202011092019AnnualReport.pdf

LISA D. NORDSTROM
Lead Counsel
[e-mail]

May 1, 2020

ELECTRONIC FILING

Ms. Diane Hanian, Secretary
Idaho Public Utilities Commission
PO Box 83720
Boise, ID 83720-0074

Re: Idaho Power Company’s 2019 Annual FERC Form 1 Report

Dear Ms. Hanian:

Pursuant to Idaho Code § 61-405, and Order No. 34622, attached for electronic filing
are Idaho Power Company’s FERC Form 1 report and Idaho supplement for the year ending
December 31, 2019. One bound and one unbound copy are being sent U.S. Mail as
previously requested by the Idaho Public Utilities Commission. Also included is the
IDACORP 2019 Annual Report.

If you have any questions, please contact Regulatory Analyst Kelley Noe at 208-
388-5736 or [e-mail].

Very truly yours,

Lisa D. Nordstrom

LDN:kkt

Enclosures

RECEIVED
2020 May 1,AM10:51
IDAHO PUBLIC
UTILITIES COMMISSION
IPC-E
Form 1 ApprovedTHISFILINGIS
OMB No.1 902-0021
Item 1 :[x]An Initial (Original)
Submission
OR Resubmission No.(Expires 11/30/2022)
Form 1 -F Approved
OMB No.1902-0029
(Expires 11/30/2022)
Form 3-Q Approved
OMB No.1 902-0205
(Expires 11/30/2022)
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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 2019/Q4
FERC FORM No.1/3-Q (REV.02-04)
Form 1 ApprovedTHISFILINGIS
OMB No.1 902-0021
Item 1 :[x]An Initial (Original)
Submission
OR Resubmission No.(Expires 11/30/2022)
Form 1 -F Approved
OMB No.1902-0029
(Expires 11/30/2022)
Form 3-Q Approved
OMB No.1 902-0205
(Expires 11/30/2022)
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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 2019/Q4
FERC FORM No.1/3-Q (REV.02-04)
Deloitte &Touche LLP
800 West Main Street
Suite 1400DeloitteBoise,ID 83702-7734
USA
Tel:[phone]
www.deloitte.com
INDEPENDENT AUDITORS'REPORT
Idaho Power Company
Boise,Idaho
We have audited the accompanying financial statements of Idaho Power Company (the
"Company"),which comprise the balance sheet—regulatory basis as of December 31,2019,
and the related statements of income—regulatory basis,retained earnings—regulatory
basis,and cash flows—regulatory basis for the year then ended,included on pages 110
through 123 of the accompanying Federal Energy Regulatory Commission Form 1,and the
related notes to the financial statements.
Management's Responsibility for the Financial Statements
Management is responsible for the preparation and fair presentation of these financial
statements in accordance with the accounting requirements of the Federal Energy
Regulatory Commission as set forth in its applicable Uniform System of Accounts and
published accounting releases;this includes the design,implementation,and maintenance
of internal control relevant to the preparation and fair presentation of financial statements
that are free from material misstatement,whether due to fraud or error.
Auditors'Responsibility
Our responsibility is to express an opinion on these financial statements based on our audit.
We conducted our audit in accordance with auditing standards generally accepted in the
United States of America.Those standards require that we plan and perform the audit to
obtain reasonable assurance about whether the financial statements are free from material
misstatement.
An audit involves performing procedures to obtain audit evidence about the amounts and
disclosures in the financial statements.The procedures selected depend on the auditor's
judgment,including the assessment of the risks of material misstatement of the financial
statements,whether due to fraud or error.In making those risk assessments,the auditor
considers internal control relevant to the Company's preparation and fair presentation of the
financial statements in order to design audit procedures that are appropriate in the
circumstances,but not for the purpose of expressing an opinion on the effectiveness of the
Company's internal control.Accordingly,we express no such opinion.An audit also includes
evaluating the appropriateness of accounting policies used and the reasonableness of
significant accounting estimates made by management,as well as evaluating the overall
presentation of the financial statements.
We believe that the audit evidence we have obtained is sufficient and appropriate to provide
a basis for our audit opinion.
Opinion
In our opinion,the regulatory-basis financial statements referred to above present fairly,in
all material respects,the assets,liabilities,and proprietary capital of Idaho Power Company
as of December 31,2019,and the results of its operations and its cash flows for the year
then ended in accordance with the accounting requirements of the Federal Energy
Regulatory Commission as set forth in its applicable Uniform System of Accounts and
published accounting releases.
Basis of Accounting
As discussed in Note 1 to the financial statements,these financial statements were prepared
in accordance with the accounting requirements of the Federal Energy Regulatory
Commission as set forth in its applicable Uniform System of Accounts and published
accounting releases,which is a basis of accounting other than accounting principles
generally accepted in the United States of America.Our opinion is not modified with respect
to this matter.
Restricted Use
This report is intended solely for the information and use of the board of directors and
management of the Company and for filing with the Federal Energy Regulatory Commission
and is not intended to be and should not be used by anyone other than these specified
parties.
April 14,2020
-2 -
This Page Intentionally Left Blank
FERC FORM NO.1/3-Q:
REPORT OF MAJOR ELECTRIC UTILITIES.LICENSEES AND OTHER
IDENTIFICATION t
01 Exact Legal Name of Respondent
Idaho Power Company
02 Year/Period of Report
End of 2019/Q4
03 Previous Name and Date of Change (if name changed during year)
I /
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)
04/14/2020
(1)K)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 04/14/2020
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)
04/14/2020
Year/Period of Report
2019/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)
General Information1 101
2 Control Over Respondent 102
3 Corporations Controlled by Respondent 103
4 Officers 104
5 Directors 105
6 Information on Formula Rates 106(a)(b)
7 Important Changes During the Year 108-109
8 Comparative Balance Sheet 110-113
9 Statement of Income for the Year 114-117
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 Fledging Activities 122(a)(b)
14 Summary of Utility Plant &Accumulated Provisions for Dep,Amort &Dep 200-201
15 Nuclear Fuel Materials 202-203 N/A
16 Electric Plant in Service 204-207
17 Electric Plant Leased to Others N/A213
18 Electric Plant Field for Future Use 214
19 Construction Work in Progress-Electric 216
20 Accumulated Provision for Depreciation of Electric Utility Plant 219
21 Investment of Subsidiary Companies 224-225
22 Materials and Supplies 227
23 Allowances 228(ab)-229(ab)N/A
24 Extraordinary Property Losses N/A230
25 Unrecovered Plant and Regulatory Study Costs 230 N/A
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
33 Long-Term Debt 256-257
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
36 Accumulated Deferred Investment Tax Credits 266-267
FERC FORM NO.1 (ED.12-96)Page 2
Year/Period of Report
End of
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)
04/14/2020
2019/Q4
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)
37 Other Deferred Credits 269
38 Accumulated Deferred Income Taxes-Accelerated Amortization Property 272-273 N/A
39 Accumulated Deferred Income Taxes-Other Property 274-275
40 Accumulated Deferred Income Taxes-Other 276-277
Other Regulatory Liabilities41 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
47 Purchased Power 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
53 Regulatory Commission Expenses 350-351
54 Research,Development and Demonstration Activities 352-353
55 Distribution of Salaries and Wages 354-355
56 Common Utility Plant and Expenses 356 N/A
57 Amounts included in ISO/RTO Settlement Statements 397 N/A
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
62 Monthly Peaks and Output 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
Year/Period of Report
2019/Q4
Date of Report
(Mo,Da,Yr)
04/14/2020 End of
LIST OF SCHEDULES (Electric Utility)(continued)
Enter in column (c)the terms "none,""not applicable,"or "NA,"as appropriate,where no information or amounts have been reported for
certain pages.Omit pages where the respondents are "none,""not applicable,"or "NA".
Line Title of Schedule Reference
Page No.
Remarks
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:
]Two copies will be submitted
I |No annual report to stockholders is prepared
Page 4FERCFORMNO.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)
04/14/2020
Year/Period of Report
2019/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)Yes...Enter the date when such independent accountant was initially engaged:
(2)H No
FERC FORM No.1 (ED.12-87)PAGE 101
Name of Respondent
Idaho Power Company
This Report Is:
(1)m An Original
(2)Q A Resubmission
Year/Period of ReportDateofReport
(Mo,Da,Yr)
04/14/2020 2019/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
Name of Respondent
Idaho Power Company
This Report Is:
(1)|X|An Original
Date of Report
(Mo,Da,Yr)
04/14/2020
Year/Period of Report
2019/Q4Endof(2)|—[AResubmissi 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.
Line Name of Company Controlled Kind of Business Percent Voting
Stock Owned
Footnote
Ref.No.
(a)(b)(c)(d)
1 Direct Control
2 Idaho Energy Resources Company Coal mining and mineral 100%
3 development
4
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Page 103FERCFORMNO.1 (ED.12-96)
Name of Respondent
Idaho Power Company
This Report Is:
(1)pg An Original
(2)||A Resubmissi
Date of Report
(Mo.Da,Yr)
04/14/2020
Year/Period of Report
2019/Q4Endof
on
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.
Title Name of Officer Salary
for Year
Line
No.(a)(b)(c)
1
2 Chief Executive Officer,Idaho Power Company (1)Darrel T.Anderson 900,000
3 President &CEO,Idaho Power Company (2)
4
5 President,Idaho Power Company (3)Lisa Grow 590,000
6 Senior Vice President,COO (2)
7
Senior Vice President,CFO &Treasurer8 Steven Keen 463,000
9
Senior Vice President &General Counsel10 Brian R.Buckham 385,000
11
Senior Vice President &Chief Operating Officer (3)12 Adam J.Richins 350,000
VP,Customer Operations &Bus.Develpment (2)13
14
15 Senior Vice President,Public Affairs Jeffrey Malmen 320,000
16
VP,T&D Engineering &Construction and CSO (2)17 Vern Porter 315,000
Vice President,Idaho Power Company (1 &4)18
19
Vice President,Power Supply20 Tessia R.Park 305,000
21
Vice President,Corporate Controller &CAO22 Ken W.Petersen 275,000
23
Vice President,Corporate Services &CIO (5)24 Jeff Glenn 270,000
25
26 Vice President,Regulatory Affairs 230,000TimTatum
27
Vice President,Human Resources (3)28 Sarah E.Griffin 210,000
29
30 Vice President,Customer Operations &CSO (3)Bo Hanchey 200,000
31
Corporate Secretary32 Patrick Harrington 220,000
33
Vice President,Corporate Services &Communiations (3)34 Debra H.Leithauser 217,000
35
Vice President,T&D Engineering &Construction (3)36 Ryan N.Adelman 190,000
37
(1)Title change effective 10/01/1938
(2)Vacated position 10/01/1939
40 (3)Appointed to position 10/01/19
(4)Retirement effective 12/31/1941
Salary shows YTD wages42
43 (5)Retired from position 10/01/19
Salary shows YTD wages44
FERC FORM NO.1 (ED.12-96)Page 104
Name of Respondent
Idaho Power Company
This Report Is:
(1)[X]An Original
(2)| |A Resubmission
Date of Report
(Mo.Da,Yr)
04/14/2020
Year/Period of Report
2019/Q4Endof
DIRECTORS
1 .Report below the information called for concerning each director of the respondent who held office at any time during the year.Include in column (a),abbreviated
titles of the directors who are officers of the respondent.
2.Designate members of the Executive Committee by a triple asterisk and the Chairman of the Executive Committee by a double asterisk.
cms Name (and Title)of Director Principal Business AddressNo.(a)(b)
1
2 Judith A.Johansen 10446 E.Palo Brea Dr.,Scottsdale,Arizona 85262
3
4 Christine King,Comp.Committee Chair,8527 East Old Field Rd
5 Scottsdale,Arizona 85266
6
7 Thomas E.Carlile 2719 North Woodview place,Boise Idaho 83702
8
9 Darrel T.Anderson President &CEO,*****Idaho Power Company,1221 W.Idaho Street,
10 P.O.Box 70,Boise,Idaho 83707-0070
11
12 Robert A.Tinstman (1 )4433 W.Quail Point Court,Boise,Idaho 83703
13
14 Richard Dahl,Board Chair &Corp Gov Chair,***(2)60 Laiki PI.
15 Kailua,Hawaii 96734-1905
16
17 Dennis L.Johnson,Corp Gov Committee,(2)926 W Oakhampton Dr,Eagle,Idaho 83616
18
19 Ronald W.Jibson 417 Aerie Circle,North Salt Lake City,Utah 84054
20
21 Richard J.Navarro,Audit Chair,***(2)1256 E.Candleridge Ct.,Boise,Idaho 83712
22
23 Annette G.Elg 3475 E.Rivernest Lane,Boise,Idaho 83706-6928
24
(1)Retired on May 16,201925
(2)Title effective on May 16,201926
27
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48
FERC FORM NO.1 (ED.12-95)Page 105
Name of Respondent
Idaho Power Company
This Report Is:
(1)[Xj An Original
(2)||A Resubmission
INFORMATION ON FORMULA RATES
Date of Report
(Mo,Da,Yr)
04/14/2020
Year/Period of Report
End of 2019/Q4
FERC Rate Schedule/Tariff Number FERC Proceeding
Does the respondent have formula rates?PX]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
FERC Electric Tariff1
2
3
4
5
6
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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)
04/14/2020
Year/Period of Report
End of 2019/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)?
f"X]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.Docket No.Description
1 20190828-5141 08/28/0019 ER09-1641-000 Idaho Power Company FERC Electric Tariff
2 2019 Annua
3 Informational Filinc
4 under ER09-1641-OOC
5
6
7
8
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FERC FORM NO.1 (NEW.12-08)Page 106a
This Page Intentionally Left Blank
Name of Respondent
Idaho Power Company
This Report Is:
(1)[X]An Original
(2)| |A Resubmission
Date of Report
(Mo,Da,Yr)
04/14/2020
Year/Period of Report
Endof 2019/Q4
INFORMATION ON FORMULA RATES
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 Page No(s).Schedule Column Line No
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FERC FORM NO.1 (NEW.12-08)Page 106b
Date of Report
04/14/2020
Name of Respondent
Idaho Power Company
This Report Is:
(1)[X] An Original
(2)A Resubmission
Year/Period of Report
End of 2019/Q4
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 11 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
Name of Respondent Date of Report Year/Period of Report
(Mo,Da,Yr)
04/14/2020
This Report is:
(1)X An Original
(2)_A ResubmissionIdahoPowerCompany 2019/Q4
IMPORTANT CHANGES DURING THE QUARTER/YEAR (Continued)
1 .None
2 .None
3 .None
4 .None
5 .None
6.In August 2019,Idaho Power purchased and remarketed two of its outstanding series of pollution control tax-exempt bonds,
one in the aggregate principal amount of $49.8 million issued in 2003 by Humboldt County,Nevada and due in 2024, and the
other in the aggregate principal amount of $116.3 million issued in 2006 by Sweetwater County,Wyoming and due in 2026.The
bonds were remarketed with substantially the same terms,but with lower term interest rates.In 2006,Idaho Power received
orders from the Idaho Public Utilities Commission,Oregon Public Utilities Commission,and Wyoming Public Service Commission
authorizing Idaho Power to change interest rate modes on each of the bonds at any time until the final maturity dates.
7.None
8.Effective 12/28/19,a 2.75%general wage adjustment was implemented.
9.None
10.None
11.Reserved
12.None
13.Officer Changes in 2019
•Darrel T.Anderson's title changed from "President and Chief Executive Officer of Idaho Power"to "Chief Executive Officer of
Idaho Power"effective October 1,2019.
•Lisa A.Grow's title changed from "Senior Vice President and Chief Operating Officer of Idaho Power "to "President of Idaho
Power"effective October 1,2019.
•Adam J.Richins1 title changed from "Vice President of Customer Operations and Business Development of Idaho Power"to
"Senior Vice President and Chief Operating Officer of Idaho Power"effective October 1,2019.
•Vern Porter's title changed from Vice President of Transmission and Distribution Engineering and Construction and Chief
Safety Officer of Idaho Power"to "Vice President of Idaho Power"effective October 1,2019.He retired as "Vice President
of Idaho Power"effective December 31,2019.
•Ryan N.Adelman was appointed "Vice President of Transmission and Distribution Engineering and Construction of Idaho
Power"effective October 1,2019.
•Bo D.Hanchey was appointed "Vice President of Customer Operations and Chief Safety Officer of Idaho Power"effective
October 1,2019.
•Debra Leithauser was appointed "Vice President of Corporate Services and Communications of Idaho Power"effective
October 1,2019.
•Sarah E.Griffin was appointed "Vice President of Human Resources of Idaho Power"effective October 1,2019.
•Jeff Glenn retired as "Vice President of Corporate Services and Chief Information Officer"effective October 1,2019.
14.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.
FERC FORM NO.1 (ED.12-96)Page 109.1
Name of Respondent
Idaho Power Company
Year/Period of ReportThisReportIs:Date of Report
(Mo,Da,Yr)
04/14/2020
(1)0 An Original
End Of 2019/Q4(2)Q A Resubmission
COMPARATIVE BALANCE SHEET (ASSETS AND OTHER DEBITS)
Current Year
End of Quarter/Year
Balance
Prior Year
End Balance
12/31
Line Ref.No.
Title of Account Page No.
(d)(a)(b)(c)
1 UTILITY PLANT
Utility Plant (101-106,114)2 200-201 6,117,438,884 6,108,607,184
Construction Work in Progress (107)3 200-201 552,498,787 480,258,675
4 TOTAL Utility Plant (Enter Total of lines 2 and 3)6,588,865,8596,669,937,671
(Less)Accum.Prov.for Depr.Amort.Depl.(108,110,111,115)5 200-201 2,341,467,978 2,394,578,627
Net Utility Plant (Enter Total of line 4 less 5)6 4,328,469,693 4,194,287,232
Nuclear Fuel in Process of Ref.,Conv.,Enrich.,and Fab.(120.1)202-203 0 07
8 Nuclear Fuel Materials and Assemblies-Stock Account (120.2)00
Nuclear Fuel Assemblies in Reactor (120.3)9 0 0
Spent Nuclear Fuel (120.4)10 0 0
11 Nuclear Fuel Under Capital Leases (120.6)0 0
12 (Less)Accum.Prov.for Amort,of Nucl.Fuel Assemblies (120.5)0202-203 0
Net Nuclear Fuel (Enter Total of lines 7-1 1 less 12)13 0 0
Net Utility Plant (Enter Total of lines 6 and 13)14 4,328,469,693 4,194,287,232
15 Utility Plant Adjustments (116)0 0
16 Gas Stored Underground -Noncurrent (117)0 0
17 OTHER PROPERTY AND INVESTMENTS
Nonutility Property (121)18 3,653,100 3,653,100
(Less)Accum.Prov.for Depr.and Amort.(122)19 0 0
20 Investments in Associated Companies (123)0 0
21 Investment in Subsidiary Companies (123.1)224-225 25,515,916 57,026,771
22 (For Cost of Account 123.1,See Footnote Page 224,line 42)
Noncurrent Portion of Allowances 023228-229 0
Other Investments (124)24 0 0
Sinking Funds (125)25 0 0
Depreciation Fund (126)26 0 0
27 Amortization Fund -Federal (127)0 0
28 Other Special Funds (128)42,737,920 36,487,611
29 Special Funds (Non Major Only)(129)0 0
Long-Term Portion of Derivative Assets (175)030 0
Long-Term Portion of Derivative Assets -Hedges (176)31 0 0
TOTAL Other Property and Investments (Lines 18-21 and 23-31)32 71 ,906,936 97,167,482
33 CURRENT AND ACCRUED ASSETS
34 Cash and Working Funds (Non-major Only)(130)0 0
35 Cash (131)72,428,510 86,225,120
Special Deposits (132-134)36 4,254,912 1,167,693
Working Fund (135)37 1 1 ,500 7,000
38 Temporary Cash Investments (136)26,510,194 79,228,007
39 Notes Receivable (141)-81 ,730 -84,743
40 Customer Accounts Receivable (142)79,182,40874,131,805
Other Accounts Receivable (143)41 13,107,045 6,330,066
42 (Less)Accum.Prov.for Uncollectible Acct.-Credit (144)1,744,072 1,989,131
43 Notes Receivable from Associated Companies (145)20,021,988 0
Accounts Receivable from Assoc.Companies (146)044 0
Fuel Stock (151)45 227 57,447,554 47,979,122
46 Fuel Stock Expenses Undistributed (152)227 0 0
47 Residuals (Elec)and Extracted Products (153)227 0 0
48 Plant Materials and Operating Supplies (1 54)227 54,238,962 53,553,674
Merchandise (155)227 049 0
Other Materials and Supplies (156)50 227 0 0
Nuclear Materials Held for Sale (157)202-203/22751 0 0
Allowances (158.1 and 158.2)52 228-229 0 0
FERC FORM NO.1 (REV.12-03)Page 110
Name of Respondent
Idaho Power Company
This Report Is:Year/Period of ReportDateofReport
(Mo,Da,Yr)
04/14/2020
(1)(X)An Original
End of 2019/04(2)A Resubmission
COMPARATIVE BALANCE SHEET (ASSETS AND OTHER DEBITS()Continued)
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)
(Less)Noncurrent Portion of Allowances53 0 0
Stores Expense Undistributed (163)54 227 2,420,600 1,433,652
Gas Stored Underground -Current (164.1)55 0 0
56 Liquefied Natural Gas Stored and Held for Processing (164.2-164.3)0 0
Prepayments (165)57 17,520,138 16,373,874
Advances for Gas (166-167)58 0 0
59 Interest and Dividends Receivable (171)169,371 56,822
60 Rents Receivable (172)0 0
61 Accrued Utility Revenues (173)64,545,373 69,318,168
62 Miscellaneous Current and Accrued Assets (174)0 0
63 Derivative Instrument Assets (175)404,917 3,655,138
64 (Less)Long-Term Portion of Derivative Instrument Assets (175)0 0
65 Derivative Instrument Assets -Hedges (176)0 0
(Less)Long-Term Portion of Derivative Instrument Assets -Hedges (17666 0 0
67 Total Current and Accrued Assets (Lines 34 through 66)405,387,067 442,436,870
68 DEFERRED DEBITS
69 Unamortized Debt Expenses (181)14,384,541 15,958,660
70 Extraordinary Property Losses (182.1)230a 0 0
Unrecovered Plant and Regulatory Study Costs (182.2)71 230b 0 0
Other Regulatory Assets (182.3)72 232 1,383,059,324 1,214,174,417
73 Prelim.Survey and Investigation Charges (Electric)(183)0 0
74 Preliminary Natural Gas Survey and Investigation Charges 183.1)0 0
Other Preliminary Survey and Investigation Charges (183.2)75 0 0
76 Clearing Accounts (184)2,111,199 2,005,924
Temporary Facilities (185)77 0 0
Miscellaneous Deferred Debits (186)78 233 71,312,712 73,405,043
Def.Losses from Disposition of Utility Pit.(187)79 0 0
80 Research,Devel.and Demonstration Expend.(188)352-353 0 0
81 Unamortized Loss on Reaquired Debt (189)41,772,825 42,445,540
82 Accumulated Deferred Income Taxes (190)234 302,161,031 293,383,262
83 Unrecovered Purchased Gas Costs (191)0 0
84 Total Deferred Debits (lines 69 through 83)1,814,801,632 1,641,372,846
TOTAL ASSETS (lines 14-16,32,67,and 84)85 6,620,565,328 6,375,264,430
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)
04/14/2020
Year/Period of Report
2019/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)
1 PROPRIETARY CAPITAL
2 Common Stock Issued (201)250-251 97,877,030 97,877,030
3 Preferred Stock Issued (204)250-251 0 0
Capital Stock Subscribed (202,205)4 0 0
5 Stock Liability for Conversion (203,206)0 0
6 Premium on Capital Stock (207)712,257,435 712,257,435
Other Paid-in Capital (208-211)7 253 0 0
8 Installments Received on Capital Stock (212)252 0 0
(Less)Discount on Capital Stock (213)9 254 0 0
10 (Less)Capital Stock Expense (214)254b 2,096,925 2,096,925
11 Retained Earnings (215,215.1,216)118-119 1,480,751,865 1,354,681,706
12 Unappropriated Undistributed Subsidiary Earnings (216.1)118-119 23,052,822 54,563,677
(Less)Reaquired Capital Stock (217)13 250-251 0 0
14 Noncorporate Proprietorship (Non-major only)(218)0 0
15 Accumulated Other Comprehensive Income (219)122(a)(b)-36,283,823 -22,843,785
16 Total Proprietary Capital (lines 2 through 15)2,275,558,404 2,194,439,138
LONG-TERM DEBT17
18 Bonds (221)256-257 1,835,460,000 1,835,460,000
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 19,885,000 19,885,000
22 Unamortized Premium on Long-Term Debt (225)0 0
(Less)Unamortized Discount on Long-Term Debt-Debit (226)23 4,301,181 4,598,059
24 Total Long-Term Debt (lines 18 through 23)1,851,043,819 1,850,746,941
OTHER NONCURRENT LIABILITIES25
26 Obligations Under Capital Leases -Noncurrent (227)0 0
27 Accumulated Provision for Property Insurance (228.1)0 0
28 Accumulated Provision for Injuries and Damages (228.2)1,748,351 1,811,302
29 Accumulated Provision for Pensions and Benefits (228.3)519,659,093 431,492,131
30 Accumulated Miscellaneous Operating Provisions (228.4)0 0
31 Accumulated Provision for Rate Refunds (229)152,686,978 136,505,890
32 Long-Term Portion of Derivative Instrument Liabilities 23,995 63,744
33 Long-Term Portion of Derivative Instrument Liabilities -Hedges 0 0
34 Asset Retirement Obligations (230)28,191,027 26,791,608
35 Total Other Noncurrent Liabilities (lines 26 through 34)702,309,444 596,664,675
CURRENT AND ACCRUED LIABILITIES36
37 Notes Payable (231 )0 0
38 Accounts Payable (232)134,005,122 134,836,251
39 Notes Payable to Associated Companies (233)0 4,552,447
40 Accounts Payable to Associated Companies (234)2,053,220 2,088,345
Customer Deposits (235)41 1,070,057 1,342,506
42 Taxes Accrued (236)262-263 2,114,255 1,306,621
43 Interest Accrued (237)21,222,675 23,857,084
44 Dividends Declared (238)0 0
45 Matured Long-Term Debt (239)0 0
FERC FORM NO.1 (rev.12-03)Page 112
Name of Respondent
Idaho Power Company
This Report is:
(1)[x]An Original
(2)A Resubmission
Date of Report
(mo,da,yr)
04/14/2020
Year/Period of Report
2019/Q4endof
COMPARATIVE BALANCE SHEET (LIABILITIES AND OTHER CREDIT&)itinued)
Current Year
End of Quarter/Year
Balance
Prior YearLineRef.End Balance
12/31
No.
Title of Account Page No.
(a)(b)(c)(d)
46 Matured Interest (240)0 0
47 Tax Collections Payable (241 )2,682,810 2,224,148
48 Miscellaneous Current and Accrued Liabilities (242)68,348,276 56,428,043
Obligations Under Capital Leases-Current (243)49 0 0
50 Derivative Instrument Liabilities (244)846,256 974,268
51 (Less)Long-Term Portion of Derivative Instrument Liabilities 23,995 63,744
52 Derivative Instrument Liabilities -Hedges (245)0 0
53 (Less)Long-Term Portion of Derivative Instrument Liabilities-Hedges 0 0
54 Total Current and Accrued Liabilities (lines 37 through 53)232,318,676 227,545,969
55 DEFERRED CREDITS
56 Customer Advances for Construction (252)6,011,590 5,156,242
57 Accumulated Deferred Investment Tax Credits (255)266-267 94,805,870 92,789,836
Deferred Gains from Disposition of Utility Plant (256)58 0 0
59 Other Deferred Credits (253)269 8,035,785 8,306,007
60 Other Regulatory Liabilities (254)278 349,006,644 351,782,980
61 Unamortized Gain on Reaquired Debt (257)0 0
Accum.Deferred Income Taxes-Accel.Amort.(281)62 272-277 0 0
63 Accum.Deferred Income Taxes-Other Property (282)933,469,366 908,615,099
64 Accum.Deferred Income Taxes-Other (283)168,005,730 139,217,543
65 Total Deferred Credits (lines 56 through 64)1 ,559,334,985 1,505,867,707
66 TOTAL LIABILITIES AND STOCKHOLDER EQUITY (lines 16,24, 35,54 and 65)6,620,565,328 6,375,264,430
FERC FORM NO.1 (rev.12-03)Page 113
Date of Report
(Mo,Da,Yr)
04/14/2020
Year/Period of Report
End of
Name of Respondent
Idaho Power Company
This Report Is:
(1)fx]An Original
(2)||AResubmissi
2019/Q4
on
STATEMENT OF INCOME
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.
Total
Current Year to
Date Balance for
Quarter/Year
Total
PriorYear to
Date Balance for
Quarter/Year
Current 3 Months
Ended
Quarterly Only
No 4th Quarter
Prior 3 Months
Ended
Quarterly Only
No 4th Quarter
Line
No.
(Ref.)
Page No.Title of Account
(e)(f)(a)(b)(c)(d)
1 UTILITY OPERATING INCOME
2 Operating Revenues (400)300-301 1,343,223,427 1,361,957,450
3 Operating Expenses
4 Operation Expenses (401)320-323 774,637,775 800,135,259
5 Maintenance Expenses (402)320-323 65,021,961 69,035,321
6 Depreciation Expense (403)336-337 160,145,693 156,332,587
7 Depreciation Expense forAsset Retirement Costs (403.1 )336-337 566,665 566,665
8 Amort.&Depl.of Utility Plant (404-405)336-337 7,169,554 6,981,078
9 Amort,of Utility PlantAcq.Adj.(406)336-337 15,018 15,018
10 Amort.Property Losses,Unrecov Plant and Regulatory Study Costs (407)
1 1 Amort,ofConversion Expenses (407)
12 Regulatory Debits (407.3)8,730,518 6,802,055
13 (Less)Regulatory Credits (407.4)3,221,217 2,167,344
1 4 Taxes OtherThan Income Taxes (408.1)262-263 34,045,010 34,792,143
15 Income Taxes -Federal (409.1)262-263 18,660,529 20,035,445
16 -Other(409.1)262-263 -4,663,949 -2,242,797
1 7 Provision forDeferred Income Taxes (410.1)234,272-277 25,440,561 37,060,319
18 (Less)Provision for Deferred Income Taxes-Cr.(411.1)234,272-277 15,033,334 44,435,246
19 InvestmentTax Credit Adj.-Net (41 1.4)266 2,016,034 5,405,098
20 (Less)Gains from Disp.of Utility Plant (411 .6)
21 Losses from Disp.of Utility Plant (41 1 .7)
22 (Less)Gains from Disposition of Allowances (41 1.8)284,504 154,940
23 Losses from Disposition of Allowances (41 1.9)
24 Accretion Expense (41 1.10)232,951 227,740
25 TOTAL Utility Operating Expenses (EnterTotal of lines 4 thru 24)1,073,479,265 1,088,388,401
26 Net Util Oper Inc (Enter Tot line 2 less 25)Carry to Pg1 17,line 27 269,744,162 273,569,049
FERC FORM NO.1/3-Q (REV.02-04)Page 114
This Report Is:
(1)[x]An Original
(2)| |A Resubmission
STATEMENT OF INCOME FOR THE YEAR (Continued)
Date of Report
(Mo.Da,Yr)
04/14/2020
Year/Period of Report
End of
Name of Respondent
Idaho Power Company 2019/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.
1 3.Enter on page 1 22 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.
ELECTRIC UTILITY GAS UTILITY OTHER UTILITY
LinePreviousYeartoDate
(in dollars)
Current Year to Date
(in dollars)
CurrentYear to Date
(in dollars)
Previous Year to Date
(in dollars)
Current Year to Date
(In dollars)
Previous Year to Date
(in dollars)No.
(9)(h)(i)0)(k)(I)
1
1,343,223,427 1,361,957,450 2
3
774,637,775 800,135,259 4
65,021,961 69,035,321 5
160,145,693 156,332,587 6
566,665 566,665 7
7,169,554 6,981,078 8
15,018 15,018 9
10
11
8,730,518 6,802,055 12
3,221,217 2,167,344 13
34,045,010 34,792,143 14
18,660,529 20,035,445 15
-4,663,949 -2,242,797 16
25,440,561 37,060,319 17
15,033,334 44,435,246 18
2,016,034 5,405,098 19
20
21
284,504 154,940 22
23
232,951 227,740 24
1,073,479,265 1,088,388,401 25
269,744,162 273,569,049 26
FERC FORM NO.1 (ED.12-96)Page 115
This Page Intentionally Left Blank
Name of Respondent
Idaho Power Company
This Report Is:
(1)[X|An Original
(2)||A Resubmission
STATEMENT OF INCOME FOR THE YEAR (continued)
Date of Report
(Mo,Da,Yr)
04/14/2020
Year/Period of Report
End of 2019/Q4
Current 3 Months
Ended
Quarterly Only
No 4th Quarter
Prior 3 Months
Ended
Quarterly Only
No 4th Quarter
Line TOTAL
No.
(Ref.)
Page No.Title of Account Current Year Previous Year
(a)(b)(c)(e)(f)(d)
27 Net Utility Operating Income (Carried forward from page 114)269,744,162 273,569,049
28 Other Income and Deductions
29 Other Income
30 Nonutilty Operating Income
31 Revenues From Merchandising,Jobbing and Contract Work (415)3,913,358 3,971,967
32 (Less)Costs and Exp,of Merchandising,Job.&Contract Work (416)4,427,209 4,003,151
33 Revenues From Nonutility Operations (417)22,503 25,046.
34 (Less)Expenses of Nonutility Operations (417.1)30,125 12,425
35 Nonoperating Rental Income (418)-53,401 -3,351
36 Equity in Earnings ofSubsidiary Companies (418.1)119 8,489,145 8,813,793
37 Interest and Dividend Income (419)10,967,595 8,923,003
38 Allowance for Other Funds Used During Construction (419.1)27,112,279 24,352,523
39 Miscellaneous Nonoperating Income (421)435,869 79,416
40 Gain on Disposition of Property (421.1)264,632
41 TOTAL Other Income (EnterTotal of lines 31 thru 40)46,430,014 42,411,453
42 Other Income Deductions
43 Loss on Disposition of Property (421 .2)48,950
44 Miscellaneous Amortization (425)
45 Donations (426.1)824,587 811,136
46 Life Insurance (426.2)4,104,372 -2,779,387
47 Penalties (426.3)56,757 40,155
48 Exp,forCertain Civic,Political &Related Activities (426.4)1,039,769 1,203,610
49 Other Deductions (426.5)7,283,056 7,820,081
50 TOTAL Other Income Deductions (Total of lines 43 thru 49)5,099,797 7,144,545
51 Taxes Applic.to Other Income and Deductions
52 Taxes OtherThan Income Taxes (408.2)262-263 23,370 19,680
53 Income Taxes-Federal (409.2)262-263 893,117 627,071
54 Income Taxes-Other (409.2)262-263 271,449 193,942
55 Provision for Deferred Inc.Taxes (410.2)234,272-277 261,6017
56 (Less)Provision for Deferred Income Taxes-Cr.(411.2)234,272-277 1,250,246 770,831
57 Investment Tax Credit Adj.-Net (41 1 .5)
58 (Less)Investment Tax Credits (420)
59 TOTAL Taxes on Other Income and Deductions (Total of lines 52-58)-62,303 331,463
60 Net Other Income and Deductions (Total of lines 41 ,50,59)41,392,520 34,935,445
61 Interest Charges
62 Interest on Long-Term Debt (427)82,457,050 84,407,634
63 Amort,of Debt Disc,and Expense (428)1,318,427 1,606,787
64 Amortization of Loss on Reaquired Debt (428.1)2,530,546 2,152,952
65 (Less)Amort,of Premium on Debt-Credit (429)
66 (Less)Amortization of Gain on Reaquired Debt-Credit (429.1)
67 Interest on Debt to Assoc.Companies (430)287,350 279,757
68 Other Interest Expense (431 )10,809,334 7,874,386
69 (Less)Allowance for Borrowed Funds Used During Construction-Cr.(432)10,702,847 10,151,313
70 Net Interest Charges (Total oflines 62 thru 69)86,699,860 86,170,203
71 Income Before Extraordinary Items (Total of lines 27,60 and 70)224,436,822 222,334,291
72 Extraordinary Items
73 Extraordinary Income (434)
74 (Less)Extraordinary Deductions (435)
75 Net Extraordinary Items (Total of line 73 less line 74)
76 Income Taxes-Federal and Other (409.3)262-263
77 Extraordinary Items After Taxes (line 75 less line 76)
78 Net Income (Total of line 71 and 77)224,436,822 222,334,291
FERC FORM NO.1/3-Q (REV.02-04)Page 117
Name of Respondent
Idaho Power Company
This Report Is:
(1)pgAn Original
(2)| |A Resubmission
STATEMENT OF RETAINED EARNINGS
Date of Report
(Mo,Da,Yr)
04/14/2020
Year/Period of Report
End of 2019/Q4
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
No.(a)(b)(c)(d)
UNAPPROPRIATED RETAINED EARNINGS (Account 216)
1,221,586,6211Balance-Beginning of Period 1,341,408,600
2 Changes
3 Adjustments to Retained Earnings (Account 439)
4,092,2084BenefitPlanTaxReformAdjustment
5
6
7
8
4,092,2089TOTALCreditstoRetainedEarnings(Acct.439)
10
11
12
13
14
15 TOTAL Debits to Retained Earnings (Acct.439)
213,520,49816BalanceTransferredfromIncome(Account 433 less Account 418.1)215,947,677
1 7 Appropriations of Retained Earnings (Acct.436)
18
19
20
21
22 TOTAL Appropriations of Retained Earnings (Acct.436)
23 Dividends Declared-Preferred Stock (Account 437)
24
25
26
27
28
29 TOTAL Dividends Declared-Preferred Stock (Acct.437)
30 Dividends Declared-Common Stock (Account 438)
(121,790,727)31 -129,877,518
32
33
34
35
(121,790,727)36 TOTAL Dividends Declared-Common Stock (Acct.438)-129,877,518
24,000,00037TransfersfromAcct216.1,Unapprop.Undistrib.Subsidiary Earnings 40,000,000
1,341,408,60038Balance-End of Period (Total 1,9,15,16,22,29,36,37)1,467,478,759
APPROPRIATED RETAINED EARNINGS (Account 215)
FERC FORM NO.1/3-Q (REV.02-04)Page 118
Name of Respondent
Idaho Power Company
This Report Is:
(1)[X]An Original
(2)| |A Resubmission
STATEMENT OF RETAINED EARNINGS
Date of Report
(Mo,Da,Yr)
04/14/2020
Year/Period of Report
End of 2019/Q4
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
No.(a)(b)(c)(d)
39
40
41
42
43
44
45 TOTAL Appropriated Retained Earnings (Account 215)
APPROP.RETAINED EARNINGS -AMORT.Reserve,Federal (Account 215.1)
46 TOTAL Approp.Retained Earnings-Amort.Reserve,Federal (Acct.215.1)13,273,10613,273,106
47 TOTAL Approp.Retained Earnings (Acct.215,215.1)(Total 45,46)13,273,10613,273,106
48 TOTAL Retained Earnings (Acct.215,215.1,216)(Total 38,47)(216.1)1,354,681,7061,480,751,865
UNAPPROPRIATED UNDISTRIBUTED SUBSIDIARY EARNINGS (Account
Report only on an Annual Basis,no Quarterly
49 Balance-Beginning of Year (Debit or Credit)69,749,88454,563,677
50 Equity in Earnings for Year (Credit)(Account 418.1)8,813,7938,489,145
51 (Less)Dividends Received (Debit)24,000,00040,000,000
52
53 Balance-End of Year (Total lines 49 thru 52)54,563,67723,052,822
FERC FORM NO.1/3-Q (REV.02-04)Page 119
This Report Is:
(1)[X]An Original
(2)| |A Resubmission
Name of Respondent
Idaho Power Company
Date of Report
(Mo,Da,Yr)
04/14/2020
Year/Period of Report
End of 2019/Q4
STATEMENT OF CASH FLOWS
(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 ofleases capitalized per the USofA General Instruction 20;instead provide a reconciliation of the
dollaramount 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:
2 Net Income (Line 78(c)on page 1 1 7)224,436,822 222,334,291
[3 Noncash Charges (Credits)to Income:
4 Depreciation and Depletion 160,712,358 1
12,492.435
156,332,587
5 Amortization of 12,186,464
6
7
8 Deferred Income Taxes (Net)17,892,072 -1,689,885
9 Investment Tax Credit Adjustment (Net)698,798 1,496,757
10 Net (Increase)Decrease in Receivables -4,934,190 633,606
11 Net (Increase)Decrease in Inventory -11,114,312 9,463,201
12 Net (Increase)Decrease in Allowances Inventory
13 Net Increase (Decrease)in Payables and Accrued Expenses -8.690,771 -9,272,216
14 Net (Increase)Decrease in Other Regulatory Assets -19,029,252 30,090,539
15 Net Increase (Decrease)in Other Regulatory Liabilities 14,719,412 18,301,367
16 (Less)Allowance for Other Funds Used During Construction 27.112,279 24,352,523
17 (Less)Undistributed Earnings from Subsidiary Companies -6,936,420 -15,186,207
18 Other (provide details in footnote):-23,495.357 -12,704,289
19
20
21
22 Net Cash Provided by (Used in)Operating Activities (Total 2 thru 21)343,512,156 418,006,106
23
24 Cash Flows from Investment Activities:
25 Construction and Acquisition of Plant (including land):
26 Gross Additions to Utility Plant (less nuclear fuel)-305,819,097 -302,175,811
27 Gross Additions to Nuclear Fuel
28 Gross Additions to Common Utility Plant
29 Gross Additions to Nonutility Plant
30 (Less)Allowance for Other Funds Used During Construction -27,112,279 -24,352,523
31 Other (provide details in footnote):6.561,916 25,112,774
32
33
34 Cash Outflows for Plant (Total of lines 26 thru 33)-272,144,902 -252,710,514
35
36 Acquisition of Other Noncurrent Assets (d)
37 Proceeds from Disposal of Noncurrent Assets (d)
38
39 Investments in and Advances to Assoc.and Subsidiary Companies -3,013 -1,655
40 Contributions and Advances from Assoc.and Subsidiary Companies 469,143
41 Disposition of Investments in (and Advances to)
42 Associated and Subsidiary Companies
43
44 Purchase of Investment Securities (a)-10,896,289 -11,390,307
45 Proceeds from Sales of Investment Securities (a)5,080,351 5,007,519
FERC FORM NO.1 (ED.12-96)Page 120
Date of Report
(Mo,Da,Yr)
04/14/2020
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
2019/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 ofamount 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)
46 Loans Made or Purchased
47 Collections on Loans
48
49 Net (Increase)Decrease in Receivables
50 Net (Increase )Decrease in Inventory
51 Net (Increase)Decrease in Allowances Held for Speculation
52 Net Increase (Decrease)in Payables and Accrued Expenses
53 Other (provide details in footnote):795,456
54
55
I56NetCashProvidedby(Used in)Investing Activities
57 Total of lines 34 thru 55)-277,963,853 -257,830,358
58
59 Cash Flows from Financing Activities:
60 Proceeds from Issuance of:
61 Long-Term Debt (b)166,100,000 220,000,000
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)166,100,000 220,000,000
71
72 Payments for Retirement of:
73 Long-term Debt (b)-166,100,000 -130,000,000
74 Preferred Stock
75 Common Stock
-2.180,70876Other(provide details in footnote):-7,570,541
77
78 Net Decrease in Short-Term Debt (c)
79
80 Dividends on Preferred Stock
81 Dividends on Common Stock -129,877,518 -121,790,727
82 Net Cash Provided by (Used in)Financing Activities
83 (Total of lines 70 thru 81)-132,058,226 -39,361,268
84
85 Net Increase (Decrease)in Cash and Cash Equivalents
86 (Total of lines 22,57 and 83)-66,509,923 120,814,480
87
88 Cash and Cash Equivalents at Beginning of Period 165,460,127 44,645,647
89
90 Cash and Cash Equivalents at End of period 98,950,204 165,460,127
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
(2)_A Resubmission
(Mo,Da,Yr)
Idaho Power Company 04/14/2020 2019/Q4
FOOTNOTE DATA
Schedule Page:120 Line No.:5 Column:b
Amortization
Plant
Unamortized debt expense
Unamortized discount
7.134 572
3,397,301
296,879
1.042,009
71,674
Water rights
Other
12,492,435
Schedule Page:120 Line No.:13 Column:b
Cash (received)paid during the period for:
Income taxes
Interest (net of amount capitalized)
\Schedule Page:120 Line No.:18 Column:b
Cash Flow from Operating Activities (Other)
15,544,584
85,197,945
Pension and postretirement benefit plan expense
Contributions to pension and postretirement benefit plans
Changes in unbilled revenues
Accrued interest
27.787.890
(43.508 380)
4.733,664
(2.634.409)
(2,490 337)
(2,433.285)
(23,495,357)
Changes in prepayments
Other
Schedule Page:120 Line No.:26 Column:b
Non-cash investing activities:
Additions to PP&E in accounts payable
Schedule Page:120 Line No.:31 Column:b
Other Cash Flows from Plant
38,815,004
Payments received from joint funding partners
Sale of renewable energy certificates and emission allowances
2,442,204
4,119,712
6,561,916
Schedule Page:120 Line No.:76 Column:b
Other Financing Cash Flows
Debt issuance costs
Discount on debt issuance
(2,180,708)
(2,180,708)
FERC FORM NO.1 (ED.12-87)Page 450.1
Date of Report
(Mo.Da,Yr)
04/14/2020
Name of Respondent
Idaho Power Company
This Report Is:
(1)[X]An Original
(2)Q A Resubmission
STATEMENTS OF ACCUMULATED COMPREHENSIVE INCOME,COMPREHENSIVE INCOME,AND HEDGING ACTIVITIES
Year/Period of Report
End of 2019/Q4
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.
Item Unrealized Gains and
Losses on Available-
for-Sale Securities
Minimum Pension
Liability adjustment
(net amount)
Foreign Currency
Hedges
Other
Adjustments
Line
No.
(a)(b)(c)(d)(e)
1 Balance of Account 219 at Beginning of
Preceding Year (26,872,209)
2 Preceding Qtr/Yr to Date Reclassifications
from Acct 219 to Net Income 2,885,872
3 Preceding Quarter/Year to Date Changes in
Fair Value 1,142,552
4 Total (lines 2 and 3)4,028,424
5 Balance of Account 219 at End of
Preceding Quarter/Year (22,843,785)
6 Balance of Account 219 at Beginning of
Current Year (22,843,785)
7 Current Qtr/Yr to Date Reclassifications
from Acct 219 to Net Income 1 ,952,226
8 Current Quarter/Year to Date Changes in
Fair Value (15,392,264)
9 Total (lines 7 and 8)(13,440,038)
10 Balance of Account 219 at End of Current
Quarter/Year (36,283,823)
FERC FORM NO.1 (NEW 06-02)Page 122a
Name of Respondent
Idaho Power Company
This Report Is:
(1)[X]An Original
(2)Q A Resubmission
STATEMENTS OF ACCUMULATED COMPREHENSIVE INCOME,COMPREHENSIVE INCOME,AND HEDGING ACTIVITIES
Date of Report
(Mo,Da,Yr)
04/14/2020
Year/Period of Report
End of 2019/Q4
Totals for each
category of items
recorded in
Account 219
Net Income (Carried
Forward from
Page 117,Line 78)
Total
Comprehensive
Income
Other Cash Flow
Hedges
Interest Rate Swaps
Other Cash Flow
Hedges
[Insert Footnote at Line 1
to specify]
Line
No.
(h)(i)G)(f)(g)
1 (26,872,209)
2 2,885,872
3 1,142,552
4 4,028,424 222,334,291 226,362,715
5 (22,843,785)
6 (22,843,785)
7 1,952,226
8 (15,392,264)
9 (13,440,038)224,436,822 210,996,784
10 (36,283,823)
FERC FORM NO.1 (NEW 06-02)Page 122b
Date of Report Year/Period of Report
End of 2019/Q4
Name of Respondent
Idaho Power Company
This Report Is:
(1)[X] An Original
(2)Q A Resubmission 04/14/2020
NOTES TO FINANCIAL STATEMENTS
1 .Use the space below for important notes regarding the Balance Sheet,Statement of Income for the year,Statement of Retained
Earnings for the year,and Statement of Cash Flows,or any account thereof.Classify the notes according to each basic statement,
providing a subheading for each statement except where a note is applicable to more than one statement.
2.Furnish particulars (details)as to any significant contingent assets or liabilities existing at end of year,including a brief explanation of
any action initiated by the Internal Revenue Service 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 1 16,Utility Plant Adjustments,explain the origin of such amount,debits and credits during the year,and plan of
disposition contemplated,giving references to Cormmission orders or other authorizations respecting classification of amounts as plant
adjustments and requirements as to disposition thereof.
4.Where Accounts 189,Unamortized Loss on Reacquired Debt,and 257,Unamortized Gain on Reacquired Debt,are not used,give
an explanation,providing the rate treatment given these items.See General Instruction 17 of the Uniform System of Accounts.
5.Give a concise explanation of any retained earnings restrictions and state the amount of retained earnings affected by such
restrictions.
6.If the notes to financial statements relating to the respondent company appearing in the annual report to the stockholders are
applicable and furnish the data required by instructions above and on pages 114-121,such notes may be included herein.
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
IDAHO POWER COMPANY
NOTES TO FINANCIAL STATEMENTS
1. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
Idaho Power Company (Idaho Power) is the principal operating subsidiary of IDACORP, Inc. (IDACORP), a holding company
formed in 1998. Idaho Power is an electric utility engaged in the generation, transmission, distribution, sales, and purchase of electric
energy and capacity with a service area covering approximately 24,000 square miles in southern Idaho and eastern Oregon. Idaho
Power is regulated primarily by the state utility regulatory commissions of Idaho and Oregon and the Federal Energy Regulatory
Commission (FERC). 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 (Jim Bridger 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 of accounting 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 of the utility plant and related operations resulting from
its interest in jointly-owned plants. In addition, under the requirements of the FERC, there are differences from U.S. GAAP in the
presentation of (1) current portion of long-term debt, (2) assets and liabilities for cost of removal of assets, (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 financial statements in conformity with generally accepted accounting
principles. These estimates and assumptions include those related to rate regulation, retirement benefits, contingencies, 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 of the 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. Accordingly, actual results could differ from those
estimates.
Regulation of Utility Operations
As a regulated utility, many of Idaho Power's fundamental business decisions are subject to the approval of governmental 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 meets the requirements under accounting principles generally accepted in the United States of America to prepare its
financial statements applying the specialized rules to account for the effects of cost-based rate regulation. Idaho Power’s financial
statements reflect the effects of the different ratemaking principles followed by the jurisdictions regulating Idaho Power. Accounting
for the economics of rate regulation impacts multiple financial statement line items and disclosures, such as property, plant, and
Name of Respondent
Idaho Power Company
This Report is:
(1) X An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
04/14/2020
Year/Period of Report
2019/Q4
NOTES TO FINANCIAL STATEMENTS (Continued)
FERC FORM NO. 1 (ED. 12-88)Page 123.1
equipment; regulatory assets and liabilities; operating revenues; operation and maintenance expense; depreciation expense; and
income tax expense. 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.
In these instances, the amounts are deferred or accrued as regulatory assets or regulatory liabilities on the balance sheet. 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 effects of applying these regulatory accounting principles to Idaho Power’s
operations are discussed in more detail in Note 3 - "Regulatory Matters."
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 of Idaho, Oregon, and Wyoming.
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 per month 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 of accounts receivable, and an
analysis of specific customer accounts. Adjustments are charged to income. Customer accounts receivable balances that remain
outstanding after reasonable collection efforts are written off.
Other receivables are also reviewed for impairment periodically, based upon transaction-specific facts. When it is probable Idaho
Power will be unable to collect all amounts due according to the contractual terms of the agreement, an allowance is established for
the estimated uncollectible portion of the receivable and charged to income.
There were no impaired receivables without related allowances at December 31, 2019 and 2018. 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 of natural 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.
Name of Respondent
Idaho Power Company
This Report is:
(1) X An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
04/14/2020
Year/Period of Report
2019/Q4
NOTES TO FINANCIAL STATEMENTS (Continued)
FERC FORM NO. 1 (ED. 12-88)Page 123.2
Revenues
Operating revenues are generally 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. Idaho Power does not report any
collections of franchise fees and similar taxes related to energy consumption on the income statement. In addition, regulatory
mechanisms in place in Idaho and Oregon affect the reported amount of revenue. The effects of applying these regulatory mechanisms
are discussed in more detail in Note 4 - "Revenues."
Property, Plant and Equipment and Depreciation
The cost of utility plant in service represents the original cost of contracted services, direct labor and material, allowance for funds
used during construction (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
of property and replacements and renewals of 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 of average depreciable utility plant in service approximated 2.9 percent in 2019 and 2.8 percent in
2018.
During the period of construction, costs expected to be included in the final value of the 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. If the
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
2019 or 2018.
Allowance for Funds Used During Construction
AFUDC represents the cost of financing construction projects with borrowed funds and equity funds. With one exception, for the
Hells Canyon Complex (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 of AFUDC 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 2019 and 2018.
Income Taxes
Idaho Power accounts for income taxes under the asset and liability method, which requires the recognition of deferred tax assets and
Name of Respondent
Idaho Power Company
This Report is:
(1) X An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
04/14/2020
Year/Period of Report
2019/Q4
NOTES TO FINANCIAL STATEMENTS (Continued)
FERC FORM NO. 1 (ED. 12-88)Page 123.3
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 of the 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 of the effect of the change in tax rates over a longer period of time.
Consistent with orders and directives of the IPUC, unless contrary to applicable income tax guidance, Idaho Power does not record
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. Idaho Power recognizes 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.
Idaho Power uses judgment, estimation, and historical data in developing the provision for income taxes and the reporting of
tax-related assets and liabilities, including development of current year tax depreciation, capitalized repair costs, capitalized
overheads, and other items. Income taxes can be impacted by changes in tax laws and regulations, interpretations by taxing
authorities, changes to accounting guidance, and actions by federal or state public utility regulators. Actual income taxes could vary
from estimated amounts and may result in favorable or unfavorable impacts to net income, cash flows, and tax-related assets and
liabilities.
In compliance with the federal income tax requirements for the use of accelerated tax depreciation, Idaho Power records 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 recorded for other temporary differences unless accounted for using flow-through.
Investment tax credits earned on regulated assets are deferred and amortized to income over the estimated service lives of the related
properties.
Income taxes are discussed in more detail in Note 2 - "Income Taxes."
Other Accounting Policies
Debt discount, expense, and premium are deferred and amortized over the terms of the 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.
New and Recently Adopted Accounting Pronouncements
Recently Adopted Accounting Pronouncements
In February 2016, the FASB issued ASU 2016-02, Leases (Topic 842), intended to improve financial reporting on leasing
transactions. The ASU requires lessees to recognize a right-of-use asset and lease liability on the balance sheet for most leases. In
addition, the ASU revises the definition of a lease in regards to when an arrangement conveys the right to control the use of the
identified asset under the arrangement. Idaho Power adopted ASU 2016-02 on January 1, 2019. The adoption did not have a material
Name of Respondent
Idaho Power Company
This Report is:
(1) X An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
04/14/2020
Year/Period of Report
2019/Q4
NOTES TO FINANCIAL STATEMENTS (Continued)
FERC FORM NO. 1 (ED. 12-88)Page 123.4
impact on its financial statements. Idaho Power does not have material agreements that meet the definition of a lease under ASU
2016-02.
