Requirements service is service which the supplier plans to provide on an ongoing basis (i.e.,the
supplier includes projects load for this service in its system resource planning).In addition,the reliability of requirement service must
be the same as,or second only to,the supplier's service to its own ultimate consumers.
LF -for long-term firm service."Long-term"means five years or longer and "firm"means that service cannot be interrupted for
economic reasons and is intended to remain reliable even under adverse conditions (e.g.,the supplier must attempt to buy emergency
energy from third parties to maintain deliveries of LF service).This category should not be used for long-term firm service firm service
which meets the definition of RQ service.For all transaction identified as LF,provide in a footnote the termination date of the contract
defined as the earliest date that either buyer or seller can unilaterally get out of the contract.
IF -for intermediate-term firm service.The same as LF service expect that "intermediate-term"means longer than one year but less
than five years.
SF -for short-term service.Use this category for all firm services,where the duration of each period of commitment for service is one
year or less.
LU -for long-term service from a designated generating unit."Long-term"means five years or longer.The availability and reliability of
service,aside from transmission constraints,must match the availability and reliability of the designated unit.
IU -for intermediate-term service from a designated generating unit.The same as LU service expect that "intermediate-term"means
longer than one year but less than five years.
EX -For exchanges of electricity.Use this category for transactions involving a balancing of debits and credits for energy,capacity,etc.
and any settlements for imbalanced exchanges.
OS -for other service.Use this category only for those services which cannot be placed in the above-defined categories,such as all
non-firm service regardless ofthe 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.
Actual Demand (MW)
Average
Monthly NCP Demand Monthly CP Demand
FERC Rate
Schedule or
Tariff Number
Statistical
Classifi
cation
Average
Monthly Billing
Demand (MW)
Name of Company or Public Authority
(Footnote Affiliations)
Line
AverageNo.
(b)(c)(d)(e)(f)(a)
N/A1Shoshone#2 LU N/A N/A
N/A2SnakeRiverPotteryLUN/A N/A
3 South Forks Joint Venture/Lowline Cana LU N/A N/A N/A
4 Tamarack Energy Partnership LU 4.942Mw
OS N/A N/A N/A5Tasco-Nampa
OS N/A6Tasco-Twin Falls N/A N/A
7 Ted S.Sorenson/Tiber Dam LU N/A N/A N/A
8 Thousand Springs Wind Park N/A N/A N/ALU
N/A N/A N/A9TuanaGulchWindParkLU
N/A10TuanaSpringsExpansionLUN/A N/A
1 1 Twin Falls Energy/Lowline Midway Hydro LU N/A N/A N/A
N/A N/A N/A12TwoPondsWindfarmLU
N/A13WhiteWaterRanchLUN/A N/A
N/A14WilliamArkoosh/Littlewood LU N/A N/A
Total
Page 326.7FERCFORMNO.1 (ED.12-90)
This Report is:
[X]An Original
Name of Respondent
Idaho Power Company
Date of Report
(Mo,Da,Yr)
04/15/2016
Year/Period of Report
End of 2015/Q4(1)
a(2)A Resubmission
FOrCHTS^TGWEfTfAccount 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 (NOP)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 POWER LineMegaWattHours
Purchased MegaWatt Hours
Received
Total (j+k+l)
of Settlement ($)
Demand Charges Energy Charges Other ChargesMegaWattHours
Delivered
No.
to(?)(?)
(m)(9)(h)(i)G)(I)
1163,659 163,6592,308
349 223,85623,856
32,002,99027,677 2,002,990
42,966,3491,576,498 1,389,85129,409
510,41210,412483
68
71,674,26029,844 1,674,260
81,485,7851,485,78526,491
91,330,238 1,330,23823,774
104,183,74662,944 4,183,746
11515,8508,456 515,850
3,507,588 123,507,58851,309
1340,536 40,536587
14233,3933,071 233,393
217,596,6042,815,124 204,436,381 10,345,0993,788,934 276,510 162,239
Page 327.7FERCFORMNO.1 (ED.12-90)
This Report Is:
(1)fx]An Original
(2)||A Resubmission
PURCHASED POWER (Account 555)
(Including power exchanges)
Name of Respondent
Idaho Power Company
Date of Report
(Mo,Da,Yr)
04/15/2016
Year/Period of Report
End of 2015/Q4
1.Report all power purchases made during the year.Also report exchanges of electricity (i.e.,transactions involving a balancing of
debits and credits for energy,capacity,etc.)and any settlements for imbalanced exchanges.
2.Enter the name of the seller or other party in an exchange transaction in column (a).Do not abbreviate or truncate the name or use
acronyms.Explain in a footnote any ownership interest or affiliation the respondent has with the seller.
3.In column (b),enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows:
RQ -for requirements service.Requirements service is service which the supplier plans to provide on an ongoing basis (i.e.,the
supplier includes projects load for this service in its system resource planning).In addition,the reliability of requirement service must
be the same as,or second only to,the supplier's service to its own ultimate consumers.
LF -for long-term firm service."Long-term"means five years or longer and "firm"means that service cannot be interrupted for
economic reasons and is intended to remain reliable even under adverse conditions (e.g.,the supplier must attempt to buy emergency
energy from third parties to maintain deliveries of LF service).This category should not be used for long-term firm service firm service
which meets the definition of RQ service.For all transaction identified as LF,provide in a footnote the termination date of the contract
defined as the earliest date that either buyer or seller can unilaterally get out of the contract.
IF -for intermediate-term firm service.The same as LF service expect that "intermediate-term"means longer than one year but less
than five years.
SF -for short-term service.Use this category for all firm services,where the duration of each period of commitment for service is one
year or less.
LU -for long-term service from a designated generating unit."Long-term"means five years or longer.The availability and reliability of
service,aside from transmission constraints,must match the availability and reliability of the designated unit.
IU -for intermediate-term service from a designated generating unit.The same as LU service expect that "intermediate-term"means
longer than one year but less than five years.
EX -For exchanges of electricity.Use this category for transactions involving a balancing of debits and credits for energy,capacity,etc.
and any settlements for imbalanced exchanges.
OS -for other service.Use this category only for those services which cannot be placed in the above-defined categories,such as all
non-firm service regardless of the Length of the contract and service from designated units of Less than one year.Describe the nature
of the service in a footnote for each adjustment.
Actual Demand (MW)
Average
Monthly NCP Demand Monthly CP Demand
Statistical
Classifi
cation
FERC Rate
Schedule or
Tariff Number
Average
Monthly Billing
Demand (MW)
Name of Company or Public Authority
(Footnote Affiliations)
Line
AverageNo.
(a)(b)(c)(d)(e)(f)
1 Littlewood River Ranch II N/A N/A N/ALU
2 Willis and Betty Deveny/Shingle Creek N/A N/A N/ALU
3 Wilson Power Company N/A N/ALUN/A
N/A4YahooCreekWindParkLU N/A N/A
5 Prior Period Overpayment Recovery
6 Scheduling Deviation
7 Other Purchased Power
OS8ADMInvestorServicesInc N/A N/A N/A
9 Arizona Public Service Co.SF WSPP N/A N/A N/A
10 Avista Corp.OS N/A N/A N/AT-12
1 1 Avista Corp.N/ASFWSPP N/A N/A
OS12AvistaCorp.WSPP N/A N/A N/A
13 Basin Electric Power Cooperative SF WSPP N/A N/A N/A
14 Black Hills Power Inc.WSPP N/A N/A N/ASF
Total
Page 326.8FERCFORMNO.1 (ED.12-90)
This Report Is:
(1)[X|An Original
(2)[~]A Resubmission
Date of Report
(Mo.Da,Yr)
04/15/2016
Year/Period of Report
End of 2015/Q4
Name of Respondent
Idaho Power Company
PURCFiA-flndu^power^Ch'antel)'0 1
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 (NOP)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.
COST/SETTLEMENT OF POWERPOWEREXCHANGES LineMegaWattHours
Purchased Other Charges Total (j+k+l)
of Settlement ($)
MegaWatt Hours
Received
MegaWatt Hours
Delivered
Demand Charges Energy Charges No.
($)($)
(g)(h)0)0)(k.(I)(m)
11,16774 1,167
262,02580562,025
31,920,418 1,920,41827,057
44,382,89452,415 4,382,894
5-8,976 -8,976
62,190
7
8-1,064,614 -1,064,614
934,096 1,047,016 1,047,016
1053753721
111,952,680 1,952,68075,515
12215,447 215,447
1314911,513 11,513
141,100 1,10020
3,788,934 276,510 162,239 2,815,124 204,436,381 10,345,099 217,596,604
Page 327.8FERCFORMNO.1 (ED.12-90)
This Report is:
[X]An Original
Year/Period of Report
End of 2015/Q4
Date of Report
(Mo,Da,Yr)
04/15/2016
Name of Respondent
Idaho Power Company (1)
(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,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 ofthe 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.
Actual Demand (MW)
Average
Monthly NCP Demand Monthly CP Demand
Statistical
Classifi
cation
FERC Rate
Schedule or
Tariff Number
Average
Monthly Billing
Demand (MW)
Name of Company or Public Authority
(Footnote Affiliations)
Line AverageNo.
(e)(f)(d)(b)(c)(a)
N/AOSN/A N/AWSPPBonnevillePowerAdministration1
N/AOSN/AWSPPN/A2BonnevillePowerAdministration
N/AN/AWSPPN/ASF3BonnevillePowerAdministration
N/AN/AN/A4CalpineEnergyServices,L.P.SF WSPP
N/AN/A N/ASFWSPP5CargillPowerMarketsLLC
N/AOSN/AISDAN/A6CargillPowerMarketsLLC
N/AN/ASFWSPPN/A7ChelanCoPUD
N/AN/AOSN/AWSPP8ChelanCoPUD
N/AOSN/A N/AISDA9CitigroupEnergyInc.
N/AN/ASFWSPPN/A10CityofAnaheim
N/AN/AWSPPN/ASF11ClatskaniePUD
N/A N/AN/A12EDFTradingNorthAmerica,LLC SF WSPP
N/A N/AOSN/A13EDFTradingNorthAmerica,LLC WSPP
N/AN/ASFWSPPN/A14EnergyKeepers
Total
Page 326.9FERCFORMNO.1 (ED.12-90)
Tilts Report Is:
(1)[xj An Original
(2)||A Resubmission
SeD POWER(Account 555)(Cdntinued)(Including power exchanges)
Name of Respondent
Idaho Power Company
Date of Report
(Mo.Da,Yr)
04/15/2016
Year/Period of Report
End of 2015/Q4
PURCHA
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 POWER LineMegaWattHours
Purchased Demand Charges Energy Charges Other Charges Total (j+k+l)
of Settlement ($)
MegaWatt Hours
Received
MegaWatt Hours
Delivered
No.
(?)(?)
(I)(m)(g)0)(j)\k(h)
1297,481297,481
23,512 3,512135
32,926,124 2,926,124103,286
4485,020 485,02012,898
5441,070441,07018,450
6540.762 540,762
7137,652137,6525,200
81271275
9151,944151,944
102,006 2,00676
119,100 9,100833
122,250,5452,250,54560,385
13697,010697,01010,495
1411,93665C11,936
217,596,604162,239 2,815,124 204,436,381 10,345,0993,788,934 276,510
Page 327.9FERCFORMNO.1 (ED.12-90)
This Report Is:
(1)fx]An Original
(2)r~|A Resubmission
Name of Respondent
Idaho Power Company
Date of Report
{Mo.Da,Yr)
04/15/2016
Year/Period of Report
2015/Q4Endof
RCHASED POWER {Account 555)(Including power exchanges)PU
1 .Report all power purchases made during the year.Also report exchanges of electricity (i.e.,transactions involving a balancing of
debits and credits for energy,capacity,etc.)and any settlements for imbalanced exchanges.
2.Enter the name of the seller or other party in an exchange transaction in column (a).Do not abbreviate or truncate the name or use
acronyms.Explain in a footnote any ownership interest or affiliation the respondent has with the seller.
3.In column (b),enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows:
RQ -for requirements service.Requirements service is service which the supplier plans to provide on an ongoing basis (i.e.,the
supplier includes projects load for this service in its system resource planning).In addition,the reliability of requirement service must
be the same as,or second only to,the supplier's service to its own ultimate consumers.
LF -for long-term firm service."Long-term"means five years or longer and "firm"means that service cannot be interrupted for
economic reasons and is intended to remain reliable even under adverse conditions (e.g.,the supplier must attempt to buy emergency
energy from third parties to maintain deliveries of LF service).This category should not be used for long-term firm service firm service
which meets the definition of RQ service.For all transaction identified as LF,provide in a footnote the termination date of the contract
defined as the earliest date that either buyer or seller can unilaterally get out of the contract.
IF -for intermediate-term firm service.The same as LF service expect that "intermediate-term"means longer than one year but less
than five years.
SF -for short-term service.Use this category for all firm services,where the duration of each period of commitment for service is one
year or less.
LU -for long-term service from a designated generating unit."Long-term"means five years or longer.The availability and reliability of
service,aside from transmission constraints,must match the availability and reliability of the designated unit.
IU -for intermediate-term service from a designated generating unit.The same as LU service expect that "intermediate-term"means
longer than one year but less than five years.
EX -For exchanges of electricity.Use this category for transactions involving a balancing of debits and credits for energy,capacity,etc.
and any settlements for imbalanced exchanges.
OS -for other service.Use this category only for those services which cannot be placed in the above-defined categories,such as all
non-firm service regardless of the Length of the contract and service from designated units of Less than one year.Describe the nature
of the service in a footnote for each adjustment.
Actual Demand (MW)
Average
Monthly NCP Demand Monthly CP Demand
FERC Rate
Schedule or
Tariff Number
Statistical
Classifi
cation
Average
Monthly Billing
Demand (MW)
Name of Company or Public Authority
(Footnote Affiliations)
Line
AverageNo.
(a)(b)(c)(d)(e)(f)
WSPP N/A N/A1EugeneWater&Electric Board SF N/A
WSPP N/A2ExelonGenerationCompany,LLC SF N/A N/A
3 Grant CO Public Utility District #2 -OS WSPP N/A N/A N/A
4 Grant CO Public Utility District #2 -SF WSPP N/A N/A N/A
5 IBERDROLA RENEWABLES,Inc.WSPP N/A N/ASFN/A
N/A6J.Aran &Company SF WSPP N/A N/A
OS7JefferiesBache N/A N/A N/A
OS8MacquarieEnergyLLC ISDA N/A N/A N/A
9 Morgan Stanley Capital Group Inc.ISDA N/A N/ASFN/A
N/A N/A10NevadaPowerCompany,DBA NV Energy SF WSPP N/A
OS11NevadaPowerCompany,DBA NV Energy WSPP N/A N/A N/A
12 Nobles Americas Energy Solutions LLC SF WSPP N/A N/A N/A
13 Northwestern Energy OS N/A N/AT-7 N/A
WSPP N/A14NorthwesternEnergySFN/A N/A
Total
Page 326.10FERCFORMNO.1 (ED.12-90)
This Report Is:
(1)[x An Original
(2)fn A Resubmission
Name of Respondent
Idaho Power Company
Date of Report
(Mo,Da,Yr)
04/15/2016
Year/Period of Report
End of 2015/Q4
CHAFED POWERfAccounl 555)^(Continued)Pur
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
MegaWatt Hours
Received
COST/SETTLEMENT OF POWER LineMegaWattHours
Purchased Energy ChargesMegaWattHours
Delivered
Demand Charges Other Charges Total (j+k+l)
of Settlement ($)No.
(?)(?)(g)(h)(i)0)(k:(i)(m)
12,075 49,842 49,842
215,625 392,480 392,480
310273273
420,475 617,147 617,147
564,883 1,581,907 1,581,907
630,800 1,101,100 1,101,100
7-14,108 -14,108
8-286,198 -286,198
9113,679 3,197,264 3,197,264
1021,949 898,271 898,271
116,703 6,703
126,400 218,208 218,208
1321532532
145,427 102,523 102,523
3,788,934 276,510 2,815,124 204,436,381 217,596,604162,239 10,345,099
Page 327.10FERCFORMNO.1 (ED.12-90)
This Report Is:
(1)[xj An Original
(2)|A Resubmission
PURCHASED POWER (Account 555)(Including power exchanges)
Year/Period of Report
End of 2015/Q4
Date of Report
(Mo,Da,Yr)
04/15/2016
Name of Respondent
Idaho Power Company
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 ofthe 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.
Actual Demand (MW)
Average
Monthly NCP Demand Monthly CP Demand
Statistical
Classifi
cation
FERC Rate
Schedule or
Tariff Number
Average
Monthly Billing
Demand (MW)
Name of Company or Public Authority
(Footnote Affiliations)
Line
AverageNo.
(c)(d)(e)(f)(a)(b)
OS N/A N/A N/A1PacifiCorpInc.T-13
N/A N/A2PacifiCorpInc.SF WSPP N/A
N/A N/AOSWSPPN/A3PacifiCorpInc.
N/AOSN/A N/A4PortlandGeneralElectricCompanyT-14
N/A N/A N/A5PortlandGeneralElectricCompanySFWSPP
N/A N/A N/A6PowerexCorp.SF WSPP
OS N/A N/AN/A7PugetSoundEnergy,Inc.T-9
N/AN/A N/A8PugetSoundEnergy,Inc.SF WSPP
N/A N/A N/A9RainbowEnergyMarketingCorporationSFWSPP
N/A N/A10SaltRiverProjectSFWSPPN/A
N/AOSWSPPN/A N/A11SeattleCityLight
N/A N/A N/A12SeattleCityLightSFWSPP
N/A N/A N/A13ShellEnergyNorthAmerica(US),L.P.SF WSPP
OS N/A N/A N/A14SierraPacificPowerCo.,dba NV Energ T-55
Total
Page 326.11FERCFORMNO.1 (ED.12-90)
This Report is:
(1)fx]An Original
Date of Report
(Mo,Da,Yr)
04/15/2016
Year/Period of Report
End of 2015/Q4
Name of Respondent
Idaho Power Company
H(2)A Resubmission
PURCHAfln^^^poie^Cexchangli)^'5"iiSued'
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 ofthe 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 POWER LineMegaWattHours
Purchased MegaWatt Hours
Received
MegaWatt Hours
Delivered
Demand Charges Energy Charges Other Charges Total (j+k+l)
of Settlement ($)No.
($)($)
(I)(m)(g)(h)(i)(j)
1992,575 2,575
216,900 16,900690
3212,313 212,313
431826826
523,016 759,724 759,724
65,078,264 5,078,264120,289
794994936
828,130 681,348 681 ,348
940010,112 10,112
102,811,045 2,811,045124,717
1135735714
1213,189 360,555 360,555
1387,416 2,937,085 2,937,085
141,537 1,53758
3,788,934 276,510 162,239 2,815,124 204,436,381 10,345,099 217,596,604
Page 327.11FERCFORMNO.1 (ED.12-90)
This Report Is:
(!)[x]An Original
(2)||A Resubmission
PURCHASED POWER (Account 555}
(Including power exchanges)
Year/Period of Report
End of 2015/Q4
Name of Respondent
Idaho Power Company
?ate of Report
(Mo.Da,Yr)
04/15/2016
1 .Report all power purchases made during the year.Also report exchanges of electricity (i.e.,transactions involving a balancing of
debits and credits for energy,capacity,etc.)and any settlements for imbalanced exchanges.
2.Enter the name of the seller or other party in an exchange transaction in column (a).Do not abbreviate or truncate the name or use
acronyms.Explain in a footnote any ownership interest or affiliation the respondent has with the seller.
3.In column (b),enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows:
RQ -for requirements service.Requirements service is service which the supplier plans to provide on an ongoing basis (i.e.,the
supplier includes projects load for this service in its system resource planning).In addition,the reliability of requirement service must
be the same as,or second only to,the supplier's service to its own ultimate consumers.
LF -for long-term firm service."Long-term"means five years or longer and "firm"means that service cannot be interrupted for
economic reasons and is intended to remain reliable even under adverse conditions (e.g.,the supplier must attempt to buy emergency
energy from third parties to maintain deliveries of LF service).This category should not be used for long-term firm service firm service
which meets the definition of RQ service.For all transaction identified as LF,provide in a footnote the termination date of the contract
defined as the earliest date that either buyer or seller can unilaterally get out of the contract.
IF -for intermediate-term firm service.The same as LF service expect that "intermediate-term"means longer than one year but less
than five years.
SF -for short-term service.Use this category for all firm services,where the duration of each period of commitment for service is one
year or less.
LU -for long-term service from a designated generating unit."Long-term"means five years or longer.The availability and reliability of
service,aside from transmission constraints,must match the availability and reliability of the designated unit.
IU -for intermediate-term service from a designated generating unit.The same as LU service expect that "intermediate-term"means
longer than one year but less than five years.
EX -For exchanges of electricity.Use this category for transactions involving a balancing of debits and credits for energy,capacity,etc.
and any settlements for imbalanced exchanges.
OS -for other service.Use this category only for those services which cannot be placed in the above-defined categories,such as all
non-firm service regardless of the Length of the contract and service from designated units of Less than one year.Describe the nature
of the service in a footnote for each adjustment.
Actual Demand (MW)Statistical
Classifi
cation
FERC Rate
Schedule or
Tariff Number
Average
Monthly Billing
Demand (MW)
Name of Company or Public Authority
(Footnote Affiliations)
Line Average
Monthly NCP Demand Monthly CP Demand
AverageNo.
(b)(c)(d)(e)(f)(a)
OS N/A N/A1SierraPacificPowerCo.,dba NV Energ WSPP N/A
N/A2SnohomishCountyPUDSFWSPPN/A N/A
OS WSPP N/A N/A N/A3TacomaPower
SF WSPP N/A N/A N/A4TacomaPower
WSPP N/A N/A5TalenEnergySFN/A
OS N/A N/AWSPPN/A6TalenEnergy
7 Tenaska Power Services Co.SF WSPP N/A N/A N/A
SF WSPP N/A N/A N/A8TheEnergyAuthority,Inc.
N/A N/A9TransAltaEnergyMarketing(U.S.)Inc.SF WSPP N/A
WSPP N/ASFN/A N/A10TurlockIrrigationDistrict
1 1 Raft River Energy I LLC N/A N/A N/ALU
N/A N/A N/A12TelocasetWindPowerPartnersLLCLUAPP-A
N/A N/A13NealHotSpringsUnit#1 LU N/A
N/AOS14OregonSolarCustomersN/A N/A
Total
Page 326.12FERCFORMNO.1 (ED.12-90)
This Report Is:
(1)[XJAn Original
(2)IA Resubmission
Date of Report
(Mo,Da,Yr)
04/15/2016
Year/Period of Report
End of 2015/Q4
Name of Respondent
Idaho Power Company
PURCHASED POWE ft/Acraun^55^(Continued)
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.
COST/SETTLEMENT OF POWERPOWEREXCHANGES LineMegaWattHours
Purchased Energy Charges Other Charges Total (j+k+l)
of Settlement ($)
MegaWatt Hours
Received
MegaWatt Hours
Delivered
Demand Charges No.
($)($)
(m)(j)K (I)(g)(h)(i)
1311311
221,83021,8301,125
375753
4152,250152,2504,050
52,818,56982,444 2,818,568
6210,309 210,3095,517
781,2512,787 81,251
8466,92419,144 466,924
91,786,1581,786,15850,951
1033,41233,4121,680
114,868,3604,868,36075,595
1216,786,78616,786,786293,122
1318,806,76418,806,764176,868
1424,261 24,261820
10,345,099 217,596,604162,239 2,815,124 204,436,3813,788,934 276,510
Page 327.12FERCFORMNO.1 (ED.12-90)
Name of Respondent
Idaho Power Company
This Report Is:
(1)|x|An Original
(2)|]A Resubmission
PURCHASED POWER (Account 555)
(Including power exchanges)
Date of Report
(Mo,Da,Yr)
04/15/2016
Year/Period of Report
End of 2015/Q4
1.Report all power purchases made during the year.Also report exchanges of electricity (i.e.,transactions involving a balancing of
debits and credits for energy,capacity,etc.)and any settlements for imbalanced exchanges.
2.Enter the name of the seller or other party in an exchange transaction in column (a).Do not abbreviate or truncate the name or use
acronyms.Explain in a footnote any ownership interest or affiliation the respondent has with the seller.
3.In column (b),enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows:
RQ -for requirements service.Requirements service is service which the supplier plans to provide on an ongoing basis (i.e.,the
supplier includes projects load for this service in its system resource planning).In addition,the reliability of requirement service must
be the same as,or second only to,the supplier's service to its own ultimate consumers.
LF -for long-term firm service."Long-term"means five years or longer and "firm"means that service cannot be interrupted for
economic reasons and is intended to remain reliable even under adverse conditions (e.g.,the supplier must attempt to buy emergency
energy from third parties to maintain deliveries of LF service).This category should not be used for long-term firm service firm service
which meets the definition of RQ service.For all transaction identified as LF,provide in a footnote the termination date of the contract
defined as the earliest date that either buyer or seller can unilaterally get out of the contract.
IF -for intermediate-term firm service.The same as LF service expect that "intermediate-term"means longer than one year but less
than five years.
SF -for short-term service.Use this category for all firm services,where the duration of each period of commitment for service is one
year or less.
LU -for long-term service from a designated generating unit."Long-term"means five years or longer.The availability and reliability of
service,aside from transmission constraints,must match the availability and reliability of the designated unit.
IU -for intermediate-term service from a designated generating unit.The same as LU service expect that "intermediate-term"means
longer than one year but less than five years.
EX -For exchanges of electricity.Use this category for transactions involving a balancing of debits and credits for energy,capacity,etc.
and any settlements for imbalanced exchanges.
OS -for other service.Use this category only for those services which cannot be placed in the above-defined categories,such as all
non-firm service regardless of the Length of the contract and service from designated units of Less than one year.Describe the nature
of the service in a footnote for each adjustment.
Actual Demand (MW)
Average
Monthly NCP Demand Monthly CP Demand
Statistical
Classifi
cation
FERC Rate
Schedule or
Tariff Number
Average
Monthly Billing
Demand (MW)
Name of Company or Public Authority
(Footnote Affiliations)
Line
AverageNo.
(c)(d)(e)(f)(a)(b)
N/A1PriorYearAdjustmentsADN/A N/A
2 Power Exchanges
N/A3AvistaCorpEXN/A N/A
N/AEXN/A N/A4BonnevillePowerAdministration
N/A N/A N/A5NorthwesternEnergyEX
EX N/A6PacifiCorpInc.N/A N/A
N/A7SierraPacificPowerCo.,dba NV Energ EX N/A N/A
N/AEXN/A N/A8ClatskaniePUD153
9 Other Transactions
10 Acctg Valuation of Clatskanie PUD OS
N/AOSN/A N/A11DemandResponseAvoidedEnergy
N/A N/A N/A12PacifiCorpLossRepaymentOS
N/A N/A13BlackThunderTestBurnOSN/A
14
Total
Page 326.13FERCFORMNO.1 (ED.12-90)
This Report Is:
^]An Original
Name of Respondent
Idaho Power Company
Date of Report
(Mo,Da,Yr)
04/15/2016
Year/Period of Report
End of 2015/Q4(1)
s(2)A Resubmission
PURCHASED PpWER(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 POWER LineMegaWattHours
Purchased MegaWatt Hours
Received
MegaWatt Hours
Delivered
Demand Charges Energy Charges Other Charges Total (j+k+l)
of Settlement ($)No.
(?)(?)
(I)(m)(9)(h)0)(j)(k.
1237237-6
2
3359
466,231
5448
6144,521 97,125
71,691
865,399 62,975
9
10114,584 114,584
116,701,2636,701,263
1264,775
132,526,094 2,526,094
14
217,596,604204,436,381 10,345,0993,788,934 276,510 162,239 2,815,124
Page 327.13FERCFORMNO.1 (ED.12-90)
Date of Report Year/Period of ReportNameofRespondentThisReportis:
(1)X An Original
(2)_A Resubmission
(Mo,Da,Yr)
2015/Q404/15/2016IdahoPowerCompany
FOOTNOTE DATA
Schedule Page:326 Line No.:2 Column:e
Unavailable
Schedule Page:326 Line No.:2 Column:f
Unavailable
Schedule Page:326.1 Line No.:11 Column:e
Unavailable
Schedule Page:326.1 Line No.:11 Column:f
Unavailable
Schedule Page:326.2 Line No.:7 Column:e
Unavailable
Schedule Page:326.2 Line No.:7 Column:f
Unavailable
Schedule Page:326.2 Line No.:13 Column:b
Non-Firm Purchases
Schedule Page:326.3 Line No.:4 Column:a
Ida West,a subsidiary o_f Idaho Power Company,has partial ownership of these projects-.
Schedule Page:326.4 Line No.:13 Column:a
Ida West,a subsidiary of Idaho Power Company,has partial ownership of these projects.
Schedule Page:326.5 Line No.:9 Column:e
Unavailable
Schedule Page:326.5 Line No.:9 Column:f
Unavailable
Schedule Page:326.6 Line No.:7 Column:e
Unavailable
Schedule Page:326.6 Line No.:7 Column:f
Unavailable
Schedule Page:326.7 Line No.:3 Column:a
Ida West,a subsidiary of Idaho Power Company,has _partial ownership of these projects ¦
Schedule Page:326.7 Line No.:4 Column:a
The Tamarack Energy Partnership demand readings are taken from an electronic demand
recorder provided by Idaho Power Co.The actual demand is not used in determining the
cost of energy.
Schedule Page:326.7 Line No.:4 Column:e
Unavailable
Schedule Page:326.7 Line No.:4 Column:f
Unavailable
Schedule Page:326.7 Line No.:5 Column:b
Non-Firm Purchases
Schedule Page:326.7 Line No.:6 Column:b
Non-Firm Purchases
Schedule Page:326.8 Line No.:3 Column:a
Ida West,a subsidiary of Idaho Power Company,has partial ownership of these projects.
Schedule Page:326.8 Line No.:6 Column:a
Difference between booked and scheduled energy.
Schedule Page:326.8 Line No.:8 Column:b
ADM Investor Services,Inc Futures Account Document,dated May 5,2015
Schedule Page:326.8 Line No.:10 Column:b
Spinning or Operating Reserves _
Schedule Page:326.8 Line No.:12 Column:b
Financial Transmission Losses __
Schedule Page:326.9 Line No.:1 Column:b
Financial Transmission Losses
Schedule Page:326.9 Line No.:2 Column:b
Spinning or Operating Reserves
I
FERC FORM NO.1 (ED.12-87)Page 450.1
Date of Report Year/Period of Report
(Mo,Da,Yr)
04/15/2016
Name of Respondent This Report is:
(1)X An Original
(2)_A Resubmission 2015/Q4IdahoPowerCompany
FOOTNOTE DATA
Schedule Page:326.9 Line No.:6 Column:b
ISDA Master Agreement With Cargill Power Markets,LLC,dated June 13,2011
Schedule Page:326.9 Line No.:8 Column:b
Spinning or Opera:ing Reserves
Schedule Page:326.9 Line No.:9 Column:b
ISDA Master Agreement with C :•igroup l'.".ov :;y PLC dated March 7,2011
Schedule Page:326.9 Line No.:13 Column:b
Unit Contingent Purchases
'Schedule Page:326.10 Line No.:3 Column:b
Spinning or Operating Reserves
Schedule Page:326.10 Line No.:7 Column:b
Prudential Bache Commodities,LLC (Jefferies Bache)Futures Account Document,dated
September 4,2008 and contract ended on May 19,2015.
Schedule Page:326.10 Line No.:8 Column:b
ISDA Master Agreement with Macquarie Energy,LLC dated April 12,2011
Schedule Page:326.10 Line No.:11 Column:b
Financial Transmission Losses
Schedule Page:326.10 Line No.:13 Column:b
Spinning or Operating Reserves
Schedule Page:326.11 Line No.:1 Column:b
Spinning or Operating Reserves
Schedule Page:326.11 Line No.:3 Column:b
Financial Transmission Losses __
Schedule Page:326.11 Line No.:4 Column:b
Spinning or Operating Reserves
Schedule Page:326.11 Line No.:7 Column:b
Spinning or Opera'ing Reserves
Schedule Page:326.11 Line No.:11 Column:b
Spinning or Operating Reserves
Schedule Page:326.11 Line No.:14 Column:b
Spinning or Operating Reserves
Schedule Page:326.12 Line No.:1 Column:b
Financial Transmission Losses
Schedule Page:326.12 Line No..^3 Column:b
Spinning or Operating Reserves
Schedule Page:326.12 Line No.:6 Column:b
Unit Contingent Purchases
Schedule Page:326.12 Line No.:14 Column:b
Schedule 88 Oregon Solar
Schedule Page:326.13 Line No.:1 Column:b
Out of period adjustments
Schedule Page:326.13 Line No.:3 Column:b
Financial Transmission Losses
Schedule Page:326.13 Line No.:4 Column:b
Financial Transmission Losses
Schedule Page:326.13 Line No.:5 Column:b
Financial Transmission Losses
Schedule Page:326.13 Line No.:6 Column:b
Financial Transmission Losses
Schedule Page:326.13 Line No.:7 Column:b
Financial Transmission Losses
Schedule Page:326.13 Line No.:8 Column:b
Energy exchange between Clatskanie PUD and Idaho Power Company at Arrowrock Dam.
Schedule Page:326.13 Line No.:10 Column:b
Energy exchange between Clatskanie PUD and Idaho Power Company at Arrowrock Dam.
J
1
1
:
FERC FORM NO.1 (ED.12-87)Page 450.2
This Page Intentionally Left Blank
Name of Respondent Date of Report Year/Period of Report
(Mo,Da,Yr)
04/15/2016
This Report is:
(1)X An Original
(2)_A ResubmissionIdahoPowerCompany 2015/Q4
FOOTNOTE DATA
Schedule Page:326.13 Line No.:11 Column:b
Incentive program for customers to reduce demand during p.eak hours
Schedule Page:326.13 Line No.:12 Column:b
Repa yine r.of transmisssion losses
Schedule Page:326.13 Line No.:13 Column:b
Coal supply test burn at Jim Bridger Plant
FERC FORM NO.1 (ED.12-87)Page 450.3
This Report ts:
[X]An Original
Name of Respondent
Idaho Power Company
Date of Report
(Mo,Da,Yr)
04/15/2016
Year/Period of Report
(1)2015/Q4Endof
TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456.1)
(Including transactions referred to as 'wheeling')
(2)A Resubmission
1 .Report all transmission of electricity,i.e.,wheeling,provided for other electric utilities,cooperatives,other public authorities,
qualifying facilities,non-traditional utility suppliers and ultimate customers for the quarter.
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:
FNO -Firm Network Service for Others,FNS -Firm Network Transmission Service for Self,LFP -"Long-Term Firm Point to Point
Transmission Service,OLF -Other Long-Term Firm Transmission Service,SFP -Short-Term Firm Point to Point Transmission
Reservation,NF -non-firm transmission service,OS -Other Transmission Service and AD -Out-of-Period Adjustments.Use this code
for any accounting adjustments or "true-ups"for service provided in prior reporting periods.Provide an explanation in a footnote for
each adjustment.See General Instruction for definitions of codes.
Payment By
(Company of Public Authority)
(Footnote Affiliation)
Energy Delivered To
(Company of Public Authority)
(Footnote Affiliation)
Statistical
Classifi
cation
Energy Received From
(Company of Public Authority)
(Footnote Affiliation)
Line
No.