Recent Accounting Pronouncements Not Yet Adopted
In June 2016, the FASB issued ASU 2016-13, Financial Instruments—Credit Losses (Topic 326): Measurement of Credit Losses on
Financial Instruments, to provide financial statement users with more information about expected credit losses on financial
instruments. The ASU revises the incurred loss impairment methodology to reflect current expected credit losses and requires
consideration of a broader range of information to estimate credit losses. The new standard is effective for interim and annual
reporting periods beginning after December 15, 2019, with early adoption permitted. Idaho Power is finalizing the assessment of the
financial impacts of adoption, but does not believe that the adoption of ASU 2016-13 will have a material impact on its financial
statements.
In August 2018, the FASB issued ASU 2018-15, Intangibles—Goodwill and Other—Internal-Use Software (Subtopic 350-40):
Customer’s Accounting for Implementation Costs Incurred in a Cloud Computing Arrangement That Is a Service Contract, to provide
guidance on implementation costs incurred in a cloud computing arrangement that is a service contract. ASU 2018-15 aligns the
recognition of such implementation costs with the accounting for costs incurred to implement an internal-use software solution.
However, the balance sheet line item for presentation of capitalized implementation costs for a cloud arrangement that is a service
contract should be the same as that for the prepayment of fees related to the same arrangement, while capitalized implementation costs
for internal-use software solutions are often included in property, plant, and equipment as an intangible asset. The new standard is
effective for interim and annual reporting periods beginning after December 15, 2019, with early adoption permitted. Idaho Power is
finalizing the assessment of the financial impacts of adoption, but does not believe the adoption of ASU 2018-15 will have a material
impact on its financial statements.
Subsequent Events
Management has evaluated the impact of events occurring after December 31, 2019, up to February 20, 2020, the date that Idaho
Power Company’s U.S. GAAP financial statements were issued and has updated such evaluation for disclosure purposes through
April 14, 2020. These financial statements include all necessary adjustments and disclosures resulting from these evaluations.
Name of Respondent
Idaho Power Company
This Report is:
(1) X An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
04/14/2020
Year/Period of Report
2019/Q4
NOTES TO FINANCIAL STATEMENTS (Continued)
FERC FORM NO. 1 (ED. 12-88)Page 123.5
Name of Respondent
Idaho Power Company
This Report is:
(1) X An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
04/14/2020
Year/Period of Report
2019/Q4
NOTES TO FINANCIAL STATEMENTS (Continued)
FERC FORM NO. 1 (ED. 12-88)Page 123.6
IDACORP's tax allocation agreement provides that each member of its consolidated group compute its income taxes on a separate
company basis. Amounts payable or refundable are settled through IDACORP and are reported as taxes accrued or income taxes
receivable, respectively, on the consolidated balance sheets of Idaho Power. See Note 1 - "Summary of Significant Accounting
Name of Respondent
Idaho Power Company
This Report is:
(1) X An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
04/14/2020
Year/Period of Report
2019/Q4
NOTES TO FINANCIAL STATEMENTS (Continued)
FERC FORM NO. 1 (ED. 12-88)Page 123.7
Policies" for further discussion of accounting policies related to income taxes.
Uncertain Tax Positions
Idaho Power believes that it has no material income tax uncertainties for 2019 and prior tax years. Idaho Power recognizes interest
accrued related to unrecognized tax benefits as interest expense and penalties as other expense.
Idaho Power is subject to examination by its major tax jurisdictions - U.S. federal and the State of Idaho. The open tax years for
examination are 2019 for federal and 2016-2019 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 2019, the IRS completed its examination of the 2018 tax year with no unresolved
income tax issues.
Income Tax Reform
On December 22, 2017, the Tax Cuts and Jobs Act was signed into law, which significantly reformed the Internal Revenue Code of
1986, as amended. Effective January 1, 2018, the Tax Cuts and Jobs Act permanently lowers the corporate tax rate to 21 percent from
the existing maximum rate of 35 percent, provides for expanded bonus depreciation, limits the deductibility of interest expense,
eliminates the alternative minimum tax, repeals the manufacturing deduction, and imposes additional limitations on the deductibility
of executive compensation. Public utility companies, such as Idaho Power, retain the full deductibility of interest expense and are
excluded from the bonus depreciation provisions; however, traditional accelerated tax depreciation methods are still available.
Due to the enactment of the Tax Cuts and Jobs Act and following generally accepted accounting principles, at December 31, 2017,
Idaho Power remeasured all deferred income tax assets and liabilities. As shown in the table above, in 2018, a net tax benefit was
recognized for the remeasurement of deferred taxes for the adjustment of temporary differences as a result of IDACORP's 2017
consolidated income tax return filings.
The change in income tax law also reduced the deferred income tax liability for depreciation-related timing differences under the
normalized tax accounting method. As this reduction will flow back to customers in the future under the statutorily prescribed average
rate assumption method, it was recorded as a regulatory liability on the consolidated balance sheets. See Note 3 - "Regulatory
Matters" for more information.
On March 12, 2018, Idaho House Bill 463 was enacted which lowered the Idaho state corporate income tax rate from 7.4 percent to
6.925 percent effective January 1, 2018. The Idaho tax rate reduction did not have a material impact on Idaho Power's 2018 income
tax expense or deferred tax asset and liability balances.
Policy Statement PL 19-2-000 Disclosures
Idaho Power’s accumulated deferred income tax (ADIT) accounts (190, 282, 283) and income tax-related regulatory asset and liability
accounts (182.3 and 254) were adjusted for the impacts from the income tax reform described above. ADIT accounts were remeasured
by first recalculating deferred income tax balances by applying the new 21 percent statutory corporate tax rate to existing temporary
differences. The remeasured balances were then compared to the deferred income tax balances on Idaho Power’s books prior to
Name of Respondent
Idaho Power Company
This Report is:
(1) X An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
04/14/2020
Year/Period of Report
2019/Q4
NOTES TO FINANCIAL STATEMENTS (Continued)
FERC FORM NO. 1 (ED. 12-88)Page 123.8
income tax reform. The difference in the balances resulted in excess ADIT (254 account), no deficient ADIT, and a reduction to Idaho
Power’s regulatory asset (182.3 account) for flow-through income tax accounting differences and regulatory liability for investment
tax credits (254 account). All of Idaho Power’s excess ADIT is protected. Unprotected temporary differences were either subject to
either Idaho Power’s flow-through regulatory income tax accounting method or the remeasured amounts were immaterial.
The following table presents the activity of Idaho Power’s regulatory liability for excess deferred income taxes (in thousands of
dollars):
Idaho Power’s protected excess ADIT will be returned through rates as the underlying temporary differences reverse using the
statutorily prescribed Average Rate Assumption Method (ARAM). The amortization of excess ADIT will be recorded in account
411.1. The excess ADIT will be included in rates for both rate base (254 account balance) and cost of service (annual amortization
pursuant to ARAM) when future general rate cases are filed for state regulatory jurisdictions and beginning with Idaho Power’s 2019
formula rate filing for FERC purposes.
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 some expenses
and revenues in a different period than when an unregulated enterprise would record those 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.
Name of Respondent
Idaho Power Company
This Report is:
(1) X An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
04/14/2020
Year/Period of Report
2019/Q4
NOTES TO FINANCIAL STATEMENTS (Continued)
FERC FORM NO. 1 (ED. 12-88)Page 123.9
Name of Respondent
Idaho Power Company
This Report is:
(1) X An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
04/14/2020
Year/Period of Report
2019/Q4
NOTES TO FINANCIAL STATEMENTS (Continued)
FERC FORM NO. 1 (ED. 12-88)Page 123.10
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
of these items, Idaho Power would be required to write off the applicable portion, which could have a materially adverse financial
impact.
Power Cost Adjustment Mechanisms and Deferred Power Supply Costs
In both its Idaho and Oregon jurisdictions, Idaho Power's power cost adjustment mechanisms address the volatility of power supply
costs and provide for annual adjustments to the rates charged to its retail customers. The power cost adjustment mechanisms compare
Idaho Power's actual net power supply costs (primarily fuel and purchased power less wholesale energy sales) against net power
supply costs being recovered in Idaho Power's retail rates. Under the power cost adjustment mechanisms, certain differences between
actual net power supply costs incurred by Idaho Power and costs being recovered in retail rates 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. The Idaho deferral period or Idaho-jurisdiction power cost adjustment (PCA) year runs from April 1 through
March 31. Amounts deferred during the PCA year are primarily recovered or refunded during the subsequent June 1 through May 31
period.
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 of authorized true-up dollars matches the amounts authorized. The PCA mechanism also includes:
·a cost or benefit sharing ratio that allocates the deviations in net power supply expenses between customers (95 percent) and
Idaho Power (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 of the mechanism.
The table below summarizes the three most recent Idaho-jurisdiction PCA rate adjustments, all of which also include
non-PCA-related rate adjustments as ordered by the IPUC:
Name of Respondent
Idaho Power Company
This Report is:
(1) X An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
04/14/2020
Year/Period of Report
2019/Q4
NOTES TO FINANCIAL STATEMENTS (Continued)
FERC FORM NO. 1 (ED. 12-88)Page 123.11
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. Oregon jurisdiction power supply cost changes under the APCU and PCAM during each of 2019 and
2018 did not have a material impact on Idaho Power’s financial statements.
Notable Idaho Base Rate Adjustments
Idaho base rates were most recently established through a general rate case in 2012, and adjusted in 2014, 2017, 2018, and 2019.
January 2012 and June 2014 Idaho Base Rate Adjustments: 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.
The IPUC 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 of the PCA rate that became effective June 1, 2014.
October 2014 Idaho Earnings Support and Sharing Settlement Stipulation: In October 2014, the IPUC issued an order approving
an extension, with modifications, of the terms of a December 2011 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 accumulated
deferred investment tax credits (ADITC) contemplated by the settlement stipulation has been amortized (October 2014 Idaho Earnings
Support and Sharing Settlement Stipulation). The provisions of the October 2014 Idaho Earnings Support and Sharing Settlement
Stipulation are described in the table included under "Income Tax Reform - Idaho Regulatory Treatment" below.
Name of Respondent
Idaho Power Company
This Report is:
(1) X An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
04/14/2020
Year/Period of Report
2019/Q4
NOTES TO FINANCIAL STATEMENTS (Continued)
FERC FORM NO. 1 (ED. 12-88)Page 123.12
In 2019, Idaho Power recorded no provision against current revenue for sharing with customers, as its full-year return on year-end
equity in the Idaho jurisdiction (Idaho ROE) was between 9.5 percent and 10.0 percent. In 2018, Idaho Power recorded a $5.0 million
provision against current revenue for sharing with customers as Idaho ROE was above 10.0 percent. Accordingly, at December 31,
2019, the full $45 million of additional ADITC remained available for future use under the terms of the May 2018 Idaho Tax Reform
Settlement Stipulation described in "Income Tax Reform - Idaho Regulatory Treatment" below.
May 2018 Idaho Tax Reform Settlement Stipulation: In December 2017, the Tax Cuts and Jobs Act was signed into law, which,
among other things, lowered the corporate federal income tax rate from 35 percent to 21 percent and modified or eliminated certain
federal income tax deductions for corporations. In March 2018, Idaho House Bill 463 was signed into law reducing the Idaho state
corporate income tax rate from 7.4 percent to 6.925 percent.
In May 2018, the IPUC issued an order approving a settlement stipulation (May 2018 Idaho Tax Reform Settlement Stipulation)
related to income tax reform. Beginning June 1, 2018, the settlement stipulation provided an annual (a) $18.7 million reduction to
Idaho customer base rates and (b) $7.4 million amortization of existing regulatory deferrals for specified items or future amortization
of other existing or future unspecified regulatory deferrals that would otherwise be a future liability recoverable from Idaho
customers. Additionally, a one-time benefit of a $7.8 million rate reduction was provided to Idaho customers through the
Idaho-jurisdiction power cost adjustment (PCA) mechanism for the period from June 1, 2018 through May 31, 2019, for the income
tax reform benefits accrued from January 1, 2018 to May 31, 2018, and the income tax reform benefits related to Idaho Power's
OATT rate. The amount provided via the PCA mechanism decreased to $2.7 million on June 1, 2019, for income tax reform benefits
related to Idaho Power's OATT rate and will cease on June 1, 2020, to reflect the impact of a full year of reduced OATT third-party
transmission revenues.
The May 2018 Idaho Tax Reform Settlement Stipulation also provides for the indefinite extension, with modifications, of the October
2014 Idaho Earnings Support and Sharing Settlement Stipulation beyond its termination date of December 31, 2019.
The table below summarizes and compares the terms of the October 2014 Idaho Earnings Support and Sharing Settlement Stipulation
with the terms in the May 2018 Idaho Tax Reform Settlement Stipulation that became applicable on January 1, 2020.
Name of Respondent
Idaho Power Company
This Report is:
(1) X An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
04/14/2020
Year/Period of Report
2019/Q4
NOTES TO FINANCIAL STATEMENTS (Continued)
FERC FORM NO. 1 (ED. 12-88)Page 123.13
Name of Respondent
Idaho Power Company
This Report is:
(1) X An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
04/14/2020
Year/Period of Report
2019/Q4
NOTES TO FINANCIAL STATEMENTS (Continued)
FERC FORM NO. 1 (ED. 12-88)Page 123.14
The May 2018 Idaho Tax Reform Settlement Stipulation did not impose a moratorium on Idaho Power filing a general rate case or
other form of rate proceeding in Idaho during its respective term.
Valmy Base Rate Adjustment Settlement Stipulations: In May 2017, the IPUC approved a settlement stipulation allowing
accelerated depreciation and cost recovery for Idaho Power’s jointly-owned North Valmy coal-fired power plant. The settlement
stipulation provides for an increase in Idaho jurisdictional revenues of $13.3 million per year, and (1) levelized collections and
associated cost recovery through December 2028, (2) accelerated depreciation on unit 1 through 2019 and unit 2 through 2025, and
(3) Idaho Power to use prudent and commercially reasonable efforts to end its participation in the operation of unit 1 by the end of
2019 and unit 2 by the end of 2025. The costs intended to be recovered by the increased jurisdictional revenues include current
investments as of May 31, 2017, in both units, forecasted unit 1 investments from 2017 through 2019, and forecasted
decommissioning costs for unit 1 and unit 2, offset by forecasted operation and maintenance costs savings. The settlement stipulation
also provides for the regulatory accrual or deferral of the difference between actual revenue requirements and levelized collections,
and provides for the regulatory accrual or deferral of the difference between actual costs incurred (including accelerated depreciation
expense on unit 1 through 2019 and unit 2 through 2025) compared with costs permitted to be recovered during the cost recovery
period specified in the settlement stipulation (including depreciation expense through 2028). If actual costs incurred differ from
forecasted amounts included in the settlement stipulation, collection or refund of any differences would be subject to regulatory
approval. In February 2019, Idaho Power reached an agreement with NV Energy that facilitates the planned end of Idaho Power's
participation in coal-fired operations at units 1 and 2 of its jointly-owned North Valmy coal-fired power plant in 2019 and 2025,
respectively. In May 2019, the IPUC issued an order approving the North Valmy plant agreement and allowing Idaho Power to
recover through customer rates the $1.2 million incremental annual levelized revenue requirement associated with required North
Valmy plant investments and other exit costs, effective June 1, 2019, through December 31, 2028. In December 2019, as planned,
Idaho Power ended its participation in coal-fired operations of North Valmy plant unit 1.
Other Notable Idaho Regulatory Matters
Fixed Cost Adjustment: The Idaho jurisdiction fixed cost adjustment (FCA) mechanism, applicable to Idaho residential and small
commercial customers, is designed to remove a portion of Idaho Power’s financial disincentive to invest in energy efficiency
programs by separating (or decoupling) the recovery of fixed costs from the variable kilowatt-hour charge and linking it instead to a
set amount per customer. Under Idaho Power's current rate design, recovery of a portion of fixed costs is included in the variable
kilowatt-hour charge, which may result in over-collection or under-collection of fixed costs. To return over-collection to customers or
to collect under-collection from customers, the FCA mechanism allows Idaho Power to accrue, or defer, the difference between the
authorized fixed-cost recovery amount per customer and the actual fixed costs per customer recovered by Idaho Power during the
year. The IPUC has discretion to cap the annual increase in the FCA recovery at 3 percent of base 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:
Name of Respondent
Idaho Power Company
This Report is:
(1) X An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
04/14/2020
Year/Period of Report
2019/Q4
NOTES TO FINANCIAL STATEMENTS (Continued)
FERC FORM NO. 1 (ED. 12-88)Page 123.15
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
Public Utility Commission of Oregon (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.
In May 2018, the OPUC issued an order approving a settlement stipulation that provides for an annual $1.5 million reduction to
Oregon customer base rates beginning June 1, 2018, through May 31, 2020, related to income tax reform. In December 2019, Idaho
Power filed an application with the OPUC requesting approval of Idaho Power’s quantification of $1.5 million in annualized Oregon
jurisdictional benefits associated with federal and state income tax changes resulting from tax reform and adjusting customer rates to
reflect this amount, effective June 1, 2020, until its next general rate case or other proceeding where the tax-related revenue
requirement components are reflected in rates.
In June 2017, the OPUC approved a settlement stipulation allowing for (1) accelerated depreciation of North Valmy plant units 1 and
2 through December 31, 2025, (2) cost recovery of incremental North Valmy plant investments through May 31, 2017, and (3)
forecasted North Valmy plant decommissioning costs. The settlement stipulation provides for an increase in the Oregon jurisdictional
revenue requirement of $1.1 million, effective July 1, 2017, with yearly adjustments, if warranted. As part of the May 2018 settlement
stipulation associated with income tax reform described above, the OPUC also deemed prudent Idaho Power's decision to pursue the
end of its participation in coal-fired operations of unit 1 by the end of 2019 and approved Idaho Power's request to recover annual
incremental accelerated depreciation relating to unit 1, beginning June 1, 2018, and ending December 31, 2019, resulting in a $2.5
million annualized revenue requirement. In October 2019, the OPUC approved the North Valmy plant agreement and authorized
Idaho Power to adjust customer rates in Oregon, effective January 1, 2020, to reflect a decrease in the annual levelized revenue
requirement of $3.2 million, which mostly relates to the decrease in depreciation expense and other costs associated with the
December 2019 end of Idaho Power's participation in coal-fired operations of North Valmy plant unit 1.
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 actual financial and operational data Idaho Power files with the FERC and allows Idaho Power to recover
costs for FERC-approved expenditures associated with its transmission system. Idaho Power's OATT rates submitted to the FERC in
Idaho Power's four most recent annual OATT Final Informational Filings were as follows:
Name of Respondent
Idaho Power Company
This Report is:
(1) X An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
04/14/2020
Year/Period of Report
2019/Q4
NOTES TO FINANCIAL STATEMENTS (Continued)
FERC FORM NO. 1 (ED. 12-88)Page 123.16
Idaho Power's current OATT rate is based on a net annual transmission revenue requirement of $107.0 million, which represents the
OATT formulaic determination of Idaho Power's net cost of providing OATT-based transmission service.
4. REVENUES
Revenues from Contracts with Customers
Revenues from contracts with customers are primarily related to Idaho Power’s regulated tariff-based sales of energy or related
services. Generally, tariff-based sales do not involve a written contract, but are classified as revenues from contracts with customers
under ASU 2014-09, Revenue from Contracts with Customers (Topic 606). Idaho Power assesses revenues on a contract-by-contract
basis to determine the nature, amount, timing, and uncertainty, if any, of revenues being recognized.
Retail Revenues:Idaho Power’s retail revenues primarily relate to the sale of electricity to customers based on regulated tariff-based
prices. Idaho Power recognizes retail revenues in amounts for which it has the right to invoice the customer in the period when energy
is delivered or services are provided to customers. The total energy price generally has a fixed component related to having service
available and a usage-based component related to the demand, delivery, and consumption of energy. The revenues recognized reflect
the consideration Idaho Power expects to be entitled to in exchange for energy and services. Retail customers are classified as
residential, commercial, industrial, or irrigation. Approximately 95 percent of Idaho Power's retail revenue originates from customers
located in Idaho, with the remainder originating from customers located in Oregon. Idaho Power’s retail customer rates are based on
Idaho Power’s cost of service and are determined through general rate case proceedings, settlement stipulations, and other filings with
the IPUC and OPUC. Changes in rates and changes in customer demand are typically the primary causes of fluctuations in retail
revenue from period to period. The primary influences on changes in customer demand for electricity are weather, economic
conditions (including growth in the number of Idaho Power customers), and energy efficiency. Idaho Power's utility revenues are not
earned evenly during the year.
Retail revenues are billed monthly based on meter readings taken throughout the month. Payments for amounts billed are generally
due from the customer within 15 days of billing. Idaho Power accrues estimated unbilled revenues for energy or related services
delivered to customers but not yet billed at period-end based on actual meter readings at period-end and estimated rates.
Credit losses recorded on receivables arising from Idaho Power’s contracts with customers were $2.6 million, $3.6 million, and $4.7
million for 2019 and 2018, respectively.
Residential Customers: Idaho Power’s energy sales to residential customers typically peak during the winter heating season and
summer cooling season. Extreme temperatures increase sales to residential customers who use electricity for cooling and heating,
compared with normal temperatures. Idaho Power's rate structure provides for higher rates during the summer when overall system
loads are at their highest, and includes tiers such that rates increase as a customer's consumption level increases. These seasonal and
tiered rate structures contribute to the seasonal fluctuations in revenues and earnings. Economic and demographic conditions can also
affect residential customer demand; strong job growth and population growth in Idaho Power’s service area have led to increasing
customer growth rates in recent years. Residential demand is also impacted by energy efficiency initiatives. Idaho Power’s FCA
mechanism mitigates some of the fluctuations caused by weather and energy efficiency initiatives.
Commercial Customers: Most businesses are included in Idaho Power's commercial customer class, as well as small industrial
Name of Respondent
Idaho Power Company
This Report is:
(1) X An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
04/14/2020
Year/Period of Report
2019/Q4
NOTES TO FINANCIAL STATEMENTS (Continued)
FERC FORM NO. 1 (ED. 12-88)Page 123.17
companies, and public street and highway lighting accounts. Idaho Power’s commercial customers are less influenced by weather
conditions than residential customers, although weather does affect commercial customer energy use. Economic conditions, including
manufacturing activity levels, and energy efficiency initiatives also affect energy use of commercial customers.
Industrial Customers: Industrial customers consist of large industrial companies, including special contract customers. Energy use of
industrial customers is primarily driven by economic conditions, with weather having little impact on this customer class.
Irrigation Customers: Irrigation customers use electricity to operate irrigation pumps, primarily during the agricultural growing
season. The amount and timing of precipitation as well as temperature levels can affect the timing and amounts of sales to irrigation
customers, with increased precipitation generally resulting in decreased sales.
Provision for Sharing: Idaho Power's sharing mechanism is associated with the October 2014 Idaho Earnings Support and Sharing
Settlement Stipulation that provides for the sharing with customers of a portion of Idaho-jurisdiction earnings exceeding a 10.0
percent Idaho ROE. Based on full-year 2019 Idaho ROE, Idaho Power recorded no provision against current revenues for sharing of
earnings with customers for 2019. Idaho Power recorded $5.0 million of sharing of earnings with customers during 2018 and no
provision was recorded during 2017. The October 2014 Idaho Earnings Support and Sharing Settlement Stipulation is described
further in Note 3 - "Regulatory Matters."
Wholesale Energy Sales:As a public utility under the Federal Power Act (FPA), Idaho Power has the authority to charge
market-based rates for wholesale energy sales under its FERC tariff. Idaho Power’s wholesale electricity sales are primarily to utilities
and power marketers and are predominantly short-term and consist of a single performance obligation satisfied as energy is transferred
to the counterparty. Idaho Power's wholesale energy sales depend largely on the availability of generation resources in excess of the
amount necessary to serve customer loads as well as adequate market power prices at the time when those resources are available. A
reduction in either factor may lead to lower wholesale energy sales.
Transmission Wheeling-Related Revenues: As a public utility under the FPA, Idaho Power has the authority to provide cost-based
wholesale and retail access transmission services under its OATT. Services under the OATT are offered on a nondiscriminatory basis
such that all potential customers have an equal opportunity to access the transmission system. Idaho Power’s transmission revenue is
primarily related to third parties reserving capacity on Idaho Power’s transmission system to transmit electricity through Idaho
Power’s service area. The reservations are predominantly short-term but may be part of a long-term capacity contract, short-term
contract, or on-demand when available. Transmission wheeling-related revenues consist of a single performance obligation satisfied
as capacity on Idaho Power’s transmission system is provided to the third party. Transmission wheeling-related revenues are affected
by changes in Idaho Power’s OATT rate and customer demand. Demand for transmission services can be affected by regional market
factors, such as loads and generation of utilities in Idaho Power’s region.
Energy Efficiency Program Revenues: Idaho Power collects most of its energy efficiency program costs through an energy
efficiency rider on customer bills. The rider collections are deferred until expenditures are incurred. Energy efficiency program
expenditures funded through the rider are reported as an operating expense with an equal amount recorded in revenues, resulting in no
net impact on earnings. Energy efficiency program revenues are recognized in the period when the related costs of the energy
efficiency program are incurred by Idaho Power. The cumulative variance between expenditures and amounts collected through the
rider is recorded as a regulatory asset or liability. A liability balance indicates that Idaho Power has collected more than it has spent,
and an asset balance indicates that Idaho Power has spent more than it has collected. At December 31, 2019, Idaho Power's energy
efficiency rider balances were a $0.3 million regulatory asset in the Idaho jurisdiction and a $1.2 million regulatory asset in the
Name of Respondent
Idaho Power Company
This Report is:
(1) X An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
04/14/2020
Year/Period of Report
2019/Q4
NOTES TO FINANCIAL STATEMENTS (Continued)
FERC FORM NO. 1 (ED. 12-88)Page 123.18
Oregon jurisdiction.
Alternative Revenue Programs and Derivative Revenues
While revenues from contracts with customers make up most of Idaho Power’s revenues, the IPUC has authorized the use of the FCA
mechanism, which may increase or decrease tariff-based rates billed to customers. The FCA mechanism is described in detail in Note
3 - "Regulatory Matters." The FCA mechanism revenues include only the initial recognition of FCA revenues when the
regulator-specified conditions for recognition have been met. Revenue from contracts with customers excludes the portion of the tariff
price representing FCA revenues that had been initially recorded in prior periods when regulator-specified conditions were met. When
those amounts are included in the price of utility service and billed to customers, such amounts are recorded as recovery of the
associated regulatory asset or liability and not as revenues.
Name of Respondent
Idaho Power Company
This Report is:
(1) X An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
04/14/2020
Year/Period of Report
2019/Q4
NOTES TO FINANCIAL STATEMENTS (Continued)
FERC FORM NO. 1 (ED. 12-88)Page 123.19
5. LONG-TERM DEBT
Name of Respondent
Idaho Power Company
This Report is:
(1) X An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
04/14/2020
Year/Period of Report
2019/Q4
NOTES TO FINANCIAL STATEMENTS (Continued)
FERC FORM NO. 1 (ED. 12-88)Page 123.20
Long-Term Debt Issuances, Maturities, and Redemptions
In March 2018, Idaho Power issued $220.0 million in principal amount of 4.20% first mortgage bonds, secured medium-term notes,
Series K, maturing on March 1, 2048. In April 2018, Idaho Power redeemed, prior to maturity, $130.0 million in principal amount of
4.50% first mortgage bonds, secured medium-term notes, Series H, due March 2020. In accordance with the redemption provisions of
the notes, the redemption included Idaho Power's payment of a make-whole premium of $4.6 million. Idaho Power used a portion of
the net proceeds from the March 2018 sale of first mortgage bonds, medium-term notes to effect the redemption.
In April 2020, Idaho Power issued an additional $230.0 million in principal amount of 4.20% first mortgage bonds, secured
medium-term notes, Series K, maturing on March 1, 2048, bringing the total principal amount of Series K bonds outstanding to $450
million. The bonds were issued at a premium of approximately $32 million.
In August 2019, Idaho Power purchased and remarketed two of its outstanding series of pollution control tax-exempt bonds, one in
the aggregate principal amount of $49.8 million issued in 2003 by Humboldt County, Nevada and due in 2024, and the other in the
aggregate principal amount of $116.3 million issued in 2006 by Sweetwater County, Wyoming and due in 2026. The bonds were
remarketed with substantially the same terms, but with lower term interest rates. The term interest rate of the series due in 2024
decreased from 5.15 percent to 1.45 percent and the term interest rate of the series due in 2026 decreased from 5.25 percent to 1.70
percent.
Idaho Power First Mortgage Bonds
Idaho Power's issuance of long-term indebtedness is subject to the approval of the IPUC, OPUC, and Wyoming Public Service
Commission (WPSC). In April and May 2019, Idaho Power received orders from the IPUC, OPUC, and WPSC authorizing the
company 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 is effective through May 31, 2022, subject to extensions
upon request to the IPUC. 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 requirement that the interest rates for the debt securities or first mortgage bonds fall
within either (a) designated spreads over comparable U.S. Treasury rates or (b) a maximum all-in interest rate limit of 7.0 percent.
In May 2019, Idaho Power filed a shelf registration statement with the SEC, which became effective upon filing, for the offer and sale
of an unspecified principal amount of its first mortgage bonds. The issuance of first mortgage bonds requires that Idaho Power meet
interest coverage and security provisions set forth in the Idaho Power's Indenture of Mortgage and Deed of Trust, dated as of October
1, 1937, as amended and supplemented from time to time (Indenture). Future issuances of first mortgage bonds are subject to
satisfaction of covenants and security provisions set forth in the Indenture, market conditions, regulatory authorizations, and
covenants contained in other financing agreements.
Name of Respondent
Idaho Power Company
This Report is:
(1) X An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
04/14/2020
Year/Period of Report
2019/Q4
NOTES TO FINANCIAL STATEMENTS (Continued)
FERC FORM NO. 1 (ED. 12-88)Page 123.21
As of the date of this report, Idaho Power has not entered into a selling agency agreement under the new shelf agreement. The
mortgage of the 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 of the properties of Idaho Power are subject to easements, leases, contracts,
covenants, workmen's compensation awards, and similar encumbrances and minor defects common to properties. The mortgage of the
Indenture does not create a lien on revenues or profits, or notes or accounts receivable, contracts or choses 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 of the Indenture creates a lien on the interest of Idaho Power in property subsequently acquired,
other than excepted property, subject to limitations in the case of consolidation, merger, or sale of all or substantially all of the 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.
The Forty-eighth Supplemental Indenture increased the maximum amount of first mortgage bonds issuable by Idaho Power under the
Indenture from $2.0 billion to $2.5 billion. Idaho Power may amend the Indenture and increase this amount without consent of the
holders of the first mortgage bonds. The amount issuable is also restricted by property, earnings, and other provisions of the Indenture
and supplemental indentures to the Indenture. 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 years or that are of an equal or higher interest rate, or prior lien bonds.
As of December 31, 2019, Idaho Power could issue under its Indenture approximately $1.9 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 Forty-eighth Supplemental Indenture. As a result, the maximum amount of first
mortgage bonds Idaho Power could issue as of December 31, 2019, was limited to approximately $669 million under the Indenture.
6. NOTES PAYABLE
Credit Facilities
On December 6, 2019, Idaho Power entered into amendments to its outstanding Credit Agreement, which provides a credit facility
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 $50 million. Idaho Power has the
right to request an increase in the aggregate principal amount of the facility to $450 million, subject to certain conditions.
The interest rates for any borrowings under the facility are based on either (1) a floating rate that is equal to the highest of the prime
rate, federal funds rate plus 0.5 percent, or LIBOR Market Index rate plus 1.0 percent, or (2) the LIBOR Market Index rate, plus, in
each case, an applicable margin, provided that the federal funds rate and LIBOR rate will not be less than zero percent. An alternate
benchmark rate selected by the administrative agent for the credit facility and Idaho Power will apply during any period in which the
Name of Respondent
Idaho Power Company
This Report is:
(1) X An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
04/14/2020
Year/Period of Report
2019/Q4
NOTES TO FINANCIAL STATEMENTS (Continued)
FERC FORM NO. 1 (ED. 12-88)Page 123.22
LIBOR rate is unavailable or unascertainable. The applicable margin is based on Idaho Power's 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 agreement. Under its credit facility, Idaho Power pays a facility fee on the commitment based
on the company's credit rating for senior unsecured long-term debt securities. While the credit facility provides for an original
maturity date of December 6, 2024, the credit agreement grants Idaho Power the right to request up to two one-year extensions,
subject to certain conditions.
At December 31, 2019, no loans were outstanding under Idaho Power's facility. At December 31, 2019, Idaho Power had regulatory
authority to incur up to $450 million in principal amount of short-term indebtedness at any one time outstanding. Idaho Power's
short-term borrowings were zero at December 31, 2019 and 2018.
7. COMMON STOCK
Idaho Power Common Stock
No contributions were made to Idaho Power in 2019 or 2018 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 its credit facility or Idaho Power’s Revised Code of Conduct. A covenant under Idaho Power’s credit
facility requires Idaho Power to maintain a leverage ratio of consolidated indebtedness to consolidated total capitalization, as defined
therein, of no more than 65 percent at the end of each fiscal quarter. At December 31, 2019, the leverage ratio for Idaho Power was 45
percent. Based on these restrictions, Idaho Power’s dividends were limited to $1.3 billion at December 31, 2019. 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 Idaho Power from any material subsidiary. At December 31, 2019, 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 of its total adjusted capital without IPUC approval. At
December 31, 2019, Idaho Power's common equity capital was 55 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 of dividends on its common stock if preferred stock
dividends are in arrears. As of the date of this report, Idaho Power has no preferred stock outstanding.
In addition to contractual restrictions on the amount and payment of dividends, the FPA prohibits the payment of dividends from
"capital accounts." The term "capital account" is undefined in the FPA or its regulations, but Idaho 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) of the Federal Power Act, Idaho Power has $13.3 million of amortization reserves established for
Name of Respondent
Idaho Power Company
This Report is:
(1) X An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
04/14/2020
Year/Period of Report
2019/Q4
NOTES TO FINANCIAL STATEMENTS (Continued)
FERC FORM NO. 1 (ED. 12-88)Page 123.23
certain of its licensed hydroelectric facilities.
8. SHARE-BASED COMPENSATION
Through its parent company IDACORP, Idaho Power has one share-based compensation plan — the 2000 Long-Term Incentive and
Compensation Plan (LTICP). The LTICP (for officers, key employees, and directors) permits the grant of stock options, restricted
stock and restricted stock units (together, Restricted Stock), performance shares and performance-based units (together,
Performance-Based Shares), and several other types of share-based awards. At December 31, 2019, the maximum number of shares
available under the LTICP was 613,394.
Restricted Stock and Performance-Based Shares Awards
Restricted Stock awards have three-year vesting periods and entitle the recipients to dividends or dividend equivalents, as applicable,
and voting rights, except that holders of restricted stock units do not have voting rights until the units are vested and settled in shares.
Unvested awards are restricted as to disposition and subject to forfeiture under certain circumstances. The fair value of these awards is
based on the closing market price of common stock on the grant date and is charged to compensation expense over the vesting period,
reduced for any forfeitures during the vesting period.
Performance-Based Shares awards have three-year vesting periods and entitle the recipients to voting rights, except that holders of
performance-based units do not have voting rights until the units are vested and settled in shares. Unvested awards 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 of attainment of the performance conditions and
the year issued, the final number of shares awarded can range from zero to 200 percent of the target award. Dividends or dividend
equivalents, as applicable, are accrued during the vesting period and paid out based on the final number of shares awarded.
The grant-date fair value of the CEPS portion is based on the closing market value at the date of grant, reduced by the loss in
time-value of the estimated future dividend payments. The fair value of this portion of the awards is charged to compensation expense
over the requisite service period based on the estimated achievement of performance targets, reduced for any forfeitures during the
vesting period. The grant-date fair value of the TSR portion is estimated using the market value at the date of grant and a statistical
model that incorporates the probability of meeting 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.
Name of Respondent
Idaho Power Company
This Report is:
(1) X An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
04/14/2020
Year/Period of Report
2019/Q4
NOTES TO FINANCIAL STATEMENTS (Continued)
FERC FORM NO. 1 (ED. 12-88)Page 123.24
A summary of Restricted Stock and Performance-Based Shares award activity is presented below. Share amounts represent shares of
IDACORP common stock:
The total fair value of shares vested was $9.4 million in 2019 and $8.3 million in 2018. At December 31, 2019, Idaho Power had $7.8
million of total unrecognized compensation cost related to nonvested share-based compensation. These costs are expected to be
recognized over a weighted-average period of 1.7 years. Original issue and/or treasury shares of IDACORP are used for these awards.
In 2019, a total of 9,594 shares of IDACORP common stock were awarded to directors of IDACORP and Idaho Power at a grant date
fair value of $98.41 per share. Directors elected to defer receipt of 3,198 of these shares, which are being held as deferred stock units
with dividend equivalents reinvested in additional stock units.
Compensation Expense: The following table shows Idaho Power’s compensation cost recognized in income and the tax benefits
resulting from the LTICP (in thousands of dollars):
No equity compensation costs have been capitalized. These costs are primarily reported within "Other operations and maintenance"
expense on the consolidated statements of income.
9. COMMITMENTS
Purchase Obligations
At December 31, 2019, Idaho Power had the following long-term commitments relating to purchases of energy, capacity, transmission
Name of Respondent
Idaho Power Company
This Report is:
(1) X An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
04/14/2020
Year/Period of Report
2019/Q4
NOTES TO FINANCIAL STATEMENTS (Continued)
FERC FORM NO. 1 (ED. 12-88)Page 123.25
rights, and fuel (in thousands of dollars):
As of December 31, 2019, Idaho Power had 1,136 MW nameplate capacity of PURPA-related projects on-line, with an additional 11
MW nameplate capacity of projects projected to be on-line by 2022. 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
$187 million in 2019 and $190 million in 2018.
Also, in March 2019, Idaho Power signed a 20-year power purchase agreement to purchase the output from a planned 120-megawatt
solar facility. The agreement was approved by the IPUC in December 2019 and is, as of the date of this report, pending approval by
the OPUC. If approved, the agreement would increase contractual obligations by $136 million over the 20-year term.
Idaho Power’s expense for operating leases was not material for the years ended 2019 and 2018.
Guarantees
Through a self-bonding mechanism, Idaho Power guarantees its portion of reclamation activities and obligations at BCC, of which
IERCo owns a one-third interest. This guarantee, which is renewed annually with the Wyoming Department of Environmental Quality
(WDEQ), was $58.3 million at December 31, 2019, representing IERCo's one-third share of BCC's total reclamation obligation of
$175.0 million. BCC has a reclamation trust fund set aside specifically for the purpose of paying these reclamation costs. At
December 31, 2019, the value of the reclamation trust fund was $139.5 million. During 2019, the reclamation trust fund made no
distributions 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, and does, add a per-ton surcharge to coal sales, all of which are made to the Jim Bridger
plant. Because of the existence of the fund and the ability to apply a per-ton surcharge, the estimated fair value of this guarantee is
minimal.
Name of Respondent
Idaho Power Company
This Report is:
(1) X An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
04/14/2020
Year/Period of Report
2019/Q4
NOTES TO FINANCIAL STATEMENTS (Continued)
FERC FORM NO. 1 (ED. 12-88)Page 123.26
In May 2019, the state of Wyoming enacted legislation that limits a mine operator's maximum amount of self-bonding. Idaho Power
and the co-owners of BCC have until December 2020 to comply with the new regulations, which would reduce the portion of Idaho
Power's guarantee of reclamation activities and obligations at BCC that Idaho Power is allowed to self-bond. As of the date of this
report, Idaho Power believes the cost of any insurance, third-party assurance, or additional collateral that might be required for this
guarantee due to the new law would be immaterial to its consolidated financial statements.
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 of the obligation
under such indemnification provisions cannot be reasonably estimated. Idaho Power periodically evaluate the likelihood of incurring
costs under such indemnities based on its historical experience and the evaluation of the specific indemnities. As of December 31,
2019, 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 sheets with respect to these indemnification obligations.
10. CONTINGENCIES
Idaho Power has in the past and expects in the future to become involved in various claims, controversies, disputes, and other
contingent matters, some of which 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 of parties. 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. 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 of the date of this report, Idaho Power's accruals for loss contingencies are
not material to its 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 of costs
incurred, although there is no assurance that such recovery would be granted.
Idaho Power is party to legal claims and legal, tax, and regulatory actions and proceedings in the ordinary course of business and, as
noted above, record an accrual for associated loss contingencies when they are probable and reasonably estimable. In connection with
its utility operations, Idaho Power is subject to claims by individuals, entities, and governmental agencies for damages for alleged
personal injury, property damage, and economic losses, relating to the company’s provision of electric service and the operation of its
generation, transmission, and distribution facilities. Some of those claims relate to electrical contacts, service quality, property
damage, and wildfires. In recent years, utilities in the western United States have been subject to significant liability for personal
injury, loss of life, property damage, trespass, and economic losses, and in some cases, punitive damages and criminal charges,
associated with wildfires that originated from utility property, most commonly transmission and distribution lines. In recent years,
Idaho Power has regularly received claims by governmental agencies and private landowners for damages for fires allegedly
originating from Idaho Power’s transmission and distribution system. As of the date of this report, Idaho Power believes that
resolution of existing claims will not have a material adverse effect on its consolidated financial statements. Idaho Power is also
Name of Respondent
Idaho Power Company
This Report is:
(1) X An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
04/14/2020
Year/Period of Report
2019/Q4
NOTES TO FINANCIAL STATEMENTS (Continued)
FERC FORM NO. 1 (ED. 12-88)Page 123.27
actively monitoring various pending environmental regulations and executive orders related to environmental matters 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 of these regulations.
11. 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 401(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 two nonqualified defined
benefit pension plans for certain senior management employees called the Security Plan for Senior Management Employees I and
Security Plan for Senior Management Employees II (together, SMSP). Idaho Power also has a nonqualified defined benefit pension
plan for directors that was 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 of service and the employee's final average earnings.
Name of Respondent
Idaho Power Company
This Report is:
(1) X An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
04/14/2020
Year/Period of Report
2019/Q4
NOTES TO FINANCIAL STATEMENTS (Continued)
FERC FORM NO. 1 (ED. 12-88)Page 123.28
The actuarial losses reflected in the benefit obligations for the pension and SMSP plans in 2019 are due primarily to decreases in the
assumed discount rates of both plans from December 31, 2018, to December 31, 2019. The actuarial gains affecting the benefit
obligations for the pension and SMSP plans in 2018 are due primarily to increases in the assumed discount rates from December 31,
2017, to December 31, 2018. For more information on discount rates, see “Plan Assumptions” below in this Note 1.
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 $97.6 million and $92.5 million at December 31, 2019 and 2018, respectively, and is
reflected in Investments and in Company-owned life insurance on the consolidated balance sheets.
Name of Respondent
Idaho Power Company
This Report is:
(1) X An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
04/14/2020
Year/Period of Report
2019/Q4
NOTES TO FINANCIAL STATEMENTS (Continued)
FERC FORM NO. 1 (ED. 12-88)Page 123.29
The following table shows the components of net 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 of the assets.
Name of Respondent
Idaho Power Company
This Report is:
(1) X An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
04/14/2020
Year/Period of Report
2019/Q4
NOTES TO FINANCIAL STATEMENTS (Continued)
FERC FORM NO. 1 (ED. 12-88)Page 123.30
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 purposes. In 2019, 2018,
and 2017, 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. As of the
date of this report, Idaho Power's minimum required contribution to the pension plan is estimated to be $14 million during 2020.
Depending on market conditions and cash flow considerations in 2020, Idaho Power could contribute up to $40 million to the pension
plan during 2020 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 of health 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.
Name of Respondent
Idaho Power Company
This Report is:
(1) X An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
04/14/2020
Year/Period of Report
2019/Q4
NOTES TO FINANCIAL STATEMENTS (Continued)
FERC FORM NO. 1 (ED. 12-88)Page 123.31
Name of Respondent
Idaho Power Company
This Report is:
(1) X An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
04/14/2020
Year/Period of Report
2019/Q4
NOTES TO FINANCIAL STATEMENTS (Continued)
FERC FORM NO. 1 (ED. 12-88)Page 123.32
Name of Respondent
Idaho Power Company
This Report is:
(1) X An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
04/14/2020
Year/Period of Report
2019/Q4
NOTES TO FINANCIAL STATEMENTS (Continued)
FERC FORM NO. 1 (ED. 12-88)Page 123.33
Plan Assumptions
The following table sets forth the weighted-average assumptions used at the end of each year to determine benefit obligations for all
Idaho Power-sponsored pension and postretirement benefits plans:
The assumed health care cost trend rate used to measure the expected cost of health benefits covered by the postretirement plan was
6.7 percent in 2019 and is assumed to decrease to 5.9 percent in 2020, 5.2 percent in 2021, 5.1 percent in 2022 and to gradually
decrease to 3.9 percent by 2091. The assumed dental cost trend rate used to measure the expected cost of dental benefits covered by
the plan was 4.0 percent, or equal to the medical trend rate if lower, for all years.
Plan Assets
Pension Asset Allocation Policy:The target allocation and actual allocations at December 31, 2019, for the pension asset portfolio by
asset class is set forth below:
Name of Respondent
Idaho Power Company
This Report is:
(1) X An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
04/14/2020
Year/Period of Report
2019/Q4
NOTES TO FINANCIAL STATEMENTS (Continued)
FERC FORM NO. 1 (ED. 12-88)Page 123.34
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 of risk and the liability profile of the portfolio.
Emphasis is placed on preservation and growth of capital along with adequacy of cash flow sufficient to fund current and future
payments to plan participants.
The three major goals in Idaho Power’s asset allocation process are to:
·determine if the investments have the potential to earn the rate of return assumed in the actuarial liability calculations;
·match the cash flow needs of the plan. Idaho Power sets bond allocations sufficient to cover approximately five years of
benefit payments. Idaho Power then utilizes growth instruments (equities, real estate, venture capital) to fund the longer-term
liabilities of the 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, real estate funds, private equity
funds, and cash and cash equivalents. With the exception of real 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 30 years when interest
rates were generally much higher.
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 of Plan Assets: Idaho Power classifies its pension plan and postretirement benefit plan investments using the three-level
fair value hierarchy described in Note 17 - "Fair Value Measurements." The following table presents the fair value of the plans'
investments by asset category (in thousands of dollars).
Name of Respondent
Idaho Power Company
This Report is:
(1) X An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
04/14/2020
Year/Period of Report
2019/Q4
NOTES TO FINANCIAL STATEMENTS (Continued)
FERC FORM NO. 1 (ED. 12-88)Page 123.35
Name of Respondent
Idaho Power Company
This Report is:
(1) X An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
04/14/2020
Year/Period of Report
2019/Q4
NOTES TO FINANCIAL STATEMENTS (Continued)
FERC FORM NO. 1 (ED. 12-88)Page 123.36
Fair Value Measurement of Level 2 Plan assets and Plan assets measured at NAV:
Level 2 Bonds: These investments represent U.S. government, agency bonds, and corporate bonds. The U.S. government and agency
bonds, as well as the corporate bonds, are not traded on an exchange and are valued utilizing market prices for similar assets or
liabilities in active markets.
Level 2 Postretirement Asset: This asset represents an investment in a life insurance contract and is 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 of the market value of an 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.
Commingled Funds: These funds, made up of the international and emerging markets equity securities and commodities fund
measured at NAV, are not publicly traded, and therefore no publicly quoted market price is readily available. The values of the
commingled funds are presented at estimated fair value, which is determined based on the unit value of the fund. The values of these
investments are calculated by the custodian for the fund company on a monthly or more frequent basis, and are based on market prices
of the assets held by each of the commingled funds divided by the number of fund shares outstanding for the respective fund. The
investments in commingled funds have redemption limitations that permit monthly redemption following notice requirements of 5 to
7 days.
Real Estate: Real estate holdings represent investments in open-end and closed-end 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
companies, 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 real estate funds also furnish annual audited financial statements that are also used to further validate the information provided.
Redemptions on the open-end funds are generally available on a quarterly basis, with 10 to 35 days written notice, depending on the
individual fund. If the fund has sufficient liquidity, the redemption will be processed at the fund NAV or the fund’s estimate of fair
value at the end of the quarter. If the fund does not have sufficient liquidity to honor the full redemption, the remainder will be set for
redemption the following quarter on a pro-rata basis with other redemption requests. This same process will repeat until the
redemption request has been completed. To protect other fund holders, real estate funds have no duty to liquidate or encumber funds
to meet redemption requests. The closed-end funds are formed for a stated life of 7 to 9 years. The fund can be further extended with
the approval of the limited partners. There are generally no redemption rights associated with these funds. The limited partner must
hold the fund for the life of the fund or find a third-party buyer.
Private Market Investments: Private market investments represent two categories: fund of hedge funds and venture capital funds.
These funds are valued by the fund companies based on the estimated fair values of the underlying fund holdings divided by the fund
shares outstanding or multiplied by the ownership percentages of the holder. 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. Redemptions are available on a
quarterly basis with 70 days written notice. Redemptions will be processed at the quarterly NAV or fair value within 60 days
following quarter end. In the event of a full redemption, a reserve amount of 5% to 10% of the redemption amount may be held in
reserve until the audited financial statements of the fund are published. This allows the fund to adjust the redemption so that other
fund holders are not adversely impacted. Venture capital fund investments are valued by the fund companies based on estimated fair
Name of Respondent
Idaho Power Company
This Report is:
(1) X An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
04/14/2020
Year/Period of Report
2019/Q4
NOTES TO FINANCIAL STATEMENTS (Continued)
FERC FORM NO. 1 (ED. 12-88)Page 123.37
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
validate the information provided. These funds are formed for a stated life of 10 to 15 years. The general partner can extend the fund
life for 2 or 3 one-year periods. The fund can be further extended with the approval of the limited partners. There are generally no
redemption rights associated with these funds. The limited partner must hold the fund for the life of the fund or find a third-party
buyer.
Employee Savings Plan
Idaho Power has a defined contribution plan designed to comply with Section 401(k) of the Internal Revenue Code and that covers
substantially all employees. Idaho Power matches specified percentages of employee contributions to the plan. Matching annual
contributions were approximately $7.7 million in both 2019 and 2018.
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 benefits included in other deferred credits on Idaho Power’s consolidated balance sheets at December 31, 2019, and
2018, were approximately $2 million.
12. PROPERTY, PLANT AND EQUIPMENT AND JOINTLY-OWNED PROJECTS
The following table presents the major classifications of Idaho Power’s utility plant in service, annual depreciation provisions as a
percent of average depreciable balance, and accumulated provision for depreciation for the years ended December 31, 2019 and 2018
(in thousands of dollars):
At December 31, 2019, Idaho Power's construction work in progress balance of $552.5 million included relicensing costs of $326.0
Name of Respondent
Idaho Power Company
This Report is:
(1) X An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
04/14/2020
Year/Period of Report
2019/Q4
NOTES TO FINANCIAL STATEMENTS (Continued)
FERC FORM NO. 1 (ED. 12-88)Page 123.38
million for the HCC, Idaho Power's largest hydropower complex. In 2019 and 2018, Idaho Power had IPUC authorization to include
in its Idaho jurisdiction rates $6.5 million annually ($8.8 million when grossed-up for the effect of income taxes) of AFUDC relating
to the HCC relicensing project. Collecting these amounts will reduce the amount collected in the future once the HCC relicensing
costs are approved for recovery in base rates. At December 31, 2019, Idaho Power's accumulated provision for rate refunds for
collection of AFUDC relating to the HCC was $151.7 million.
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.
These jointly-owned facilities, including balance sheet amounts and the extent of Idaho Power’s participation, were as follows at
December 31, 2019 (in thousands of dollars):
IERCo, Idaho Power’s wholly-owned subsidiary, is a joint venturer in BCC. Idaho Power’s coal purchases from the joint venture
were $73.6 million in 2019 and $81.8 million in 2018.
Idaho Power has contracts to purchase the energy from four PURPA qualifying facilities that are 50 percent owned by Ida-West.,
Idaho Power’s power purchases from these facilities were $8.6 million in 2019 and $9.7 million in 2018.
13. ASSET RETIREMENT OBLIGATIONS (ARO)
The guidance relating to accounting for AROs requires that legal obligations associated with the retirement of property, plant, and
equipment be recognized as a liability at fair value when incurred and when a reasonable estimate of the fair value of the 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 of the 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. Accretion, depreciation, and gains or losses related to the Boardman generating facility
are 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 reclamation and removal costs at its jointly-owned coal-fired generation facilities.
Name of Respondent
Idaho Power Company
This Report is:
(1) X An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
04/14/2020
Year/Period of Report
2019/Q4
NOTES TO FINANCIAL STATEMENTS (Continued)
FERC FORM NO. 1 (ED. 12-88)Page 123.39
Idaho Power also has additional AROs associated with its transmission system, hydropower facilities, natural gas-fired generation
facilities, and jointly owned coal-fired generation facilities; however, due to the indeterminate removal date, the fair value of the
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 of AROs (in thousands of dollars):
14. INVESTMENTS
Investments in Equity Securities
Investments in equity securities are reported at fair value. Any unrealized gains or losses on equity securities are included in income.
Unrealized gains and losses on equity securities were immaterial at December 31, 2019 and December 31, 2018. The following table
summarizes sales of equity securities (in thousands of dollars):
Name of Respondent
Idaho Power Company
This Report is:
(1) X An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
04/14/2020
Year/Period of Report
2019/Q4
NOTES TO FINANCIAL STATEMENTS (Continued)
FERC FORM NO. 1 (ED. 12-88)Page 123.40
15. 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 of their contractual
obligations and commitments, which affects the supply of or 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 of economically hedging forecasted purchases and
sales, though none of these 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 of transactions 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 of transactions are excluded from the offsetting presented in the derivative fair value
and offsetting table below.
Name of Respondent
Idaho Power Company
This Report is:
(1) X An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
04/14/2020
Year/Period of Report
2019/Q4
NOTES TO FINANCIAL STATEMENTS (Continued)
FERC FORM NO. 1 (ED. 12-88)Page 123.41
Settlement gains and losses on electricity swap contracts are recorded on the income statement in revenues from contracts with
customers 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 16 - "Fair Value Measurements" for additional information
concerning the determination of fair value for Idaho Power’s assets and liabilities from price risk management activities.
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 of derivatives recognized as assets and as liabilities to the net amounts presented in
the balance sheets at December 31, 2019 and 2018 (in thousands of dollars):
Name of Respondent
Idaho Power Company
This Report is:
(1) X An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
04/14/2020
Year/Period of Report
2019/Q4
NOTES TO FINANCIAL STATEMENTS (Continued)
FERC FORM NO. 1 (ED. 12-88)Page 123.42
Credit Risk
Name of Respondent
Idaho Power Company
This Report is:
(1) X An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
04/14/2020
Year/Period of Report
2019/Q4
NOTES TO FINANCIAL STATEMENTS (Continued)
FERC FORM NO. 1 (ED. 12-88)Page 123.43
At December 31, 2019, 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 WSPP, Inc.
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 of these 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 of all derivative instruments with credit-risk-related contingent features
that were in a liability position at December 31, 2019, was $3.0 million. Idaho Power posted $1.4 million cash collateral related to
this amount. If the credit-risk-related contingent features underlying these agreements were triggered on December 31, 2019, Idaho
Power would have been required to pay or post collateral to its counterparties up to an additional $6.7 million to cover open liability
positions as well as completed transactions that have not yet been paid.
16. FAIR VALUE MEASUREMENTS
Idaho Power has categorized its financial instruments into a three-level fair value hierarchy, based on the priority of the 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 of the 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 for derivative instruments are based on quoted market prices adjusted for location using
Name of Respondent
Idaho Power Company
This Report is:
(1) X An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
04/14/2020
Year/Period of Report
2019/Q4
NOTES TO FINANCIAL STATEMENTS (Continued)
FERC FORM NO. 1 (ED. 12-88)Page 123.44
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 requires judgment 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, 2019 and 2018.
The following table presents information about Idaho Power’s assets and liabilities measured at fair value on a recurring basis as of
December 31, 2019 and 2018 (in thousands of dollars):
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 with quoted prices in an active market. Natural gas and diesel derivatives are valued using
New York Mercantile Exchange and Intercontinental Exchange pricing, adjusted for location basis, which are also quoted under
NYMEX and ICE pricing. Equity securities consist of employee-directed investments related to an executive deferred compensation
plan and actively traded money market and exchange traded funds related to the SMSP. The investments are measured using quoted
prices in active markets 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, 2019 and 2018, using available market information and appropriate valuation methodologies (in thousands).
Name of Respondent
Idaho Power Company
This Report is:
(1) X An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
04/14/2020
Year/Period of Report
2019/Q4
NOTES TO FINANCIAL STATEMENTS (Continued)
FERC FORM NO. 1 (ED. 12-88)Page 123.45
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.
17. CHANGES IN ACCUMULATED OTHER COMPREHENSIVE INCOME
Comprehensive income includes net income and amounts related to the SMSP. The table below presents changes in components of
accumulated other comprehensive income (AOCI), net of tax, during the years ended December 31, 2019 and 2018 (in thousands of
dollars). Items in parentheses indicate reductions to AOCI.
The table below presents the effects on net income of amounts reclassified out of components of AOCI and the income statement
location of those amounts reclassified during the years ended December 31, 2019 and 2018 (in thousands of dollars). Items in
parentheses indicate increases to net income.
Name of Respondent
Idaho Power Company
This Report is:
(1) X An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
04/14/2020
Year/Period of Report
2019/Q4
NOTES TO FINANCIAL STATEMENTS (Continued)
FERC FORM NO. 1 (ED. 12-88)Page 123.46
18. 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 $0.8 million in 2019 and $0.7 million in 2018.
At December 31, 2019 and 2018, Idaho Power had a $1.9 million payable to IDACORP, which was included in its accounts payable
to affiliates balance on its consolidated balance sheets.
Ida-West:Ida-West Energy Company (Ida-West) is a wholly-owned subsidiary of IDACORP and is an operator of small hydropower
generation projects that satisfy the requirements of the Public Utility Regulatory Policies Act of 1978. Idaho Power purchases all of
the power generated by four of Ida-West’s hydropower projects located in Idaho. Idaho Power paid Ida-West $8.6 million in 2019 and
$9.7 million in 2018 for that power.
Name of Respondent
Idaho Power Company
This Report is:
(1) X An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
04/14/2020
Year/Period of Report
2019/Q4
NOTES TO FINANCIAL STATEMENTS (Continued)
FERC FORM NO. 1 (ED. 12-88)Page 123.47
This Page Intentionally Left Blank
Name of Respondent
Idaho Power Company
I his Report Is:
(1)[xjAn Original
Date of Report
{Mo.Da,Yr)
04/14/2020
Year/Period ot Report
End of 2019/Q4(2)| |A Resubmission
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
Classification ElectricLine
No.(c)(a)(b)
1 Utility Plant
2 In Service
3 Plant in Service (Classified)6,112,816,292 6,112,816,292
4 Property Under Capital Leases
5 Plant Purchased or Sold
6 Completed Construction not Classified
7 Experimental Plant Unclassified
8 Total (3 thru 7)6,112,816,292 6,112,816,292
9 Leased to Others
10 Held for Future Use 3,871,699 3,871,699
1 1 Construction Work in Progress 552,498,787 552,498,787
12 Acquisition Adjustments 750,893 750,893
13 Total Utility Plant (8 thru 12)6,669,937,671 6,669,937,671
14 Accum Prov for Depr,Amort,&Depl 2,341,467,978 2,341,467,978
15 Net Utility Plant (13 less 14)4,328,469,693 4,328,469,693
16 Detail of Accum Prov for Depr,Amort &Depl
17 In Service:
18 Depreciation 2,313,565,686 2,313,565,686
I19Amort&Depl of Producing Nat Gas Land/Land Right
20 Amort of Underground Storage Land/Land Rights
21 Amort of Other Utility Plant 27,839,718 27,839,718
22 Total In Service (18 thru 21)2,341,405,404 2,341,405,404
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 62,574 62,574
33 Total Accum Prov (equals 14)(22,26,30,31,32)2,341,467,978 2,341,467,978
FERC FORM NO.1 (ED.12-B9)Page 200
Date of Report
(Mo,Da,Yr)
04/14/2020
Name of Respondent
Idaho Power Company
This Report Is:
(1)pg An Original
(2)£-|A Resubmission
ELECTRIC PLANT IN SERVICE (Account 101,102,103 and 106}
Year/Period of Report
End of 2019/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)
Line Account Balance
Beginning of Year
Additions
No.(a)(b)(c)
1 1.INTANGIBLE PLANT
2 (301)Organization 5,703
3 (302)Franchises and Consents 33.498,042 784.118
4 (303)Miscellaneous Intangible Plant 29,028,326 11,573,558
5 TOTAL Intangible Plant (Enter Total of lines 2,3,and 4)62,532,071 12,357,676
6 2.PRODUCTION PLANT
7 A.Steam Production Plant
8 (310)Land and Land Rights 1,722,421
9 (311)Structures and Improvements 156,069,228 2,111,918
10 (312)Boiler Plant Equipment 763,836,141 15,335,849
11 (313)Engines and Engine-Driven Generators
12 (314)Turbogenerator Units 172,389,727 1 .294.280
13 (315)Accessory Electric Equipment 74,658,335 111,433
14 (316)Misc.Power Plant Equipment 22,031,279 228,765
14,156,74515(317)Asset Retirement Costs for Steam Production 584.151
16 TOTAL Steam Production Plant (Enter Total of lines 8 thru 15)1,204,863,876 19,666,396
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 31,655,065 269,265
28 (331)Structures and Improvements 199,926,283 8,714,255
29 (332)Reservoirs,Dams,and Waterways 275,186,449 8,668,581
30 (333)Water Wheels,Turbines,and Generators 291,046,612 1,883.361
31 (334)Accessory Electric Equipment 63,782,202 2,315,954
32 (335)Misc.Power PLant Equipment 26,619,157 1,308,162
33 (336)Roads,Railroads,and Bridges 11,881,733 119,572
34 (337)Asset Retirement Costs for Hydraulic Production
35 TOTAL Hydraulic Production Plant (Enter Total of lines 27 thru 34)900,097,501 23,279,150
36 D.Other Production Plant
37 (340)Land and Land Rights 2,699,794
38 (341)Structures and Improvements 143,338,791 10,256,874
39 (342)Fuel Holders,Products,and Accessories 10,714,867
40 (343)Prime Movers 227,443,929 1,817,339
41 (344)Generators 66,714,048
42 (345)Accessory Electric Equipment 91,837,192 195,607
43 (346)Misc.Power Plant Equipment 6,491,088 258,973
44 (347)Asset Retirement Costs for Other Production
45 TOTAL Other Prod.Plant (Enter Total of lines 37 thru 44)549.239,709 12,528,793
46 TOTAL Prod.Plant (Enter Total of lines 16,25, 35,and 45)2,654,201,086 55,474,339
FERC FORM NO.1 (REV.12-05)Page 204
Name of Respondent
Idaho Power Company
This Report Is:
(1)fx]An Original
(2)| |A Resubmission
Dale of Report
(Mo.Da,Yr)
04/14/2020
Year/Period of Report
End of 2019/Q4
ELECTRIC PLANT IN SERVICE (Account 101,102,103 and 106)(Continued)
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 106 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 pf Year
Line
No.(e)(f)
1
5,703 2
34,282,160 3
4,559,559 36,042,325 4
4,559,559 70,330,188 5
6
7
1,722,421 8
25,456,769 132,724,377 9
95,950,017 683,221,973 10
11
21,695,066 151,988,941 12
16,990,156 57,779,612 13
3,506,357 18,753,687 14
14,740,896 15
163,598,365 1,060,931,907 16
17
18
19
20
21
22
23
24
25
26
31,924,330 27
476,842 208,163,696 28
92.955 283,762,075 29
1,057,282 291,872,691 30
493,214 65,604.942 31
309,028 27,618,291 32
12,001,305 33
34
2,429,321 920,947,330 35
36
2,699,794 37
169,333 153,426.332 38
276,619 10,438,248 39
7,122,304 222,138,964 40
66,714,048 41
36,376 91 ,996,423 42
104,937 6,645,124 43
44
7,709,569 554,058,933 45
173,737,255 2,535,938,170 46
FERC FORM NO.1 (REV.12-05)Page 205
Name of Respondent
Idaho Power Company
This Report Is:
(1)[XI An Original
(2)A Resubmission
ELECTRIC PLANT IN SERVICE (Account 101, 102.103 and 106)(Continued)
Date of Report
(Mo.Da,Yr)
04/14/2020
Year/Period of Report
End of 2019/Q4
Balance
Beginning of Year
Line Account Additions
No.(a)(c)M
47 3.TRANSMISSION PLANT
48 (350)Land and Land Rights
49 (352)Structures and Improvements
38,923,537 86,564
81,023,794 1,199,316
50 (353)Station Equipment 441,025,698 15,662,807
51 (354)Towers and Fixtures 211,357,840 3,749,251
52 (355)Poles and Fixtures 13,875,825195,207,683
53 (356)Overhead Conductors and Devices 233,163,083 9,112,908
54 (357)Underground Conduit
55 (358)Underground Conductors and Devices
56 (359)Roads and Trails 390,266
57 (359.1 )Asset Retirement Costs for Transmission Plant
58 TOTAL Transmission Plant (Enter Total of lines 48 thru 57)
59 4.DISTRIBUTION PLANT
1,201,091,901 43,686,671
60 (360)Land and Land Rights 6.553,285 831.412
61 (361)Structures and Improvements 40,283,756 7,626,265
62 (362)Station Equipment 254,363,384 18,088,390
63 (363)Storage Battery Equipment
64 (364)Poles,Towers,and Fixtures 271,695,898 14,246,292
65 (365)Overhead Conductors and Devices 140,485,165 5,534,717
66 (366)Underground Conduit 2,346,72752,238,001
67 (367)Underground Conductors and Devices 275,969,031 18,221,495
68 (368)Line Transformers 587,592,181 33,854,487
69 (369)Services 61,919,728 1,528,445
70 (370)Meters 93,327,295 7,740,607
71 (371)Installations on Customer Premises 3,124,332 86,066
72 (372)Leased Property on Customer Premises
73 (373)Street Lighting and Signal Systems 4,588,885 100,244
74 (374)Asset Retirement Costs for Distribution Plant 142,630,-142,630
75 TOTAL Distribution Plant (Enter Total of lines 60 thru 74)1,792,283,571 110,062,517
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
86 (389)Land and Land Rights 17,743,554 62,673
87 (390)Structures and Improvements 127,518,769 6,264,328
88 (391)Office Furniture and Equipment 48,506,483 5,789,019
89 (392)Transportation Equipment 92,865,678 8,129,169
90 (393)Stores Equipment 3,023,105 544,044
91 (394)Tools,Shop and Garage Equipment 11,094,864 866,055
92 (395)Laboratory Equipment 13,703,530 1,635,713
93 (396)Power Operated Equipment 19,234,311 3,625,092
94 (397)Communication Equipment 51,929,302 1,049,390
95 (398)Miscellaneous Equipment 7,376,604 376,755
96 SUBTOTAL (Enter Total of lines 86 thru 95)392,996,200 28,342,238
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)392,996,200 28,342,238
100 TOTAL (Accounts 101 and 106)6,103,104,829 249,923,441
101 (102)Electric Plant Purchased (See Instr.8)
102 (Less)(102)Electric Plant Sold (See Instr.8)
103 (103)Experimental Plant Unclassified
104 TOTAL Electric Plant in Service (Enter Total of lines 100 thru 103)6,103,104,829 249,923,441
FERC FORM NO.1 (REV.12-05)Page 206
Name of Respondent
Idaho Power Company
Date of Report
{Mo.Da,Yr)
04/14/2020
This Report Is:
(1)[XjAn Original
(2)j~jA Resubmission
ELECTRIC PLANT IN SERVICE (Account 101,102,103 and 106)(Continued)
Year/Period of Report
End of 2019/Q4
Retirements Adjustments Transfers Balance at
End ofYear
Line
No.(d)(e)(f)
47
39,010,101 48
591,258 81.631.852 49
19,597,540 50437,090,965
215,107,091 51
2,093,564 206.989,944 52
1,793,402 240,482,589 53
54
55
390,266 56
57
24,075,764 1,220,702,808 58
59
7,384,697 60
149,605 47,760,416 61
2,983,896 269,467,878 62
63
2,425,242 283,516,948 64
1,686,997 144,332,885 65
340.375 54,244,353 66
2,550,150 291,640,376 67
6,593,742 614,852,926 68
257,898 63,190,275 69
3,176,938 97,890,964 70
14,599 3,195,799 71
72
30,919 4,658,210 73
74
20,210,361 1,882,135,727 75
76
77
78
79
80
81
82
83
84
85
17,806,227 86
792,670 132,990,427 87
9,235,375 45,060.127 88
3,959,610.97,035,237 89
31,810 3,535,339 90
290,670 1 1 ,670,249 91
442,959 14,896,284 92
922,146 21,937,257 93
1,837,526 51,141,166 94
116,273 7,637,086 95
17,629,039 403,709,399 96
97
98
17,629.039 403,709,399 99
240,211,978 6,112,816,292 100
101
102
103
240,211,978 6,112,816,292 104
FERC FORM NO.1 (REV.12-05)Page 207
Name of Respondent
Idaho Power Company
This Report Is:
(1)pq An Original
(2)| |A Resubmission
ELECTRIC PLANT HELD FOR FUTURE USE (Account 105)
Date of Report
(Mo,Da,Yr)
04/14/2020
Year/Period of Report
2019/Q4Endof
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.
Description and Location Date Originally Included!Date Expected to be used
in This Account in Utilily Service
Balance at
End of YearLineOfPropertyNo.(b)(d)(c)
1 Land and Rights:
2 Boise Operations Center 12/31/82 2020/2021 480,501
3 Production 109,961
4 Transmission Stations 423,089
5 Transmission Lines 195,489
6 Distribution Stations 1,289,207
7 Homedale Substation 2/29/08 2035 109,453
8 Line #854 500 Kv 3/31/09 2024 308,066
9 Distribution Line 25,581
10
11
12 Column B and C if no date listed it is various
13
14
15
16
17
18
19
20
21 Other Property:
22 Transmission Stations 199,069
23 Distribution Stations 69,941
24 Homedale Substation 2/29/08 217,7972035
25 Underground Vault,Blaine County 8/30/16 2023 443,545
26
27
28
29 Column B and C If no date listed it is various
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46
47 Total 3,871,699
FERC FORM NO.1 (ED.12-96)Page 214
Name of Respondent
Idaho Power Company
This Report Is:
(1)[x]An Original
(2)Q A Resubmission
CONSTRUCTION WORK IN PROGRESS --ELECTRIC (Account 107)
Date of Report
(Mo,Da,Yr)
04/14/2020
Year/Period of Report
End of 2019/Q4
1.Report below descriptions and balances at end of year of projects in process of construction (107)
2.Show items relating to "research,development,and demonstration"projects last,under a caption Research,Development,and Demonstrating (see
Account 107 of the Uniform System of Accounts)
3.Minor projects (5%of the Balance End of the Year for Account 107 or $1,000,000,whichever is less)may be grouped.
Line Description of Project Construction work in progress -
Electric (Account 107)No.(a)(b)
ROLLUP RELIC COST BROWNLEE 122,479,5321
ROLLUP RELIC COST HELLS CANYON 83,404,3132
GATEWAY WEST 500KV LINE 41,232,5173
ROLLUP RELIC COST OXBOW 38,802,9534
HELLS CANYON RELICENSING OUTSI 35,835,6925
B2H PERMITTING 11/1/2011 &FOR 19,813,1796
BROWNLEE UNIT 2 TURBINE REFURB 13,639,7007
SHOSHONE FALLS UPGRADE -REPLA 10,418,3448
BOARDMAN -HEMINGWAY 500 KV LI 10,052,7939
HCC WATERSHED ENHANCEMENT PROG 8,324,78710
LOWER SALMON UNIT 2 REFURB 8,305,36911
UPPER MALAD FISH LADDER 6,995,93312
WQ HCC401 CERTIFICATION OPS AN 6,785,45313
LEGAL DEPT.LABOR FOR RELICENS 6,169,36014
BAYHA ISLAND RESEARCH PROJECT 5,205,77015
CDAL1 60001 4,246,38016
REL-HCC OREGON REAUTHORIZATION 4,233,02517
BULL TROUT PROGRAM -ADMINISTR 3,850,71618
B2H TLINE CONSTRUCTION COSTS 3,481,62919
STAT1 60001 NEW MC 3,268,15120
GRAND VIEW IRRIGATION UPGRADE 3,164,20121
BIRD NET REPLACEMENT 2017 CAPI 2,927,10522
WDRI-KCHM NEW 138KV 2,874,38023
PTSN PURCHASE AND INSTALL NEW 2,725,17424
FALL CHINOOK PROGRAM -REDD SU 2,707,65625
WQ HCC401 APPLICATION,REVISIO 2,633,26626
HBND-041:ALT LINE ROUTE TO GAR 2,593,92827
BROWNLEE UNIT 5 REWIND 2,406,25628
LOWER SALMON UNIT 1 REFURBISHM 2,245,08729
LOWER SALMON UNIT 3 REFURB 2,215,55130
HCC RELICENSING WATER QUALITY 2,183,96331
BROWNLEE SECURITY ENHANCEMENT 1,961,73232
BOBN170004 REPLACE C231 SERIES 1,913,67733
HC SEDIMENT PROGRAMS 1,833,36634
HOURLY SETTLEMENT BILLING 1,718,97235
SMART KEY FOBS &CORES 1,701,55236
BOCB1 70034 -MBE 9 PURCHASE A 1,629,24337
VAR1 160010 -PLANNING,SCOPING 1,552,43538
REPORTING MODEL FOR SNAKE RIVE 1 ,480,43539
WHITE STURGEON PROGRAM -HCC R 1 ,455,66240
VARI160010 -MOBILE VEHICLE RA 1,381,53441
BLISS CONCRETE REPAIR 1,378,66142
TOTAL43 552,498,787
FERC FORM NO.1 (ED.12-87)Page 216
This Page Intentionally Left Blank
Name of Respondent
Idaho Power Company
This Report Is:
(1)[x]An Original
(2)| |A Resubmissi
CONSTRUCTION WORK IN PROGRESS --ELECTRIC (Account 107)
Date of Report
(Mo,Da,Yr)
04/14/2020
Year/Period of Report
End of 2019/Q4
on
1 .Report below descriptions and balances at end of year of projects in process of construction (107)
2.Show items relating to "research,development,and demonstration"projects last,under a caption Research,Development,and Demonstrating (see
Account 107 of the Uniform System ofAccounts)
3.Minor projects (5%of the Balance End of the Year for Account 107 or $1,000,000,whichever is less)may be grouped.
Line Description of Project Construction work in progress -
Electric (Account 107)No.
(a)(b)
HCC SNAKE RIVER ENHANCEMENT RE 1 ,344,8391
2 CDAL1 70001 -EXTEND 230KV SERV 1 ,206,949
3 HELLS CANYON ROCKFALL MITIGATI 1,030,713
HCC RELICENSING:HART AND 4014 1,011,333
5 BOC SITE EXPANSION:NEW STC B 1,004,474
6 Other Minor Projects Under $1 ,000,000 63,671,047
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43 TOTAL 552,498,787
FERC FORM NO.1 (ED.12-87)Page 216.1
Name of Respondent
Idaho Power Company
This Report Is:
(1)[xjAn Original
(2)| |A Resubmission
ACCUMULATED PROVISION FOR DEPRECIATION OF ELECTRIC UTILITY PLANT (Account 108)
Date of Report
(Mo,Da,Yr)
04/14/2020
Year/Period of Report
End of 2019/Q4
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
Line Item (c+3+e)Electric Plant in
Service Electric Plant Held Electric PlantLeasedtoOthersforFutureUseNo.(a)(b)(c)(e)(d)
1 Balance Beginning of Year 2,369,301,348 2,369,301,348
2 Depreciation Provisions for Year,Charged to
3 (403)Depreciation Expense 160,145,693 160,145,693
4 (403.1)Depreciation Expense for Asset
Retirement Costs
566,665 566,665
5 (413)Exp.of Elec.Pit.Leas,to Others
6 Transportation Expenses-Clearing 4,921,624 4,921,624
7 Other Clearing Accounts
8 Other Accounts (Specify,details in footnote):
9 Fuel Stock 241,578 241,578
10 TOTAL Deprec.Prov for Year (Enter Total of
lines 3 thru 9)
165,875,560 165,875,560
11 Net Charges for Plant Retired:
12 Book Cost of Plant Retired 235,652,420 235,652,420
13 Cost of Removal 14,947,193 14,947,193
14 Salvage (Credit)1,041,889 1,041,889
15 TOTAL Net Chrgs.for Plant Ret.(Enter Total
of lines 12 thru 14)
249,557,724 249,557,724
16 Other Debit or Cr.Items (Describe,details in
footnote):
27,946,50227,946,502
17
18 Book Cost or Asset Retirement Costs Retired
19 Balance End of Year (Enter Totals of lines 1,
10,15, 16,and 18)
2,313,565,686 2,313,565,686
Section B.Balances at End of Year According to Functional Classification
20 Steam Production 592,496,235 592,496,235
21 Nuclear Production
22 Hydraulic Production-Conventional 446,783,960 446,783,960
23 Hydraulic Production-Pumped Storage
24 Other Production 120,948,585 120,948,585
25 Transmission 371,992,159 371,992,159
26 Distribution 657,914,261 657,914,261
27 Regional Transmission and Market Operation
28 General 123,430,486 123,430,486
29 TOTAL (Enter Total of lines 20 thru 28)2,313,565,686 2,313,565,686
FERC FORM NO.1 (REV.12-05)Page 219
Name of Respondent Date of Report Year/Period of ReportThisReportis:
(Mo,Da,Yr)(1)X An Original
(2)_A ResubmissionIdahoPowerCompany 04/14/2020 2019/Q4
FOOTNOTE DATA
Schedule Page:219 Line No.:16 Column:c
Valmy depreciation adjustments
Obligation activity.
CIAC and Asset Retirement(ID 33771 and OR 17-235),
FERC FORM NO.1 (ED.12-87)Page 450.1
This Report Is:
(1)[X]An Original
(2)Q A Resubmission
INVESTMENTS IN SUBSIDIARY COMPANIES (Account 123.1)
Date of Report
(Mo,Da,Yr)
04/14/2020
Year/Period of Report
End of 2019/Q4
Name of Respondent
Idaho Power Company
1.Report below investments in Accounts 123.1,investments in Subsidiary Companies.
2.Provide a subheading for each company and List there under the information called for below.Sub -TOTAL by company and give a TOTAL in
columns (e),(f),(g)and (h)
(a)Investment in Securities -List and describe each security owned.For bonds give also principal amount,date of issue,maturity and interest rate.
(b)Investment Advances -Report separately the amounts of loans or investment advances which are subject to repayment,but which are not subject to
current settlement.With respect to each advance show whether the advance is a note or open account.List each note giving date of issuance,maturity
date,and specifying whether note is a renewal.
3.Report separately the equity in undistributed subsidiary earnings since acquisition.The TOTAL in column (e)should equal the amount entered for
Account 418.1.
Line Description of Investment Amount of Investment at
Beginning of Year
Date Of
MajorityDateAcquired
No.(a)(b)(d)
1 Idaho Energy Resources Company
2 Common Stock 02/01/74 500
3 Capital contributions 2,462,594
4 Equity in earnings 54,563,677
5
6 Subtotal Idaho Energy Resources Company 57,026,771
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 Total Cost of Account 123.1 $TOTAL2,463,094 57,026,771
FERC FORM NO.1 (ED.12-89)Page 224
This Report is:
(1)[X]An Original
(2)|J A Resubmission
INVESTMENTS IN SUBSIDIARY COMPANIES (Account 123,1)(Continued)
Name of Respondent
Idaho Power Company
Date of Report
(Mo.Da,Yr)
04/14/2020
Year/Period of Report
End of 2019/Q4
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
"Revenues for YearEquityinSubsidiary
Earninas of Year
Amount of Investment at
End ^Year
Gain or Loss from Investment
Disposed of
Line
fej No.(f)
1
500 2
2,462,594 3
8,489,145 40,000,000 23,052,822 4
5
8,489,145 40,000,000 25,515,916 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
8,489,145 40,000,000 25,515,916 42
FERC FORM NO.1 (ED.12-89)Page 225
Name of Respondent
Idaho Power Company
This Report Is:
(1)[x]An Original
(2)||A Resubmission
Date of Report
(Mo,Da,Yr)
04/14/2020
Year/Period of Report
End of 2019/Q4
MATERIALS AND SUPPLIES
1 .For Account 154,report the amount of plant materials and operating supplies under the primary functional classifications as indicated in column (a);
estimates of amounts by function are acceptable.In column (d),designate the department or departments which use the class of material.
2.Give an explanation of important inventory adjustments during the year (in a footnote)showing general classes of material and supplies and the
various accounts (operating expenses,clearing accounts,plant,etc.)affected debited or credited.Show separately debit or credits to stores expense
clearing,if applicable.
Line Account Balance
Beginning of Year
Balance
End of Year
Department or
Departments which
Use Material
No.
(a)(b)(d)(c)
Fuel Stock (Account 151)1 47,979,122 57,447,554 Electric
2 Fuel Stock Expenses Undistributed (Account 152)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)17,733.796 18,044,916
8 Transmission Plant (Estimated)9,422,601 7,751,239
9 Distribution Plant (Estimated)27,160,500 27,522,183
10 Regional Transmission and Market Operation Plant
(Estimated)
1 1 Assigned to -Other (provide details in footnote)-763,223 920,624
12 TOTAL Account 154 (Enter Total of lines 5 thru 11)53,553,674 54,238,962 Electric
1 3 Merchandise (Account 155)
14 Other Materials and Supplies (Account 156)
15 Nuclear Materials Held for Sale (Account 157)(Not
applic to Gas Util)
16 Stores Expense Undistributed (Account 163)1,433,652 2,420,600
17
18
19
20 TOTAL Materials and Supplies (Per Balance Sheet)102,966,448 114,107,116
FERC FORM NO.1 (REV.12-05)Page 227
Name of Respondent This Report is:
(1)X An Original
(2)_A Resubmission
Date of Report Year/Period of Report
(Mo,Da,Yr)
04/14/2020IdahoPowerCompany 2019/Q4
FOOTNOTE DATA
Schedule Page:227 Line No.:11 Column:c
This amount represents miscellaneous inventory that is not yet assigned to a particular
function .
FERC FORM NO.1 (ED.12-87)Page 450.1
Name of Respondent
Idaho Power Company
Date of Report
(Mo,Da,Yr)
04/14/2020
This Report Is:
(1)[X]An Original
(2)||A Resubmission
Year/Period of Report
End of 2019/Q4
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.
1 It Line Reimbursements
Received During
the Period
Costs Incurred During
Period
Account Credited
With ReimbursementNo.Description Account Charged
(a)(b)(c)(d)(e)
1 Transmission Studies
2 IPCL TRANS SIS 88754178 48,318 186623 (61,993)186623
3 BPAP NETWORK SIS 90030618 (10,000)1866234,343 186623
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21 Generation Studies
22 BAKER CITY 1 SOLAR (176)186623
23 WARM SPRINGS HYDRO #526 28,983 186623
24 AMALGAMATED SUGAR #531 17,724 186623
25 CAT CREEK PUMP STORAGE #530 (58,943)18662338,303 186623
GEM-VALE #534 300MW26 11.716 (86,730)186623186623
27 GEM-VALE WIND #53 500MW 9,327 186623 55,124 186623
28 VERDE LIGHT POWER #532 3MW 7,304 186623 (16,372)186623
29 BORREGO SOLAR #533 3,693 186623
OLD CAMP SOLAR 80MW30 11,228 186623 (50,823)186623
31 MASON DAM HYDRO #538 2MW 500 186623
32 OPAL SOLAR #539 677 186623 (677)186623
MOONSTONE SOLAR #54133 (10,677)1866236,276 186623
34 FRANKLIN SOLAR #549 12,035 186623 (50,000)186623
35 ADA COUNTY BIOMASS #554 1,866 186623 (1,866)186623
36 PRAIRIE CITY SOLAR #556 18,356 186623 (60,000)186623
ARH SOLAR #55837 2,190 186623 (60,000)186623
38 BLACK MESA ENERGY #557 6,395 186623 (10,000)186623
39 MC6 HYDRO #559 2,166 186623 (10,000)186623
40 BENNETT SOLAR 1 #551 6,222 186623 (20,000)186623
FERC FORM NO.1/1-F/3-Q (NEW.03-07)Page 231
Name of Respondent
Idaho Power Company
This Report Is:
(1)[Xj An Original
(2)[|A Resubmission
Transmission Service and Generation Interconnection Study Costs (continued)
Date of Report
(Mo,Da,Yr)
04/14/2020
Year/Period of Report
End of 2019/Q4
Line Reimbursements
Received During
the Period
Costs Incurred During
Period
Account Credited
With ReimbursementNo.Description Account Charged
(d)(e)(a)(b)(c)
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
BENNETT SOLAR 2 #552 (20,000)186623224,030 186623
BENNETT SOLAR 3 #553 (20,000)186623232,935 186623
BENNETT SOLAR 4 #560 (10,000)186623244,746 186623
COLEMAN HYDRO #548 (11,000)186623253,294 186623
26 MIDPOINT SOLAR #561 (10,000)186623
MOORE HOLLOW SOLAR #561 (20,000)18662327
DURKEE SOLAR #546 (11,000)186623282,132 186623
PLEASANT VALLEY SOLAR #568 (20,000)186623291,947 186623
(10,000)18662330ARCOWIND950MW#563
ARCO SOLAR 950MW #563 6,722 18662331
PIGEON COVE HYDRO-MV90 METER INSL (1,500)18662332
SAWTOOTH SOLAR #572 (783)18662333783186623
34 MOON CRATER SOLAR #57 293 (30,000)186623186623
MAGIC VALLEY ENERGY #572 1,221 (30,000)18662335186623
OLD OREGON TRAIL 1 #568 (10,000)18662336
JACOBSON SOLAR #566 (1,000)18662337
38
39
40
FERC FORM NO.1/1-F/3-Q (NEW.03-07)Page 231.1
This Page Intentionally Left Blank
Date of Report Year/Period of Report
(Mo,Da,Yr)
04/14/2020
Name of Respondent This Report is:
(1)X An Original
(2)_A Resubmission 2019/Q4IdahoPowerCompany
FOOTNOTE DATA
Schedule Page:231 Line No.:23 Column:d
Amounts represent both reimbursements received (credit amounts)and refunds back to the
counterparties (debit amounts).Refunds are initiated when the initial deposit exceeds
the final expenses.
FERC FORM NO.1 (ED.12-87)Page 450.1
Name of Respondent
Idaho Power Company
This Report Is:
(1)[X]An Original
Date of Report
(Mo,Da,Yr)
04/14/2020
Year/Period of Report
End of 2019/(34
(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/Year Account
Charged (f)(a)(b)(c)(e)
34,502,069 35,208,267 400 34,502,069FixedCostAdjustment(FCA)(182302)35,208,2671
2 Order Pending (Amort period 06/20 thru 05/21
3
(107,935)248,407 2283 47,2704AOCIImpactofUnfundedPostRetirementLiability 93,202
5 Order#30256 (182306)
6
881,510 2,059,3407FCACalenderMoAdjustment 2,940,850
8
7,119,639 34,788,276 400 26,040,501PriorYearFCA-Order#33527 (182309)15,867,4149
10 Order $34346 (Amortization period 06/19 thru 05/20)
11
278,781,669 82,630,675 2283 13,571,003AOCIImpactofUnfundedPensionLiability 347,841,34112
Order#30256 (182320)13
14
21,024,974 39,379,047 1823 38,116,777DeferredPensionExpenseNetofContributions 22,287,24415
Order #30333 (182321)16
17
358,202,341 41,065,081FAS109Unfunded(182322)399,267,42218
Accum Deferred Income Noncurrent19
20
126,810,747 40,692,724 Various 17,153,713IdahoPensionCash-Order #32248 (182327)150,349,75821
22 (Amort period beginning 06/1 1 thru indefinite)
23
910,525 88,264ASC815MarktoMarketShort-Term (182330)244 822,26124
25
4,896,573 699,265 4073 153,953OregonPensionExpenseCapitalized(182339)5,441,88526
Order #10-06427
28
17,563,478 1,226,00929AssetRetirementObligations(182341)18,789,487
IPUC Order#29414-OPUC Order #04-58530
31
313,506RA-Hells Canyon-Baker Co (182360)313,50632
Order#3394833
34
130,814 43,605LidarSurveys-Order#32426 (182361)402 87,20935
(Amort period 01/12 thru 12/21)36
37
192,471 3,719RA-lntervenor Funding-Idaho (182387)196,19038
Muliltple IPUC Orders39
40
255,941,746 8,323,141RA-CONTRA-DEF INC TAX (182389)Various 247,618,60541
42
Idaho Boardman ARO -Order#29414 (18239343
Page 232FERCFORMNO.1/3-Q (REV.02-04)
Year/Period of Report
End of 201 !9'Q4
Date of Report
(Mo,Da,Yr)
04/14/2020
Name of Respondent
Idaho Power Company
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
CREDITS Balance at end of
Current Quarter/Year
DebitsLineDescriptionandPurposeof
Other Regulatory Assets Written off During
the Period Amount
No.Written offDuring the
Quarter/Year AccountQuarter/Year
Charged (f)(e)(b)(c)(a)
1,282,099 102,724 1,384,823LangleyRevenueAccrual(182398)1
2 Advice #12-226
3
38,114(159,711)-197,82541904RA-OR Langley Rev Int Res (182399)
5
431,48810,338,443 9,906,95540736SiemensLongTermDeferredRateBase(182410)
7 Order #33420 (Amort period 01/16 thru 12/43)
8
643,86615,427,037 14,783,1714073SiemensLongTermDeferredRateBase(182411)g
Order #33420 (Amort period 01/16 thru 12/43)10
11
44,04731,785 Various415,298 403,036SiemensLongTermDeferredRateBase(182412)12
Order #15-387 (Amort period 01/16 thru 12/36)13
14
39,316668,368 629,0524073SiemensLongTermDeferredRateBase(182413)15
Order #15-387 (Amort period 01/16 thru 12/36)16
17
31,785(100,562)-132,3474190SeimensLongTermInterestReserve(182414)18
19
207,828(2,708,051)4,323,199 Various 1,407,320RA-Valmy O&M ID (182432)20
IPUC Order#3377121
22
888,513888,513 403RA-Valmy OR Depr Adj 17-325 (182434)23
24 (Amort period 06/17 thru 12/25)
25
28,137,49777,249,844 105,387,341RA-Valmy Acctg Adj ID (182435)26
IPUC Order#3377127
28
1,643,007299,752 Various1,997,400 654,145RA-Valmy Decomm OR (182436)29
OPUC Advice #17-235 (Amort period 06/17 thru 12/2530
31
(5,438,694)5,438,694IdahoBoardmanDecomissioning(182493)32
IPUC Order#32549 &#3245733
34
5,292,8565,292,856 254RA-ID Boardman Decomm (182495)35
IPUC Order #3245736
37
237,789237,789 254RA-OR Boardman Decomm (182496)38
OPUC Advice #12-23539
40
37,758,93538,069,980 Various 311,045IdahoDSMRider41
IPUC Order #2866142
43
Page 232.1FERCFORMNO.1/3-Q (REV.02-04)
Year/Period of Report
Endof 2019/Q4
Date of Report
(Mo,Da,Yr)
04/14/2020
Name of Respondent
Idaho Power Company
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
DebitsDescriptionandPurposeof
Other Regulatory Assets
Line
Written off During
the Period Amount
No.Written off During the
Quarter /Year Account
Charged
Quarter/Year
(f)(e)(b)(c)(a)
2,125,2371,397,749 1,881,768 Various 1,154,280OregonDSMRider(254202)1
2 Advice #05-03
3
201,535221,912 223,310 Various 243,6874MinorItems(9)
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
1,383,059,324356,509,519 "5 187,624,61244TOTAL:1,214,174,417
Page 232.2FERCFORMNO.1/3-Q (REV.02-04)
Date of Report Year/Period of Report
(Mo,Da,Yr)
04/14/2020
Name of Respondent This Report is:
(1)X An Original
(2)_A Resubmission 2019/Q4IdahoPowerCompany
FOOTNOTE DATA
Schedule Page:232.1 Line No.:32 Column:a
During 2019,this balance was reclassed to a Regulatory Liability for financial statement
presentation .
Schedule Page:232.1 Line No.:35 Column:a
During 2019,this balance was reclassed to a Regulatory Liability for financial statement
assentation.
Schedule Page:232.1 Line No.:38 Column:a
During 20i9,this balance was reclassed to a Regulatory Liability for financial statement
presentation .
1SchedulePage:232.1 Line No.:41 Column:a
During 2019,this balance was reclassed from a Regulatory Liability to a Regulatory Asset
for financial statement presentation.
FERC FORM NO.1 (ED.12-87)Page 450.1
This Page Intentionally Left Blank
Name of Respondent
Idaho Power Company
This Report Is:
(1)[X]An Original
Date of Report
(Mo,Da,Yr)
04/14/2020
Year/Period of Report
End of 2019/Q4(2)||A Resubmission
MISCELLANEOUS DEFFERED DEBITS (Account 186)
1 .Report below the particulars (details)called for concerning miscellaneous deferred debits.
2.For any deferred debit being amortized,show period of amortization in column (a)
3.Minor item (1%of the Balance at End of Year for Account 186 or amounts less than $100,000,whichever is less)may be grouped by
classes.
DebitsDescriptionofMiscellaneous
Deferred Debits
Balance at
Beginning of Year
CREDITS Balance at
End of Year
Line
Account
ChargedNo.Amount
(a)(b)(c)(e)ill
1 Prepaid Credit Facility 186025
2 Amortization period 12/19-12/24
746,660 1 ,647,040 Various 1,192,140 1.201,560
3
4 Prepaid Services (LT)1 86052 3,673,840 Various 609,703 3,064,137
5 Amortization periods -multiple
6
7 Workers Compensation 186121 1,118,612 401 156,354 962,258
8
9 Prepaid ROW(LT)186160 618,779 401 43,902 574,877
10 Amortization periods -multiple
11
12 Prepaid Services (LT)186255 189,930 401 15,430 174,500
13 Amortization periods -multiple
14
15 CARB Inventory 186650 843,050 428,350 242 275,967 995,433
16
17 Coal Royalties 186709 943,618 151 71,673 871,945
18
19 Stable Value Life Inv 186719 45,435,744 3,181,628 48,617,372
20
Security Plan 18672021 10,567,539 127,320 4262 4,387,108 6,307,751
22 Net Insurance Asset
23
24 Retiree Medical-COLI 186726 3,849,093 301,710 4262 153,551 3,997,252
25
26 American Falls Water Rts 186727 6,338,887 401 1,042,009 5,296,878
27 Amortization period 01/06-02/25
28
29 American Falls Bond Refi 186770 295,995 401 47,999 247,996
30 Amortization period 1 2/09-02/25
31
32 Regulatory Reserves 186800 -1,122,387 4190 64,609 -1,186,996
33
34 Minor Items (6)95,613 2,382,374 Various 2,290,238 187,749
35
36
37
38
39
40
41
42
43
44
45
46
47 Misc.Work in Progress
Deferred Regulatory Comm.
Expenses (See pages 350 -351)48
49 TOTAL 73,405,043 71,312,712
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
ACCUMULATED DEFERRED INCOME TAXES (Account 190)
Date of Report
(Mo.Da,Yr)
04/14/2020
Year/Period of Report
End of 2019/Q4
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 at End
of Year
Balance of Begining
of YearNo.(a)(b)(c)
1 Electric
2
3
4
5 Other Electric (See footnote)84,487,16096,930,307
6
7 Other (See footnote)198,768,052178,068,785
8 TOTAL Electric (Enter Total of lines 2 thru 7)283,255,212274,999,092
Gas9
10
11
12
13
14
15 Other
16 TOTAL Gas (EnterTotal of lines 10 thru 15
18,905,81917OtherNonElectric(See footnote)18,384,170
1 8 TOTAL (Acct 190)(Total of lines 8,16 and 17)293,383,262 302,161,031
Notes
Page 234FERCFORMNO.1 (ED.12-88)
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 04/14/2020 2019/Q4
FOOTNOTE DATA
Schedule Page:234 Line No.:5 Column:c
Beginning Balance Ending Balance
Construction Advances
Postretirement Benefits
USBR-American Falls O&M Costs Settlement
Non-VEBA Pension and Benefits
Executive Deferred Compensation
Stock Based Compensation
Pension Expense-Oregon
Bridger Revenue Deferral
Asset Retirement Obligation (ARO)
Incentive Deferral-Profit Sharing-Not in Rates
OR Reconnect Fees Adv
Tax Reform Regulatory Stipulation
Rate Case Disallowance
Unrealized Loss on Investments
Provision for Rate Refunds
Prov for Rate Refund-HC Relicensing (AFUDC)
Revenue Sharing
VEBA-Post Retirement Benefits
Deferred Idaho ITC
Deferred GBC Federal
Total Other Electric
1,082,811
313,224
64,475
(468,289)
4,427
3,437,429
3,019,304
499,057
1,423,588
3,491,132
1 ,262,434
419,012
55,478
(557,867)
4,341
3,036,306
3,378,637
652,901
1 ,629,409
3,464,858
1,718
2,497,753
1,191,952
955
0
1,268,220
0 129
349,943
39,039,171
0
35,136,616
1,293,322
8,976,089
26,408,291
10,979,656
0
8,714,850
19,346,135
0
96,930,307 84,487,160
ISchedulePage:234 Line No.:7 Column:c
Beginning Balance Ending Balance
Pension-FAS 158 72,101,874
98,042,217
7,952,476
(27,782)
178,068,785
89,534,362
96,598,638
12,611,062
23,990
Regulatory Liability-FAS 109
Minimum Pension Liability
Postretirement Plan-FAS 158
Total Other 198,768,052
Schedule Page:234 Line No.:17 Column:c
Beginning Balance Ending Balance
Senior Management Security Plan
Total Non Electric
18,384,170 18,905,819
18,384,170 18,905,819
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
CAPITAL STOCKS (Account 201 and 204)
Date of Report
(Mo.Da,Yr)
04/14/2020
Year/Period of Report
End of 2019/Q4
1 .Report below the particulars (details)called for concerning common and preferred stock at end of year,distinguishing separate
series of any general class.Show separate totals for common and preferred stock.If information to meet the stock exchange reporting
requirement outlined in column (a)is available from the SEC 10-K Report Form filing,a specific reference to report form (i.e.,year and
company title)may be reported in column (a)provided the fiscal years for both the 10-K report and this report are compatible.
2.Entries in column (b)should represent the number of shares authorized by the articles of incorporation as amended to end of year.
Line Class and Series of Stock and
Name of Stock Series
Number of shares
Authorized by Charter
Par or Stated
Value per share
Call Price at
End of YearNo.
(a)(b)(c)(d)
1 Account 201
2 Common Stock all of which is held by 50,000,000 2.50
3 IdaCorp,Inc.and not traded
4 Total Common Stock 50,000,000 2.50
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
Date of Report
(Mo,Da,Yr)
04/14/2020
Year/Period of ReportNameofRespondent
Idaho Power Company
This Report Is:
(1)[X]An Original
(2)||A Resubmission
CAPITAL STOCKS (Account 201 and 204)(Continued)
2019/Q4Endof
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 FUNDSASREACQUIREDSTOCK(Account 217)
Shares Amount Shares Cost Shares Amount
G)(e)(f)(9)(h)G)
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
FERC FORM NO.1 (ED.12-88)Page 251
Year/Period of Report
End of 2019/Q4
Date of Report
(Mo,Da,Yr)
04/14/2020
Name of Respondent
Idaho Power Company
This Report Is:
(1)[x]An Original
(2)|—|A Resubmission
OTHER PAID-IN CAPITAL (Accounts 208-21 1 ,inc.)
Report below the balance at the end of the year and the information specified below for the respective other paid-in capital accounts.Provide 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.
"AfrwTjei
.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
Name of Respondent
Idaho Power Company
Date of Report
(Mo,Da,Yr)
04/14/2020
Year/Period of Report
End of 2019/Q4
This Report Is:
(1)|X|An Original
(2)| |A Resubmission
CAPITAL STOCK EXPENSE (Account 214)
1 .Report the balance at end of the year of discount on capital stock for each class and series of capital stock.
2.If any change occurred during the year in the balance in respect to any class or series of stock,attach a statement giving particulars
(details)of the change.State the reason for any charge-off of capital stock expense and specify the account charged.
Line Class and Series of Stock Balance at End of"Year
(b)(a)No.
Common Stock1 2,096,925
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
22 TOTAL 2,096,925
FERC FORM NO.1 (ED.12-87)Page 254b
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)
04/14/2020
Year/Period of Report
End of 2019/Q4
1 .Report by balance sheet account the particulars (details)concerning long-term debt included in Accounts 221 ,Bonds,222,
Reacquired Bonds,223,Advances from Associated Companies,and 224,Other long-Term Debt.
2.In column (a),for new issues,give Commission authorization numbers and dates.
3.For bonds assumed by the respondent,include in column (a)the name of the issuing company as well as a description of the bonds.
4.For advances from Associated Companies,report separately advances on notes and advances on open accounts.Designate
demand notes as such.Include in column (a)names of associated companies from which advances were received.
5.For receivers,certificates,show in column (a)the name of the court -and date of court order under which such certificates were
issued.
6.In column (b)show the principal amount of bonds or other long-term debt originally issued.
7.In column (c)show the expense,premium or discount with respect to the amount of bonds or other long-term debt originally issued.
8.For column (c)the total expenses should be listed first for each issuance,then the amount of premium (in parentheses)or discount.
Indicate the premium or discount with a notation,such as (P)or (D).The expenses,premium or discount should not be netted.
9.Furnish in a footnote particulars (details)regarding the treatment of unamortized debt expense,premium or discount associated with
issues redeemed during the year.Also, give in a footnote the date of the Commission's authorization of treatment other than as
specified by the Uniform System of Accounts.
Line Class and Series of Obligation,Coupon Rate
(For new issue,give commission Authorization numbers and dates)
Principal Amount
Of Debt issued
Total expense,
Premium or DiscountNo.
(c)(b)(a)
1 Account 221:
2 First Mortgage Bonds:
3 5.50%Series due 2033 70,000,000 728,701
4 36,400 D
5
6 3.40%Series due 2020 1,159,871100,000,000
7 499,000 D
8
9 5.30%Series Due 2035 60,000,000 3,849,739
10 408,600 D
11
12 4.00%Series due 2043 75,000,000 742,017
194,250 D13
14
15 6.00%Series due 2032 100,000,000 1,191,216
16 544,000 D
17
18 5.875%Series due 2034 585,75955,000,000
748,000 D19
20
21 5.50%Series due 2034 50,000,000 524,419
383,500 D22
23
24 4.85%Series Due 2040 100,000,000 1,284,871
25 170,000 D
26
27 6.30%Series due 2037 1,500,031140,000,000
28 278,600 D
29
30 6.25%Series due 2037 100,000,000 1,227,490
268,000 D31
32
33 TOTAL 2,021,445,000 33,876,373
FERC FORM NO.1 (ED.12-96)Page 256
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)(Continued)
Date of Report
(Mo,Da,Yr)
04/14/2020
Year/Period of Report
2019/Q4Endof
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)
AMORTIZATION PERIOD Line
Nominal Date
of Issue
Date of
Maturity
Interest for Year
Amount No.Date From Date To
(d)(e)(f)(g)(i)
1
2
5/13/03 4/01/33 5/13/03 3/31/33 70,000,000 3,850,000 3
4
5
8/30/10 11/01/20 8/30/10 11/01/20 100,000,000 3,400,000 6
7
8
8/26/05 8/15/35 8/26/05 8/15/35 60,000,000 3,180,000 9
10
11
4/08/13 4/01/43 4/08/13 4/01/43 75,000,000 123,000,000
13
14
11/15/02 11/15/32 11/15/02 11/15/32 100,000,000 6,000,000 15
16
17
8/16/04 8/15/34 8/16/04 8/15/34 55,000,000 3,231,250 18
19
20
3/26/04 3/15/34 3/15/343/26/04 50,000,000 2,750,000 21
22
23
8/30/10 8/15/40 8/30/10 8/15/40 100,000,000 4,850,000 24
25
26
6/22/07 6/15/37 6/22/07 6/15/37 140,000,000 8,820,000 27
28
29
10/15/37 10/18/0710/18/07 10/15/37 100,000,000 6,250,000 30
31
32
331,855,345,000 82,457,050
FERC FORM NO.1 (ED.12-96)Page 257
This Report Is:
(1)[X]An Original
(2)|A Resubmission
LONG-TERM DEBT (Account 221. 222,223:and 224}
Name of Respondent
Idaho Power Company
Date of Report
(Mo,Da,Yr)
04/14/2020
Year/Period of Report
End of 2019/Q4
1 .Report by balance sheet account the particulars (details)concerning long-term debt included in Accounts 221 ,Bonds,222,
Reacquired Bonds,223,Advances from Associated Companies,and 224,Other long-Term Debt.
2.In column (a),for new issues,give Commission authorization numbers and dates.
3.For bonds assumed by the respondent,include in column (a)the name of the issuing company as well as a description of the bonds.
4.For advances from Associated Companies,report separately advances on notes and advances on open accounts.Designate
demand notes as such.Include in column (a)names of associated companies from which advances were received.
5.For receivers,certificates,show in column (a)the name of the court -and date of court order under which such certificates were
issued.
6. In column (b)show the principal amount of bonds or other long-term debt originally issued.
7. In column (c)show the expense,premium or discount with respect to the amount of bonds or other long-term debt originally issued.
8.For column (c)the total expenses should be listed first for each issuance,then the amount of premium (in parentheses)or discount.
Indicate the premium or discount with a notation,such as (P)or (D).The expenses,premium or discount should not be netted.
9.Furnish in a footnote particulars (details)regarding the treatment of unamortized debt expense,premium or discount associated with
issues redeemed during the year. Also,give in a footnote the date of the Commission's authorization of treatment other than as
specified by the Uniform System of Accounts.
Line Class and Series of Obligation,Coupon Rate
(For new issue,give commission Authorization numbers and dates)
Principal Amount
Of Debt issued
Total expense,
Premium or DiscountNo.
(c)(b)(a)
Port of Morrow Variable due 20271 4,360,000 189,597
2
3 Humboldt 5.15%due 2024 49,800,000 1,309,010
4
5 Humboldt 1 .45%due 2024 49,800,000 396,278
6
7 Sweetwater 5.25%due 2026 116,300,000 3,044,152
8
9 Sweetwater 1.70%due 2026 116,300,000 908,982
10
11 2.50%Series due 2023 75,000,000 648,267
12 374,250 D
13
14 4.30%Series Due 2042 75,000,000 802,240
15 49,500 D
16
17 2.95%Series Due 2022 75,000,000 708,490
18 128,250 D
19
20 3.65%Series Due 2045 250,000,000 2,559,510
21 1,715,000 D
22
23 4.05%Series Due 2046 120,000,000 1,311,383
24 309,600 D
25
26 4.20%Series Due 2048 220,000,000 2,283,400
Idaho Order #33513 (4/27/16)27 814,000 D
Oregon Order #16-151 (4/21/16)28
29 Wyoming Docket #20005-37-ES1 6 (5/17/16)
30
Subtotal Account 22131 2,001,560,000 33,876,373
32
TOTAL33 2,021,445,000 33,876,373
FERC FORM NO.1 (ED.12-96)Page 256.1
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)(Continued)
Date of Report
(Mo,Da,Yr)
04/14/2020
Year/Period of Report
2019/Q4Endof
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
respondent)
AMORTIZATION PERIOD Line
Date of
Maturity
Interest for Year
Amount
Nominal Date
of Issue No.Date From Date To
(d)(e)(f)(g)(i)
5/17/00 2/01/27 05/17/00 02/01/27 4,360,000 74,135 1
2
8/20/09 12/01/24 8/20/09 12/01/24 1,638,558 3
4
8/21/19 12/01/24 8/21/19 12/01/24 49,800,000 260,758 5
6
8/20/09 7/15/26 8/20/09 7/15/26 3,900,896 7
8
7/15/268/21/19 8/21/19 7/15/26 116,300,000 713,953 9
10
4/08/13 4/01/23 4/08/13 4/01/23 1,875,000 1175,000,000
12
13
4/13/12 4/01/42 4/13/12 4/01/42 75,000,000 3,225,000 14
15
16
4/13/12 4/01/22 4/13/12 4/01/22 2,212,50075,000,000 17
18
19
3/06/15 3/01/45 3/06/15 3/01/45 250,000,000 9,125,000 20
21
22
3/10/16 3/01/46 3/10/16 3/1/46 120,000,000 4,860,000 23
24
25
3/16/18 3/01/48 3/16/18 3/01/48 220,000,000 9,240,000 26
27
28
29
30
1,835,460,000 82,457,050 31
32
331,855,345,000 82,457,050
FERC FORM NO.1 (ED.12-96)Page 257.1
Date of Report
(Mo,Da,Yr)
04/14/2020
Year/Period of Report
End of 2019/Q4
Name of Respondent
Idaho Power Company
This Report Is:
(1)g An Original
(2)j—|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 222 -Reaquired Bonds
2
3 Account 223:Advances for Associated Companies
4
5 Account 224:
6 Bond Guarantee -American Falls 19,885,000
19,885,0007SubtotalAccount224
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 TOTAL 2,021,445,000 33,876,373
FERC FORM NO.1 (ED.12-96)Page 256.2
Name of Respondent
Idaho Power Company
This Report Is:
(1)fx]An Original
(2)||A Resubmission
LONG-TERM DEBT (Account 221, 222,223 and 224){Continued)
Date of Report
(Mo.Da,Yr)
04/14/2020
Year/Period of Report
2019/Q4Endof
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)
AMORTIZATION PERIOD Line
Nominal Date
of Issue
Date of
Maturity
Interest for Year
Amount No.Date From Date To
(d)(e)(f)(g)(i)
1
2
3
4
5
4/26/00 2/01/25 19,885,000 6
19,885,000 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
331,855,345,000 82,457,050
FERC FORM NO.1 (ED.12-96)Page 257.2
This Page Intentionally Left Blank
Name of Respondent Date of Report Year/Period of Report
(Mo,Da,Yr)
04/14/2020
This Report is:
(1)X An Original
(2)_A ResubmissionIdahoPowerCompany 2019/Q4
FOOTNOTE DATA
Schedule Page:256.1 Line No.:26 Column:a
Unamortized debt expense at refunding is amortized by equal monthly amounts over the life
of the new issue.
FERC FORM NO.1 (ED.12-87)Page 450.1
This Page Intentionally Left Blank
Year/Period of Report
End of 2019/Q4
This Report Is:
(1)[x]An Original
(2)Resubmission
RECONCILIATION OF REPORTED NET INCOME WITH TAXABLE INCOME FOR FEDERAL INCOME TAXES
Date of Report
(Mo,Da,Yr)
04/14/2020
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.