(a)(b)(c)(d)
FNOBonnevillePowerAdministration-OTEC Oregon Trails Electric Co-op1BonnevillePowerAdministration
ADOregonTrailsElectricCo-op2BonnevillePowerAdministration-OTEC Bonneville Power Administration
FNO3BonnevillePowerAdministration-USBR Bonneville Power Administration United States Bureau of Reclamati
AD4BonnevillePowerAdministration-USBR Bonneville Power Administration United States Bureau of Reclamati
FNO5BonnevillePowerAdministration-PF Priority Firm CustomersBonnevillePowerAdministration
ADPriorityFirmCustomers6BonnevillePowerAdministration-PF Bonneville Power Administration
FNO7PacifiCorp-Imnaha PacifiCorp West PacifiCorp West
AD8PacifiCorp-Imnaha PacifiCorp WestPacifiCorpWest
OLF9MilnerIrrigationDistrictUnitedStatesBureauofReclamatiMilnerIrrigationDistrict
OS10UnitedStatesBureauofIndianAffairsBonnevillePowerAdministrationUnitedStatesBureauofIndianAf
OS11ShellEnergyNorthAmerica(US),L.P.Seattle City Light Bonneville Power Administration
OSUnitedMaterialsofGreatFallsNorthWestern/PacifiCorp East Idaho Power Company12
OS13UnitedMaterialsofGreatFallsPacifiCorpEastIdahoPowerCompany
OS14UnitedMaterialsofGreatFallsSierraPacificPowerPacifiCorpEast
AD15UnitedMaterialsofGreatFalls
16
LFP17PacifiCorpInc.PacifiCorp East PacifiCorp East
LFP18PacifiCorpInc.PacifiCorp East Bonneville Power Administration
LFP19PacifiCorpInc.PacifiCorp East PacifiCorp West
LFP20PacifiCorpInc.Idaho Power CompanyIdahoPowerCompany
LFPPacifiCorpWest21PacifiCorpInc.PacifiCorp East
LFP22ShellEnergyNorthAmerica(US),L.P.Idaho Power Company Bonneville Power Administration
23
NF24BlackHillsPower
NF25BonnevillePowerAdminstrationNorthWestern/PacifiCorp East Bonneville Power Administration
NF26BonnevillePowerAdminstrationNorthWestern/PacifiCorp East Sierra Pacific Power
NFBonnevillePowerAdministration27BonnevillePowerAdminstrationBonnevillePowerAdministration
NFSierraPacificPower28BonnevillePowerAdminstrationBonnevillePowerAdministration
NF29BonnevillePowerAdminstrationBonnevillePowerAdministrationAvista
NF30BonnevillePowerAdminstrationSierraPacificPowerAvista
AD31BonnevillePowerAdministration
AD32Cargill-Alliant
NFNorthWestern/PacifiCorp East PacifiCorp East33IberdrolaRenewablesLLC
34
TOTAL
Page 328FERCFORMNO.1 (ED.12-90)
This Report Is:
(1)[X]An Original
(2)IA Resubmission
Name of Respondent
Idaho Power Company
Date of Report
(Mo,Da,Yr)
04/15/2016
Year/Period of Report
End of 2015/Q4
TRANSMISSION OP ELECTRICITY FOR OTHERS (Account 456)(Continued)
(Including transactions reffered to as 'wheeling')
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.
8.Report in column (i)and (j)the total megawatthours received and delivered.
FERC Rate
Schedule of
Tariff Number
Point of Receipt
(Subsatation or Other
Designation)
Point of Delivery
(Substation or Other
Designation)
Billing
Demand
TRANSFER OF ENERGY
MegaWatt Hours
Delivered
Line
MegaWatt Hours
Received
No.(MW)
(e)(0 (g)(h)(i)0)
9 336,735 336,735 1
9 2
9 297,100 3297,100
9 4
9 1,260,4691,260,469 5
9 6
9 2,067 2,067 7
9 8
Legacy 9,393Minidoka,Idaho Various in Idaho 99,393
Legacy LaGrande,Oregon 16,261 10VariousinIdaho16,261
4 277,687 11277,687
5/6 66 12
5/6 7,539 7.53S 13
5/6 7,859 7,859 14
5/6 15
16
7/8 BORA 663,949 663,949 17KPRT
7/8 BORA LAGRANDE 69,227 1869,227
7/8 BOFtA 287,668HURR287,668 19
7/8 470,041JBWTHMWY470,041 20
7/8 KPRT HURR 121,062 121,062 21
7/8 LYPK LAGRANDE 21,675 21,675 22
23
7/8 24
7/8 BPAT.NWMT LAGRANDE 1,369 1,369 25
7/8 BPAT.NWMT 266 26M345266
7/8 LAGRANDE 776LAGRANDE776 27
7/8 LAGRANDE M345 10,813 10,813 28
7/8 LOLO LAGRANDE 3,193 3,193 29
7/8 LOLO 1,956 1,956 30M345
7/8 31
7/8 32
7/8 40BPAT.NWMT BRDY 40 33
34
0 5,920,350 5,920,350
Page 329FERCFORMNO.1 (ED.12-90)
This Report Is:Date of Report
(1)[^J An Original (Mo.Da,Vr)
(2)||A Resubmission 04/15/2016
TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456.1 )
(Including transactions referred to as 'wheeling')
Name of Respondent
Idaho Power Company
Year/Period of Report
End of 2015/Q4
1 .Report all transmission of electricity,i.e.,wheeling,provided for other electric utilities,cooperatives,other public authorities,
qualifying facilities,non-traditional utility suppliers and ultimate customers for the quarter.
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:
FNO -Firm Network Service for Others,FNS -Firm Network Transmission Service for Self,LFP -"Long-Term Firm Point to Point
Transmission Service,OLF -Other Long-Term Firm Transmission Service,SFP -Short-Term Firm Point to Point Transmission
Reservation,NF -non-firm transmission service,OS -Other Transmission Service and AD -Out-of-Period Adjustments.Use this code
for any accounting adjustments or "true-ups"for service provided in prior reporting periods.Provide an explanation in a footnote for
each adjustment.See General Instruction for definitions of codes.
Statistical
Classifi
cation
Energy Received From
(Company of Public Authority)
(Footnote Affiliation)
Energy Delivered To
(Company of Public Authority)
(Footnote Affiliation)
Payment By
(Company of Public Authority)
(Footnote Affiliation)
Line
No.
(d)(a)(b)(c)
NFNorthWestern/PacifiCorp East Sierra Pacific Power1IberdrolaRenewablesLLC
NFPacifiCorpEastSierraPacificPower2IberdrolaRenewablesLLC
NF3IberdrolaRenewablesLLCPacifiCorpEastBonnevillePowerAdministration
NF4IberdrolaRenewablesLLCIdahoPowerCompanyPacifiCorpEast
NF5IberdrolaRenewablesLLCIdahoPowerCompanySierraPacificPower
NFPacifiCorpEastSierraPacificPower6IberdrolaRenewablesLLC
NFPacifiCorpEast7IberdrolaRenewablesLLCBonnevillePowerAdministration
NFSierraPacificPower8IberdrolaRenewablesLLCBonnevillePowerAdministration
NF9IberdrolaRenewablesLLCAvistaPacifiCorpEast
NF10IberdrolaRenewablesLLCAvistaSierraPacificPower
NF11IberdrolaRenewablesLLCSierraPacificPowerBonnevillePowerAdministration
NFIberdrolaRenewablesLLCPacifiCorpWestPacifiCorpEast12
AD13IberdrolaRenewablesLLC
NFSierraPacificPower14MacQuarieCookBonnevillePowerAdministration
NFNorthWestern/PacifiCorp East PacifiCorp East15MorganStanleyCapitalGroupInc.
NFIdahoPowerCompany16MorganStanleyCapitalGroupInc.NorthWestern/PacifiCorp East
NF17MorganStanleyCapitalGroupInc.NorthWestern/PacifiCorp East Bonneville Power Administration
NF18MorganStanleyCapitalGroupInc.NorthWestern/PacifiCorp East Sierra Pacific Power
SFPNorthWestern/PacifiCorp East PacifiCorp West19MorganStanleyCapitalGroupInc.
NFPacifiCorpEastBonnevillePowerAdministration20MorganStanleyCapitalGroupInc.
NFSierraPacificPower21MorganStanleyCapitalGroupInc.PacifiCorp East
NF22MorganStanleyCapitalGroupInc.NorthWestern/PacifiCorp East PacifiCorp East
NFNorthWestern/PacifiCorp East PacifiCorp East23MorganStanleyCapitalGroupInc.
NFNorthWestern/PacifiCorp East Bonneville Power Administration24MorganStanleyCapitalGroupInc.
NFSierraPacificPower25MorganStanleyCapitalGroupInc.NorthWestern/PacifiCorp East
SFP26MorganStanleyCapitalGroupInc.NorthWestern/PacifiCorp East PacifiCorp West
NF27MorganStanleyCapitalGroupInc.PacifiCorp East NorthWestern/PacifiCorp East
NFPacifiCorpEastPacifiCorpEast28MorganStanleyCapitalGroupInc.
NFIdahoPowerCompany29MorganStanleyCapitalGroupInc.PacifiCorp East
NF30MorganStanleyCapitalGroupInc.PacifiCorp East PacifiCorp West
NF31MorganStanleyCapitalGroupInc.PacifiCorp East Bonneville Power Administration
NF32MorganStanleyCapitalGroupInc.PacifiCorp East Avista
NFPacifiCorpEastSierraPacificPower33MorganStanleyCapitalGroupInc.
34
TOTAL
Page 328.1FERCFORMNO.1 (ED.12-90)
Name of Respondent
Idaho Power Company
This Report Is:
(1)fx]An Original
(2)]|A Resubmission
TRSR'S'MrS5T0N"0F'ElKTRTC'ITYTO"FTOTRERS'(AccouTii'456)(Continued)
(Including transactions reffered to as 'wheeling')
Date of Report
(Mo,Da,Yr)
04/15/2016
Year/Period of Report
End of 2015/Q4
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.
8.Report in column (i)and (j)the total megawatthours received and delivered.
Point of Receipt
(Subsatation or Other
Designation)
Point of Delivery
(Substation or Other
Designation)
BillingFERCRate
Schedule of
TRANSFER OF ENERGY
Megawatt Hours
Delivered
LineDemandMegaWattHours
Received
No.(MW)Tariff Number
(i)0)(f)(g)(h)(e)
115 115 17/8 BPAT.NWMT M345
40 2407/8 BRDY M345
6262 37/8 GSHN LAGRANDE
3,286 43,2867/8 BORAHMWY
635 635 57/8 HMWY M345
140 61407/8 JBSN M345
1,669 1,665 77/8 LAGRANDE BORA
9,565 9,565 87/8 LAGRANDE M345
40 40 97/8 LOLO BORA
1,762 1,762 107/8 LOLO M345
1,214 1,214 11LAGRANDE7/8 M345
250 250 12BORA7/8 SMLK
137/8
379 143797/8 LAGRANDE M345
153093097/8 AVAT.NWMT BORA
25 25 167/8 AVAT.NWMT HMWY
856 856 177/8 AVAT.NWMT LAGRANDE
47,673 47,673 187/8 AVAT.NWMT M345
29,450 1929,4507/8 AVAT.NWMT M345
204104107/8 BORA LAGRANDE
3,187 3,187 217/8 BORA M345
1,350 1,350 22BORA7/8 BPAT.NWMT
612 612 237/8 BPAT.NWMT BRDY
6,720 24LAGRANDE6,7207/8 BPAT.NWMT
6,527 6,527 257/8 BPAT.NWMT M345
5,382 5,382 267/8 BPAT.NWMT M345
19 19 277/8 BRDY AVAT.NWMT
540540 287/8 BRDY BORA
607 607 29HMWY7/8 BRDY
10 10 30HURR7/8 BRDY
10,379 10,379 31LAGRANDE7/8 BRDY
186 186 32LOLO7/8 BRDY
37,611 37,611 337/8 BRDY M345
34
0 5,920,350 5,920,350
Page 329.1FERCFORMNO.1 (ED.12-90)
This Report Is:
(1)[xj An Original
(2)A Resubmission
Name of Respondent
Idaho Power Company
Date of Report
(Mo.Da,Yr)
04/15/2016
Year/Period of Report
End of 2015/Q4
TRANSMISSION ELECTRICITY FOR OTHERS (Account 456.1)
(Including transactions referred to as 'wheeling')
1 .Report all transmission of electricity,i.e.,wheeling,provided for other electric utilities,cooperatives,other public authorities,
qualifying facilities,non-traditional utility suppliers and ultimate customers for the quarter.
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:
FNO -Firm Network Service for Others,FNS -Firm Network Transmission Service for Self,LFP -"Long-Term Firm Point to Point
Transmission Service,OLF -Other Long-Term Firm Transmission Service,SFP -Short-Term Firm Point to Point Transmission
Reservation,NF -non-firm transmission service,OS -Other Transmission Service and AD -Out-of-Period Adjustments.Use this code
for any accounting adjustments or "true-ups"for service provided in prior reporting periods.Provide an explanation in a footnote for
each adjustment.See General Instruction for definitions of codes.
Statistical
Classifi
cation
Energy Received From
(Company of Public Authority)
(Footnote Affiliation)
Energy Delivered To
(Company of Public Authority)
(Footnote Affiliation)
Payment By
(Company of Public Authority)
(Footnote Affiliation)
Line
No.
(d)(b)(c)(a)
SFPPacifiCorpWest1MorganStanleyCapitalGroupInc.PacifiCorp East
NFPacifiCorpEast2MorganStanleyCapitalGroupInc.PacifiCorp West
NFPacifiCorpEast3MorganStanleyCapitalGroupInc.PacifiCorp West
NF4MorganStanleyCapitalGroupInc.PacifiCorp West Sierra Pacific Power
NF5MorganStanleyCapitalGroupInc.Idaho Power Company PacifiCorp East
NFIdahoPowerCompanyPacifiCorpEast6MorganStanleyCapitalGroupInc.
NFIdahoPowerCompanySierraPacificPower7MorganStanleyCapitalGroupInc.
NFSierraPacificPower8MorganStanleyCapitalGroupInc.PacifiCorp East
SFPPacifiCorpWest9MorganStanleyCapitalGroupInc.PacifiCorp West
NFSierraPacificPower10MorganStanleyCapitalGroupInc.Idaho Power Company
NF11MorganStanleyCapitalGroupInc.PacifiCorp East PacifiCorp East
NF12MorganStanleyCapitalGroupInc.PacifiCorp East Bonneville Power Administration
NFSierraPacificPower13MorganStanleyCapitalGroupInc.PacifiCorp East
SFPNorthWestern/PacifiCorp East PacifiCorp West14MorganStanleyCapitalGroupInc.
NFPacifiCorpEast15MorganStanleyCapitalGroupInc.Bonneville Power Administration
SFPPacifiCorpEast16MorganStanleyCapitalGroupInc.Bonneville Power Administration
NF17MorganStanleyCapitalGroupInc.Bonneville Power Administration PacifiCorp East
NFBonnevillePowerAdministrationSierraPacificPower18MorganStanleyCapitalGroupInc.
SFPPacifiCorpWest19MorganStanleyCapitalGroupInc.Bonneville Power Administration
NFPacifiCorpEast20MorganStanleyCapitalGroupInc.Avista
SFPPacifiCorpEast21MorganStanleyCapitalGroupInc.Avista
NF22MorganStanleyCapitalGroupInc.PacifiCorp EastAvista
NFPacifiCorpEast23MorganStanleyCapitalGroupInc.Avista
NFBonnevillePowerAdministration24MorganStanleyCapitalGroupInc.Avista
NFSierraPacificPower25MorganStanleyCapitalGroupInc.Avista
SFPPacifiCorpWest26MorganStanleyCapitalGroupInc.Avista
NFSierraPacificPowerNorthWestern/PacifiCorp East27MorganStanleyCapitalGroupInc.
NFNorthWestern/PacifiCorp East28MorganStanleyCapitalGroupInc.Sierra Pacific Power
NFPacifiCorpEast29MorganStanleyCapitalGroupInc.Sierra Pacific Power
NFSierraPacificPowerPacifiCorpEast30MorganStanleyCapitalGroupInc.
NFSierraPacificPowerBonnevillePowerAdministration31MorganStanleyCapitalGroupInc.
NFSierraPacificPower32MorganStanleyCapitalGroupInc.Avista
AD33MorganStanleyCapitalGroupInc.
34
TOTAL
Page 328.2FERCFORMNO.1 (ED.12-90)
This Report Is:
m An Original
Date of Report
(Mo,Da,Yr)
(2)f |A Resubmission 04/15/2016
TRSWSMrS'SI'Ofil'OF ELECTRICITVFOR OTHERS (Account 456)(Continue3]
(Including transactions reffered to as 'wheeling')
Year/Period of Report
End of 2015/Q4
Name of Respondent
Idaho Power Company (1)
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.
8.Report in column (i)and (j)the total megawatthours received and delivered.
FERC Rate
Schedule of
Tariff Number
Point of Receipt
(Subsatation or Other
Designation)
Point of Delivery
(Substation or Other
Designation)
Billing
Demand
TRANSFER OF ENERGY Line
Megawatt Hours
Received
MegaWatt Hours
Delivered
No.(MW)
(j)(h)(i)(e)(f)(g)
13,8857/8 3,885BRDYM345
1.37S 2BORA1,3797/8 ENPR
146 31467/8 ENPR BRDY
8,288 48,2887/8 ENPR M345
804804 57/8 HMWY BORA
134 61347/8 BRDYHMWY
5,033 75,0337/8 HMWY M345
1 ,366 81,3667/8 JBSN M345
4,081 94,0817/8 JBSN M345
287 102877/8 JBWT M345
316 113167/8 BORAJEFF
1 1 ,344 1211,3447/8 LAGRANDEJEFF
13158,131 158,1317/8 JEFF M345
1,450 1,450 147/8 JEFF M345
3,142 3,142 15BOFtA7/8 LAGRANDE
566 16BOFtA5667/8 LAGRANDE
1,844 171,8447/8 LAGRANDE BRDY
27,130 1827,1307/8 LAGRANDE M345
140 191407/8 LAGRANDE M345
6,3566,356 207/8 BOFtALOLO
368 21BORA3687/8 LOLO
507 225077/8 LOLO BRDY
32 23327/8 LOLO JEFF
117 117 247/8 LOLO LAGFtANDE
135,160 25135,1607/8 LOLO M345
191,191 26191,1917/8 LOLO M345
451 274517/8 AVAT.NWMTM345
416416 28BPAT.NWMT7/8 M345
80 29807/8 M345 BRDY
82 30827/8 M345 JEFF
415 314157/8 LAGRANDEM345
95 32957/8 LOLOM345
337/8
34
5,920,35005,920,350
Page 329.2FERCFORMNO.1 (ED.12-90)
This Report Is:
(1)[X]An Original
(2)||A Resubmission
Name of Respondent
Idaho Power Company
Date of Report
(Mo,Da,Yr)
04/15/2016
Year/Period of Report
2015/Q4Endof
TRANSMISSION ELECTRICITY FOR OTHERS (Account 466."I)
(Including transactions referred to as 'wheeling')
1 .Report all transmission of electricity,i.e.,wheeling,provided for other electric utilities,cooperatives,other public authorities,
qualifying facilities,non-traditional utility suppliers and ultimate customers for the quarter.
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:
FNO -Firm Network Service for Others,FNS -Firm Network Transmission Service for Self,LFP -"Long-Term Firm Point to Point
Transmission Service,OLF -Other Long-Term Firm Transmission Service,SFP -Short-Term Firm Point to Point Transmission
Reservation,NF -non-firm transmission service,OS -Other Transmission Service and AD -Out-of-Period Adjustments.Use this code
for any accounting adjustments or "true-ups"for service provided in prior reporting periods.Provide an explanation in a footnote for
each adjustment.See General Instruction for definitions of codes.
Energy Delivered To
(Company of Public Authority)
(Footnote Affiliation)
Statistical
Classifi
cation
Payment By
(Company of Public Authority)
(Footnote Affiliation)
Energy Received From
(Company of Public Authority)
(Footnote Affiliation)
Line
No.
(a)(b)(c)(d)
NFSierraPacificPower1NevadaPowerCompanyPacifiCorpEast
NFSierraPacificPower2NevadaPowerCompanyPacifiCorpEast
NF3NevadaPowerCompanyIdahoPowerCompanySierraPacificPower
NF4NevadaPowerCompanyPacifiCorpEastSierraPacificPower
NF5NevadaPowerCompanySierraPacificPowerBonnevillePowerAdministration
NF6NevadaPowerCompanySierraPacificPowerAvista
SFPPacifiCorpWest7NevadaPowerCompanyAvista
AD8NevadaPowerCompany
NF9PacifiCorpInc.PacifiCorp East PacifiCorp West
NF10PacifiCorpInc.PacifiCorp East Idaho Power Company
NF11PacifiCorpInc.PacifiCorp East PacifiCorp West
NF12PacifiCorpInc.PacifiCorp East Sierra Pacific Power
NFPacifiCorpEast13PacifiCorpInc.PacifiCorp East
SFPPacifiCorpEast14PacifiCorpInc.PacifiCorp East
NFPacifiCorpWest15PacifiCorpInc.PacifiCorp East
NF16PacifiCorpInc.PacifiCorp East PacifiCorp East
NF17PacifiCorpInc.PacifiCorp East Bonneville Power Administration
NF18PacifiCorpInc.PacifiCorp West PacifiCorp East
SFPPacifiCorpWestPacifiCorpEast19PacifiCorpInc.
NFPacifiCorpEast20PacifiCorpInc.PacifiCorp West
NFPacifiCorpEast21PacifiCorpInc.PacifiCorp West
SFP22PacifiCorpInc.PacifiCorp West PacifiCorp East
NFIdahoPowerCompanyPacifiCorpEast23PacifiCorpInc.
NFPacifiCorpEast24PacifiCorpInc.Idaho Power Company
NFIdahoPowerCompany25PacifiCorpInc.Idaho Power Company
NFIdahoPowerCompanyPacifiCorpEast26PacifiCorpInc.
NFBonnevillePowerAdministration27PacifiCorpInc.Idaho Power Company
NF28PacifiCorpInc.Idaho Power Company Avista
NFPacifiCorpEast29PacifiCorpInc.Avista
NFPacifiCorpWest30PacifiCorpInc.Avista
AD31PacifiCorpInc.
NFNorthWestern/PacifiCorp East32PortlandGeneralElectricCompanyPacifiCorpEast
NFBonnevillePowerAdministration33PortlandGeneralElectricCompanyPacifiCorpEast
34
TOTAL
Page 328.3FERCFORMNO.1 (ED.12-90)
This Report Is:
(1)[xj An Original
(2)I IA Resubmission
TRANSMISSION OF FLFCTRIClTYTTTR OTHERS (Account 456)(Contmued]
(Including transactions reffered to as 'wheeling')
Name of Respondent
Idaho Power Company
Date of Report
(Mo,Da,Yr)
04/15/2016
Year/Period of Report
End of 2015/Q4
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.
8.Report in column (i)and (j)the total megawatthours received and delivered.
FERC Rate
Schedule of
Tariff Number
Point of Receipt
(Subsatation or Other
Designation)
Point of Delivery
(Substation or Other
Designation)
Billing
Demand
TRANSFER OF ENERGY
MegaWatt Hours
Delivered
Line
MegaWatt Hours
Received
No.(MW)
(e)(f)(g)(h)(i)G)
7/8 BORA M345 2,020 2,020 1
7/8 BRDY M345 1,011 1,011 2
7/8 HMWY M345 750 750 3
7/8 JEFF M345 1,409 1,409 4
7/8 LAGRANDE M345 701 701 5
7/8 LOLO M345 4,065 4,065 6
7/8 LOLO M345 2,400 2,400 7
7/8 8
7/8 BORA ENPR 4,279 4,279 9
7/8 BORA HMWY 745 745 10
7/8 BORA HURR 837 837 11
7/8 BOFtA M345 48 48 12
7/8 BRDY BRDY 1,0611,061 13
7/8 BRDY BRDY 2,2442,244 14
7/8 BRDY ENPR 7,978 7,978 15
7/8 BRDY KPRT 553 553 16
7/8 BRDY LAGRANDE 16,396 16,396 17
7/8 ENPR BORA 136,570 136,570 18
7/8 ENPR BORA 2,176 2,176 19
7/8 ENPR BRDY 884 884 20
7/8 HURR BORA 219 219 21
7/8 HURR BORA 5,604 5,604 22
7/8 JBWT BOFtA 1,126 1,126 23
7/8 JBWT GSHN 51 2451
7/8 JBWT HMWY 4,000 4,000 25
7/8 JBWT KPRT 4,975 4,975 26
7/8 JBWT LAGRANDE 154,480 154,480 27
7/8 JBWT LOLO 1,637 1,637 28
7/8 LOLO BORA 2,239 2,239 29
7/8 LOLO ENPR 8,820 8,820 30
7/8 31
7/8 BORA BPAT.NWMT 250 25C 32
7/8 BORA LAGRANDE 1,670 1,670 33
34
0 5,920,350 5,920,350
Page 329.3FERCFORMNO.1 (ED.12-90)
This Report is:
§Date of Report
(Mo,Da,Yr)
04/15/2016
TRANSMISSION C5F ELECTRICITY FOR OTHERS (Account 456.1)
(Including transactions referred to as 'wheeling')
Year/Period of Report
End of 201 5/Q4
Name of Respondent
Idaho Power Company (1)An Original
(2)A Resubmission
1 .Report all transmission of electricity,i.e.,wheeling,provided for other electric utilities,cooperatives,other public authorities,
qualifying facilities,non-traditional utility suppliers and ultimate customers for the quarter.
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:
FNO -Firm Network Service for Others,FNS -Firm Network Transmission Service for Self,LFP -"Long-Term Firm Point to Point
Transmission Service,OLF -Other Long-Term Firm Transmission Service,SFP -Short-Term Firm Point to Point Transmission
Reservation,NF -non-firm transmission service,OS -Other Transmission Service and AD -Out-of-Period Adjustments.Use this code
for any accounting adjustments or "true-ups"for service provided in prior reporting periods.Provide an explanation in a footnote for
each adjustment.See General Instruction for definitions of codes.
Statistical
Classifi
cation
Energy Delivered To
(Company of Public Authority)
(Footnote Affiliation)
Payment By
(Company of Public Authority)
(Footnote Affiliation)
Energy Received From
(Company of Public Authority)
(Footnote Affiliation)
Line
No.
(d)(b)(c)(a)
NFSierraPacificPower1PortlandGeneralElectricCompanyPacifiCorpEast
NF2PortlandGeneralElectricCompanyNorthWestern/PacifiCorp East PacifiCorp East
NFNorthWestern/PacifiCorp East Sierra Pacific Power3PortlandGeneralElectricCompany
NFPacifiCorpEastBonnevillePowerAdministration4PortlandGeneralElectricCompany
NFIdahoPowerCompanyPacifiCorpEast5PortlandGeneralElectricCompany
NFSierraPacificPower6PortlandGeneralElectricCompanyIdahoPowerCompany
NFPacifiCorpEast7PortlandGeneralElectricCompanyIdahoPowerCompany
NF8PortlandGeneralElectricCompanyIdahoPowerCompanyBonnevillePowerAdministration
NFPacifiCorpEastBonnevillePowerAdministration9PortlandGeneralElectricCompany
NFBonnevillePowerAdministrationPacifiCorpEast10PortlandGeneralElectricCompany
NFSierraPacificPower11PortlandGeneralElectricCompanyBonnevillePowerAdministration
NFSierraPacificPowerNorthWestern/PacifiCorp East12PortlandGeneralElectricCompany
NFSierraPacificPowerBonnevillePowerAdministration13PortlandGeneralElectricCompany
AD14PortlandGeneralElectricCompany
NFSierraPacificPowerNorthWestern/PacifiCorp East15PowerexCorporation
SFPNorthWestern/PacifiCorp EastPacifiCorpEast16PowerexCorporation
NFPacifiCorpEastPacifiCorpWest17PowerexCorporation
NFPacifiCorpEastIdahoPowerCompany18PowerexCorporation
NFPacifiCorpEastPacifiCorpEast19PowerexCorporation
NFBonnevillePowerAdministration20PowerexCorporationPacifiCorpEast
NFSierraPacificPowerPacifiCorpEast21PowerexCorporation
NFNorthWestern/PacifiCorp East PacifiCorp East22PowerexCorporation
SFPNorthWestern/PacifiCorp East PacifiCorp East23PowerexCorporation
NFNorthWestern/PacifiCorp East PacifiCorp East24PowerexCorporation
NFIdahoPowerCompanyNorthWestern/PacifiCorp East25PowerexCorporation
NFNorthWestern/PacifiCorp East Bonneville Power Administration26PowerexCorporation
NFNorthWestern/PacifiCorp East Sierra Pacific Power27PowerexCorporation
SFPNorthWestern/PacifiCorp East PacifiCorp West28PowerexCorporation
NFNorthWestern/PacifiCorp EastPacifiCorpEast29PowerexCorporation
NFPacifiCorpEastIdahoPowerCompany30PowerexCorporation
NFPacifiCorpEastBonnevillePowerAdministration31PowerexCorporation
NFPacifiCorpEastSierraPacificPower32PowerexCorporation
NFPacifiCorpWestPacifiCorpEast33PowerexCorporation
34
TOTAL
Page 328.4FERCFORMNO.1 (ED.12-90)
This Report Is:
[X]An Original
j I A Resubmission
TRANSMISSION OF ELECTRICITY FOR OTHERS (Abcount 456)(Continued)
(Including transactions reffered to as 'wheeling')
Dale of Report
(Mo.Da,Yr)
04/15/2016
Year/Period of Report
End of 2015/Q4
Name of Respondent
Idaho Power Company (1)
(2)
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.
8.Report in column (i)and (j)the total megawatthours received and delivered.
Point of Delivery
(Substation or Other
Designation)
FERC Rate
Schedule of
Tariff Number
Point of Receipt
(Subsatation or Other
Designation)
Billing
Demand
TRANSFER OF ENERGY
MegaWatt Hours
Delivered
Line
MegaWatt Hours
Received
No.(MW)
G)(g)(h)(i)(e)(f)
2 2 17/8 BORA M345
200 200 27/8 BORABPAT.NWMT
100 100 3M3457/8 BPAT.NWMT
10,396 4LAGRANDE10,3967/8 BRDY
1,535BORA1,535 57/8 HMWY
3,900 3,900 67/8 M345HMWY
114114 77/8 BORAJBWT
75 87/8 LAGRANDE 75JBWT
1,435 1,435 9LAGRANDE7/8 JEFF
979 979 10BORA7/8 LAGRANDE
813 813 117/8 LAGRANDE M345
1250507/8 BPAT.NWMTM345
324 324 137/8 LAGRANDEM345
147/8
76 76 157/8 M345AVAT.NWMT
512 512 16BPAT.NWMT7/8 BORA
80 80 177/8 BORA ENPR
525 185257/8 BORA HMWY
3C 19307/8 BORA JEFF
211 211 207/8 BORA LAGRANDE
184184 21M3457/8 BORA
1,558 1,558 22BORA7/8 BPAT.NWMT
23BORA2,613 2,6137/8 BPAT.NWMT
588 588 247/8 BRDYBPAT.NWMT
43 43 25IPCOLOSS7/8 BPAT.NWMT
1,012 1,012 26LAGRANDE7/8 BPAT.NWMT
7,276 7,276 277/8 BPAT.NWMT M345
55,295 55,295 28M3457/8 BPAT.NWMT
213 213 29BPAT.NWMT7/8 BRDY
41 41 307/8 BRDY HMWY
2,849 31LAGRANDE2,8497/8 BRDY
2,4302,430 327/8 M345BRDY
47,641 47,641 33BORA7/8 ENPR
34
5,920,350 5,920,3500
Page 329.4FERCFORMNO.1 (ED.12-90)
This Report Is:
(1)[x]An Original
(2)||A Resubmission
TRANSMISSION OF "ELECTRICITY FOR OTHERS (Account 456T)
(Including transactions referred to as 'wheeling')
Name of Respondent
Idaho Power Company
Date of Report
(Mo,Da,Yr)
04/15/2016
Year/Period of Report
End of 2015/Q4
1 .Report all transmission of electricity,i.e.,wheeling,provided for other electric utilities,cooperatives,other public authorities,
qualifying facilities,non-traditional utility suppliers and ultimate customers for the quarter.
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:
FNO -Firm Network Service for Others,FNS -Firm Network Transmission Service for Self,LFP -"Long-Term Firm Point to Point
Transmission Service,OLF -Other Long-Term Firm Transmission Service,SFP -Short-Term Firm Point to Point Transmission
Reservation,NF -non-firm transmission service,OS -Other Transmission Service and AD -Out-of-Period Adjustments.Use this code
for any accounting adjustments or "true-ups"for service provided in prior reporting periods.Provide an explanation in a footnote for
each adjustment.See General Instruction for definitions of codes.
Statistical
Classifi
cation
Payment By
(Company of Public Authority)
(Footnote Affiliation)
Energy Received From
(Company of Public Authority)
(Footnote Affiliation)
Energy Delivered To
(Company of Public Authority)
(Footnote Affiliation)
Line
No.
(d)(a)(b)(c)
SFP1PowerexCorporationPacifiCorpWestPacifiCorpEast
NF2PowerexCorporationPacifiCorpWestPacifiCorpEast
NFSierraPacificPower3PowerexCorporationPacifiCorpWest
SFP4PowerexCorporationPacifiCorpWestPacifiCorpWest
NF5PowerexCorporationPacifiCorpEastBonnevillePowerAdministration
NF6PowerexCorporationPacifiCorpEastSierraPacificPower
NF7PowerexCorporationIdahoPowerCompanyPacifiCorpEast
NF8PowerexCorporationIdahoPowerCompanyPacifiCorpEast
NFIdahoPowerCompanySierraPacificPower9PowerexCorporation
NFSierraPacificPower10PowerexCorporationPacifiCorpEast
NF11PowerexCorporationIdahoPowerCompanyIdahoPowerCompany
NF12PowerexCorporationPacifiCorpEastPacifiCorpEast
NF13PowerexCorporationPacifiCorpEastPacifiCorpEast
NF14PowerexCorporationBonnevillePowerAdministrationPacifiCorpEast
NF15PowerexCorporationPacifiCorpEastBonnevillePowerAdministration
NFIdahoPowerCompany16PowerexCorporationBonnevillePowerAdministration
NFSierraPacificPower17PowerexCorporationBonnevillePowerAdministration
SFP18PowerexCorporationBonnevillePowerAdministrationPacifiCorpWest
NF19PowerexCorporationPacifiCorpEastAvista
NF20PowerexCorporationPacifiCorpEastAvista
NF21PowerexCorporationSierraPacificPowerAvista
SFP22PowerexCorporationAvistaPacifiCorpWest
NF23PowerexCorporationSierraPacificPowerPacifiCorpEast
NF24PowerexCorporationSierraPacificPowerNorthWestern/PacifiCorp East
NF25PowerexCorporationSierraPacificPowerPacifiCorpEast
NF26PowerexCorporationSierraPacificPowerBonnevillePowerAdministration
NF27PowerexCorporationPacifiCorpWestPacifiCorpEast
NF28PowerexCorporationPacifiCorpWestPacifiCorpEast
NFPacifiCorpWestSierraPacificPower29PowerexCorporation
AD30PowerexCorporation
NFNorthWestern/PacifiCorp East31PugetSoundEnergy,Inc.Sierra Pacific Power
NF32PugetSoundEnergy,Inc.Sierra Pacific Power Bonneville Power Administration
SFP33ShellEnergyNorthAmerica(US),L.P.PacifiCorp East Sierra Pacific Power
34
TOTAL
Page 328.5FERCFORMNO.1 (ED.12-90)
This Report is:
(1 )|x)An Original
Date of Report
(Mo.Da,Yr)
04/15/2016
Year/Period of Report
End of 2015/Q4
Name of Respondent
Idaho Power Company (2)||A Resubmission
TRANSMISSION OF ELECTRICITY FOR OTHERS (Account T56)("ContinueT)(Including transactions refferod to as 'wheeling')
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.
8.Report in column (i)and (j)the total megawatthours received and delivered.
FERC Rate
Schedule of
Tariff Number
Point of Delivery
(Substation or Other
Designation)
Billing
Demand
Point of Receipt
(Subsatation or Other
Designation)
TRANSFER OF ENERGY
MegaWatt Hours
Delivered
Line
MegaWatt Hours
Received
No.
(MW)
G)(e)(9)(h)G)(f)
12,700 112,7007/8 ENPR BORA
1,590 21,5907/8 ENPR BRDY
6,1526,152 37/8 M345ENPR
2,534 47/8 2,534ENPRM345
905 57/8 GSHN LAGRANDE 905
60 67/8 60GSHNM345
44,47544,475 77/8 HMWY BORA
3,587 3,587 87/8 HMWY BRDY
22,74622,746 97/8 HMWY M345
49 49 107/8 JBSN M345
265 117/8 HMWY 265JBWT
25 127/8 BORA 25JEFF
59 13597/8 JEFF BRDY
15,644 14BORA15,6447/8 LAGRANDE
3,6283,628 157/8 LAGRANDE BRDY
27 27 167/8 LAGRANDE IPCOLOSS
56,73256,732 177/8 LAGFtANDE M345
266 187/8 LAGRANDE M345 266
885 19BORA8857/8 LOLO
216 202167/8 LOLO BRDY
2114,872 14,8727/8 LOLO M345
7,598 227/8 LOLO 7,598M345
125 23BORA1257/8 M345
116 241167/8 M345 BPAT.NWMT
50 50 257/8 M345 JEFF
2,764 267/8 LAGRANDE 2,764M345
3,003 27BORA3,0037/8 SMLK
138 281387/8 SMLK BRDY
648 648 297/8 SMLK M345
307/8
1 1 317/8 BPAT.NWMTM345
40 32LAGRANDE407/8 M345
440 334407/8 BORA M345
34
5,920,350 5,920,3500
Page 329.5FERCFORMNO.1 (ED.12-90)
This Report Is:
(1)[X]An Original
Date of Report
(Mo.Da,Yr)
04/15/2016
Name of Respondent
Idaho Power Company
Year/Period of Report
End of 2015/Q4
TRANSMISSION 9 ELECTRICITY FOR OTHERS (Account 456.1)
(Including transactions referred to as 'wheeling)
(2)A Resubmission
1 .Report all transmission of electricity,i.e.,wheeling,provided for other electric utilities,cooperatives,other public authorities,
qualifying facilities,non-traditional utility suppliers and ultimate customers for the quarter.