Line Particulars (Details)Amount
(b)(a)No.
224,436,8221NetIncomefortheYear(Page 117)
2
3
4 Taxable Income Not Reported on Books
38,303,9965
6
7
8
9 Deductions Recorded on Books Not Deducted for Return
191.835,82310
11
12
13
14 Income Recorded on Books Not Included in Return
78,774,25715
16
17
18
19 Deductions on Return Not Charged Against Book Income
198,930,79520
21
22
23
24
25
26
176,871,58927FederalTaxNetIncome
28 Show Computation of Tax:
37,143,03429TentativeFederalTax@21%
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)
04/14/2020
Name of Respondent This Report is:
(1)X An Original
(2)_A Resubmission 2019/Q4IdahoPowerCompany
FOOTNOTE DATA
Schedule Page:261 Line No.:5 Column:b
4005-AVOIDED COST 4,645,489
855,3494003-CONSTRUCTION ADVANCES
17,117,8204013-CIAC -TAXABLE -ACCT 107
4021 -ENGINEERING FEES -TAXABLE -ACCT 107 427,934
4024-RENEWABLE ENERGY CERTIFICATES (REC)SALES 3,360,669
10,625,8055058-FIXED COST ADJUSTMENT
1,270,9305066-BOARDMAN DECOMMISSION
38,303,996Total
Schedule Page:261 Line No.:10 Column:b
Total Federal and State taxes deducted on books 26,334,168
499,0005024-NON-DEDUCTIBLE MEALS
172,1305010-POSTEMPLOYMENT BENEFITS-SFAS1 1 2
S035-PCA EXPENSE DEFERRAL 0
05047-EXECUTIVE DEFERRED COMP
5053-STOCK BASED COMPENSATION 116,188
1,396,0125061-PENSION EXPENSE -OREGON
5067-ASSET RETIREMENT OBLIGATION (ARO)799,616
5071 -INCENTIVE DEFERRAL-PROFIT SHARING-NOT IN RATES 59,842
5078-TAX STIP 7,417,848
5504-NON-DEDUCTIBLE POLITICAL EXPENSES 805,700
2,026,6095505-SMSP -NET
7010-PROV FOR RATE REFUND -HC RELICENSING (AFUDC)16,520,970
8009-DEPR TIMING DIFF -OPERATING -FEDERAL 130,732,744
2,316,6968042-GAIN/LOSS ON REACQUIRED DEBT
8703-IPCQ-162(m)THRESHHOLD 2,638,300
191,835,823Total
Schedule Page:261 Line No.:15 Column:b
5074-VALMY SETTLEMENT ADJUSTMENT 1 ,450,044
5077-VALMY DEPRECIATION ADJUSTMENT 27,063,729
5501-SMSP -INSURANCE COSTS 3,273,415
8,489,1457501-REVERSE EQUITY EARNINGS OF SUBSIDIARIES
7502-ALLOWANCE FOR OFUDC 27,112,279
10,702,8477503-ALLOWANCE FOR BFUDC
7509-SMSP -INSURANCE PROCEEDS 682,798
78,774,257Total
Schedule Page:261 Line No.:20 Column:b
5001 -BAD DEBT EXPENSE 245,060
1,654,8245002-INVENTORY RESERVE ADJUSTMENT
1,643,9815008-GAIN/LOSS ON REACQUIRED DEBT
34,000,0005022-263A CAPITALIZED OVERHEADS
25,438,7385023-PENSION EXPENSE
1,3555060-OREGON -PCAM
5070-INCENTIVE DEFERRAL-CRI &RELIABILITY-INCLUDED IN RATES 369,148
2,8025075-EIM DEFERRAL
FERC FORM NO.1 (ED.12-87)Page 450.1
Date of Report Year/Period of ReportNameofRespondentThisReportis:
(1)X An Original
(2)A Resubmission
(Mo,Da,Yr)
2019/Q404/14/2020IdahoPowerCompany
FOOTNOTE DATA
3,519,7495538-STOCK BASED COMP -STOCK
5,024,5627012-REVENUE SHARING
8001 -VEBA -POST RETIREMENT BENEFITS 1,480,025
18,322,8358009A-VALMY1 BOOK BASIS ADJUSTMENT
8020-CONSERVATION EXPENSES 41,168
14,947,1938034-REMOVAL COSTS
8059-SOFTWARE -LABOR COSTS DEDUCTED -ACCT 107 4,744,000
2,570,0008072-RELICENSING -LABOR COSTS DEDUCTED -ACCT 107
88,000,0008073-REPAIRS DEDUCTION
733,2608077-PREPAID INSURANCE &OTHER EXPENSES
8702-STOCK BASED COMP -DIVIDENDS 705,440
(4,513,345)STATE INCOME TAX DEDUCTED ON FEDERAL RETURN
198,930,795Total
FERC FORM NO.1 (ED.12-87)Page 450.2
Name of Respondent
Idaho Power Company
This Report Is:
(1)pq An Original
(2)|j A Resubmission
TAXES ACCRUED,PREPAID AND CHARGED~DURING YEAR
Date of Report
(Mo.Da,Yr)
04/14/2020
Year/Period of Report
2019/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.
Line TChargedBALANCEATBEGINNINGOFYEAR isKindofTax
(See instruction 5)
Adjust-
Taxes Accrued Prepaid Taxes '
(Include in Account 165)
No.w ments(Account 236)
(a)(b)(c)m (e)(f)
1 Federal:
21,193,4452Income-7,619,635 19,947,719
3 Social Security -(FOAB)377,660 16,370,738 15,807,436
4 Unemployment 39,391 92,008 578,568
Subtotal Federal 36,333,7235-7,202,584 37,656,191
6
7 State of Idaho:
8 Income -2,711,454 -5,087,002 -5,061,934
9 Unemployment 14,073 202,781 200,852
10 Property 22,352,72210,107,466 21,874,411
11 Non-Operating 8,824 21,368 19,508
12 kWh 86,873 1 ,934,493 1,939,721
13 Regulatory Commission 3,092,482 3,092,482
14 Business License -Sho Ban 150 150
15 Subtotal Idaho 7,505,782 22,038,683 22,543,501
16
1 7 State of Oregon
18 Income -321,948 715,811 650,074
19 Unemployment 3,042 40,734 41,244
20 Property 1,780,237 3,695,451 3,828,710
21 Non-Operating Property 1,029 2,002 1,946
22 Regulatory Commission 263,573 263,573
23 Franchise 199,684 836,083851,644
Subtotal Oregon24 -119,222 1,781,266 5,569,215 5,621,630
25
26 State of Montana:
27 Property 169,975 358,390 349,371
28 Subtotal Montana 349,371169,975 358,390
29
30 State of Nevada:
31 Property 422,251 776,752 705,192
Subtotal Nevada 422,251 776,752 705,19232
33
34 State of Wyoming
35 Property 712,218 1,346,901 1 ,385,668
36 Corporate License 3,982 3,982
Subtotal Wyoming 1,389,65037712,218 1,350,883
38
39
40
41 TOTAL 2,203,517 -274,54851,026,961 66,712,6821,306,621
FERC FORM NO.1 (ED.12-96)Page 262
Year/Period of Report
End of 2019/Q4
Name of Respondent
Idaho Power Company
This Report Is:
(1)[x]An Original
(2)Q A Resubmission
TAXES ACCRUED,PREPAID AND CHARGED DURING YEAR (Continued)
Date of Report
(Mo,Da,Yr)
04/14/2020
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
Acco
Electric
(Account 408.1 ,409.1)No.Other
^236)(I)(h)(i)0)(k)
1
2,532,946 2-6,373,909 18,660,529
3940,962 16,370,738
4-447,169 92,008
2,532,916-5,880,116 35,123,275 5
6
7
253,311 8-2,736,522 -5,340,313
916,002 202,781
1,131 109,629,156 21,873,280
21,368 1110,684
1281,645 1,934,493
133,092,482
14150
275,810 157,000,965 21,762,873
16
17
13,559 18-256,211 702,252
192,532 40,734
156,505 201,913,496 3,538,946
2,002 21973
22263,573
23851,644215,244
172,066 24-38,435 1,914,469 5,397,149
25
26
27178,994 358,390
358,390 28178,994
29
30
31350,691 776,752
776,752 32350,691
33
34
35673,450 1,346,901
3,982 36
37673,450 1,350,883
38
39
40
48,041,590 2,985,371 412,114,255 2,265,160
FERC FORM NO.1 (ED.12-96)Page 263
Name of Respondent
Idaho Power Company
Date of Report
(Mo,Da,Yr)
04/14/2020
Year/Period of Report
End of 2019/Q4
This Report Is:
(1)[x]An Original
&n
TAXES ACCRUED,PREPAID AND CHARGED DURING YEAR
A Resubmission
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 Sipj
v
wBALANCEATBEGINNINGOFYEAR
Taxes Accrued
(Account 236)
Kind of Tax
(See instruction 5)
Adjust-
Prepaid Taxes
(Include in Account 165)
No.ments
(f)(a)(b)(c)<d)(e)
1 State of Washington
2 Property 4,416 7,41611,000
3 Subtotal Washington 7,41611,000 4,416
4
5 Other States Income 209,241 -21,308 8,725
-274,5486CanadaGSTTax20,211 -246,526
7 Payroll Tax Credit -16,706,261
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
TOTAL41 2,203,517 -274,5481,306,621 51,026,961 66,712,682
FERC FORM NO.1 (ED.12-96)Page 262.1
Year/Period of Report
End of 2019/Q4
Date of Report
{Mo.Da,Yr)
04/14/2020
Name of Respondent
Idaho Power Company
This Report Is:
(1)[x]An Original
(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.
DISTRIBUTION OF TAXES CHARGEDBALANCEATENDOFYEAR Line
Adjustments to Ret.
Earnings (Account 439)
Prepaid Taxes
(Incl.in Account 165)
Extraordinary Items
(Account 409.3)
(Taxes accrued
Acco
Electric
(Account 408.1 ,409.1 )
No.Other
(k)(I)(h)(i)(j)
1
28,000 4,416
38,000 4,416
4
4,579 5-25,887179,208
6-7,811
-16,706,261 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
2,985,371 4148,041,5902,114,255 2,265,160
FERC FORM NO.1 (ED.12-96)Page 263.1
This Page Intentionally Left Blank
Date of Report Year/Period of Report
(Mo,Da,Yr)
04/14/2020
Name of Respondent This Report is:
(1)X An Original
(2)_A Resubmission
FOOTNOTE DATA
2019/Q4IdahoPowerCompany
Schedule Page:262
Account 409.2
Account 426.5
Account 409.1
Line No.:2 Column:I
893,116
140,517
$1,499,283
$
$
$2,532,916Total
Schedule Page:262
Account 409.2
Schedule Page:262
Account 107
Schedule Page:262
Account 408.2
Schedule Page:262 Line No.:18 Column:I
Account 409.2
Schedule Page:262
Account 107
Schedule Page:262
Account 408.2
Schedule Page:262.1
Account 409.2
Schedule Page:262.1 Line No.:6 Column:f
Canada GST accrual is an adjustment because the offset account is not a 600 expense
account .
Schedule Page:262.1 Line No.:7 Column:i
This amount is an offset to lines 3,4,9,and 19.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.
Line No.:8 Column:I
$253,311
Line No.:10 Column:I
1,131
Line No.:11 Column:I
$21,368
$
$13,559
Line No.:20 Column:I
$156,505
Line No.:21 Column:I
2,002
Line No.:5 Column:I
4,579
$
$
FERC FORM NO.1 (ED.12-87)Page 450.1
ate of Report
(Mo,Da,Yr)
04/14/2020
Year/Period of Report
End of 2019/Q4
Name of Respondent
Idaho Power Company
This Report Is:
(1)|x]An Original
(2)QA Resubmission
ACCUMULATED DEFERRED INVESTMENT TAX CREDITS (Account~255T
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.
Account
No.Subdivisions
Balance at Beginning
of Year
Allocations to
Current Year's Income
Amount
Line Deferred for Year Adjustments
Account No.Amount Account No.(b)(g)if;(d)(e)cl
1 Electric Utility
2 3%
3 4%243,760 411.401 29,617
4 7%
5 10%1,621,86213,611,193 411.401
476,1256Other-Federal 11,973,700 4,362,046
7 Other -State 66,961,183 411.402 3,905,612 411.402 4,124,016
8 TOTAL 8,267,658 6,251,62492,789,836
9 Other (List separately
and show 3%,4%,7%,
10%and TOTAL)
10 11%1,063,916 411.401 22,265
48
Page 266FERCFORMNO.1 (ED.12-89)
455885
Year/Period of Report
End of 2019/Q4
Date of Report
(Mo,Da,Yr)
04/14/2020
This Report is:
(1)[X]An Original
(2)Q A Resubmission
ACCUMULATED DEFERRED INVESTMENT TAX CREDITS (Account 255)(continued)
Name of Respondent
Idaho Power Company
Average Period
of Allocation
to Income
LineBalanceatEnd
of Year ADJUSTMENT EXPLANATION
No.
M.
1
2
3214,143 8.23
4
511,989,331 8.39
615,859,617 24.04
766,742,779 16.24
894,805,870
9
101,041,647 47.77
1114,817,970 24.04
1215,859,617
13
14
1566,742,779
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
Name of Respondent
Idaho Power Company
Date of Report
(Mo,Da,Yr)
04/14/2020
Year/Period of ReportThisReportIs:
(1)[X]An Original
(2)|jAResubmissi
OTHER DEFFERED CREDITS (Account 253)
End of 2019/Q4
on
1 .Report below the particulars (details)called for concerning other deferred credits.
2.For any deferred credit being amortized,show the period ofamortization.
3.Minor items (5%of the Balance End of Year for Account 253 or amounts less than $1 00,000,whichever is greater)may be grouped by classes.
Balance at
End of Year
Description and Other
Deferred Credits
Balance at
Beginning of Year
DEBITSLine
CreditsContra
Account
AmountNo.
(b)(a)(d)(e)(f)(c)
1,495,5501PTPTransmissionDeposits2532011,595,437 Various 1,151,675 1,051,788
2
866,6663FTVDarkFiberRental2532021,266,666 400 400,000
4 Amortization period 03/98-02/23
5
6 Escrow Deposits 253350 92,147 92,147
7
8 Sho-Ban Scholarships 253480 127,500142,500 242 15,000
9 Amortization period 01/05-12/27
10
Operations Accruals 253550 94,127 402,82311496,950 Various
12
1 ,627,86213PostretirementBenefits2539601,455,732 172,130
14
15 Directors Deferred Compensation 3,348,722 401 213,912 288,427 3,423,237
16 253970-253999
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46
TOTAL 8,306,007 1,874,714 1 ,604,492 8,035,78547
Page 269FERCFORMNO.1 (ED.12-94)
Year/Period of Report
End of 2019/Q4
Date of Report
(Mo,Da,Yr)
04/14/2020
This Report Is:
(1)[X]An Original
(2)||A Resubmission
Name of Respondent
Idaho Power Company
ACCUMULATED DEFFERED INCOME TAXES -OTHER PROPERTY (Account 282)
1 .Report the information called for below concerning the respondent's accounting for deferred income taxes rating to property not
subject to accelerated amortization
2.For other (Specify),include deferrals relating to other income and deductions.
CHANGES DURING YEAR
Line Balance at
Beginning of Year
Account Amounts Credited
to Account 41 1.1
Amounts Debited
to Account 410.1
No.
(d)(c)(b)(a)
1 Account 282
289,283,288 17,916,1294,534,6912Electric
3 Gas
4 Other
17,916,1294,534,691289,283,2885TOTAL(Enter Total of lines 2 thru 4)
6 Non-Operating Property
614,144,0867Other-Regulatory Asset
5,187,7258LikeKindExchange-Reclass No
17,916,1294,534,691908,615,0999TOTALAccount282(Enter Total of lines 5 thru
10 Classification of TOTAL
17,821,9654,465,977733,509,32611FederalIncomeTax
94,16468,714175,105,77412StateIncomeTax
13 Local Income Tax
NOTES
FERC FORM NO.1 (ED.12-96)Page 274
Year/Period of Report
End of 2019/Q4
Date of Report
(Mo,Da,Yr)
04/14/2020
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
DebitsAmountsDebited
to Account 410.2
Credits No.Account
Credited
Amount Account
Debited
Amount
0)(f)(e)(k)(h)(g)ill
1
281,617,312 26,402,462282/254687,000254
3
4
281,617,312 56,402,462687,000
6
32,741,941 646,886,027 7182
4,966,027 8-221,698282
933,469,366 938,922,705687,000
10
749,308,583 11182/254 29,842,245687,000254
184,160,783 129,080,459182
13
NOTES (Continued)
FERC FORM NO.1 (ED.12-96)Page 275
This Page Intentionally Left Blank
Date of Report Year/Period of ReportNameofRespondentThisReportis:
(1)X An Original
(2)_A Resubmission
(Mo,Da,Yr)
2019/Q404/14/2020IdahoPowerCompany
FOOTNOTE DATA
Schedule Page:274 Line No.:2 Column:b
2019AdjustmentsCredlis2019ChangesduringYear
CR to CR to
411.2
DR to
410.1
Ending
Balance
Acct.Beginning
Balance debited Amount411.1Account
kfi(a)dbc
464,329,392DepreciationTimingDiff-Operating
13,669,343 687,000473,935,322 4,750,413
(4,966,027)282111LikeKindExchange-Reclass Non-Rate
Base 221,698
6,180,764
(5,187,725)
(183,881,576)254967ExcessDeferredTaxonDepreciation
(190,062,340)(Reg Liab)
CIAC-Taxable-Acct 107 (7,679,938)
(3,596,029)4,083,909
(609,496)Engineering Fees-Taxable-Acct 107
(446,619)162,877
2,048,323Software-Labor Costs Deducted-Acct
(788,474)2,836,797107
12,376,634Intangible-Labor Costs Deducted-Acct
11,803,882 572,752107
TOTAL 281,617,3126,402,462289,283,288 4,534,691 17,916,129 687,000
FERC FORM NO.1 (ED.12-87)Page 450.1
Name of Respondent
Idaho Power Company
Dale of Report
(Mo,Da,Yr)
(2)|—|A Resubmission 04/14/2020
ACCUMULATED DEFFERED INCOME TAXES -OTHER (Account 283}
Year/Period of Report
End of 2019/Q4
This Report Is:
(1)fx]An Original
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 YEARBalanceat
Beginning of Year
Line Amounts Debited
to Accost 410.1
Amounts Credited
to Accost 411.1
Account
No.
(a)(b)
1 Account 283
2 Electric
3 Other Electric ~See Note 67,157.877 4,118,79515,464,314
4
5
6
7
8 Other --See Note 72,074,092
9 TOTAL Electric (Total of lines 3 thru 8)4,118,795139,231,969 15,464,314
10 Gas
11
12
13
14
15
16
17 TOTAL Gas (Total of lines 11 thru 16)
18 Other -See Note -14,426 6 41 ,597
19 TOTAL (Acct 283)(Enter Total of lines 9,17 and 18)139,217,543 15,464,320 4,160,392
20 Classification of TOTAL
21 Federal Income Tax 106,765,901 11,859,584 3,190,604
22 State Income Tax 32,451,641 3,604,736 969,788
23 Local Income Tax
NOTES
FERC FORM NO.1 (ED.12-96)Page 276
Year/Period of Report
End of 2019/Q4
Name of Respondent
Idaho Power Company
Date of Report
(Mo.Da,Yr)
04/14/2020
This Report Is:
(1)[xj An Original
(2)Q 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
Credits LineDebitsBalanceat
End of YearAccount
Debited
AmountAccountAmount No.
Cr|djted(e,(f)(h)(i)c:
1
2
378,503,396
4
5
6
7
889,558,35119017,484,259
9168,061,74717,484,259
10
11
12
13
14
15
16
17
18-56,017
19168,005,73017,484,259
20
2119013,408,675 128,843,556
224,075,585 39,162,174190
23
NOTES (Continued)
FERC FORM NO.1 (ED.12-96)Page 277
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 04/14/2020 2019/Q4
FOOTNOTE DATA
Schedule Page:276 Line No.:3 Column:b
Changes during Year [2019
DR to CR to Ending
410.1 411.1 Balance
2019
Beginning
BalanceAccount
Renewable Energy Certificates (REC)Sales
(194,769)693,082 865,036 (366,723)
Royalty Income
233,398 1,989 235,387
Gain/Loss on Reaqcuired Debt
423,161 423,161
Pension Expense
36,366,190 6,839,037 43,205,227
PCA Expense
Intervenor Funding Orders
58,708 2,656 61,364
Fixed Cost Adjustment
10,940,327 2,735,082 8,205,245
PS &I Costs
34,336 34,336
Oregon PCAM
1,863 349 2,212
2011 LIDAR Surveys Deferral
44,895 11,223 33,672
Boardman Decommission
(1,648)327,137 (328,785)
Valmy Settlement Adjustment
5,917,771 474,266 6,392,037
EIM Deferral
9,001 721 9,722
Valmy Depreciation Adjustment
13,298,364 6,966,205 101,025 20,163,544
Langley Revenue Accrual
(32,355)32,355
Conservation Expenses
326,219 10,597 336,816
Siemens LTP Contract
58,849 17,213 76,062
Prepaid Credit Facility
106,572 36,539 70,033
Siemens OR DRB Interest Reserve
(25,885)(17,468)8.417
Boardman Removal Costs
7,624 2,683 10,307
TOTAL
67,157,877 15,464,314 4,118,795 78,503,396
Schedule Page:276 Line No.:8 Column:b
2019 Adjustments Credits
Acct.
debited
2019
Ending
Balance
Beginning
BalanceAccount Amount
Pension-FAS 158
72,101,875 190 17,432,486 89,534,361
Postretirement Plan-FAS 158
(27,783)
72,074,092
190 51,773 23,990
TOTAL 17,484,259 89,558,351
Schedule Page:276 Line No.:18 Column:b
2019 Changes during Year 2019
Beginning
Balance
CR toDRto Ending
BalanceAccount
EDC-Unrealized Gain/Loss From Rabbit
Trust
410.1 411.1
(63)(316)253
FERC FORM NO.1 (ED.12-87)Page 450.1
Name of Respondent Date of Report Year/Period of Report
(Mo,Da,Yr)
04/14/2020
This Report is:
(1)X An Original
(2)_A Resubmission
FOOTNOTE DATA
Idaho Power Company 2019/Q4
SMSP-Unrealized Gain/Loss From Rabbi
Trust
Oregon Non-Op Prop Tax Adj
(14,622)(55,966)41,344
J3 265259
TOTAL
(14,426)6 41,597 (56,017)
FERC FORM NO.1 (ED.12-87)Page 450.2
Name of Respondent This Report Is:(1) An Original
(2) A Resubmission
Date of Report(Mo, Da, Yr)Year/Period of Report
End of
OTHER REGULATORY LIABILITIES (Account 254)
Idaho Power Company X
04/14/2020 2019/Q4
Line
No.
Description and Purpose of DEBITS
CreditsAccount
(d)(c)(a)
Balance at End
of Current
Quarter/Year
(e)
Other Regulatory Liabilities Amount
(f)
Credited
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 Begining
of Current
Quarter/Year
(b)
3,700,413 3,295,496 404,917Market to Market Short Term (254001)175 1
IPUC Order #28661 2
3
66,574 39,011 140,442 112,879Oregon Solar Rider (254005)Various 4
Advice #10-198 5
6
5,024,562 5,068,654 44,092Idahe Revenue Sharing (254101)1823 7
IPUC Order #34351 8
9
5,258,957 38,069,980 32,811,023Idaho DSM Rider (254201)Various 10
IPUC Order #29026 11
12
1,897,389 10,330,420 4,132,893 12,565,924BPA Credit Residential Idaho (254401)Various 13
Advice #15-13 14
15
95,684 399,946 146,607 450,869BPA Credit Residential Oregon (254402)Various 16
Advice #15-11 17
18
338,459 1,539,416 885,855 2,086,812BPA Credit Farm Idaho (254403)Various 19
Advice #15-13 20
21
14,490 85,628 42,855 113,993BPA Credit Farm Oregon (254404)Various 22
Advice #15-11 23
24
171,832 118,040 297,261 243,469Oregon Green Tags (254415)401 25
Advice #11-086 26
27
1,721,624 9,139,472 7,417,848Idaho Tax Settlement (254451) 28
IPUC Order #34071 29
30
564,308 564,308Oregon Tax Settlement (254452) 31
OPUC Advice #18-199 32
33
2,536,525 3,134,211 597,686Bridger Depreciation (254800) 34
OPUC Order #12-296 35
36
130,384 156,790 26,406RL-WAQC CRYOVR (254901) 37
IPUC Order #29505 38
39
32,162,811 32,861,609 698,798Unfunded Accum Def Income Tax (254966) 40
FERC FORM NO. 1/3-Q (REV 02-04)Page 278
41 TOTAL 106,647,202 109,423,538 349,006,644 351,782,980
Name of Respondent This Report Is:(1) An Original
(2) A Resubmission
Date of Report(Mo, Da, Yr)Year/Period of Report
End of
OTHER REGULATORY LIABILITIES (Account 254)
Idaho Power Company X
04/14/2020 2019/Q4
Line
No.
Description and Purpose of DEBITS
CreditsAccount
(d)(c)(a)
Balance at End
of Current
Quarter/Year
(e)
Other Regulatory Liabilities Amount
(f)
Credited
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 Begining
of Current
Quarter/Year
(b)
190,062,341 6,180,764 183,881,577RL-DEF INC TAX-ARAM (254967)282 1
2
65,879,405 2,142,376 63,737,029RL-DEF INC TAX-ARAM GROSS-UP (254968)190 3
4
42,153,807 42,153,807 48,194,075 48,194,075Idaho PCA Deferral (254425)1823 5
IPUC Order Pending 6
7
1,277,331 1,277,331Boardman Decommissioning (254426) 8
Advice #12-235, IPUC Order #32457 9
10
3,415 9,412 5,997Minor Items (2) 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
FERC FORM NO. 1/3-Q (REV 02-04)Page 278.1
41 TOTAL 106,647,202 109,423,538 349,006,644 351,782,980
This Page Intentionally Left Blank
Name of Respondent This Report is:
(1)X An Original
(2)_A Resubmission
Date of Report Year/Period of Report
(Mo,Da,Yr)
04/14/2020IdahoPowerCompany 2019/Q4
FOOTNOTE DATA
Schedule Page:278 Line No.:10 Column:a
During 2019,this balance flipped from a liability to a receivable and was reclassed to a
Regulatory Asset for financial statement presentation.
FERC FORM NO.1 (ED.12-87)Page 450.1
Year/Period of Report
End of 2019/Q4
Dale of Report
(Mo,Da,Yr)
04/14/2020
Name of Respondent
Idaho Power Company
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 ofthese 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 number offlat rate accounts;exceptthat 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.
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.
(b)o)(a)
1 Sales of Electricity
533,062,0282(440)Residential Sales 528,572,308
3 (442)Commercial and Industrial Sales
466,201,6004Small(or Comm.)(See Instr.4)428,953,227
181,871,403 191,175,3615Large(or Ind.)(See Instr.4)
6 (444)Public Street and Highway Lighting 3,850,765 4,032,545
7 (445)Other Sales to Public Authorities
8 (446)Sales to Railroads and Railways
9 (448)Interdepartmental Sales
10 TOTAL Sales to Ultimate Consumers 1,143,247,703 1,194,471,534
79,156,53711(447)Sales for Resale 101,908,387
1,273,628,07112TOTALSalesofElectricity1,245,156,090
8,440,245 19,972,54113(Less)(449.1)Provision for Rate Refunds
14 TOTAL Revenues Net of Prov.for Refunds 1,236,715,845 1,253,655,530
15 Other Operating Revenues
16 (450)Forfeited Discounts
4,601,49717(451 )Miscellaneous Service Revenues 4,463,096
18 (453)Sales of Water and Water Power
16,936,179 16,048,73619(454)Rent from Electric Property
20 (455)Interdepartmental Rents
41.061,301 36,461,05621(456)Other Electric Revenues
22 (456.1)Revenues from Transmission of Electricity of Others 43,848,605 51,329,032
23 (457.1)Regional Control Service Revenues
24 (457.2)Miscellaneous Revenues
25
106,507,582 108,301,92026TOTALOtherOperatingRevenues
27 TOTAL Electric Operating Revenues 1,343,223,427 1,361,957,450
FERC FORM NO.1/3-Q (REV.12-05)Page 300
Year/Period of Report
End of 2019/Q4
Daie of Report
(Mo,Da,Yr)
04/14/2020
Name of Respondent
Idaho Power Company
This Report Is:
(1)[X]An Original
(2)||A Resubmission
ELECTRIC OPERATING REVENUES (Acoount 400}
6.Commercial and industrial Sales,Account 442,may be classified according to the basis of classification (Small or Commercial,and Large or Industrial)regularly used by the
respondent if such basis of classification is not generally greater than 1000 Kw of demand.(See Account 442 of the Uniform System of Accounts.Explain basis ofclassification
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 304for amounts relating to unbilled revenue by accounts.
9.Include unmetered sales.Provide details of such Sales in a footnote.
AVG.NO.CUSTOMERS PER MONTHMEGAWATTHOURSSOLD Line
No.Year to Date Quarterly/Annual Amount Previous year(no Quarterly)Previous Year (no Quarterly)Current Year (no Quarterly)
(9)(d)(e)(f)
1
459,128 2471,2985,272,659 5,134,576
3
88,929 46,049,156 90,1645,819,993
118127 53,412,410 3,370,566
3,280 63,48831,652 32,224
7
8
9
551,455 10565,07714,536,714 14,586,522
112,863,6372,850,922
551,455 1217,387,636 17,450,159 565,077
13
551,455 14565,07717,387,636 17,450,159
Line 12,column (b)includes $
Line 12,column (d)includes
-4,965,101
-47,683
of unbilled revenues.
MWH relating to unbilled revenues
FERC FORM NO.1/3-Q (REV.12-05)Page 301
Date of Report Year/Period of Report
(Mo,Da,Yr)
04/14/2020
Name of Respondent This Report is:
(1)X An Original
(2)_A Resubmission 2019/Q4IdahoPowerCompany
FOOTNOTE DATA
Schedule Page:300 Line No.:17 Column:b
This amount consists of:
Service Establishment/Connection Charges
(Includes late and after hour charges)
Misc.Under $250,000
$4,329,171
332,326
$4,661,497TotalAccount451
Schedule Page:300 Line No.:21 Column:b
This amount consists of:
DSM Activity
Alternate Distribution Service
Misc.Under $250,000
$40,127,871
781,431
151,999
$41,061,301TotalAccount456
FERC FORM NO.1 (ED.12-87)Page 450.1
Name of Respondent
Idaho Power Company
This Report Is:
(1)[X]An Original
(2)||AResubmissi
SALES OF ELECTRICITY BY RATE SCHEDULES
Date of Report
{Mo,Da,Yr)
04/14/2020
Year/Period of Report
End of 201 9/Q4
on
1 .Report below for each rate schedule in effect during the year the MWH of electricity sold,revenue, average number of customer,average Kwh per
customer,and average revenue per Kwh,excluding date for Sales for Resale which is reported on Pages 310-311.
2.Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues,"Page
300-301 .If the sales under any rate schedule are classified in more than one revenue account,List the rate schedule and sales data under each
applicable revenue account subheading.
3.Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential
schedule and an off peak water heating schedule),the entries in column (d)for the special schedule should denote the duplication in number of reported
customers.
4.The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12
if all billings are made monthly).
5.For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto.
6.Report amount of unbilled revenue as of end of year for each applicable revenue account subheading.
Line Number and I itle ot Kate schedule TvfWfrSolcJ'"Revenue"Average Number
of Customers
KWh ot bales
Per (^ustomer
i.v.enue Per
>olNo.(f)
1
2 1 1 ,268
217,045
16,583
5,592
0.0978
0.0934
0.0944
0.1039
0.2403
0.0868
3
4
5
6
7
9 11,188 0.1002
10
11
12 4,838
3,857
2,165,155
92,810
1,365,200
0.1211
0.1257
0.0626
0.0709
0.0679
0.1708
0.0553
0.0608
0.0588
0.0773
0.0834
0.0478
0.1307
13
14
15
16
17
18 19,808,750
6,122,000
45,741,000
82,507
10,690
298,330,667
19
20
21
22
23
24
25
26 102,252 0.0662
27
28
29 1,671
12,036
3,904
0.0839
0.1280
0.0600
0.1945
30
31
32
33
34 9,075 0.1217
35
36
37
38
39
40
41 25,810 0.0787
0.1041
0.0786
042
43 25,725
FERC FORM NO.1 (ED.12-95)Page 304
^
This Report Is:
(1)[x]An Original
(2)||A Resubmission
SALES FOR RESALE (Account 447)
Date of Report
(Mo.Da,Yr)
04/14/2020
Year/Period of Report
End of 2019/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 Demant Monthly CFTDNo.emand
(e)(f)(b)(c)(d)(a)
n/an/aWSPPn/a3PhasesRenewablesInc.SF1
n/a n/aWSPPn/a2ADMInvestorServices,Inc.OS
n/a n/an/a3ArizonaPublicServiceCo.SF WSPP
n/a n/an/aOSOATT4AvangridRenewables(IBERDROLA)
n/an/a n/aSFWSPP5AVANGRIDRENEWABLES,LLC
n/an/a n/aSFWSPP6AvistaCorp.
n/aOSn/a n/aOATT7AvistaCorp.-WWP Div.
n/a n/aWSPPn/a8BasinElectricPowerCooperativeSF
n/a n/an/aSFWSPP9BlackHillsPowerInc.
n/a n/aOSn/aOATT10BonnevillePower
n/an/a n/aWSPP11BonnevillePowerAdministrationSF
n/an/aWSPPn/a12BPEnergyCompanySF
n/a n/aOSWSPPn/a13BritishColumbiaHydroandPowerAuthor
n/a n/an/aOSOATT14BrookfieldEnergyMarketing
0 00SubtotalRQ
0 00Subtotalnon-RQ
0 00Total
Page 310FERCFORMNO.1 (ED.12-90)
This Report Is:
(1)[x]An Original
(2)—A Resubmission
Year/Period of Report
End of 2019/Q4
Date of Report
(Mo,Da,Yr)
04/14/2020
Name of Respondent
Idaho Power Company
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 LineMegaWattHoursTotal($)
(h+i+j)Other ChargesEnergyChargesDemandCharges No.Sold ($)($)($)
(i)(k)(h)(9)0)
110,451,76210,451,762337,775
2818,050818,050
31,4041,40478
410,02610,026
5243,075243,0757,063
610,200,20310,200,203177,311
710,63310,633
828,23028,2305,325
9932,522932,52285,688
102,960,0562,960,056
1111,035,40611,035,406287,774
12420,438420,43820,673
131111113
142,2852,285
00000
101,908,38711,645,706090,262,6812,850,922
101,908,38711,645,70690,262,6812,850,922 0
Page 311FERCFORMNO.1 (ED.12-90)
Name of Respondent
Idaho Power Company
This ReportIs;
(1)[X]An Original
(2)| |A Resubmission
SALES FOR RESALE (Account 447)
Year/Period of Report
End of 2019/Q4
Date of Report
(Mo,Da,Yr)
04/14/2020
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 Demanc Monthly CRT)
FERC Rate
Schedule or
Tariff Number
AverageStatistical
Classifi
cation
Name of Company or Public Authority
(Footnote Affiliations)
Line Monthly Billing
Demand (MW)No.emand
(f)(d)(e)(a)(b)(c)
n/an/a n/aOSOATT1BrookfieldRenewableTrading&Marketin
n/a n/aWSPPn/a2BrookfieldRenewableTradingandMarketSF
n/a n/aCAISOn/a3CaliforniaIndependentSystemOperatorSF
n/a n/an/a4ChelanCoPUDSFWSPP
n/an/a n/a5CitigroupEnergyInc.SF ISDA
n/an/a n/a6ClatskaniePUDSFWSPP
n/an/a n/a7CleanPowerAllianceofSouthernCalifoSFWSPP
n/a n/a8DirectEnergyBusinessMarketing,LLC SF WSPP n/a
n/a n/aWSPPn/a9DTEEnergyTrading,Inc.SF
n/a n/an/aOSOATT10EDFTradingNorthAmerica
n/an/a n/a11EDFTradingNorthAmerica,LLC SF WSPP
n/a n/a n/aSFWSPP12EnergyKeepers,Inc
n/a n/aOSOATTn/a13EnergyKeepers,Inc.
n/a n/aWSPPn/a14EugeneWater&Electric Board SF
0 00SubtotalRQ
0 0Subtotalnon-RQ 0
000Total
Page 310.1FERCFORMNO.1 (ED.12-90)
This Report Is:
(1)[x]An Original
(2)—A Resubmission
Year/Period of Report
End of 2019/Q4
Date of Report
(Mo,Da,Yr)
04/14/2020
Name of Respondent
Idaho Power Company
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.($)($)($)
(i)(k)(g)(h)iiI
148,22348,223
2502,062502,06212,045
313,701,15413,701,154238,742
417,51417,514936
52,4582,458103
637,41837,4181,308
72,824,4772,824,477107,250
8375,908375,90810,000
96,584,6166,584,616245,800
101,9361,936
1180,87280,8723,025
129,3719,3711,243
133,371 3,371
14391,906391,90610,213
00000
11,645,706 101,908,38790,262,6812,850,922 0
101,908,38790,262,681 11,645,70602,850,922
Page 311.1FERCFORMNO.1 (ED.12-90)
This Report Is:
[X]An Original
Year/Period of Report
End of 2019/Q4
Dale of Report
(Mo,Da,Yr)
04/14/2020
Name of Respondent
Idaho Power Company (1)
(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)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 NCR Demanc Monthly CP DNo.emand
(f)(d)(e)(b)(c)(a)
n/an/an/aWSPP1ExelonGenerationCompany,LLC SF
n/an/a n/aISDA2J.Aron &Company LLC OS
n/aOSn/a n/aOATT3MacquarieEnergyLLC
n/an/aWSPPn/aSF4MacquarieEnergyLLC
n/an/aOSn/aOATT5MAGEnergySolutions
n/an/an/aOSOATT6MorganStanleyCapitalGroupInc.
n/a n/an/aISDA7MorganStanleyCapitalGroupInc.SF
n/a n/an/aOSOATT8NevadaPower
n/an/a n/aOSWSPP9NevadaPowerCompany,dba NV Energy
n/an/an/aSFWSPP10NevadaPowerCompany,dba NV Energy
n/an/an/aSFWSPP11NorthwesternEnergy
n/a n/aOSn/aOATT12NorthwesternEnergyNWDS
n/aOSn/a n/aT-713PacifiCorp
n/an/aOSn/aWSPP14PacifiCorp
000SubtotalRQ
000Subtotalnon-RQ
000Total
Page 310.2FERCFORMNO.1 (ED.12-90)
This Report Is:
(1)[XjAn Original
(2)|A Resubmission
SALES FOR RESALE (Account 447)(Continued)
Year/Period of Report
End of 2019/Q4
ate of Report
(Mo.Da,Yr)
04/14/2020
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 ofthe 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 NOP 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)(j)
133,487 33,487626
86,048 286,048
38,539 8,539
41,360,451112,688 1,360,451
543,76043,760
61,199,5151,199,515
7398,031398,03131,459
81,787 1,787
9738,672 738,67216,788
10172,711172,7116,028
1180,97280,9724,120
12369369
132,935 2,93599
1489893
0 0000
11,645,706 101,908,3872,850,922 0 90,262,681
101,908,387090,262,681 11,645,7062,850,922
Page 311.2FERCFORMNO.1 (ED.12-90)
This Report Is:
C)EAn Original
(2)||A Resubmission
SALES FOR RESALE (Account 447)
Year/Period of Report
End of 2019/Q4
Date of Report
(Mo,Da,Yr)
04/14/2020
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 -fortong-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 CP Demand
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)(b)(c)(d)(a)
n/aOSn/aWSPPn/a1PacifiCorp
n/a n/aWSPPn/a2PacifiCorpSF
n/a n/an/aOSOATT3PacifiCorpInc.
n/a n/an/a4PortlandGeneralElectricCompanyOSOATT
n/an/a n/aSFWSPP5PortlandGeneralElectricCompany
n/an/a n/aOSOATT6PowerexCorp.
n/an/aWSPPn/a7PowerexCorp.SF
n/a n/aOSn/a8PugetSoundEnergy,Inc.T-7
n/a n/an/aSFWSPP9PugetSoundEnergy,Inc.
n/aOSn/a n/aOATT10RainbowEnergyMarketingCorporation
n/an/a n/aSFWSPP11RainbowEnergyMarketingCorporation
n/a n/aWSPPn/a12SeattleCityLightSF
n/a n/aOSOATTn/a13ShellEnergyNorthAmerica(US),L.P.
n/an/a n/a14ShellEnergyNorthAmerica(US),L.P.SF WSPP
000SubtotalRQ
0 00Subtotalnon-RQ
000Total
Page 310.3FERCFORMNO.1 (ED.12-90)
This Report Is:
(1)[X|An Original
(2)|~j A Resubmission
SALES FOR RESALE (Account 447)(Continued)
Year/Period of Report
End of 2019/Q4
Date of Report
(Mo,Da,Yr)
04/14/2020
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 ,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)(J)
13,5003,500250
22,886,7752,886,775137,261
34,948,4494,948,449
440,38740,387
5425,969425,96917,411
6134,230134,230
7513,100513,10027,508
81111114
9357,392357,39215,442
1016,32716,327
111,736,0121,736,012125,792
129,769,4549,769,454176,821
13422,509422,509
1410,450,00910,450,009435,523
00000
101,908,38711,645,70690,262,68102,850,922
101,908,38711,645,70690,262,68102,850,922
Page 311.3FERCFORMNO.1 (ED.12-90)
This Report Is:
(1)[XjAn Original
(2)|[A Resubmission
Year/Period of Report
End of 2019/Q4
ate of Report
(Mo.Da,Yr)
04/14/2020
Name of Respondent
Idaho Power Company
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 ofthe 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 Demanc Monthly CFHTNo.emand
(e)(f)(b)(c)(d)(a)
n/a n/aOSn/a1SierraPacificPowerCo.,dba NV Energy T-7
n/a n/an/a2SnohomishCountyPUDSFWSPP
n/a n/an/aSFWSPP3TacomaPower
n/aOSn/a n/aOATT4TenaskaPowerServicesCo.
n/an/a n/aWSPP5TenaskaPowerServicesCo.SF
n/an/aOATTn/a6TheEnergyAuthority,Inc.OS
n/a n/aWSPPn/a7TheEnergyAuthority,Inc.SF
n/a n/an/a8TransAltaEnergyMarketing(U.S.)Inc.OS OATT
n/a n/an/a9TransAltaEnergyMarketing(U.S.)Inc.SF WSPP
n/an/a n/aOS10TransmissionPenaltyDistribution
n/an/a n/aOSOATT11UtahAssociatedMunicipalPowerSystems
n/a n/aWSPPn/a12UtahAssociatedMunicipalPowerSystemsSF
n/a n/aOSn/a13WesternAreaPowerAdministration(WAC T-7
n/aOSn/a n/a14WesternAreaPowerAdministration(WAC WSPP
000SubtotalRQ
000Subtotalnon-RQ
000Total
Page 310.4FERCFORMNO.1 (ED.12-90)
This Report Is:
(1)[Xl An Original
(2)||A Resubmission
SALES FOR RESALE (Account 447)(Continued)
Year/Period of Report
End of 2019/Q4
Date of Report
(Mo,Da,Yr)
04/14/2020
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 ,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)(g)(h)(j)
11,159 1,15936
2109,9663,457 109,966
3240,30010,410 240,300
437,96837,968
5639,932639,93267,390
615,10115,101
71,080,89426,581 1 ,080,894
872,764 72,764
91,411,9201,411,92046,395
1014,56214,562
111,1541,154
12754,51036,430 754,510
1356056027
1452052018
00000
101,908,387090,262,681 11,645,7062,850,922
101,908,38790,262,681 11,645,7062,850,922 0
Page 311.4FERCFORMNO.1 (ED.12-90)
Date of Report Year/Period of Report
(Mo,Da,Yr)
04/14/2020
This Report is:Name of Respondent
(1)X An Original
(2)_A Resubmission 2019/Q4IdahoPowerCompany
FOOTNOTE DATA
]Schedule Page:310 Line No.:2 Column:b
ADM Investor Services,Inc Futures Account Document,da:cui May:5,.2015
Schedule Page:310 Line No.:4 Column:b
Financial Transmission Losses
Schedule Page:310 Line No.:7 Column:b
Financial Transmission Losses
Schedule Page:310 Line No.:10 Column:b
Financial Transmission Losses _
Schedule Page:310 Line No.:13 Column:b
Spinning or Operating Reserves
Schedule Page:310 Line No.:14 Column:b
Financial Transmission Losses
Schedule Page:310.1 Line No.:1 Column:b
Financial Transmission Losses
"i
i
Schedule Page:310.1 Line No.:10 Column:b
Financial Transmission Losses
Schedule Page:310.1 Line No.:13 Column:b
Financial Transmission Losses
Schedule Page:310.2 Line No.:2 Column:b
ISDA Master Agreement with J.Aron &Company dated April 30, 2014
Schedule Page:310.2 Line No.:3 Column:b
Financial Transmission Losses
Schedule Page:310.2 Line No.:5 Column:b
Financial Transmission Losses
Schedule Page:310.2 Line No.:6 Column:b
Financial Transmission Losses
Schedule Page:310.2 Line No.:8 Column:b
Financial Transmission Losses
Schedule Page:310.2 Line No.:9 Column:b
Non-firm Sales
Schedule Page:310.2 Line No.:12 Column:b
Financial Transmission Losses
Schedule Page:310.2 Line No.:13 Column:b
Financial Transmission Losses
Schedule Page:310.2 Line No.:14 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
Financial Transmission Losses
Schedule Page:310.3 Line No.:4 Column:b
Financial Transmission Losses
Schedule Page:310.3 Line No.:6 Column:b
Financial Transmission Losses _
Schedule Page:310.3 Line No.:8 Column:b
Financial Transmission Losses
Schedule Page:3 1.3 Line No.:10 Column:b
Financial Transmission Losses
Schedule Page:310.3 Line No.:13 Column:b
Financial Transmission Losses
Schedule Page:310.4 Line No.:1 Column:b
Financial Transmi ssion Losses
Schedule Page:310.4 Line No.:4 Column:b
Financial Transmission Losses
FERC FORM NO.1 (ED.12-87)Page 450.1
Date of Report Year/Period of Report
(Mo,Da,Yr)
04/14/2020
Name of Respondent This Report is:
(1)X An Original
(2)_A Resubmission 2019/Q4IdahoPowerCompany
FOOTNOTE DATA
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.:10 Column:b
Transmission penalty distribution credits
Schedule Page:310.4 Line No.:11 Column:b
Financial Transmission Losses
Schedule Page:310.4 Line No.:13 Column:b
Financial Transmission Losses
Schedule Page:310.4 Line No.:14 Column:b
Financial Transmission Losses
FERC FORM NO.1 (ED.12-87)Page 450.2
Date of Report
(Mo,Da,Yr)
04/14/2020
Year/Period of Report
End of 2019/Q4
Name of Respondent
Idaho Power Company
This Report Is:
(1)[X]An Original
(2)||A Resubmission
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 Account imoun
urrent
or
earNo.(b)(c)(a)
1 1.POWER PRODUCTION EXPENSES
2 A.Steam Power Generation
3 Operation
1 ,204,9424(500)Operation Supervision and Engineering
5 (501 )Fuel
1,533,140
105,256,975 115,523,971
9,912,7346^(502)Steam Expenses 10,783,230
7 (503)Steam from Other Sources
8 (Less)(504)Steam Transferred-Cr.
1,894,278 1 ,868,4339(505)Electric Expenses
9,134,29310(506)Miscellaneous Steam Power Expenses 9,195,043
250,86111(507)Rents 224,649
12 (509)Allowances
13 TOTAL Operation (Enter Total of Lines 4 thru 12)128,887,315 137,895,234
14 Maintenance
213,25615(510)Maintenance Supervision and Engineering 139,168
295,201 349,42316(51 1 )Maintenance of Structures
10,847,20117(512)Maintenance of Boiler Plant
18 (513)Maintenance of Electric Plant
10,532,166
4,545,0264.078,463
6,024,870 7,142,70419(514)Maintenance of Miscellaneous Steam Plant
20 TOTAL Maintenance (Enter Total of Lines 15 thru 19)21,069,868 23,097,610
160,992,84421TOTALPowerProductionExpenses-Steam Power (Entr Tot lines 1 3 &20)149,957,183
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
5,629,02044(535)Operation Supervision and Engineering
45 (536)Water for Power
5,775,190
6,626,256 9,123,648
14,697,182 15,387,25046(537)Hydraulic Expenses
47 (538)Electric Expenses 2,049,374 1 ,884,840
5,600,84348(539)Miscellaneous Hydraulic Power Generation Expenses 5,798,449
252,726 246,70449(540)Rents
50 TOTAL Operation (Enter Total of Lines 44 thru 49)35,199,177 37,872,305
51 C.Hydraulic Power Generation (Continued)
52 Maintenance
134,465 93,53053(541)Mainentance Supervision and Engineering
745,08154(542)Maintenance of Structures 646,148
633,585 332,57155(543)Maintenance of Reservoirs,Dams,and Waterways
56 (544)Maintenance of Electric Plant 2,369,254 2,988,299
2,804,309 2,666,88357(545)Maintenance of Miscellaneous Hydraulic Plant
58 TOTAL Maintenance (Enter Total of lines 53 thru 57)6,587,761 6,826,364
41,786,938 44,698,66959TOTALPowerProductionExpenses-Hydraulic Power (tot of lines 50 &58)
Page 320FERCFORMNO.1 (ED.12-93)
Year/Period of Report
End of 2019/Q4
Date of Report
(Mo,Da,Yr)
04/14/2020
Name of Respondent
Idaho Power Company
This Report Is:
(1)mAn 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.
„mpuntfprPreviousYear
ALineAccountmoun
urrent
or
earNo.(c)(b)(a)
60 D.Other Power Generation
61 Operation
648,94762(546)Operation Supervision and Engineering
63 (547)Fuel
671,349
17,673,94951,615,143
4,513,4264,395,34564(548)Generation Expenses
1 ,406,54965(549)Miscellaneous Other Power Generation Expenses 633,622
66 (550)Rents
24,242,87157,315,45967TOTALOperation(Enter Total of lines 62 thru 66)
68 Maintenance
4069(551)Maintenance Supervision and Engineering
215,293207,99970(552)Maintenance of Structures
124.643260,73471(553)Maintenance of Generating and Electric Plant
72 (554)Maintenance of Miscellaneous Other Power Generation Plant 2,641,0042,840,749
2,980,9803,309,48273TOTALMaintenance(Enter Total of lines 69 thru 72)
27.223.85160,624,94174TOTALPowerProductionExpenses-Other Power (Enter Tot of 67 &73)
75 E.Other Power Supply Expenses
287,762,141280,320,69776(555)Purchased Power
77 (556)System Control and Load Dispatching 5,3314,948
46,535,9086,759,64978(557)Other Expenses
334,303,38079TOTALOtherPowerSupplyExp(Enter Total of lines 76 thru 78)
80 TOTAL Power Production Expenses (Total of lines 21 ,41 ,59,74 &79)
287,085,294
567.218.744539,454,356
2.TRANSMISSION EXPENSES81
82 Operation
3.318.397!3,163,97283(560)Operation Supervision and Engineering
84
22,832 10,08485(561.1)Load Dispatch-Reliability
2,117,7262,389,65686(561.2)Load Dispatch-Monitor and Operate Transmission System
87 (561.3)Load Dispatch-Transmission Service and Scheduling 1,440,8421,042,766
9,944 6,43888(561 .4)Scheduling,System Control and Dispatch Services
89 (561.5)Reliability,Planning and Standards Development
90 (561.6)Transmission Service Studies
30,393 35,96191(561.7)Generation Interconnection Studies
92 (561 .8)Reliability,Planning and Standards Development Services
93 (562)Station Expenses
1,715.6392,001,275
2,816,318 2,855,188
896,240 878,70894(563)Overhead Lines Expenses
95 (564)Underground Lines Expenses
96 (565)Transmission of Electricity by Others 2,844,842 3,602,155
15,16597(566)Miscellaneous Transmission Expenses
2.710.6733,934,69698(567)Rents
99 TOTAL Operation (Enter Total of lines 83 thru 98)19,152,934 18,706,976
100 Maintenance
712,201-40,993101(568)Maintenance Supervision and Engineering
-2,653102(569)Maintenance of Structures
34,910 33,857103(569.1)Maintenance of Computer Hardware
1,024,3041,176,214104(569.2)Maintenance of Computer Software
15,55316,080105(569.3)Maintenance of Communication Equipment
106 (569.4)Maintenance of Miscellaneous Regional Transmission Plant
1,616,137 1.721.024107(570)Maintenance of Station Equipment
832,096991,062108(571)Maintenance of Overhead Lines
109 (572)Maintenance of Underground Lines
470110(573)Maintenance of Miscellaneous Transmission Plant
3,793,880 4,336,382111TOTALMaintenance(Total of lines 101 thru 110)
22,946,814 23,043,358112TOTALTransmissionExpenses(Total of lines 99 and 111)
Page 321FERCFORMNO.1 (ED.12-93)
Year/Period of Report
End of 2019/Q4
This Report Is:
(1)m An Original
(2)A Resubmission
ELECTRIC OPERATION AND MAINTENANCE EXPENSES (Continued)
Date of Report
(Mo,Da,Yr)
04/14/2020
Name of Respondent
Idaho Power Company
If the amount for previous year is not derived from previously reported figures,explain in footnote.
Amount forPreviousYearV;&Line Account moun
urrent
or
earNo.(c)(b)(a)
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
118 (575.4)Capacity Market Facilitation
119 (575.5)Ancillary Services Market Facilitation
120 (575.6)Market Monitoring and Compliance
411,723121(575.7)Market Facilitation,Monitoring and Compliance Services 611,254
122 (575.8)Rents
411,723611,254123TotalOperation(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)411,723611,254
132 4.DISTRIBUTION EXPENSES
133 Operation
4,550,9064,385,764134(580)Operation Supervision and Engineering
4,354,5624,529,601135(581 )Load Dispatching
136 (582)Station Expenses 1,565,9051,601,059
4,095,135 3,896,819137(583)Overhead Line Expenses
3,392,1393,628,041138(584)Underground Line Expenses
157,86161,704139(585)Street Lighting and Signal System Expenses
4.402,350 4,570,706140(586)Meter Expenses
1,287,2511,231,750141(587)Customer Installations Expenses
4,939,6454,492,746142(588)Miscellaneous Expenses
332,764 1,203,806143(589)Rents
144 TOTAL Operation (EnterTotal of lines 134 thru 143)29,919,60028,760,914
145 Maintenance
604,934-274,492146(590)Maintenance Supervision and Engineering
-1 ,04868,850147(591 )Maintenance of Structures
4.482.3184,143,359148(592)Maintenance of Station Equipment
17,401,29716,936,900149(593)Maintenance of Overhead Lines
703,795726,528150(594)Maintenance of Underground Lines
51,099 45,593151(595)Maintenance of Line Transformers
589,313260,970152(596)Maintenance of Street Lighting and Signal Systems
91 1 ,444,910,486153(597)Maintenance of Meters
214,170198,923154(598)Maintenance of Miscellaneous Distribution Plant
24,951,81623,022,623155TOTALMaintenance(Total of lines 146 thru 154)
54,871,41651,783,537156TOTALDistributionExpenses(Total of lines 144 and 155)
157 5.CUSTOMER ACCOUNTS EXPENSES
158 Operation
1,116,501941,128159(901)Supervision
1,790,5121,801,856160(902)Meter Reading Expenses
161 (903)Customer Records and Collection Expenses 13,951,11213,233,844
2,249,077 3,350,112162(904)Uncollectible Accounts
-4114163(905)Miscellaneous Customer Accounts Expenses
20,208,23318,226,019164TOTALCustomerAccountsExpenses(Total of lines 159 thru 163)
Page 322FERCFORMNO.1 (ED.12-93)
Name of Respondent
Idaho Power Company
This Report Is:
(1)pq An Original
(2)| |A Resubmission
ELECTRIC OPERATION AND MAINTENANCE EXPENSES (Continued)
Date of Report
(Mo.Da,Yr)
04/14/2020
Year/Period of Report
End of 2019/Q4
If the amount for previous year is not derived from previously reported figures,explain in footnote.