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:
FNO -Firm Network Service for Others,FNS -Firm Network Transmission Service for Self,LFP -"Long-Term Firm Point to Point
Transmission Service,OLF -Other Long-Term Firm Transmission Service,SFP -Short-Term Firm Point to Point Transmission
Reservation,NF -non-firm transmission service,OS -Other Transmission Service and AD -Out-of-Period Adjustments.Use this code
for any accounting adjustments or "true-ups"for service provided in prior reporting periods.Provide an explanation in a footnote for
each adjustment.See General Instruction for definitions of codes.
Statistical
Classifi
cation
Payment By
(Company of Public Authority)
(Footnote Affiliation)
Energy Received From
(Company of Public Authority)
(Footnote Affiliation)
Energy Delivered To
(Company of Public Authority)
(Footnote Affiliation)
Line
No.
(a)(b)(c)(d)
NF1ShellEnergyNorthAmerica(US),L.P.PacifiCorp East NorthWestern/PacifiCorp East
NF2ShellEnergyNorthAmerica(US),L.P,PacifiCorp East Bonneville Power Administration
NF3ShellEnergyNorthAmerica(US),L.P.PacifiCorp East Sierra Pacific Power
SFP4ShellEnergyNorthAmerica(US),L.P.PacifiCorp East PacifiCorp West
NF5ShellEnergyNorthAmerica(US),L.P.PacifiCorp West Bonneville Power Administration
NF6ShellEnergyNorthAmerica(US),L.P.PacifiCorp West Sierra Pacific Power
NF7ShellEnergyNorthAmerica(US),L.P.Idaho Power Company Sierra Pacific Power
SFP8ShellEnergyNorthAmerica(US),L.P.Idaho Power Company PacifiCorp West
NF9ShellEnergyNorthAmerica(US),L.P.Idaho Power Company PacifiCorp East
NF10ShellEnergyNorthAmerica(US),L.P.Idaho Power Company Bonneville Power Administration
NF11ShellEnergyNorthAmerica(US),L.P.Idaho Power Company Sierra Pacific Power
NF12ShellEnergyNorthAmerica(US),L.P.PacifiCorp East Bonneville Power Administration
NF13ShellEnergyNorthAmerica(US),L.P.PacifiCorp East Sierra Pacific Power
SFP14ShellEnergyNorthAmerica(US),L.P.NorthWestern/PacifiCorp East PacifiCorp West
NF15ShellEnergyNorthAmerica(US),L.P,Bonneville Power Administration PacifiCorp East
SFP16ShellEnergyNorthAmerica(US),L.P.Bonneville Power Administration PacifiCorp East
NF17ShellEnergyNorthAmerica(US),L.P.Bonneville Power Administration Avista
NF18ShellEnergyNorthAmerica(US),L.P.Sierra Pacific PowerBonnevillePowerAdministration
SFP19ShellEnergyNorthAmerica(US),L.P.PacifiCorp WestBonnevillePowerAdministration
NF20ShellEnergyNorthAmerica(US),L.P.Avista Idaho Power Company
NF21ShellEnergyNorthAmerica(US),L.P.Avista Bonneville Power Administration
NF22ShellEnergyNorthAmerica(US),L.P.Sierra Pacific PowerAvista
SFP23ShellEnergyNorthAmerica(US),L.P.PacifiCorp WestAvista
SFP24ShellEnergyNorthAmerica(US),L.P.Idaho Power Company PacifiCorp East
NF25ShellEnergyNorthAmerica(US),L.P.Idaho Power Company PacifiCorp East
SFP26ShellEnergyNorthAmerica(US),L.P.Sierra Pacific Power PacifiCorp East
NF27ShellEnergyNorthAmerica(US),L.P.Idaho Power Company Idaho Power Company
NF28ShellEnergyNorthAmerica(US),L.P.Idaho Power Company Bonneville Power Administration
NF29ShellEnergyNorthAmerica(US),L.P.Idaho Power Company Sierra Pacific Power
SFP30ShellEnergyNorthAmerica(US),L.P.Sierra Pacific Power PacifiCorp West
NF31ShellEnergyNorthAmerica(US),L.P.Sierra Pacific Power PacifiCorp East
NF32ShellEnergyNorthAmerica(US),L.P.Sierra Pacific Power Idaho Power Company
NF33ShellEnergyNorthAmerica(US),L.P.Sierra Pacific Power Bonneville Power Administration
34
TOTAL
Page 328.6FERCFORMNO.1 (ED.12-90)
This Report Is:
(1)|x]An Original
(2)I IA Resubmission
Name of Respondent
Idaho Power Company
Dale of Report
(Mo,Da,Yr)
04/15/2016
Year/Period of Report
2015/Q4Endof
TRANSMIS'SI'ON'OF ELECTRICITY'FOJTOTHERS'(Account 456y(Cbntihi7ed)
(Including transactions reffered to as 'wheeling')
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.
8.Report in column (i)and (j)the total megawatthours received and delivered.
FERC Rate
Schedule of
Tariff Number
Point of Receipt
(Subsatation or Other
Designation)
Point of Delivery
(Substation or Other
Designation)
Billing
Demand
TRANSFER OF ENERGY
MegaWatt Hours
Delivered
Line
MegaWatt Hours
Received
No.(MW)
(e)(f)(9)(h)(i)G)
7/8 BRDY BPAT.NWMT 15050
7/8 BRDY LAGRANDE 3,387 3,387 2
43,016 37/8 BRDY M345 43,016
7/8 BRDY M345 68,767 68,767 4
7/8 ENPR LAGRANDE 36 36 5
7/8 ENPR M345 1,218 1,218 6
7/8 HMWY 5,144M345 5,144 7
7/8 HMWY 2,417M3452,417 8
7/8 IPCOGEN BRDY 30 30 9
7/8 IPCOGEN 924LAGRANDE 924 10
7/8 IPCOGEN M345 1155
7/8 JEFF LAGRANDE 182 182 12
7/8 JEFF M345 651 13651
7/8 JEFF M345 1,176 141,176
7/8 LAGRANDE BRDY 1,040 1,040 15
7/8 LAGRANDE BRDY 900 900 16
7/8 LAGRANDE LOLO 56 56 17
7/8 LAGRANDE M345 98,756 98,756 18
7/8 LAGRANDE M345 1,216 1,216 19
7/8 LOLO IPCO 56 2056
7/8 LOLO LAGRANDE 68 68 21
7/8 LOLO M345 7,660 7,660 22
7/8 LOLO M345 16,512 16,512 23
7/8 LYPK BORA 230 24230
7/8 LYPK BRDY 19,241 19,241 25
7/8 LYPK BRDY 5,464 5,464 26
7/8 LYPK HMWY 71 71 27
7/8 LYPK LAGRANDE 10,872 10,872 28
7/8 LYPK M345 77,800 77,800 29
7/8 LYPK M345 132,217 132,217 30
7/8 M345 BRDY 50 50 31
7/8 M345 HMWY 248 248 32
7/8 M345 LAGRANDE 4,397 4,397 33
34
0 5,920,350 5,920,350
Page 329.6FERCFORMNO.1 (ED.12-90)
This Report Is:
[XJ An Original
Name of Respondent
Idaho Power Company
Date of Report
{Mo.Da,Vr)
04/15/2016
Year/Period of Report
End of 2015/Q4(1)
HA Resubmission
Transmission of electricity for others (Account 456.1)
(including transactions referred lo as 'wheeling')
(2)
1 .Report all transmission of electricity,i.e.,wheeling,provided for other electric utilities,cooperatives,other public authorities,
qualifying facilities,non-traditional utility suppliers and ultimate customers for the quarter.
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:
FNO -Firm Network Service for Others,FNS -Firm Network Transmission Service for Self,LFP -"Long-Term Firm Point to Point
Transmission Service,OLF -Other Long-Term Firm Transmission Service,SFP -Short-Term Firm Point to Point Transmission
Reservation,NF -non-firm transmission service,OS -Other Transmission Service and AD -Out-of-Period Adjustments.Use this code
for any accounting adjustments or "true-ups"for service provided in prior reporting periods.Provide an explanation in a footnote for
each adjustment.See General Instruction for definitions of codes.
Payment By
(Company of Public Authority)
(Footnote Affiliation)
Energy Received From
(Company of Public Authority)
(Footnote Affiliation)
Energy Delivered To
(Company of Public Authority)
(Footnote Affiliation)
Statistical
Classifi
cation
Line
No,
(a)(b)(c)(d)
NF1ShellEnergyNorthAmerica(US),L.P.Idaho Power Company Bonneville Power Administration
NF2ShellEnergyNorthAmerica(US),L.P.Idaho Power Company Avista
NF3ShellEnergyNorthAmerica(US),L.P.Idaho Power Company Bonneville Power Administration
NF4ShellEnergyNorthAmerica(US),L.P.PacifiCorp West Sierra Pacific Power
SFP5ShellEnergyNorthAmerica(US),L.P.PacifiCorp West PacifiCorp West
AD6ShellEnergyNorthAmerica(US),L.P.
NF7TalenEnergyNorthWestern/PacifiCorp East Bonneville Power Administration
NF8TalenEnergyPacifiCorpEastIdahoPowerCompany
NF9TalenEnergyPacifiCorpEastIdahoPowerCompany
NF10TalenEnergyPacifiCorpEastBonnevillePowerAdministration
NF11TalenEnergyIdahoPowerCompanyPacifiCorpEast
NF12TalenEnergyIdahoPowerCompanySierraPacificPower
NF13TalenEnergyPacifiCorpEastPacifiCorpEast
NF14TalenEnergyPacifiCorpEastBonnevillePowerAdministration
NF15TalenEnergyPacifiCorpEastAvista
NF16TalenEnergySierraPacificPowerPacifiCorpEast
AD17TalenEnergy
NF18TenaskaPowerServicesCo.NorthWestern/PacifiCorp East Sierra Pacific Power
NF19TenaskaPowerServicesCo.PacifiCorp East Bonneville Power Administration
NF20TenaskaPowerServicesCo.PacifiCorp East Sierra Pacific Power
NF21TenaskaPowerServicesCo.PacifiCorp East Sierra Pacific Power
NF22TheEnergyAuthority,Inc.PacifiCorp EastNorthWestern/PacifiCorp East
SFP23TheEnergyAuthority,Inc.NorthWestern/PacifiCorp East PacifiCorp East
NF24TheEnergyAuthority,Inc.NorthWestern/PacifiCorp East Sierra Pacific Power
SFP25TheEnergyAuthority,Inc.NorthWestern/PacifiCorp East PacifiCorp West
NF26TheEnergyAuthority,Inc.NorthWestern/PacifiCorp EastPacifiCorpEast
NF27TheEnergyAuthority,Inc.PacifiCorp East Idaho Power Company
NF28TheEnergyAuthority,Inc.PacifiCorp East Bonneville Power Administration
NF29TheEnergyAuthority,Inc.Idaho Power Company PacifiCorp East
NF30TheEnergyAuthority,Inc.Idaho Power Company PacifiCorp East
NF31TheEnergyAuthority,Inc.Idaho Power Company Sierra Pacific Power
NF32TheEnergyAuthority,Inc.Bonneville Power Administration PacifiCorp East
NF33TheEnergyAuthority,Inc.Bonneville Power Administration PacifiCorp East
34
TOTAL
Page 328.7FERCFORMNO.1 (ED.12-90)
This Report Is:
[X]An Original
Date of Report
(Mo,Da,Yr)
04/15/2016
Year/Period of Report
End of 2015/Q4
Name of Respondent
Idaho Power Company (1)
(2)||A Resubmission
TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456")(Continued)
(Including transactions reffered to as 'wheeling'}
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.
8.Report in column (i)and (j)the total megawatthours received and delivered.
Point of Delivery
(Substation or Other
Designation)
Billing
Demand
FERC Rate
Schedule of
Tariff Number
Point of Receipt
(Subsatation or Other
Designation)
TRANSFER OF ENERGY
MegaWatt Hours
Delivered
Line
MegaWatt Hours
Received
No.
(MW)
0)0)(9)(h)(e)(f)
451 451 1LAGRANDE7/8 MDSK
50 2507/8 MDSK LOLO
135 135 37/8 OBBLPR LAGRANDE
1,082 41,082M3457/8 SMLK
4,1924,192 57/8 SMLK M345
67/8
15 7LAGRANDE157/8 BPAT.NWMT
1,800 81,8007/8 IPCOBRDY
150 91507/8 IPCOEASTBRDY
2,082 102,0827/8 LAGRANDEBRDY
1,340 111,3407/8 HMWY BRDY
129509507/8 HMWY M345
210 210 137/8 JEFF BRDY
447 447 14LAGRANDE7/8 JEFF
175 151757/8 LOLO BRDY
100 161007/8 BRDYM345
177/8
100 18100M3457/8 BPAT.NWMT
167 19167LAGRANDE7/8 BRDY
250 250 207/8 M345BRDY
90C 219007/8 M345JEFF
4,972 224,972BORA7/8 BPAT.NWMT
23400400BORA7/8 BPAT.NWMT
2,368 2,368 247/8 M345BPAT.NWMT
11,713 2511,7137/8 M345BPAT.NWMT
545 26545BPAT.NWMT7/8 BRDY
25 25 277/8 HMWYBRDY
1,182 1,182 28LAGRANDE7/8 BRDY
190 29190BORA7/8 HMWY
161 30161BRDY7/8 HMWY
31505CM3457/8 HMWY
32270270BORA7/8 LAGRANDE
7,444 7,444 337/8 LAGRANDE BRDY
34
5,920,3505,920,3500
Page 329.7FERCFORMNO.1 (ED.12-90)
This Report Is:
[X]An Original
Name of Respondent
Idaho Power Company
Date of Report
(Mo.Da,Yr)
04/15/2016
TRANSMISSION^ELECTRICITY FOR OTHERS {Account 456.1)
(Including transactions referred to as 'wheeling')
Year/Period of Report
End of 2015/Q4(1)
9(2)A Resubmission
1 .Report all transmission of electricity,i.e.,wheeling,provided for other electric utilities,cooperatives,other public authorities,
qualifying facilities,non-traditional utility suppliers and ultimate customers for the quarter.
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:
FNO -Firm Network Service for Others,FNS -Firm Network Transmission Service for Self,LFP -"Long-Term Firm Point to Point
Transmission Service,OLF -Other Long-Term Firm Transmission Service,SFP -Short-Term Firm Point to Point Transmission
Reservation,NF -non-firm transmission service,OS -Other Transmission Service and AD -Out-of-Period Adjustments.Use this code
for any accounting adjustments or "true-ups"for service provided in prior reporting periods.Provide an explanation in a footnote for
each adjustment.See General Instruction for definitions of codes.
Energy Delivered To
(Company of Public Authority)
(Footnote Affiliation)
Statistical
Classifi
cation
Payment By
(Company of Public Authority)
(Footnote Affiliation)
Energy Received From
(Company of Public Authority)
(Footnote Affiliation)
Line
No.
(d)(b)(c)(a)
NF1TheEnergyAuthority,Inc.Bonneville Power Administration Sierra Pacific Power
NF2TheEnergyAuthority,Inc.Sierra Pacific Power NorthWestern/PacifiCorp East
NFSierraPacificPowerPacifiCorpEast3TheEnergyAuthority,Inc.
NFSierraPacificPowerBonnevillePowerAdministration4TheEnergyAuthority,Inc.
AD5TheEnergyAuthority,Inc.
NFPacifiCorpEastIdahoPowerCompany6TransaltaEnergyMarketing(U.S.)Inc.
NF7TransaltaEnergyMarketing(U.S.)Inc.PacifiCorp East Bonneville Power Administration
NF8TransaltaEnergyMarketing(U.S.)Inc.Idaho Power Company PacifiCorp East
NF9TransaltaEnergyMarketing(U.S.)Inc.Idaho Power Company Sierra Pacific Power
NF10TransaltaEnergyMarketing(U.S.)Inc.Bonneville Power Administration PacifiCorp East
NFSierraPacificPower11TransaltaEnergyMarketing(U.S.)Inc.Bonneville Power Administration
NFPacifiCorpEast12TransaltaEnergyMarketing(U.S.)Inc.Avista
NFSierraPacificPowerNorthWestern/PacifiCorp East13TransaltaEnergyMarketing(U.S.)Inc.
NF14TransaltaEnergyMarketing(U.S.)Inc.Sierra Pacific Power Bonneville Power Administration
NF15TransaltaEnergyMarketing(U.S.)Inc.PacifiCorp West PacifiCorp East
AD16TransaltaEnergyMarketing(U.S.)Inc.
NFPacifiCorpEastSierraPacificPower17UtahAssociatedMunicipalPower
AD18UtahAssociatedMunicipalPower
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
TOTAL
Page 328.8FERCFORMNO.1 (ED.12-90)
This Report Is:
(1)[x]An Original
(2)]A Resubmission
TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456}(Continued)
(Including transactions reffered to as 'wheeling')
Date of Report
(Mo,Da,Yr)
04/15/2016
Year/Period of Report
End of 2015/Q4
Name of Respondent
Idaho Power Company
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.
8.Report in column (i)and (j)the total megawatthours received and delivered.
Point of Receipt
(Subsatation or Other
Designation)
Point of Delivery
(Substation or Other
Designation)
Billing
Demand
FERC Rate
Schedule of
Tariff Number
TRANSFER OF ENERGY
MegaWattHours
Delivered
Line
MegaWatt Hours
Received
No.(MW)
0)(f)(g)(h)(i)(e)
1,4931,493 17/8 LAGRANDE M345
202 27/8 M345 BPAT.NWMT 202
45 37/8 M345 45BRDY
504 47/8 LAGFtANDE 504M345
57/8
292292 67/8 BORA HMWY
1,136 1,136 77/8 BORA LAGRANDE
36,005 87/8 HMWY BORA 36,005
906 97/8 HMWY 906M345
3,324 107/8 LAGRANDE BOFtA 3,324
2,407 117/8 LAGFRANDE 2,407M345
150 12LOLO1507/8 BORA
165165 137/8 M345 BPAT.NWMT
1,550 1,550 147/8 M345 LAGRANDE
575 157/8 SMLK BORA 575
167/8
4,288 177/8 BOFRA 4,288M345
187/8
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
5,920,35005,920,350
Page 329.8FERCFORMNO.1 (ED.12-90)
Name of Respondent
Idaho Power Company
This Report Is:
~jA Resubmission
TRARSMlSSiOKl OF FLTCTRICTTY FOR OTHERS (Account 456)(Continued)
(Including transactions reffered to as 'wheeling')
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 (1 101 1 )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.The total amounts in columns (i)and (j)must be reported as Transmission Received and Transmission Delivered for annual report
purposes only on Page 401,Lines 16 and 17,respectively.
1 1 .Footnote entries and provide explanations following all required data.
?ate of Report
(Mo.Da,Yr)
04/15/2016
Year/Period of Report
End of 2015/Q4(1)An Original
(2)
REVENUE FROM TRANSMISSION OF ELECTRICITY FOR OTHERS
LineTotalRevenues($)
(k+l+m)
(Other Charges)Demand Charges Energy Charges
($)($)($)No.
(m)(n)(k)(I)
1,490,951 11,356,463 134,488
2-3,155-3,155
1,535,146 31,450,555 84,591
-1,609 4-1,609
5,350,636479,709 54,870,927
-10,878 6-10,878
9,423 78,391 1,032
-19 8-19
15,217 15,217 9
54,752 1054,752
65,123 1165,123
6 126
7,766 137,766
8,096 148,096
15
16
17
269,445 18269,445
941,105 19941,105
3,776,788 203,776,788
766,651 21766,651
2,294,437 222,294,437
23
643 24643
5,808 255,808
1,128 261,128
3,292 273,292
2845,87745,877
13,547 2913,547
8,299 308,299
-482 31-482
-13 32-13
167 33167
34
0 24,129,37216,403,9457,725,427
Page 330FERCFORMNO.1 (ED.12-90)
This Report Is:
XJAn Original
Year/Period of ReportNameofRespondent
Idaho Power Company
Date of Report
(Mo.Da,Yr)
04/15/2016
(1)2015/Q4Endof
TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456)(Continued)
(including transactions reffered to as 'wheeling')
(2)A Resubmission
9.In column (k)through (n),report the revenue amounts as shown on bills or vouchers.In column (k),provide revenues from demand
charges related to the billing demand reported in column (h).In column (I),provide revenues from energy charges related to the
amount of energy transferred.In column (m),provide the total revenues from all other charges on bills or vouchers rendered,including
out of period adjustments.Explain in a footnote all components of the amount shown in column (m).Report in column (n)the total
charge shown on bills rendered to the entity Listed in column (a).If no monetary settlement was made,enter zero (1 101 1 )in column
(n).Provide a footnote explaining the nature of the non-monetary settlement,including the amount and type of energy or service
rendered.
10.The total amounts in columns (i)and (j)must be reported as Transmission Received and Transmission Delivered for annual report
purposes only on Page 401,Lines 16 and 17,respectively.
1 1 .Footnote entries and provide explanations following all required data.
REVENUE FROM TRANSMISSION OF ELECTRICITY FOR OTHERS
LineTotalRevenues($)
(k+l+m)
Energy Charges (Other Charges)Demand Charges
($)No.($)($)
(n)(k)(I)(m)
481 1481
167 2167
259 3259
13,746 413,746
2,656 52,656
586 6586
6,982 76,982
40,014 840,014
167 9167
7,371 107,371
115,0785,078
1,046 121,046
-488 13-488
3,210 143,210
1,178 151,178
95 1695
3,262 173,262
181,699 18181,699
112,245 19112,245
1,563 201,563
12,147 2112,147
5,145 225,145
2,332 232,332
25,612 2425,612
24,877 2524,877
20,513 2620,513
72 2772
2,058 282,058
2,313 292,313
38 3038
39,558 3139,558
709 32709
143,349 33143,349
34
24,129,37207,725,427 16,403,945
Page 330.1FERCFORMNO.1 (ED.12-90)
This Report Is:
(1)[x]An Original
(2)|I A Resubmission
N OF ELECTRICITY FOR OTHERS (Account 456)(Continued)'
(Including transactions reffered lo as 'wheeling')
9.In column (k)through (n),report the revenue amounts as shown on bills or vouchers.In column (k),provide revenues from demand
charges related to the billing demand reported in column (h).In column (I),provide revenues from energy charges related to the
amount of energy transferred.In column (m),provide the total revenues from all other charges on bills or vouchers rendered,including
out of period adjustments.Explain in a footnote all components of the amount shown in column (m).Report in column (n)the total
charge shown on bills rendered to the entity Listed in column (a).If no monetary settlement was made,enter zero (1 101 1 )in column
(n).Provide a footnote explaining the nature of the non-monetary settlement,including the amount and type of energy or service
rendered.
10.The total amounts in columns (i)and (j)must be reported as Transmission Received and Transmission Delivered for annual report
purposes only on Page 401,Lines 16 and 17,respectively.
1 1 .Footnote entries and provide explanations following all required data.
Date of Report
(Mo.Da,Yr)
04/15/2016
Year/Period of Report
End of 2015/Q4
Name of Respondent
Idaho Power Company
TRANSMISSIO
REVENUE FROM TRANSMISSION OF ELECTRICITY FOR OTHERS
LineTotalRevenues($)
(k+l+m)
(Other Charges)Demand Charges Energy Charges
($)($)($)No.
(n)(k)(I)(m)
114,80714,807
5,256 25,256
556 3556
31,588 431,588
3,0643,064 5
6511511
19,182 719,182
5,206 85,206
15,554 915,554
1,094 101,094
1,204 111,204
43,236 1243,236
13602,695 602,695
5,526 145,526
11,975 1511,975
2,157 162,157
7,028 177,028
103,402 18103,402
534 19534
24,225 24,225 20
1,403 211,403
1,932 221,932
122 23122
446 446 24
515,144 25515,144
728,698 26728,698
1,719 271,719
1,586 1,586 28
305 29305
313 30313
1,582 311,582
362 32362
-9,194 33-9,194
34
0 24,129,3727,725,427 16,403,945
Page 330.2FERCFORMNO.1 (ED.12-90)
This Report Is:Date of Report
(1)[XJ An Original (Mo,Da,Yr)
(2)f |A Resubmission 04/15/2016
TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456)(Continued)
(Including transactions reffered to as 'wheeling')
Year/Period of Report
End of 2015/Q4
Name of Respondent
Idaho Power Company
9.In column (k)through (n),report the revenue amounts as shown on bills or vouchers.In column (k),provide revenues from demand
charges related to the billing demand reported in column (h).In column (I),provide revenues from energy charges related to the
amount of energy transferred.In column (m),provide the total revenues from all other charges on bills or vouchers rendered,including
out of period adjustments.Explain in a footnote all components of the amount shown in column (m).Report in column (n)the total
charge shown on bills rendered to the entity Listed in column (a).If no monetary settlement was made,enter zero (1 101 1 )in column
(n).Provide a footnote explaining the nature of the non-monetary settlement,including the amount and type of energy or service
rendered.
10.The total amounts in columns (i)and (j)must be reported as Transmission Received and Transmission Delivered for annual report
purposes only on Page 401,Lines 16 and 17,respectively.
1 1 .Footnote entries and provide explanations following all required data.
REVENUE FROM TRANSMISSION OF ELECTRICITY FOR OTHERS
LineTotalRevenues($)Energy Charges (Other Charges)Demand Charges
($)($)(k+l+m)No.($)
(n)(I)(m)(k)
7,647 17,647
3,827 23,827
2,839 32,839
5,334 45,334
2,654 52,654
21,739 621,739
2,736 72,736
-67 8-67
31,277 931,277
5,446 105,446
6,118 116,118
351 12351
137,7557,755
1416,40316,403
58,315 1558,315
4,042 164,042
119,847 17119,847
998,262 18998,262
15,905 1915,905
206,4626,462
1,601 211,601
40,963 2240,963
8,231 238,231
373 24373
29,238 2529,238
36,365 2636,365
1,129,176 271,129,176
1 1 ,966 2811,966
16,366 2916,366
64,470 3064,470
-12,044 31-12,044
1,030 321,030
6,879 336,879
34
0 24,129,37216,403,9457,725,427
Page 330.3FERCFORMNO.1 (ED.12-90)
This Report ts:
(1)[x|An Original
Name of Respondent
Idaho Power Company
Date of Report
(Mo.Da,Yr)
04/15/2016
Year/Period of Report
2015/Q4Endof~|A Resubmission
TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456)(Continued)
(Including transactions reffered to as 'wheeling')
(2)
9.In column (k)through (n),report the revenue amounts as shown on bills or vouchers.In column (k),provide revenues from demand
charges related to the billing demand reported in column (h).In column (I),provide revenues from energy charges related to the
amount of energy transferred.In column (m),provide the total revenues from all other charges on bills or vouchers rendered,including
out of period adjustments.Explain in a footnote all components of the amount shown in column (m).Report in column (n)the total
charge shown on bills rendered to the entity Listed in column (a).If no monetary settlement was made,enter zero (1101 1)in column
(n).Provide a footnote explaining the nature of the non-monetary settlement,including the amount and type of energy or service
rendered.
10.The total amounts in columns (i)and (j)must be reported as Transmission Received and Transmission Delivered for annual report
purposes only on Page 401,Lines 16 and 17,respectively.
1 1 .Footnote entries and provide explanations following all required data.
REVENUE FROM TRANSMISSION OF ELECTRICITY FOR OTHERS
LineTotalRevenues($)
(k+l+m)
Demand Charges (Other Charges)Energy Charges
($)($)(5)No.
(k)(I)(m)(n)
8 8 1
824 2824
412 3412
42,822 42,822 4
6,323 6,323 5
16,065 16,065 6
470470 7
309 8309
5,911 95,911
4,033 4,033 10
3,349 3,349 11
206 206 12
1,335 1,335 13
-540 -540 14
348 15348
2,347 162,347
17367367
2,406 2,406 18
137 137 19
967 967 20
843 21843
7,1407,140 22
11,976 11,976 23
2,695 2,695 24
197 25197
4,6384,638 26
33,346 33,346 27
253,420 253,420 28
976 29976
188188 30
13,057 13,057 31
11,137 11,137 32
218,342 218,342 33
34
16,403,945 24,129,3727,725,427 0
Page 330.4FERCFORMNO.1 (ED.12-90)
This Report Is:
(1)[XJAn Original
(2)|A Resubmission
TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456)(Continued)*"
(Including transactions reffered to as 'wheeling')
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 (1 101 1 )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.The total amounts in columns (i)and (j)must be reported as Transmission Received and Transmission Delivered for annual report
purposes only on Page 401,Lines 16 and 17,respectively.
1 1 .Footnote entries and provide explanations following all required data.
Date of Report
(Mo,Da,Yr)
04/15/2016
Year/Period of Report
End of 2015/Q4
Name of Respondent
Idaho Power Company
REVENUE FROM TRANSMISSION OF ELECTRICITY FOR OTHERS
LineTotalRevenues($)
(k+l+m)
(Other Charges)Demand Charges Energy Charges
($)No.($)($)
(m)(n)(k)(I)
58,205 158,205
7,287 27,287
28,195 328,195
411,61311,613
4,148 54,148
275 6275
203,832 7203,832
16,439 816,439
104,246 9104,246
225 10225
1,215 111,215
12115115
270 13270
71 ,697 1471,697
16,627 1516,627
124 16124
260,006 17260,006
1,219 181,219
4,056 194,056
990 20990
68,159 2168,159
34,822 2234,822
23573573
532 24532
229 25229
12,668 2612,668
13,763 2713,763
632 28632
2,970 292,970
-3,506 30-3,506
8 318
300 32300
67 3367
34
24,129,37207,725,427 16,403,945
Page 330.5FERCFORMNO.1 (ED.12-90)
This Report Is:Date of Report
(1)[X]An Original (Mo,Da,Yr)
(2)ri A Resubmission 04/15/2016
TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456}(Continued)
(Including transactions reffered to as 'wheeling')
Name of Respondent
Idaho Power Company
Year/Period of Report
End of 2015/Q4
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 (1101 1)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.The total amounts in columns (i)and (j)must be reported as Transmission Received and Transmission Delivered for annual report
purposes only on Page 401,Lines 16 and 17,respectively.
1 1 .Footnote entries and provide explanations following all required data.
REVENUE FROM TRANSMISSION OF ELECTRICITY FOR OTHERS
LineTotalRevenues($)
(k+l+m)
Demand Charges Energy Charges (Other Charges)
($)($)No.(5)
(n)(k)(I)(m)
8 18
515 2515
6,536 36,536
410,449 10,449
5 55
185 6185
782 7782
367 8367
955
140 10140
1111
28 1228
99 1399
179 14179
158 15158
137 16137
9 179
1815,006 15,006
185 19.185
9 209
10 2110
1,164 1,164 22
2,509 232,509
35 2435
2,924 252,924
830 830 26
11 11 27
1,652 281,652
11,822 2911,822
20,090 20,090 30
8 8 31
38 3238
668 33668
34
24,129,3727,725,427 16,403,945 0
Page 330.6FERCFORMNO.1 (ED.12-90)
This Report Is:
(1)[X]An Original
(2)r~|A Resubmission
TRANSMISSION OF ELKTRrCITY'FOR OTHERS (Account 456)(Continued)
{Including transactions reffered to as 'wheeling')
Year/Period of Report
End of 2015/Q4
Name of Respondent
Idaho Power Company
Date of Report
(Mo.Da,Yr)
04/15/2016
9.In column (k)through (n),report the revenue amounts as shown on bills or vouchers.In column (k),provide revenues from demand
charges related to the billing demand reported in column (h).In column (I),provide revenues from energy charges related to the
amount of energy transferred.In column (m),provide the total revenues from all other charges on bills or vouchers rendered,including
out of period adjustments.Explain in a footnote all components of the amount shown in column (m).Report in column (n)the total
charge shown on bills rendered to the entity Listed in column (a).If no monetary settlement was made,enter zero (1 101 1 )in column
(n).Provide a footnote explaining the nature of the non-monetary settlement,including the amount and type of energy or service
rendered.
10.The total amounts in columns (i)and (j)must be reported as Transmission Received and Transmission Delivered for annual report
purposes only on Page 401,Lines 16 and 17,respectively.
1 1 .Footnote entries and provide explanations following all required data.
REVENUE FROM TRANSMISSION OF ELECTRICITY FOR OTHERS
LineTotalRevenues($)
(k+l+m)
Demand Charges Energy Charges (Other Charges)
($)($)($)No.
(n)(k)(I)(m)
16969
8 28
21 321
164 4164
637 637 5
6-6,180 -6,180
69 769
8,306 88,306
692 9692
9,608 109,608
6,184 116,184
4,384 124,384
13969969
142,0632,063
808 15808
461 16461
-807 17-807
465 18465
776 19776
1,1621,162 20
4,182 214,182
22,334 2222,334
1,797 231,797
2410,637 10,637
52,615 2552,615
2,448 262,448
112 27112
5,310 5,310 28
853 29853
723 30723
225 31225
1,213 321,213
33,438 3333,438
34
24,129,3727,725,427 16,403,945 0
Page 330.7FERCFORMNO.1 (ED.12-90)
Name of Respondent
Idaho Power Company
This Report Is:
(1)fx]An Original
(2)IA Resubmission
Year/Period of Report
End of 2015/Q4
Date of Report
(Mo.Da,Yr)
04/15/2016
TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 4S6)(Continued)
(Including transactions reffered to as 'wheeling')
9.In column (k)through (n),report the revenue amounts as shown on bills or vouchers.In column (k),provide revenues from demand
charges related to the billing demand reported in column (h).In column (I),provide revenues from energy charges related to the
amount of energy transferred.In column (m),provide the total revenues from all other charges on bills or vouchers rendered,including
out of period adjustments.Explain in a footnote all components of the amount shown in column (m).Report in column (n)the total
charge shown on bills rendered to the entity Listed in column (a).If no monetary settlement was made,enter zero (1 101 1)in column
(n).Provide a footnote explaining the nature of the non-monetary settlement,including the amount and type of energy or service
rendered.
10.The total amounts in columns (i)and (j)must be reported as Transmission Received and Transmission Delivered for annual report
purposes only on Page 401,Lines 16 and 17,respectively.
1 1 .Footnote entries and provide explanations following all required data.
REVENUE FROM TRANSMISSION OF ELECTRICITY FOR OTHERS
LineTotalRevenues($)
(k+l+m)
(Other Charges)Demand Charges Energy Charges
($)($)($)No.
(n)(k)(I)(m)
6,707 16,707
907 2907
202 3202
2,264 42,264
-56 5-56
61,1881,188
4,620 74,620
146,443 8146,443
3,685 93,685
13,520 1013,520
9,790 119,790
610 12610
13671671
146,3046,304
2,339 152,339
-520 16-520
17,587 1717,587
-165 18-165
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
0 24,129,3727,725,427 16,403,945
Page 330.8FERCFORMNO.1 (ED.12-90)
Date of Report Year/Period of ReportNameofRespondentThisReportis:
(1)X An Original
(2)_A Resubmission
(Mo,Da,Yr)
04/15/2016 2015/Q4IdahoPowerCompany
FOOTNOTE DATA
Schedule Page:328 Line No.:1 Column:e
9,Open Access Transmission Tariff,Schedule 9 Network Integration Transmission Service
Schedule Page:328 Line No.:1 Column:h
The network service agreement between Idaho Power and the Bonneville Power Administration
for the Oregon Trail Electric Cooperative expires September 30,2028.The billing demand
for network service is the customer's demand at the time of Idaho Power Company
transmission system peak and varies by month.
Schedule Page:328 Line No.:2 Column:h
per revised Informational Filing postedRaterefundforOctober2014thruDecember2014,
12/22/15 .
Schedule Page:328 Line No.:3 Column:h
The network service agreement between Idaho Power and the Bonneville Power Administration
for the United States Bureau of Reclamation expires December 31,2023.The billing demand
for network service is the customer's demand at the time of Idaho Power Company
transmission system peak and varies by month.
Schedule Page:328 Line No.:4 Column:h
Rate refund for October 2014 thru December 2014,per revised Informational Filing posted
12/22/15.
Schedule Page:328 Line No.:5 Column:h
The network service agreement between Idaho Power and the Bonneville Power Administration
for the Priority Firm Customers expires September 30,2028.The billing demand for network
service is the customer's demand at the time of Idaho Power Company transmission system
peak and varies by month.
Schedule Page:328 Line No.:6 Column:h
Rate refund for October 2014 thru December 2014,per revised Informational Filing posted
12/22/15.
Schedule Page:328 Line No.:7 Column:h
The contract between Idaho Power and PacifiCorp -Imnaha expires on March 31,2016.The
billing demand for network service is the customer's demand at the time of Idaho Power
Company transmission system peak and varies by month.