Amount forPreviousYearv;Line Account &orrnoun
urrent earNo.(C)(a)(b)
165 6.CUSTOMER SERVICE AND INFORMATIONAL EXPENSES
166 Operation
802,563167(907)Supervision 786,744
42,486,187168(908)Customer Assistance Expenses 47,188,829
341,699165,868169(909)Informational and Instructional Expenses
627,857170(910)Miscellaneous Customer Service and Informational Expenses 619,951
44,258,306171TOTALCustomerServiceandInformationExpenses(Total 167 thru 170)48,761 ,392
172 7.SALES EXPENSES
173 Operation
174 (911)Supervision
175 (912)Demonstrating and Selling Expenses
176 (913)Advertising Expenses
177 (916)Miscellaneous Sales Expenses
178 TOTAL Sales Expenses (Enter Total of lines 174 thru 177)
179 8.ADMINISTRATIVE AND GENERAL EXPENSES
180 Operation
88,828,776181(920)Administrative and General Salaries 89,843,262
14,790,380182(921)Office Supplies and Expenses 14,655,584
33,154,579 29,219,811183(Less)(922)Administrative Expenses Transferred-Credit
7,744,1339,431 ,043184(923)Outside Services Employed
3,010,285185(924)Property Insurance
186 (925)Injuries and Damages
3,437,586
5,349,936 5,617,495
52,315,07452,072,747187(926)Employee Pensions and Benefits
188 (927)Franchise Requirements
5,320,889 5,021,358189(928)Regulatory Commission Expenses
190 (929)(Less)Duplicate Charges-Cr.
191 (930.1)General Advertising Expenses
192 (930.2)Miscellaneous General Expenses
46,762 603,786
3,605,1533,634,788
193 (931)Rents
150,638,018 152,316,629194TOTALOperation(Enter Total of lines 181 thru 193)
195 Maintenance
6,842,171196(935)Maintenance of General Plant 7,238,346
157,876,364 159,158,800197TOTALAdministrative&General Expenses (Total of lines 194 and 196)
869,170,580198TOTALElecOpandMaintExpns(Total 80,1 1 2,1 31 ,1 56,164,1 71 ,1 78,1 97)839,659,736
Page 323FERCFORMNO.1 (ED.12-93)
This Report Is:
X]An Original
Year/Period of Report
End of 2019/Q4
Date of Report
(Mo,Da,Yr)
04/14/2020
Name of Respondent
Idaho Power Company (1)
|A Resubmission(2)
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 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 Average
Monthly Billing
Demand (MW)
Statistical
Classifi
cation
Name of Company or Public Authority
(Footnote Affiliations)
Line Schedule or
Tariff Number
AverageNo.
(f)(d)(e)(b)(c)(a)
N/AN/AN/A1AmericanFallsSolar,LLC LU
N/AN/AN/A2AmericanFallsSolarII,LLC LU
N/AN/A N/A3AgPowerJeromeLLC-Double A Digester LU
N/AN/AN/A4AllanRavenscroft/Malad River LU
N/AN/AN/ALU5BakerCityHydro
N/AN/AN/ALU6BannockCounty,Idaho
N/A N/AN/A7BennettCreekWindFarmLU
N/AN/A N/A8BensonCreekWindFarmLU
N/AN/AN/A9BettencourtDryCreekBiofactoryLU
N/AN/AN/ALU10BigSkyWestDairyDigester
N/AN/A N/A11BlackCanyonBlissLU
N/AN/AN/A12BlindCanyonHydroLU
N/AN/AN/A13Branchflower-Trout Company LU
N/AN/AN/ALU14BurleyButteWindPark
Total
Page 326FERCFORMNO.1 (ED.12-90)
This Report Is:
(1 )fx)An Original
(2)[|A Resubmission
Name of Respondent
Idaho Power Company
Date of Report
(Mo,Da,Yr)
04/14/2020
Year/Period of Report
End of 2019/Q4
PURCHASED P0WER(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.
COST/SETTLEMENT OF POWERPOWEREXCHANGES LineMegaWattHours
Purchased MegaWatt Hours
Received
MegaWatt Hours
Delivered
Demand Charges Energy Charges Other Charges Total G+k+l)
of Settlement ($)No.
($)($)«(I)(m)(g)(h)0)0)
11,262,802 1,262,80243,224
21,283,686 1,283,68643,611
31,539,99918,956 1,539,999
4190,1822,757 51,102 139,080
539,556 39,559648
6532,333 532,3338,964
72,660,042 2,660,04239,824
81,689,34028,425 1,689,340
91,079,967 1,079,96711,962
10606,613 606,6139,513
117,4051947,405
74,353 1274,3531,517
1363,151 63,151887
1456,106 3,458,016 3,458,016
280,631 270,606,686 9,433,380 280,320,6975,194,040 59,640 148,478
Page 327FERCFORMNO.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 2019/Q4
Date of Report
(Mo.Da,Yr)
04/14/2020
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
Monthly NCP Demand Monthly CP Demand
Statistical
Classifi
cation
FERC Rate Average
Monthly Billing
Demand (MW)
Name of Company or Public Authority
(Footnote Affiliations)
Line Schedule or
Tariff Number
AverageNo.
(e)(f)(a)(b)(c)(d)
N/A N/A1CAFCOIdahoRefuseManagementLLC-SI N/ALU
N/AN/A N/A2CampReedWindParkLU
N/AN/A N/A3CassiaWindFarmLU
4 CCP OR Tenant 1,LLC
N/A N/A5GroveSolarCenter,LLC LU N/A
N/A N/AHylineSolarCenter,LLC N/A6LU
N/AN/A N/A7OpenRangeSolarCenter,LLC LU
N/A N/A N/ARailroadSolarCenter,LLC LU8
N/A N/AValeAirSolarCenter,LLC LU N/A9
N/A N/AN/AThundereggSolarCenter,LLC LU10
N/AN/A N/A11CityofHaileyLU
N/A N/A N/ALU12CityofPocatello
N/A N/AN/A13ClearSpringsFoodInc.LU
N/A N/A14CliftonE.Jenson -Birch Creek N/ALU
Total
Page 326.1FERCFORMNO.1 (ED.12-90)
This Report Is:
[X|An Original
Name of Respondent
Idaho Power Company
Date of Report
{Mo.Da,Yr)
04/14/2020
Year/Period of Report
End of 2019/Q4(1)
H(2)A Resubmission
PTJRCRSSED 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
MegaWatt Hours MegaWatt Hours
Received Delivered
COST/SETTLEMENT OF POWER
Demand Charges Energy Charges Other Charges Total (j+k+l)
of Settlement ($)
LineMegaWattHours
Purchased No.
($)ffl ($)(g)(h)(i)0)(I)(m)
116,303 553,963 553,963
265,323 5,393,008 5,393,008
318,646 964,518 964,518
4
513,397 852.031 852.031
620,130 1,279,640 1,279,640
722,836 1,452,994 1,452,994
89,996 637,586 637,586
921,793 1,387,340 1,387,340
1022,371 1,425,547 1,425,547
11966,3326,332
121,420 104,310 104,310
133,434 208,203 208,203
1435514,583 16,058 30,641
5,194,040 59,640 148,478 280,631 270,606,686 9,433,380 280,320,697
Page 327.1FERCFORMNO.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)
04/14/2020
Year/Period of Report
End of 2019/Q4
PURCHASED POWER (Accoui
(including power exchangesm 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)
Average Average
Monthly NCP Demantl 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
No.
(f)(b)(c)(d)(e)(a)
N/AN/A N/A1ColdSpringsWindfarm,LLC LU
N/AN/A N/A2CollegeofSouthernIdaho-Pristine S LU
N/A N/A3CollegeofSouthernIdaho-Pristine S LU N/A
4 Consolidated Hydro Inc./Enel
N/AN/A N/ABarberDamLU5
N/AN/A N/A6DietrichDropLU
N/A N/ALowline#2 LU N/A7
N/ARockCreek#2 N/A N/A8LU
N/AN/A N/A9CrystalSpringsHydroLU
N/A N/A N/A10CurryCattleCompanyLU
N/A11CycleHorseshoeBendWind,LLC LU N/A N/A
N/AN/A N/A12DavidRSnedigarLU
N/AN/A N/A13DesertMeadowWindfarmLU
N/A N/A14DurbinCreekWindfarmLUN/A
Total
Page 326.2FERCFORMNO.1 (ED.12-90)
This Report Is:
(1)[x]An Original
(2)f~(A Resubmission
PURCHASED POWER(Account 555)(Continued)
(Including power exchanges)
Name of Respondent
Idaho Power Company
ate of Report
(Mo,Da,Yr)
04/14/2020
Year/Period of Report
End of 2019/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 (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 Energy Charges Other Charges Total (j+k+l)
of Settlement ($)
MegaWatt Hours
Received
MegaWatt Hours
Delivered
Demand Charges No.
($)ffl ($)(g)(h)(i)G)(I)(m)
150,137 3,925,652 3,925,652
751 248,500 48,500
1,416 390,586 90,586
4
513,076 653,058 653,058
612,904 728,079 728,079
71,908 69,802 69,802
81,053 39,541 39,541
911,923 807,757 807,757
1074963,975 63,975
1116,483 1,021,329 1,021,329
121,266 87,180 87,180
1356,858 4,462,530 4,462,530
1426,115 1,538,879 1,538,879
5,194,040 59,640 148,478 280,631 270,606,686 9,433,380 280,320,697
Page 327.2FERCFORMNO.1 (ED.12-90)
This Report 1st
[X]An Original
Year/Period of Report
End of 2019/Q4
Date of Report
(Mo,Da,Yr)
04/14/2020
Name of Respondent
Idaho Power Company (1)
(2)|[A Resubmission
PURCHASED POWER (/
(Including power excn
nt 555)Accoui
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.
(f)(e)(c)(d)(b)(a)
N/AN/A N/A1EightmileHydroCorpLU
N/AN/A N/A2ElDoradoHydro-Elk Creek LU
3 Enerparc Solar Development LLC
N/AN/AN/ALUBakerSolarCenter4
N/ALUN/A N/ABrushSolar5
N/AN/A N/ALUMorganSolar6
N/AN/ALUN/AValeISolar7
N/AN/AN/ALU8FaulknerBrothersHydroInc.
N/AN/A N/A9FisheriesDevelopmentLU
N/AN/AN/ALU10FossilGulchWind
N/AN/AN/ALU11G2EnergyHiddenHollow
N/AN/AN/A12GoldenValleyWindParkLU
N/AN/A N/A13GrandViewPVSolarTwo,LLC LU
N/AN/A N/A14HammettHillWindfarm,LLC LU
Total
Page 326.3FERCFORMNO.1 (ED.12-90)
This Report Is:
X|An Original
Name of Respondent
Idaho Power Company
Year/Period of Report
End of 2019/Q4
Date of Report
{Mo,Da,Yr)
04/14/2020
(1)
s(2)A Resubmission
PURCHASED POWER(Account 355)(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.
(?)(?)(m)(g)(i)0)(k.(I)(h)
194,7521,517 94,752
2256,8313,718 256,831
3
41761767
51,926 -11,960 -10,03475
6-15,022 -15,022
7120-14,219 -14,199
8258,023 258,0233,293
911,399 11,399492
101,574,05624,819 1,574,056
1125,495 1 ,766,390 1,766,390
1230,219 1,858,364 1,858,364
139,975,950 9,975,950179,177
144,064,045 4,064,04551,737
9,433,380 280,320,6975,194,040 59,640 148,478 280,631 270,606,686
Page 327.3FERCFORMNO.1 (ED.12-90)
Name of Respondent
Idaho Power Company
This Report Is:
(1)[X'i An Original
(2)[A Resubmission
Year/Period of Report
End of 2019/Q4
Date of Report
{Mo,Da,Yr)
04/14/2020
rjt 555)PURCHASED POWER (/
(Including power exch
Accoui
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)FERC Rate
Schedule or
Tariff Number
Statistical
Classifi
cation
Average
Monthly Billing
Demand (MW)
Name of Company or Public Authority
(Footnote Affiliations)
Line Average
Monthly NCP Demand Monthly CP Demand
Average
No.
(f)(b)(c)(d)(e)(a)
LU N/A N/AN/A1HazeltonBPowerCompany
N/A N/AN/A2HighMesaEnergyLU
N/AN/A3H.K.Hydro Mud Creek S &S N/ALU
N/A N/AN/A4HorseshoeBendHydroLU
N/A N/AN/A5HotSpringsWindFarmLU
N/AN/AN/A6IDSolar1,LLC LU
N/AN/A7IdahoWinds-Sawtooth Wind Project LU N/A
N/AN/AN/A8JRSimplotCo.IU
N/A N/AN/A9J.M.Miller/Sahko Hydro LU
N/A N/A10JettCreekWindfarmLUN/A
N/AN/AN/A11JohnRLeMoyneLU
N/A N/AN/A12KootenaiElectricCooperative-Fighti LU
N/A N/AN/A13KooshInc.Geo Bon #2 LU
N/A N/AN/A14KoyleHydroInc.LU
Total
Page 326.4FERCFORMNO.1 (ED.12-90)
This Report Is:
(1)fx")An Original
(2)r~|A Resubmission
Name of Respondent
Idaho Power Company
Year/Period of Report
End of 2019/Q4
Date of Report
(Mo,Da,Yr)
04/14/2020
HASEBPOWER(AooouniSSS)(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
Energy Charges Other Charges Total (j+k+l)
of Settlement ($)
LineMegaWattHours
Purchased MegaWatt Hours
Received
MegaWatt Hours
Delivered
Demand Charges No.
(?)ffi (?)(g)(h)(i)(j)(I)(m)
122,447 1,612,342 1,612,342
292,795 5,008,281 5,008,281
31,707 100,525 100,525
437,422 2,715,208 2,715,208
537,139 2,461,725 2,461,725
694,464 4,996,178 4,996,178
754,367 4,777,5744,777,574
83,539,37665,655 3,539,376
91,336 118,272 118,272
1028,489 1,703,175 1,703,175
1164636,129 36,129
1214,645 1,242,783 1,242,783
134,364 320,761 320,761
143,926 224,759 224,759
5,194,040 59,640 148,478 280,631 270,606,686 9,433,380 280,320,697
Page 327.4FERCFORMNO.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)
04/14/2020
Year/Period of Report
End of 2019/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 ofthe 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 Lateral 10 Ventures N/A N/ALU N/A
2 Lemhi Hydro Power Co.-Schaffner N/ALU N/A N/A
3 Lime Wind LU N/A N/A N/A
4 Little Mac Power Co./Cedar Draw LU N/A N/A N/A
5 Little Wood River Irrigation District N/A N/A N/ALU
6 Mainline Windfarm N/ALU N/A N/A
7 Marco Rancher's Irrigation Inc.LU N/A N/A N/A
8 Marysville Hydro Partners-Falls River LU N/A N/A N/A
9 McCollum Enterprises -Canyon Springs N/A N/ALU N/A
Milner Dam Wind Park10 LU N/A N/A N/A
Mountain Home Solar I,LLC11 LU N/A N/A N/A
12 Mud Creek White Hydro,Inc LU N/A N/A N/A
13 Murphy Flat Power,LLC N/A N/ALU N/A
14 New Energy One -Rock Creek Dairy LU N/A N/A N/A
Total
Page 326.5FERCFORMNO.1 (ED.12-90)
This Report Is:
X]An Original
A Resubmission
Year/Period of Report
End of 2019/Q4
Name of Respondent
Idaho Power Company
Date of Report
(Mo,Da,Yr)
04/14/2020
(1)
a(2)
PURCHAi^ED^PQWp^Acwuri^§5SyContinued )
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 Other Charges Total (j+k+l)
of Settlement ($)
MegaWatt Hours
Received
MegaWatt Hours
Delivered
Demand Charges Energy Charges No.
($)($)(I)(m)(i)0)(K(g)(h)
1442,904442,9047,020
294,57694,5761,250
3471,3075,900 471,307
4317,066317,0665,822
5606,130606,1308,444
64,329,143 4,329,14355,289
7196,249196,2492,929
83,232,5203,232,52047,835
936,74936,749610
103,152,3303,152,33051,216
111,982,5231,982,52349,741
1235,59135,591527
131,465,286 1,465,28646,119
14904,828 904,8289,526
9,433,380 280,320,69759,640 148,478 280,631 270,606,6865,194,040
Page 327.5FERCFORMNO.1 (ED.12-90)
This Report Is:
(1)[x|An Original
(2)| |A Resubmission
RCHASED POWER U(Including power exch
Date of Report
(Mo.Da,Yr)
04/14/2020
Year/Period of Report
End of 2019/Q4
Name of Respondent
Idaho Power Company
rjt 555)PU Accoui
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.
(e)(f)(c)(d)(a)(b)
N/AN/A N/A1NorthGoodingMain,Hydro LU
2 North Side Energy Company Inc
N/AN/A N/A3BypassLimitedLU
N/AN/AN/A4HazeltonALU
N/AN/A N/AHeadofUCanalLU5
N/AN/A N/A6OrchardRanchSolar,LLC LU
N/AN/A N/A7OregonTrailWindParkLU
8 Owyhee Irrigation District
N/AN/A N/ALU9MitchellButte
N/AN/A N/AOwyheeDamLU10
N/AN/AN/A11Tunnel#1 LU
N/A N/AN/A12Payne's Ferry Wind Park LU
N/AN/A N/A13PicoEnergy-B6 Anaerobic Digester LU
N/AN/A N/A14PigeonCovePowerLU
Total
Page 326.6FERCFORMNO.1 (ED.12-90)
This Report Is;
(1)fx]An Original
(2)I l A Resubmission
Year/Period of Report
End of 2019/Q4
Date of Report
(Mo,Da,Yr)
04/14/2020
Name of Respondent
Idaho Power Company
WER^AcMunt^555)^^(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 Other Charges Total (j+k+l)
of Settlement ($)
MegaWatt Hours
Received
MegaWatt Hours
Delivered
Demand Charges Energy Charges No.
($)(?)(m)(k.(I)(g)(h)(i)(j)
1404,569404,5694,812
2
31,403,2681,403,26825,904
41,948,01823,166 1,948,018
5408,4224,494 408,422
61,404,4751,404,47548,214
2,268,033 72,268,03336,487
8
9193,133193,1336,794
10522,227522,22721,878
11712,989 712,98922,316
125,122,7735,122,77361,653
131,379,5811,379,58115,633
14637,992331,258 306,7347.73C
280,320,697148,478 280,631 270,606,686 9,433,3805,194,040 59,640
Page 327.6FERCFORMNO.1 (ED.12-90)
This Report Is:
(1)[X]An Original
(2)QA Resubmission
Name of Respondent
Idaho Power Company
Date of Report
(Mo,Da,Yr)
04/14/2020
Year/Period of Report
End of 2019/Q4
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 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
FERC Rate
Schedule or
Tariff Number
Statistical
Classifi
cation
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 Pilgrim Stage Station Wind Park N/A N/A N/ALU
N/A N/A2ProspectorWindfarmLUN/A
N/A N/A3ReynoldsIrrigationDistrictLUN/A
4 Richard Kaster
5 Box Canyon N/A N/A N/ALU
6 Briggs Creek N/A N/ALUN/A
N/A N/A7RiversideHydro-Mora Drop LU N/A
8 Riverside Investments
N/A N/A N/A9ArenaDropLU
N/A N/A10FargoDropLUN/A
N/A N/A11RocklandWindProjectLUN/A
12 Ryegrass Windfarm N/A N/A N/ALU
N/A N/A N/A13SalmonFallsWindParkLU
N/A N/A14ShingleCreekLLCLUN/A
Total
Page 326.7FERCFORMNO.1 (ED.12-90)
This Report is:
|Xj An Original
Name of Respondent
Idaho Power Company
Date of Report
(Mo,Da,Yr)
04/14/2020
Year/Period of Report
End of 2019/Q4(1)
(2)| |A Resubmission
^Cj POWER(Accounl^555)^^(Continued)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 MegaWatt Hours
Received
MegaWatt Hours
Delivered
Demand Charges Energy Charges Other Charges Total (j+k+l)
of Settlement ($)No.
(?)(?)
(g)(h)0)G)(k:(i)(m)
131,677 1,966,421 1,966,421
228,126 1,671,437 1,671,437
31,086 80,568 80,568
4
51,942 123,203 123,203
63,624 247,188 247,188
4.54E 294,421 294,421
8
91,585 142,606 142,606
103,760 226,058 226,058
11247,583 17,192,513 17,192,513
1252,259 4,094,862 4,094,862
1360,456 3,728,612 3,728,612
141,064 63,513 63,513
5,194,040 59,640 148,478 280,631 270,606,686 9,433,380 280,320,697
Page 327.7FERCFORMNO.1 (ED.12-90)
This Report Is:
(1 )fx]An Original
(2)A Resubmission
Name of Respondent
Idaho Power Company
Date of Report
(Mo,Da,Yr)
04/14/2020
Year/Period of Report
End of 2019/Q4
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 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 T Average "
Monthly NCP Demand Monthly CP DemandNo.
(a)(b)(c)(d)(e)(f)
1 Shorock Hydro Inc.
2 Rock Creek #1 LU N/A N/A N/A
3 Shoshone CSPP LU N/A N/A N/A
Shoshone #24 LU N/A N/A N/A
5 Simcoe Solar,LLC N/A N/ALU N/A
6 Snake River Pottery LU N/A N/A N/A
7 South Forks Joint Venture-Lowline Cana LU N/A N/A N/A
8 Tamarack Energy Partnership LU N/A N/A N/A
OS9Tasco-Nampa N/A N/A N/A
10 Tasco -Twin Falls OS N/A N/A N/A
1 1 Thousand Springs Wind Park LU N/A N/A N/A
12 Tiber Montana LLC -Tiber Dam LU N/A N/A N/A
13 Tuana Gulch Wind Park LU N/A N/A N/A
14 Tuana Springs Expansion LU N/A N/A N/A
Total
Page 326.8FERCFORMNO.1 (ED.12-90)
This Report Is:
(1)[X]An Original
Name of Respondent
Idaho Power Company
Date of Report
(Mo,Da,Yr)
04/14/2020
Year/Period of Report
End of 2019/Q4(2)I |A Resubmission
SED POWER(Account 555}(Continued!(Including 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.
POWER EXCHANGES COST/SETTLEMENT OF POWER LineMegaWattHours
Purchased Total (j+k+l)
of Settlement ($)
MegaWatt Hours
Received
MegaWatt Hours
Delivered
Demand Charges Energy Charges Other Charges No.
($)($)
(j)(0 (m)(g)(h)(i)\K
1
211,216 648,188 648,188
3106,4741,802 106,474
4190,8102,825 190,810
548,273 1,534,554 1,534,554
641527,695 27,695
71,903,70926,280 1,903,709
825,192 1 ,459,648 1,459,648
914149149
10
111,902,97030,707 1,902,970
121,727,87427,814 1,727,874
1328,917 1,796,995 1,796,995
1470,139 5,728,505 5,728,505
59,640 148,478 280,631 270,606,686 9,433,380 280,320,6975,194,040
Page 327.8FERCFORMNO.1 (ED.12-90)
This Report !s:
[X]An Original
Year/Period of Report
End of 2019/Q4
Date of Report
(Mo,Da,Yr)
04/14/2020
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 of the Length ofthe 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
Statistical
Classifi
cation
Average
Monthly Billing
Demand (MW)
Name of Company or Public Authority
(Footnote Affiliations)
Line Average Average
Monthly NCP Demand Monthly CP DemandNo.
(e)(f)(b)(c)(d)(a)
N/AN/A N/ALU1TwinFallsEnergy-Lowline Midway Hydro
N/AN/A N/ALU2TwoPondsWindfarm
N/AN/AN/A3WhiteWaterRanchLU
N/A N/AN/A4WilliamArkoosh-Littlewood/Arkoosh LU
N/AN/A N/ALU5WilliamArkoosh-Littlewood River Ranc
N/AN/A N/ALU6WillowSpringWindfarm
N/ALUN/AN/A7WilsonPowerCompany
8 Wood Hydro
N/AN/A N/ABlackCanyon#3 LU9
N/AN/A N/ALU10JimKnight
N/A N/AN/ALU11MagicReservoir
N/A N/AN/ALU12Mile28
N/AN/A N/ALU13Sagebrush
N/AN/A N/ALU14YahooCreekWindPark
Total
Page 326.9FERCFORMNO.1 (ED.12-90)
This Report Is:
[X]An Original
Name of Respondent
Idaho Power Company
Date of Report
{Mo,Da,Yr)
04/14/2020
Year/Period of Report
End of 2019/Q4(1)
(2)f~]A Resubmission
SED PQWER(Account 555)(Continued)(Including 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.
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.
($)($)
(h)0)(k.0)(m)(g)(i)
1533,344 533,3448,735
250,458 3,983,861 3,983,861
346,497 46,497681
4318,083 318,0834,331
5327,7364,822 327,736
632,023 1 ,884,034 1,884,034
725,269 1,813,266 1,813,266
8
928,77840428,778
1074,5581,055 74,558
111,518,840 1,518,84029,810
12-48,443926-116,312 67,869
1397269,251 69,251
1462,906 5,249,623 5,249,623
5,194,040 148,478 280,631 270,606,686 9,433,380 280,320,69759,640
Page 327.9FERCFORMNO.1 (ED.12-90)
This Report Is:
(1)[X]An Original
(2)|A Resubmission
Year/Period of Report
End of 2019/Q4
Date of Report
(Mo,Da,Yr)
04/14/2020
Name of Respondent
Idaho Power Company
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 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
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 DemandNo.
(e)(f)(d)(c)(b)(a)
N/AN/AN/AOS1SchedulingDeviation
2 Other Purchased Power
N/AN/AN/AWSPPSF3 3 Phases Renewables Inc.
N/AN/AOSWSPPN/A4ADMInvestorServices,Inc.
N/AN/AWSPPN/ASF5ArizonaPublicServiceCo.
N/AN/AOSN/AWSPP6AVANGRIDRENEWABLES,LLC
N/AN/AN/AWSPP7AVANGRIDRENEWABLES,LLC SF
N/AOSN/AT-12 N/A8AvistaCorp.
N/AN/AN/AOSWSPP9AvistaCorp.
N/AN/AN/ASFWSPP10AvistaCorp.
N/AN/AN/AWSPPSF11BlackHillsPowerInc.
N/AN/AOSWSPPN/ABonnevillePowerAdministration12
N/AN/AOSN/AWSPP13BonnevillePowerAdministration
N/AN/AN/ASFWSPP14BonnevillePowerAdministration
Total
Page 326.10FERCFORMNO.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)
04/14/2020
Year/Period of Report
End of 2019/Q4
PQWER(Account 555)^,(Continued)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 (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 Total (j+k+l)
of Settlement ($)
MegaWatt Hours
Received
MegaWatt Hours
Delivered
Demand Charges Energy Charges Other Charges No.
($)s ($)
0)G)(I)(m)(g)(h)
120,555
2
3409,825409,82520,087
42,210,772 2,210,772
5662,80023,800 662,800
6663
7161,322 161,3227,300
849749718
997,079 97,079
10219,107219,1078,474
1112012040
122,838 2,838110
13284,079 284,079
14771,753 771,75329,388
9,433,380148,478 280,631 270,606,686 280,320,6975,194,040 59,640
Page 327.10FERCFORMNO.1 (ED.12-90)
This Report Is:
(1)fx]An Original
(2)j |A Resubmission
PURCHASED POWER (Account 555)(Including power exchanges)
Date of Report
(Mo,Da,Yr)
04/14/2020
Year/Period of Report
End of 2019/Q4
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 ofthe 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.
(f)(a)(b)(c)(d)(e)
1 BP Energy Company SF WSPP N/A N/A N/A
N/A N/A N/A2CaliforniaIndependentSystemOperatorSFCAISO
OS N/A N/A3ChelanCoPUD
~4 Chelan Co PUD
WSPP N/A
N/ASFWSPPN/A N/A
OS N/A5CitigroupEnergyInc.ISDA N/A N/A
SF N/A N/A N/A6CitigroupEnergyInc.ISDA
N/A N/A7CitigroupEnergyInc.SF WSPP N/A
N/A8ClatskaniePUDSFWSPPN/A N/A
9 Clean Power Alliance of Southern Calif SF WSPP N/A N/A N/A
OS N/A N/A N/A10DouglasCountyPUDWSPP
N/A N/A11DTEEnergyTrading,Inc.SF WSPP N/A
N/A12EDFTradingNorthAmerica,LLC OS WSPP N/A N/A
13 EDF Trading North America,LLC SF WSPP N/A N/A N/A
N/A N/A N/A14EnergyKeepers,Inc SF WSPP
Total
Page 326.11FERCFORMNO.1 (ED.12-90)
This Report Is:
(1)[x]An Original
(2)HA Resubmission
Year/Period of Report
End of 2019/Q4
Name of Respondent
Idaho Power Company
Date of Report
(Mo,Da,Yr)
04/14/2020
SED PCWER(Account 555)(Continued)
(Including 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
Received
MegaWatt Hours
Delivered
Demand Charges Energy Charges Other Charges Total (j+k+l)
of Settlement ($)No.
(?)ffi (?)
G)(i)(m)(g)(h)G)
117,961,51117,961,511644,225
26,376,029 6,376,029581,888
3442
4655,63226,800 655,632
5-27,836-27,836
61,879,550 1,879,55047,800
7375,908 375,90810,000
879,63215779,632
91,3161,316150
10442
1112,761 12,76152£
1256,2251,360 56,225
13867,415867,41528,160
14131,380 131,3804,928
280,631 270,606,686 9,433,380 280,320,6975,194,040 59,640 148,478
Page 327.11FERCFORMNO.1 (ED.12-90)
This Report Is:
(1)[x]An Original
(2)[~~|A Resubmission
Year/Period of Report
End of 2019/Q4
Name of Respondent
Idaho Power Company
Date of Report
(Mo,Da,Yr)
04/14/2020
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 ofthe 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 ofthe 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 NCR Demand Monthly CP DemandNo.
(e)(f)(a)(b)(c)(d)
N/A N/A1ExelonGenerationCompany,LLC SF WSPP N/A
OS N/AWSPPN/A N/A2GrantCOPublicUtilityDistrict#2 -
N/AOSN/A N/A3GridforceEnergyManagement,LLC WSPP
N/A N/A N/A4MacquarieEnergyLLCSFWSPP
N/A N/A5MorganStanleyCapitalGroupInc.SF ISDA N/A
N/AN/A N/A6NealHotSpringsUnit#1 LU
N/AN/A N/A7NevadaPowerCompany,dba NV Energy SF WSPP
N/A N/AOST-7 N/A8NorthwesternEnergy
N/A N/ASFWSPPN/A9NorthwesternEnergy
N/AOSWSPPN/A N/A10NorthwesternEnergy(Transmission)
OS N/A N/A N/A11NorthwesternEnergy(Transmission)WSPP
OS N/A N/A12OregonSolarCustomersN/A
T-13OS N/A N/AN/A13PacifiCorp
N/ASFWSPPN/A N/A14PacifiCorp
Total
Page 326.12FERCFORMNO.1 (ED.12-90)
This Report Is:
[XjAn Original
Date of Report
(Mo,Da,Yr)
04/14/2020
Year/Period of Report
End of 2019/Q4
Name of Respondent
Idaho Power Company (1)
B(2)A Resubmission
SED P0WER(Account 555)(Continued)(including 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
Other Charges Total (j+k+l)
of Settlement ($)
MegaWatt Hours
Received
Demand Charges Energy Charges No.
($.)($)(m)(k!(I)(h)(i)(j)(g)
1131,985 131,9855,560
21731739
3222222
4157,429157,4296,287
563,72863,7281,207
621,382,50721,382,507185,455
7172.650172,6504,930
861061012
985,37585,3752,865
1014147
111,2041,204
1232,79132,791785
133,2073,207100
14200,404200,4048,600
9,433,380 280,320,697280,631 270,606,68659,640 148,4785,194,040
Page 327.12FERCFORMNO.1 (ED.12-90)
This Report Is:
(1)[X]An Original
(2)[~~A Resubmission
Year/Period of Report
End of 2019/Q4
Date of Report
(Mo.Da,Yr)
04/14/2020
Name of Respondent
Idaho Power Company
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 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.
(e)(f)(c)(d)(a)(b)
OS N/AN/A N/AWSPP
T-14
1 PacifiCorp Inc.
N/AN/AOSN/A2PortlandGeneralElectricCompany
N/A N/ASFWSPPN/A3PortlandGeneralElectricCompany
N/A N/AWSPPN/A4PowerexCorp.SF
N/AN/A N/A5PublicServiceCompanyofNewMexicoSFWSPP
N/AOSN/A N/AT-96PugetSoundEnergy,Inc.
N/A N/ASFWSPPN/A7PugetSoundEnergy,Inc.
N/AN/A N/A8RaftRiverEnergyILLCLU
N/AN/A N/A9RainbowEnergyMarketingCorporationSFWSPP
N/A N/ASFWSPPN/A10SaltRiverProject
N/A N/AOSWSPPN/A11SeattleCityLight
N/AWSPPN/A N/A12SeattleCityLightSF
N/AN/A N/A13ShellEnergyNorthAmerica(US),L.P.SF WSPP
OS N/A N/AT-55 N/A14SierraPacificPowerCo.,dba NV Energ
Total
Page 326.13FERCFORMNO.1 (ED.12-90)
This Report Is:
(1)|x]An Original
(2)| |A Resubmission
I TSlB POWER(Aooount 55Q)(Continued)
(Including power exchanges)
Year/Period of Report
End of 2019/Q4
Name of Respondent
Idaho Power Company
Date of Report
(Mo,Da,Yr)
04/14/2020
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 Other Charges Total G+k+l)
of Settlement ($)
MegaWatt Hours
Received
MegaWatt Hours
Delivered
Demand Charges Energy Charges No.
($)($)
0)(m)(h)(i)(j)(k.(g)
134,893 34,893
276776725
3265,863265,86310,565
4402,570 402,57010,524
512,360 12,360400
61,036 1,03630
7868,634868,63436,800
86,590,6166,590,61695,617
917,974 17,974472
109,2502509,250
1127427411
12195,458 195,4588,871
13518,789 518,78919,205
141,214 1,21446
9,433,380 280,320,6975,194,040 59,640 148,478 280,631 270,606,686
Page 327.13FERCFORMNO.1 (ED.12-90)
This Report Is:
[XjAn Original
Year/Period of Report
End of 2019/Q4
Name of Respondent
Idaho Power Company
Date of Report
(Mo,Da,Yr)
04/14/2020
(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 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.
(e)(f)(a)(b)(c)(d)
N/A1SnohomishCountyPUDSFWSPPN/A N/A
OS N/AWSPPN/A N/A2TacomaPower
SF WSPP N/A N/A N/A3TacomaPower
N/A N/A N/A4TelocasetWindPowerPartnersLLCLUAPP-A
N/A N/A5TenaskaPowerServicesCo.SF WSPP N/A
N/A6TheEnergyAuthority,Inc.SF WSPP N/A N/A
7 TransAlta Energy Marketing (U.S.)Inc.SF WSPP N/A N/A N/A
N/A N/A N/A8Tri-State Generation and Transmission SF WSPP
OS N/A N/A9WesternAreaPowerAdministration(WA WSPP N/A
EX10NorthwesternEnergy
EX11PacifiCorpInc.
EX12SierraPacificPowerCo.,dba NV Energ
EX13ClatskaniePUD 153
"oOS N/A14AcctgValuationofClatskaniePUDN/A N/A
Total
Page 326.14FERCFORMNO.1 (ED.12-90)
This Report Is:
(1)|x|An Original
(2)rn A Resubmission
Date of Report
(Mo,Da,Yr)
04/14/2020
Year/Period of Report
End of 2019/Q4
Name of Respondent
Idaho Power Company
R^Account^555^^(Continued)FuRCRA
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 Other Charges Total (j+k+l)
of Settlement ($)
MegaWatt Hours
Received
MegaWatt Hours
Delivered
Demand Charges Energy Charges No.
($)($)(k (I)(m)(9)(h)(i)(j)
137,26037,2601,650
21661665
33,258 3,258181
419,863,581306,220 19,863,581
526,00840426,008
628,550 28,5501,000
71,834,250 1 ,834,25067,477
826,00026,000400
939739710
1094
1191,519
123,690
1353,17559,640
14-166,066 -166,066
280.631 270,606,686 9,433,380 280,320,6975,194,040 59,640 148,478
Page 327.14FERCFORMNO.1 (ED.12-90)
This Report Is:
[X]An Original
Year/Period of Report
End of 2019/Q4
Name of Respondent
Idaho Power Company
Date of Report
(Mo,Da,Yr)
04/14/2020
(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 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
Statistical
Classifi
cation
Average
Monthly Billing
Demand (MW)
Name of Company or Public Authority
(Footnote Affiliations)
Line Average
Monthly NCP Demand Monthly CP Demand
AverageNo.
(f)(c)(d)(e)(a)(b)
N/AI-N/A N/A1DemandResponseAvoidedEnergyOS
2
3
4
5
6
7
8
9
10
11
12
13
14
Total
Page 326.15FERCFORMNO.1 (ED.12-90)
This Report Is:
X]An Original
Name of Respondent
Idaho Power Company
Year/Period of Report
End of 2019/Q4
Date of Report
(Mo,Da,Yr)
04/14/2020
(1)
PURCHASE^P0W£R(Account 555)(Continued)
(Including power exchanges)
AD -for out-of-period adjustment.Use this code for any accounting adjustments or "true-ups"for service provided in prior reporting
years.Provide an explanation in a footnote for each adjustment.
(2)A Resubmission
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
Energy Charges Other Charges
LineMegaWattHours
Purchased MegaWatt Hours
Received
Demand Charges Total (j+k+l)
of Settlement ($)
MegaWatt Hours
Delivered
No.
(?)(?)
(g)(h)0)(j)(kl (I)(m)
16,996,236 6,996,236
2
3
4
5
6
7
8
9
10
11
12
13
14
9,433,3805,194,040 59,640 148,478 280,631 270,606,686 280,320,697
Page 327.15FERCFORMNO.1 (ED.12-90)
Date of Report Year/Period of Report
(Mo,Da,Yr)
04/14/2020
Name of Respondent This Report is:
(1)X An Original
(2)_A ResubmissionIdahoPowerCompany 2019/Q4
FOOTNOTE DATA
Schedule Page:326.3 Line No.:5 Column:b
Delay-Daniag.es
Schedule Page:326.3 Line No.:6 Column:b
Delay Damages _ _
Schedule Page:326.3 Line No.:7 Column:b
Delay Damages
Schedule Page:326.4 Line No.:1 Column:b
Ida West,a subsidiary of IdaCorp (Idaho Power Company's parent company),has partial
ownership of these projects .
Schedule Page:326.5 Line No.:8 Column:b
Ida West,a subsidiary of IdaCorp (Idaho Power Company's parent company),has partial
ownership of these projects.
Schedule Page:326.8 Line No.:7 Column:b
Ida West,a subsidiary of IdaCorp (Idaho Power Company's parent company),has partial
ownership of these projects.
Schedule Page:326.8 Line No.:9 Column:b
Non Firm Purchases
Schedule Page:326.8 Line No.:10 Column:b
Non Firm Purchases
Schedule Page:326.9 Line No.:7 Column:b
Ida West,a subsidiary of IdaCorp (Idaho Power Company's parent company),has partial
ownership of these projects .
Schedule Page:326.10 Line No.:1 Column:b
Difference between booked and scheduled energy
Schedule Page:326.10 Line No.:4 Column:b
ADM Investor Services,Inc Futures Account Document,dated May 5,2015
Schedule Page:326.10 Line No.:6 Column:b
Spinning or Operating Reserves
Schedule Page:326.10 Line No.:8 Column:b
Spinning or Operating Reserves _
Schedule Page:326.10 Line No.:9 Column:b
Financial Transmission Losses
Schedule Page:326.10 Line No.:12 Column:b
Spinning or (QpSiratinig--Reserves
Schedule Page:326.10 Line No.:13 Column:b
Financial Transmission Losses
Schedule Page:326.11 Line No.:3 Column:b
Spinning or Operating Reserves
Schedule Page:326.11 Line No.:5 Column:b
ISDA Master Agreement With Citigroup,dated March 7,2011
Schedule Page:326.11 Line No.:10 Column:b
Spinning or Operating Reserves
Schedule Page:326.11 Line No.:12 Column:b
Non Firm Purchases
Schedule Page:326.12 Line No.:2 Column:b
Spinning or Operating Reserves
Schedule Page:326.12 Line No.:3 Column:b
Spinningor Operating Reserves
Schedule Page:326.12 Line No.:8 Column:b
Spinning or Operating Reserves
Schedule Page:326.12 Line No.:10 Column:b
Spinning or Operating Reserves
Schedule Page:326.12 Line No.:11 Column:b
Financial Transmission Losses
!
J
FERC FORM NO.1 (ED.12-87)Page 450.1
Date of Report Year/Period of ReportNameofRespondentThisReportis:
(Mo,Da,Yr)(1)X An Original
(2)_A Resubmission 2019/Q404/14/2020IdahoPowerCompany
FOOTNOTE DATA
Schedule Page:326.12 Line No.:12 Column:b
Schedule 88 Oregon Solar
Schedule Page:326.12 Line No.:13 Column:b
Spinning or Operating Reserves
Schedule Page:326.13 Line No.:1 Column:b
Financial Transmission Losses
Schedule Page:326.13 Line No.:2 Column:b
Spinning or Ope ru I :ng Reserves
Schedule Page:326.13 Line No.:6 Column:b
Spinning or Operating;'Reserves
Schedule Page:326.13 LineNo.:11_Column:b
Spinning or Operating Reserves
1
Schedule Page:326.13 Line No.:14 Column:b
Sp i nning or Operating Reserve s
Schedule Page:326.14 Line No.:2 Column:b
Spinning or Operating Reserves
Schedule Page:326.14 Line No.:9 Column:b
Spinning o r Ope r ating-Reserves:
_l
Schedule Page:326.14 Line No.:10 Column:b J
Physical Transmission Losses
Schedule Page:326.14 Line No.:11 Column:b
Physical Transmission Losses
\Schedule Page:326.14 Line No.:12 Column:b
Physical Transmission Losses
Schedule Page:326.14_Line No.:13 Column:b
Energy exchange between Clatskanie PUD and Idaho Power Company at Arrowrock Dam
Schedule Page:326.14 Line No.:14 Column:b
Energy exchange between Clatskanie PUD and Idaho Power Company at Arrowrock Dam
Schedule Page:326.15 Line No.:1 Column:b
Incentive program for customers to reduce demand during peak hours
FERC FORM NO.1 (ED.12-87)Page 450.2
This Report Is:
(1)[xj An Original
A Resubmission
TRANSMISSION "5F 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.
Year/Period of Report
End of 2019/Q4
Name of Respondent
Idaho Power Company
Date of Report
(Mo.Da,Yr)
04/14/2020(2)
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.
(c)(d)(a)(b)
FNOBonnevillePowerAdministration-OTEC Oregon Trails Electric Co-op1BonnevillePowerAdministration
FNO2BonnevillePowerAdministration-USSR United States Bureau of ReclamatiBonnevillePowerAdministration
FNOPriorityFirmCustomers3BonnevillePowerAdministration-PF Bonneville Power Administration
OLFUnitedStatesBureauofReclamatiMilnerIrrigationDistrict4MflnerIrrigationDistrict
OSBonnevillePowerAdministration5MorganStanleyCapitalGroupInc.Seattle City Light
FNO6PaclfiCorpPacifiCorpWestPacifiCorpWest
OSUnitedStatesBureauofIndianAf7UnitedStatesBureauofIndianAffairsBonnevillePowerAdministration
OS8CycleHorseshoeBendWind.LLC PacifiCorp East PacifiCorp East
OSPacifiCorpEastPacifiCorpEast9CycleHorseshoeBendWind,LLC
10
LFP11PacifiCorpInc.PacifiCorp East Bonneville Power Administration
LFP12PacifiCorpInc.PacifiCorp East PacifiCorp West
LFP13PacifiCorpInc.PacifiCorp East PacifiCorp West
LFP14MorganStanleyCapitalGroupInc.Idaho Power Company Bonneville Power Administration
LFPPacifiCorpWestPacifiCorpEast15BonnevillePowerAdministration
LFPPacifiCorpWestPacifiCorpEast16BonnevillePowerAdministration
17
NF18AmericanFallsSolar
NF19AvangridRenewables,LLC PacifiCorp East Bonneville Power Administration
NF20AvangridRenewables,LLC NorthWestern/PacifiCorp East Sierra Pacific Power
NFBonnevillePowerAdministration21AvangridRenewables,LLC PacifiCorp East
NFSierraPacificPower22AvangridRenewables,LLC PacifiCorp East
NF23AvangridRenewables,LLC Idaho Power Company Bonneville Power Administration
NFPacifiCorpEast24AvangridRenewables,LLC Bonneville Power Administration
NFSierraPacificPower25AvangridRenewables,LLC Bonneville Power Administration
NF26AvangridRenewables,LLC Avista Sierra Pacific Power
NFSierraPacificPowerBonnevillePowerAdministration27AvangridRenewables,LLC
NFPacifiCorpWestPacifiCorpEast28AvangridRenewables,LLC
NFSierraPacificPower29AvangridRenewables,LLC PacifiCorp West
NFPacifiCorpEast30AvistaCorporationAvista
NF31AvistaCorporationSierraPacificPowerAvista
NF32BellRapids/Thousand Springs
NFNorthWestern/PacifiCorp East PacifiCorp East33BlackHillsPower
NFPacifiCorpEast34BlackHillsPowerAvista
TOTAL
Page 328FERCFORMNO.1 (ED.12-90)
This Report Is:
(1)[X]An Original
(2)r~|A Resubmission
Date of Report
(Mo,Da,Yr)
04/14/2020
Year/Period of Report
End of 2019/Q4
Name of Respondent
Idaho Power Company
TROTSMS'STON OF ELECTRFClTYTnR'OTHER'S '{Account 456)(Cb"ntinuecf)
(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
Point of Receipt
(Subsatation or Other
Designation)
Point of Delivery
(Substation or Other
Designation)
Billing
Demand
TRANSFER OF ENERGY
MegaWatTRours
Delivered
Line
MegaWatt Hours
Received
No.(MW)Tariff Number
0)(e)(f)(g)(h)(i)
9 329,400 1329,400
181,845181,845 29
1,313,505 1,313,505 39
9,082 4LegacyMinidoka,Idaho Various in Idaho 9,082
4 363,903 363,903 5
2,063 2,063 69
LaGrande,Oregon 16,612 16,612 7LegacyVariousinIdaho
5/6 2,756 2,756 8BRDYIPCOEAST
13,086 13,086 95/6 JEFF IPCOEAST
10
1,134,195 11BORALAGRANDE1,134,1957/8
808,805 12808,8057/8 KPRT HURR
BORA 1,178,874 1,178,874 137/8 HURR
19,43419,434 147/8 LYPK LAGRANDE
68,115 68,115 157/8 M500 KPRT
251,216 251,216 167/8 SMLK KPRT
17
11 18
609 60S 197/8 BORA LAGRANDE
24 24 207/8 BPAT.NWMT M345
230 217/8 BRDY LAGFtANDE 230
187 187 227/8 BRDY M345
LAGRANDE 75 237/8 IPCOGEN 75
1,769 1,76S 247/8 LAGRANDE BORA
1,162 1,162 257/8 LAGRANDE M345
LOLO 423 423 267/8 M345
2,509 2,509 277/8 M345 LAGRANDE
566 566 287/8 SMLK BORA
270 297/8 SMLK 270M345
LOLO 275 275 307/8 BRDY
2,1732,173 317/8 LOLO M345
3211
337/8 BPAT.NWMT JBSN 71 71
40 40 347/8 LOLO JBSN
7,886,49307,886,493
Page 329FERCFORMNO.1 (ED.12-90)
Name of Respondent
Idaho Power Company
Year/Period of ReportThisReportIs:
(1)[x]An Original
(2)P]A Resubmission
Date of Report
(Mo.Da,Yr)
04/14/2020
TRAh'SMfeSJON'SrELFCTRICITY FOR OTHERS (Account 466.1)
(Including transactions referred to as 'wheeling')
2019/Q4Endof
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)
SFP1BonnevillePowerAdministrationPacifiCorpEastPacifiCorpWest
NF2BonnevillePowerAdministrationNorthWestern/PacifiCorp East Bonneville Power Administration
NF3BonnevillePowerAdministrationNorthWestern/PacifiCorp East Sierra Pacific Power
SFP4BonnevillePowerAdministrationNorthWestern/PacifiCorp East Sierra Pacific Power
NF5BonnevillePowerAdministrationPacifiCorpEastSierraPacificPower
NF6BonnevillePowerAdministrationBonnevillePowerAdministrationPacifiCorpEast
NF7BonnevillePowerAdministrationBonnevillePowerAdministrationPacifiCorpEast
NF8BonnevillePowerAdministrationBonnevillePowerAdministrationBonnevillePowerAdministration
NF9BonnevillePowerAdministrationBonnevillePowerAdministrationSierraPacificPower
NF10BonnevillePowerAdministrationAvistaPacifiCorpEast
11 NFBonnevillePowerAdministrationAvistaPacifiCorpEast
NF12BonnevillePowerAdministrationAvistaBonnevillePowerAdministration
NF13BonnevillePowerAdministrationAvistaSierraPacificPower
NF14BonnevillePowerAdministrationPacifiCorpWestSierraPacificPower
SFP15BonnevillePowerAdministrationPacifiCorpWestPacifiCorpEast
NF16BonnevillePowerAdministrationPacifiCorpWestSierraPacificPower
SFP17BonnevillePowerAdministrationPacifiCorpWestSierraPacificPower
NF18BrookfieldEnergyMarketingLPPacifiCorpWestPacifiCorpEast
NF19BrookfieldEnergyMarketingLPPacifiCorpEastPacifiCorpWest
SFP20BrookfieldEnergyMarketingLPPacifiCorpEastPacifiCorpWest
NF21EDFTradingNorthAmerica,LLC NorthWestern/PacifiCorp East Bonneville Power Administration
NF22EDFTradingNorthAmerica,LLC PacifiCorp East Bonneville Power Administration
NF23EDFTradingNorthAmerica,LLC PacifiCorp East Bonneville Power Administration
NF24EDFTradingNorthAmerica,LLC Bonneville Power Administration PacifiCorp East
NF25EDFTradingNorthAmerica,LLC Bonneville Power Administration Sierra Pacific Power
NF26EnergyKeepers,Inc.NorthWestern/PacifiCorp East Bonneville Power Administration
NF27EnergyKeepers,Inc.PacifiCorp East Sierra Pacific Power
SFP28EnergyKeepers,Inc.PacifiCorp East Sierra Pacific Power
NF29EnergyKeepers,Inc.Avista Sierra Pacific Power
NF30GuzmanEnergyGroup
NF31HuntingtonWind
NF32IdahoSolarI
NF33LimeWind
NF34MacquarieEnergy,LLC PacifiCorp East Bonneville Power Administration
TOTAL
Page 328.1FERCFORMNO.1 (ED.12-90)
Name of Respondent
Idaho Power Company
This Report Is:
fx]An Original
Date of Report
(Mo.Da,Yr)
I 1 A Resubmission 04/14/2020
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.
Year/Period of Report
(1)2019/Q4Endof(2)
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)0)
7/8 BORA H500 7,051 7,051 1
7/8 BPAT.NWMT BPASID 280 280 2
7/8 BPAT.NWMT M345 375 375 3
7/8 BPAT.NWMT M345 12,519 12,519 4
7/8 BRDY M345 274 274 5
7/8 LAGRANDE BORA 746 746 6
7/8 LAGRANDE KPRT 4,449 4,449 7
7/8 LAGRANDE LAGRANDE 14,368 14,368 8
7/8 LAGRANDE M345 5,547 5,547 9
7/8 LOLO BORA 67 67 10
7/8 LOLO KPRT 82 82 11
7/8 LOLO LAGRANDE 2,340 2,340 12
7/8 LOLO M345 5,280 5,280 13
7/8 M500 M345 4 4 14
7/8 SMLK BORA 10,626 10,626 15
7/8 SMLK M345 232 232 16
7/8 SMLK M345 86,709 86,709 17
7/8 H500 BORA 2,800 2,800 18
7/8 BORA H500 6,000 6,000 19
7/8 BORA H500 34,811 34,811 20
7/8 BPAT.NWMT LAGRANDE 87 87 21
7/8 BRDY LAGRANDE 879 879 22
7/8 JEFF LAGRANDE 489 489 23
7/8 LAGRANDE BRDY 142 142 24
7/8 LAGRANDE M345 240 240 25
7/8 BPAT.NWMT LAGRANDE 10 10 26
7/8 BRDY M345 922 922 27
7/8 BRDY M345 1,557 1,557 28
7/8 LOLO M345 496 496 29
7/8 30
11 31
11 32
11 33
7/8 BRDY LAGRANDE 5 345
0 7,886,493 7,886,493
Page 329.1FERCFORMNO.1 (ED.12-90)
This Report Is:
(1)[XJAn Original
(2)H A Resubmission
TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456.1)
(Inducting transactions referred to as 'wheeling')
Name of Respondent
Idaho Power Company
Date of Report
(Mo,Da,Yr)
04/14/2020
Year/Period of Report
2019/Q4Endof
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)
NF1MacquarieEnergy,LLC Sierra Pacific PowerPacifiCorpEast
NF2MacquarieEnergy,LLC PacifiCorp East NorthWestern/PacifiCorp East
NF3MacquarieEnergy,LLC PacifiCorp East Bonneville Power Administration
NF4MacquarieEnergy,LLC PacifiCorp East Sierra Pacific Power
NF5MacquarieEnergy,LLC PacifiCorp East PacifiCorp East
NF6MacquarieEnergy,LLC PacifiCorp East Bonneville Power Administration
NF7MacquarieEnergy,LLC PacifiCorp East Sierra Pacific Power
NF8MacquarieEnergy,LLC Bonneville Power Administration Sierra Pacific Power
NF9MacquarieEnergy,LLC Avista Sierra Pacific Power
NF10MacquarieEnergy,LLC Sierra Pacific Power PacifiCorp East
NF1 1 Mag Energy Solutions Idaho Power Company PacifiCorp East
NF12MagEnergySolutionsSierraPacificPowerPacifiCorpEast
NF13MagEnergySolutionsPacifiCorpEastSierraPacificPower
NF14MagEnergySolutionsSierraPacificPowerPacifiCorpEast
NF15MountainFlomeSolar
NF16MorganStanleyCapitalGroupInc.NorthWestern/PacifiCorp East PacifiCorp East
SFP17MorganStanleyCapitalGroupInc.NorthWestern/PacifiCorp East PacifiCorp East
NF18MorganStanleyCapitalGroupInc.NorthWestern/PacifiCorp East Bonneville Power Administration
SFP19MorganStanleyCapitalGroupInc.NorthWestern/PacifiCorp East Sierra Pacific Power
SFP20MorganStanleyCapitalGroupInc.Idaho Power Company PacifiCorp East
NF21MorganStanleyCapitalGroupInc.PacifiCorp East NorthWestern/PacifiCorp East
NF22MorganStanleyCapitalGroupInc.PacifiCorp East PacifiCorp East
SFP23MorganStanleyCapitalGroupInc.PacifiCorp East PacifiCorp East
NF24MorganStanleyCapitalGroupInc.PacifiCorp East Bonneville Power Administration
SFP25MorganStanleyCapitalGroupInc.PacifiCorp East Bonneville Power Administration
NF26MorganStanleyCapitalGroupInc.PacifiCorp East Avista
NF27MorganStanleyCapitalGroupInc.PacifiCorp East Sierra Pacific Power
NF28MorganStanleyCapitalGroupInc.NorthWestern/PacifiCorp East PacifiCorp East
SFP29MorganStanleyCapitalGroupInc.NorthWestern/PacifiCorp East PacifiCorp East
NF30MorganStanleyCapitalGroupInc.NorthWestern/PacifiCorp East Bonneville Power Administration
SFP31MorganStanleyCapitalGroupInc.NorthWestern/PacifiCorp East Bonneville Power Administration
NF32MorganStanleyCapitalGroupInc.NorthWestern/PacifiCorp East Sierra Pacific Power
SFP33MorganStanleyCapitalGroupInc.NorthWestern/PacifiCorp East Sierra Pacific Power
NF34MorganStanleyCapitalGroupInc.PacifiCorp East NorthWestern/PacifiCorp East
TOTAL
Page 328.2FERCFORMNO.1 (ED.12-90)
This Report is:
(1)[XTAn Original
(2)QA Resubmission
TRANSMISSION OF ELtTCTRltlTY FOR OTHERS (Account 456)(Continued)
(Including transactions reffered to as 'wheeling')
Name of Respondent
Idaho Power Company
Date of Report
(Mo.Da,Yr)
04/14/2020
Year/Period of Report
End of 2019/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 Line
MegaWatt Hours
Received
MegaWatt Hours
Delivered
No.(MW)
(e)(f)(9)(h)(i)(j)
7/8 BRDY M345 193193 1
7/8 JBSN BPAT.NWMT 693 693 2
7/8 JBSN LAGRANDE 462 462 3
7/8 JBSN M345 434 434 4
7/8 JEFF BORA 75 75 5
7/8 JEFF LAGRANDE 15 15 6
7/8 JEFF M345 541 541 7
7/8 LAGRANDE M345 145 145 8
7/8 LOLO M345 100 100 9
7/8 M345 BORA 48 48 10
7/8 BGSY JEFF 606 606 11
7/8 BRDY M345 15,916 15,916 12
7/8 JEFF M345 2,061 2,061 13
7/8 M345 GSHN 606 606 14
11 15
7/8 AVAT.NWMT BORA 22 22 16
7/8 AVAT.NWMT BORA 5,385 5,385 17
7/8 AVAT.NWMT LAGRANDE 1,013 1,013 18
7/8 AVAT.NWMT M345 16,861 16,861 19
7/8 BGSY JEFF 1,163 1,163 20
7/8 BORA BPAT.NWMT 1,171 1,171 21
7/8 BORA BRDY 846 846 22
7/8 BORA BRDY 12,709 12,709 23
7/8 BORA LAGRANDE 5,275 5,275 24
7/8 BORA LAGRANDE 25,319 25,319 25
7/8 BORA LOLO 50 50 26
7/8 BORA M345 106 106 27
7/8 BPAT.NWMT BORA 929 929 28
7/8 BPAT.NWMT BRDY 3,600 3,600 29
7/8 BPAT.NWMT LAGRANDE 2,188 2,188 30
7/8 BPAT.NWMT LAGRANDE 512 512 31
7/8 BPAT.NWMT M345 12,909 12,909 32
7/8 BPAT.NWMT M345 123,337 123,337 33
7/8 BRDY AVAT.NWMT 164 164 34
0 7,886,493 7,886,493
Page 329.2FERCFORMNO.1 (ED.12-90)
This Report Is:
(1)fx]An Original
(2)I I A Resubmission
TRANSMISSION OF ELECTRICITY FOR OTHEks (Account 456.1)
(Including transactions referred to as 'wheeling')
Name of Respondent
Idaho Power Company
Date of Report
(Mo,Da,Yr)
04/14/2020
Year/Period of Report
2019/Q4Endof
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)
NF1MorganStanleyCapitalGroupInc.PacifiCorp East PacifiCorp East
SFP2MorganStanleyCapitalGroupInc.PacifiCorp East PacifiCorp East
NF3MorganStanleyCapitalGroupInc.PacifiCorp East NorthWestern/PacifiCorp East
SFP4MorganStanleyCapitalGroupInc.PacifiCorp East NorthWestern/PacifiCorp East
SFP5MorganStanleyCapitalGroupInc.PacifiCorp East PacifiCorp East
NF6MorganStanleyCapitalGroupInc.PacifiCorp East Bonneville Power Administration
SFP7MorganStanleyCapitalGroupInc.PacifiCorp East Bonneville Power Administration
NF8MorganStanleyCapitalGroupInc.PacifiCorp East Avista
NF9MorganStanleyCapitalGroupInc.PacifiCorp East Sierra Pacific Power
SFP10MorganStanleyCapitalGroupInc.PacifiCorp East Sierra Pacific Power
NF11MorganStanleyCapitalGroupInc.PacifiCorp West Sierra Pacific Power
NF12MorganStanleyCapitalGroupInc.Idaho Power Company Bonneville Power Administration
NF13MorganStanleyCapitalGroupInc.PacifiCorp East PacifiCorp East
NF14MorganStanleyCapitalGroupInc.PacifiCorp East Bonneville Power Administration
NF15MorganStanleyCapitalGroupInc.PacifiCorp East Sierra Pacific Power
NF16MorganStanleyCapitalGroupInc.PacifiCorp East PacifiCorp East
SFP17MorganStanleyCapitalGroupInc.PacifiCorp East PacifiCorp East
NF18MorganStanleyCapitalGroupInc.PacifiCorp East Bonneville Power Administration
NF19MorganStanleyCapitalGroupInc.PacifiCorp East Avista
NF20MorganStanleyCapitalGroupInc.PacifiCorp East Sierra Pacific Power
SFP21MorganStanleyCapitalGroupInc.PacifiCorp East Sierra Pacific Power
NF22MorganStanleyCapitalGroupInc.Bonneville Power Administration PacifiCorp East
NF23MorganStanleyCapitalGroupInc.Bonneville Power Administration PacifiCorp East
NF24MorganStanleyCapitalGroupInc.Bonneville Power Administration PacifiCorp East
NF25MorganStanleyCapitalGroupInc.Sierra Pacific PowerBonnevillePowerAdministration
SFP26MorganStanleyCapitalGroupInc.Bonneville Power Administration Sierra Pacific Power
NF27MorganStanleyCapitalGroupInc.Avista PacifiCorp East
SFP28MorganStanleyCapitalGroupInc.PacifiCorp EastAvista
NF29MorganStanleyCapitalGroupInc.PacifiCorp EastAvista
NF30MorganStanleyCapitalGroupInc.Avista Bonneville Power Administration
SFP31MorganStanleyCapitalGroupInc.Avista Bonneville Power Administration
NF32MorganStanleyCapitalGroupInc.Avista Sierra Pacific Power
SFP33MorganStanleyCapitalGroupInc.Sierra Pacific PowerAvista
NF34MorganStanleyCapitalGroupInc.Idaho Power Company PacifiCorp East
TOTAL
Page 328.3FERCFORMNO.1 (ED.12-90)
This Report Is:
(1)fxlAn Original
(2)ri A Resubmission
Name of Respondent
Idaho Power Company
Date of Report
(Mo,Da,Yr)
04/14/2020
Year/Period of Report
End of 2019/Q4
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.
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 BRDY BORA 402 402 1
7/8 BRDY BORA 10,487 10,487 2
7/8 BRDY BPAT.NWMT 170 170 3
7/8 BRDY BPAT.NWMT 1,008 1,008 4
7/8 BRDY GSHN 1,163 1,163 5
7/8 BRDY LAGRANDE 9,437 9,437 6
7/8 BRDY LAGRANDE 1,200 1,200 7
7/8 BRDY LOLO 491 491 8
7/8 BRDY M345 14,927 14,927 9
7/8 BRDY M345 130,303 130,303 10
7/8 H500 M345 169 169 11
7/8 IPCOGEN LAGRANDE 100 100 12
7/8 JBSN BOF5A 351 351 13
7/8 JBSN LAGRANDE 845 845 14
7/8 JBSN M345 11 11 15
7/8 JEFF BORA 12,704 12,704 16
7/8 JEFF BORA 1,555 1,555 17
7/8 JEFF LAGRANDE 1,118 1,118 18
7/8 JEFF LOLO 412 412 19
7/8 JEFF M345 52,03652,036 20
7/8 JEFF M345 7,484 7,484 21
7/8 LAGRANDE BORA 3,195 3,195 22
7/8 LAGRANDE BRDY 1,424 1,424 23
7/8 LAGRANDE JBSN 140 140 24
7/8 LAGRANDE M345 59,254 59,254 25
7/8 LAGRANDE M345 965 965 26
7/8 LOLO BORA 10,269 10,269 27
7/8 LOLO BORA 10,661 10,661 28
7/8 LOLO 576BRDY 576 29
7/8 LOLO LAGRANDE 2,416 2,416 30
7/8 LOLO LAGRANDE 21,957 21,957 31
7/8 LOLO M345 75,192 75,192 32
7/8 LOLO M345 37,168 37,168 33
7/8 LYPK BORA 876 876 34
0 7,886,493 7,886,493
Page 329.3FERCFORMNO.1 (ED.12-90)
This Report Is:
(1)[X]An Original
(2)I ]A Resubmission
TRANSMISSION OF ELECTRICITY FOR OTHEks (Account 456.1 )
(Including transactions referred to as 'wheeling')
Date of Report
(Mo,Da,Yr)
04/14/2020
Name of Respondent
Idaho Power Company
Year/Period of Report
End of 2019/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.
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)
SFP1MorganStanleyCapitalGroupInc.Idaho Power Company PacifiCorp East
NF2MorganStanleyCapitalGroupInc.NorthWestern/PacifiCorp EastIdahoPowerCompany
NF3MorganStanleyCapitalGroupInc.Idaho Power Company PacifiCorp East
SFP4MorganStanleyCapitalGroupInc.Idaho Power Company PacifiCorp East
SFP5MorganStanleyCapitalGroupInc.Idaho Power Company PacifiCorp East
NF6MorganStanleyCapitalGroupInc.Idaho Power Company Avista
NF7MorganStanleyCapitalGroupInc.Idaho Power Company Sierra Pacific Power
SFP8MorganStanleyCapitalGroupInc.Idaho Power Company Sierra Pacific Power
NF9MorganStanleyCapitalGroupInc.Sierra Pacific Power NorthWestern/PacifiCorp East
NF10MorganStanleyCapitalGroupInc.Sierra Pacific Power NorthWestern/PacifiCorp East
NF11MorganStanleyCapitalGroupInc.Sierra Pacific Power PacifiCorp East
NF12MorganStanleyCapitalGroupInc.Sierra Pacific Power Bonneville Power Administration
NF13MorganStanleyCapitalGroupInc.Sierra Pacific Power Avista
NF14MorganStanleyCapitalGroupInc.PacifiCorp West PacifiCorp East
SFP15MorganStanleyCapitalGroupInc.PacifiCorp West PacifiCorp East
NF16MorganStanleyCapitalGroupInc.PacifiCorp West Sierra Pacific Power
SFP17MorganStanleyCapitalGroupInc.PacifiCorp West Sierra Pacific Power
NF18MorganStanleyCapitalGroupInc.Idaho Power Company PacifiCorp East
NF19MorganStanleyCapitalGroupInc.Idaho Power Company Sierra Pacific Power
NF20MurphyFlatSolar
NF21NorthwesternEnergyPacifiCorpEastBonnevillePowerAdministration
NFPacifiCorpEast22NorthwesternEnergyBonnevillePowerAdministration
NF23NevadaPowerCompanyPacifiCorpEastBonnevillePowerAdministration
NF24NevadaPowerCompanyPacifiCorpEastSierraPacificPower
NF25NevadaPowerCompanySierraPacificPowerBonnevillePowerAdministration
NF26OrchardRanchSolar
SFP27PacifiCorpInc.PacifiCorp East Avista
NF28PacifiCorpInc.PacifiCorp East PacifiCorp East
SFP29PacifiCorpInc.PacifiCorp East PacifiCorp East
NF30PacifiCorpInc.PacifiCorp East PacifiCorp East
NF31PacifiCorpInc.PacifiCorp East PacifiCorp West
NFPacifiCorpEast32PacifiCorpInc.Bonneville Power Administration
NFPacifiCorpEast33PacifiCorpInc.Avista
NF34PacifiCorpInc.PacifiCorp West PacifiCorp East
TOTAL
Page 328.4FERCFORMNO.1 (ED.12-90)
Name of Respondent
Idaho Power Company
Date of Report
(Mo,Da,Yr)
(2)f IA Resubmission 04/14/2020
TRSNSMISSIOfiTJFEL&CTftlCITY FOR OTHERS (Account 456)(Continued)
(Including transactions reffered to as 'wheeling')
This Report is:
(X]An Original
Year/Period of Report
End of 2019/Q4(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 TRANSFER OF ENERGY
MegaWatt Hours
Delivered
LineDemandMegaWattHours
Received
No.(MW)
(e)(f)(g)(h)(i)0)
7/8 LYPK BORA 25,827 25,827 1
7/8 LYPK BPAT.NWMT 256 256 2
7/8 LYPK BRDY 573 573 3
7/8 LYPK BRDY 240 240 4
7/8 LYPK JBSN 56 56 5
7/8 LYPK LOLO 2 2 6
7/8 LYPK M345 1,475 1,475 7
7/8 LYPK M345 314,810 314,810 8
7/8 M345 AVAT.NWMT 200200 g
7/8 M345 BPAT.NWMT 630 630 10
7/8 M345 BRDY 2,3502,350 11
7/8 M345 LAGRANDE 4,538 4,538 12
7/8 M345 LOLO 137777
7/8 SMLK BORA 2,235 2,235 14
7/8 SMLK BOFtA 4,781 4,781 15
7/8 SMLK M345 4,513 4,513 16
7/8 SMLK M345 600 600 17
7/8 WALLAWALLA BORA 293 293 18
7/8 WALLAWALLA M345 198 198 19
11 20
7/8 LAGRANDEBRDY 380 380 21
7/8 JEFF LAGRANDE 150 150 22
7/8 BORA LAGRANDE 45 45 23
7/8 BORA M345 550 550 24
7/8 M345 LAGRANDE 40 40 25
11 26
7/8 BORA LOLO 374,286 374,286 27
7/8 BORABRDY 5,722 5,722 28
7/8 BRDY BORA 255 255 29
7/8 BRDY BRDY 2,045 2,045 30
7/8 BRDY HURR 584 584 31
7/8 BRDY LAGFtANDE 2,799 2,799 32
7/8 LOLOBRDY 1,501 1,501 33
7/8 BOFtAHURR 3,749 3,749 34
0 7,886,493 7,886,493
Page 329.4FERCFORMNO.1 (ED.12-90)
This Report is:Date of Report
mAn Original (Mo,Da,Yr)
[A Resubmission 04/14/2020
TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456.1)
(Including transactions referred to as 'wheeling')
Name of Respondent
Idaho Power Company
Year/Period of Report
(1)2019/Q4Endof
(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)
NF1PacifiCorpInc.PacifiCorp East Idaho Power Company
2 PacifiCorp Inc.NFBonnevillePowerAdministrationPacifiCorpEast
3 PacifiCorp Inc.NFAvistaPacifiCorpEast
4 PacifiCorp Inc.NFAvistaPacifiCorpEast
5 PacifiCorp Inc.NFAvistaPacifiCorpWest
6 PacifiCorp Inc.NFPacifiCorpWestPacifiCorpEast
7 PacifiCorp Inc.NFPacifiCorpWestPacifiCorpEast
8 PacifiCorp Inc.NFIdahoPowerCompanyPacifiCorpEast
9 PacifiCorp Inc.NFIdahoPowerCompanyPacifiCorpEast
10 Portland General Electric SFPPacifiCorpEastBonnevillePowerAdministration
11 Portland General Electric SFPPacifiCorpEastBonnevillePowerAdministration
1 2 Powerex Corporation SFPPacifiCorpEastNorthWestern/PacifiCorp East
1 3 Powerex Corporation NFPacifiCorpEastBonnevillePowerAdministration
14 Powerex Corporation NFPacifiCorpEastAvista
1 5 Powerex Corporation NorthWestern/PacifiCorp East NFPacifiCorpEast
1 6 Powerex Corporation NorthWestern/PacifiCorp East NFSierraPacificPower
1 7 Powerex Corporation PacifiCorp East NFNorthWestern/PacifiCorp East
1 8 Powerex Corporation NFPacifiCorpEastPacifiCorpEast
19 Powerex Corporation NFPacifiCorpEastNorthWestern/PacifiCorp East
20 Powerex Corporation PacifiCorp East NFBonnevillePowerAdministration
21 Powerex Corporation SFPPacifiCorpEastBonnevillePowerAdministration
22 Powerex Corporation NFPacifiCorpEastAvista
23 Powerex Corporation NFPacifiCorpEastSierraPacificPower
24 Powerex Corporation PacifiCorp East NFBonnevillePowerAdministration
25 Powerex Corporation PacifiCorp West NFPacifiCorpEast
26 Powerex Corporation NFPacifiCorpEastNorthWestern/PacifiCorp East
27 Powerex Corporation NFPacifiCorpEastPacifiCorpWest
28 Powerex Corporation PacifiCorp East NFBonnevillePowerAdministration
29 Powerex Corporation PacifiCorp East NFPacifiCorpEast
30 Powerex Corporation NFPacifiCorpEastBonnevillePowerAdministration
31 Powerex Corporation NFBonnevillePowerAdministrationPacifiCorpEast
32 Powerex Corporation Bonneville Power Administration NFPacifiCorpEast
33 Powerex Corporation Bonneville Power Administration NFSierraPacificPower
34 Powerex Corporation NFAvistaPacifiCorpEast
TOTAL
Page 328.5FERCFORMNO.1 (ED.12-90)
Name of Respondent
Idaho Power Company
This Report Is:
(1)fx An Original
(2)I (A Resubmission
Date of Report
(Mo,Da,Yr)
04/14/2020
rRSNSMISSIOIvl OF'ElTCTRiCITY FOR OTHERS (Account 456)(Continued)
(Including transactions reffered to as 'wheeling')
Year/Period of Report
End of 2019/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 TRANSFER OF ENERGY
Megawatt Hours
Delivered
LineDemandMegaWattHours
Received
No.(MW)
(e)(f)(9)(h)(i)G)
7/8 JEFF BGSY 2,073 2,073 1
7/8 LAGRANDE BORA 244 244 2
7/8 LOLO BORA 1,072 1,072 3
7/8 LOLO BRDY 2,450 2,450 4
7/8 LOLO HURR 183 183 5
7/8 SMLK BORA 7,780 7,780 6
7/8 SMLK BRDY 2,231 2,231
7/8 WALLAWALLA BORA 182 182 8
7/8 WALLAWALLA BRDY 50 50 9
7/8 BORA LAGRANDE 13,581 13,581 10
7/8 BRDY LAGRANDE 2,396 2,396 11
7/8 BORA BPAT.NWMT 431 431 12
7/8 BORA LAGRANDE 2,577 2,577 13
7/8 BORA LOLO 80 80 14
7/8 BPAT.NWMT BORA 95 95 15
7/8 BPAT.NWMT M345 109 16109
7/8 BRDY AVAT.NWMT 17
7/8 BRDY BORA 257 257 18
7/8 BRDY BPAT.NWMT 21 21 19
7/8 BRDY LAGRANDE 15,064 15,064 20
7/8 BRDY LAGRANDE 4,282 4,282 21
7/8 BRDY LOLO 570 570 22
7/8 BRDY M345 286 286 23
7/8 GSHN LAGRANDE 164 164 24
7/8 HURR BORA 464 464 25
7/8 JBSN BPAT.NWMT 64 64 26
7/8 JBSN HURR 50 50 27
7/8 JBSN LAGRANDE 3,781 3,781 28
7/8 JEFF BORA 422 422 29
7/8 JEFF LAGRANDE 12 12 30
7/8 LAGRANDE BORA 1,215 1,215 31
7/8 LAGRANDE BRDY 1,876 1,876 32
7/8 LAGRANDE M345 2,833 2,833 33
7/8 LOLO 186 34BORA186
0 7,886,493 7,886,493
Page 329.5FERCFORMNO.1 (ED.12-90)
This Report Is:Date of Report
(1)(XjAn Original (Mo,Da,Yr)
(2)[)A Resubmission 04/14/2020
TRANSMISSION OF ELECTRICITY FORT5THERS (Account 456.1)
(Including transactions referred to as 'wheeling')
Year/Period of Report
End of 2019/Q4
Name of Respondent
Idaho Power Company
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)
1 Powerex Corporation NFAvistaBonnevillePowerAdministration
2 Powerex Corporation NFAvistaSierraPacificPower
3 Powerex Corporation Sierra Pacific Power NFPacifiCorpEast
4 Powerex Corporation NFSierraPacificPowerNorthWestern/PacifiCorp East
5 Powerex Corporation NFSierraPacificPowerPacifiCorpWest
6 Powerex Corporation NFSierraPacificPowerBonnevillePowerAdministration
7 Powerex Corporation NFSierraPacificPowerAvista
8 Powerex Corporation NFPacifiCorpWestPacifiCorpWest
9 Powerex Corporation SFPPacifiCorpWestPacifiCorpWest
1 0 Powerex Corporation NFPacifiCorpWestPacifiCorpEast
1 1 Powerex Corporation NFPacifiCorpWestPacifiCorpEast
1 2 Powerex Corporation NFPacifiCorpWestSierraPacificPower
1 3 Powerex Corporation NFIdahoPowerCompanyPacifiCorpEast
14 Powerex Corporation NFIdahoPowerCompanyPacifiCorpEast
1 5 Powerex Corporation NFIdahoPowerCompanySierraPacificPower
SFP16RainbowEnergyMarketingCorp.Idaho Power Company PacifiCorp East
17 Rainbow Energy Marketing Corp.SFPPacifiCorpEastPacifiCorpEast
18 Rainbow Energy Marketing Corp.NFPacifiCorpEastBonnevillePowerAdministration
19 Rainbow Energy Marketing Corp.SFPPacifiCorpEastAvista
20 Rockland Wind NF
Sawtooth Wind21 NF
22 Shell Energy North America (US),L.P.NFPacifiCorpEastBonnevillePowerAdministration
23 Shell Energy North America (US),L.P,NFPacifiCorpEastSierraPacificPower
24 Shell Energy North America (US),L.P.SFPPacifiCorpEastPacifiCorpWest
25 Shell Energy North America (US),L.P.NFNorthWestern/PacifiCorp East PacifiCorp East
26 Shell Energy North America (US),L.P,NFNorthWestern/PacifiCorp East Sierra Pacific Power
27 Shell Energy North America (US),L.P,SFPNorthWestern/PacifiCorp East Sierra Pacific Power
28 Shell Energy North America (US),L.P,NFPacifiCorpEastNorthWestern/PacifiCorp East
29 Shell Energy North America (US),L.P.SFPPacifiCorpEastNorthWestern/PacifiCorp East
30 Shell Energy North America (US),L.P.NFPacifiCorpEastBonnevillePowerAdministration
31 Shell Energy North America (US),L.P.SFPPacifiCorpEastBonnevillePowerAdministration
32 Shell Energy North America (US),L.P.PacifiCorp East NFAvista
33 Shell Energy North America (US),L.P.SFPPacifiCorpEastAvista
34 Shell Energy North America (US),L.P.NFPacifiCorpEastSierraPacificPower
TOTAL
Page 328.6FERCFORMNO.1 (ED.12-90)
This Report Is:
RqAn Original
Name of Respondent
Idaho Power Company
Date of Report
(Mo,Da,Yr)
(2)n A Resubmission 04/14/2020
TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456)(Continued)
(Including transactions raftered to as 'wheeling')
Year/Period of Report
End of 2019/Q4(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
MegaWatt Hours
Delivered
Line
MegaWatt Hours
Received
No.(MW)
(e)(f)(g)(h)(i)(j)
7/8 LOLO LAGRANDE 4,460 4,460 1
7/8 LOLO M345 300300 2
7/8 M345 BORA 4141 3
7/8 M345 BPAT.NWMT 560 560 4
7/8 M345 HURR 4 4 5
7/8 M345 LAGRANDE 1,719 1,719 6
7/8 M345 LOLO 19 19 7
7/8 POP HURR 287 287 8
7/8 POP HURR 332 332 9
7/8 SMLK BORA 4,870 4,870 10
7/8 SMLK BRDY 226 226 11
7/8 SMLK M345 600 600 12
7/8 WALLAWALLA BORA 45,282 45,282 13
7/8 WALLAWALLA BRDY 1,169 1,169 14
7/8 WALLAWALLA M345 2,121 2,121 15
7/8 BGSY JEFF 2,837 2,837 16
7/8 BRDY GSHN 1,845 1,845 17
7/8 BRDY LAGRANDE 400 400 18
7/8 BRDY LOLO 2,381 2,381 19
11 20
11 21
7/8 BORA LAGRANDE 8,659 8,659 22
7/8 BORA M345 305 305 23
7/8 BORA M500 44,232 44,232 24
7/8 BPAT.NWMT BRDY 25 25 25
7/8 BPAT.NWMT M345 1,992 1,992 26
7/8 BPAT.NWMT M345 280 280 27
7/8 BRDY AVAT.NWMT 788 788 28
7/8 BRDY BPAT.NWMT 878 878 29
7/8 BRDY LAGRANDE 10,427 10,427 30
7/8 BRDY LAGRANDE 2,851 2,851 31
7/8 BRDY LOLO 1,879 1,879 32
7/8 BRDY LOLO 37,624 37,624 33
7/8 BRDY M345 8,750 8,750 34
0 7,886,493 7,886,493
Page 329.6FERCFORMNO.1 (ED.12-90)
This Report is:
[X]An Original
Year/Period of ReportNameofRespondent
Idaho Power Company
Date of Report
(Mo.Da,Yr)
| |A Resubmission 04/14/2020
TRANSMISSION CF'ELECTRICITY FOR 'OTHERS (Account 456.1)
(Including transactions referred to as 'wheeling')
(1)2019/Q4Endof
(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)
SFP1ShellEnergyNorthAmerica(US),L.P,PacifiCorp East Sierra Pacific Power
2 Shell Energy North America (US),L.P.NFPacifiCorpEastPacifiCorpWest
3 Shell Energy North America (US),L.P.SFPPacifiCorpEastPacifiCorpWest
4 Shell Energy North America (US),L.P.NFPacifiCorpWestBonnevillePowerAdministration
5 Shell Energy North America (US),L.P.SFPIdahoPowerCompanyAvista
6 Shell Energy North America (US),L.P.NFIdahoPowerCompanyPacifiCorpWest
7 Shell Energy North America (US),L.P.SFPIdahoPowerCompanyPacifiCorpWest
8 Shell Energy North America (US),L.P,NFPacifiCorpEastPacifiCorpEast
9 Shell Energy North America (US),L.P.NFPacifiCorpEastBonnevillePowerAdministration
10 Shell Energy North America (US),L.P.PacifiCorp East NFAvista
1 1 Shell Energy North America (US),L.P.PacifiCorp East NFSierraPacificPower
12 Shell Energy North America (US),L.P.NFPacifiCorpEastPacifiCorpWest
13 Shell Energy North America (US),L.P.NFPacifiCorpEastSierraPacificPower
14 Shell Energy North America (US),L.P.NFBonnevillePowerAdministrationPacifiCorpEast
15 Shell Energy North America (US),L.P.NFBonnevillePowerAdministrationPacifiCorpEast
16 Shell Energy North America (US),L.P.Bonneville Power Administration NFPacifiCorpEast
17 Shell Energy North America (US),L.P.NFBonnevillePowerAdministrationSierraPacificPower
18 Shell Energy North America (US),L.P.SFPBonnevillePowerAdministrationSierraPacificPower
19 Shell Energy North America (US),L.P.NFAvistaPacifiCorpEast
20 Shell Energy North America (US),L.P.NFAvistaPacifiCorpEast
21 Shell Energy North America (US),L.P.SFPAvistaPacifiCorpEast
22 Shell Energy North America (US),L.P.NFAvistaSierraPacificPower
23 Shell Energy North America (US),L.P.SFPAvistaSierraPacificPower
24 Shell Energy North America (US),L.P.NFSierraPacificPowerBonnevillePowerAdministration
25 Shell Energy North America (US),L.P.Sierra Pacific Power NFAvista
26 Shell Energy North America (US),L.P.Sierra Pacific Power NFPacifiCorpWest
27 Shell Energy North America (US),L.P.NFPacifiCorpWestPacifiCorpEast
28 Shell Energy North America (US),L.P.NFPacifiCorpWestPacifiCorpEast
29 Shell Energy North America (US),L.P.PacifiCorp West NFSierraPacificPower
30 Shell Energy North America (US),L.P,NFIdahoPowerCompanyPacifiCorpEast
31 Shell Energy North America (US),L.P.NFIdahoPowerCompanyPacifiCorpEast
32 Shell Energy North America (US),L.P.NFIdahoPowerCompanySierraPacificPower
33 Simcoe Solar NF
34 TEC Energy,Inc.NF
TOTAL
Page 328.7FERCFORMNO.1 (ED.12-90)
Name of Respondent
Idaho Power Company
This Report Is:
(1)fx)An Original
A Resubmission
Date of Report
{Wo,Da,Yr)
04/14/2020
Year/Period of Report
End of 2019/Q4
TRANSMISSION OF ELECTRICITY FQRT3TRERSTAbcount456)(Continued)
(Including transactions reffered to as 'wheeling')
(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.
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)0)G)
7/8 BRDY M345 2,545 2,545 1
7/8 BRDY M500 2,467 2,467 2
7/8 BRDY M500 2,850 2,850 3
7/8 HURR LAGRANDE 15 15 4
7/8 IPCOGEN LOLO 1,598 1,598 5
7/8 IPCOGEN M500 1,212 1,212 6
7/8 IPCOGEN M500 550 550 7
7/8 JBSN BRDY 174 174 8
7/8 JBSN LAGRANDE 10,862 10,862 9
7/8 JBSN LOLO 49 49 10
7/8 JBSN M345 1,054 1,054 11
7/8 JBSN M500 1,437 1,437 12
7/8 JEFF M345 240 240 13
7/8 LAGRANDE BORA 2,850 2,850 14
7/8 LAGRANDE BRDY 1,271 1,271 15
7/8 LAGRANDE JBSN 1,980 1,980 16
7/8 LAGRANDE M345 24,735 24,735 17
7/8 LAGRANDE M345 642 642 18
7/8 LOLO BORA 2,085 2,085 19
7/8 LOLO BRDY 25 25 20
7/8 LOLO BRDY 613 613 21
7/8 LOLO M345 35,994 35,994 22
7/8 LOLO M345 4,351 4,351 23
7/8 M345 LAGRANDE 5,947 5,947 24
7/8 M345 LOLO 600 600 25
7/8 M345 M500 32 32 26
7/8 SMLK BORA 300 300 27
7/8 SMLK BRDY 248 248 28
7/8 SMLK M345 402402 29
7/8 WALLAWALLA BORA 17,352 17,352 30
7/8 WALLAWALLA BRDY 2,942 2,942 31
7/8 WALLAWALLA M345 14,915 14,915 32
11 33
7/8 34
0 7,886,493 7,886,493
Page 329.7FERCFORMNO.1 (ED.12-90)
This Report Is:Date of Report
X]An Original (Mo,Da,Yr)
I A Resubmission 04/14/2020
TRANSMISSION^ELECTRICITY FOR OTHERS (Account 4S6.1)
(Including transactions referred to as 'wheeling')
Year/Period of Report
End of 2019/Q4
Name of Respondent
Idaho Power Company (1)
(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)
1 Tenaska Power Services NFPacifiCorpEastSierraPacificPower
SFP2TenaskaPowerServicesPacifiCorpEastSierraPacificPower
NF3TenaskaPowerServicesBonnevillePowerAdministrationPacifiCorpEast
NF4TenaskaPowerServicesBonnevillePowerAdministrationSierraPacificPower
5 Tenaska Power Services NFAvistaSierraPacificPower
6 The Energy Authority,Inc.NFPacifiCorpEastBonnevillePowerAdministration
NF7TheEnergyAuthority,Inc.NorthWestern/PacifiCorp East PacifiCorp East
NF8TheEnergyAuthority,Inc.NorthWestern/PacifiCorp East Sierra Pacific Power
NF9TheEnergyAuthority,Inc.PacifiCorp East NorthWestern/PacifiCorp East
NF10TheEnergyAuthority,Inc.PacifiCorp East Bonneville Power Administration
NF11TheEnergyAuthority,Inc.PacifiCorp East Avista
12 The Energy Authority,Inc.NFPacifiCorpEastPacifiCorpWest
NF13TheEnergyAuthority,Inc.Bonneville Power Administration PacifiCorp East
NF14TheEnergyAuthority,Inc.Bonneville Power Administration PacifiCorp East
NF15TheEnergyAuthority,Inc.Bonneville Power Administration Sierra Pacific Power
NF16TheEnergyAuthority,Inc.Avista PacifiCorp East
17 The Energy Authority,Inc.NFAvistaPacifiCorpEast
18 The Energy Authority,Inc.NFSierraPacificPowerBonnevillePowerAdministration
NF19TheEnergyAuthority,Inc.Sierra Pacific Power Avista
NF20TheEnergyAuthority,Inc.PacifiCorp West PacifiCorp East
NF21TheEnergyAuthority,Inc.Idaho Power Company Sierra Pacific Power
22 Transalta Energy Marketing (U.S.)Inc.NFPacifiCorpEastBonnevillePowerAdministration
NF23TransaltaEnergyMarketing(U.S.)Inc.PacifiCorp East Sierra Pacific Power
NF24TransaltaEnergyMarketing(U.S.)Inc.PacifiCorp East PacifiCorp West
NF25TransaltaEnergyMarketing(U.S.)Inc.NorthWestern/PacifiCorp East Bonneville Power Administration
26 Transalta Energy Marketing (U.S.)Inc.NFNorthWestern/PacifiCorp East Sierra Pacific Power
NF27TransaltaEnergyMarketing(U.S.)Inc.PacifiCorp East Bonneville Power Administration
NF28TransaltaEnergyMarketing(U.S.)Inc.PacifiCorp East Sierra Pacific Power
29 Transalta Energy Marketing (U.S.)Inc.NFIdahoPowerCompanySierraPacificPower
30 Transalta Energy Marketing (U.S.)Inc.NFPacifiCorpEastBonnevillePowerAdministration
31 Transalta Energy Marketing (U.S.)Inc.NFPacifiCorpEastSierraPacificPower
NF32TransaltaEnergyMarketing(U.S.)Inc.Bonneville Power Administration PacifiCorp East
NF33TransaltaEnergyMarketing(U.S.)Inc.Bonneville Power Administration PacifiCorp East
NF34TransaltaEnergyMarketing(U.S.)Inc.Bonneville Power Administration Sierra Pacific Power
TOTAL
Page 328.8FERCFORMNO.1 (ED.12-90)
This Report Is:
(1)[X]An Original
(2)I I A Resubmission
TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456)(Ccnlinued)
(Including transactions reffered to as 'wheeling')
Name of Respondenl
Idaho Power Company
Date of Report
(Mo,Da,Yr)
04/14/2020
Year/Period of Report
2019/Q4Endof
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 M345 842 842 1
7/8 BRDY M345 40,812 40,812 2
7/8 LAGRANDE BRDY 157 157 3
7/8 LAGRANDE M345 192 192 4
7/8 LOLO M345 1,421 1,421 5
7/8 BORA LAGRANDE 3,795 3,795 6
7/8 BPAT.NWMT BRDY 79 76 7
7/8 BPAT.NWMT M345 276 276 8
7/8 BRDY BPAT.NWMT 444 444 9
7/8 BRDY LAGRANDE 3,307 3,307 10
7/8 BRDY LOLO 284 284 11
7/8 BRDY M500 250 250 12
7/8 LAGRANDE BORA 541 541 13
7/8 LAGRANDE BRDY 928 928 14
7/8 LAGRANDE M345 1,001 1,001 15
7/8 LOLO BORA 26 26 16
7/8 LOLO BRDY 380 380 17
7/8 M345 LAGRANDE 4,108 4,108 18
7/8 M345 LOLO 275 275 19
7/8 SMLK BORA 2,261 2,261 20
7/8 WALLAWALLA M345 101 101 21
7/8 BORA LAGRANDE 2,007 2,007 22
7/8 BORA M345 83 83 23
7/8 BORA M500 25 25 24
7/8 BPAT.NWMT LAGRANDE 30 30 25
7/8 BPAT.NWMT M345 23 2623
7/8 BRDY LAGRANDE 889 889 27
7/8 BRDY M345 117 117 28
7/8 IPCOGEN M345 50 50 29
7/8 JBSN LAGRANDE 713 713 30
7/8 JBSN M345 912 912 31
7/8 LAGRANDE BORA 10,515 10,515 32
LAGRANDE7/8 BRDY 73 73 33
LAGRANDE7/8 M345 13,636 13,636 34
0 7,886,493 7,886,493
Page 329.8FERCFORMNO.1 (ED.12-90)
Date of Report
(Mo,Da,Yr)
[A Resubmission 04/14/2020
TRWJSnfeSIBtfSF ELECTRICITY FOR OTHERS (Account 456.1)
(Including transactions referred to as 'wheeling')
This Report Is:
XJAn Original
Year/Period of Report
End of 2019/Q4
Name of Respondent
Idaho Power Company (1)
(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)
NF1TransaltaEnergyMarketing(U.S.)Inc.Avista PacifiCorp East
2 Transalta Energy Marketing (U.S.)Inc.NFAvistaPacifiCorpEast
3 Transalta Energy Marketing (U.S.)Inc.NFAvistaSierraPacificPower
4 Transalta Energy Marketing (U.S.)Inc.NFSierraPacificPowerPacifiCorpEast
NF5TransaltaEnergyMarketing(U.S.)Inc.Sierra Pacific Power NorthWestern/PacifiCorp East
NF6TransaltaEnergyMarketing(U.S.)Inc.Sierra Pacific Power PacifiCorp West
7 Transalta Energy Marketing (U.S.)Inc.NFSierraPacificPowerBonnevillePowerAdministration
8 Transalta Energy Marketing (U.S.)Inc.NFSierraPacificPowerAvista
9 Transalta Energy Marketing (U.S.)Inc.NFPacifiCorpWestPacifiCorpEast
10 Transalta Energy Marketing (U.S.)Inc.NFPacifiCorpWestSierraPacificPower
NF11TransaltaEnergyMarketing(U.S.)Inc.Idaho Power Company PacifiCorp East
12 Transalta Energy Marketing (U.S.)Inc.NFIdahoPowerCompanySierraPacificPower
1 3 Utah Associated Municipal Power Systems NFPacifiCorpEastSierraPacificPower
14 Utah Associated Municipal Power Systems NFPacifiCorpEastSierraPacificPower
15 Utah Associated Municipal Power Systems NFIdahoPowerCompanyPacifiCorpEast
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
TOTAL
Page 328.9FERCFORMNO.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)
04/14/2020
TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456)(Continued)
(Including transactions reffered to as 'wheeling')
Year/Period of Report
End of 2019/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 Line
MegaWatt Hours
Received
MegaWatt Hours
Delivered
No.(MW)
(e)(f)(g)(h)(i)(I)
7/8 LOLO BORA 2,331 2,331 1
7/8 LOLO BRDY 119 119 2
7/8 LOLO M345 4,100 4,100 3
7/8 M345 BORA 106 106 4
7/8 M345 BPAT.NWMT 73 73 5
7/8 M345 HURR 60 6C 6
7/8 M345 LAGRANDE 11,393 11,393 7
7/8 M345 LOLO 50 50 8
7/8 SMLK BORA 2,142 2,142 9
2607/8 SMLK M345 260 10
7/8 WALLAWALLA BORA 7,351 7,351 11
7/8 WALLAWALLA M345 4,443 4,443 12
7/8 BORA M345 1,429 1,429 13
7/8 BRDY M345 81 81 14
7/8 WALLAWALLA BORA 100 100 15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
0 7,886,493 7,886,493
FERC FORM NO.1 (ED.12-90)Page 329.9
This Report Is:
(1)(x]An Original
(2)|A Resubmission
TRANSMISSION OF ElectRlCitV 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 ofthe 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.
Name of Respondent
Idaho Power Company
Date of Report
(Mo,Da,Yr)
04/14/2020
Year/Period of Report
End of 2019/Q4
REVENUE FROM TRANSMISSION OF ELECTRICITY FOR OTHERS
LineDemandChargesEnergyCharges(Other Charges)Total Revenues ($)
(k+l+m)($)($)(5)No.
(n)(k)(I)(m)
1,688,834 125,112 1,813,946 1
1 ,773,672 21,625,030 148,642
36,634,105 451,782 7,085,887
14,712 14,712 4
118,040 118,040 5
933 11,910 610,978
54,85754,857 7
2,7612,761 8
13,107 13,107 9
10
4,388,846 4,388,846 11
3,753,220 3,753,220 12
7,294,564 7,294,564 13
3,057,0583,057,058 14
3,026,790 3,026,790 15
3,026,790 3,026,790 16
17
3,906 3,906 18
4,951 194,951
195 195 20
1,870 1,870 21
1,520 1,520 22
610 610 23
14,383 14,383 24
9,447 9,447 25
3,439 3,439 26
20,39920,399 27
4,602 4,602 28
2,195 2,195 29
2,842 2,842 30
22,455 3122,455
100100 32
502 502 33
283 283 34
9,958,947 33,889,659 0 43,848,605
Page 330FERCFORMNO.1 (ED.12-90)
Name of Respondent
Idaho Power Company
This Report Is:
(1)[X]An Original
(2)I I A Resubmission
TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456)(Continued)
(Including transactions reffered to as 'wheeling')
Date of Report
(Mo,Da,Yr)
04/14/2020
Year/Period of Report
End of 2019/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 (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
LineDemandChargesTotalRevenues($)
(k+l+m)
Energy Charges (Other Charges)
($)($)($)No.
(k)(I)(m)(n)
8,504 8,504 1
338 2338
452 452 3
15,100 15,100 4
330 330 5
900 900 6
5,366 5,366 7
17,330 17,330 8
6,690 6,690 9
81 81 10
99 99 11
2,822 2,822 12
6,368 136,368
5 5 14
12,816 12,816 15
280 280 16
104,582 104,582 17
10,241 10,241 18
21,944 1921,944
127,316 127,316 20
359 359 21
3,624 3,624 22
2,016 2,016 23
585 585 24
990 990 25
82 82 26
7,520 7,520 27
12,700 12,700 28
4,046 4,046 29
4 304
2,277 2,277 31
5,809 5,809 32
88 88 33
57 57 34
9,958,947 33,889,659 0 43,848,605
Page 330.1FERCFORMNO.1 (ED.12-90)
This Report Is:
(1)[X]An Original
Name of Respondent
Idaho Power Company
Year/Period of Report
End of 2019/Q4
Date of Report
(Mo,Da,Yr)
||A Resubmission 04/14/2020
ZCTROT FOR OTHERS (Account 456)(Continued)
(Including transactions reffered to as 'wheeling')
(2)
TRANSMISSION OF EL
9. In column (k)through (n),report the revenue amounts as shown on bills or vouchers.In column (k),provide revenues from demand
charges related to the billing demand reported in column (h).In column (I),provide revenues from energy charges related to the
amount of energy transferred.In column (m),provide the total revenues from all other charges on bills or vouchers rendered,including
out of period adjustments.Explain in a footnote all components of the amount shown in column (m).Report in column (n)the total
charge shown on bills rendered to the entity Listed in column (a).If no monetary settlement was made,enter zero (1101 1)in column
(n).Provide a footnote explaining the nature of the non-monetary settlement,including the amount and type of energy or service
rendered.
10.The total amounts in columns (i)and (j)must be reported as Transmission Received and Transmission Delivered for annual report
purposes only on Page 401,Lines 16 and 17,respectively.
1 1 .Footnote entries and provide explanations following all required data.
REVENUE FROM TRANSMISSION OF ELECTRICITY FOR OTHERS
LineDemandChargesTotalRevenues($)
(k+l+m)
Energy Charges (Other Charges)
($)($)($)No.
(k)(I)(m)(n)
2,208 2,208 1
7,929 7,929 2
5,286 5,286 3
4,966 4,966 4
858 858 5
172 172 6
6,190 6,190 7
1,659 1,659 8
1,144 1,144 9
549 549 10
3,985 3,985 11
104,659 12104,659
13,553 13,553 13
3,985 3,985 14
3,205 3,205 15
43 43 16
10,472 10,472 17
1,970 1,970 18
32,790 32,790 19
2,262 2,262 20
2,277 2,277 21
1,645 1,645 22
24,715 24,715 23
10,258 10,258 24
49,238 49,238 25
97 97 26
206 206 27
1,807 1,807 28
7,001 7,001 29
4,255 4,255 30
996 996 31
25,104 25,104 32
239,856 239,856 33
319 319 34
9,958,947 33,889,659 0 43,848,605
Page 330.2FERCFORMNO.1 (ED.12-90)
This Report Is:
n
Name of Respondent
Idaho Power Company
Date of Report
(Mo,Da,Yr)
04/14/2020
TRAnSWiSSIOKI OF ELECTRICITY FOR OTHERS (Account 456)(Continued)
(Including transactions reffered to as 'wheeling')
Year/Period of Report
End of 2019/Q4(1)An Original
(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 1 01 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
LineDemandChargesEnergyCharges(Other Charges)Total Revenues ($)
(k+l+m)($)($)($)No.
(k)(I)(m)(n)
782 782 1
20,394 20,394 2
331 331 3
1,960 1.960 4
2,262 2,262 5
18,352 18,352 6
2,334 2,334 7
955 955 8
29,029 29,029 9
253,403 253,403 10
329 329 11
194 194 12
683 683 13
1,643 1,643 14
21 21 15
24,706 24,706 16
3,024 3,024 17
2,174 2,174 18
801 801 19
101,196 101,196 20
14,554 14,554 21
6,213 6,213 22
2,769 2,769 23
272 272 24
115,233 115,233 25
1,877 1,877 26
19,970 19,970 27
20,733 20,733 28
1.120 1,120 29
4,698 4,698 30
42,700 42,700 31
146,228 146,228 32
72,281 72,281 33
1,704 1,704 34
9,958,947 33,889,659 0 43,848,605
Page 330.3FERCFORMNO.1 (ED.12-90)
This Report Is:
(1)[X|An Original
(2)I j A Resubmission
TRANSMISSION!OF ELECTRICITY FOR OTHERS (Account 4S6)(Continued)
(including transactions reffered to as 'wheeling')
Date of Report
(Mo,Da,Yr)
04/14/2020
Name of Respondent
Idaho Power Company
Year/Period of Report
End of 2019/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 (11011)in column
(n).Provide a footnote explaining the nature of the non-monetary settlement,including the amount and type of energy or service
rendered.
10.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
LineDemandChargesEnergyCharges(Other Charges)Total Revenues ($)
(k+l+m)($)($)($)No.
(k)(I)(m)(n)
50,226 50,226 1
498 498 2
1,114 1,114 3
467 467 4
109 109 5
4 4 6
2,868 2,868 7
612,218 612,218 8
389 389 9
1,225 1,225 10
4,570 4,570 11
8,825 8,825 12
150 150 13
4,346 144,346
9,298 9,298 15
8,777 8,777 16
1,167 1,167 17
570 570 18
385 385 19
5,309 5,309 20
1,636 1,636 21
646 646 22
287 287 23
3,509 3,509 24
255 255 25
5,809 5,809 26
2,508,983 272,508,983
38,357 38,357 28
1,709 1.709 29
13,708 13,708 30
3.915 3,915 31
18,763 18,763 32
10,062 10,062 33
25,131 25,131 34
9,958,947 33,889,659 0 43,848,605
Page 330.4FERCFORMNO.1 (ED.12-90)
This Report Is:
(1)[xj An Original
(2)r~|A Resubmission
Year/Period of Report
End of 2019/Q4
Name of Respondent
Idaho Power Company
Date of Report
(Mo.Da,Yr)
04/14/2020
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.
REVENUE FROM TRANSMISSION OF ELECTRICITY FOR OTHERS
LineDemandChargesEnergyCharges(Other Charges)Total Revenues ($)
(k+l+m)($)($)($)No.
(k)(I)(m)(n)
13,896 13,896 1
1,636 1,636 2
7,186 7,186 3
16,423 16,423 4
1,227 1,227 5
52,152 52,152 6
14,955 14,955 7
1,220 1,220 8
335 335 9
85,467 85,467 10
15,078 15,078 11
2,721 2,721 12
16,269 16,269 13
505 505 14
600 600 15
688 688 16
17
1,623 1,623 18
133 133 19
95,103 95,103 20
27,033 27,033 21
3,599 3,599 22
1,806 1,806 23
1,035 1,035 24
2,929 2,929 25
404 404 26
316 316 27
23,870 23,870 28
2,664 2,664 29
76 76 30
7,671 7,671 31
11,844 11,844 32
17,885 17,885 33
1,174 1,174 34
9,958,947 33,889,659 0 43,848,605
Page 330.5FERCFORMNO.1 (ED.12-90)
This Report Is;
[X|An Original
Name of Respondent
Idaho Power Company
Year/Period of Report
End of 2019/Q4
Date of Report
(Mo,Da,Yr)
04/14/2020
(1)
TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 455}(Continued)
(Including transactions reffered to as 'wheeling')
(2)A Resubmission
9.In column (k)through (n),report the revenue amounts as shown on bills or vouchers.In column (k),provide revenues from demand
charges related to the billing demand reported in column (h).In column (I),provide revenues from energy charges related to the
amount of energy transferred.In column (m),provide the total revenues from all other charges on bills or vouchers rendered,including
out of period adjustments.Explain in a footnote all components of the amount shown in column (m).Report in column (n)the total
charge shown on bills rendered to the entity Listed in column (a).If no monetary settlement was made,enter zero (1 101 1 )in column
(n).Provide a footnote explaining the nature of the non-monetary settlement,including the amount and type of energy or service
rendered.
10.The total amounts in columns (i)and (j)must be reported as Transmission Received and Transmission Delivered for annual report
purposes only on Page 401,Lines 16 and 17,respectively.
1 1 .Footnote entries and provide explanations following all required data.
REVENUE FROM TRANSMISSION OF ELECTRICITY FOR OTHERS
LineTotalRevenues($)
(k+l+m)
Energy Charges (Other Charges)Demand Charges
($)($)No.($)
(n)(m)(k)(I)
28,157 128,157
1,894 21,894
259 3259
3,535 43,535
25 525
10,852 610,852
120 7120
1,812 81,812
2,096 92,096
1030,74530,745
1,427 111,427
3.788 123,788
285.876 13285,876
7,380 147,380
13,390 1513,390
1615,62715,627
10,163 1710,163
2,203 182,203
13,115 1913,115
15,571 2015,571
2,878 212,878
52,336 2252,336
1,843 231,843
267,342 24267,342
151 25151
12,040 2612,040
1,692 271,692
4,763 284,763
5,307 295,307
63,022 3063,022
17,232 3117,232
11,357 3211,357
227,403 33227,403
52,886 3452,886
43,848,60533,889,659 09,958,947
Page 330.6FERCFORMNO.1 (ED.12-90)
This Report Is:
(1)[X]An Original
(2)r~A Resubmission
TRANSMISSION OF ELTEctRICITy TOR OTHERS (Account 456)(Continued)
(Including transactions reffered to as 'wheeling')
Year/Period of Report
End of 2019/Q4
Name of Respondent
Idaho Power Company
ate of Report
(Mo,Da,Yr)
04/14/2020
9.In column (k)through (n),report the revenue amounts as shown on bills or vouchers.In column (k),provide revenues from demand
charges related to the billing demand reported in column (h).In column (I),provide revenues from energy charges related to the
amount of energy transferred.In column (m),provide the total revenues from all other charges on bills or vouchers rendered,including
out of period adjustments.Explain in a footnote all components of the amount shown in column (m).Report in column (n)the total
charge shown on bills rendered to the entity Listed in column (a).If no monetary settlement was made,enter zero (1 101 1 )in column
(n).Provide a footnote explaining the nature of the non-monetary settlement,including the amount and type of energy or service
rendered.
10.The total amounts in columns (i)and (j)must be reported as Transmission Received and Transmission Delivered for annual report
purposes only on Page 401,Lines 16 and 17,respectively.
1 1 .Footnote entries and provide explanations following all required data.
REVENUE FROM TRANSMISSION OF ELECTRICITY FOR OTHERS
LineDemandChargesTotalRevenues($)
(k+l+m)
Energy Charges (Other Charges)
($)($)($)No.
(k)(I)(m)(n)
15,382 115,382
14,911 214,911
17,226 17,226 3
91 91 4
9.6589,658 5
7,325 67,325
3,324 3,324 7
1,052 1,052 8
65,651 65,651 9
296 296 10
6,370 6,370 11
8,685 128,685
1,4511,451 13
17,226 17,226 14
7,682 7,682 15
11,967 1 1 ,967 16
149,501 149,501 17
3,8803,880 18
12,602 12,602 19
151 151 20
3,705 3,705 21
217,551 217,551 22
26,298 26,298 23
35,944 35,944 24
3,626 3,626 25
193193 26
1,813 1,813 27
1,499 1,499 28
2,430 2,430 29
104,877104,877 30
17,782 17,782 31
90,148 90,148 32
7,813 7,813 33
13 13 34
33,889,659 43,848,6059,958,947 0
Page 330.7FERCFORMNO.1 (ED.12-90)
This Report Is:Date of Report
XjAn Original (Mo,Da,Yr)
~|A Resubmission 04/14/2020
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.
Name of Respondent
Idaho Power Company
Year/Period of Report
(1)2019/Q4Endof
(2)
REVENUE FROM TRANSMISSION OF ELECTRICITY FOR OTHERS
LineDemandChargesEnergyCharges(Other Charges)Total Revenues ($)
(k+l+m)($)($)($)No.
(k)(I)(m)(n)
3,298 3,298 1
159,834 159,834 2
615 615 3
752 4752
5,565 5,565 5
21,479 21,479 6
447 447 7
1,562 1,562 8
2,513 2,513 9
18,717 1018,717
1,607 1,607 11
1,415 1,415 12
3,062 3,062 13
5,252 5,252 14
5,665 155,665
147 16147
2,151 2,151 17
23,250 23,250 18
1,556 1,556 19
12,797 12,797 20
21572572
11,522 11,522 22
476 476 23
144 144 24
172172 25
132 132 26
5,104 5,104 27
672 28672
287 287 29
4,093 4,093 30
5,236 5,236 31
60,364 60,364 32
419 419 33
78,281 78,281 34
9,958,947 33,889,659 0 43,848,605
Page 330.8FERCFORMNO.1 (ED.12-90)
This Report Is:
(1)[x]An Original
(2)fn A Resubmission
Date of Report
{Mo,Da,Yr)
04/14/2020
TRANSMISSION OF ELECTRICITY FOR OTHERS {Account 456)(Continued)
(Including transactions reffered to as 'wheeling')
9. In column (k)through (n),report the revenue amounts as shown on bills or vouchers.In column (k),provide revenues from demand
charges related to the billing demand reported in column (h).In column (I),provide revenues from energy charges related to the
amount of energy transferred.In column (m),provide the total revenues from all other charges on bills or vouchers rendered,including
out of period adjustments.Explain in a footnote all components ofthe amount shown in column (m).Report in column (n)the total
charge shown on bills rendered to the entity Listed in column (a).If no monetary settlement was made,enter zero (1 101 1 )in column
(n).Provide a footnote explaining the nature of the non-monetary settlement,including the amount and type of energy or service
rendered.