Schedule Page:328 Line No.:8 Column:h
Rate refund for October 2014 thru December 2014,per revised Informational Filing posted
12/22/15.
Schedule Page:328 Line No.:9 Column:e
Legacy,contract prior to the Open Access Transmission Tariff
Schedule Page:328 Line No.:9 Column:h
The contract between Idaho Power and the Milner Irrigation District expires December 31,
2017 .
Schedule Page:328 Line No.:10 Column:h
The agreement between Idaho Power and the United States Department of the Interior,Bureau
of Indian Affairs is subject to termination upon 90 days written notice by the Bureau.
Schedule Page:328 Line No.:11 Column:e
4,Qpen "Access.Transmission Tariff,Schedule 4 Energy.Imbalance Service
Schedule Page:328 Line No.:11 Column:h
The agreement between Idaho Power and the City of Seattle expires December 31,2017.City
of Seattle has re-sold this transmission service request to Shell and Shell is now
responsible for payment.
Schedule Page:328 Line No.:12 Column:e
5/6,Open Access Transmission Tariff,Schedule 5/6 Operating Reserves
Schedule Page:328 Line No.:12 Column:h
The agreement between Idaho Power and United Materials of Great Falls,Inc.has no
expiration date and can be terminated by either party at any time.
Schedule Page:328 Line No.:13 Column:h
The agreement between Idaho Power and United Materials of Great Falls,Inc.has no
expiration date and can be terminated by either party at any time.
FERC FORM NO.1 (ED.12-87)Page 450.1
This Page Intentionally Left Blank
Date of Report Year/Period of ReportThisReportis:Name of Respondent
(Mo,Da,Yr)(1)X An Original
(2)_A Resubmission 2015/Q404/15/2016IdahoPowerCompany
FOOTNOTE DATA
Schedule Page:328 Line No.:14 Column:h I
The agreement between Idaho Power and United Materials of Great Falls,
date and can be terminated by either party at any time.
Inc.has no
ex
Schedule Page:328 Line No.:15 Column:h
Rate refund for October 2014 thru December 2014,per revised Informational Filing posted
12/22/15.
Schedule Page:328 Line No.:17 Column:e
7/8,Open Access Transmission Tariff,Schedule 7/8 Point-to-Point Transmission Service
Schedule Page:328 Line No.:17 Column:h
Legacy agreement providing OATT-like service,but billed under 454 Facilities revenue.
Schedule Page:328 Line No.:31 Column:h
Rate refund for October 2014 thru December 2014,per revised Informational Filing posted
12/22/15 .
Schedule Page:328 Line No.:32 Column:h
Rate refund for October 2014 thru December 2014,per revised Informational Filing posted
12/22/15 .
Schedule Page:328.1 Line No.:13 Column:h
Rate refund for October 2014 thru December 2014,per revised Informational Filing posted
12/22/15.
Schedule Page:328.2 Line No.:33 Column:h
Rate refund for October 2014 thru December 2014,per revised Informational Filing posted
12/22/15.
Schedule Page:328.3 Line No.:8 Column:h
Rate refund for October 2014 thru December 2014,per revised Informational Filing posted
12/22/15 .
Schedule Page:328.3 Line No.:31 Column:h
Rate refund for October 2014 thru December 2014,per revised Informational Filing posted
12/22/15.
Schedule Page:328.4 Line No.:14 Column:h
Rate refund for October 2014 thru December 2014,per revised Informational Filing posted
12/22/15.
Schedule Page:328.5 Line No.:30 Column:h
Rate refund for October 2014 thru December 2014,per revised Informational Filing posted
12/22/15.
Schedule Page:328.7 Line No.:6 Column:h
Rate refund for October 2014 thru December 2014,per revised Informational Filing posted
12/22/15 .
Schedule Page:328.7 Line No.:17 Column:h
Rate refund for October 2014 thru December 2014,per revised Informational Filing posted
12/22/15.
Schedule Page:328.8 Line No.:5 Column:h
Rate refund for October 2014 thru December 2014,per revised Informational Filing posted
12/22/15 .
Schedule Page:328.8 Line No.:16 Column:h
Rate refund for October 2014 thru December 2014,per revised Informational Filing posted
12/22/15 .
Schedule Page:328.8 Line No.:18 Column:h
Rate refund for October 2014 thru December 2014,per revised Informational Filing posted
12/22/15 .
FERC FORM NO.1 (ED.12-87)Page 450.2
Year/Period of Report
End of 2015/Q4
Name of Respondent
Idaho Power Company
This Report Is:
(1)[X]An Original
(2)£~|A Resubmission
TRANSMISSION OF ELECTRICITY BY OTHERS (Account 565)
(Including transactions referred to as "wheeling")
Dale of Report
(Mo,Da,Yr)
04/15/2016
1 .Report all transmission,i.e.wheeling or electricity provided by other electric utilities,cooperatives,municipalities,other public
authorities,qualifying facilities,and others for the quarter.
2.In column (a)report each company or public authority that provided 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.Use additional columns as necessary to report all companies or public authorities that provided
transmission service for the quarter reported.
3.In column (b)enter a Statistical Classification code based on the original contractual terms and conditions of the service as follows:
FNS -Firm Network Transmission Service for Self,LFP -Long-Term Firm Point-to-Point Transmission Reservations.OLF -Other
Long-Term Firm Transmission Service,SFP -Short-Term Firm Point-to-Point Transmission Reservations,NF -Non-Firm Transmission
Service,and OS -Other Transmission Service.See General Instructions for definitions of statistical classifications.
4.Report in column (c)and (d)the total megawatt hours received and delivered by the provider of the transmission service.
5.Report in column (e),(f)and (g)expenses as shown on bills or vouchers rendered to the respondent.In column (e)report the
demand charges and in column (f)energy charges related to the amount of energy transferred.On column (g)report 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 (g).Report in column (h)the total charge shown on bills rendered to the respondent.If no
monetary settlement was made,enter zero in column (h).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.
7.Footnote entries and provide explanations following all required data.
EXPENSES FOR TRANSMISSION OF ELECTRICITY BY OTHERS
Uther
Charges
TRANSFER OF ENERGYLine
Magawail-
hours
Received
fvlagawatl-
hours
Delivered
Demand
Chargesif
Energy
Chargesir
Total Cost of
Transmission
No.Name of Company or Public
Authority (Footnote Affiliations)
Statistical
Classification
(b)(a)fa(C)(d)(e)M
214,62129,184 214,6211AvistaCorp-WWP Div NF 29,184
802,613 802,6132AvistaCorp-WWP Div SFP 144,542 144,542
-802 -8023AvistaCorp-WWP Div OS
3,200,575 3,200,5754BonnevillePowerAdminLFP179,776 179,776
24,107 24,107SFP321,574 321,5745BonnevillePowerAdmin
2,473 2,4735405406BonnevillePowerAdminNF
15,312 15,3127BonnevillePowerAdminOS
521,220 521,2208BonnevillePowerAdminOS
29,754 29,7549BonnevillePowerAdmlnnAD
-48,769 -48,76910BonnevillePowerAdmlnnAD
11 Bonneville Power Adminn OS 811 811
-65,522 -65,52212ExelonGenerationCoOS
-3,087 -3,08713IberdrolaRenewablesOS
-72514MorganStanleyCapital-725OS
132,500 132,50015NevadaPowerCompanySFP14,850 14,850
2,150 2,15016NevadaPowerCompany328328NF
TOTAL 6,279,1335,914,531 364,602918,343 918,343
FERC FORM NO.1/3-Q (REV.02-04)Page 332
Year/Period of Report
End of 2015/Q4
Date of Report
(Mo.Da,Yr)
04/15/2016
Name of Respondent
Idaho Power Company
This Report Is:
(1)[X]An Original
(2)A Resubmission
TRANSMISSION OF ELECTRICITY BY OTHERS (Account 565)
(Including transactions referred to as "wheeling")
1 .Report all transmission,i.e.wheeling or electricity provided by other electric utilities,cooperatives,municipalities,other public
authorities,qualifying facilities,and others for the quarter.
2.In column (a)report each company or public authority that provided 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.Use additional columns as necessary to report all companies or public authorities that provided
transmission service for the quarter reported.
3.In column (b)enter a Statistical Classification code based on the original contractual terms and conditions of the service as follows:
FNS -Firm Network Transmission Service for Self,LFP -Long-Term Firm Point-to-Point Transmission Reservations.OLF -Other
Long-Term Firm Transmission Service,SFP -Short-Term Firm Point-to-Point Transmission Reservations,NF -Non-Firm Transmission
Service,and OS -Other Transmission Service.See General Instructions for definitions of statistical classifications.
4.Report in column (c)and (d)the total megawatt hours received and delivered by the provider of the transmission service.
5.Report in column (e),(f)and (g)expenses as shown on bills or vouchers rendered to the respondent.In column (e)report the
demand charges and in column (f)energy charges related to the amount of energy transferred.On column (g)report 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 ofthe amount shown in column (g).Report in column (h)the total charge shown on bills rendered to the respondent.If no
monetary settlement was made,enter zero in column (h).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.
7.Footnote entries and provide explanations following all required data.
EXPENSES FOR TRANSMISSION OF ELECTRICITY BY OTHERSTRANSFEROFENERGYLine
utnerMagawaIt-
Received
Magawatt-
hours
Delivered
Demand
Charges
Energy
Charges
<sr
Total Cost of
Transmission
No.Name of Company or Public
Authority (Footnote Affiliations)
Statistical
Classification
Charcjes
i(a)(b)(f)(c)(d)e)M.'h
19,54019,5401NevadaPowerCompanyOS
-3,522 -3,5222NextEraEnergyOS
74,35374,3533NorthwesternEnergy7,775NF7,775
10,50910,5094NorthwesternEnergySFP1,985 1,985
4,4104,4105NorthwesternEnergyOS
928,749928,749LFP63,546 63,5466PacifiCorpInc.
208,07738,104 208,0777PacifiCorpInc.NF 38,104
125,584115,328 125,5848PacifiCorpInc.SFP 115,328
-2,048 -2,0489PacifiCorpInc.OS
-65,539-65,53910PacifiCorpInc.OS
282811PacifiCorpInc.OS
58,43658,43612PacifiCorpInc.OS
-57,056-57,05613PowerexCorp.OS
187,62014PugetSoundEnergy,lnc 187,620SFP
60060015ShellEnergyN.America SFP
-1,73616ShellEnergyN.America -1,736OS
TOTAL 364,602 6,279,133918,343 5,914,531918,343
FERC FORM NO.1/3-Q (REV.02-04)Page 332.1
Year/Period of Report
End of 2015/Q4
Name of Respondent
Idaho Power Company
This Report Is:
(1)[X]An Original
(2)|—|A Resubmission
TRANSMISSION OF ELECTRICITY BY OTHERS (Account 565)
(Including transactions referred to as "wheeling")
Date of Report
(Mo.Da,Yr)
04/15/2016
1 .Report all transmission,i.e.wheeling or electricity provided by other electric utilities,cooperatives,municipalities,other public
authorities,qualifying facilities,and others for the quarter.
2.In column (a)report each company or public authority that provided 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.Use additional columns as necessary to report all companies or public authorities that provided
transmission service for the quarter reported.
3.In column (b)enter a Statistical Classification code based on the original contractual terms and conditions of the service as follows:
FNS -Firm Network Transmission Service for Self,LFP -Long-Term Firm Point-to-Point Transmission Reservations.OLF -Other
Long-Term Firm Transmission Service,SFP -Short-Term Firm Point-to-Point Transmission Reservations,NF -Non-Firm Transmission
Service,and OS -Other Transmission Service.See General Instructions for definitions of statistical classifications.
4.Report in column (c)and (d)the total megawatt hours received and delivered by the provider of the transmission service.
5.Report in column (e),(f)and (g)expenses as shown on bills or vouchers rendered to the respondent.In column (e)report the
demand charges and in column (f)energy charges related to the amount of energy transferred.On column (g)report 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 (g).Report in column (h)the total charge shown on bills rendered to the respondent.If no
monetary settlement was made,enter zero in column (h).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.
7.Footnote entries and provide explanations following all required data.
TRANSFER OF ENERGY EXPENSES FOR TRANSMISSION OF ELECTRICITY BY OTHERS
Energy"
Chafes
Line
Magawait-
Received
Ivlagawatt-
hours
Delivered
Demand
Charges
($r
OtherNo.Total Cost of
Transmission
Name of Company or Public
Authority (Footnote Affiliations)
Statistical
Classification
Chafes
(a)(b)(c)(d)(e)(l)hM
1 TransAlta Energy U.S.-35,292 -35,292OS
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
TOTAL 5,914,531 364,602 6,279,133918,343 918,343
FERC FORM NO.1/3-Q (REV.02-04)Page 332.2
Name of Respondent This Report is:
(1)X An Original
(2)_A Resubmission
Date of Report Year/Period of Report
(Mo,Da,Yr)
Idaho Power Company 04/15/2016 2015/Q4
FOOTNOTE DATA
Schedule Page:332 Line No.:3 Column:a
Unreserved Use Penalty.
Schedule Page:332 Line No.:4 Column:b
Contract Expiration Da_te_09/30/2016
Schedule Page:332 Line No.:7 Column:a
Spinning /Supplemental Reserves
Schedule Page:332 Line No.:8 Column:a
Ancillary Services
Schedule Page:332 Line No.:9 Column:a
Correction of refund for System Control and Dispatch Charges in 2013
Schedule Page:332 Line No.:10 Column:a
Refund of Adjustment for System Control and Dispatch Charges.
Schedule Page:332 Line No.:11 Column:a
BPAT is provider for transmission services settled with PSEMKT.
Schedule Page:332 Line No.:12 Column:a
Resale Transmission
[Schedule Page:332 Line No.:13 Column:a
Resale Transmission
-]Schedule Page:332 Line No.:14 Column:a
Resale Transmission
Schedule Page:332.1 Line No.:1 Column:a
Ancillary Services
Schedule Page:332.1 Line No.:5 Column:a
Ancillary Services
~|Schedule Page:332.1 Line No.:6 Column:b
Contract Expiration Date 05/31/2019 .
Schedule Page:332.1 Line No.:11 Column:a
Energy Imbalance Market
Schedule Page:332.1 Line No.:12 Column:a
Ancillary Services
Schedule Page:332.1 Line No.:13 Column:a
Resale Transmission
J
Schedule Page:332.1 Line No.:14 Column:a
BPAT is provider for transmission services settled with PSEMKT
Schedule Page:332.1 Line No.:16 Column:a
Resale Transmission
Schedule Page:332.2 Line No.:1 Column:a
Resale Transmission
FERC FORM NO.1 (ED.12-87)Page 450.1
Name of Respondent
Idaho Power Company
This Report Is:
(1)0 An Original
(2)Q A Resubmission
MISCELLANEOUS GENERAL EXPENSES (Account 930.2)(ELECTRIC)
Date of Report
(Mo,Da,Yr)
04/15/2016
Year/Period of Report
End of 2015/Q4
AmountLineDescription
No.(b)
Industry Association Dues 505,6041
2 Nuclear Power Research Expenses
3 Other Experimental and General Research Expenses
4 Pub &Dist Info to Stkhldrs...expn servicing outstanding Securities 1,602,436
5 Oth Expn >=5,000 show purpose,recipient,amount.Group if <$5,000 64,833
6
7 Director Fees and Expenses:
Christine King 88,3598
Dennis Johnson 70,2909
J Lamont Keen 64,35010
Jan Packwood 26,81211
Joan Smith 35,39512
Judith Johansen 78,33113
Richard Dahl 91,57514
Richard Navarro 65,06615
Robert Tintsman 170,77516
Ronald Jibson 74,47317
Thomas Carlile 76,23018
Thomas Wilford 30,57119
20
Corporate Memberships and Subscriptions:21
Arizona State University 50,00022
Associated Taxpayers of Idaho 22,00023
Boston College for Corporations 5,00024
Business Plus 5,00025
Ceati International 13,35026
Corporate Executive Board 87,53527
Idaho Association of Commerce &Industry 15,00028
Idaho Technology Council 12,50029
National Association of Directors 7,12530
National Hydropower Association 36,06931
North American Energy Standard 7,00032
Northwest Power Pool 342,47233
Pacific NW Utilities 40,16034
SNL Financial Unlimited Subscription 23,20035
Western Alliance for Economic 2,50036
Western Energy Coordinating Council 1,604,33937
Western Energy Institute 30,79438
Misc Memberships Under $2,000 5,57439
40
Chambers of Commerce &Other Civic Organizations41
90,13542
43
44
45
46 TOTAL 5,444,853
FERC FORM NO.1 (ED.12-94)Page 335
Date of Report Year/Period of Report
(Mo,Da,Yr)
04/15/2016
This Report is:
(1)X An Original
(2)_A Resubmission
Name of Respondent
2015/Q4IdahoPowerCompany
FOOTNOTE DATA
Schedule Page:335 Line No.:4 Column:b
AmountRecipientPurpose
Mgmt Services
Misc Expense
Misc Expense
Broker Fees
Mgmt Services
Mgmt Services
Mgmt Services
Listing Services
Misc Expense
Misc Expense
Mgmt Services
Misc Expense
Mgmt Services
Misc Expense
$65,293
10,146
46,949
30,000
39,906
32,310
62,573
50,163
175,051
14,813
15,840
949,993
107,626
1,773
American Stock Transfer &Trust
Bloomberg Finance LP
Broadridge Financial Solutions
Deutsche Bank
E Source
Moody's Analytics
NASDAQ Corp Solutions
New York Stock Exchange
Payroll Related Expenses
PR Newswire
Rivel Research Group
Stock Based Compensation
Wells Fargo Shareowner Services
Miscellaneous under $5,000
$1,602,436
Schedule Page:335 Line No.:5 Column:b
Recipient AmountPurpose
Revenue Bonds
Misc Expense
Misc Expense
Revenue Bonds
Misc Expense
$13,925
22,311
5,175
9,680
13,742
Bank of New York
Payroll Related Expense
Total Electric
Union Bank
Miscellaneous under $5,000
$64,833
FERC FORM NO.1 (ED.12-87)Page 450.1
Date of Report
(Mo.Da,Yr)
04/15/2016
Year/Period of Report
End of 2015/Q4
Name of Respondent
Idaho Power Company
This Report Is:
(1)[X|An Original
(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 :(b)Depreciation Expense (Account 403;(c)Depreciation Expense for Asset
Retirement Costs (Account 403.1 ;(d)Amortization of Limited-Term Electric Plant (Account 404);and (e)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
Depreciation
Expense for Asset
Retirement Costs
Amortization of
Limited Term
Electric Plant
(Account 404)
Amortization of
Other Electric
Plant (Acc 405)
Depreciation
Expense
(Account 403)
Line TotalFunctionalClassificationNo.(Account 403.1)
(f)(b)(c)(d)(e)(a)
7,095,9267,095,9261IntangiblePlant
26,029,976549,0172SteamProductionPlant25,480,959
3 Nuclear Production Plant
14,513,9234HydraulicProductionPlant-Conventional 14,513,923
5 Hydraulic Production Plant-Pumped Storage
17,072,8396OtherProductionPlant17,072,839
20,991,2607TransmissionPlant20,991,260
41,882,3798DistributionPlant41,882,379
9 Regional Transmission and Market Operation
10,440,76810GeneralPlant10,440,768
1 1 Common Plant-Electric
138,027,071130,382,128 549,017 7,095,92612TOTAL
B.Basis for Amortization Charges
Balance 12/31/2015
24,000
9,794,550
5,062,565
13,191,811
3,460,098
193,795
878,552
Remaining MonthsAcct404Balance1/1/2015
36,000
10,339,996
5,251,629
15,747,708
3,747,997
201,821
604,625
2015 Amortization
12,000
545,446
189,064
6,035,788
287,899
8,026
17,702
(1)24
(2)
(3)321
(4)
(5)156
(6)
(7)
Total 32,605,37235,929,777
(1)Shoshone-Bannock Tribe License &Use Agreement(Termination date December 31,2023).
(2)Middle Snake Relicesing Costs (Amortized over a 30 year license period).
(3)Swan Falls Relicesing Costs (Amortized over a 30 year license period).
(4)Computer Software packages (Amortized over a 60 month period from date of purchase).
(5)Shoshone-Bannock Right of Way (Termination date December 31,2028).
(6)Boardman Retrofit Tech Analysis (Termination date December 31 ,2040)
(7)FERC License Compliance Costs (Termination date will be expiration date of the FERC Licenses)
7,095,926
FERC FORM NO.1 (REV.12-03)Page 336
Date of Report
(Mo,Da,Yr)
04/15/2016
Year/Period of Report
End of 2015/Q4
Name of Respondent
Idaho Power Company
This Report Is:
(1)[X]An Original
(2)QA Resubmission
DEPRECIATION AND AMORTIZATION OF ELECTRIC PLANT (Continued)
C.Factors Used in Estimating Depreciation Charges
"Depreciable
Plant Base
(In Thousands)
Applied
Depr.rales
(Percent)
Mortality Average
Remaining
Estimated WeTLine
Avg.Service CurveAccountNo.Salvage
(Percent)No,LifeLifeTeR(g)M (b)(si
12 310.20 20.203.63 R4.065775.00
13 311.00 1.84 S1.0 21.30153,408 100.00 -10.00
14 312.10 1.15 R3.0 21.80133,426 60.00 -5.00
15 312.20 20.90545,122 60.00 -5.00 2.77 R1.5
16 312.30 20.00 2.36 R3.0 7.904,341 25.00
17 314.00 3.25 S1.0 19.40162,544 45.00 -5.00
18 315.00 1.44 S1.5 19.8070,702 60.00
19 316.00 19.00-5.00 3.75 R0.512,808 45.00
20 316.10 8.72 L2.0 6.308412.00 15.00
21 316.40 7.9024712.00 15.00 0.87 L2.0
22 316.50 5.1031012.00 15.00 5.60 L2.0
23 316.60 18.0015.00 4.39 L2.010620.00
24 316.70 14.402.09 L2.08020.00 15.00
25 316.80 3.52 01.0 16.603,855 20.00 30.00
26 316.90 2.45 S1.0 34.701435.00 15.00
27 317.00 13,930
28 Subtotal Steam 1,101,634
29 331.00 2.40 R2.5 33.00175,996 105.00 -25.00
30 332.10 1.31 S4.0 39.8019,460 95.00 -20.00
31 332.20 1.65 S4.0 35.60245,027 95.00 -20.00
32 332.30 1 .44 SQUARE 49.105,472
33 333.00 32.6080.00 -5.00 1.73 R3.0211,679
34 334.00 26.10-5.00 2.75 R1.558,474 50.00
35 335.00 28.1022,054 2.28 R2.095.00
36 335.10 6.77 SQUARE 6.508815.00
37 335.20 5.57 SQUARE 5.3036620.00
38 335.30 12.90 SQUARE 3.302885.00
39 336.00 21.4010,881 75.00 2.22 R3.0
40 Subtotal Hydro 749,785
41 341.00 2.89 SQUARE 27.20142,711
42 342.00 2.98 S2.5 28.5010,453 50.00
43 343.00 3.46 S1.5 25.90218,961 40.00
44 344.00 2.45 S2.0 26.8045.0066,532
45 345.00 3.23 S1.5 22.6091,099 50.00
46 346.00 3.40 R2.5 24.506,010 35.00
47 Subtotal Other 535,766
48 350.20 58.501.39 R3.031,780 70.00
49 350.22 2.9317130.00
50 352.00 77,780 1.84 R3.0 53.7065.00 -35.00
FERC FORM NO.1 (REV.12-03)Page 337
Name of Respondent
Idaho Power Company
Year/Period of Report
End of 201 5/Q4
This Report Is:
(1)[x]An Original
(2)Q A Resubmission
DEPRECIATION AND AMORTIZATION OF ELECTRIC PLANT (Continued)
Date of Report
(Mo,Da,Yr)
04/15/2016
C.Factors Used in Estimating Depreciation Charges
Depreciable
Plant Base
(In Thousands)
Estimated
Avg.Service
TJeF Applied
Depr rates
(Percent)
Mortality
Curve
Line Average
RemainingAccountNo,Salvage
(Percent)No.LifeLifeTIe
(g)M (C)(e)(b)
12 353.00 40.70407,603 50.00 -5.00 1.90 R1.5
13 354.00 50.80184,628 65.00 -15.00 1.65 S3.0
14 355.00 157,531 60.00 -70.00 2.70 R2.0 43.60
15 355.10 849 10.00 7.78
16 356.00 48.50211,905 65.00 -40.00 2.19 R2.0
17 359.00 24.0039065.00 0.79 R2.5
18 Subtotal Transmission 1,072,637
19 360.22 30.0047630.00 3.49
20 361.00 53.3034,175 65.00 -40.00 2.13 R2.5
21 362.00 216,854 50.00 -5.00 1.98 R1.0 40.20
22 364.00 244,791 44.00 3.06 R1.5 31.30-45.00
23 364.10 2,195 12.00 7.55
24 365.00 33.60129,331 45.00 -35.00 2.96 R0.5
25 366.00 48.4048,323 60.00 -20.00 1.93 R2.0
26 367.00 230,143 46.00 2.23 R2.0 35.30-15.00
27 368.00 2.57 R1.0 27.00515,652 35.00 -3.00
28 369.00 29.5058,771 40.00 -40.00 2.54 R2.0
29 370.00 3.46 01 .0 17.5016,979 22.00 1.00
30 370.10 13.1068,269 15.00 6.88 S2.5
31 371.10 12.00 -2.00 S4.0 9.00
32 371.20 2,954 17.00 1.51 R1.5 14.70-2.00
33 373.20 4,543 30.00 2.41 R1.0 20.60-25.00
34 374.00 164
35 Subtotal Distribution 1,573,620
36 390.11 2.57 SO.5 28.8029,421 100.00 -5.00
37 390.12 1.89 SO.5 44.3081,504 55.00 -5.00
38 390.20 35.00 3.94 S3.0 25.70
39 391.10 14,155 20.00 2.92 SQUARE 12.90
40 391.20 24,594 11.73 SQUARE 3.205.00
41 391.21 5.707,944 8.00 11.50 L2.0
42 392.10 8.9082212.00 15.00 7.39 L2.0
43 392.30 4,563 10.00 50.00 2.06 S2.5 3.40
44 392.40 23,290 12.00 7.03 L2.0 6.8015.00
45 392.50 1,127 12.00 3.33 L2.0 9.0015.00
46 392.60 13.4034,103 20.00 15.00 4.03 L2.0
47 392.70 6,944 20.00 15.00 3.12 L2.0 12.50
48 392.90 5,031 35.00 15.00 2.05 S1.0 24.30
49 393.00 3.18 SQUARE 19.402,255 25.00
50 394.00 4.14 SQUARE 13.308,022 20.00
FERC FORM NO.1 (REV.12-03)Page 337.1
?ate of Report
(Mo.Da,Yr)
04/15/2016
Name of Respondent
Idaho Power Company
This Report Is:
(1)[X|An Original
(2)A Resubmission
DEPRECIATION AND AMORTIZATION OF ELECTRIC PLANT (Continued)
Year/Period of Report
End of 2015/Q4
C.Factors Used in Estimating Depreciation Charges
Depreciable
Plant Base
(In Thousands)
Estimates"
Avg.Service
TJeT Applied'
Depr.rates
(Percent)
"Mortality Average
Remaining
Line
Salvage
(Percent)
CurveAccountNo.No.LifeLifeTIe
M)(e)laiM(b)
12 395.00 12.104.31 SQUARE12,704 20.00
13 396.00 1.57 01.0 17.6015,082 20.00 30.00
14 397.10 4.41 SQUARE 8.304,672 15.00
15 397.20 5.44 SQUARE 9.8030,517 15.00
16 397.30 8.006.03 SQUARE3,472 15.00
17 397.40 7.44 SQUARE 6.5016,754 10.00
18 398.00 5.19 SQUARE 10.605,968 15.00
19 Subtotal General 332,944
20 Total Plant 5,366,386
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 (REV.12-03)Page 337.2
This Page Intentionally Left Blank
Date of Report Year/Period of Report
(Mo,Da,Yr)
04/15/2016
This Report is:
(1)X An Original
(2)_A Resubmission
Name of Respondent
2015/Q4IdahoPowerCompany
FOOTNOTE DATA
Schedule Page:336 Line No.:28 Column:a !
Steam,hydro,and other production depreciation and amortization of certain electric plant
is maintained by plant location.Effective April 1,1993 the forecast life span method of
life analysis using an interim retirement rate was utilized to develop all production
plant rates.Rates,Service lives,net salvage and remaining lives indicated are on a
composite basis.An average plant balance was used in computing these rates by FERC
account.Effective April 1,1993 all depreciable plant is being depreciated using the
straight-line life method.
Schedule Page:336 Line No.:40 Column:a
Steam,hydro,and other production depreciation and amortization of certain electric plant
is maintained by plant location.Effective April 1,1993 the forecast life span method of
life analysis using an interim retirement rate was utilized to develop all production
plant rates.Rates,Service lives,net salvage and remaining lives indicated are on a
composite basis.An average plant balance was used in computing these rates by FERC
account.Effective April 1,1993 all depreciable plant is being depreciated using the
straight-line life method.
Schedule Page:336 Line No.:47 Column:a
Steam,hydro,and other production depreciation and amortization of certain electric plant
is maintained by plant location.Effective April 1,1993 the forecast life span method of
life analysis using an interim retirement rate was utilized to develop all production
plant rates.Rates,Service lives,net salvage and remaining lives indicated are on a
composite basis.An average plant balance was used in computing these rates by FERC
account.Effective April 1,1993 all depreciable plant is being depreciated using the
straight-line life method.
FERC FORM NO.1 (ED.12-87)Page 450.1
Year/Period of Report
End of 2015/Q4
Name of Respondent
Idaho Power Company
This Report Is:
(1)mAn Original
(2)|—|A Resubmission
REGULATORY COMMISSION EXPENSES
Date of Report
(Mo,Da,Yr)
04/15/2016
1 .Report particulars (details)of regulatory commission expenses incurred during the current year (or incurred in previous years,if
being amortized)relating to format cases before a regulatory body,or cases in which such a body was a party.
2.Report in columns (b)and (c),only the current year's expenses that are not deferred and the current year's amortization of amounts
deferred in previous years.
DeTerred
in Account
Beginning o/year
Expenses Total
Expense for
Current Year
Line Description
(Furnish name of regulatory commission or body the
docket or case number and a description of the case)
Assessed by
Regulatory
Commission
ofNo.
Utility (b)+(c)
(d)(e)(a)<b)(C)
1 Federal Energy Regulatory Commission:
2 Annual admin charges assessed by FERC 3,306,7913,306,791
3
4 General Regulatory Expenses and
17,0615VariousotherDockets17,061
6
7 Oregon Flydro -Fees Amortization 158,501 158,501
8
9 Regulatory Commission Expenses -Idaho
10 Rate Case -Misc expenses 1,066 1,066
11
12 Regulatory Commission Expenses -Oregon
Rate Case -Misc expenses 138 13813
111,54114GeneralRegulatory111,541
Other OPUC expenses 21,1591521,159
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
3,465,292 150,965 3,616,25746TOTAL
FERC FORM NO.1 (ED.12-96)Page 350
Year/Period of Report
End of 2015/Q4
Name of Respondent
Idaho Power Company
This Report Is:
(1)[X]An Original
(2)||A Resubmission
REGULATORY COMMISSION EXPENSES (Continued)
Date of Report
(Mo,Da,Yr)
04/15/2016
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.
AMORTIZED DURING YEAREXPENSESINCURREDDURINGYEAR
Deferred in
Account 182.3
End of Year
Contra
Account
Deferred to
Account 182.3
CURRENTLY CHARGED TO
Account'—
LineAmount
AmountDepartment No.No.
0)G)no(h)illM
1
23,306,791Electric928
3
4
5Electric92817,061
6
7158,501Electric928
8
9
101,066Electric928
11
12
13Electric928138
14Electric928111,541
15Electric21,159928
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
3,616,257 46
FERC FORM NO.1 (ED.12-96)Page 351
Date of Report
(Mo.Da,Yr)
04/15/2016
Year/Period of Report
End of 2015/Q4
Name of Respondent
Idaho Power Company
This Report Is:
(1)[x]An Original
(2)|—|A Resubmission
RESEARCH,DEVELOPMENT,AND DEMONSTRATION ACTIVITIES
1 .Describe and show below costs incurred and accounts charged during the year for technological research,development,and demonstration (R,D &
D)project initiated,continued or concluded during the year.Report also support given to others during the year for jointly-sponsored projects.(ldentify
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:
(1)Generation
a.hydroelectric
i.Recreation fish and wildlife
ii Other hydroelectric
b.Fossil-fuel steam
c.Internal combustion or gas turbine
d.Nuclear
e.Unconventional generation
f.Siting and heat rejection
(2)Transmission
a.Overhead
b.Underground
(3)Distribution
(4)Regional Transmission and Market Operation
(5)Environment (other than equipment)
(6)Other (Classify and include items in excess of $50,000.)
(7)Total Cost Incurred
B.Electric,R,D &D Performed Externally:
(1)Research Support to the electrical Research Council or the Electric
Power Research Institute
DescriptionLineClassification
No.(b)(a)
1 Idaho Power did not incur any Research and
2 Development expenditures in 2015,
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
FERC FORM NO.1 (ED.12-87)Page 352
Name of Respondent
Idaho Power Company
Date of Report
(Mo,Da,Yr)
04/15/2016
Year/Period of Report
End of 2015/Q4
This Report Is:
(1)[X]An Original
(2)Q A Resubmission
RESEARCH,DEVELOPMENT,AND DEMONSTRATION ACTIVITIES (Continued)
(2)Research Support to Edison Electric Institute
(3)Research Support to Nuclear Power Groups
(4)Research Support to Others (Classify)
(5)Total Cost Incurred
3.Include in column (c)all R,D &D items performed internally and in column (d)those items performed outside the company costing $50,000 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 $50,000 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.
Unamortized
Accumulation
AMOUNTS CHARGED IN CURRENT YEARCostsjncurredInternallyCostsIncurredExternally
Current Year
Line
Current.Year Account Amount No.
(g)M (e)(f)
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
FERC FORM NO.1 (ED.12-87)Page 353
Name of Respondent
Idaho Power Company
This Report Is:
(1)|X|An Original
(2)||A Resubmission
Year/Period of Report
End of 2015/Q4
Date of Report
(Mo.Da,Yr)
04/15/2016
DISTRIBUTION OF SALARIES AND WAGES
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.
Allocation of
Payroll charged for
Clearing Accounts
Line Classification Direct Payroll
Distribution Total
No.
(b)(d)(a)
1 Electric
2 Operation
3 Production 23,391,734
4 Transmission 7,150,122
5 Regional Market
6 Distribution 19,443,315
7 Customer Accounts 11,146,099
8 Customer Service and Informational 5,063,852
9 Sales
10 Administrative and General 45,969,645,
11 TOTAL Operation (Enter Total of lines 3 thru 10)112,164,767
12 Maintenance
13 Production 4,962,423
14 Transmission 3,482,962
15 Regional Market
16 Distribution 8,340,987
17 Administrative and General 963,324
18 TOTAL Maintenance (Total of lines 13 thru 17)17,749,696
19 Total Operation and Maintenance
20 Production (Enter Total of lines 3 and 13)28,354,157
21 Transmission (Enter Total of lines 4 and 14)10,633,084
22 Regional Market (Enter Total of Lines 5 and 15)
23 Distribution (Enter Total of lines 6 and 16)27,784,302
24 Customer Accounts (Transcribe from line 7)11,146,099
Customer Service and Informational (Transcribe from line 8)25 5.063,852
26 Sales (Transcribe from line 9)
27 Administrative and General (Enter Total of lines 10 and 17)46,932,969
28 TOTAL Oper.and Maint.(Total of lines 20 thru 27)129,914,463 129,914,463
29 Gas
30 Operation
31 Production-Manufactured Gas
32 Production-Nat.Gas (Including Expl.and Dev.)
33 Other Gas Supply
34 Storage,LNG Terminaling and Processing
35 Transmission
36 Distribution
Customer Accounts37
38 Customer Service and Informational
39 Sales
40 Administrative and General
41 TOTAL Operation (Enter Total of lines 31 thru 40)
42 Maintenance
43 Production-Manufactured Gas
44 Production-Natural Gas (Including Exploration and Development)
45 Other Gas Supply
46 Storage,LNG Terminaling and Processing
47 Transmission
FERC FORM NO.1 (ED.12-88)Page 354
Name of Respondent
Idaho Power Company
This Report Is:
(1)[x]An Original
(2)|—|A Resubmission
DISTRIBUTION OF SALARIES AND WAGES (Continued)
Date of Report
(Mo,Da,Yr)
04/15/2016
Year/Period of Report
End of 2015/Q4
Allocation of
Payroll charged for
Clearing Accounts
Line Classification Direct Payroll
Distribution Total
No.
M (b)(d)
48 Distribution
49 Administrative and General
50 TOTAL Maint.(Enter Total of lines 43 thru 49)
Total Operation and Maintenance51
52 Production-Manufactured Gas (Enter Total of lines 31 and 43)
53 Production-Natural Gas (Including Expl.and Dev.)(Total lines 32,
54 Other Gas Supply (Enter Total of lines 33 and 45)
55 Storage,LNG Terminaling and Processing (Total of lines 31 thru
56 Transmission (Lines 35 and 47)
57 Distribution (Lines 36 and 48)
58 Customer Accounts (Line 37)
59 Customer Service and Informational (Line 38)
60 Sales (Line 39)
61 Administrative and General (Lines 40 and 49)
62 TOTAL Operation and Maint.(Total of lines 52 thru 61 )
63 Other Utility Departments
64 Operation and Maintenance
65 TOTAL All Utility Dept.(Total of lines 28,62,and 64)129,914,463 129,914,463
66 Utility Plant
67 Construction (By Utility Departments)
68 Electric Plant
Gas Plant69
70 Other (provide details in footnote):
71 TOTAL Construction (Total of lines 68 thru 70)
72 Plant Removal (By Utility Departments)
Electric Plant73
Gas Plant74
75 Other (provide details in footnote):
76 TOTAL Plant Removal (Total of lines 73 thru 75)
77 Other Accounts (Specify,provide details in footnote):
78 Stores Expense 5,289,704 5,289,704
79 Other Clearing Accounts 3,200,159 3,200,159
80 Construction Work in Progress 57,439,81157,439,811
Other Work in Progress81 3,287,058 3,287,058
82 Paid Absences 23,344,477 23,344,477
83 Preliminary Survey and Investigation 4,463 4,463
84 Other Accounts 5,389,0685,389,068
85
86
87
88
89
90
91
92
93
94
95 TOTAL Other Accounts 97,954,740 97,954,740
96 TOTAL SALARIES AND WAGES 227,869,203 227,869,203
FERC FORM NO.1 (ED.12-88)Page 355
Name of Respondent
Idaho Power Company
Date of Report
(Mo,Da,Yr)
04/15/2016
Year/Period of Report
End of 2015/Q4
This Report Is:
(1)[X]An Original
(2)||A Resubmissi
PURCHASES AND SALES OF ANCILLARY SERVICES
on
Report the amounts for each type of ancillary service shown in column (a)for the year as specified in Order No.888 and defined in the
respondents Open Access Transmission Tariff.
In columns for usage,report usage-related billing determinant and the unit of measure.
(1 )On line 1 columns (b),(c),(d),(e),(f)and (g)report the amount of ancillary services purchased and sold during the year.
(2)On line 2 columns (b)(c),(d),(e),(f),and (g)report the amount of reactive supply and voltage control services purchased and sold
during the year.
(3)On line 3 columns (b)(c),(d),(e),(f),and (g)report the amount of regulation and frequency response services purchased and sold
during the year.
(4)On line 4 columns (b),(c),(d),(e),(f),and (g)report the amount of energy imbalance services purchased and sold during the year.
(5)On lines 5 and 6,columns (b),(c),(d),(e),(f),and (g)report the amount of operating reserve spinning and supplement services
purchased and sold during the period.
(6)On line 7 columns (b),(c),(d),(e),(f),and (g)report the total amount of all other types ancillary services purchased or sold during
the year.Include in a footnote and specify the amount for each type of other ancillary service provided.
Amount Purchased for the Year Amount Sold for the Year
Usage -Related Billing Determinant Usage -Related Billing Determinant
Unit of
Measure
Unit of
MeasureTypeofAncillaryServiceNumberofUnitsDollarsNumberofUnits DollarsLine
(a)(b)(c)(d)(e)(f)(g)No.
1 Scheduling,System Control and Dispatch 563,957
2 Reactive Supply and Voltage 39,649
3 Regulation and Frequency Response 3,202,871 KW 313,721
4 Energy Imbalance -2,946 KWH -15,107
5 Operating Reserve -Spinning 7,991 4,154,060 KW 406,890
6 Operating Reserve -Supplement 7,321 4,154,060 KW 406,890
7 Other
8 Total (Lines 1 thru 7)618,918 11,508,045 1,112,394
FERC FORM NO.1 (New 2-04)Page 398
Date of Report Year/Period of Report
(Mo,Da,Yr)
04/15/2016
Name of Respondent This Report is:
(1)X An Original
(2)A Resubmission
FOOTNOTE DATA
2015/Q4IdahoPowerCompany
Schedule Page:398 Column:bLineNo.:8
Idaho Power does not systematically record the number of units related to ancillary
services purchased.
FERC FORM NO.1 (ED.12-87)Page 450.1
This Report Is:
(1)jjjAn Original
(2)"HA Resubmission
Name of Respondent
Idaho Power Company
Date of Report
(Mo,Da,Yr)
04/15/2016
Year/Period of Report
End of 2015/Q4
MONTHLY TRANSMISSION SYSTEM PEAK LOAD
(1)Report the monthly peak load on the respondent's transmission system.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 on Column (b)by month the transmission system's peak load.
(3)Report on Columns (c )and (d)the specified information for each monthly transmission -system peak load reported on Column (b).
(4)Report on Columns (e)through (j)by month the system'monthly maximum megawatt load by statistical classifications.See General Instruction for
the definition of each statistical classification.
NAME OF SYSTEM:Idaho Power Company
Line Monthly Peak
MW -Total
Day of
Monthly
Hourof Firm Network
Monthly Service for Self
Peak
Short-Term Firm
Point-to-point
Reservation
Other
Service
Firm Network
Sen/ice for
Others
Long-Term Firm
Point-to-point
Reservations
Other Long-
Term Firm
Service
No.Month
Peak
(a)(b)(c)(d)(e)(f)(g)(h)(i)(j)
4,700 3,850 242 463 1451January21000
4,275 3,137 4911844632February19800
3,3264,422 211 463 4223March5800
10,313 637 1,389 1,0584TotalforQuarter1
4,476 3,396 259 463 3585April211900
4,71 £3,533 285 463 4386May42100
5,934 4,818 2803734637June261700
11,747 1,0769171,3898TotalforQuarter2
6,016 4,979 1983764639July11800
4,4585,623 307 463 39510August131500
5,048 4,070 293 463 22211September20001
13,507 976 1,389 81512TotalforQuarter3
4,281 3,375 170 463 27313October101700
3,208 2,103 234 9877314November3C1900
3,257 1,851 244 38977315DecemberI800
7,329 7606482,00916TotalforQuarter4

1 7 Total Year to
Date/Year 42,896 3,178 6,176 3,709
Page 400FERCFORMNO.1/3-Q (NEW.07-04)
Date of Report Year/Period of Report
(Mo,Da,Yr)
04/15/2016
Name of Respondent This Report is:
(1)X An Original
(2)_A Resubmission 2015/Q4IdahoPowerCompany
FOOTNOTE DATA
Schedule Page:400 Line No.:17 Column:e
Firm Network Service for Self,includes 1836 MW associated with pre-Order No.588
transmission agreements between PacifiCorp and Idaho Power.
associated with the pre-Order No.888 transmission agreements is part of Idaho Power's
total firm load and is included in the load denominator in the computation of,and
accordance with,Idaho Power's Open Access Transmission Tariff ("OATT")rate.
24,2014,the Parties entered into a Joint Purchase and Sale Agreement and a Termination
Agreement that resulted in the elimination of 1836 MW of contract demand that is
associated with the pre-Order No.888 transmission agreements that terminate upon closing
of the transaction.
The contract demand
On October
The Parties received all required regulatory approvals and the
transaction closed October 30,2015.
FERC FORM NO.1 (ED.12-87)Page 450.1
Date of Report
(Mo,Da,Yr)
04/15/2016
Name of Respondent
Idaho Power Company
This Report Is:
(1)[X|An Original
(2)||A Resubmission
ELECTRIC ENERGY ACCOUNT
Year/Period of Report
End of 2015/Q4
Report below the information called for concerning the disposition of electric energy generated,purchased,exchanged and wheeled during the year.
Line Item Line Item MegaWatt HoursMegaWattHours
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
Interdepartmental Sales)
14,264,493
3 Steam 4,676,370
23 Requirements Sales for Resale (See
instruction 4,page 311.)
4 Nuclear
5 Hydro-Conventional 5,909,916
24 Non-Requirements Sales for Resale (See
instruction 4,page 311.)
1,254,1366Hydro-Pumped Storage
7 Other 2,075,731
25 Energy Furnished Without Charge8LessEnergyforPumping
26 Energy Used by the Company (Electric
Dept Only,Excluding Station Use)
9 Net Generation (Enter Total of lines 3
through 8)
12,662,017
27 Total Energy Losses 1,051,71810Purchases3,788,934
28 TOTAL (Enter Total of Lines 22 Through
27)(MUST EQUAL LINE 20)
16,570,34711PowerExchanges:
12 Received 276,510
13 Delivered 162,239
14 Net Exchanges (Line 12 minus line 13)114,271
15 Transmission For Other (Wheeling)
16 Received 5,920,350
17 Delivered 5,915,225
18 Net Transmission for Other (Line 16 minus
line 17)
5,125
19 Transmission By Others Losses
20 TOTAL (Enter Total of lines 9,10,14,18
and 19)
16,570,347
Page 401aFERCFORMNO.1 (ED.12-90)
This Report Is:
(1)[x|An Original
(2)Q A Resubmission
Name of Respondent
Idaho Power Company
Year/Period of Report
End of 2015/Q4
Date of Report
(Mo.Da,Yr)
04/15/2016
MONTHLY PEAKS AND OUTPUT
1.Report the monthly peak load and energy output.If the respondent has two or more power which are not physically integrated,furnish the required
information for each non-integrated system.
2.Report in column (b)by month the system 's output in Megawatt hours for each month.
3.Report in column (c)by month the non-requirements sales for resale.Include in the monthly amounts any energy losses associated with the sales.
4.Report in column (d)by month the system 's monthly maximum megawatt load (60 minute integration)associated with the system.
5.Report in column (e)and (f)the specified information for each monthly peak load reported in column (d).
NAME OF SYSTEM:Idaho Power Company
Monthly Non-Requirments
Sales for Resale &
Associated Losses
MONTHLY PEAKLine
No.Megawatts (See Instr.4)Day of Month HourMonthTotalMonthlyEnergy
(e)(f)(a)(b)(c)(d)
29 January 1,429,454 162,212 2,168 2 9 AM
30 February 1,215,125 1,993 23 8 AM205,779
4 8 AM31March1,214,436 167,129 1,919
10 PM32April1,212,235 35,621 1,997 28
33 May 1,304,647 103,313 2,156 4 8 PM
34 June 1,718,107 3,402 30 4 PM62,532
3,360 1 7 PM35July1,747,644 109,737
12 6 PM36August1,644,547 30,741 3,221
1 7 PM37September1,270,259 62,870 2,473
38 October 1,186,337 138,462 1,814 10 6 PM
39 November 1,209,550 66,026 2,203 30 7 PM
1,418,006 2,241 1 8 AM40December109,714
41 TOTAL 16,570,347 1,254,136
Page 401bFERCFORMNO.1 (ED.12-90)
This Page Intentionally Left Blank
Date of Report Year/Period of Report
(Mo,Da,Yr)
04/15/2016
Name of Respondent This Report is:
(1)X An Original
(2)_A ResubmissionIdahoPowerCompany 2015/Q4
FOOTNOTE DATA
Schedule Page:401 Line No.:17 Column:b
Page 329 Column I differs from page 401 by 5,125 MWH,reported for Lucky Peak variation
and BPA Energy imbalance schedules on page 401.The numbers that are shown on pages
328-330 are for account 456 wheeling only,the numbers on page 401 have to be adjusted for
account 447 transmission.
FERC FORM NO.1 (ED.12-87)Page 450.1
Year/Period of Report
End of 2015/Q4
This Report Is:
(1)[X|An Original
(2)||A Resubmission
Date of Report
(Mo.Da,Yr)
04/15/2016
Name of Respondent
Idaho Power Company
STEAM-ELECTRIC GENERATING PLANT STATISTICS (Large Plants)
1 .Report data for plant in Service only.2.Large plants are steam plants with installed capacity (name plate rating)of 25,000 Kw or more.Report in
this page gas-turbine and internal combustion plants of 10,000 Kw or more,and nuclear plants.3.Indicate by a footnote any plant leased or operated
as a joint facility.4.If net peak demand for 60 minutes is not available,give data which is available,specifying period.5.If any employees attend
more than one plant,report on line 1 1 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 Met.7.Quantities of fuel burned (Line 38)and average cost
per unit of fuel burned (Line 41)must be consistent with charges to expense accounts 501 and 547 (Line 42)as show on Line 20.8.If more than one
fuel is burned in a plant furnish only the composite heat rate for all fuels burned.
Plant
Name:Boardman
Item Plant
Name:Jim Bridger
Line
No.
(c)(a)(b)
SteamSteam1KindofPlant(Internal Comb,Gas Turb,Nuclear
Conventional2TypeofConstr(Conventional,Outdoor,Boiler,etc)Semi-Outdoor Boiler
198019743YearOriginallyConstructed
1979 19804YearLastUnitwasInstalled
770.50 64.205TotalInstalledCap(Max Gen Name Plate Ratings-MW)
646NetPeakDemandonPlant-MW (60 minutes)727
501787607PlantHoursConnectedtoLoad
008NetContinuousPlantCapability(Megawatts)
009WhenNotLimitedbyCondenserWater
0010WhenLimitedbyCondenserWater
0011AverageNumberofEmployees
182941000409605000012NetGeneration,Exclusive of Plant Use -KWh
10661051772013CostofPlant:Land and Land Rights
124920167039675114StructuresandImprovements
546181648 6361329815EquipmentCosts
44314319755694AssetRetirementCosts16
80643355626851813TotalCost17
1256.127018CostperKWofInstalledCapacity(line 17/5)Including 813.5650
39740523464319ProductionExpenses:Oper,Supv,&Engr
473707211608460620Fuel
00CoolantsandWater(Nuclear Plants Only)21
771734591437522SteamExpenses
0 0SteamFromOtherSources23
0024SteamTransferred(Cr)
00ElectricExpenses25
3937626301917MiscSteam(or Nuclear)Power Expenses26
043203827Rents
0 028Allowances
109988 1284029MaintenanceSupervisionandEngineering
876400MaintenanceofStructures30
2235057602363MaintenanceofBoiler(or reactor)Plant31
19676452550850MaintenanceofElectricPlant32
6711067 46900MaintenanceofMiscSteam(or Nuclear)Plant33
145941847 8638503TotalProductionExpenses34
0.04720.0356ExpensesperNetKWh35
Coal OilCoalOil36Fuel:Kind (Coal,Gas,Oil,or Nuclear)
Tons BarrelsUnit(Coal-tons/Oil-barrel/Gas-mcf/Nuclear-indicate)Tons Barrels37
111192 1083 038Quantity(Units)of Fuel Burned 2303826 6262 0
8559 138800 039AvgHeatCont-Fuel Burned (btu/indicate if nuclear)9173 140000 0
39.377 76.795 0.00040AvgCostofFuel/unit,as Delvd f.o.b.during year 108.869 0.00048.729
41.435 105.956 0.00090.059 0.000AverageCostofFuelperUnitBurned50.03841
2.464 18.182 0.00015.316 0.00042AverageCostofFuelBurnedperMillionBTU2.722
0.000 0.00043AverageCostofFuelBurnedperKWhNetGen0.000 0.000 0.0260.028
10255.000 0.000 0.0000.000 0.00044AverageBTUperKWhNetGeneration10347.000
FERC FORM NO.1 (REV.12-03)Page 402
Year/Period of Report
End of 2015/Q4
Name of Respondent
Idaho Power Company
This Report Is:
(1)[x]An Original
(2)||A Resubmission
Date of Report
(Mo.Da,Yr)
04/15/2016
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 25 "Electric Expenses,"and Maintenance Account Nos.553 and 554 on Line 32,"Maintenance of Electric Plant."Indicate plants
designed for peak load service.Designate automatically operated plants.1 1 .For a plant equipped with combinations of fossil fuel steam,nuclear
steam,hydro,internal combustion or gas-turbine equipment,report each as a separate plant.However,if a gas-turbine unit functions in a combined
cycle operation with a conventional steam unit,include the gas-turbine with the steam plant.12.If a nuclear power generating plant,briefly explain by
footnote (a)accounting method for cost of power generated including any excess costs attributed to research and development;(b)types of cost units
used for the various components of fuel cost;and (c)any other informative data concerning plant type fuel used,fuel enrichment type and quantity for the
report period and other physical and operating characteristics of plant.
LinePlant
Name:Valmy
Plant
Name:Danskin
Plant
Name:Bennett Mountain No.
(e)(f)(d)
Gas Turbine Gas Turbine 1Steam
Conventional 2OutdoorConventional
3198120012005
2005 419852008
283.50 172.80 5270.90
185 6262252
1538 1023 77664
164 80261
0 0 90
0 1000
4 1108
157875000 12255025000249740000
1340274501106140
1688442 14705199616087725
51991319 15323843957100153211
0 16-257063 0
53679761 17395212995106643681
310.6468 181394.0494 393.6644
12812 19655838192181
6071381 20972946210464678
0 0 210
0 2231055020
0 2300
0 2400
471697 251262175539906
152790 26-19410 311203
0 0 270
0 0 280
0 2941650
135606 30790432134240
5795 3160356912151
234934894058246946 32
0 0 33165285
7085015 342335841411156089
0.0449 350.0935 0.0437
Gas 36CoalOilGas
MCF MCF 37TonsBarrels
2547925 1601807 0 0 3813992012293000
1027 0 0 39113981387780102700
0.000 0.000 4036.239 88.175 0.000 3.819 0.000 0.000 3.790
0.000 0.000 4167.361 83.462 0.000 3.819 0.000 0.000 3.790
0.000 0.000 4214.319 0.000 3.200 0.000 0.000 3.1803.725
0.000 0.000 430.000 0.038 0.000 0.000 0.0380.042 0.000
0.000 0.000 440.000 10261.000 0.000 0.000 10420.00010419.000 0.000
FERC FORM NO.1 (REV.12-03)Page 403
Year/Period of Report
End of 2015/Q4
Name of Respondent
Idaho Power Company
This Report Is:
(1)|x|An Original
(2)||A Resubmission
Date of Report
(Mo,Da,Yr)
04/15/2016
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 internal combustion plants of 10,000 Kw or more,and nuclear plants.3.Indicate by a footnote any plant leased or operated
as a joint facility.4.If net peak demand for 60 minutes is not available,give data which is available,specifying period.5.If any employees attend
more than one plant,report on line 1 1 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 Met.7.Quantities of fuel burned (Line 38)and average cost
per unit of fuel burned (Line 41 )must be consistent with charges to expense accounts 501 and 547 (Line 42)as show on Line 20.8.If more than one
fuel is burned in a plant furnish only the composite heat rate for all fuels burned.
Line Plant
Name:Langley Gulch
Plant
Name:
Item
No.
(c)(a)(b)
1 Kind of Plant (Internal Comb,Gas Turb,Nuclear Gas Turbine
2 Type of Constr (Conventional,Outdoor,Boiler,etc)Conventional
3 Year Originally Constructed 2012
4 Year Last Unit was Installed 2012
0.005TotalInstalledCap(Max Gen Name Plate Ratings-MW)318.45
06NetPeakDemandonPlant-MW (60 minutes)301
6132 07PlantHoursConnectedtoLoad
8 Net Continuous Plant Capability (Megawatts)0300
09WhenNotLimitedbyCondenserWater0
010WhenLimitedbyCondenserWater0
011AverageNumberofEmployees22
12 Net Generation.Exclusive of Plant Use -KWh 1662770000 0
2287261 013CostofPlant:Land and Land Rights
134922940 014StructuresandImprovements
015EquipmentCosts240012947
016AssetRetirementCosts0
017TotalCost377223148
018CostperKWofInstalledCapacity(line 17/5)Including 1184.5601
19 Production Expenses:Oper,Supv,&Engr 310438 0
39140394 020Fuel
021CoolantsandWater(Nuclear Plants Only)0
022SteamExpenses0
023SteamFromOtherSources0
024SteamTransferred(Cr)0
0359230425ElectricExpenses
26 Misc Steam (or Nuclear)Power Expenses 350000 0
0 027Rents
0 028Allowances
029MaintenanceSupervisionandEngineering0
0MaintenanceofStructures9384830
Maintenance of Boiler (or reactor)Plant 32341 031
788337 032MaintenanceofElectricPlant
033MaintenanceofMiscSteam(or Nuclear)Plant 0
04430766234TotalProductionExpenses
0.00000.026635ExpensesperNetKWh
36 Fuel:Kind (Coal,Gas,Oil,or Nuclear)Gas
37 Unit (Coal-tons/Oil-barrel/Gas-mcf/Nuclear-indicate)MCF
0 038Quantity(Units)of Fuel Burned 11344468 0 0 0
0 039AvgHeatCont-Fuel Burned (btu/indicate if nuclear)1027 0 0 0
0.000 0.00040AvgCostofFuel/unit,as Delvd f.o.b.during year 3.450 0.000 0.000 0.000
0.00041AverageCostofFuelperUnitBurned3.450 0.000 0.000 0.000 0.000
0.0002.950 0.000 0.000 0.000 0.00042AverageCostofFuelBurnedperMillionBTU
43 Average Cost of Fuel Burned per KWh Net Gen 0.024 0.000 0.000 0.000 0.000 0.000
44 Average BTU per KWh Net Generation 7007.000 0.000 0.000 0.000 0.000 0.000
FERC FORM NO.1 (REV.12-03)Page 402.1
Date of Report Year/Period of Report
(Mo,Da,Yr)
04/15/2016
Name of Respondent This Report is:
(1)X An Original
(2)_A Resubmission 2015/Q4IdahoPowerCompany
FOOTNOTE DATA
,—|
Schedule Page:402 Line No.:3 Column:b
This footnote applies to lines 3 and 4 .The Jim Bridger Power
Plant consists of four equal units constructed jointly by Idaho
Power Company and Pacific Power and Light Company,with Idaho
owning 1/3 and PacifiCorp owning 2/3.Unit #1 was placed in
commercial operation November 30,1974,Unit #2 December 1,1975,
Unit #3 September 1,1976,and Unit #4 November 29,1979.
Schedule Page:402 Line No.:3 Column:c
This footnote applies to lines 3 and 4 .The Boardman plant
consists of one unit constructed jointly by Portland General
Electric Company,Idaho Power Company,and Pacific Northwest
Generating Company,with Idaho Power Company owning 10%.The
unit was placed in commercial operation August 3,1980.
Schedule Page:403 Line No.:3 Column:d
This footnote applies to lines 3 and 4 .The Valmy plant consists
of two units constructed jointly by Sierra Pacific Power Company
and Idaho Power Company,with Sierra owning 1/2 and Idaho owning
1/2.Unit #1 was placed in commercial operation December 11,1981
and Unit #2 May 21,1985.
Schedule Page:402 Line No.:5 Column:b
This footnote applies to line 5 and lines 12 through 43.
Information reflects Idaho Power Company's share as explained
in note for line 3 page 402 column B.
Schedule Page:402 Line No.:5 Column:c
This footnote applies to line 5 and lines 12 through 43.
Information reflects Idaho Power Company's share as explained
in note on line 3 page 402 column C
Schedule Page:403 Line No.:5 Column:d
This footnote applies to line 5 and lines 12 through 43.
Information reflects Idaho Power Company's share as explained
in note for line 3 page 403 column D.
Schedule Page:402 Line No.:9 Column:b
This footnote applies to lines 9,10,and 11.PacifiCorp
as operator of the plant will report this
information .
Schedule Page:402 Line No.:9 Column:c
This footnote applies to lines 9,10,and 11.Portland General
Electric Company,as operator will report this information.
Schedule Page:403 Line No.:9 Column:d
This footnote applies to lines 9,10,and 11.Sierra Pacific
Power,as operator of the plant,will report this information.
FERC FORM NO.1 (ED.12-87)Page 450.1
Year/Period of Report
End of 2015/Q4
Name of Respondent
Idaho Power Company
This Report Is:
(1)pg An Original
(2)||A Resubmission
Date of Report
{Mo.Da,Yr)
04/15/2016
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 plant,report on line 1 1 the approximate average number of employees assignable to each
plant.
FERC Licensed Project No.1975
Plant Name:Bliss
FERC Licensed Project No.2736
Plant Name:American Falls
Line Item
No.
(c)M(a)
Run-of-River Run-of-River1KindofPlant(Run-of-River or Storage)
OutdoorOutdoor2PlantConstructiontype(Conventional or Outdoor)
194919783YearOriginallyConstructed
195019784YearLastUnitwasInstalled
75.0092.305Totalinstalledcap(Gen name plate Rating in MW)
546NetPeakDemandonPlant-Megawatts (60 minutes)95
8,7276,9097PlantHoursConnecttoLoad
8 Net Plant Capability (in megawatts)
761109(a)Under Most Favorable Oper Conditions
1010(b)Under the Most Adverse Oper Conditions
4411AverageNumberofEmployees
311,673,000294,308,00012NetGeneration,Exclusive of Plant Use -Kwh
13 Cost of Plant
768,366875,31814LandandLandRights
1,098,13511,986,63615StructuresandImprovements
8,963,5814,293,07516Reservoirs,Dams,and Waterways
9,463,70332,331,62417EquipmentCosts
486,477839,27618Roads,Railroads,and Bridges
0019AssetRetirementCosts
20,780,26250,325,92920TOTALcost(Total of 14 thru 19)
277.0702CostperKWofInstalledCapacity(line 20 /5)545.243021
22 Production Expenses
814,397209,91623OperationSupervisionandEngineering
870,0281,530,108WaterforPower24
964,512136,36425HydraulicExpenses
46,37183,11426ElectricExpenses
449,505277,54927MiscHydraulicPowerGenerationExpenses
3,40513728Rents
5,9768,57629MaintenanceSupervisionandEngineering
44,538158,78830MaintenanceofStructures
67,4646,12831MaintenanceofReservoirs,Dams,and Waterways
115,994304,393MaintenanceofElectricPlant32
145,73767,013MaintenanceofMiscHydraulicPlant33
3,527,9272,782,08634TotalProductionExpenses(total 23 thru 33)
0.01130.009535ExpensespernetKWh
Page 406FERCFORMNO.1 (REV.12-03)
Date of Report
(Mo,Da,Yr)
04/15/2016
Year/Period of Report
End of 2015/Q4
Name of Respondent
Idaho Power Company
This Report Is:
(1)[X]An Original
(2)||A Resubmission
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.2848
Plant Name:Cascade
FERC Licensed Project No.1971
Plant Name:Oxbow
FERC Licensed Project No.1971
Plant Name:Brownlee
Line
No.
(e)M .01
Storage 1Run-of-RiverStorage
2OutdoorOutdoorOutdoor
3196119581983
4196119841980
5190.0012.42585.40
620512534
78,7607,8718,760
8
922115747
102021220
11628
12750,079,00031,539,0001,719,268,000
13
141,212,76782,14218,266,595
1510,878,1677,380,84232,472,875
1630,432,9753,145,63067,619,060
1719,497,72113,881,88661,266,804
18585,876122,668529,364
19000
2062,607,50624,613,168180,154,698
21329.51321,981.7366307.7463
22
23382,292226,686810,294
24299,516228,916666,009
25553,562417,4741,228,538
26161,460107,054314,903
27415,275927,272 294,065
2818,315141111,511
2910,9183,21625,206
30112,66112,431181,794
315,274-934,061
32147,76764,559748,067
33341,148100,709428,623
342,448,1881,455,2425,476,278
350.00330.04610.0032
FERC FORM NO.1 (REV.12-03)Page 407
Date of Report
(Mo.Da,Yr)
04/15/2016
Year/Period of Report
End of 2015/Q4
Name of Respondent
Idaho Power Company
This Report Is:
(1)[X]An Original
(2)||A Resubmission
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 plant,report on line 1 1 the approximate average number of employees assignable to each
plant.
FERC Licensed Project No.2726
Plant Name:Malad
FERC Licensed Project No.1971
Plant Name:Hells Canyon
Line Item
No.
(b)M(a)
Run-of-RiverStorage1KindofPlant(Run-of-River or Storage)
Outdoor Outdoor2PlantConstructiontype(Conventional or Outdoor)
19483YearOriginallyConstructed1967
194819674YearLastUnitwasInstalled
391.50 21.775Totalinstalledcap(Gen name plate Rating in MW)
236NetPeakDemandonPlant-Megawatts (60 minutes)330
8,7607PlantHoursConnecttoLoad8,760
! "
8 Net Plant Capability (in megawatts)
445 259(a)Under Most Favorable Oper Conditions
137 2110(b)Under the Most Adverse Oper Conditions
111AverageNumberofEmployees5
154,194,00012NetGeneration,Exclusive of Plant Use -Kwh 1,461,432,000
13 Cost of Plant
205,3761,880,38114LandandLandRights
2,824,1262,931,90015StructuresandImprovements
52,872,923 6,283,40616Reservoirs,Dams,and Waterways
19,960,871 12,088,094EquipmentCosts17
1,542,871922,78118Roads,Railroads,and Bridges
0AssetRetirementCosts019
22,943,873TOTALcost(Total of 14 thru 19)78,568,85620
1,053.9216200.686721CostperKWofInstalledCapacity(line 20 /5)
I22ProductionExpensesB
472,143 196,89523OperationSupervisionandEngineering
425,145 849,855WaterforPower24
797,610 230,74025HydraulicExpenses
65,750295,71126ElectricExpenses
177,704575,747MiscHydraulicPowerGenerationExpenses27
30,450 0Rents28
24,842 3,42029MaintenanceSupervisionandEngineering
8,347MaintenanceofStructures36,43030
22,262244,24931MaintenanceofReservoirs,Dams,and Waterways
359,716 35,828MaintenanceofElectricPlant32
688,719 147,409MaintenanceofMiscHydraulicPlant33
1,738,21034TotalProductionExpenses(total 23 thru 33)3,950,762
0.01130.002735ExpensespernetKWh
FERC FORM NO.1 (REV.12-03)Page 406.1
Date of Report
(Mo,Da,Yr)
04/15/2016
Year/Period of Report
End of 2015/Q4
This Report Is:
(1)[X|An Original
(2)||A Resubmission
Name of Respondent
Idaho Power Company
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.503
Plant Name:Swan Falls
FERC Licensed Project No.18
Plant Name:Twin Falls
FERC Licensed Project No.2055
Plant Name:C J Strike
Line
No.
(d)(e)ifl
1Run-of-RiverRun-of-RiverRun-of-River
2ConventionalConventionalOutdoor
3193519101952
4199519941952
552.7425.0082.80
6372287
77,1578,7478,760
8
9245391
10145084
11345
1276,114,000110,847,000375,982,000
13
14255,499231,5845,476,746
1511,021,54727,334,9049,780,013
9,000,263 1615,989,46510,807,310
1721,350,84531,037,69214,047,800
181,917,603835,9461,602,868
19000
2043,545,75775,429,59141,714,737
21825.66853,017.1836503.8012
22
23195,251621,417871,100
24214,848710,027963,737
25127,868873,6301,152,655
2674,46425,46450,830
27228,498557,788678,592
283,2246,29855,646
294,16410,7956,615
3044,281126,81782,602
3155,02918,03246,467
3274,878271,370196,523
3386,230258,82588,092
341,108,7353,480,4634,192,859
350.01460.03140.0112
FERC FORM NO.1 (REV.12-03)Page 407.1
Year/Period of ReportThisReportIs:
(1)[Xj An Original
(2)||A Resubmission
Date of Report
(Mo,Da,Yr)
04/15/2016
Name of Respondent
Idaho Power Company End of 201 5/Q4
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 plant,report on line 1 1 the approximate average number of employees assignable to each
plant.
FERC Licensed Project No.2778
Plant Name:Shoshone Falls
FERC Licensed Project No.2777
Plant Name:Upper Salmon
ItemLine
No.
(c)(b)M
Run-of-River1KindofPlant(Run-of-River or Storage)Run-of-River
Conventional2PlantConstructiontype(Conventional or Outdoor)Outdoor
19073YearOriginallyConstructed1937
192119474YearLastUnitwasInstalled
12.505Totalinstalledcap(Gen name plate Rating in MW)34.50
136NetPeakDemandonPlant-Megawatts (60 minutes)36
8,760 8,3857PlantHoursConnecttoLoad
8 Net Plant Capability (in megawatts)
149(a)Under Most Favorable Oper Conditions 39
1110(b)Under the Most Adverse Oper Conditions 32
3 211AverageNumberofEmployees
203,255,000 74,608,00012NetGeneration,Exclusive of Plant Use -Kwh
13 Cost of Plant
313,328202,39814LandandLandRights
1,253,6352,080,26615StructuresandImprovements
10,108,9026,130,43016Reservoirs,Dams,and Waterways
4,703,9418,923,67917EquipmentCosts
51,38329,35918Roads,Railroads,and Bridges
0 0AssetRetirementCosts19
17,366,132 16,431,189TOTALcost(Total of 14 thru 19)20
503.3661 1,314.4951CostperKWofInstalledCapacity(line 20 /5)21
22 Production Expenses
150,239281,12023OperationSupervisionandEngineering
161,587281,81224WaterforPower
339,108 90,955HydraulicExpenses25
94,946 45,14026ElectricExpenses
241,563 183,33527MiscHydraulicPowerGenerationExpenses
88028Rents
2,7785,57029MaintenanceSupervisionandEngineering
24,323111,480MaintenanceofStructures30
36,230 987MaintenanceofReservoirs,Dams,and Waterways31
85,340 79,795MaintenanceofElectricPlant32
68,595115,27833MaintenanceofMiscHydraulicPlant
34 Total Production Expenses (total 23 thru 33)1,592,447 807,822
0.0078 0.0108ExpensespernetKWh35
Page 406.2FERCFORMNO.1 (REV.12-03)
Name of Respondent
Idaho Power Company
This Report Is:
(1)[X]An Original
(2)||A Resubmission
Date of Report
(Mo,Da,Yr)
04/15/2016
Year/Period of Report
Endof 2015/Q4
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.2061
Plant Name:Lower Salmon
FERC Licensed Project No.1971
Plant Name:Common Facilities
FERC Licensed Project No.2899
Plant Name:Milner
Line
No.
M (e)ia
1Run-of-River Run-of-River
2OutdoorConventional
319921949
419491992
50.00 59.4560.00
603834
705,8278,758
8
906461
100601
11025
12070,756,000207,416,000
13
14114,367 424,428 138,100
1541,098,277 2,869,695 10,431,584
1613,556,785 6,920,148 17,431,179
172,246,883 8,197,531 29,260,290
1899,051 501,87788,693
19000
2057,115,363 18,500,495 57,763,030
210.0000 308.3416 971 .6237
22
230270,998 197,687
240298,475 1,477,096
257,416,144 129,881347,273
26032,689125,419
270286,774 276,779
2802,756 3,295
2903,460 3,964
30033,55879,756
31018,43211,408
32044,913 93,791
3392,248 80,272 102,119
347,508,392 1,551,504 2,369,291
350.0000 0.03350.0075
FERC FORM NO.1 (REV.12-03)Page 407.2
This Page Intentionally Left Blank
Date of Report Year/Period of Report
(Mo,Da,Yr)
04/15/2016
Name of Respondent This Report is:
(1)X An Original
(2)_A Resubmission 2015/Q4IdahoPowerCompany
FOOTNOTE DATA
Schedule Page:406 Line No.:1 Column:b
American Falls generating capacity is dependent upon water releases controlled by the
USBR .
Schedule Page:406 Line No.:1 Column:e
Cascade generating capacity is dependent upon water releases controlled by the USBR.
Schedule Page:406 Line No.:1 Column:f
Upstreamstorage in Brownlee Reservoir
Schedule Page:406.1 Line No.:1 Column:b
Upstream storage in Brownlee Reservo ir
Schedule Page:406.1 Line No.:1 Column:c
Lower Malad maximum demand 15,000 Kw,Upper Malad maximum demand 9,000 Kw non-coincident.
FERC FORM NO.1 (ED.12-87)Page 450.1
This Report !s:
(1)[X]An Original
(2)|A Resubmission
GENERATING PLANT STATISTICS (Small Rants)
Name of Respondent
Idaho Power Company
Date of Report
(Mo.Da,Yr)
04/15/2016
Year/Period of Report
End of 2015/Q4
1.Small generating plants are steam plants of,less than 25,000 Kw;internal combustion and gas turbine-plants,conventional hydro plants and pumped
storage plants of less than 10,000 Kw installed capacity (name plate rating).2.Designate any plant leased from others,operated under a license from
the Federal Energy Regulatory Commission,or operated as a joint facility,and give a concise statement of the facts in a footnote.If licensed project,
give project number in footnote.
Installed Ca
Name Plate
(In MW)
pacity
Ratine
Net Peak
Demand
MW(60(gjin.)
Year
Orig.
Const.
Net Generation
Excluding
Plant Use
Line Cost of PlantNameofPlant
No.