10.The total amounts in columns (i)and (j)must be reported as Transmission Received and Transmission Delivered for annual report
purposes only on Page 401,Lines 16 and 17,respectively.
1 1 .Footnote entries and provide explanations following all required data.
Year/Period of Report
End of 2019/Q4
Name of Respondent
Idaho Power Company
REVENUE FROM TRANSMISSION OF ELECTRICITY FOR OTHERS
LineTotalRevenues($)
(k+l+m)
(Other Charges)Demand Charges Energy Charges
($)No.($)($)
(m)(n)(k)(I)
13,382 113,382
683 2683
323,53723,537
609 4609
419 5419
344 6344
65,404 765,404
287 8287
12,297 912,297
1,493 101,493
42,200 1142,200
25,506 1225,506
8,791 138,791
498 14498
15615615
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
43,848,60533,889,659 09,958,947
Page 330.9FERCFORMNO.1 (ED.12-90)
This Page Intentionally Left Blank
Date of Report Year/Period of Report
(Mo,Da,Yr)
04/14/2020
Name of Respondent This Report is:
(1)X An Original
(2)„A Resubmission 2019/Q4IdahoPowerCompany
FOOTNOTE DATA
Schedule Page:328 Line No.:1 Column:a
The network service agreement between Idaho Power and the Bonneville Power Administration
for the Oregon Trail _Electric Cooperative expires September 30,2028 .
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 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:a
The network service agreement between Idaho Power and the Bonneville Power Administration
for the USBR expires December 31,2023.
Schedule Page:328 Line No.:3 Column:a
The network service agreement between Idaho Power and the Bonneville Power Administration
for the Priority Firm Customers e&pf res i&iggt ember 30,_2028.
Schedule Page:328 Line No.:4 Column:a
The contract between Idaho Power and the Milner Irrigation District expires December 31,.
2022.
Schedule Page:328 Line No.4_Column:e
Legacy,contract prior :.o the Open Access Transmission Tariff
Schedule Page:328 Line No.:5 Column:a
The agreement between Idaho Power and the City of Seattle expires December 31,2019.City
of Seattle has re-sold this transmission service request to Morgan Stanley and Morgan
Stanley is now responsible for payment.
Schedule Page:328 Line No.:5 Column:e
4,Open Access Transmission Tariff,Schedule 4 Energy Imbalance Service
Schedule Page:328 Line No.:6 Column:a
The contract between Idaho;Power and PacifiCorp -Imnaha expires on March 31,2021.
Schedule Page:328 Line No.:7 Column:a
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.:8 Column:a
The agreement between Idaho Power and Cycle Horseshoe Bend Wind,LLC has no expiration
date and can be terminated by either party at any time.
Schedule Page:328 Line No.:8 Column:e _
5/6,Open Access Transmi s s ion Tariff,Schedule 5/6 Operating Reserves
Schedule Page:328 Line No.:11 Column:e
7/8,.Open Access Transmission Tariff,Schedule 7/8 Firm/Non-Frim Point-to-Point
Transmission Service
Schedule Page:328 Line No.:18 Column
11,Open Access Transmission Tariff,Unreserved Use Penalty
FERC FORM NO.1 (ED.12-87)Page 450.1
Date of Report
(Mo,Da,Yr)
04/14/2020
Year/Period of Report
End of 2019/Q4
This Report Is:
(1)prjAn Original
(2)A Resubmission
TRANSMISSION OF ELECTRICITY BY OTHERS (Account 565)
(Including transactions referred to as "wheeling")
Name of Respondent
Idaho Power Company
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 OTHERSTRANSFEROFENERGYLine
Other"Magawatt-
toufs
Received
Magawatt-Uemand
Charges
t$r
Energy
Chafes Total Cost of
Transmission
No.Statistical
Classification
Name of Company or Public
Authority (Footnote Affiliations)
Chafeshours
Delivered
(b)(a)(f)(d)(c)(e)(g)h'
101,679101,67912,056 12,0561AvistaCorp-WWP Div NF
310,760310,76091,749 91,7492AvistaCorp-WWP Div SFP
1,146,7501,146,750250,983LFP250,9833BonnevillePowerAdmin
4,8224,822SFP4204204BonnevillePowerAdmin
20,13520,1353,940 3,9405BonnevillePowerAdminNF
236,426 236,426OS6BonnevillePowerAdmin
5,065 5,065OS7BonnevillePowerAdmin
45,469OS45,4698BonnevillePowerAdmin
OS 3,5453,5459BonnevillePowerAdmin
OS 2,6992,69910BonnevillePowerAdmin
OS 8,6148,61411BonnevillePowerAdmin
OS 5,549 5,54912BonnevillePowerAdmin
5,0005,000OS13BonnevillePowerAdmin
12,61612,616603SFP60314NorthwesternEnergy
6,5596,55926026015NorthwesternEnergyNF
760 760OS16NorthwesternEnergy
TOTAL 2,844,8422,585,398 259,444453,446453,446
Page 332FERCFORMNO.1/3-Q (REV.02-04)
Year/Period of Report
End of 2019/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)
04/14/2020
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 OTHERSTRANSFEROFENERGYLine
Demand
Charries
Magawatt-
Dhours
Received
Magawatt-Lnergy
Chafes
Other
Charges Total Cost of
Transmission
No.Statistical
Classification
Name of Company or Public
Authority (Footnote Affiliations)
hours
Delivered ($
(b)(a)(h(d)(c)(e to)to:
712,333712,3338,800 8,8001PacifiCorpInc.LFP
15,39615,3961,496 1,4962PacifiCorpInc.SFP
123,569123,56917,263 17,2633PacifiCorpInc.NF
34,06834,068OS4PacifiCorpInc.
-237-237AO5PacifiCorpInc.
-1.094-1,0946PacifiCorpInc.AD
-20,544 -20,544AD7PacifiCorpInc.
11,05011,0508PugetSoundEnergy,Inc SFP
4,1854,1859SeattleCityLightSFP
14,65014,65010ShellEnergyNorthAme.SFP
77,462SFP77,4621 1 Snohomish County PUD
23,43223,432SFP12TacomaPower
13
14
15
16
TOTAL 2,844,8422,585,398 259,444453,446 453,446
Page 332.1FERCFORMNO.1/3-Q (REV.02-04)
This Page Intentionally Left Blank
Date of Report Year/Period of Report
(Mo,Da,Yr)
04/14/2020
Name of Respondent This Report is:
(1)X An Original
(2)_A ResubmissionIdahoPowerCompany 2019/Q4
FOOTNOTE DATA
Schedule Page:332 Line No.:3 Column:b
Contract Expiration Date 12/31/2021 ~ ~
Schedule Page:332 Line No.:6 Column:b
Spinninq/supp !omenta I reserves____
Schedule Page:332 Line No.:7 Column:b
Ancillary Services
Schedule Page:332 Line No.:8 Column:b
BPAT is provider for capacity reassignment settled with Snohomish County PUD,
Schedule Page:332 Line No.:9 Column:b
BPAT is provider for capacity reassignment settled;'With-Puget Sound :•:.e r gy ,
Schedule Page:332 Line No.:10 Column:b
BPAT is provider for capacity reassignment settled with Seattle City Light.
Schedule Page:332 Line No.:11 Column:b
BPAT is provider for capacity reassignment settled with Tacoma Power,
Schedule Page:332 Line No.:12 Column:b
BPAT is prov :do r for capacity reassignment settled with Shell Energy;
Schedule Page:332 Line No.:13 Column:b
Processing Fee for Transmission Service
Schedule Page:332 Line No.:16 Column:b
Ancillary Services
Schedule Page:332.1 Line No.:1 Column:b
Contract Expiration Date 05/31/2024
Schedule Page:332.1 Line No.:4 Column:b
Ancillary Services
]
J
Schedule Page:332.1 Line No.:5 Column:b
2016 Unreserved Use Refund
Schedule Page:332.1 Line No.:6 Column:b
2017 Unreserved Use Refund
Schedule Page:332.1 Line No.:7 Column:b
2017 PTP True-Up
Schedule Page:332.1 Line No.:8 Column:b
Capacity reassignment,BPAT is provider
Schedule Page:332.1 Line No.:9 Column:b
Capacify reassignment ,BPAT is provider
Schedule Page:332.1 Line No.:10 Column:b
Gapaci t y reassignment,BPAT is provider
Schedule Page:332.1 Line No.:11 Column:b
Capacity reass i gnraen",BPAT is provider
Schedule Page:332.1 Line No.:12 Column:b
Capacity reassignment,BPAT is provider
FERC FORM NO.1 (ED.12-87)Page 450.1
This Report Is:
("•)IxJ An Original
(2)|~^j A Resubmission
MISCELLANEOUS GENERAL EXPENSES (Account 930.2)(ELECTRIC)
Year/Period of Report
End of 2019/Q4
Name of Respondent
Idaho Power Company
Date of Report
(Mo.Da,Yr)
04/14/2020
AmountLineDescription
No.M
Industry Association Dues 550,9391
2 Nuclear Power Research Expenses
3 Other Experimental and General Research Expenses
1,601,4734Pub&Dist Info to Stkhldrs...expn servicing outstanding Securities
5 Oth Expn >=5,000 show purpose,recipient,amount.Group if <$5,000 127,162
6
7 Director Fees and Expenses
Annette Elg 88,0618
9 Christine King 99,764
Dennis Johnson 91 ,40010
Judith Johansen 89,10611
Richard Dahl 164,23812
Richard Navarro 98,10513
Robert Tinstman 64,46614
Ronald Jibson 82,03815
Thomas Carlile 81,45416
17 Travel &Lodging 26,289
18
Corporate Memberships and Subscriptions19
Associated Taxpayers of Idaho 26,00020
Bannock Development Corp 6,00021
Boise Vallley Economic Par 25,00022
Business Plus Inc 5,00023
CEATI International Inc 59,50024
Chartwell Inc 50,38825
ESource 15,72926
IBISWorld Inc 8,50027
Idaho Association of Commerce 16,50028
National Hydropower Association 93,28029
North American Energy Standard 7,50030
Oregon State University 15,00031
Pacific NW Utilities 51,95832
Southern Idaho Economic Development 5,00033
Misc.Memberships or Subscriptions under $5000 32,03834
35
Chamber of Commerce and Other Civic Organizations 52,90036
37
38
39
40
41
42
43
44
45
TOTAL46 3,634,788
FERC FORM NO.1 (ED.12-94)Page 335
Schedule Page: 335 Line No.: 4 Column: b
Recipient Purpose Amount
BLOOMBERG FINANCE LP MISC EXPENSE $ 24,467
BROADRIDGE FINANCIAL SOLUTIONS MISC EXPENSE 52,168
DEUTSCHE BANK BROKER FEES 30,000
D F KING & COMPANY INC-Proxy Printers MISC EXPENSE 39,515
EQ SHAREOWNER SERVICES MGMT EXPENSE 127,392
MODERN NETWORKS IR, LLC MISC EXPENSE 11,821
NASDAQ CORPORATE SOLUTIONS LLC MGMT EXPENSE 55,114
NEW YORK STOCK EXCHANGE I LISTING SERVICES 66,980
OKAPI PARTNERS LLC MGMT EXPENSE 19,800
PAYROLL RELATED MISC EXPENSE 177,200
PR NEWSWIRE MISC EXPENSE 18,169
RIVEL RESEARCH GROUP INC MGMT EXPENSE 15,840
Stock based compensation MISC EXPENSE 934,704
Travel Expense-Stock related MISC EXPENSE 28,303
$ 1,601,473
Schedule Page: 335 Line No.: 5 Column: b
Name of Respondent
Idaho Power Company
This Report is:
(1) X An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
04/14/2020
Year/Period of Report
2019/Q4
FOOTNOTE DATA
FERC FORM NO. 1 (ED. 12-87)Page 450.1
Date of Report
(Mo,Da,Yr)
04/14/2020
Year/Period of Report
End of 2019/Q4
Name of Respondent
Idaho Power Company
This Report Is:
(1)[X]An Original
m n
DEPRECIATION AND AMORTIZATION OF ELECTRIC PLANT (Account 403,404,405)
(Except amortization of aquisition adjustments)
A Resubmission
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 1 971 ,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
(Account 403.1)(Account 404)
Amortization of
Limited Term
Electric Plant
Amortization of
Other Electric
Plant (Acc 405)
Depreciation
Expense
(Account 403)
Line Functional Classification TotalNo.
(b)(d)(e)(f)(a)(c)
7,169,5547,169,5541IntangiblePlant
48,585,2822SteamProductionPlant48,018,617 566,665
3 Nuclear Production Plant
16,909,3684HydraulicProductionPlant-Conventional 16,909,368
5 Hydraulic Production Plant-Pumped Storage
16,072,0616OtherProductionPlant16,072,061
22,815,2967TransmissionPlant22,815,296
41,127,96641,127,9668DistributionPlant
9 Regional Transmission and Market Operation
15,202,38510GeneralPlant15,202,385
1 1 Common Plant-Electric
167,881,91212TOTAL160,145,693 566,665 7,169,554
B.Basis for Amortization Charges
See Footnote
FERC FORM NO.1 (REV.12-03)Page 336
Date of Report Year/Period of Report
(Mo,Da,Yr)
04/14/2020
Name of Respondent This Report is:
(1)X An Original
(2)_A Resubmission 2019/Q4IdahoPowerCompany
FOOTNOTE DATA
Schedule Page:336 Line No.:1 Column:
Balance 12/31/2019 Remaining MonthsBalance1/1/2019Acct404
(1)Shoshone Bannock Agreement
(2)Mid Snake Relicensing
(3)Swan Falls Relicensing
(4)Software
(5)Shoshone Bannock ROW
(6)Boardman Retrofit Analysis
(7)FERC Compliance Costs
(8)Radio Frequency -Spectrum
Total
2019 Amortization
36,000
7,691,855
4,304,580
19,363,826
2,308,501
56,559
5,192,628
3,530,819
42,484,768
3612,000
523,123
189,908
5,961,479
287,899
56,554
93,935
44,656
7,169,554
(1)Shoshone-Bannock Tribe License &Use Agreement.New five year advance payment starting January 2018,with a
December 31,2022 termination date.
(2)Middle Snake Relicensing Costs (Amoritzed over a 30 year license period;licenses expire July 31,2034 and February 28,2035).
(3)Swan Falls Relicensing Costs (Amortized over a 30 year license period,license expires August 31,2042).
(4)Computer Software packages (Amortized over a 62 month period).
(5)Shoshone-Bannock Right of Way (Termination date December 31,2027).
(6)Boardman Retrofit Tech Analysis (Scheduled decommission date December 31,2020).
(7)FERC License Compliance Costs (Termination date will be expiration date of the applicable FERC Licenses)
(8)Radio Frequency Spectrum (Amorized over a 40 year period beginning July 2019)
48,000
8,214,978
4,494,488
17,327,222
2,596,400
113,113
4,488,479
272
96
12
474
37,282,680
Schedule Page:336 Line No.:28 Column:a
(Column:c,d,f,g)Plant accounts 31020 through 31650 and 31670 through 31690 are presented for Jim Bridger facility
only.This data is provided by the most recent depreciation study;Jim Bridger was the only thermal production facility
included in the depreciation study.Plant account 31660 is associated with Valmy facility only.Valmy was not part of
the 2016 depreciation study,as Valmy has been reviewed for decommissioning within regulatory order #33771.There
is no data for estimated service life,net salvage percentage,or mortality curve.
(Column:e)An average plant balance was used in computing these rates by plant account.
Schedule Page:336 Line No.:45 Column:a
Plant account 34410 (created in 2018)was not in the last depreciation study and has not been subject to depreciation
study review.
Schedule Page:336.2 Line No.:19 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.Effective April 1,1993 all depreciable plant is being depreciated using the straight-line remaining life
method.
FERC FORM NO.1 (ED.12-87)Page 450.1
Date of Report
(Mo,Da,Yr)
04/14/2020
Year/Period of Report
End of 2019/Q4
Name of Respondent
Idaho Power Company
This Report Is:
(1)fx]An Original
(2)QAResubmi
DEPRECIATION AND AMORTIZATION OF ELECTRIC PLANT (Continued)
ssion
C.Factors Used in Estimating Depreciation Charges
Mortality
Curve
Average
Remaining
Applied
epr.rates
(Percent)
Depreciable
Plant Base
(In Thousands)
"Estimated"TJeFLine
Avg.Service Salvage
(Percent)
Account No.No.LifeTLiferM£c)(elM(b)
12 310.20 17.904.40 R4.075.00649
13 311.00 17.903.09 SO.5100.00 -9.00132,724
14 312.10 3.46 S1.0 18.10-5.00194,637 70.00
15 312.20 17.004.90 R1.5484,352 53.00 -8.00
16 312.30 13.505.65 R3.04,233 35.00 10.00
17 314.00 16.504.73 SO.545.00 -7.00151,989
18 315.00 3.71 S1.5 16.80-3.0057,780 60.00
19 316.00 14.604.64 SO.O12,127 35.00 2.00
20 316.10 5.407.32 L2.013.00 15.00386
21 316.40 15.00 1.46 L2.025313.00
22 316.50 11.805.56 L2.01,163 13.00 15.00
23 316.60 13.7545
24 316.70 0.37 S1.0 12.2021.00 15.00401
25 316.80 4.35 01.0 17.8025.004,364 20.00
26 316.90 30.602.43 S1.01435.00 15.00
27 317.00 14,741
28 Subtotal Steam 1,059,858
29 331.00 35.80120.00 -25.00 2.08 R2.5208,164
30 332.10 0.98 S1.5 46.20-20.0019,461 120.00
31 332.20 31.20-20.00 1.80 S1.5258,829 120.00
32 332.30 55.101.15 Square5,472
33 333.00 30.601.92 R2.5291,873 100.00 -10.00
34 334.00 27.802.82 R1.565.00 -10.0065,605
35 335.00 31.2090.00 -5.00 2.18 R2.027,124
36 335.10 7.92 Square 7.909315.00
37 335.20 0.80 Square 9.204220.00
38 335.30 2.5014.42 Square3595.00
39 336.00 22.702.58 R3.012,001 100.00
40 Subtotal Hydro 889,023
41 341.00 2.72 Square 32.80153,426
42 342.00 28.702.81 S2.510,438 50.00
43 343.00 26.003.18 R2.0222,139 40.00
44 344.00 2.45 S2.0 28.4050.0066,619
45 344.10 25.00 4.0095
46 345.00 29.302.91 R2.091,997 55.00
47 346.00 3.24 R2.5 24.006,645 35.00
48 Subtotal Other 551,359
49 350.20 85.200.89 R4.034,942 100.00
50 350.22 3.3319930.00
FERC FORM NO.1 (REV.12-03)Page 337
Name of Respondent
Idaho Power Company
Date of Report
(Mo,Da,Yr)
04/14/2020
Year/Period of ReportThisReportIs:
(1)[X]An Original
(2)| |A Resubmission
2019/Q4Endof
DEPRECIATION AND AMORTIZATION OF ELECTRIC PLANT (Continued)
C.Factors Used in Estimating Depreciation Charges
'Depreciable
Plant Base
(In Thousands)
Estimated
Avg.Service
TJeT Applied Mortality "Average
Remaining
Line
Account No.CurveSalvage
(Percent)
Depr.rates
(Percent)No.LifeLifeTIe
M (a)(b)M
12 352.00 53.2081,632 65.00 -33.00 1.88 R3.0
13 353.00 1.97 SO.5 42.00437,091 52.00 -10.00
14 354.00 215,107 71.1080.00 -10.00 1.07 R4.0
15 355.00 53.90204,378 65.00 -80.00 2.64 R1.5
16 355.10 2,612 10.00 10.00
17 356.00 74.00 1.87 R1.5 62.30240,483 -50.00
18 359.00 33.3039065.00 0.91 R2.5
19 Subtotal Transmission 1,216,834
20 360.22 30.00 3.33874
21 361.00 2.17 R3.0 54.4047,761 70.00 -50.00
22 362.00 42.90269,468 55.00 -6.00 1.85 R1.5
23 364.00 58.00 -50.00 2.17 R1.5 44.10273,345
24 364.10 12.00 8.3410,172
25 365.00 34.40144,333 49.00 -30.00 2.65 R1.0
26 366.00 49.1054,244 65.00 -25.00 1.89 R2.5
27 367.00 291,640 50.00 -11.00 1.90 R1.5 39.40
28 368.00 614,853 42.00 -7.00 2.17 R0.5 34.80
29 369.00 1.58 R1.5 43.4063,190 55.00 -40.00
30 370.00 2.05 01.0 25.7017,938 30.00 -5.00
31 370.10 14.0079,953 18.00 -5.00 5.39 R1.5
32 371.20 3,196 21.00 -5.00 2.88 R1.0 14.70
33 373.20 4,658 40.00 -30.00 1.73 R1.0 29.00
34 374.00
35 Subtotal Distribution 1,875,625
36 390.11 2.08 S1.0 33.2033,681 90.00 -3.00
37 390.12 38.8099,310 55.00 -3.00 2.11 R2.0
38 391.10 4.00 Square 12.3014,194 20.00
39 391 .20 25,344 5.00 20.00 Square 2.70
40 391.21 8.00 12.50 Square 3.505,523
41 392.10 7.07 L2.0 9.3087313.00 15.00
42 392.30 4.13 S2.54,563 15.00 40.00 9.70
43 392.40 27,743 13.00 15.00 6.20 L2.0 8.50
44 392.50 13.00 15.00 6.34 L2.0 8.901,774
45 392.60 3.95 S1.0 14.0045,490 21.00 15.00
46 392.70 4.16 S1.010,004 21.00 15.00 12.30
47 392.90 6,589 35.00 15.00 2.24 S1.0 24.30
48 393.00 3,535 4.00 Square 17.4025.00
49 394.00 5.00 Square1 1 ,670 20.00 12.40
50 395.00 5.00 Square14,896 20.00 10.60
FERC FORM NO.1 (REV.12-03)Page 337.1
This Page Intentionally Left Blank
Year/Period of Report
End of 2019/Q4
Date of Report
(Mo,Da,Yr)
04/14/2020
Name of Respondent
Idaho Power Company
This Report Is:
(1)[X|An Original
(2)J-J A Resubmission
DEPRECIATION AND AMORTIZATION OF ELECTRIC PLANT (Continued)
C.Factors Used in Estimating Depreciation Charges
Average
Remaining
Depreciable
Plant Base
(In Thousands)
fcstirriated
Avg.Service
W Applied
Depr.rates
(Percent)
Mortality
Curve
Line
Salvage
(Percent)
Account No.No.LifeLife'Ie
MM(b)(£)M
12 396.00 16.7020.00 25.00 2.97 01.021,937
13 397.10 4.706.67 Square2,446 15.00
14 397.20 8.106.67 Square24,435 15.00
15 397.30 6.67 Square 9.7015.004,285
16 397.40 13.1019,974 6.02 Square15.00
17 398.00 8.606.67 Square7,637 15.00
18 Subtotal General 385,903
19 Total Plant 5,978,602
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46
47
48
49
50
FERC FORM NO.1 (REV.12-03)Page 337.2
Year/Period of Report
End of 2019/Q4
Date of Report
{Mo,Da,Yr)
04/14/2020
Name of Respondent
Idaho Power Company
This Report Is:
(1)[X]An Original
(2)||A Resubmission
REGULATORY COMMISSION EXPENSES
1 ,Report particulars (details)of regulatory commission expenses incurred during the current year (or incurred in previous years,if
being amortized)relating to format cases before a regulatory body,or cases in which such a body was a party.
2.Report in columns (b)and (c),only the current year's expenses that are not deferred and the current year's amortization of amounts
deferred in previous years.
Deferred
in Account
Total
Expense for
Current Year
ExpensesAssessedby
Regulatory
Commission
Line Description
{Furnish name of regulatory commission or body the
docket or case number and a description of the case)
ofNo.182.3 atBeginningofYUtility(b)+(c)ear
(e)(a)(c)(d)(b)
1 Federal Energy Regulatory Commission:
2 Annual admin charges assessed by FERC 4,326,4064,326,406
3
4 General Regulatory Expenses and
Various other Dockets 112,711 112,7115
6
158,5017OregonHydro-Fees Amortization 158,501
8
9 Regulatory Commission Expenses -Idaho
1 0 Rate Case -Misc expenses 63,470 63,470 27,719
11
12 Regulatory Commission Expenses -Oregon
Rate Case -Misc expenses 87,303 87,30313
General Regulatory 552,003 552,00314
Other OPUC expenses 20,495 20,49515
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
4,484,907 835,982 5,320,889 27,71946TOTAL
FERC FORM NO.1 (ED.12-96)Page 350
Year/Period of Report
End of 2019/Q4
Date of Report
(Mo,Da,Yr)
04/14/2020
Name of Respondent
Idaho Power Company
This Report Is:
(1)[x]An Original
(2)||A Resubmission
REGULATORY COMMISSION EXPENSES (Continued)
3.Show in column (k)any expenses incurred in prior years which are being amortized.List in column (a)the period of amortization.
4.List in column (f),(g),and (h)expenses incurred during year which were charged currently to income,plant,or other accounts.
5.Minor items (less than $25,000)may be grouped.
AMORTIZED DURING YEAREXPENSESINCURREDDURINGYEAR
Contra
Account
Deferred in
Account 182.3
End of Year
CURRENTLY CHARGED TO
Account
Deferred to
Account 182.3
LineAmount
Department Amount No.No.
(I)(i)m (k)in (g)M.
1
2Electric4,326,406928
3
4
5Electric112,711928
6
7Electric928158,501
8
9
1055,967 22,6227,503 50,870 928203Electric928
11
12
1387,303Electric928
14552,003Electric928
1520,495Electric928
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
55,9675,264,922 50,870 22,622 46
Page 351FERCFORMNO.1 (ED.12-96)
Year/Period of Report
End of 2019/Q4
Name of Respondent
Idaho Power Company
ate of Report
(Mo,Da,Yr)
04/14/2020
This Report Is:
(1)[x]An Original
(2)Q 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.(Identify
recipient regardless of affiliation.)For any R,D &D work carried with others,show separately the respondent's cost for the year and cost chargeable to
others (See definition of research,development,and demonstration in Uniform System of Accounts).
2.Indicate in column (a)the applicable classification,as shown below:
Classifications:
A.Electric R,D &D Performed Internally:
(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 2019.
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
Year/Period of Report
End of 2019/Q4
Name of Respondent
Idaho Power Company
This Report Is:
(1)[XJ An Original
(2)A Resubmission
RESEARCH,DEVELOPMENT,AND DEMONSTRATION ACTIVITIES (Continued)
Date of Report
(Mo,Da,Yr)
04/14/2020
(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 YEARCostsIncurredInternallyCostsIncurredExternally
Curren^Year
Line
Current Year No.Account Amount
(g)(e)(f)(d)
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
Date of Report
(Mo,Da,Yr)
04/14/2020
Year/Period of Report
End of 2019/Q4
This Report Is:
(1)p<]An Original
(2)||A Resubmission
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.
(d)(a)(b)
1 Electric
2 Operation
3 Production 21,828,625
4 Transmission 6,865,279
5 Regional Market
6 Distribution 17,754,666
7 Customer Accounts 9,194,898
Customer Service and Informational8 4,937,487
9 Sales
10 Administrative and General 79,638,723
TOTAL Operation (Enter Total of lines 3 thru 10)11 140,219,678
12 Maintenance
13 Production 4,424,027
14 Transmission 3,147,207
15 Regional Market
16 Distribution 7,735,580
Administrative and General17 966,334
18 TOTAL Maintenance (Total of lines 13 thru 17)16,273,148
19 Total Operation and Maintenance
20 Production (Enter Total of lines 3 and 13)26,252,652
21 Transmission (Enter Total of lines 4 and 14)10,012,486
Regional Market (Enter Total of Lines 5 and 15)22
23 Distribution (Enter Total of lines 6 and 16)25,490,246
24 Customer Accounts (Transcribe from line 7)9,194,898
25 Customer Service and Informational (Transcribe from line 8)4,937,487
26 Sales (Transcribe from line 9)
27 Administrative and General (Enter Total of lines 10 and 17)80,605,057
28 TOTAL Oper.and Maint.(Total of lines 20 thru 27)156,492,826 156,492,826
Gas29
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
Customer Service and Informational38
Sales39
40 Administrative and General
41 TOTAL Operation (Enter Total of lines 31 thru 40)
42 Maintenance
Production-Manufactured Gas43
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)
04/14/2020
Year/Period of Report
End of 2019/Q4
Allocation of
Payroll charged for
Clearing Accounts
Line Classification Direct Payroll
Distribution Total
No.
(a)(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)156,492,826 156,492,826
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)
73 Electric Plant
74 Gas Plant
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 Store Expense 4,951,538 4,951,538
79 Other Clearing Accounts 3,800,752 3,800,752
80 Construction Work in Progress 64,149,359 64,149,359
Other Work in Progress81 3,759,926 3,759,926
82 Other Acounts 5,182,165 5,182,165
83 Indirect Loading 46,764,986 46,764,986
84
85
86
87
88
89
90
91
92
93
94
TOTAL Other Accounts95 81,843,740 46,764,986 81,843,740
TOTAL SALARIES AND WAGES96 238,336,566 46,764,986 238,336,566
FERC FORM NO.1 (ED.12-88)Page 355
This Page Intentionally Left Blank
Date of Report Year/Period of Report
(Mo,Da,Yr)
04/14/2020
Name of Respondent This Report is:
(1)X An Original
(2)_A Resubmission 2019/Q4IdahoPowerCompany
FOOTNOTE DATA
Schedule Page:354 Line No.:83 Column:a
Amount reported is total amount of indirect loading.The loading is allocated to
departments based on labor charges.
FERC FORM NO.1 (ED.12-87)Page 450.1
Year/Period of Report
End of 2019/Q4
This Report Is:
(1)[X]An Original
(2)|-1 A Resubmission
PURCHASES AND SALES OF ANCILLARY SERVICES
Date of Report
(Mo,Da,Yr)
04/14/2020
Name of Respondent
Idaho Power Company
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 Sold for the YearAmountPurchasedfortheYear
Usage -Related Billing DeterminantUsage-Related Billing Determinant
Unit of
Measure
Unit of
Measure DollarsNumberofUnitsTypeofAncillaryServiceNumberofUnitsDollarsLine
(9)(e)(f)(b)(c)(d)(a)No.
1 Scheduling,System Control and Dispatch 256,948
2 Reactive Supply and Voltage 14,306
3 Regulation and Frequency Response 3,295,910 KW 322,835
4 Energy Imbalance
5 Operating Reserve -Spinning 4,310,917 KW2,755 422,254
6 Operating Reserve -Supplement 2,310 4,310,917 KW 422,254
7 Other
8 Total (Lines 1 thru 7)11,917,744276,319 1,167,343
FERC FORM NO.1 (New 2-04)Page 398
Date of Report Year/Period of Report
(Mo,Da,Yr)
04/14/2020
This Report is:
(1)X An Original
(2)_A Resubmission
Name of Respondent
2019/Q4IdahoPowerCompany
FOOTNOTE DATA
Schedule Page:398 Line No.:1 Column:b
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)[X]An Original
(2)| |A Resubmission
MONTHLY TRANSMISSION SYSTEM PEAK LOAD
Year/Period of Report
End of 2019/Q4
Name of Respondent
Idaho Power Company
Date of Report
(Mo,Da,Yr)
04/14/2020
(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:
Other
Service
Line Monthly Peak
MW -Total
OtherLong-
Term Firm
Service
Short-Term Firm
Point-to-point
Reservation
Day of
Monthly
Hour of
Monthly
Firm Network
Service for
Others
Long-Term Firm
Point-to-point
Reservations
Firm Network
Service for SelfNo.Month
Peak Peak
(i)0)(e)(f)(9)(h)(a)(b)(c)(d)
3,283 1,579 973 4962351January90022
3,429 7001,511 245 9732February22800
1,3253,150 629 223 9733March6900
2,5213,719 703 2,9194TotalforQuarter1
973 1,0862,782 525 198268005April
7923,543 1,480 298 9736May132000
2484,138 2,565 352 9737June181900
2,1264,570 848 2,9198TotalforQuarter2
174,478 3,111 377 9739July121600
1819734,067 2,567 34610August151600
973 1184,326 2,895 34016001 1 September 5
2,919 3168,573 1,06312TotalforQuarter3
3303,331 1,768 260 97313October31800
2753,269 1,781 240 97314November1900
3931,759 262 9733,38715December 18 800
762 2,919 9985,30816TotalforQuarter4
17 TotalYear to
Date/Year 5,96122,170 3,376 11,676
Page 400FERCFORMNO.1/3-Q (NEW.07-04)
Year/Period of Report
End of 2019/Q4
Date of Report
{Mo,Da,Yr)
04/14/2020
Name of Respondent
Idaho Power Company
This Report Is:
(1)[x]An Original
(2)| |A Resubmission
ELECTRIC ENERGY ACCOUNT
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.
(b)(b)(a)(a)
21 DISPOSITION OF ENERGY1SOURCESOFENERGY
14,536,7142Generation(Excluding Station Use):22 Sales to Ultimate Consumers (Including
Interdepartmental Sales)3 Steam 3,012,385
23 Requirements Sales for Resale (See
instruction 4,page 311.)
4 Nuclear
5 Hydro-Conventional 8,293,793
24 Non-Requirements Sales for Resale (See
instruction 4,page 311.)
2,850,9226Hydro-Pumped Storage
7 Other 2,114,102
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)
13,420,280
1,146,82327TotalEnergyLosses10Purchases5,194,040
28 TOTAL (Enter Total of Lines 22 Through
27)(MUST EQUAL LINE 20)
18,534,45911PowerExchanges:
12 Received 59,640
13 Delivered 148,478
14 Net Exchanges (Line 12 minus line 13)-88,838
15 Transmission For Other (Wheeling)
16 Received 7,886,493
17 Delivered 7,877,516
8,97718NetTransmissionforOther(Line 16 minus
line 17)
19 Transmission By Others Losses
20 TOTAL (Enter Total of lines 9,10, 14,18
and 19)
18,534,459
Page 401aFERCFORMNO.1 (ED.12-90)
Date of Report Year/Period of Report
(Mo,Da,Yr)
04/14/2020
Name of Respondent This Report is:
(1)X An Original
(2)_A Resubmission 2019/Q4IdahoPowerCompany
FOOTNOTE DATA
Schedule Page:401 Line No.:18 Column:b
Page 329 Column I differs from page 401 by 8,977 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
This Report Is:
(1)[XlAn Original
(2)]|A Resubmission
Name of Respondent
Idaho Power Company
Date of Report
(Mo,Da,Yr)
04/14/2020
Year/Period of Report
End of 2019/Q4
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.Month Total Monthly Energy Megawatts (See Instr.4)Day of Month Hour
(a)(b)(c)(d)(e)(f)
29 January 1,437,804 121,613 2,195 2 0900
30 February 1 ,582,242 375,283 2,225 7 0800
31 March 1,667,258 508,715 2,037 1 0800
32 April 1,574,313 524,562 1,781 30 0800
33 May 1,527,689 328,670 2,306 14 1700
34 June 1 ,665,859 189,081 2,818 17 1800
35 July 1,849,708 94,069 3,242 22 2000
36 August 1,767,923 88,582 3,201 20005
37 September 1,505,714 271,753 3,074 5 1800
38 October 1,265,938 121,792 2,226 30 0900
39 November 1,270,702 109,256 2,059 1 0900
40 December 1,419,309 117,546 2,256 17 0800
41 TOTAL 18,534,459 2,850,922
Page 401bFERCFORMNO.1 (ED.12-90)
Year/Period of Report
End of 2019/Q4
Name of Respondent
Idaho Power Company
This Report Is:
(1)[x]An Original
(2)|—|A Resubmission
Date of Report
(Mo.Da,Yr)
04/14/2020
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
Plant
Name:Jim Br/dger
Line Item
No.
(c)(b)(a)
SteamSteam1KindofPlant(Internal Comb,Gas Turb,Nuclear
ConventionalSemi-Outdoor Boiler2TypeofConstr(Conventional,Outdoor,Boiler,etc)
198019743YearOriginallyConstructed
198019794YearLastUnitwasInstalled
64.20770.505TotalInstalledCap(Max Gen Name Plate Ratings-MW)
597046NetPeakDemandonPlant-MW (60 minutes)
569487607PlantHoursConnectedtoLoad
008NetContinuousPlantCapability(Megawatts)
009WhenNotLimitedbyCondenserWater
0010WhenLimitedbyCondenserWater
001 1 Average Number of Employees
255121000224291000012NetGeneration,Exclusive of Plant Use -KWh
10661050967113CostofPlant:Land and Land Rights
126282967285054214StructuresandImprovements
6409791664765639915EquipmentCosts
50460089783428AssetRetirementCosts16
81878830730800040TotalCost17
1275.371218CostperKWofInstalledCapacity(line 17/5)Including 948.4751
43189818186119ProductionExpenses:Oper,Supv,&Engr
67025397498097720Fuel
00CoolantsandWater(Nuclear Plants Only)21
983727569936722SteamExpenses
00SteamFromOtherSources23
0024SteamTransferred(Cr)
0025ElectricExpenses
982144688842026MiscSteam(or Nuclear)Power Expenses
022464927Rents
0028Allowances
462529291629MaintenanceSupervisionandEngineering
358510MaintenanceofStructures30
1208176848631MaintenanceofBoiler(or reactor)Plant31
9961162400660MaintenanceofElectricPlant32
47821591958633MaintenanceofMiscSteam(or Nuclear)Plant
1034716510323706734TotalProductionExpenses
0.04060.0460ExpensesperNetKWh35
Coal OilCoalOil36Fuel:Kind (Coal,Gas,Oil,or Nuclear)
Tons Barrels37Unit(Coal-tons/Oil-barrel/Gas-mcf/Nuclear-indicate)Tons Barrels
149646 935 038Quantity(Units)of Fuel Burned 1267922 5834 0
8608 138800 039AvgHeat Cont -Fuel Burned (btu/indicate if nuclear)9343 140000 0
87.902 0.00097.044 0.000 42.40540AvgCostofFuel/unit,as Delvd f.o.b.during year 55.864
95.384 0.00078.749 0.000 44.084AverageCostofFuelperUnitBurned58.63841
16.356 0.00013.393 0.000 2.57742AverageCostofFuelBurnedperMillionBTU3.138
0.0000.000 0.026 0.00043AverageCostofFuelBurnedperKWhNetGen0.033 0.000
0.000 10055.000 0.000 0.00044AverageBTUperKWhNetGeneration10578.000 0.000
FERC FORM NO.1 (REV.12-03)Page 402
Name of Respondent
Idaho Power Company
Date of Report
(Mo,Da,Yr)
04/14/2020
Year/Period of Report
End of 2019/Q4
This Report Is:
(1)p?|An Original
(2)| |A Resubmission
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.
Plant
Name:Valmy
LinePlant
Name:Danskin
Plant
Name:Bennett Mountain No.
(d)(e)(f)
Gas TurbineSteamGasTurbine 1
Outdoor Conventional Conventional 2
2005 319812001
2008 2005 41985
283.50 270.90 172.80 5
180 6256242
227738212076 7
0 261 164 8
0 0 90
0 0 100
4 1106
317878000 12514354000294755000
1106140 402745 0 13
6031153 1783440 1447245540
105040745 54056780 15199989898
0 0 16-88540
55840220 17248253038111474643
323.1494 18875.6721 411.4974
7798919380149645 19
23573460 7379352 7377286 20
0 0 210
0 0 224100136
0 2300
0 2400
352628 251894278559417
1324479 157792 46458 26
0 0 270
0 0 280
0 2900
7239425935076139 30
3562719 59119 13408 31
472835 248235 32681687
0 33574630
8118207363729528854299 34
0.0707 0.0300 0.0255 35
Coal Oil Gas Gas 36
MCF MCF 37TonsBarrels
3301141 02826451025703089460000 38
9874 138778 0 1027 0 0 1027 0 0 39
97.372 0.000 2.389 0.000 0.000 2.235 0.000 0.000 4047.571
79.791 0.000 2.389 0.000 0.000 2.235 0.000 0.000 4197.406
0.000 2.690 0.000 0.0004.041 16.711 0.000 2.880 0.000 42
0.000 0.023 0.000 0.0000.046 0.000 0.000 0.025 0.000 43
0.000 10665.000 0.000 0.00010986.000 0.000 0.000 10764.000 0.000 44
FERC FORM NO.1 (REV.12-03)Page 403
Year/Period of Report
Endof 2019/Q4
This Report Is:
(1)[X]An Original
Date of Report
(Mo.Da,Yr)
04/14/2020
Name of Respondent
Idaho Power Company (2)||A Resubmission
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.
Plant
Name:
Plant
Name:Langley Gulch
Line Item
No.
(c)(b)(a)
Gas Turbine1KindofPlant(Internal Comb,Gas Turb,Nuclear
Conventional2TypeofConstr(Conventional,Outdoor,Boiler,etc)
20123YearOriginallyConstructed
20124YearLastUnitwasInstalled
0.00318.455TotalInstalledCap(Max Gen Name Plate Ratings-MW)
02986NetPeakDemandonPlant-MW (60 minutes)
055497PlantHoursConnectedtoLoad
03008NetContinuousPlantCapability(Megawatts)
009WhenNotLimitedbyCondenserWater
0010WhenLimitedbyCondenserWater
02411AverageNumberofEmployees
0150143600012NetGeneration,Exclusive of Plant Use -KWh
0228726113CostofPlant:Land and Land Rights
014559978114StructuresandImprovements
023786820815EquipmentCosts
00AssetRetirementCosts16
038575525017TotalCost
018CostperKWofInstalledCapacity(line 17/5)Including 1211.3526
051196319ProductionExpenses:Oper,Supv,&Engr
03685110720Fuel
00CoolantsandWater(Nuclear Plants Only)21
0022SteamExpenses
0023SteamFromOtherSources
0024SteamTransferred(Cr)
03483300ElectricExpenses25
028453826MiscSteam(or Nuclear)Power Expenses
0027Rents
0028Allowances
00MaintenanceSupervisionandEngineering29
059465MaintenanceofStructures30
065093MaintenanceofBoiler(or reactor)Plant31
02119679MaintenanceofElectricPlant32
0033MaintenanceofMiscSteam(or Nuclear)Plant
43375145 0TotalProductionExpenses34
0.00000.028935ExpensesperNetKWh
Gas36Fuel:Kind (Coal,Gas,Oil,or Nuclear)
37 Unit (Coal-tons/Oil-barrel/Gas-mcf/Nuclear-indicate)MCF
0 0 0117167270038Quantity(Units)of Fuel Burned
0 039AvgHeatCont-Fuel Burned (btu/indicate if nuclear)0 0 01027
0.000 0.0000.000 0.000 0.00040AvgCostofFuel/unit,as Delvd f.o.b.during year 3145.000
0.0000.000 0.000 0.000 0.000AverageCostofFuelperUnitBurned3145.00041
0.0000.000 0.000 0.00042AverageCostofFuelBurnedperMillionBTU3.860 0.000
0.000 0.000 0.000 0.00043AverageCostofFuelBurnedperKWhNetGen0.025 0.000
0.000 0.000 0.000 0.00044AverageBTUperKWhNetGeneration8014.000 0.000
FERC FORM NO.1 (REV.12-03)Page 402.1
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 04/14/2020 2019/Q4
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 4 02 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
Name of Respondent
Idaho Power Company
Year/Period of Report
End of 2019/Q4
This Report Is:
(1)[X]An Original
(2)| |A Resubmission
Date of Report
{Mo.Da,Yr)
04/14/2020
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.
Line Item FERC Licensed Project No.2736
Plant Name:American Falls
FERC Licensed Project No.1975
Plant Name:BlissNo.
(a)(b)(c)
1 Kind of Plant (Run-of-River or Storage)Run-of-River Run-of-River
2 Plant Construction type (Conventional or Outdoor)Outdoor Outdoor
3 Year Originally Constructed 1978 1949
4 Year Last Unit was Installed 1978 1950
5 Total installed cap (Gen name plate Rating in MW)75.0092.34
6 Net Peak Demand on Plant-Megawatts (60 minutes)107 72
7 Plant Hours Connect to Load 5,860 8,760
8 Net Plant Capability (in megawatts)
9 (a)Under Most Favorable Oper Conditions 76110
10 (b)Under the Most Adverse Oper Conditions 0 1
1 1 Average Number of Employees 4 4
12 Net Generation,Exclusive of Plant Use -Kwh 382,537,000 388,381,000
13 Cost of Plant
14 Land and Land Rights 875,319 768,366
15 Structures and Improvements 12,090,205 1,757,779
16 Reservoirs,Dams,and Waterways 4,293,075 9,087,082
17 Equipment Costs 33,222,412 21,479,331
18 Roads,Railroads,and Bridges 839,276 486,477
19 Asset Retirement Costs 0 0
TOTAL cost (Total of 14 thru 19)51,320,28720 33,579,035
Cost per KW of Installed Capacity (line 20 /5)21 555.7753 447.7205
22 Production Expenses
23 Operation Supervision and Engineering 248,887 760,110
24 Water for Power 1,808,422 593,062
25 Hydraulic Expenses 173,773 865,455
26 Electric Expenses 85,676 87,528
27 Misc Hydraulic Power Generation Expenses 364,413 619,267
28 Rents 191 4,898
29 Maintenance Supervision and Engineering 15,279 8,458
30 Maintenance of Structures 105,053 37,974
31 Maintenance of Reservoirs,Dams,and Waterways 334 10,561
32 Maintenance of Electric Plant 435,257 128,177
33 Maintenance of Misc Hydraulic Plant 131,683 195,459
34 Total Production Expenses (total 23 thru 33)3,368,968 3,310,949
35 Expenses per net KWh 0.0088 0.0085
FERC FORM NO.1 (REV.12-03)Page 406
Year/Period of Report
End of 2019/Q4
Date of Report
{Mo.Da,Yr)
04/14/2020
This Report Is:
(1)m 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.2848
Plant Name:Cascade
FERC Licensed Project No.1971
Plant Name:Oxbow
FERC Licensed Project No.1971
Plant Name:Brownlee
Line
No.
(e)(d)ID.
1StorageRun-of-RiverStorage
2OutdoorOutdoorOutdoor
3196119831958
4196119841980
5190.0012.42652.60
621212553
78,7608,7538,760
8
922115747
102021220
11628
121,093,024,00036,596,0002,538,737,000
13
141,212,76782,14218,400,296
1514,865,0987,328,25240,104,551
1631,502,5513,145,63167,642,337
1722,357,19513,486,621114,707,578
18585,876122,6681,459,263
19000
2070,523,48724,165,314242,314,025
21371.17621,945.6775371.3056
22
23421,957198,222612,510
24222,404165,548371,020
25720,689465,0601,171,215
26247,867109,654457,772
27442,509305,163660,352
2819,837120,989 75
2913,1026,64618,551
3047,2673,42629,283
3117,2111740,181
32140,422190,453382,274
33402,739116,442414,552
342,696,0041,560,7064,278,699
350.00250.04260.0017
FERC FORM NO.1 (REV.12-03)Page 407
Name of Respondent
Idaho Power Company
Year/Period of Report
End of 2019/Q4
This Report Is:
(1)pgAn Original
(2)| |A Resubmission
ate of Report
(Mo,Da,Yr)
04/14/2020
HYDROELECTRIC GENERATING PLANT STATISTICS (Large Plants)
1 .Large plants are hydro plants of 1 0,000 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.
Line FERC Licensed Project No.1971
Plant Name:Hells Canyon
Item FERC Licensed Project No.2726
Plant Name:MaladNo.
(a)
1 Kind of Plant (Run-of-River or Storage)Storage Run-of-River
2 Plant Construction type (Conventional or Outdoor)OutdoorOutdoor
3 Year Originally Constructed 19481967
4 Year Last Unit was Installed 19481967
5 Total installed cap (Gen name plate Rating in MW)391.50 21.77
6 Net Peak Demand on Plant-Megawatts (60 minutes)350 8
7 Plant Hours Connect to Load 8,728 8,755
8 Net Plant Capability (in megawatts)
9 (a)Under Most Favorable Oper Conditions 445 25
10 (b)Under the Most Adverse Oper Conditions 137 21
1 1 Average Number of Employees 15
12 Net Generation,Exclusive of Plant Use -Kwh 2,213,314,000 148,512,000
13 Cost of Plant
14 Land and Land Rights 2,113,754 205,376
15 Structures and Improvements 3,163,455 3,954,760
16 Reservoirs,Dams,and Waterways 53,958,676 7,356,921
17 Equipment Costs 22,638,014 16,736,415
18 Roads,Railroads,and Bridges 969,681 1,507,442
Asset Retirement Costs19 0 0
20 TOTAL cost (Total of 14 thru 19)82,843,580 29,760,914
21 Cost per KW of Installed Capacity (line 20 /5)211.6056 1,367.0608
22 Production Expenses
23 Operation Supervision and Engineering 348,267 165,453
Water for Power24 221,174 721,716
25 Hydraulic Expenses 684,405 218,957
26 Electric Expenses 238,272 41,188
27 Misc Hydraulic Power Generation Expenses 504,401 141,872
28 Rents 32,997 0
29 Maintenance Supervision and Engineering 13,230 6,639
30 Maintenance of Structures 2,820 8,021
Maintenance of Reservoirs,Dams,and Waterways31 87,681 29,880
Maintenance of Electric Plant32 173,271 132,792
33 Maintenance of Misc Hydraulic Plant 354,014 121,453
34 Total Production Expenses (total 23 thru 33)2,660,532 1,587,971
Expenses per net KWh35 0.0012 0.0107
FERC FORM NO.1 (REV.12-03)Page 406.1
Year/Period of Report
Endof 2019/Q4
Name of Respondent
Idaho Power Company
This Report Is:
(1)[X|An Original
(2)| |A Resubmission
Date of Report
{Mo,Da,Yr)
04/14/2020
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)M 10.
1Run-of-RiverRun-of-RiverRun-of-River
2ConventionalOutdoorConventional
3193519101952
4199519521994
552.9082.80 27.17
6522492
77,2218,4358,760
8
9539124
10508414
11245
12147,630,000134,329,000495,712,000
13
14255,4995,725,987 309,957
1511,184,2809,951,925 27,504,527
169,024,93311,994,588 15,989,465
1722,495,77032,153,97214,731,841
181,917,603835,9461,602,868
19000
2044,878,08544,007,209 76,793,867
21848.3570531.4880 2,826.4213
22
23502,739665,822 520,704
24204,012485,607 380,244
25241,674880,9361,117,340
2662,63880,227 94,387
27227,047526,453 428,681
284,3488,19752,900
296,0617,44210,509
3040,86592,547 54,669
317Q.22156,951 23,732
3263,387174,117 126,919
3392,211122,146138,806
341,515,2033,401,279 2,648,057
350.01030.0069 0.0197
FERC FORM NO.1 (REV.12-03)Page 407.1
Year/Period of Report
End of 2019/Q4
Name of Respondent
Idaho Power Company
This Report Is:
(1)[x]An Original
(2)|—|A Resubmission
Date of Report
(Mo,Da,Yr)
04/14/2020
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.
Line FERC Licensed Project No.2777
Plant Name:Upper Salmon
FERC Licensed Project No.2778
Plant Name:Shoshone Falls
Item
No.
(a)M (c)
Run-of-River1KindofPlant(Run-of-River or Storage)Run-of-River
Conventional2PlantConstructiontype(Conventional or Outdoor)Outdoor
3 Year Originally Constructed 19071937
19214YearLastUnit was Installed 1947
11.505Totalinstalledcap(Gen name plate Rating in MW)34.50
6 Net Peak Demand on Plant-Megawatts (60 minutes)35 13
7 Plant Hours Connect to Load 4,6678,755
8 Net Plant Capability (in megawatts)
149(a)Under Most Favorable Oper Conditions 39
10 (b)Under the Most Adverse Oper Conditions 32 11
1 1 Average Number of Employees 3 3
22,003,00012NetGeneration,Exclusive of Plant Use -Kwh 216,643,000
13 Cost of Plant
313,32814LandandLandRights202,399
15 Structures and Improvements 3,142,130 7,714,668
8,931,630 14,891,70516Reservoirs,Dams,and Waterways
Equipment Costs 9,436,352 5,668,95717
115,10818Roads,Railroads,and Bridges 29,359
019AssetRetirementCosts0
28,703,76620TOTALcost(Total of 14 thru 19)21,741,870
Cost per KW of Installed Capacity (line 20 /5)630.1991 2,495.979721
22 Production Expenses
23 Operation Supervision and Engineering 188,626 281,200
199,62424WaterforPower147,883
193,01125HydraulicExpenses309,391
26 Electric Expenses 136,797 72,827
Misc Hydraulic Power Generation Expenses 237,314 464,35827
14 20728Rents
2,40629MaintenanceSupervisionandEngineering10,457
Maintenance of Structures 52,805 30,32630
Maintenance of Reservoirs,Dams,and Waterways 69,679 6,00231
Maintenance of Electric Plant 214,342 30,91532
38,639MaintenanceofMiscHydraulicPlant123,30733
34 Total Production Expenses (total 23 thru 33)1,490,615 1,319,515
0.0069 0.060035ExpensespernetKWh
FERC FORM NO.1 (REV.12-03)Page 406.2
Date of Report
(Mo.Da,Yr)
04/14/2020
Year/Period of Report
End of 2019/Q4
Name of Respondent
Idaho Power Company
This Report Is:
(1)[X|An Original
(2)Q A Resubmission
HYDROELECTRIC GENERATING PLANT STATISTICS (Large Plants)(Continued)
5.The items under Cost of Plant represent accounts or combinations ofaccounts 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.2899
Plant Name:Milner
FERC Licensed Project No.1971
Plant Name:Common Facilities
Line
No.
(d)(e)
1Run-of-RiverRun-of-River
2ConventionalOutdoor
319921949
419921949
559.4560.000.00
660530
76,1598,7530
8
961064
101600
11205
12157,221,000244,930,0000
13
14138,100114,368 424,428
1510,663,9273,521,21850,643,369
1617,767,0027,769,89513,556,785
1729,317,47417,765,3592,671,666
18501,87788,693142,581
19000
2058,388,38067,128,769 29,569,593
21982.1426492.82660.0000
22
23302,649496,8630
24807,609252,4690
25296,710452,4386,795,573
2658,675206,3290
27355,334428,554134
283,8784,1960
294,3795,6840
3081,339 25,0690
314,32026,6570
3283,43844,6040
3379,87397,491274,264
342,096,624 2,021,9347,069,971
350.01290.00860.0000
Page 407.2FERCFORMNO.1 (REV.12-03)
This Report Is:
(1)fx|An Original
(2)| |A Resubmission
GENERATING PLANT STATISTICS (Small Plants)
Year/Period of Report
End of 2019/Q4
Date of Report
(Mo,Da,Yr)
04/14/2020
Name of Respondent
Idaho Power Company
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 Capacity
Name Plate Ratine
(In MW)
Net Peak
DemandYear
Orig.
Const.
Net Generation
Excluding
Plant Use
Line Cost of PlantNameofPlant
(effln.)No.