(a)(b)(c)(e)(f)
1 Hydro:
2 Clear Lakes 1937 2.50 2.3 15,695 3,583,449
3 Thousand Springs 1912 8.80 7.6 9,566,53152,740
4
5
6 Internal Combustion:
7 Salmon Diesel 1967 5.00 4.0 909,25913
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
Page 410FERCFORMNO.1 (REV.12-03)
Date of Report
(Mo,Da,Yr)
04/15/2016
This Report is:
(1)|X|An Original
(2)||A Resubmission
Year/Period of Report
End of 2015/Q4
Name of Respondent
Idaho Power Company
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.
Production Expenses Fuel Costs (in cents
(per Million Btu)
Operation
Exc'l.Fuel
Plant Cost (Incl Asset
Retire.Costs)Per MW
LineKindofFuelFueFMaintenanceNo.(I)(k)(i)G)(g)(h)
1
238,000 270,4441,433,380
259,879 384,5741,087,106
4
5
6
7Diesel181,852
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
Page 41 1FERCFORMNO.1 (REV.12-03)
This Page Intentionally Left Blank
Date of Report Year/Period of Report
(Mo,Da,Yr)
04/15/2016
This Report is:
(1)X An Original
(2)_A Resubmission
Name of Respondent
2015/Q4IdahoPowerCompany
FOOTNOTE DATA
Schedule Page:410 Line No.:7 Column:a _
Salmon units are classified as standby.
FERC FORM NO.1 (ED.12-87)Page 450.1
Name of Respondent
Idaho Power Company
This Report Is:
(1)[x]An Original
(2)||A Resubmission
TRANSMISSION LINE STATISTICS
Date of Report
(Mo,Da,Yr)
04/15/2016
Year/Period of Report
End of 2015/Q4
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.
DESIGNATION VOLTAGE (KV)
(Indicate where
other than
60 cycle.3 phase)
LENGTH (Pole miles)
(In the casfi.ofundergroundlines
report circuit miles)
On structure On ytructu,;
of Line of AnotherDestanatedLine
Line Type of
Supporting
Structure
NumberNo.
Of
res CircuitsFromOperatingToDesigned
?f)(a)(b)(c)(e)(d)(h)(fl)
345.0C 500.00 S Tower 62.35 1Midpoint1Borah
500.0C 500.00 S Tower 1.79 1Slatt2Boardman
500.0C 500.00 S Tower 0.41 1Hemingway3Summerlake
500.00 500.00 S Tower 0.37 1Midpoint4Hemingway
500.0C 500.00 S Tower 53.09 1Hemingway
Midpoint
5 Summer Lake
500.00 S Tower 47.83500,0C 16Hemingway
7
345.00 345.00 S Tower 66.13 1Goshen8JimBridger
345.00 345.00 S Tower 76.06 29StateLineMidpoint
345.00 345.00 S Tower 19.85 1Borah10Kinport
345.00 345.00 S Tower 60.94 1Populus11JimBridger
345.00 345.00 S Tower 7.42 1Kinport12Populus
345.00 345.00 S Tower 61.09 1Populus13JimBridger
345.00 345.00 S Tower 9.05 1Borah14Populus
345.00 S Tower345.0C 7.49 115GoshenKinport
345.0C 345.00 H Wood 51.07 1Borah#116Midpoint
345.00 345.00 H Wood 50.01 2Borah#217Midpoint
345.0C 345.00 H Wood 1.72 218AdelaideTapAdelaide
19
230.00 230.00 H Wood 46.27 120QuartzLaGrande
230.00 230.00 S Tower 0.70 221MidpointHunt
56.41230.0C 230.00 H Wood 122BradyAntelope
230.00 230.00 H Wood 0.11 123BradyTreasureton
230.00 230.00 S Tower 17.94 224Brady#1 &#2 Kinport
230.00 230.00 H Wood 1PointofRocks25JimBridger
230.00 230,00 S Tower 72.67 126BrownleeOntario
138.00 230.00 S P Wood 9.98 127MoraBowmont
138.00 230.00 H Wood 8.75 128MoraBowmont
230.0C 230.00 H Wood 1PointofRocks29JimBridger
230.0C 230.00 SP Steel 18.60 130Caldwell710Locust
230.0C 230.00 S Tower 7.73 1Caldwell31BoiseBench
230.00 230.00 H Wood 33.49 1Caldwell32BoiseBench
230.0C 230.00 S Tower 15.78 233BoiseBenchCloverdale
230.00 230.00 H Wood 1.67 1DalreedSub34Boardman
230.0C 230.00 SP Steel 11.04 235Brownlee714Oxbow
TOTAL 4,769.03 11.02 20336
Page 422FERCFORMNO.1 (ED.12-87)
Date of Report
{Mo.Da,Yr)
04/15/2016
Year/Period of ReportNameofRespondent
Idaho Power Company
This Report Is:
(1)[x|An Original
(2)|-]A Resubmi
TRANSMISSION LINE STATISTICS (Continued)
2015/Q4Endof
ssion
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.
COST OF LINE (Include in Column (J)Land,EXPENSES,EXCEPT DEPRECIATION AND TAXES
Land rights,and clearing right-of-way)Size of
Conductor
and Material Land Construction and
Other Costs
Total Cost Operation
Expenses
Maintenance
Expenses
Rents Total
Expenses
Line
No.(o)(P)(i)0 (k)(I)(m)(n)
11272ACSR256,381 15,974,858 16,231,239
22X1780ACSR446,708 446,708
1272 ACSR 603,657 603,657 3
1272 ACSR 4
3X1272 ACSR 17,991,88217,991,882 5
63X1272ACSR16,358,594 16,358,594
7
81272ACSR483,309 5,787,895 6,271,204
11,680,140 9795ACSR571,979 11,108,161
101272ACSR344,220 4,396,928 4,741,148
111272ACSR9,512,5979,512,597
121272ACSR
1272 ACSR 139,249,735 9,249,735
141272ACSR
152X1272ACSR514,724 514,724
16715.5 ACSR 283,143 8,543,370 8,826,513
64,851 17715.5 ACSR 10,228,542 10,293,393
18715.5 ACSR 51,448 224,222 275,670
19
20795ACSR62,218 5,685,245 5,747,463
21715.5 ACSR 9,145 998,452 1,007,597
221272ACSR108,301 3,399,123 3,507,424
23795ACSR6,186 6,186
24715.5 ACSR 1,099,27018,829 1,080,441
1,190 251272ACSR1,190
1,676,838 262X954ACSR20,541,790 22,218,628
27715.5 ACSR 413,793 2,209,007 2,622,800
715.5 ACSR 28
291272ACSR1,899 1,899
301590ACSR2,138,236 8,775,086 10,913,322
311272ACSR1,748,214 7,631,906 9,380,120
32715.5 ACSR
331272ACSR3,062,812 6,560,901 9,623,713
34795AAC89,68089,680
954 ACSR 34,174 16,060,644 3516,026,470
8,044,636 3,092,363 3,084,849 14,221,848 3632,174,968 555,434,671 587,609,639
Page 423FERCFORMNO.1 (ED.12-87)
Name of Respondent
Idaho Power Company
This Report Is:
(1)[X]An Original
(2)||A Resubmission
TRANSMISSION LINE STATISTICS
Date of Report
(Mo.Da,Yr)
04/15/2016
Year/Period of Report
End of 2015/Q4
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.
VOLTAGE (KV)DESIGNATION LENGTH (Pole miles)(In Ihe case ofuhdergroundhnes
report circuit miles)
Un Structure On Structures
of Line of Another
Designated
Line Type of
Supporting
Structure
(Indicate where
other than
60 cycle.3 phase)
NumberNo.Of
CircuitsFromToOperatingDesignedme(a)(b)(c)(e)(d)(g)(h)
230.00 30.10 1230.00 H Wood1CaldwellOntario
3.14230.0C 1230.00 S Tower2CaldwellOntario
4.43 1230.00 230.00 SP SteelRattlesnakeTS3BennettMtnPP
68.17230.00 230.00 H Steel 14BorahHunt
230.00 230.00 H Steel 36.30 15DanskinHubbard
230.00 230.00 SP Steel 1.84 16DanskinHubbard
230.00 230.00 SP Steel 1.30 27DanskinHubbard
230,0C 5.39 1230,00 SP Steel8DanskinBennettMtn
230.0C 13.01 1230.00 SP Steel9HemingwayBowmont
138.0C 14.19 1230.00 SP Steel10LangleyGulchGallowayRd
138.0C 230.00 SP Steel 2.09 111GallowayRdWillisTap
230.00 230.00 H Wood 31.66 112WallaWallaHurricane
230.0C 230.00 S Tower 0.87 113BoiseBenchMidpoint#1
230.00 230.00 H Wood 108.68 114BoiseBenchMidpoint#1
230.0C 230.00 S Tower 1.51 115BrownleeQuartzJet
230.00 41.30 1230.00 H WoodQuartzJet16Brownlee
99.76230.0C 230.00 S Tower 2BoiseBench#1 &#217Brownlee
10.40230.00 230.00 S Tower 218OxbowBrownlee
230.00 230.00 S Tower 3.49 119BoiseBenchMidpoint#2
230.00 230.00 H Wood 102.17 120BoiseBenchMidpoint#2
230.00 230.00 S Tower 20.11 221OxbowPalletteJet
230.00 24.43230.00 H Wood 222PalletteJetImnaha
9.05230.00 230.00 S Tower 223HellsCanyonPaletteJet
230.00 230.00 S Tower 102.55 224BrownleeBoiseBench
230.00 230.00 H Wood 106.29 125BoiseBenchMidpoint#3
230.0C 230.00 H Wood 29.62 126PaletteJetEnterprise
0.46230.00 230.00 S Tower 1Brady#227Borah
3.52230.00 230.00 H Wood 128BorahBrady#2
230.00 230.00 H Wood 3.87 129BorahBrady#1
30
161 ,0C 161.00 H Wood 40.93 1StateLine31Goshen
161.00 2.37161.00 S Tower 232DonGoshen
161.00 48.42161.00 H Wood 2Goshen33Don
161.00 5.67161.00 H Wood 1Goshen34Antelope
35
TOTAL 4,769.03 11.02 20336
Page 422.1FERCFORMNO.1 (ED.12-87)
Year/Period of Report
End of 2015/Q4
Date of Report
(Mo,Da,Yr)
04/15/2016
Name of Respondent
Idaho Power Company
This Report Is:
(1)[X]An Original
(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.
1 0.Base the plant costfigures called for in columns (j)to (I)on the book cost at end of year.
COST OF LINE (Include in Column (j)Land,
Land rights,and clearing right-of-way)
EXPENSES,EXCEPT DEPRECIATION AND TAXES
Size of
Conductor
and Material _Total
Expenses
RentsTotalCostOperation
Expenses
Maintenance
Expenses
Construction and
Other Costs
Land Line
No.(o)(P)(k)(I)(i)(j)(n)(m)
19,282,426 9,518,5782X954ACSR236,152
21272ACSR
31,748,05581,701 1,666,3541272ACSR
4624,917 22,467,321 23,092,2361590ACSR
515,210,561 15,210,5611590ACSR
61590ACSR
71590ACSR
83,528,033 3,528,0331590ACSR
911,132,9761,854,996 9,277,9801590ACSR
10948,166 10,029,0569,080,8901590ACSR
111272ACSR
126,191,922 6,191,9221272ACSR
139,806,478 10,191,765715.5 ACSR 385,287
14715.5 ACSR
153,500,5473,447,479795ACSR53,068
16795ACSR
179,256,921289,934 8,966,987VARIOUS
181,252,33414,810 1,237,5241272ACSR
1916,105,174 16,332,999715.5 ACSR 227,825
20VARIOUS
213,902,140 3,989,6081272ACSR87,468
221,674,451 1,845,532171,0811272ACSR
231,296,81744,687 1,252,1301272ACSR
246,441,971184,817 6,257,154954ACSR
715.5 ACSR 255,849,559 6,097,416247,857
261,904,234 1,988,2481272ACSR84,014
27541,820 544,8883,0681272ACSR
28715.5 ACSR
297,246 421,273 428,5211272ACSR
30
31424,195 440,35016,155250COPPER
3288,204 2,312,904 2,401,108715.5 ACSR
33397.5 ACSR
34784,659784,659397.5 ACSR
35
14,221,848 363,084,8498,044,636 3,092,363555,434,671 587,609,63932,174,968
Page 423.1FERCFORMNO.1 (ED.12-87)
Date of Report
(Mo,Da,Yr)
04/15/2016
Year/Period of Report
End of 2015/Q4
Name of Respondent
Idaho Power Company
This Report Is:
(1)[X|An Original
(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.
DESIGNATION VOLTAGE (KV)
(Indicate where
other than
60 cycle,3 phase)
LENGTH (Pole miles(In the Case,of
underground lines
report circuit miles)
On Structure (Jri
De^jjnafed
Line Type of
Supporting
Structure
Number
No.Of
CircuitsofAnotherOperatingDesignedFromTo
¦¦(a)(b)(c)(e)(d)(9)(h)
2138.0C 138.00 H Wood 11.221AmericanFallsPowerPlantAdelaide
2138.00 138.00 SP Wood 0.122AmericanFallsPowerPlantAdelaide
138.00 138.00 S Tower 1.15 23MinidokaLoopAdelaide
2138.00 138.00 S P Wood 9.57Caldwell4Nampa
138.00 54.45 1138.00 H Wood5UpperSalmonMountainHomeJet
138.00 1138.00 H Wood 30.816UpperSalmonCliff
138.00 1138.00 SP Wood 2.087EastgateRusset
138.00 2138.00 S Tower 1.038BradyFremont
2138.0C 138.00 H Wood 24.389BradyFremont
138.00 SP Wood 24.33 2138.0C10BradyFremont
84.74 2138.0C 138.00 H Wood11KingLowerMalad
66.49 2138.00 138.00 H Wood12EmmettJctPayette
1138.0C 138.00 H Wood 6.2013MountainHomeAFBTap
1138.00 138.00 H Wood 73.4014OntarioQuartz
2138.0C 138.00 S Tower 1.0115KingAmericanFallsPP
1138.0C 138.00 H Wood 142.4116KingAmericanFallsPP
138.00 138.00 S P Wood 3.71 117KingAmericanFallsPP
138.0C 138.00 H Wood 6.22 118DuffinClawson
0.33 1138.00 138.00 H Wood19AmericanFallsBradyTie
1138.0C 138.00 H Wood 5.6620UpperSalmonA-B King
138.0C 1138.00 H Wood 125.5921UpperSalmonBWells
1138.0C 138.00 H Wood 63.9922KingWoodRiver
9.80 1138.00 138.00 S P Wood23ToponisPocket
10.39 2138.00 138.00 S P Wood24BoiseBenchGrove
1138.00 138.00 H Wood 67.3225QuartzJohnDay
1138.00 138.00 H Wood 2.8026SinkerCreekTap
1138.0C 138.00 H Wood 2.51Cloverdale27Mora
22.28 1138.00 138.00 S P WoodCloverdale28Mora
2138.0C 138.00 S P Steel 0.9629MoraCloverdale
1138.0C 138.00 S P Steel 3.8030StoddardJetStoddardSub
1138.0C 138.00 H Wood 1.9531FossilGulchTap
138.0C 138.00 H Wood 53.08 232WoodRiverMidpoint
138.00 S P Wood 16.69 2138.0C33WoodRiverMidpoint
37.15 1138.0C 138.00 H Wood34OxbowMcCall
2.32 1138.0C 138.00 S P Wood35OxbowMcCall
TOTAL 4,769.03 11.02 20336
Page 422.2FERCFORMNO.1 (ED.12-87)
Name of Respondent
Idaho Power Company
This Report Is:
(1)|x|An Original
(2)||A Resubmission
TRANSMISSION LINE STATISTICS (Continued)
Date of Report
(Mo.Da,Yr)
04/15/2016
Year/Period of Report
End of 2015/Q4
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.
1 0.Base the plant cost figures called for in columns (j)to (I)on the book cost at end of year.
COST OF LINE (Include in Column (j)Land,EXPENSES,EXCEPT DEPRECIATION AND TAXES
Land rights,and clearing right-of-way)Size of
Conductor
and Material Operation
Expenses
Land Construction and
Other Costs
Total Cost Maintenance
Expenses
Rents Total
Expenses Line
No.(o)(i)(j)(k)(I)(P)(m)(n)
250 COPPER 407,669 126,507 381,162
250 COPPER 2
215.5 ACSR 21,327 249,232 270,559 3
795 AAC 696,535 3,311,830 4,008,365 4
795 ACSR 84,229 4,258,619 4,342,848 5
795 ACSR 43,568 2,811,365 62,767,797
795 AAC 270,823 832,384561,561 7
VARIOUS 4,702,195564,932 4,137,263 8
VARIOUS 9
VARIOUS 10
VARIOUS 76,823 3,206,705 3,283,528 11
VARIOUS 55,521 2,811,621 2,867,142 12
397.5 ACSR 1,955 8,885 136,930
VARIOUS 5,499,389 1434,428 5,464,961
715.5 ACSR 15216,919 9,677,074 9,893,993
715.5 ACSR 16
715.5 ACSR 17
4\0 4,191 443,775 447,966 18
954 ACSR 96,921 96,921 19
250 COPPER 2,741 756,666 20753,925
VARIOUS 3,250,08628,490 3,221,596 21
VARIOUS 173,683 4,156,121 4,329,804 22
397.5 ACSR 23
VARIOUS 225,602 1,652,772 1,878,374 24
397.5 ACSR 2,555,723 2592,173 2,463,550
VARIOUS 77,2192077,199 26
715.5 ACSR 3.123.38C 8,853,560 11,976,940 27
VARIOUS 28
795AAC 29
1272 ACSR 30
250 COPPER 450 187,848 188,298 31
397.5 ACSR 349,712 7,115,557 7,465,269 32
397.5 ACSR 33
397.5 ACSR 141,534 2,679,939 2,821,473 34
397.5 ACSR 35
587,609,63932,174,968 555,434,671 8,044,636 3,092,363 3,084,849 14,221,848 36
Page 423.2FERCFORMNO.1 (ED.12-87)
Name of Respondent
Idaho Power Company
Year/Period of Report
End of 2015/Q4
This Report Is:
(1)[x]An Original
(2)j |A Resubmission
TRANSMISSION LINE STATISTICS
Date of Report
(Mo.Da,Yr)
04/15/2016
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.
deSTGnation vOlTaGe (kv)
(indicate where
other than
60 cycle,3 phase)
iNGTH (Pole miles)
(In the fcasenfundergroundhnes
report circuit miles)
Un Structure On
of Line ol
Designated
Line Type of
Supporting
Structure
NumberNo.
Of
ructures
nother CircuitsFromToOperatingDesigned
ine(a)(b)(c)(e)(d)(9)(h)
138.OC 138.00 S P Wood 7.50 21LowellJetNampa
138.00 138.00 SP Wood 19.40 12HuntMilner
138.0C 138.00 H Wood 13.50 13StrikeBruneauBridge
18.46138.00 138.00 SP Wood 2KramerSub4AmericanFalls
138.0C 138.00 SP Wood 11.72 15PingreeHaven
138.00 138.00 SP Wood 25.22 26MidpointTwinFalls
138.00 138.00 S P Wood 1.69 17TwinFallsRussett
46.00 138.00 S P Wood 6.17 28BlackfootAiken
69.00 138.00 H Wood 57.10 19PetersonTendoy
138.0C 138.00 S P Wood 6.36 110EastgateTapEastgate
138.00 138.00 SP Steel 1.84 211KimberlyTapKimberly
138.00 138.00 H Wood 13.14 212BoiseBenchMora
138.00 138.00 S P Wood 0.51 113Bowmont-Caldwell Simplot Sub
138.0C 138.00 S P Wood 6.65 114GaryLaneEagle
138.0C 138.00 SP Steel 9.25 2.98 115LocustGroveBlackcatSub
0.14138.0C 138.00 S P Wood 4.02 116BoiseBenchButler
138.0C 138.00 S P Wood 6.74 117EagleStar
138.0C 138.00 S P Steel 3.60 118KarcherSubZilogTap
138.00 138.00 S P Steel 0.43 4.02 119Cloverdale-712 712 -Wye
138.0C 138.00 SP Steel 1.89 120VictoryJetVictory
138.00 138.00 SP Steel 2.94 121ButlerWye
138.00 138.00 H Wood 33.97 122HorseflatStarkey
138.0C 138.00 S P Steel 2.23 223StarkeyMccall
138.00 138.00 H Wood 3.80 124StarkeyMccall
138.00 138.00 S P Steel 1.50 125StarkeyMccall
138.00 138.00 SP Wood 17.61 126StarkeyMccall
138.0C 138.00 SP Steel 2.78 127ChestnutHappyValley
138.0028GarnetWard
138.0C 138.00 S P Wood 8.89 129McCallLakeFork
138.00 138.00 S Steel 2.9030McCallLakeFork
138.00 138.00 S P Steel 1.30 131CaldwellWillis
138.00 138.00 S P Steel 1.59 132CaldwellWillis
138.00 138.00 S P Wood 0.87 133CaldwellWillis
138.00 138.00 S P Steel 0.80 234ValivueTap
138.00 138.00 SP Steel 8.72 1HappyValley35Bowmont
TOTAL 4,769.03 11.02 20336
Page 422.3FERCFORMNO.1 (ED.12-87)
Year/Period of ReportNameofRespondent
Idaho Power Company
This Report Is:
(1)[x]An Original
(2)||A Resubmission
Transmission line statistics (Continued)
Date of Report
(Mo,Da,Yr)
04/15/2016
2015/Q4Endof
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.
COSY OF LINE (Include in Column (j)Land,EXPENSES,EXCEPT DEPRECIATION AND TAXES
Land rights,and clearing right-of-way)Size of
Conductor
and Material Land Construction and
Other Costs
Total Cost Operation
Expenses
Maintenance
Expenses
Rents Total
Expenses
Line
No.(o)(P)(i)(j)(k)(I)(n)(m)
1715.5 ACSR 211,131 1,454,879 1,666,010
2715.5 ACSR 3,324 1,426,231 1,429,555
397.5 ACSR 14,927 616,667 631,594 3
13,734 1,077,292 1,091,026 4715.5 ACSR
397.5 ACSR 18,223 1,281,344 1,299,567 5
66,256 3,110,194 3,176,450 6VARIOUS
16,790715.5 ACSR 213,033 229,823 7
8715.5 ACSR 13,616 529,756 543,372
395,696 9397.5 ACSR 3,540,775 3,936,471
10343,955 2,138,853 2,482,808715.5 ACSR
11795ACSR
12715.5 ACSR 14,697 811,164 825,861
13795AAC50,319 50,319
14795AAC489,037 2,165,954 2,654,991
151272ACSR935,810 3,503,157 4,438,967
161272ACSR34,687 838,605 873,292
17715.5 ACSR 179,817 2,932,783 3,112,600
434,341 477,376 18795AAC43,035
2,717,487 191272ACSR140,412 2,577,075
201272ACSR
134,471 1,539,907 21795ACSR1,405,436
22715.5 ACSR 2,473,833 18,884,762 21,358,595
23715.5 ACSR
24715.5 ACSR
25715.5 ACSR
26715.5 ACSR
78,579 2,219,508 2,298,087 271272ACSR
40,580 2840,580
331,539 5,014,418 29715.5 ACSR 4,682,879
30
311272ACSR272,231 2,141,218 2,413,449
32795ACSR
33795ACSR
351,497 34795ACSR351,497
6,737,014 351272ACSR691,728 6,045,286
14,221,848 363,092,363 3,084,84932,174,968 555,434,671 587,609,639 8,044,636
Page 423.3FERCFORMNO.1 (ED.12-87)
Name of Respondent
Idaho Power Company
This Report Is:
(1)[X]An Original
(2)||A Resubmission
Date of Report
(Mo.Da,Yr)
04/15/2016
Year/Period of Report
End of 2015/Q4
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.
DESIGNATION VOLTAGE (KV)
(Indicate where
other than
60 cycle.3 phase)
Operating Designed
underground lin
report circuit miles)
On Structure On
De'si^nated
LELineTypeof
Supporting
Structure
NumberNo.
Of
j structures
of Another CircuitsFromTo
me(a)(b)(c)(e)(d)(0)(h)
138.00 138.00 H Wood 0.12 11AntelopeScoville
Wheelon 138.00 138.00 H Wood 1.052AmericanFalls 1
138.0C 138.00 S Tower 1.323Kinport 2Don#1
138.0C 138.00 SP Steel4Donn 2.72 1HOKU
138.0C5HOKU 138.00 SP Steel 0.22 2Alamed
138.0C6HOKU 138.00 SP Steel 0.23 2Alamed
138.0C 138.00 S P Steel 2.85 17HOKUAlamed
138.0C 138.00 S P Steel 5.308RocklandJet 1RocklandWindFarm
138.00 138.00 SP Wood 0.119King 1Justice
138.0C 138.00 S P Wood 6.1710NorthViewTap 1
138.00 138.00 H Wood11TwinFallsPPTap 0.99 1
138.0C 138.00 S P Steel 0.38 112AmericanFallsPPAmercianFallsTransST
138.0013LowerSalmon 138.00 H Wood 0.11 1KingTie
14 C J Strike 138.00 138.00 S Tower 4.30 2StrikeJet
138.00 138.00 H Wood 23.42 115StrikeJetMountainHomeJet
138.00 H Wood 0.0516StrikeJet 1Bowmont
138.00 138.00 S Tower 0.3617StrikeJet 1Bowmont
138.00 138.00 H Wood 68.2018StrikeJet 1Bowmont
138.00 138.00 H Wood 4.48 219LuckyPeakLuckyPeakJet
138.0C 138.00 H Wood 10.47 120BlissKing
138.0C 138.00 S P Wood 1.30 121MilnerDeadendMilnerPP
138.00 138.00 H Wood 1.00 122SwanFallsTap
23
24
25
115.00 115.00 H Wood 3.35 126HinesBPA(Harney)
27
28
69.0C 69.00 H Wood 167.03 12969KvLines
69.00 69.00 S P Wood 928.75 13069KvLines
31
32
46.00 46.00 S P Wood 408.703346KvLines 1
34
4,769.03 11.02 20335Totalalllines
TOTAL 4,769.03 1102 20336
Page 422.4FERCFORMNO.1 (ED.12-87)
This Report Is:
(1)[X)An Original
(2)||A Resubmission
TRANSMISSION LINE STATISTICS (Continued)
Name of Respondent
Idaho Power Company
Date of Report
(Mo,Da,Yr)
04/15/2016
Year/Period of Report
End of 2015/Q4
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.
COST OF LINE (Include in Column (j)Land,EXPENSES,EXCEPT DEPRECIATION AND TAXES
Land rights,and clearing right-of-way)Size of
Conductor
and Material Total CostLandConstructionand
Other Costs
Operation
Expenses
Maintenance
Expenses
Rents Total
Expenses
Line
No.(o)(i)G)(k)(I)(P)(m)(n)
397.5 ACSR 11,121 11,121 1
250 COPPER 96,249 96,249 2
715.5 ACSR 1,174 225,641 226,815 3
1272 ACSR 19C 4,594 4,784 4
1272 ACSR 5
795 ACSR 6
795 ACSR 7
795 ACSR -16,973 -16,973 8
1590 ACSR 60,659 60,659 9
715.5 ACSR 4,177,555 4,177,555 10
250 COPPER 58 63,264 63,322 11
715.5 ACSR 76,560 76,560 12
397.5 ACSR 4,406 4,406 13
715.5 ACSR 1,074 622,115 623,189 14
397.5 ACSR 2,569,728 2,576,0606,332 15
715.5 ACSR 2,516,18086,651 2,602,831 16
715.5 ACSR 17
18
715.5 ACSR 7 279,481 279,488 19
715.5 ACSR 5,620 1,366,840 1,372,460 20
715.5 ACSR 2,814 183,606 186,420 21
397.5 ACSR 17,818 261,512 279,330 22
23
24
25
397.5 ACSR 1,978 63,404 65,382 26
27
28
VARIOUS 1,680,630 66,163,470 67,844,100 29
VARIOUS 30
31
32
194,536"18,389,461VARIOUS18,194,925 33
14,221,848 348,044,636 3,084,8493,092,363
32,174,968 555,434,671 587,609,639 14,221,848 358,044,636 3,084,8493,092,363
32,174,968 555,434,671 587,609,639 3,092,363 3,084,849 14,221,848 368,044,636
Page 423.4FERCFORMNO.1 (ED.12-87)
Date of Report Year/Period of Report
(Mo,Da,Yr)
04/15/2016
Name of Respondent This Report is:
(1)X An Original
(2)_A Resubmission 2015/Q4IdahoPowerCompany
FOOTNOTE DATA
Schedule Page:422 Line No.:1 Column:b
This line is jointly owned with PacifiCorp and Idaho Power owns 73.2%of this 85.4 mile
line .
Schedule Page:422 Column:bLineNo.:2
This line is jointly owned with Portland General Electric and Idaho Power owns 10.0%of
this 17.8 mile line.
\Schedule Page:422_Line No.:3 Column:b
This line is jointly owned with PacifiCorp and Idaho Power owns 22.0%of this 241.3 mile
line .
Schedule Page:422 Line No.:4 Column:b
This line is jointly owned with PacifiCorp and Idaho Power owns 37.0%of this 129.3 mile
line .
Schedule Page:422 Line No.:5 CoiumnjJb
This line is jointly owned with PacifiCorp and Idaho Power owns 22.0%of this 241.3 mile
line .
Schedule Page:422 Line No.:6 Column:b
This l/tiie is Jointly owned with PacifiCorp arid Idaho Power owns 37.0%of this 129.3 mile
line .
Schedule Page:422 Line No.:8 Column:b
This line is jointly owned with PacifiCorp and Idaho Power owns 29.2%of this 226.6 mile
line .
Schedule Page:422 Line No.:10 Column:b
This line is jointly owned with PacifiCorp and Idaho Power owns 73.2%of this 27.1 mile
line .
Schedule Page:422 Line No.:11 Column:b
This line is jointly owned with PacifiCorp and Idaho Power owns 29.2%of this
approximately 193 mile line.
Schedule Page:422 Line No.:12 Column:b
This line is jointly owned with PacifiCorp and Idaho Power owns 29.2%of this 41.2 mile
line._
Schedule Page:422 Line No.:13 Column:b
This line is jointly owned with PacifiCorp and Idaho Power owns 29.2%of this
approximately 193 mile line.
Schedule Page:422 Line No.:14 Column:b
This line is jointly owned with PacifiCorp and Idaho Power owns 29.2%of this 47.3 mile
line.
Schedule Page:422 Line No.:15 Column:b
This line is jointly owned with PacifiCorp and Idaho Power owns 18.3%of this 40.9 mile
line .
Schedule Page:422 Line No.:16 Column:b
This line is jointly owned with PacifiCorp and Idaho Power owns 64.4%of this 79.5 mile
line .
Schedule Page:422 Line No.:17 Column:b
This line is jointly owned with PacifiCorp and Idaho Power owns 64.4%of this 77.9 mile
line .
Schedule Page:422 Line No.:18 Column:b
This line is jointly owned with PacifiCorp and Idaho Power owns 64.4%of this 0.9 mile
line .
j.Schedule Page:422 Line No.:34 Column:b
This line is jointly owned with Portland General Electric and Idaho Power owns 10.0%of
this 16.7 mile line.
Schedule Page:422.1 Line No.:12 Column:b
This line is jointly owned with PacifiCorp and Idaho Power owns 40.8%of this 77.6 mile
line .
Schedule Page:422.1 Line No.:31 Column:b
FERC FORM NO.1 (ED.12-87)Page 450.1
Date of Report Year/Period of Report
(Mo,Da,Yr)
04/15/2016
This Report is:
(1)X An Original
(2)_A Resubmission
Name of Respondent
2015/Q4IdahoPowerCompany
FOOTNOTE DATA
This line is jointly owned with PacifiCorp.Idaho Power owns 37.8%of Goshen-Jefferson
28.9 mile segment,37.8%of the Jefferson-Big Grassy 20.8 mile segment and 100%of the
Big Grassy-State Line 40.9 mile segment.
Schedule Page:422.1 Line No.:34 Column:b
This line is jointly owned with PacifiCorp and Idaho Power owns 21.9%of this 25.8 mile
line .
Schedule Page:422.4 Line No.:1 Column:b
This line is jointly owned with PacifiCorp and Idaho Power owns 11.5%of this 1 mile line.
Schedule Page:422.4 Line No.:2 Column:b
This line is jointly owned with PacifiCorp and Idaho Power owns 7.2%of this 29.1 mile
line .
FERC FORM NO.1 (ED.12-87)Page 450.2
Name of Respondent
Idaho Power Company
This Report Is:
(1)[Xj An Original
(2)||A Resubmission
TRANSMISSION LINES ADDED DURING YEAR
Date of Report
(Mo,Da,Yr)
04/15/2016
Year/Period of Report
End of 2015/Q4
1 .Report below the information called for concerning Transmission lines added or altered during the year.It is not necessary to report
minor revisions of lines.
2.Provide separate subheadings for overhead and under-ground construction and show each transmission line separately.If actual
costs of competed construction are not readily available for reporting columns (I)to (o),it is permissible to report in these columns the
LINE DESIGNATION Line "SUPPORTING STRUCTURE CIRCUITS PER STRUCTURELineLengthAverage
Number per
Miles
No.From To Type Present Ultimatein
Miles
(a)(b)(c)(d)(e)(f)(g)
9.80 S P Wood1ToponisPocket 17.76 1 1
6.17 S P Wood2NorthViewTap 16.70 11
0.12 H WoodScoville3Antelope 10.00 1 1
1.05 H WoodWheelon4AmericanFalls 8.66 1 1
5
5.67 H WoodGoshen6Antelope 17.13 1
7
31.66 H Wood8WallaWallaHurricane 4.84 1 1
9
7.49 Latice10GoshenKinport 4.56 1 1
11
53.09 LaticeHemingway12SummerLake 4.50 1 1
47.83 Latice13HemingwayMidpoint 4.50 1 1
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
162.8844TOTAL 78.65 9 9
Page 424FERCFORMNO.1 (REV.12-03)
This Report Is:
(1)[XjAn Original
(2)|—|A Resubmission
TRANSMISSION LINES ADDED DURING YEAR (Continued)
Date of Report
(Mo,Da,Yr)
04/15/2016
Year/Period of Report
End of 2015/Q4
Name of Respondent
Idaho Power Company
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.
CONDUCTORS LINE COST LineVoltage
Size Poles,Towers
and Fixtures
Conductors
and Devices
Asset
Retire.Costs
No.Configuration
and Spacing
TotalLandand
Land Rights
Specification KV
(Operating)
(o)(P)(h)ill (!)(k)(!)(m)!n)
1138397ACSRTVS
24,177,555715ACSR138138,062 2,021,538 2,017,955TVS-HL
11,121 313818210,939397ACSRHorizonal
413822,687 96,249250CopperHorizonal73,562
5
784,659 6161667,466 117,193397ACSRHorizonal
7
82301,807,264 6,191,9221272ACSRHorizonal4,384,658
9
514,724 10Double1272ACSR345232,927 281,797Delta
11
17,991,882 127,002,272Double1272ACSRHorizonal50010,989,610
136,366,612 16,358,594Triple1273ACSRHorizonal5009,991,982
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
46,126,706138,062 28,361,925 17,626,719 44
Page 425FERCFORMNO.1 (REV.12-03)
This Page Intentionally Left Blank
Date of Report Year/Period of Report
(Mo,Da,Yr)
04/15/2016
Name of Respondent This Report is:
(1)X An Original
(2)_A Resubmission 2015/Q4IdahoPowerCompany
FOOTNOTE DATA
Schedule Page:424 Line No.:3 Column:b
This Title is Jointly owned with PacifiCorp and Idaho Power owns 11.5%of this 1 mile line.
Schedule Page:424 Line No.:4 Column:b
This line is jointly owned with PacifiCorp and Idaho Power owns 7.2%of this 29.1 mile
line .
Schedule Page:424 Line No.:6 Column:b
This line is jointly owned with PacifiCorp and Idaho Power owns 21.9%of this 25.8 mile
line.
Schedule Page;424 Line No.:8 Column:b
This line is jointly owned with PacifiCorp and Idaho Power owns 40.8%of this 77.6 mile
line .
Schedule Page:424 Line No.:10 Column:b
This line is jointly owned with PacifiCorp and Idaho Power owns 18.3%of this 40.9 mile
line._
Schedule Page:424 Line No.:12 Column:b _
This line is jointly owned with PacifiCorp and Idaho Power owns 22.0%of this 241.3 mile
line .
Schedule Page:424 Line No.:13 Column:b
This line is jointly owned with PacifiCorp and Idaho Power owns 37.0%of this 129.3 mile
line .
FERC FORM NO.1 (ED.12-87)Page 450.1
This Report Is:
(1)[x]An Original
(2)f~|A Resubmission
Name of Respondent
Idaho Power Company
Date of Report
(Mo,Da,Yr)
04/15/2016
Year/Period of Report
2015/Q4Endof
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).
VOLTAGE (In MVa)Line
Name and Location of Substation Character of SubstationNo.Primary Secondary Tertiary
(e)(b)(c)(d)(a)
1 Adelaide 345.00 138.00 13.80transmission
46.00 13.002Aikendistribution
13.00distribution46.003Alameda
138.00 13.094Alamedadistribution
138.00 13.805AmericanFallsPP-attended transmission
138.00 46.00 12.476AmericanFallstransmission
161.007Antelope230.00transmission
46.00 13.008Artesiandistribution
46.00 13.009BannockCreekdistribution
230.00 18.00BennettMountainPowerPlant-attended transmission10
18.00 4.16BennettMountainPowerPlant-attended distribution11
13.0012BethelCourtdistribution138.00
1 3 Big Grassy 161.00transmission
14 Black Cat 138.00 13.09distribution
46.00 13.0015Blackfootdistribution
161 .00 46.00 12.4716Blackfoottransmission
161.00 138.00 12.9817Blackfootdistribution
13.8018Bliss-attended 138.00transmission
35.0019BlueGulchdistribution138.00
230.00 138.00 13.2020BoiseBench-attended transmission
distribution 138.00 35.0021BoiseBench-attended
138.00 69.00 12.9822BoiseBench-attended transmission
230.00 138.00 13.8023BoiseBench-attended transmission
138.00 13.00distribution24Boise
230.00 13.8025Borah345.00transmission
distribution 69.00 46.00 6.9026Bowmont
138.00 35.0027Bowmontdistribution
138.00 69.00 12.9828Bowmonttransmission
138.00 69.00 12.4729Bowmonttransmission
138.00230.00 13.8030Bowmonttransmission
230.00 138.00 13.8031Bradytransmission
138.00 46.00 12.47transmission32Brady
46.00 13.00distribution33Brady
13.80230.0034Brownlee-attended transmission
distribution 138.00 35.0035BruneauBridge
138.00 36.2036BruneauBridgedistribution
69.00 35.0037Buckhorndistribution
46.00 7.20distribution38Bucyrus
46.00 13.00distribution39Buhl
69.00 13.0040BurleyRuraldistribution
Page 426FERCFORMNO.1 (ED.12-96)
Name of Respondent
Idaho Power Company
This Report Is:
(1)[X]An Original
(2)|A Resubmission
Date of Report
(Mo.Da,Yr)
04/15/2016
Year/Period of Report
End of 2015/Q4
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
Transformers
In Service
Number of
Spare
Transformers
CONVERSION APPARATUS AND SPECIAL EQUIPMENTCapacityofSubstation
(In Service)(In MVa)
Line
Total Capacity
(In MVa)
No.Type of Equipment Number of Units
m.M (h)(i)ill (k)
13002
2202
3151
4181
5721
6251
72241
8101
9101
101351
1151
12151
13
14241
15302
165031
17801
18693
19151
202542
21422
22753
232402
24673
2545031
2683
27181
28251
29251
303602
313123
321
334
3472151
35181
36241
37201
3861
391011
40121
Page 427FERCFORMNO.1 (ED.12-96)
Name of Respondent
Idaho Power Company
This Report ts:
(1)[x|An Original
(2)J~|A Resubmission
SUBSTATIONS
Date of Report
(Mo.Da,Yr)
04/15/2016
Year/Period of Report
End of 2015/Q4
1 .Report below the information called for concerning substations of the respondent as of the end ofthe 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).
VOLTAGE (In MVa)Line
Name and Location of Substation Character of SubstationNo.Secondary TertiaryPrimary
(a)(b)(c)(d)(e)
Butler distribution 138.00 13.091
2 Caldwell 13.00distribution138.00
3 Caldwell transmission 230.00 138.00
4 Caldwell distribution 138.00 13.09
5 Caldwell 138.00 69.00 12.47transmission
6 Caldwell 138.00 12.47transmission230.00
7 Caldwell distribution 13.00 4.16
8 Canyon Creek distribution 138.00 35.00
9 Canyon Creek 138.00 69.00 12.98transmission
10 Cascade Power Plant -attended 69.00 4.60transmission
Cascade 13.1011distribution69.00
12 Cascade distribution 25.00
13 Chestnut distribution 138.00 13.00
14 Clear Lake -attended 46.00 2.40transmission
15 Cliff 138.00 46.00 12.50transmission
16 Cliff 138.00 46.00 12.95transmission
17 Cloverdale 13.00distribution138.00
4.6018Daledistribution46.00
19 Dale distribution 46.00 13.00
20 Dale distribution 69.00 13.00
21 distribution 138.00 36.20Dale
138.00 46.00 12.4722Daletransmission
230.00 18.0023Danskin-attended transmission
138.00 13.8024Danskin-attended transmission 230.00
25 Danskin-attended distribution 18.00 4.16
26 Danskin-attended 138.00 12.00transmission
35.00 13.8027Danskin-attended distribution
138.00 7.6028Dondistribution
13.2029Dondistribution138.00
30 Don distribution 138.00 13.00
distribution 14.0031Don
138.00 13.0932DRAMdistribution
13.8033DRAMtransmission230.00 138.00
34 DRAM distribution 138.00 12.47
Duffin distribution 138.00 35.0035
distribution 138.00 13.0936Eagle
138.0037Eastgatedistribution
138.00 13.0038Eastgatedistribution
138.00 36.2039Eckertdistribution
36.2040Edendistribution138.00
Page 426.1FERCFORMNO.1 (ED.12-96)
This Report is;
(1)m An Original
(2)[j A Resubmission
Year/Period of Report
End of 2015/Q4
Name of Respondent
Idaho Power Company
Date of Report
{Mo,Da,Yr)
04/15/2016
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
Transformers
In Service
Number of
Spare
Transformers
CONVERSION APPARATUS AND SPECIAL EQUIPMENTCapacityofSubstation Line
Total Capacity
(In MVa)
No.(In Service)(In MVa)Type of Equipment Number of Units
(g)m (k)(h)(i)
1482
2151
31201
4241
5753
61201
71
8151
9"15 1
10121
11152
1241
13482
1441
151221
1641
17482
181
196
201
21271
22251
231401
241801
2561
26962
2751
281
2910863
302611
31806
321187
331602
34171
35362
36382
37241
38181
39181
40241
Page 427.1FERCFORMNO.1 (ED.12-96)
This Report Is:
(1)[x]An Original
(2)||A Resubmission
Name of Respondent
Idaho Power Company
?ate of Report
(Mo.Da,Yr)
04/15/2016
Year/Period of Report
End of 2015/Q4
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).
VOLTAGE (In MVa)Line
Name and Location of Substation Character of SubstationNo.Primary Secondary Tertiary
(a)(b)(c)(d)(e)
1 Eden transmission 138.00 46.00 12.98
2 Elkhorn distribution 138.00 12.47
Elkhorn3 distribution 138.00 13.00
4 Elmore distribution 138.00 35.00
Elmore5 transmission 138.00 69.00 12.50
6 Elmore transmission 138.00 69.00 12.98
7 Emmett distribution 138.00
8 Emmett transmission 138.00 69.00 12.47
9 Falls distribution 46.00 13.00
10 Falls distribution 46.00
11 Filer distribution 46.00 13.00
12 Flat Top distribution 46.00 13.00
13 Flying H distribution 69.00 2.40
14 Fort Hall distribution 46.00 13.00
15 Fossil Gulch distribution 138.00 35.00
16 Fremont transmission 138.00 46.00 12.50
17 Gary distribution 138.00 13.09
18 Gary distribution 138.00 13.00
19 Gem distribution 69.00 13.00
20 Gem distribution 69.00
21 Gooding Rural distribution 46.00 13.00
22 Golden Valley distribution 69.00 13.00
23 Goshen transmission 345.00 161.00
24 Gowen Substation distribution 138.00 35.00
Grindstone25 distribution 35.00
26 Grove distribution 138.00 13.09
27 Grove distribution 138.00 13.00
28 Hagerman distribution 46.00 13.00
29 Hagerman distribution 69.00 13.00
30 Hailey distribution 138.00 13.00
31 Happy Valley distribution 138.00 13.09
32 Haven distribution 138.00 35.00
33 Haven transmission 138.00 46.00
34 Hemingway transmission 500.00 230.00 34.50
35 Hewlett Packard distribution 138.00 13.00
36 Hidden Springs distribution 138.00 13.00
37 Highland distribution 138.00 13.00
38 Hill distribution 138.00 13.00
39 Hillsdale distribution 138.00
40 Hoku distribution 138.00 13.80
Page 426.2FERCFORMNO.1 (ED.12-96)
This Report is:
(1)fjpAn Original
(2)[|A Resubmission
SUBSTATIONS {Continued)
Name of Respondent
Idaho Power Company
Date of Report
(Mo,Da,Yr)
04/15/2016
Year/Period of Report
2015/Q4Endof
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
Transformers
In Service
Number of
Spare
Transformers
CONVERSION APPARATUS AND SPECIAL EQUIPMENTCapacityofSubstation
(In Service)(In MVa)
Line
Total Capacity
(In MVa)
No.Type of Equipment Number of Units
(f)M (h)(i)Xil (k)
1151
281
381
4171
5151
6151
7241
8251
981
10101
11101
12132
13152
141011
15151
165031
17201
18171
1981
20101
21152
221011
238962
24241
2552
26482
27241
28101
2951
30201
31181
32121
33251
3460031
35201
3681
37181
38392
39241
402
Page 427.2FERCFORMNO.1 (ED.12-96)
This Report Is:
X]An Original
Resubmission
SUBSTATIONS
Year/Period of ReportNameofRespondent
Idaho Power Company
?ate of Report
(Mo.Da,Yr)
04/15/2016
(1)2015/Q4Endof
(2)
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).
VOLTAGE (In MVa)Line
Character of SubstationNameandLocationofSubstationNo.Secondary TertiaryPrimary
(e)(c)(d)(a)(b)
69.00 13.001Homedaledistribution
230.00 138.00 13.802HorseFlattransmission
35.003HorseshoeBenddistribution
69.00 36.204HorseshoeBenddistribution
69.00 25.005HorseshoeBenddistribution
13.0069.006Hustondistribution
46.00 13.007Hulendistribution
230.00 138.00 13.808Hunttransmission
138.00 36.209Hydradistribution
69.00 13.00distribution10Island
161.00 161.0011Jeffersontransmission
13.00138.0012Jeromedistribution
138.00 13.0913Jeromedistribution
138.00 35.0014JulionClawsondistribution
138.00 13.0015Joplindistribution
138.00 35.00distribution16Joplin
230.00 138.00 13.8017Justicetransmission
138.00 13.00distribution18Karcher
13.0069.0019Kenyondistribution
138.00 13.0020Ketchurndistribution
138.00 13.0021Kimberlydistribution
161.00 46.00 13.2022Kinporttransmission
230.00 138.00 12.4723Kinporttransmission
230.00 138.00 13.8024Kinporttransmission
345.00 230.00 13.8025Kinporttransmission
138.00 35.0026Kramerdistribution
138.00 36.2027Kramerdistribution
138.00 13.00distribution28Kuna
69.00 13.00distribution29Lake
138.00 36.2030LakeForkdistribution
138.00 69.00 12.50LakeForktransmission31
138.00 13.00distribution32Lamb
230.00 138.00 13.8033LangleyGulch-attended transmission
230.0034LangleyGulch-attended transmission
4.1635LangleyGulch-attended distribution
13.00 4.1636LangleyGulch-attended distribution
230.00 150.0037LangleyGulch-attended transmission
69.00 13.00distribution38Lansing
138.00 13.09distribution39Lincoln
138.00 13.00distribution40Linden
Page 426.3FERCFORMNO.1 (ED.12-96)
This Report Is:
XjAn Original
^A Resubmission
SUBSTATIONS (Continued)
Name of Respondent
Idaho Power Company
Date of Report
(Mo,Da,Yr)
04/15/2016
Year/Period of Report
End of 2015/Q4(1)
(2)
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
Transformers
In Service
Number of
Spare
Transformers
CONVERSION APPARATUS AND SPECIAL EQUIPMENTCapacityofSubstation Line
Total Capacity
(In MVa)
No.(In Service)(In MVa)Type of Equipment Number of Units
m (a)(h)ti)(k)
1222
21001
351
4121
551
6101
7101
83003
g482
10121
111121
12201
13201
14302
15151
16"18 1
TT1801
18121
19202
20422
212711
227
231801
241801
2560031
26121
27181
28151
29101
30181
31151
32181
331801
342462
35121
36121
371
38121
39101
40332
Page 427.3FERCFORMNO.1 (ED.12-96)
This Report Is:
(1)[X|An Original
(2)|]A Resubmission
Name of Respondent
Idaho Power Company
Date of Report
(Mo,Da,Yr)
04/15/2016
Year/Period of Report
2015/Q4Endof
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).
VOLTAGE (In MVa)Line
Name and Location of Substation Character of SubstationNo.Primary Secondary Tertiary
(a)(b)(c)(d)(e)
1 Locust distribution 138.00 36.20
2 Locust transmission 230.00 138.00 13.80
3 Lower Malad -attended transmission 138.00 7.20
4 Lower Salmon -attended transmission 138.00 13.80
5 Map Rock distribution 69.00 13.00
6 McCall distribution 13.00 13.09
7 McCall distribution 138.00 36.20
8 Meridian distribution 138.00 13.00
9 Micron distribution 138.00 13.09
10 Micron distribution 138.00 13.00
1 1 Midpoint transmission 138.00 13.80230.00
12 Midpoint 13.80transmission345.00 230.00
13 Midpoint transmission 500.00 345.00
14 Midrose distribution 138.00 13.09
15 Milner transmission 138.00 69.00 12.47
16 Milner distribution 69.00 46.00 6.90
17 Milner distribution 138.00 35.00
18 Milner PP -attended transmission 138.00 13.80
19 Moonstone distribution 138.00 35.00
20 Mora distribution 138.00 35.00
21 Mora distribution 138.00 36.20
22 Moreland distribution 35.00 13.00
23 Moreland distribution 46.00 13.00
24 Moreland distribution 46.00 35.00 12.47
25 Mountain Home distribution 69.00 13.00
26 Mountain Home Air Force Base distribution 69.00 13.00
27 Mountain Home Air Force Base distribution 138.00 13.00
28 Nampa transmission 230.00 138.00 13.80
29 Nampa distribution 138.00 13.00
30 New Meadows distribution 138.00 36.20
31 New Plymouth distribution 69.00 13.00
32 Notch Butte distribution 138.00 13.09
33 Orchard distribution 69.00 36.20
34 Orchard distribution 69.00 35.00 12.47
35 Parma distribution 69.00 13.00
36 Parma distribution 69.00 35.00
37 Paul distribution 138.00 35.00
38 Payette distribution 138.00 13.00
39 Pingree transmission 138.00 46.00 12.50
40 Pingree distribution 138.00 35.00
Page 426.4FERCFORMNO.1 (ED.12-96)
This Report Is:
X]An Original
Name of Respondent
Idaho Power Company
Date of Report
(Mo,Da,Yr)
04/15/2016
Year/Period of Report
End of 2015/Q4(1)
A Resubmission(2)
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
Transformers
In Service
Number of
Spare
Transformers
CONVERSION APPARATUS AND SPECIAL EQUIPMENTCapacityofSubstation
(In Service)(In MVa)
Line
Total Capacity
(In MVa)
No.Type of Equipment Number of Units
(f)M (h)ill(i)(k)
1723
23602
3161
4704
5101
6121
7181
8362
9242
10242
111201
1284021
137503
14241
157531
16831
17292
18361
19121
20151
21241
2261
"2381
24631
25151
261
27181
281801
29503
30121
31"10 1
32101
3361
34103
35101
36121
37362
38233
39503
40222
Page 427.4FERCFORMNO.1 (ED.12-96)
This Report Is:
(1 )[x]An Original
(2)|A Resubmission
SUBSTATIONS
Name of Respondent
Idaho Power Company
Date of Report
(Mo.Da,Yr)
04/15/2016
Year/Period of Report
2015/Q4Endof
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).
VOLTAGE (In MVa)Line
Name and Location of Substation Character of SubstationNo.Primary Secondary Tertiary
(a)(b)(c)(d)(e)
1 Pleasant Valley distribution 138.00 35.00
2 Pocatello distribution 46.00 13.00
3 Pocket distribution 138.00 36.20
4 Poleline distribution 138.00 13.09
5 Popufus 345.00transmission
6 Portneuf 138.00distribution 35.00
7 Portneuf distribution 46.00 35.00
8 Rockford distribution 46.00 13.00
9 Russett distribution 138.00 13.00
10 Sailor Creek distribution 138.00 2.40
11 Sailor Creek 138.00distribution 35.00
12 Salmon distribution 69.00 13.00
13 Salmon distribution 69.00 34.50 12.47
14 Salmon distribution 69.00 12.47
15 Salmon 13.00 2.40transmission
16 Shoshone distribution 46.00 13.00
17 Shoshone 46.00distribution 7.20
18 Shoshone Falls -attended transmission 46.00 2.30
19 Shoshone Falls -attended transmission 46.00 6.60
20 Silver distribution 138.00 35.00
21 Simplot distribution 138.00 13.00
22 Sinker Creek distribution 138.00 35.00
23 Siphon distribution 138.00 35.00
24 South Park distribution 46.00 13.00
25 Star distribution 138.00 13.09
26 Starkey 138.00 69.00 12.47transmission
27 State distribution 69.00 13.00
28 Stoddard distribution 138.00 13.00
29 Strike Power Plant -attended transmission 138.00 13.80
30 Sugar distribution 138.00 35.00
Swan Falls -attended31 138.00 6.90transmission
32 Taber distribution 46.00 13.00
33 Ten Mile distribution 138.00 13.09
34 Terry distribution 138.00 13.09
35 Terry distribution 138.00 13.00
36 Thousand Springs -attended 46.00transmission 7.20
37 Thousand Springs -attended transmission 7.00 2.40
38 Three Mile Knoll transmission 345.00
39 Toponis distribution 138.00 33.00
40 Twin Falls distribution 138.00 13.09
Page 426.5FERCFORMNO.1 (ED.12-96)
This Report !s:
(1)\X]An Original
(2)[~]A Resubmission
SUBSTATIONS (Continued)
Name of Respondent
Idaho Power Company
Date of Report
(Mo,Da,Yr)
04/15/2016
Year/Period of Report
End of 2015/Q4
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
Spare
Transformers
Number of
Transformers
In Service
CONVERSION APPARATUS AND SPECIAL EQUIPMENTCapacityofSubstation
(In Service)(In MVa)
Line
Total Capacity
(In MVa)
No.Type of Equipment Number of Units
(f)(k)M (h)(i)01
1422
2362
3241
4181
5
6181
71
8142
9181
10152
11151
123101
13103
142
1525
16101
1723
1831
19101
20121
21302
22121
23332
24101
25181
26181
27332
28151
29833
30202
31181
3251
33241
12 341
35302
3618
371
38
39181
40442
Page 427.5FERCFORMNO.1 (ED.12-96)
This Report Is:
XjAn Original
Name of Respondent
Idaho Power Company
Date of Report
(Mo.Da,Yr)
04/15/2016
Year/Period of Report
End of 2015/Q4(1)
^jA Resubmission(2)
SUBSTATIONS
1 .Report below the information called for concerning substations of the respondent as of the end ofthe 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).
VOLTAGE (In MVa)Line
Name and Location of Substation Character of SubstationNo,SecondaryPrimary Tertiary
(c)(d)(e)(a)(b)
1 Twin Falls transmission 138.00 46.00 12.98
2 Twin Falls PP -attended 138.00 7.20transmission
3 Twin Falls PP -attended 138.00 13.20transmission
4 Upper Malad -attended transmission 45.00 7.20
5 Upper Salmon-attended 138.00 7.20transmission
6 Ustick distribution 138.00 13.00
7 Vallivue 138.00 13.09distribution
8 Victory distribution 138.00 13.00
9 Victory distribution 138.00 13.09
10 Ware distribution 69.00 13.00
11 Weiser distribution 69.00 13.00
12 Weiser 138.00 69.00 12.47transmission
13 Wilder distribution 69.00 13.00
14 Willis distribution 138.00 13.09
15 Wye distribution 138.00 13.00
16 Wye distribution 138.00 13.09
17 Zilog distribution 138.00 13.09
18
19
20 The above are all State of Idaho
21
22 Montana:
23 Peterson 230.00 69.00 13.20transmission
24
Nevada:25
26 Valmy -attended transmission 345.00 125.00 24.90
27 Valmy -attended transmission 345.00 125.00 24.90
28 Valmy -attended 120.00 24.90 7.20transmission
29 Valmy -attended 345.00transmission
30 Valmy -attended transmission 345.00
31 Valmy -attended transmission 345.00
32 Valmy -attended 345.00transmission
345.0033Valmy-attended transmission
34 Wells transmission 138.00 69.00 13.00
35
36 Oregon:
37 Boardman -attended 500.00 24.00transmission
38 Boardman -attended 230.00 7.20transmission
39 Boardman -attended 24.00 7.20transmission
40 Bums 500.00transmission
Page 426.6FERCFORMNO.1 (ED.12-96)
This Report ts:
[X]An Original
Date of Report
(Mo,Da,Yr)
04/15/2016
Year/Period of Report
End of 2015/Q4
Name of Respondent
Idaho Power Company (1)
(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
Transformers
In Service
Number of
Spare
Transformers
CONVERSION APPARATUS AND SPECIAL EQUIPMENT LineCapacityofSubstation
(In Service)(In MVa)Total Capacity
(In MVa)
No.Type of Equipment Number of Units
(i)(k)M (h)(i)1G.
1332
291
3721
481
5364
6442
18 1
8241
9181
101211
11202
12251
13101
14181
15362
16201
17241
18
19
20
21
22
232431
24
25
261
271
281
29LineReactor148
30135LineReactor
3135LineReactor1
32LineReactor135
33LineReactor135
341203
35
36
376853
38155
39155
40
Page 427.6FERCFORMNO.1 (ED.12-96)
This Report Is:
(1)[x]An Original
(2)||A Resubmission
Name of Respondent
Idaho Power Company
?ate of Report
(Mo.Da,Yr)
04/15/2016
Year/Period of Report
End of 2015/Q4
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).
VOLTAGE (In MVa)Line
Name and Location of Substation Character of SubstationNo.SecondaryPrimary Tertiary
(a)(b)(c)(d)(e)
1 Cairo distribution 69.00 13.00
2 Hells Canyon -attended transmission 230.00 13.80
3 Hells Canyon -attended 69.00distribution 0.50
4 Hines transmission 138.00 115.00 12.47
5 Hurricane transmission 230.00
6 Malheur Butte distribution 69.00 34.50
7 Nyssa distribution 69.00 13.00
8 Ontario distribution 138.00 13.00
9 Ontario transmission 138.00 69.00 12.47
10 Ontario transmission 230.00 138.00 13.80
Ontario11 transmission 138.00 69.00 12.98
12 Ontario transmission 138.00 69.00 13.09
13 Ore-Ida distribution 69.00 13.00
1 4 Oxbow -attended transmission 138.00 69.00 13.00
15 Oxbow -attended transmission 230.00 13.80
16 Oxbow -attended transmission 230.00 138.00 13.80
17 Quartz transmission 138.00 69.00 12.50
18 Quartz transmission 230.00 138.00 12.98
19 Quartz transmission 138.00 69.00 12.98
20 Summer Lake transmission 500.00
21 Vale distribution 69.00 13.00
22
23 Washington:
24 Walla Walla transmission 230.00
25
26 Wyoming:
27 Jim Bridger-attended 345.00transmission 22.00 34.50
28
29
30
31
32
33 Transformers-distribution substations under 10,000
34 KVA 83 unattended.
35
36
37
38
39
40
Page 426.7FERCFORMNO.1 (ED.12-96)
Name of Respondent
Idaho Power Company
This Report Is:
(1)fx]An Original
(2)p~]A Resubmission
SUBSTATIONS (Continued)
Year/Period of Report
End of 2015/Q4
Date of Report
(Mo,Da,Yr)
04/15/2016
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
Spare
Transformers
Number of
Transformers
In Service
CONVERSION APPARATUS AND SPECIAL EQUIPMENT LineCapacityofSubstation
(In Service)(In MVa)Total Capacity
(In MVa)
No.Type of Equipment Number of Units
(Jl (k)M (i)(g)(f)
1112
215003
311
4140
5
6183
7202
8238
91125
102240
11502
121
13151
143110
152244
161100
17151
1811003
19151
20
21110
22
23
24
25
26
2742244
28
29
30
31
32
33
34329
35
36
37
W
39
40
Page 427.7FERCFORMNO.1 (ED.12-96)
Date of Report Year/Period of ReportThisReportis:
(1)X An Original
(2)_A Resubmission
Name of Respondent
(Mo,Da,Yr)
2015/Q404/15/2016IdahoPowerCompany
FOOTNOTE DATA
Column:aLineNo.:1
PacifiCorp has an ownership interest in certain high-voltage transmission related and
interconnection equipment located at Idaho Power's Adelaide station.Ownership interest
varies by terminal.
Schedule Page:426
Schedule Page:426 Column:aLineNo.:7
Idaho Power has an ownership interest in certain high-voltage transmission related and
interconnection equipment located at PacifiCorp 's Antelope station.Ownership interest
varies by terminal.
Schedule Page:426 Line No.:13 Column:a
Idaho Power has an ownership interest in certain high-voltage transmission related and:
interconnection equipment located at PacifiCorp's Big Grassy station.Ownership interest
varies by terminal.
Schedule Page:426 Line No.:25 Column:a
PacifiCorp has an ownership interest in certain high-voltage transmission related and
interconnection equipment located at Idaho Power's Borah station.Ownership interest
varies by terminal.
Schedule Page:426.2 Line No.:23 Column:a
Idaho Power has an ownership interest in certain high-voltage transmission related and
interconnection equipment located at PacifiCorp's Goshen station.Ownership interest
varies by terminal.
Schedule Page:426.2 Line No.:34 Column:a
PacifiCorp has an ownership interest in certain high-voltage transmission related and
interconnection equipment located at Idaho Power's Hemingway station.Ownership interest
varies by terminal.
Schedule Page:426.3 Line No.:11 Column:a
Idaho Power has an ownership interest in certain high-voltage transmission related and
interconnection equipment located at PacifiCorp's Jefferson station.Ownership interest
varies by terminal.
Schedule Page:426.3 Line No.:25 Column:a
PacifiCorp has an ownership interest in certain high-voltage transmission related and
interconnection equipment located at Idaho Power's Kinport station.Ownership interest
varies by terminal .
Schedule Page:426.4 Line No.:13 Column:a
PacifiCorp has an ownership interest in certain high-voltage transmission related and
interconnection equipment located at Idaho Power's Midpoint station.Ownership interest
varies by terminal.
Line No.:5
Idaho Power has an ownership interest in certain high-voltage transmission related and
interconnection equipment located at PacifiCorp's Populus station.Ownership interest
varies by terminal.
Schedule Page:426.5 Column:a
Schedule Page:426.5 Line No.:38 Column:a
Idaho Power has an ownership interest in certain high-voltage transmission related and
interconnection equipment located at PacifiCorp's Three Mile Knoll station.Ownership
interest varies by terminal.
Schedule Page:426.6 Line No.:26 Column:a
Jointly owned with Sierra Pacific Power Company,d/b/a NV Energy.Idaho Power has a 50%
share of ownership.
Schedule Page:426.6 Line No.:27 Column:a
Jointly owned with Sierra Pacific Power Company,d/b/a NV Energy.Idaho Power has a 50%
share of ownership .
Schedule Page:426.6 Line No.:28 Column:a
Jointly owned with Sierra Pacific Power Company,d/b/a NV Energy.Idaho Power has a 50%
share of ownership.
Schedule Page:426.6 Line No.:29 Column:a
Jointly owned with Sierra Pacific Power Company,d/b/a NV Energy.Idaho Power has a 50%
share of ownership.
FERC FORM NO.1 (ED.12-87)Page 450.1
Date of Report Year/Period of Report
(Mo,Da,Yr)
04/15/2016
Name of Respondent This Report is:
(1)X An Original
(2)_A Resubmission 2015/Q4IdahoPowerCompany
FOOTNOTE DATA
"ISchedulePage:426.6 Line No.:30 Column:a
Jointly owned with Sierra Pacific Power Company,d/b/a NV Energy.Idaho Power has a 50%
share of ownership.
Schedule Page:426.6 Line No.:31 Column:a
Jointly owned with Sierra Pacific Power Company,d/b/a NV Energy.Idaho Power has a 50%
share of ownership.
Schedule Page:426.6 Line No.:32 Column:a
Jointly owned with Sierra Pacific Power Company,d/b/a NV Energy.Idaho Power has a 50%
share of ownership.
Schedule Page:426.6 Line No.:33 Column:a
Jointly owned with Sierra Pacific Power Company,d/b/a NV Energy.Idaho Power has a 50%
share of ownership,
Schedule Page:426.6 Line No.:37 Column:a
Jointly owned with Portland General Electric,Power Resources Cooperative and BA Leasing
BCS,LLC.Idaho Power has a 10%share of the jointly owned capacity.100%of the capacity
is reported._
Schedule Page:426.6 Line No.:38 Column:a
Jointly owned.'with Portland General Electric,Power Resources Cooperative and BA Leasing
BCS,LLC.Idaho Power has a 10%share of the jointly owned capacity.100%of the capacity
is reported.
Schedule Page:426.6 Line No.:39 Column:a
Jointly owned with Portland General Electric,Power Resources Cooperative and BA Leasing
BCS,LLC.Idaho Power has a 10%share of the jointly owned capacity.100%of the capacity
is reported.
Schedule Page:426.6 Line No.:40 Column:a
Idaho Power has a 22%ownership interest in certain high-voltage transmission related and
interconnection equipment located at PacifiCorp's Burns station^
Schedule Page:426.7 Line No.:5 Column:a
Idaho Power has an ownership interest in certain high-voltage transmission related and
interconnection equipment located at PacifiCorp's Hurricane station.Ownership interest
varies by terminal.
Schedule Page:426.7 Line No.:20 Column:a
Idaho Power has an ownership interest in certain high-voltage transmission related and
interconnection equipment located at PacifiCorp's Summer Lake station.Ownership interest
varies by terminal.
Schedule Page:426.7 Line No.:24 Column:a
Idaho Power has an ownership interest in certain high-voltage transmission related and
interconnection equipment located at PacifiCorp's Walla Walla station.Ownership interest
varies by terminal.
Schedule Page:426.7 Line No.:27 Column:a
Jointly owned with PacificCorp.Idaho Power has a 33.3%share of ownership.
FERC FORM NO.1 (ED.12-87)Page 450.2
This Page Intentionally Left Blank
Name of Respondent
Idaho Power Company
This Report Is:
(1)[xjAn Original
(2)QA Resubmission
TRANSACTIONS WITH ASSOCIATED (AFFILIATED)COMPANIES
Date of Report
(Mo.Da,Yr)
04/15/2016
Year/Period of Report
End of 2015/Q4
1 .Report below the Information called for concerning all non-power goods or services received from or provided to associated (affiliated)companies.
2.The reporting threshold for reporting purposes is $250,000 The threshold applies to the annual amount billed to the respondent or billed to
an associated/affiliated company for non-power goods and services.The good or service must be specific in nature.Respondents should not
attempt to include or aggregate amounts in a nonspecific category such as "general"
3.Where amounts billed to or received from the associated (affiliated)company are based on an allocation process,explain in a footnote.
Account
Charged or
Credited
Name of
Associated/Affiliated
Company
Amount
Charged or
Credited
Line
No.Description of the Non-Power Good or Service
(a)(b)(c)(d)
—
1 Non-power Goods or Services Provided by Affiliated
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20 Non-power Goods or Services Provided for Affiliate
Managerial Expenses IDACORP,INC.417420 517,69321
922000 60,45222
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
Page 429FERCFORMNO.1 (New)
FERC FORM NO.1-F (New)
December 31,201 5
ANNUAL REPORT
IDAHO SUPPLEMENT TO FERC FORM 1
MULTI-STATE ELECTRIC COMPANIES
INDEX
Page
Number Title
1 Statement of Income for the Year
2 Taxes Allocated to Idaho
3 Notes and Accounts Receivable
3 Accumulated Provision for Uncollectible Accounts
4 Receivables from Associated Companies
Gain or Loss on Disposition of Property5
6 Professional or Consultative Services
7-10 Electric Plant in Service
11 Electric Operating Revenues
12-15 Electric Operation and Maintenance Expenses
15 Number of Electric Department Employees
IDAHO SUPPLEMENT
This Page Intentionally Left Blank
STATE OF IDAHO -ALLOCATED
Idaho Power Company An Original December 31,2015
STATEMENT OF INCOME FOR THE YEAR
1 .Report amounts for accounts 412 and 413,Revenue and Expenses from Utility Plant Leased to Others,in another utility
column (i,k,m,o)in a similar manner to a utility department.Spread the amount(s)over lines 01 thru 24 as appropriate.
Include these amounts in columns (c)and (d)totals.
2.Report amounts in account 414,Other Utility Operating Income,in the same manner as accounts 412 and 413 above.
3.Report data for lines 7,9,and 10 for Natural Gas companies using accounts 404.1,404.2,404.3,407.1,and 407.2.
4.Use page 122 for important notes regarding the state ment of income or any account thereof.
5.Give concise explanations concerning unsettled rate proceedings where a contingency exists such that refunds of a
material amount may need to be made to the utility's customers or which may result in a material refund to the utility
with respect to power or gas purchases.State for each year affected the gross revenues or costs to which the contingency
relates and the tax effects together with an explanation of retain such revenues or recover amounts paid with respect
to power and gas purchases.
6.Give concise explanations concerning significant amounts of any refunds made or received during the year.
(Ref.)
PageLineAccount TOTAL
No.Current YearNo.Previous Year
(a)(b)(c)(d)
1 UTILITY OPERATING INCOME
2 Operating Revenues (400)
3 Operating Expenses
4 Operation Expenses (401 )
5 Maintenance Expenses (402)
6 Depreciation Expense (403)
7 Amort.&Depl.of Utility Plant (404-405)
8 Amort,of Utility Plant Acq.Adj.(406)
9 Amort,of Property Losses,Unrecovered Plant and
1 0 Accretion Expense (411)
Regulatory Study Costs (407)
12 Amort,of Conversion Expenses (407)
1 3 Regulatory Debits/Credits (407.3 &407.4)
14 Taxes Other Than Income Taxes (408.1)
15 Income Taxes -Federal (409.1)
-Other (409.1)
17 Provision for Deferred Income Taxes (410.1 &411.1)Net
18 Investment Tax Credit Adj.-Net(411.4)
19 (Less)Gains from Disp.of Utility Plant (411.6)
20 Losses from Disp.of Utility Plant (41 1 .7)
21 (Less)Gains from Disposition of Allowances (41 1 .8)
22 Losses from Disposition of Allowances (41 1 .9)
$1,208,201,834 $1,219,568,33711
15 695,189,223
65,984,911
125,382,354
6,708,360
744,61 1 ,224
64,952,478
120,300,338
6,687,969
15
221,919 296,254
11
2 30,566,626
12,620,531
5,825,567
27,032,456
471,511
29,569,719
(7,055,229)
6,624,230
17,355,209
39,767
2
16 2
2
2
23
24 TOTAL Utility Operating Expenses (Enter Total of lines 4 thru 22).970,003,458 983,381,958
25
26
Net Utility Operating Income (Enter Total of line 2 less 24)$238,198,376 $236,186,37927
Page 1IDAHOSUPPLEMENT
STATE OF IDAHO -ALLOCATED
An OriginalIdahoPowerCompany December 31,2015
TAXES ALLOCATED TO IDAHO
Taxes Charged
During YearKindofTax
Taxes Other Than Income Taxes:
Labor Related:
FICA
FUTA
State Unemployment
Payroll Deduction &Loading....
Total Labor Related
$13,981,739
88,992
582,363
(14,653,094)
0
Property Taxes
Kilowatt-hour Tax
Licenses
Regulatory Commission Fees
Irrigation PIC
Canada Sales Tax
Total Taxes Other Than Income Taxes
26,310,700
1,184,956
4,788
2,842,553
223,629
0
30,566,626
Federal Income Taxes
State Income Taxes
Deferred Income Taxes
Investment Tax Credit Adjustment -Net.
12,620,531
5,825,567
27,032,456
471,511
$76,516,691TotalTaxesAllocatedtoIdaho
Page 2IDAHOSUPPLEMENT
STATE OF IDAHO
An OriginalIdahoPowerCompany December 31,2015
NOTES AND ACCOUNTS RECEIVABLE
Summary for Balance Sheet
Show separately by footnote the total amount of notes and accounts receivable
from directors,officers,and employees included in Notes Receivable (Account
141)and Other Accounts Receivable (Account 143)
Balance
Beginning of
Year
Balance
End of
Year
AccountsLine
(a)(b)(c)No.
1 Notes Receivable (Account 141)
2 Customer Accounts Receivable (Account 142)
3 Other Accounts Receivable (Account 143)
4 (Disclose any capital stock subscription received)
Total...
$
85,040,915
14,677,441
75,650,719
23,486,155
$99,136,874$99,718,3565
6
Less:Accumulated Provision for Uncollectible
Accounts-Cr.(Account 144)
7
4,650,829 1,355,0428
9
10 Total,Less Accumulated Provision for
Uncollectible Accounts $95,067,527 $97,781,83211
12
13
14
15
16
17
18
19
20
ACCUMULATED PROVISION FOR UNCOLLECTIBLE ACCOUNTS -CR.(Account 144)
1.Report below the information called for concerning this accumulated provision.
2.Explain any important adjustments of subaccounts.
3.Entries with respect to officers and employees shall not include items for utility services.
Mdse,
Jobbing &
Contract
Work
OtherItemUtility
Customers
Officers TotalLine
and
(a)EmployeesNo.
(c)(d)(e)(f)(b)
$4,650,82921BalanceBegofYear:$4,650,829
$22
$$(751,888)(751,888)$Uncollectible Retail Electric Sales23
24
$15,63325UncollectibleDamageClaims15,633
26
$(2,559,532)Uncollectibe Other Revenues (2,559,532)27
28
29
30
31
$$1 ,355,042Balanceendofyear. $1 ,355,042 $$32
33
Page 3IDAHOSUPPLEMENT
STATE OF IDAHO
Idaho Power Company An Original December 31,2015
RECEIVABLES FROM ASSOCIATED COMPANIES (Accounts 145,146)
1 .Report particulars of notes and accounts receivable from associated companies at end of year.
2.Provide separate headings and totals for accounts 145,Notes Receivable from Associated Companies,and 146,
Accounts Receivable from Associated Companies,in addition to a total for the combined accounts.
3.For notes receivable list each note separately and state purpose for which received.Show also in column
(a)date of note,date of maturity and interest rate.
4.If any note was received in satisfaction of an open account,state the period covered by such open account.
5.Include in column (f)interest recorded as income during the year,including interest on accounts and notes
held at any time during the year.
6.Give particulars of any notes pledged or discounted,also of any collateral held as guarantee of payment
of any note or account.
Balance
Beginning
of Year
Line Totals for Year Balance
End of Year
Interest
For Year
Particulars
Debits Credits
(a)(b)(c)(d)(e)(f)No.
Account 1 45:1
2
$2,053,198 $2,438,845IERCO.$1,541,850 $1,156,2023
4
5
6
7
8
9
Total Account 145...10 2,053,198 1,541,850 2,438,845 1,156,202
11
12 Account 146:
13
14
15
$7,479,664$7,479,66416IDACORP,Inc $
17
18
19
20
21
22
23
24
25
26
27
28
29
30
$$7,479,664 $7,479,664 $Total Account 146.31
32
Page 4IDAHOSUPPLEMENT
STATE OF IDAHO
An OriginalIdahoPowerCompany December 31,2015
STATE OF IDAHO -TOTAL SYSTEM DATA
GAIN OR LOSS ON DISPOSITION OF PROPERTY (Account 421.1 and 421.2)
1 .Give a brief description of property creating the gain or loss.Include name of party acquiring the property (when
acquired by another utility or associated company)and the date transaction was completed.Identify property
by type;Leased,Held for Future Use,or Nonutility.
2.Individual gains or losses relating to property with an original cost of less than $50,000 may be grouped,with the
number of such transactions disclosed in column (a).
3.Give the date of Commission approval ofjournal entries in column (b),when approval is required.Where approval
is required but has not been received,give explanation following the item in column (a).(See account 102,Utility
Plant Purchased or Sold.)
Original Cost
of Related
Date Journal
Entry Approved
(When Required)
Line Description of Property Acct 421.1 Acct 421.2
(b)(c)(d)(e)No.(a)
1 Gain on disposition of
property:$$2 $
3
4
5
6
7
8
9
10
11
12
13
Total gain.$0 $14 0
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
$$Total loss.31 0 0
Page 5IDAHOSUPPLEMENT
STATE OF IDAHO
An Original December 31,2015IdahoPowerCompany
STATE OF IDAHO -TOTAL SYSTEM DATA
PROFESSIONAL OR CONSULTATIVE SERVICES -ITEMS $10,000 AND OVER
Line PAYEE "SERVICE TYPE Amount
(b)(c)No.(a)
—
243,477
45,060
13,051
235,321
49.219
40,481
375,658
252,880
18,950
15,000
47,433
16,768
16,940
41,304
25,969
183,502
75,000
47,506
370,555
1,460,545
36,015
31,675
131,753
19,472
363,574
23,044
124,064
143,192
37,200
31,139
733,253
114,081
132,682
35,000
220,882
16,505
140,400
20,000
710,141
12.220
28,573
19,928
207,111
161,580
JManagementServices
2 AGREE TECHNOLOGIES AND SOLUTIO Energy Efficiency Services
3 AKIN GUMP STRAUSS HAUER &FELD Legal Services
4 ALSTOM GRID INC Power Grid Consulting
5 ANDERSON BANDUCCI PLLC Legal Services
6 APPLIED ENERGY GROUP Management Services
7 BAKER BOTTS LLP Legal Services
8 BARKER,ROSHOLT &SIMPSON LLP Legal Services
9 BAYSWATER LLC Legal Services
10 BETHKE LAW PLLC Legal Services
1 1 BONNEVILLE BILLINGS &COL Customer Billing Services
12 BROADRIDGE FINANCIAL SOLUTIONS Management Services
13 BULLARD SMITH JERNSTEDT WILSON Legal Services
14 BURR COMPUTER ENVIRONMENTS INC]IT Services
1 5 CAMACK CONSULTING INC
16 CASE FORENSICS CORPORATION
1 7 CGI TECHNOLOGIES AND SOLUTIONS
18 CLEAREDGE PARTNERS INC
19 COMPUNET,INC
20 CORPORATE OFFICE INSTALLATIONS Management Services
Legal Services
Management Services
Training Consultants
24 ERGO RISK MANAGEMENT GROUP INC Training Consultants
Legal Services
26 EVERGREEN CONSULTING GROUP,LL Management Services
27 EVERGREEN ECONOMICS,INC.
28 EXISTBI
29 GIVENS PURSLEY LLP
30 H.W.LOCHNER,INC.
31 HAWLEY TROXELL ENNIS &HAWLEY
32 HONEYWELL INTERNATIONAL INC
33 INDUSTRIAL HYGIENE RESOURCES,
34 INTELLITECT
35 ISS CORPORATE SERVICES,INC
36 ITRON,INC.
37 J EVAN ROBERTSON PA
38 MAINLINE INFORMATION SYSTEMS I
39 MAXISYS
40 MCDOWELL RACKNER &GIBSON PC
41 MICROSOFT CORP
42 MIRANDE,MICHAEL
43 MORROW &FISCHER PLLC
44 MOVESAFE INC
45 NIELSEN GROUP INC
T ADECCO
Employee Benefit Services
Management Services
IT Services
Management Services
IT Services
DAVIS WRIGHT TREMAINE LLP21
22 DELOITTE TAX LLP
23 E SOURCE,INC.
25 EVANS KEANE
Management Services
Business Intelligence Support services
Legal Services
Enviromental Services
Legal Services
Management Services
Management Services
Management Services
Management Services
Resource Management
Legal Services
Management Services
Management Services
Legal Services
IT Services
Legal Services
Legal Services
Training Consultants
IT Services
Page 6
IDAHO SUPPLEMENT
STATE OF IDAHO
Idaho Power Company An Original December 31,2015
STATE OF IDAHO -TOTAL SYSTEM DATA
PROFESSIONAL OR CONSULTATIVE SERVICES -ITEMS $10,000 AND OVER
Line payee EERviUETYFE Amount
No.(a)(b)(c)
-m OXFORD GLOBAL RESOURCES INC
PAINE HAMBLEN LLP
PARR BROWN GEE &LOVELESS INC
PATRIOT ELECTRIC INC
PERKINS COIE LLP
PRICEWATERHOUSE COOPERS LLP
PROFESSIONAL TRAINING SYSTEMS
REED HARRIS ENVIRONMENTAL LTD
REGULIS INTEGRATED SOLUTIONS
REX BLACK CONSULTING SERVICES
RIGHT SYSTEMS,INC
RM ENERGY CONSULTING
SCHWABE WILLIAMSON &WYATT
SHLUS INC
STOEL RIVES LLP
SULLIVAN &CROMWELL
TATA AMERICA INTERNATIONAL COR
TELVENT USA LLC
TRINOOR LLC
TUERI LLC
UNIVERSITY OF IDAHO
VAN NESS FELDMAN
WESTERN UNION FINANCIAL
Management Services
Legal Services
Legal Services
Residential Construction Consulting
Legal Services
Management Services
Training Consultants
Environmental Services
Customer Billing Services
IT Services
IT Services
Management Services
Legal Services
Talent Services
Legal Services
Legal Services
Management Services
Power Grid Consulting
HR Consulting
Management Services
Management Services
Legal Services
Customer Billing Services
247,575
57,201
15,668
15,997
384,090
189,722
11,221
33,671
82,795
27,969
36,514
326,647
23,566
49,356
138,314
135,810
1,613,709
14,616
51,406
140,655
223,332
448,994
40,000
47
48
49
50
51
52
53
54
55
56
57
58
59
60
61
62
63
64
65
66
67
68
69
70
71
72
73
74
75
76
77
78
79
80
81
82
83
84
85
86
87
TOTAL T& 11.395.S45
Page 6A
IDAHO SUPPLEMENT
This Page Intentionally Left Blank
STATE OF IDAHO
An OriginalIdahoPowerCompany December 31,2015
PROFESSIONAL OR CONSULTATIVE SERVICES
ITEMS $5,000 OR MORE BUT LESS THAN $10,000
Line PREDOMINANT
NATURE OF SERVICE AMOUNTNo.PAYEE
Km
7,925
7,633
5,000
8,325
6,023
8,709
9,200
5)689
8,900
8,218
8,691
5,100
1 CLEARESULT CONSULTING INC
2 CME,INC.OF IDAHO
3 ESKER,INC
4 FORREST SERVICE
5 FIRE CAUSE ANALYSIS
6 HIRST APPLEGATE LLP
7 JACO ENVIRONMENTAL INC
Energy Efficiency Services
General Electrical Contracting
IT Services
Environmental Services
Fire Investigation Services
Legal Services
Environmental Services
MILLER &CHEVALIER CHARTERED Legal Services
Electronic Filing Services
TOWERS WATSON PENNSYLVANIA Energy Efficiency Services
VARIN WARDWELL LLC
WALDNER LAW OFFICES LLC
WILKINSON,BARKER,KNAUER LLP Legal Services
I
8
R R DONNELLEY9
10
Legal Services
Legal Services
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
40
41
42
43
44
m TOTAL I 97,912
Page 6BIDAHOSUPPLEMENT
STATE OF IDAHO -ALLOCATED
An Original December 31,2015IdahoPowerCompany
ELECTRIC PLANT IN SERVICE (Accounts 101,102,103 and 106)
1.Report below the original cost of electric plant in service according to the prescribed accounts.
2.In addition to Account 101,Electric Plant in Service (Classified),this page and the next include Account 102,Electric Plant
Purchased or Sold;Account 103,Experimental Electric Plant Unclassified;and Account 106,Completed Construction
Not Classified -Electric.
3.Include in column (c)or (d),as appropriate,corrections of additions and retirements for the current or preceding year.
4.Enclose in parentheses credit adjustments of plant accounts to indicate the negative effect of such accounts.
5.Classify Account 106 according to prescribed accounts,on an estimated basis if necessary,and include the entries in
column (c).Also to be included in column (c)are entries for reversals oftentative distributions of prior year reported in
column (b).Likewise,if the respondent has a significant amount of plant retirements the end of the year,include in
column (d)a tentative distribution of such retirements,on an estimated basis,with appropriate contra entry to the account
for accumulated depreciation provision.Include also in column (d)reversals of tentative distributions of prior year of un
classified retirements.Attach supplemental statement showing the account distributions of these tentative classifications in
columns (c)and (d),including the reversals of the prior years tentative account distributions of these amounts.Careful ob
servance of the above instructions and the 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.
Beginning of year AdditionsLineAccount
(c)(a)(b)No.
1 INTANGIBLE plantT
$5,459
28,048,263
28,362,313
sg;4i6;rag'
2 (301)Organization...,..,,,...,.,
3 (302)Franchises and Consents
4 (303)Miscellaneous Intangible Plant
5 TOTAL Intangible Plant (Enter Total of lines 2,3,and 4).
'2.PRODUCTION PLANT
A.Steam Production Plant
6
7
(310)Land and Land Rights
(311)Structures and Improvements
(312)Boiler Plant Equipment
(313)Engines and Engine Driven Generators
(314)Turbogenerator Units
(315)Accessory Electric Equipment
(316)Misc.Power Plant Equipment
(317)Asset Retirement Costs for Steam Production
TOTAL Steam Production Plant (Enter Total of lines 8 thru 15).
B.Nuclear Production Plant
8
9
10
11
12
13
14
6,611,52915
956,598,85016
17
18 (320)Land and Land Rights
(321)Structures and Improvements
(322)Reactor Plant Equipment
(323)Turbogenerator Units
(324)Accessory Electric Equipment
(325)Misc.Power Plant Equipment
(326)Asset Retirement Costs for Nuclear Production
TOTAL Nuclear Production Plant (Enter Total of lines 17 thru 24).
C.Hydraulic Production Plant
19
20
21
22
23
24
25
26
(330)Land and Land Rights.27
28
(332)Reservoirs,Dams,and Waterways
(333)Water Wheels,Turbines,and Generators
(334)Accessory Electric Equipment
(335)Misc.Power Plant Equipment
(336)Roads,Railroads,and Bridges
(337)Asset Retirement Costs for Hydraulic Production
TOTAL Hydraulic Production Plant (Enter Total of lines 27 thru 34).
D.Other Production Plant
29
30
31
32
33
34
m5'77,8C>3'35
36
(340)Land and Land Rights
(341)Structures and Improvements
(342)Fuel Holders,Products and Accessories.
(343)Prime Movers
(344)Generators
(345)Accessory Electric Equipment
(346)Misc Power Plant Equipment
37
38
39
40
41
42
43
Page 7
IDAHO SUPPLEMENT
STATE OF IDAHO -ALLOCATED
An Original December 31,2015IdahoPowerCompany
ELECTRIC PLANT IN SERVICE (Accounts 101 ,102,103 and 106)(Continued)
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 1 02.In showing the clearance of Account 1 02,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.
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
requirements of these pages.
For each amount comprising the reported balance and changes in Account 102,state the property purchased
or sold,name of vendor or purchaser,and date of transaction.If proposed journal entries have been filed
with the Commission as required bythe Uniform System of Accounts,give also date of such filing.
End of Year LineRetirementsAdjustments[ransfers
(9)(d)(e)(f)No.
T
(301)
(302)
$5,464
28,537,018
27,301,694
6b,S4<1/7
2
3
(303)4
5
6
7
(310)
(311)
8
9
(312)
(313)
10
11
(314)
(315)
12
13
(316)14
(317)13,515,196 15
Tt557^nS98 16
17
(320)
(321)
18
19
(322)20
(323)
(324)
(325)
(326)
21
22
23
24
25
26
(330)27
(331)28
(332)
(333)
29
30
(334)31
(335)
(336)
32
33
(337)34
i4&:52s;m 35
36
(340)
(341)
(342)
37
38
39
(343)40
(344)
(345)
41
42
(345)43
Page 8
IDAHO SUPPLEMENT
STATE OF IDAHO -ALLOCATED
An Original December 31,2015IdahoPowerCompany
ELECTRIC PLANT IN SERVICE (Accounts 101,102,103 and 106)(Continued)
balance at
Beginning of year
Line
AdditionsAccount
(b)(c)(a)No.
44 (346)Misc.Power Plant Equipment
TOTAL Other Production Plant (Enter Total of lines 37 thru 44)...
TOTAL Production Plant (Enter Total of lines 16,25,35,and 45).
3.TRANSMISSION PLANT
J—53u^jo,722
—xmyvzsrs
45
46
47
34,605,711
69,637,541
382,710,777
161,019,362
136,488,285
187,968,276
48 (350)Land and Land Rights
(352)Structures and Improvements
(353)Station Equipment
(354)Towers and Fixtures
(355)Poles and Fixtures — >—<¦
(356)Overhead Conductors and Devices
(357)Underground Conduit
(358)Underground Conductors and Devices
(359)Roads and Trails..,,.,.......,..,.
(359.1)Asset Retirement Costs for Transmission Plant
TOTAL Transmission Plant (Enter Total of lines 48 thru 57).
4.DISTRIBUTION PLANT
(360)Land and Land Rights
(361)Structures and Improvements
(362)Station Equipment
(363)Storage Battery Equipment
(364)Poles,Towers,and Fixtures
(365)Overhead Conductors and Devices
(366)Underground Conduit
(367)Underground Conductors and Devices
(368)Line Transformers
(369)Services
(370)Meters
(371)Installations on Customer Premises
(372)Leased Property on Customer Premises
(373)Street Lighting and Signal Systems
(374)Asset Retirement Costs for Distribution Plant
TOTAL Distribution Plant (Enter Total of lines 60 thru 74)....
5.GENERAL PLANT
49
50
51
52
53
54
55
373,63556
57
972,811,58758
59
5,051,237
32,116,160
195,069,259
60
61
62
63
222,604,427
119,358,951
46,631,228
215,537,454
475,247,016
55,003,907
77,835,697
2,688,508
64
65
66
67
68
69
70
71
72
4,299,30273
74
1,451,443,14775
76
15,870,623
102,467,445
43,942,561
71,045,176
1,853,706
7,251,311
12,112,184
13,342,917
51,491,365
5,338,964
324,716:262
77 (389)Land and Land Rights
(390)Structures and Improvements
(391)Office Furniture and Equipment
(392)Transportation Equipment
(393)Stores Equipment
(394)Tools,Shop,and Garage Equipment
(395)Laboratory Equipment
(396)Power Operated Equipment
(397)Communication Equipment
(398)Miscellaneous Equipment
SUBTOTAL (Enter Total of lines 77 thru 86)
(399)Other Tangible Property
(399.1)Asset Retirement Costs for General Plant
TOTAL General Plant (Enter Total of lines 87,88 and 89).
TOTAL (Accounts 101 and 106)
(102)Electric Plant Purchased
(Less)(102)Electric Plant Sold
(103)Experimental Plant Unclassified
78
79
80
81
82
83
84
85
86
87
88
89
324,716,25?90
5,024:099,39691
92
93
94
95
'$"'5,'0'2'4,"0'9'9:3'95|TOTAL Electric Plant in Service.96
Page 9
IDAHO SUPPLEMENT
STATE OF IDAHO -ALLOCATED
An Original December 31,2015IdahoPowerCompany
ELECTRIC PLANT IN SERVICE (Accounts 101,102,103 and 106)(Continued)
Balance at
End of Year
Line
Retirements Adjustments Transfers
(d)(f)(9)No.(e)
jm
1 616,333,612
'2,322,81?,m
45
46
47
(350)
(352)
(353)
(354)
34,884,459
74,584,045
390,824,535
177,042,687
151,840,760
203,174,425
48
49
50
51
(355)
(356)
52
53
(357)
(358)
54
55
374,232 (359)56
(359.1)57
77532^25,142'58
59
(360)
(361)
(362)
5,176,136
32,644,394
207,064,121
60
61
62
(363)
(364)
63
64228,143,181
120,527,316
47,672,004
227,020,812
496,171,835
55,899,072
82,333,518
2,729,762
(365)
(366)
65
66
(367)67
(368)
(369)
68
69
(370)70
(371)
(372)
71
72
(373)
(374)
4,333,517 73
74
i;S0'9"?io,6'6'S'75
76
15,884,981
106,283,870
44,738,612
72,704,300
2,161,043
7,685,955
12,172,325
14,451,045
53,096,779
5,718,032
(389)
(390)
77
78
(391)79
(392)80
(393)
(394)
81
82
(395)
(396)
(397)
(398)
83
84
85
86
87
jmf 88
(399.1)89
334,896,942
5^55,999:909
90
91
vm 92
(102)
(371)
93
94
95
$'5:255,999,909'96
Page 10
IDAHO SUPPLEMENT
STATE OF IDAHO -ALLOCATED
December 31,2015AnOriginalIdahoPowerCompany
ELECTRIC OPERATING REVENUES (Account 400)
1 .Report below operating revenues for each prescribed account,and manufactured gas revenues in total.
2.Report number of customers,columns (f)and (g),on the basis of meters,in addition to the number of flat rate
accounts;except that where separate meter readings are added for billing purposes,one customer should be counted
for each group of meters added.The average number of customers means the average of twelve figures at the close
of each month.
3.If previous year (columns (c),(e)and (g),are not derived from previously reported figures,explain any
inconsistencies in a footnote.
OPERATING REVENUES
Amount for
Previous Year
Amount for
Current YearNo.
(c)(b)(a)
Sales of Electricity1
$....$481,950,250494,611,4682(440)Residential Sales
3 (442)Commercial and Industrial Sales
4 Small (or Commercial)(See Instr.4)(1 )
5 Large (or lndustrial)(See Instr.4)(2)
6 (444)Public Street and Highway Lighting
7 (445)Other Sales to Public Authorities
8 (446)Sales to Railroads and Railways
9 (448)Interdepartmental Sales
10 TOTAL Sales to Ultimate Consumers
1 1 (447)Sales for Resale -Opportunity....Non-Firm Only.
12 TOTAL Sales of Electricity
1 3 (449)Provision for Rate Refunds
14 TOTAL Revenue Net of Provision for Refunds
Other Operating Revenues
16 (450)Forfeited Discounts
17 (451)Miscellaneous Service Revenues
18 (453)Sales of Water and Water Power....
19 (454)Rent from Electric Property
20 (455)Interdepartmental Rents
21 (456)Other Electric Revenues
436,588,320
167,602,922
3,976,711
447,471,324
166,580,123
3,905,150
1,112,568,065 *
29,477,405
1,090,118,203
73,741,042
1,163,859,245
(18,363,613)
1,142,045,471
(13,865,518)
1,145,495,6321,128,179,953
15
3,696,7034,036,347
22,576,03423,713,987
47,799,96752,271,548
22
23
24
74,072,70580,021,882TOTALOtherOperatingRevenues...
TOTAL Electric Operating Revenues
25
$$1,208,201,834 1,219,568,33726
(1)Commercial and Industrial sales -Small -under 1,000 KW and includes all irrigation customers.
(2)Commercial and Industrial sales -Large -1,000 KW and over.
Page 1 1
IDAHO SUPPLEMENT
STATE OF IDAHO -ALLOCATED
An Original December 31,2015IdahoPowerCompany
ELECTRIC OPERATING REVENUES (Account 400)(Continued)
4.Commercial and Industrial Sales,Account 442,may be classified according to the basis of classification
(Small or Commercial,and Large or Industrial)regularly used by the respondent if such basis of classification
is not generally greater than 1000 Kw of demand.(See Account 442 of the Uniform System of Accounts.Explain
5.See page 108,Important Changes During Year,for important new territory added and important rate increases or
decreases.
6.For lines 2,4,5,and 6,see page 304 for amounts relating to unbilled revenue by accounts.
7.Include unmetered sales.Provide details of such sales in a footnote.
AVERAGE NUMBER OF CUSTOMERS PER MONTHKILOWATTHOURSSOLD
Number for
Previous Year
LineAmountfor
Current Year
Amount for
Previous Year
Amount for
Current Year No.
(9)(f)(e)(d)
1
2411,689418,9064,784,072,5144,803,995,275
3
79,248 480,2615,675,423,865
2,970,925,860
31,654,264
5,836,330,091
2,938,946,430
31,192,274
110 5113
62,3492,559
7
8
9
493,396 10501,83913,610,464,070 **
1,196,890,694
13,462,076,503
1,609,051,066 11N/AN/A
493,396 12501,83915,071,127,56914,807,354,764
13
*Includes $7,438,098 unbilled revenues.
**Includes 95,904,770 KWH relating to unbilled revenues.
Lines 11 through 21 are on an "allocated"basis.
Page 11a
IDAHO SUPPLEMENT
STATE OF IDAHO -ALLOCATED
An Original December 31,2015IdahoPowerCompany
ELECTRIC OPERATION AND MAINTENANCE EXPENSES
it tne amount tor previous year is not derived trom previously reported figures,explain in rootnotes.
AiYIOUfH lOr
Previous Year
Aniouril lot
Current Year
Tif!^
AccountNo,
tc)(a)
1.POWER PRODUCTION EXPENSES1
"Z 7v3lgarrTT^wen55rWaii5iT
3 Operation
4 (500)Operation Supervision and Engineering
5 (501)Fuel
6 (502)Steam Expenses
7 (503)Steam from Other Sources
8 (Less)(504)Steam Transferred-Cr
9 (505)Electric Expenses
10 (506)Miscellaneous Steam Power Expenses
11 (507)Rents
12 (509)Allowances
TOTAL Operation (Enter Total of lines 4 thru 12)
14 Maintenance
15 (510)Maintenance Supervision and Engineering
16 (511)Maintenance of Structures
17 (512)Maintenance of Boiler Plant
18 (513)Maintenance of Electric Plant
19 (514)Miscellaneous Steam Plant... .
TOTAL Maintenance (Enter Total of Lines 15 thru 19)... ...
TOTAL Power Production Expenses-Steam Power (Enter Total of lines 13 and I
B.Nuclear Power Generation
$..$1,318,039
149,242,737
8,353,412
1,234,974
125,293,762
9,344,671
1,528,536
9,189,663
507,91 1
1,204,563
6,401,977
414,288
"iT07i40;2"97143,864,28513
266,044
678,123
10,438,403
5,776,736
5,558,967
~2jTii,272
121,775
841,997
13,228,845
5,165,496
6,638,813
25,966,925
169,891,166
20
21
22
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
TOTAL Operation (Enter Total of lines 24 thru 32)....
Maintenance
33
34
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 Power Production Expenses-Nuclear Power (Enter Total of lines 33 and
C.Hydraulic Power Generation
41
42
43 Operation
44 (535)Operation Supervision and Engineering
45 (536)Water for Power
46 (537)Hydraulic Expenses
47 (538)Electric Expenses
48 (539)Miscellaneous Hydraulic Power Generation Expenses.
49 (540)Rents
5,456,838
7,004,348
13,497,028
1,464,659
5,488,290
248,637
33,159,799
5,558,396
8,697,696
14,295,462
1,555,246
5,442,169
225,600
"35,774,569TOTALOperation(Enter Total of lines 44 thru 49).50
Page 12
IDAHO SUPPLEMENT
STATE OF IDAHO -ALLOCATED
December 31,2015AnOriginalIdahoPowerCompany
ELECTRIC OPERATION AND MAINTENANCE EXPENSES
it tne amount Tor previous year is not derived tram previously reported tigures,explain in tootnotes.
AnTGurtl !6T
Previous Year
tm "AfrTouritlof-
Current YearNo.Account
(c)(D)(a)
C Hydraulic Power Generation (Continued)51
52 Maintenance
53 (541)Maintenance Supervision and Engineering
54 (542)Maintenance of Structures
55 (543)Maintenance of Reservoirs,Dams,and Waterways
56 (544)Maintenance of Electric Plant
57 (545)Maintenance of Miscellaneous Hydraulic Plant
58 TOTAL Maintenance (Enter Total of lines 53 thru 57).,... ,
59 TOTAL Power Production Expenses-Hydraulic Power (Enter Total of lines 50 and
D.Other Power Generation
115,391 $
1,074,449
551,802
2,542,063
116,975
1,328,245
350,696
2,181,187
2,445,769
6,422,872
X5S2^7T
$
2,742,589
7,026,293
42780OS63
60
61 Operation
62 (546)Operation Supervision and Engineering
63 (547)Fuel
64 (548)Generation Expenses
65 (549)Miscellaneous Other Power Generation Expenses
66 (550)Rents
67 TOTAL Operation (Enter Total of lines 62 thru 66)
68 Maintenance
69 (551)Maintenance Supervision and Engineering
70 (552)Maintenance of Structures
71 (553)Maintenance of Generating and Electric Plant
72 (554)Maintenance of Miscellaneous Other Power Generation Plant
73 TOTAL Maintenance (Enter Total of lines 69 thru 72)
74 TOTAL Power Production Expenses-Other Power (Enter Total of lines 67 and 73
E.Other Power Supply Expenses
76 (555)Purchased Power
77 (556)System Control and Load Dispatching
78 (557)Other Expenses
79 TOTAL Other Power Supply Expenses (Enter Total of lines 76 thru 78)
80 TOTAL Power Production Expenses (Enter Total of lines 21,41,59,74,and 79).
2.TRANSMISSION EXPENSES
779,191
43,069,104
3,440,496
866,982
620,066
52,436,682
4,405,378
895,988
00
58,356,114 46,155,773
00
361,955
82,752
1,332,131
T776T8"38
49,932,611
348,753
68,784
1,218,031
1,635,366
39,993,681
75
226,605,619
(1,189)
22,805,378
"249^09,808"
531,783,669"
207,677,199
2,336
18,163,160
225,642,695
498,528,400
81
82 Operation
83 (560)Operation Supervision and Engineering
84 (561)Load Dispatching
85 (562)Station Expenses ,
86 (563)Overhead Line Expenses
87 (564)Underground Line Expenses
88 (565)Transmission of Electricity by Others
89 (566)Miscellaneous Transmission Expenses
90 (567)Rents
TOTAL Operation (Enter Total of lines 83 thru 90)
92 Maintenance
93 (568)Maintenance Supervision and Engineering
94 (569)Maintenance of Structures
95 (570)Maintenance of Station Equipment
96 (571 )Maintenance of Overhead Lines
97 (572)Maintenance of Underground Lines
98 (573)Maintenance of Miscellaneous Transmission Plant
TOTAL Maintenance (Enter Total of lines 93 thru 98)
TOTAL Transmission Expenses (Enter Total of lines 91 and 99).
3.DISTRIBUTION EXPENSES
3,847,645
2,579,291
2,353,313
640,645
3,966,098
2,817,822
2,524,933
927,497
5,811,469
17,494
3,144,575
T8^9M30
5,992,521
2,268
2,957,854
19,188,99191
162,267
994,016
3,544,467
3,061,759
150,586
894,294
3,151,054
2,814,416
1,525
Twms
267158:464
0
"77<5T0^j(j"
26,169,341
99
100
101
102 Operation
103 (580)Operation Supervision and Engineering.4,102,960 3,856,280
Page 13
IDAHO SUPPLEMENT
STATE OF IDAHO -ALLOCATED
December 31,2015IdahoPowerCompanyAnOriginal
ELECTRIC OPERATION AND MAINTENANCE EXPENSES
IT tne amount Tor previous year is not derived tram previously reported Tigures,explain in rootnotes.
—jmmrw
Previous Year
-OHS""7TiTTSuTTTrsr-
Current YearNo.Account
(c)(a)W
3.DISTRIBUTION EXPENSES (Continued)
105 (581)Load Dispatching
106 (582)Station Expenses
107 (583)Overhead Line Expenses
108 (584)Underground Line Expenses
109 (585)Street Lighting and Signal System Expenses.
1 10 (586)Meter Expenses
1 1 1 (587)Customer Installations Expenses
112 (588)Miscellaneous Distribution Expenses
113 (589)Rents
104
$3,750,022 $
1,279,072
3,676,494
2,850,198
83,896
4,606,198
724,519
5,778,592
250,686
27,102,636
3,500,477
1,139,653
2,908,059
2,489,099
73,399
4,276,734
640,974
5,540,895
446,160
114 TOTAL Operation (Enter Total of lines 103 thru 113).
Maintenance115
116 (590)Maintenance Supervision and Engineering
117 (591)Maintenance of Structures
118 (592)Maintenance of Station Equipment
1 19 (593)Maintenance of Overhead Lines .
120 (594)Maintenance of Underground Lines..
121 (595)Maintenance of Line Transformers
122 (596)Maintenance of Street Lighting and Signal Systems
123 (597)Maintenance of Meters
124 (598)Maintenance of Miscellaneous Distribution Plant
TOTAL Maintenance (Enter Total of lines 116 thru 124)
TOTAL Distribution Expenses (Enter Total of lines 1 14 and 125).
4.CUSTOMER ACCOUNTS EXPENSES
10,165 15,747
00
3,814,699
12,883,895
621,410
142,325
507,517
710,855
386,170
19,082,61?
4335A347"
3,466,718
13,159,994
596,266
35,220
464,372
741,737
267,593
18,742,066
45,844,703
125
126
127
128 Operation
129 (901)Supervision
130 (902)Meter Reading Expenses
131 (903)Customer Records and Collection Expenses
132 (904)Uncollectible Accounts
133 (905)Miscellaneous Customer Accounts Expenses
134 TOTAL Customer Accounts Expenses (Enter Total of lines 129 thru 133).
5.CUSTOMER SERVICE AND INFORMATIONAL EXPENSES
466,780
1,764,385
14,953,292
3,128,782
481,778
1,492,534
16,030,097
6,316,859
90379
24,321,35820,313,618
135
136 Operation
137 (907)Supervision
138 (908)Customer Assistance Expenses..
139 (909)Informational and Instructional Expenses
140 (910)Miscellaneous Customer Service and Informational Expenses ,
TOTAL Cust.Service and Informational Expenses (Enter Total of lines 137 thru 1'
6.SALES EXPENSES
758,841
35,331,512
409,488
691,250
377rawi"
561,496
32,298,865
361,011
658,759
33,880,131141
142
143 Operation
144 (911)Supervision
145 (912)Demonstrating and Selling Expenses
146 (913)Advertising Expenses
147 (916)Miscellaneous Sales Expenses.....
TOTAL Sales Expenses (Enter Total of lines 144 thru 147)..
7.ADMINISTRATIVE AND GENERAL EXPENSES
76,081
TS^JST148
149
150 Operation
151 (920)Administrative and General Salaries
152 (921)Office Supplies and Expenses
153 (Less)(922)Administrative Expenses Transferred-Credit
69,850,602
16,647,453
(26,023,220)
69,806,988
14,063,954
(24,956,472)
Page 14
IDAHO SUPPLEMENT
STATE OF IDAHO -ALLOCATED
An Original December 31,2015IdahoPowerCompany
ELECTRIC OPERATION AND MAINTENANCE EXPENSES
it tne amount tor previous year is not derived tram previously reported tigures,explain in tootnotes.
¦AiTTOUmW
Current Year
Amount lor
Previous Year
TiW
No.Account
(c)(a)
7.ADMINISTRATIVE AND GENERAL EXPENSES (Continued)
155 (923)Outside Services Employed
156 (924)Property Insurance
157 (925)Injuries and Damages
158 (926)Employee Pensions and Benefits
159 (927)Franchise Requirements
160 (928)Regulatory Commission Expenses
161 (929)Duplicate Charges-Cr
162 (930.1)General Advertising Expenses
163 (930.2)Miscellaneous General Expenses
164 (931)Rents
154
$$7,813,431
3,242,063
6,348,690
41,999,742
4,492,073
3,315,652
5,847,681
59,787,654
0 0
3,242,0133,334,101
590,563
5,202,216
1,916
127,447,192
432,639
4,685,182
168
uwtmTOTALOperation(Enter Total of lines 151 thru 164).
Maintenance
165
166
7,187,845167(935)Maintenance of General Plant
168 TOTAL Admin and General Expenses (Enter Total of lines 165-167)
169 TOTAL Elec Op and Maint Exp (Total of 80,100,126,134,141,148,168).
5,573,707
133,020,960
761,174,134
149,465,742
669,663,702TJ
IDAHO ONLY
NUMBER OF ELECTRIC DEPARTMENT EMPLOYEES
t .1 ne data on numDer ot employees snouid De reported tor tne payroll period ending nearest to uctoDer 31 ,
or any payroll period ending t>o days Detore or atter uctoDer 31 .
2.it tne respondent s payroll tor tne reporting period includes any special construction personnel,include
sucn employees on line 3,and snow tne numDer ot sucn special construction employees in a tootnote.
3.1 ne numDer ot employees assignaDie to tne electric department trom joint tunctions ot comDination utilities
may De determined Dy estimate,on tne Dasis or employee equivalents,snow tne estimated numDer or equiv
alent employees attriDuteo to tne electric department trom joint tunctions.
December 31,2015 December 31,20141PayrollPeriodEnded(Date).
I2TotalRegularFull-Time Employees.1,993 2,011
[
¦I3TotalPart-Time and Temporary Employees.19 20
2,012 2,0314TotalEmployees.
Page 1 5
IDAHO SUPPLEMENT