(e)(f)(a)(b)(c)
1 Hydro:
3,565,8642.5 17,2722ClearLakes19372.50
56,953 11,663,2843ThousandSprings19126.80 7.9
4
5
6 Internal Combustion:
884,1347SalmonDiesel19675.00 5.5 33
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)
This Report Is:
(1 )[x]An Original
(2)[~1A Resubmission
Year/Period of Report
End of 2019/Q4
Name of Respondent
Idaho Power Company
Date of Report
(Mo,Da,Yr)
04/14/2020
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 ofsteam,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)
Plant Cost (Incl Asset
Retire.Costs)Per MW
Operation
Exc'l.Fuel
LineKindofFuelFuelMaintenanceNo.
(I)(k)(g)(h)(i)G)
1
157,869 276,7731,426,346
221,466 31,715,189 303,810
4
5
6
7Diesel176,827
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)
Year/Period of Report
End of 2019/Q4
Name of Respondent
Idaho Power Company
Date of Report
(Mo,Da,Yr)
04/14/2020
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)
LEpHe»NeS)undergrouncllines
report circuit miles)
Un Structure On StructuresofLineofAnother
Designated Line
Line Type of
Supporting
Structure
NumberNo.
Of
CircuitsOperatingFromToDesigned
%(a)(b)(c)(e)(d)(g)(h)
345.0C 62.35 1500.00 S TowerMidpoint1Borah
500.00 1.79 1500.00 S TowerSiatt2Boardman
1500.0C 500.00 S Tower 0.08Hemingway
Midpoint
3 Summer lake
1500.0C 500.00 S Tower 0.154Hemingway
1500.00 S Tower 53.07500.005SummerLakeHemingway
Midpoint 147.76500.00 500.00 S Tower6Hemingway
7
66.15 1345.0C 345.00 S TowerGoshen8JimBridger
2345.00 345.00 S Tower 76.069StateLineMidpoint
1345.00 345.00 S Tower 19.81Borah10Kinport
345.00 345.00 S Tower 60.93 1Populus11JimBridger
345.0C 345.00 S Tower 7.42 1Kinport12Populus
345.00 61.10 1345.00 S TowerPopulus
Borah
13 Jim Bridger
9.05 1345.0C 345.00 S Tower14Populus
7.48 1345.00 345.00 S Tower15GoshenKinport
51.07 1345.0C 345.00 H WoodBorah#116Midpoint
345.0C 345.00 H Wood 49.98 2Borah#217Midpoint
345.0C 345.00 H Wood 1.72 218AdelaideTapAdelaide
19
45.97 1230.00 230.00 H Wood20QuartzLaGrande
0.70 2230.00 230.00 S Tower21MidpointHunt
1230.00 230.00 H Wood 56.3822BradyAntelope
230.00 230.00 H Wood 0.08 123BradyTreasureton
230.0C 17.94 2230.00 S Tower24Brady#1 &#2 Kinport
72.67 1230.0C 230.00 S TowerOntario25Brownlee
1138.0C 230.00 S P Wood 9.9926MoraBowmont
138.00 230.00 H Wood 8.75 127MoraBowmont
230.00 SP Steel 18.50 1230.0028Caldwell710Locust
7.69 1230.00 230.00 S TowerCaldwell29BoiseBench
1230.0C 230.00 H Wood 33.4930BoiseBenchCaldwell
15.91230.0C 230.00 S Tower 231BoiseBenchCloverdale
230.0C 230.00 H Wood 1.67 1DalreedSub32Boardman
230.00 SP Steel 11.04 2230.00Oxbow33Brownlee714
30.06 1230.0C 230.00 H Wood34CaldwellOntario
3.14 1230.00 230.00 S TowerOntario35Caldwell
TOTAL 4,768.60 11.02 21136
Page 422FERCFORMNO.1 (ED.12-87)
Year/Period of Report
End of 2019/Q4
Name of Respondent
Idaho Power Company
This Report Is:
(1)[X|An Original
<2>n "
TRANSMISSION LINE STATISTICS (Continued)
Date of Report
(Mo,Da,Yr)
04/14/2020AResubmission
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 G)to (I)on the book cost at end ofyear.
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 Construction and
Other Costs
Total Cost Operation
Expenses
Maintenance
Expenses
Rents Total
Expenses
Land Line
No.(°)(P)(i)G)(k)(I)(m)(n)
1272 ACSR 116,048,838 16,305,219256,381
22X1780ACSR446,708446,708
31272ACSR
41272ACSR
3X1272 ACSR 18,865,237 18,865,237 5
63X1272ACSR17,078,077 17,078,077
7
81272ACSR5,806,242483,309 5,322,933
11,829,149 9795ACSR571,979 11,257,170
101272ACSR344,220 4,397,073 4,741,293
111272ACSR9,535,579 9,535,579
121272ACSR
131272ACSR9,261,147 9,261,147
141272ACSR
15585,4532X1272ACSR585,453
1614,537,211715.5 ACSR 283,143 14,254,068
64,851 14,986,458 17715.5 ACSR 14,921,607
18715.5 ACSR 51,448 224,249 275,697
19
207,074,370 7,136,588795ACSR62,218
211,008,383715.5 ACSR 9,145 999,238
3,567,921 221272ACSR108,301 3,459,620
23795ACSR6,186 6,186
24715.5 ACSR 18,825 1,144,918 1,163,747
2520,742,897 22,419,7352X954ACSR1,676,836
2,791,698 26715.5 ACSR 413,793 2,377,905
27715.5 ACSR
281590ACSR2,378,436 8,775,086 11,153,522
297,833,438 9,581,6401272ACSR1,748,202
30715.5 ACSR
9,642,189 311272ACSR3,062,812 6,579,377
32795AAC89,089 89,089
33954ACSR34,174 16,026,470 16,060,644
349,384,090 9,620,2422X954ACSR236,152
351272ACSR
7,525,410 950,539 3,934,696 12,410,645 3635,480,823 662,969,892 698,450,715
Page 423FERCFORMNO.1 (ED.12-87)
Year/Period of Report
End of 2019/Q4
Name of Respondent
Idaho Power Company
This Report Is:
(1)|x]An Original
(2)||A Resubmission
TRANSMISSION LINE STATISTICS
ate of Report
(Mo,Da,Yr)
04/14/2020
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)
(Indicate where
other than
60 cycle,3 phase)
DESIGNATION LENGTH (Pole miles
(In the Case,ofundergroundlines
report circuit miles)
Line Type of
Supporting
Structure
Number
No.Of
Un Structure Un Struct!
of Line of AnothDesignatedLine
ures CircuitsToOperatingDesignedFromer
(c)(a)(b)(e)(d)(h)(9)
14.39230.0C 230.00 SP Steel1BennettMtnPPRattlesnakeTS
68.12 1230.0C 230.00 H Steel2BorahHunt
36.25 1230.0C 230.00 H SteelHubbard3Danskin
1.84 1230.00 SP Steel230.004DanskinHubbard
2230.00 SP Steel 1.30230.005DanskinHubbard
15.39230.0C 230.00 SP Steel6DanskinBennettMtn
12.94 1230.00 230.00 SP Steel7HemingwayBowmont
14.19 1138.00 230.00 SP Steel8LangleyGulchGallowayRd
2.09 1138.00 230.00 SP Steel9GallowayRdWillisTap
1230.00 H Wood 31.67230.00Hurricane10WallaWalla
1230.00 S Tower 0.71230.0CMidpoint#111BoiseBench
1230.00 H Wood 108.67230.00Midpoint#112BoiseBench
1.51 1230.00 230.00 S Tower13BrownleeQuartzJet
41.30 1230.00 230.00 H WoodQuartzJet14Brownlee
99.78 2230.0C 230.00 S TowerBoiseBench#1 &#215Brownlee
10.38 2230.0C 230.00 S Tower16OxbowBrownlee
1230.00 S Tower 3.49230.0CMidpoint#217BoiseBench
1102.17230.00 230.00 H WoodMidpoint#218BoiseBench
220.11230.00 230.00 S Tower19OxbowPalletteJet
24.43 2230.00 230.00 H Wood20PalletteJetImnaha
9.05 2230.00 230.00 S Tower21HellsCanyonPaletteJet
102.11 2230.0C 230.00 S TowerBoiseBench22Brownlee
1106.29230.00 230.00 H WoodMidpoint#323BoiseBench
29.60 1230.0C 230.00 H WoodEnterprise24PaletteJet
0.42 1230.00 230.00 S TowerBrady#225Borah
1230.00 230.00 H Wood 3.52Brady#226Borah
13.84230.00 230.00 H WoodBrady#127Borah
28
40.89 1161.00 161.00 H WoodStateLine29Goshen
2161.00 161.00 S Tower 2.37Goshen30Don
2161.00 161.00 H Wood 48.4231DonGoshen
1161.00 161.00 H Wood 5.67Goshen32Antelope
161.00 "10.93 1161.00 H WoodStateLine33Goshen
161.OC 7.84 1161.00 H WoodStateLine34Goshen
35
TOTAL 4,768.60 11.02 21136
Page 422.1FERCFORMNO.1 (ED.12-87)
Year/Period of Report
End of 2019/Q4
Date of Report
(Mo,Da,Yr)
04/14/2020
This Report Is:
(1)|Xj An Original
(2)||A Resubmission
TRANSMISSION LINE STATISTICS (Continued)
Name of Respondent
Idaho Power Company
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 0)to (I)on the book cost at end of year.
COST OF LINE (Include in Column 0)Land,EXPENSES,EXCEPT DEPRECIATION AND TAXES
Land rights,and clearing right-of-way)Size of
Conductor
and Material Total
Expenses
RentsTotalCostOperation
Expenses
Maintenance
Expenses
Land Construction and
Other Costs
Line
No.(°)(P)(k)(I)(i)(J)(m)(n)
181,701 1,666,354 1,748,0551272ACSR
223,092,2381590ACSR624,917 22,467,321
315,210,56115,210,5611590ACSR
41590ACSR
51590ACSR
63,528,033 3,528,0331590ACSR
711,132,9761590ACSR1,854,996 9,277,980
810,015,775948,166 9,067,6091590ACSR
91272ACSR
106,611,933 6,611,9331272ACSR
1114,854,803 15,240,090715.5 ACSR 385,287
12715.5 ACSR
134,876,884 4,929,952795ACSR53,068
14795ACSR
159,489,377289,923 9,199,454VARIOUS
161,480,89814,810 1,466,0881272ACSR
17227,814 18,194,010 18,421,824715.5 ACSR
18VARIOUS
193,933,180 4,020,6481272ACSR87,468
204,438,835171,081 4,267,7541272ACSR
211,537,57244,687 1,492,8851272ACSR
226,411,734 6,596,539954ACSR184,805
238,140,906 8,388,752715.5 ACSR 247,846
241,927,018 2,011,0321272ACSR84,014
25539,0873,068 536,0191272ACSR
26715.5 ACSR
27427,228 434,4761272ACSR7,248
28
293,448,220375,576 3,072,644250COPPER
302,686,09188,204 2,597,887715.5 ACSR
31397.5 ACSR
32798,075397.5 ACSR 798,075
331,437,015116,873 1,320,142250COPPER
34673,58376,969 596,614250COPPER
35
3,934,696 12,410,645 367,525,410 950,539662,969,892 698,450,71535,480,823
Page 423.1FERCFORMNO.1 (ED.12-87)
Year/Period of Report
End of 2019/Q4
Name of Respondent
Idaho Power Company
This Report Is:
(1)[x]An Original
21JP"
TRANSMISSION LINE STATISTICS
Date of Report
(Mo,Da,Yr)
04/14/2020AResubmission
1 .Report information concerning transmission lines,cost of lines,and expenses for year.List each transmission line having nominal voltage of 1 32
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.
LENGTH (Pole mites)
(In the Case,ofuftdergrouncTlines
report circuit miles)
Un Structure Un Structu
of Line of AnotherDesignatedLine
WSiGnatiOn VOlTaGE (Kv)
(Indicate where
other than
60 cycle,3 phase)
Line Type of
Supporting
Structure
NumberNo,Of
mr;CircuitsFromToOperatingDesigned
(a)(b)(c)(e)(d)(h)<9>
14.07 2138.00 138.00 H Wood1AmericanFallsPowerPlantAdelaide
0.12 2138.00 138.00 S P Wood2AmericanFallsPowerPlantAdelaide
2138.00 138.00 S Tower 1.133MinidokaLoopAdelaide
2138.00 138.00 SP Wood 9.594NampaCaldwell
2138.00 138.00 S P Steel 0.895SkywayTap
154.38138.00 138.00 H Wood6UpperSalmonMountainHomeJet
30.81 1138.00 138.00 H Wood7UpperSalmonCliff
138.00 2.06 1138.00 S P Wood8EastgateRusset
2138.00 138.00 S Tower 1.019BradyFremont
2138.00 138.00 H Wood 24.3810BradyFremont
2138.00 138.00 S P Wood 24.3311BradyFremont
138.00 H Wood 84.73 2138.0012KingLowerMalad
66.46 2138.0C 138.00 H Wood13EmmettJctPayette
6.20 1138.0C 138.00 H Wood14MountainHomeAFBTap
1138.0C 138.00 H Wood 73.2015OntarioQuartz
2138.0C 138.00 S Tower 0.9116KingAmericanFallsPP
1138,0C 138.00 H Wood 142.1617KingAmericanFallsPP
1138,0C 138.00 S P Wood 3.7118KingAmericanFallsPP
6.19 1138.0C 138.00 H Wood19DuffinClawson
0.33 1138.00 138.00 H Wood20AmericanFallsBradyTie
1138.0C 138.00 H Wood 5.6621UpperSalmonA-B King
1138.0C 138.00 H Wood 125.5422UpperSalmonBWells
73.72138.0C 138.00 H Wood 123KingWoodRiver
9.80 1138.0C 138.00 S P Wood24ToponisPocket
10.37 2138.00 138.00 S P Wood25BoiseBenchGrove
1138.0C 138.00 H Wood 67.3026QuartzJohnDay
138.00 138.00 H Wood 2.79 127SinkerCreekTap
2.51 1138.00 138.00 H WoodCloverdale28Mora
22.26 1138.0C 138.00 S P WoodCloverdale29Mora
2138.0C 138.00 S P Steel 0.9630MoraCloverdale
138.0C 138.00 SP Steel 3.80 131StoddardJetStoddardSub
138.0C 138.00 H Wood 1.81 132FossilGulchTap
53.08 2138.00 138.00 H Wood33WoodRiverMidpoint
16.69 2138.00 138.00 SP Wood34WoodRiverMidpoint
37.15 1138.00 138.00 H WoodMcCall35Oxbow
TOTAL 2114,768.60 11.0236
Page 422.2FERCFORMNO.1 (ED.12-87)
Date of Report
(Mo,Da,Yr)
04/14/2020
Year/Period of Report
End of 2019/Q4
Name of Respondent
Idaho Power Company
This Report Is:
(1)[XjAn Original
(2)|—|AResubmi ssion
TRANSMISSION LINE STATISTICS (Continued)
7.Do not report the same transmission line structure twice.Report Lower voltage Lines and higher voltage lines as one line.Designate in a footnote if
you do not include Lower voltage lines with higher voltage lines.If two or more transmission line structures support lines of the same voltage,report the
pole miles of the primary structure in column (f)and the pole miles of the other line(s)in column (g)
8.Designate any transmission line or portion thereof for which the respondent is not the sole owner.If such property is leased from another company,
give name of lessor,date and terms of Lease,and amount of rent for year.For any transmission line other than a leased line,or portion thereof,for
which the respondent is not the sole owner but which the respondent operates or shares in the operation of,furnish a succinct statement explaining the
arrangement and giving particulars (details)of such matters as percent ownership by respondent in the line,name of co-owner,basis of sharing
expenses of the Line,and how the expenses borne by the respondent are accounted for,and accounts affected.Specify whether lessor,co-owner,or
other party is an associated company.
9.Designate any transmission line leased to another company and give name of Lessee,date and terms of lease,annual rent for year,and how
determined.Specify whether lessee is an associated company.
10.Base the plant cost figures called for in columns (j)to (I)on the book cost at end of year.
"COSTTJFuNe (Include in Column (j)Land,EXPENSES,EXCEPT DEPRECIATION AND TAXES
Land rights,and clearing right-of-way)Size of
Conductor
and Material Total Cost Operation
Expenses
Rents Total
Expenses
Land Construction and
Other Costs
Maintenance
Expenses
Line
No.(o)(P)(i)G)(k)(I)(m)(n)
1411,573250COPPER26,507 385,066
2250COPPER
3715.5 ACSR 21,327 249,232 270,559
4795AAC1,798,312 5,965,067 7,763,379
1272 ACSR 5
65,119,332795ACSR78,078 5,041,254
3,039,238 7795ACSR43,568 2,995,670
8795AAC270,823 561,561 832,384
5,275,244 9VARIOUS564,932 4,710,312
10VARIOUS
11VARIOUS
1276,823 3,744,888 3,821,711VARIOUS
134,719,777VARIOUS55,521 4,664,256
145,086 86,929397.5 ACSR 81,843
15VARIOUS34,426 6,921,520 6,955,946
16715.5 ACSR 216,919 11,229,578 11,446,497
17715.5 ACSR
18715.5 ACSR
19475,664 479,8554\0 4,191
2096,921954ACSR96,921
21250COPPER2,741 753,925 756,666
2228,490 4,905,542 4,934,032VARIOUS
23186,198 24,631,195 24,817,393VARIOUS
24397.5 ACSR
1,871,910 25VARIOUS225,602 1,646,308
2696,582 2,780,313 2,876,895397.5 ACSR
2711,083 133,347 144,430VARIOUS
2813,062,202715.5 ACSR 3,123,380 9,938,822
29VARIOUS
30795AAC
311272ACSR
3245C190,553 191,003250COPPER
8,936,362 33397.5 ACSR 349,712 8,586,650
34397.5 ACSR
141,534 2,886,748 35397.5 ACSR 2,745,214
3,934,696 12,410,645 36662,969,892 698,450,715 7,525,410 950,53935,480,823
Page 423.2FERCFORMNO.1 (ED.12-87)
Name of Respondent
Idaho Power Company
Date of Report
(Mo,Da,Yr)
04/14/2020
Year/Period of Report
End of 2019/Q4
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 1 32
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 ofwhich 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)
LEn^l|oTles)unoergrounolines
report circuit miles)
Un Structure Un structi
of Line of Anoth
Designated Li
Line Type of
Supporting
Structure
NumberNo,
Of
U'fc-s CircuitsFromToOperatingDesignedCi
neS5(a)(b)(c)(e)(d)(h)(Si)
1138.00 138.00 S P Wood 2.321OxbowMcCall
2138.0C 138.00 S P Wood 7.492LowellJetNampa
1138.0C 138.00 S P Wood 19.423HuntMilner
138.0C 138.00 H Wood 13.49 14StrikeBruneauBridge
138.00 S P Wood 18.46 2138.0C5AmericanFallsKramerSub
11.72 1138.00 138.00 S P Wood6PingreeHaven
2138.00 138.00 S P Wood 25.207MidpointTwin Falls
1138.00 138.00 SP Wood 1.718TwinFallsRussett
46.00 138.00 S P Wood 6.22 29BlackfootAiken
69.00 138.00 H Wood 57.03 110PetersonTendoy
138.00 138.00 SP Wood 6.36 111EastgateTapEastgate
138.00 1.84 2138.00 SP Steel12KimberlyTapKimberly
138.00 13.10 2138.00 H Wood13BoiseBenchMora
138.00 1138.00 SP Wood 0.51SimplotSub14Bowmont-Caldwell
1138.00 138.00 SP Wood 6.6515GaryLaneEagle
138.00 138.00 SP Steel 9.25 2.98 116LocustGroveBlackcatSub
138.0C 138.00 SP Wood 0.14 4.02 117BoiseBenchButler
138.00 SP Wood 6.75 1138.0CStar18Eagle
1138.00 138.00 SP Steel 5.5019StarLansing
1138.0C 138.00 S P Steel 3.5020KarcherSubZilogTap
138.00 138.00 S P Steel 1.50 121ZilogCanAda
138.00 138.00 S P Steel 0.42 4.02 122Cloverdale-712 712 -Wye
138.0C 138.00 S P Steel 1.89 123VictoryJetVictory
138.00 2.94 1138.00 S P Steel24ButlerWye
33.97 1138.0C 138.00 H Wood25HorseflatStarkey
138.00 138.00 S P Steel 2.23 226StarkeyMccall
138.0C 3.80 1138.00 H Wood27StarkeyMccall
1.50 1138.00 138.00 S P Steel28StarkeyMccall
138.00 138.00 S P Wood 17.61 129Starkey
30 Chestnut
Mccall
138.00 138.00 SP Steel 2.78 1HappyValley
138.0031GarnetWard
138.00 SP Wood 8.89 1138.00LakeFork32McCall
2.90 1138.00 138.00 S Steel33McCallLakeFork
1.30138.00 138.00 S P Steel 134CaldwellWillis
138.00 138.00 S P Steel 3.62 135CaldwellWillis
TOTAL 4,768.60 11.02 21136
Page 422.3FERCFORMNO.1 (ED.12-87)
Year/Period of Report
End of 2019/Q4
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)
04/14/2020
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.
DOST 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
Rents Total
Expenses
Land Construction and
Other Costs
Total Cost Maintenance
Expenses
Line
No.(o)(P)0)(I)(i)(k)(m)(n)
1397.5 ACSR
21,454,879715.5 ACSR 211,131 1,666,010
33,324 1,549,290 1,552,614715.5 ACSR
414,927 717,475 732,402397.5 ACSR
1,086,028 5715.5 ACSR 13,734 1,072,294
61,317,396397.5 ACSR 18,223 1,299,173
7VARIOUS66,286 3,212,160 3,278,446
8715.5 ACSR 16,790 213,033 229,823
913,616 584,098 597,714715.5 ACSR
10395,696 3,593,395 3,989,091397.5 ACSR
2,195,624 112,539,579715.5 ACSR 343,955
12795ACSR
13751,249715.5 ACSR 14,697 736,552
14795AAC50,319 50,319
15308,141 2,169,334 2,477,475795AAC
16935,810 3,749,932 4,685,7421272ACSR
1734,687 838,605 873,2921272ACSR
186,678,554 7,297,682715.5 ACSR 619,128
19795AAC
20716,559795AAC43,911 672,648
21795AAC
22140,412 2,577,075 2,717,4871272ACSR
231272ACSR
24134,471 1,539,907795ACSR1,405,436
252,473,833 19,006,561 21,480,394715.5 ACSR
26715.5 ACSR
27715.5 ACSR
28715.5 ACSR
29715.5 ACSR
3078,579 2,219,508 2,298,0871272ACSR
3140,580 40,580
325,014,418715.5 ACSR 331,539 4,682,879
33715.5 ACSR
34827,220 5,879,563 6,706,7831272ACSR
35795ACSR
3,934,696 12,410,645 36662,969,892 698,450,715 7,525,410 950,53935,480,823
Page 423.3FERCFORMNO.1 (ED.12-87)
Date of Report
(Mo,Da,Yr)
04/14/2020
Year/Period of Report
End of 2019/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 1 32
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
LENGTH (Pole miles)
(In (he tase,ofundergroundlines
report circuit mites)
Un Structure
Designated
Line Type of
Supporting
Structure
Number
Of
Circuits
Line
No.
60 cycle.3 phase)
OperatingFromTo Designed
(a)(b)(c)(e)(d)(9)(h)
1138.00 SP Wood 0.87138.001CaldwellWillis
138.00 3.23 2138.00 Verious2WillisLansing
138.00 0.79 2138.00 S P Steel3ValivueTap
1138.00 138.00 S P Steel 8.654BowmontHappyValley
1138.00 138.00 H Wood 0.12Scovllle5Antelope
1138.00 138.00 H Wood 1.056AmericanFallsWheelon
138.00 S Tower 1.27 2138.007KinportDon#1
138.00 SP Steel 2.69 1138.00HOKU8Donn
0.22 2138.00 138.00 S P Steel9HOKUAlamed
0.23 2138.00 138.00 S P Steel10HOKUAlamed
1138,00 138.00 S P Steel 2.8511HOKUAlamed
1138.0C 138.00 S P Steel 0.8512Eldridgetap
138.0C 138.00 S P Steel 5.18 113RocklandJetRocklandWindFarm
0.07 1138.0C 138.00 S P Wood14KingJustice
138.0C 6.17 1138.00 S P Wood15NorthViewTap
0.99 1138.00 138.00 H Wood16Twin Falls PPTap
0.37 1138.0C 138.00 S P SteelAmercianFallsTransST17AmericanFallsPP
1138.0C 138.00 H Wood 0.1118LowerSalmonKingTie
138.0C 138.00 S Tower 4.30 219CJStrikeStrikeJet
138.00 H Wood 23.42 1138.0C20StrikeJetMountainHomeJet
0.05 1138.00 H Wood21StrikeJetBowmont
0.36 1138.0C 138.00 S Tower22StrikeJetBowmont
1138.0C 138.00 H Wood 67.8723StrikeJetBowmont
138.0C 138.00 H Wood 4.48 2LuckyPeakJet24LuckyPeak
10.51 1138.00 138.00 H WoodKing25Bliss
1.30 1138.0C 138.00 SP Wood26MilnerDeadendMilnerPP
1138.00 138.00 H Wood 0.9527SwanFallsTap
28
29
30
1115.00 115.00 H Wood 3.35BPA(Harney)31 Hines
32
33
69.00 69.00 H Wood 205.81 13469KvLines
69.00 878.80 169.00 S P Wood3569KvLines
TOTAL 4,768.60 11.02 21136
Page 422.4FERCFORMNO.1 (ED.12-87)
Date of Report
(Mo,Da,Yr)
04/14/2020
Year/Period of Report
End of 2019/Q4
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.
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,
Land rights,and clearing right-of-way)
EXPENSES,EXCEPT DEPRECIATION AND TAXES
Size of
Conductor
and Material Rents Total
Expenses
Total Cost Operation
Expenses
Maintenance
Expenses
Land Construction and
Other Costs
Line
No.(o)(P)(k)(I)(i)0)(n)(m)
1795ACSR
2795ACSR
3351,497351,497795ACSR
46,737,014691,728 6,045,2861272ACSR
594,004 94,004397.5 ACSR
6105,684 105,684250COPPER
7274,449715.5 ACSR 1,174 273,275
8320,323 2,188,419 2,508,7421272ACSR
91272ACSR
10795ACSR
11795ACSR
12795ACSR
13-16,973 -16,973795ACSR
1460,6591590ACSR60,659
154,230,987105,933 4,125,054715.5 ACSR
1663,3225663,264250COPPER
17176,736176,736715.5 ACSR
184,4064,406397.5 ACSR
191,074 636,545 637,619715.5 ACSR
202,566,179 2,572,5116,332397.5 ACSR
2186,651 4,902,9804,816,329715.5 ACSR
22715.5 ACSR
23715.5 ACSR
24287,676 287,683715.5 ACSR 7
251,733,914 1,739,5345,620715.5 ACSR
26198,57414,968 183,606715.5 ACSR
27261,512 278,719397.5 ACSR 17,207
28
29
30
3168,8121,978 70,790397.5 ACSR
32
33
3489,169,178 90,984,7161,815,538VARIOUS
35VARIOUS
3,934,696 12,410,645 367,525,410 950,539662,969,892 698,450,71535,480,823
Page 423.4FERCFORMNO.1 (ED.12-87)
Date of Report
(Mo,Da,Vr)
04/14/2020
Year/Period of Report
End of 2019/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.
VOLTAGE W)
(Indicate where
other than
60 cycle.3 phase)
DESIGNATION LENGTH (Pole miies)
(In the case.ofundergroundlines
report circuit miles)
Un0~re |USfWreS|Circuits
Desiunaled Line
Line Type of
Supporting
Structure
Number
No.Of
From To Operating Designed
1(c)(a)(b)(e)(d)(9)(h)
1
2
46.00 146.00 S P Wood 377.97346KvLines
4
2114,768.60 11.025Totalalllines
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
TOTAL 4,768.60 11.02 21136
Page 422.5FERCFORMNO.1 (ED.12-87)
Date of Report
(Mo,Da,Yr)
04/14/2020
Year/Period of Report
End of 2019/Q4
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.
10.Base the plant cost figures called for in columns (j)to (I)on the book cost at end of year.
Dost 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
Expenses
Operation
Expenses
RentsLandConstructionand
Other Costs
Total Cost Maintenance
Expenses
Line
No.(o)(P)(k)(I)(i)G)(m)(n)
1
2
3VARIOUS196,503 21,147,803 21,344,306
12,410,645 43,934,6967,525,410 950,539
698,450,715 12,410,645 535,480,823 662,969,892 7,525,410 950,539 3,934,696
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
3,934,696 12,410,645 36698,450,715 7,525,410 950,53935,480,823 662,969,892
Page 423.5FERCFORMNO.1 (ED.12-87)
Date of Report Year/Period of Report
(Mo,Da,Yr)
04/14/2020
Name of Respondent This Report is:
(1)X An Original
(2)_A Resubmission 2019/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 Line No.:2 Column:b
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 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.:6 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.: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:J>
This line is jointly owned with PacifiCorp and Idaho Power owns 29.2%of this 47.3 mile
line .
ISchedulePage: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.
Schedule Page:422 Line No.:32 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.:10 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.:29 Column:b
FERC FORM NO.1 (ED.12-87)Page 450.1
Date of Report Year/Period of Report
(Mo,Da,Yr)
04/14/2020
This Report is:Name of Respondent
(1)X An Original
(2)_A Resubmission 2019/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.:32 Column:b
This line is jointly owned with PacifiCorp and Idaho Power owns 21.9%of this 25.8 mile
line .
Schedule Page:422.1 Line No.:33 Column:b
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 4 0.9 mile segment. _
Schedule Page:422.1 Line No.:34 Column:b
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:422.4 Line No.:5 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.:6 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
Year/Period of Report
End of 2019/Q4
Date of Report
(Mo,Da,Yr)
04/14/2020
Name of Respondent
Idaho Power Company
This Report Is:
(1)[X]An Original
(2)|—|A Resubmission
TRANSMISSION LINES ADDED DURING YEAR
1 .Report below the information called for concerning Transmission lines added or altered during the year.It is not necessary to report
minor revisions of lines.
2.Provide separate subheadings for overhead and under-ground construction and show each transmission line separately.If actual
costs of competed construction are not readily available for reporting columns (I)to (o), it is permissible to report in these columns the
CIRCUITS PER STRUCTURELine
Length
in
Miles
SUPPORTING STRUCTURElinPdesignationLine
Average
Number per
Miles
No.UltimatePresentTypeFromTo
(g)(e)(f)(c)(d)(a)(b)
0.85 steel LD 213.60 t1EldridgetapEldridge
0.89 steel LD 2218.702SkywaytapSkyway
3.23 various 2 218.89Lansing3Willis
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
4.97 51.19 5 6TOTAL44
Page 424FERCFORMNO.1 (REV.12-03)
Year/Period of Report
End of 2019/Q4
Date of Report
(Mo.Da,Yr)
04/14/2020
Name of Respondent
Idaho Power Company
This Report Is:
(1)[Xj An Original
(2)[—]A Resubmission
TRANSMISSION LINES ADDED DURING YEAR (Continued)
costs.Designate,however,if estimated amounts are reported.Include costs of Clearing Land and Rights-of-Way,and Roads and
Trails,in column (I)with appropriate footnote,and costs of Underground Conduit in column (m).
3.If design voltage differs from operating voltage,indicate such fact by footnote;also where line is other than 60 cycle,3 phase,
indicate such other characteristic.
TTNFCOSTCONDUCTORS LineVoltage
Size Poles,Towers
and Fixtures
Conductors
and Devices
Asset
Retire.Costs
No.TotalConfiguration
and Spacing
Land and
Land Rights
Specification KV
(Operating)
(o)(P)M.(n)(h)ill (i)(k)(I)
2.307,702 11,035,167 539,141 733,394795TemTVS-DC 138
2,495,527 21,203,491 972,0031272TVS-DC 138 320,133Bittern
4,293,334 31,714,257TAS&TVS 138 554,989 2,024,086795Tern
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
9,096,6633,766,720 3,419,6541,910,289 44
Page 425FERCFORMNO.1 (REV.12-03)
This Page Intentionally Left Blank
Date of Report Year/Period of Report
(Mo,Da,Yr)
04/14/2020
This Report is:
(1)X An Original
(2)_A Resubmission
Name of Respondent
2019/Q4IdahoPowerCompany
FOOTNOTE DATA
Schedule Page:424 Line No.:1 Column:o
Estimated amounts are reported
Schedule Page:424 Line No.:2 Column:o
Estimated amounts are reported
Schedule Page:424 Line No.:3 Column:o
Estimated amounts are reported
FERC FORM NO.1 (ED.12-87)Page 450.1
This Report Is:
(1)[x]An Original
(2)[[A Resubmission
SUBSTATIONS
Year/Period of Report
End of 2019/Q4
Date of Report
(Mo,Da,Yr)
04/14/2020
Name of Respondent
Idaho Power Company
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.Secondary TertiaryPrimary
(d)(e)(a)(b)(c)
138.00 13.80345.001Adelaidetransmission
46.00 13.002Aikendistribution
13.003Alamedadistribution138.00
13.09distribution138.004Alameda
138.00 13.805AmericanFallsPP-attended transmission
138.00 46.00 12.476AmericanFallstransmission
161.00 13.80230.007Antelopetransmission
13.00distribution46.008Artesian
46.00 13.009BannockCreekdistribution
230.00 18.0010BennettMountainPowerPlant-attended transmission
18.00 4.1611BennettMountainPowerPlant-attended distribution
13.0012BethelCourtdistribution138.00
13 Big Grassy 161.00transmission
138.00 13.0914BlackCatdistribution
138.00 13.0015BlackMesadistribution
46.00 13.0016Blackfootdistribution
161.00 46.00 12.4717Blackfoottransmission
138.00 12.98distribution161.0018Blackfoot
13.80138.0019Bliss-attended transmission
138.00 35.0020BlueGulchdistribution
230.00 138.00 13.2021BoiseBenchtransmission
138.00 35.0022BoiseBenchdistribution
138.00 69.00 12.98transmission23BoiseBench
138.00 13.80230.0024BoiseBenchtransmission
13.00distribution138.0025Boise
26 Borah 345.00 230.00 13.80transmission
138.00 13.00distribution27Border
distribution 35.0028Border
distribution 138.00 35.0029Bowmont
138.00 69.00 12.9830Bowmonttransmission
138.00 69.00 12.47transmission31Bowmont
138.00230.00 13.8032Bowmonttransmission
230.00 138.00 13.8033Bradytransmission
138.00 46.00 12.47transmission34Brady
46.00 13.00distribution35Brady
7.20distribution46.0036Brady
230.00 13.8037Brownlee-attended transmission
138.00 35.0038BruneauBridgedistribution
36.20138.0039BruneauBridge
40 Buckhorn
distribution
69.00 35.00distribution
Page 426FERCFORMNO.1 (ED.12-96)
This Report !s:Date of Report
(Mo,Da,Yr)
04/14/2020
Year/Period of Report
End of 2019/Q4
Name of Respondent
Idaho Power Company a(1)An Original
(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
0)(k)M M 01
15002
2272
3301
4301
51120
6471
72501
8141
9114
102251
1151
12281
13
14902
15111
16562
179331
181351
19863
20248
214482
22702
231253
244482
253117
2617503
27111
2835
29130
30461
31471
322600
333123
341
352814
362
3717525
38130
39451
40371
Page 427FERCFORMNO.1 (ED.12-96)
This Report Is:
(1)fx]An Original
(2)|[A Resubmission
Year/Period of Report
End of 2019/Q4
Date of Report
(Mo,Da,Yr)
04/14/2020
Name of Respondent
Idaho Power Company
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
Character of SubstationNameandLocationofSubstationNo.SecondaryPrimary Tertiary
(d)(e)(b)(c)(a)
46.00 13.20Buhldistribution1
69.00 13.00distribution2BurleyRural
13.09distribution69.003BurleyRural
138.00 13.094Butlerdistribution
138.00 13.005Caldwelldistribution
230.00 138.006Caldwelltransmission
13.09distribution138.007Caldwell
12.47138.00 69.008Caldwelltransmission
12.47230.00 138.009Caldwelltransmission
35.00distribution10Camas
14.40distribution35.0011Camas
13.09distribution138.0012Can-Ada
138.00 36.2013CanyonCreekdistribution
12.98138.00 69.0014CanyonCreektransmission
138.00 13.00distribution15Cartwright
69.00 4.6016CascadePowerPlant-attended transmission
13.00distribution69.0017Cascade
69.00 13.1018Cascadedistribution
25.0019Cascadedistribution
138.00 13.0020Chestnutdistribution
138.00 13.09distribution21Chestnut
46.00 13.00distribution22Cinder
46.00 2.4023ClearLake-attended transmission
46.00 12.50138.0024Clifftransmission
12.95138.00 46.0025Clifftransmission
138.00 13.00distribution26Cloverdale
138.00 13.09distribution27Cloverdale
13.0069.0028Councildistribution
69.00 13.0029CraneCreekdistribution
46.00 13.00distribution30Crater
46.00 4.60distributionDale31
46.00 13.00distribution32Dale
69.00 13.00distribution33Dale
138.00 36.20distribution34Dale
138.00 46.00 12.47transmission35Dale
18.00230.0036Danskin-attended transmission
138.00 13.80230.00transmission37Danskin-attended
18.00 4.16distribution38Danskin-attended
138.00 12.00transmission39Danskin-attended
35.00 13.80distribution40Danskin-attended
Page 426.1FERCFORMNO.1 (ED.12-96)
This Report Is:
X]An Original
[A Resubmission
SUBSTATIONS (Continued)
Name of Respondent
Idaho Power Company
Date of Report
(Mo,Da,Yr)
04/14/2020
Year/Period of Report
End of 2019/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 EQUIPMENT LineCapacityofSubstation
(In Service)(In MVa)Total Capacity
(In MVa)
No.Type of Equipment Number of Units
(k)(!)iii(f)M (h)
11
21
3301
4902
5281
61225
7451
81403
92001
10153
111031
12451
13451
14120
15111
16161
1771
18141
1915
20451
21145
22111
2315
242121
25101
26451
27451
28141
29111
30111
311
327
331
34145
35471
362331
371300
3816
392160
4051
Page 427.1FERCFORMNO.1 (ED.12-96)
This Report Is:
(1)[X]An Original
(2)[~]A Resubmission
SUBSTATIONS
Date of Report
(Mo,Da,Yr)
04/14/2020
Year/Period of Report
End of 2019/Q4
Name of Respondent
Idaho Power Company
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.TertiarySecondaryPrimary
(e)(c)(d)(a)(b)
46.00 13.00distribution1Deen
46.00 13.09distribution2Dietrich
7.60138.00distribution3Don
138.00 13.20distribution4Don
138.00 13.00distributionDon5
13.09138.00distribution6DRAM
138.00 13.80230.00transmission7DRAM
138.00 12.47distribution8DRAM
138.00 13.00distribution9DRAM
138.00 35.00distribution10Duffin
13.09138.00distribution11Eagle
138.00distribution12Eastgate
138.00 13.00distribution13Eastgate
138.00 36.20distribution14Eckert
138.00 36.20distribution15Eden
46.00 12.98138.00transmission16Eden
13.09138.00distribution17Eldredge
12.47138.00distribution18Elkhorn
138.00 13.00distribution19Elkhorn
138.00 35.00distributionElmore20
138.00 69.00 12.50transmission21Elmore
69.00 12.98138.00transmission22Elmore
138.00distribution23Emmett
12.47138.00 69.00transmission24Emmett
46.00 13.00distributionFalls25
46.00 13.00distribution26Filer
13.00distribution46.0027FlatTop
69.00 2.40distribution28FlyingH
46.00 13.00distribution29FortHall
138.00 35.00distribution30FossilGulch
46.00 12.50138.00transmission31Fremont
138.00 13.09distribution32Gary
138.00 13.00distribution33Gary
13.00distribution69.0034Gem
distribution 69.0035Gem
138.00 13.00distribution36GlennsFerry
46.00 13.00distribution37GoodingRural
69.00 13.00distribution38GoldenValley
345.00 161.00 69.0039Goshentransmission
138.00 35.00distribution40GowenSubstation
Page 426.2FERCFORMNO.1 (ED.12-96)
Name of Respondent
Idaho Power Company
This Report Is:
(1)[X]An Original
(2)| |A Resubmission
SUBSTATIONS (Continued)
Year/Period of Report
End of 2019/Q4
Date of Report
(Mo,Da,Yr)
04/14/2020
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
No.Total Capacity
(In MVa)
Type of Equipment Number of Units
(k)(f)M (h)(i)ill
1111
2141
31
418061
5441
61686
72122
8281
9281
10602
11672
12145
13301
14301
15451
16201
17451
18111
19111
20281
21251
22201
23451
24471
25282
26141
27172
28202
291411
30281
316731
32371
33281
341412
35141
36111
37202
381141
399084
40451
Page 427.2FERCFORMNO.1 (ED.12-96)
This Report Is:
(1)fx]An Original
(2)|]A Resubmission
SUBSTATIONS
Date of Report
(Mo,Da,Yr)
04/14/2020
Year/Period of Report
End of 2019/Q4
Name of Respondent
Idaho Power Company
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
(c)(d)(e)(a)(b)
Grindstone distribution 35.001
2.4035.002Grindstonedistribution
138.00 13.093Grovedistribution
13.004Grovedistribution138.00
13.00distribution46.005Hagerman
69.00 13.006Hagermandistribution
138.00 13.00distribution7Hailey
13.09distribution138.008HappyValley
35.00distribution138.009Haven
138.00 46.0010Haventransmission
500.00 230.00 34.5011Hemingwaytransmission
138.00 13.00distribution12HewlettPackard
13.0013HiddenSpringsdistribution138.00
13.00distribution138.0014Highland
13.00distribution138.0015Hill
138.0016Hillsdaledistribution
69.00 13.00distribution17Homedale
230.00 138.00 13.8018HorseFlattransmission
distribution 35.0019HorseshoeBend
36.20distribution69.0020HorseshoeBend
69.00 25.0021HorseshoeBenddistribution
69.00 13.00distribution22Huston
46.00 13.00distribution23Hulen
230.00 138.00 13.8024Hunttransmission
36.20distribution138.0025Hydra
13.0069.00distribution26Island
161.00transmission27Jefferson
138.00 13.00distribution28Jerome
13.09distribution138.0029Jerome
138.00 35.0030JulionClawsondistribution
138.00 13.00distribution31Joplin
138.00 36.20distribution32Joplin
138.00 13.80230.00transmission33Justice
138.00 13.00distribution34Karcher
69.00 13.00distribution35Kenyon
138.00 13.00distribution36Ketchum
13.09distribution138.0037Kimberly
46.00161.00 13.20transmission38Kinport
230.00 138.00 12.47transmission39Kinport
230.00 138.00 13.80transmission40Kinport
Page 426.3FERCFORMNO.1 (ED.12-96)
This Report Is:
[X]An Original
Year/Period of Report
End of 2019/Q4
Name of Respondent
Idaho Power Company
Date of Report
(Mo,Da,Yr)
04/14/2020
(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
(k)M 11 (j)
171
271
3902
4451
5141
661
7371
8301
9201
10471
11100031
12137
13111
14301
15732
16451
17234
181001
1971
20221
2117
22141
23114
243363
25902
26201
27
28137
29371
30562
31128
32451
333001
34201
35225
36752
37451
387
393001
403001
Page 427.3FERCFORMNO.1 (ED.12-96)
Name of Respondent
Idaho Power Company
This Report Is:
(1)[X]An Original
(2)| |A Resubmission
SUBSTATIONS
Year/Period of Report
End of 2019/Q4
Date of Report
(Mo.Da,Yr)
04/14/2020
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
(d)(e)(a)(b)(c)
1 Kinport 230.00 13.80345.00transmission
2 Kramer 138.00 35.00distribution
138.00 36.203Kramerdistribution
13.094Kunadistribution138.00
Lake distribution 69.00 13.005
6 Lake Fork 138.00 36.20distribution
138.00 69.00 12.507LakeForktransmission
13.008Lambdistribution138.00
13.809LangleyGulch-attended 230.00 138.00transmission
1 0 Langley Gulch-attended 230.00transmission
1 1 Langley Gulch-attended 230.00 150.00transmission
13.0912Lansingdistribution138.00
13.0913Lincolndistribution138.00
14 Linden distribution 138.00 13.00
15 Locust 138.00 36.20distribution
230.00 138.00 13.8016Locusttransmission
138.00 7.2017LowerMalad-attended transmission
18 Lower Salmon -attended 13.80transmission138.00
13.0919MapRockdistribution69.00
20 McCall distribution 138.00 13.09
McCall distribution 138.00 36.2021
69.00 13.0022Melbadistribution
138.00 13.0023Meridiandistribution
13.0924Microndistribution138.00
distribution 138.00 13.0025Micron
230.00 138.00 13.8026Midpointtransmission
345.00 230.00 13.8027Midpointtransmission
345.0028Midpointtransmission500.00
distribution 138.00 13.0929Midrose
138.00 69.00 12.4730Milnertransmission
69.00 46.00 6.9031Milnerdistribution
35.00distribution138.0032Milner
138.00 13.8033MilnerPP-attended transmission
distribution 138.00 35.0034Moonstone
138.00 13.0935Moradistribution
36.2036Moradistribution138.00
37 Moreland distribution 46.00 13.00
distribution 69.00 13.0038MountainHome
distribution 69.00 13.0039MountainHomeAirForceBase
distribution 138.00 13.0040MountainHomeAirForceBase
Page 426.4FERCFORMNO.1 (ED.12-96)
Date of Report
(Mo,Da,Yr)
04/14/2020
This Report is:
(1)|X|An Original
(2)| |A Resubmission
SUBSTATIONS (Continued)
Year/Period of Report
End of 2019/Q4
Name of Respondent
Idaho Power Company
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)
1100031
2201
3301
4145
5141
6301
7201
8130
96362
104102
111
12451
13141
14582
151343
166002
17161
18704
T<r114
20221
21301
22111
23602
24402
25402
262001
27140021
28150031
29145
3011253
31831
32250
33160
34201
35451
36451
37282
38281
391
40341
Page 427.4FERCFORMNO.1 (ED.12-96)
This Report Is:
(1)fx]An Original
(2)—A Resubmission
Year/Period of Report
End of 2019/Q4
Name of Respondent
Idaho Power Company
Date of Report
{Mo.Da,Yr)
04/14/2020
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
(d)(e)(a)(b)(c)
13.801Nampa230.00 138.00transmission
2 Nampa 138.00 13.00distribution
36.203NewMeadowsdistribution138.00
4 New Plymouth distribution 69.00 13.00
5 Northview distribution 138.00
6 Notch Butte 138.00 13.09distribution
7 Orchard 36.20distribution69.00
8 Orchard distribution 69.00
9 Parma distribution 69.00 13.00
69.00 35.0010Parmadistribution
138.00 35.0011Pauldistribution
36.2012Pauldistribution138.00
13 Payette distribution 138.00
14 Pingree 138.00 46.00 12.50transmission
138.00 35.0015Pingreedistribution
138.00 35.0016PleasantValleydistribution
138.00 36.2017PleasantValleydistribution
13.0018Pocatellodistribution46.00
19 Pocket distribution 138.00 36.20
20 Poleline distribution 138.00 13.09
345.0021Populustransmission
Portneuf 138.00 35.0022distribution
Portneuf 46.00 35.0023distribution
24 Rockford distribution 46.00 13.00
25 Russett distribution 138.00 13.00
26 Sailor Creek distribution 138.00 2.40
27 Sailor Creek 138.00 35.00distribution
28 Salmon distribution 69.00 13.00
12.4729Salmondistribution69.00 34.50
30 Salmon 69.00 7.20distribution
46.00 13.0931Shoshonedistribution
32 Shoshone distribution 46.00 7.20
33 Shoshone Falls -attended 46.00 4.16transmission
46.00 6.6034ShoshoneFalls-attended transmission
138.0035Silverdistribution 35.00
36 Simplot distribution 138.00 13.00
37 Sinker Creek distribution 138.00 35.00
38 Siphon distribution 138.00 35.00
distribution 138.00 13.0939Skyway
distribution 46.00 13.0040SouthPark
Page 426.5FERCFORMNO.1 (ED.12-96)
This Report Is:
r
Date of Report
(Mo.Da,Yr)
04/14/2020
Year/Period of Report
End of 2019/Q4
Name of Respondent
Idaho Power Company (1)An Original
(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
Total Capacity
(In MVa)
No.(In Service)(In MVa)Type of Equipment Number of Units
(iimialMiil
13001
2873
3221
4131
5451
6141
781
8331
9141
10122
113011
12451
13451
14673
15342
16301
17451
18602
19451
20301
21
22301
231
24252
25301
26212
27281
281414
291031
301
31141
3223
331
34141
35201
36532
37201
38255
39145
40141
Page 427.5FERCFORMNO.1 (ED.12-96)
This Report Is:
(1)|X]An Original
(2)|A Resubmission
SUBSTATIONS
Year/Period of Report
End of 2019/Q4
Name of Respondent
Idaho Power Company
Date of Report
(Mo,Da,Yr)
04/14/2020
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.Secondary TertiaryPrimary
(c)(d)(e)(a)(b)
1 Spring Valley 12.47distribution138.00
2 Star distribution 138.00 13.09
3 Starkey 138.00 69.00 12.47transmission
4 State 69.00 13.00distribution
5 Sterling distribution 46.00 13.00
6 Stoddard distribution 138.00 13.00
7 Strike Power Plant -attended 138.00 13.80transmission
8 Sugar 35.00distribution138.00
9 Swan Falls -attended 138.00 6.90transmission
10 Taber distribution 46.00 13.00
11 Tamarack distribution 138.00 2.40
138.00 13.0912TenMiledistribution
13.0913Terrydistribution138.00
14 Terry distribution 138.00 13.00
15 Thousand Springs -attended 46.00 7.20transmission
16 Three Mile Knoll 345.00transmission
distribution 138.00 33.0017Toponis
138.00 13.0918TwinFallsdistribution
46.00 12.9819TwinFallstransmission138.00
20 Twin Falls PP -attended transmission 138.00 7.20
21 Twin Falls PP -attended 138.00 13.20transmission
22 Tyhee distribution 46.00 13.00
45.00 7.2023UpperMalad-attended transmission
138.00 7.2024UpperSalmon-attended transmission
13.0025Ustickdistribution138.00
26 Vallivue distribution 138.00 13.09
distribution 138.00 13.0027Victory
138.00 13.0928Victorydistribution
13.0029Waredistribution69.00
distribution 69.00 13.0030Weiser
138.00 69.00 12.4731Weisertransmission
69.00 13.0032Wilderdistribution
33 Willis distribution 138.00 13.09
34 Willow Creek distribution 138.00 13.00
distribution 138.00 13.0035Wye
138.00 13.0936Wyedistribution
13.0937Zilogdistribution138.00
38
39
40 The above are all State of Idaho
Page 426.6FERCFORMNO.1 (ED.12-96)
This Report Is:
(1)fx]An Original
Name of Respondent
Idaho Power Company
Date of Report
(Mo,Da,Yr)
04/14/2020
Year/Period of Report
End of 2019/Q4
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)(g)(h)(j)(k)0)
1111
2301
3301
4582
5112
6281
71043
8282
9341
1061
11111
12902
13201
14502
1581
16
17301
18822
19502
20131
21721
22141
2381
24424
25772
26301
27451
28301
292011
302821
31421
32141
33301
34111
35602
36371
37451
38
39
40
Page 427.6FERCFORMNO.1 (ED.12-96)
This Report Is:
[X]An Original
Name of Respondent
Idaho Power Company
Date of Report
(Mo,Da,Yr)
04/14/2020
Year/Period of Report
End of 2019/Q4(1)
(2)|A Resubmission
SUBSTATIONS
1 .Report below the information called for concerning substations of the respondent as of the end of the year.
2.Substations which serve only one industrial or street railway customer should not be listed below.
3.Substations with capacities of Less than 10 MVa except those serving customers with energy for resale,may be grouped according
to functional character,but the number of such substations must be shown.
4.Indicate in column (b)the functional character of each substation,designating whether transmission or distribution and whether
attended or unattended.At the end of the page,summarize according to function the capacities reported for the individual stations in
column (f).
VOLTAGE (In MVa)Line
Name and Location of Substation Character of SubstationNo.Primary Secondary Tertiary
(a)(b)(c)(d)(e)
1
2 Montana:
3 Mill Creek transmission 230.00
4 Peterson 230.00 69.00 13.20transmission
5
6 Nevada:
7 Valmy -attended transmission 345.00 18.00
8 Wells 138.00 69.00 13.00transmission
9
10 Oregon:
11 Adrian distribution 69.00 13.00
12 Boardman -attended transmission 500.00 24.00
1 3 Boardman -attended 230.00 7.20transmission
1 4 Boardman -attended 24.00 7.20transmission
15 Bums transmission 500.00
16 Cairo distribution 69.00 13.00
17 Hells Canyon -attended transmission 230.00 13.80
18 Hells Canyon -attended distribution 69.00 0.50
19 Hines 138.00 115.00 12.47transmission
20 Hurricane 230.00transmission
21 Jacobson Gulch distribution 2.4069.00
22 Malheur Butte distribution 69.00 34.50
23 Nyssa distribution 69.00 13.00
24 Ontario distribution 138.00 13.00
25 Ontario 138.00 69.00 12.47transmission
26 Ontario 13.80transmission230.00 138.00
27 Ontario transmission 138.00 69.00 12.98
28 Ontario transmission 138.00 69.00 13.09
29 Ontario 138.00 69.00 12.50transmission
30 Ore-Ida distribution 69.00 13.00
31 Oxbow -attended transmission 138.00 69.00 13.00
32 Oxbow -attended 230.00 13.80transmission
33 Oxbow -attended 230.00 138.00 13.80transmission
34 Quartz transmission 138.00 69.00 12.50
35 Quartz transmission 230.00 138.00 12.98
36 Quartz 138.00 69.00 12.98transmission
37 Summer Lake 500.00transmission
38 Vale distribution 69.00 13.00
39
40 Washington:
Page 426.7FERCFORMNO.1 (ED.12-96)
Name of Respondent
Idaho Power Company
This Report Is:
[X]An Original
Date of Report
(Mo,Da,Yr)
04/14/2020
Year/Period of Report
End of 2019/Q4(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 EQUIPMENTCapacityofSubstation Line
Total Capacity
(In MVa)
No.(In Service)(In MVa)Type of Equipment Number of Units
(f)M (h)iii (k)
1
3
43031
5
6
73151
82531
9
10
11111
126853
13155
14551
15
16201
175603
1811
19501
20
21111
221131
23282
246721
25471
264002
27932
281
191
30281
311331
322742
331001
34251
3516731
36201
37
38141
39
40
Page 427.7FERCFORMNO.1 (ED.12-96)
This Report Is:
(1)|x]An Original
(2)[|A Resubmission
SUBSTATIONS
Name of Respondent
Idaho Power Company
ate of Report
(Mo,Da,Yr)
04/14/2020
Year/Period of Report
End of 2019/Q4
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
(d)(e)(a)(b)(c)
1 Walla Walla 230.00transmission
2
3 Wyoming:
22.00 34.504JimBridget-attended transmission 345.00
5
6
7
8
9
10 Transformers-distribution substations under 10,000
11 KVA 61 unattended.
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
Page 426.8FERCFORMNO.1 (ED.12-96)
This Report Is:
(1)[x]An Original
(2)A Resubmission
Year/Period of Report
End of 2019/Q4
Date of Report
(Mo,Da,Yr)
04/14/2020
Name of Respondent
Idaho Power Company
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
Spare
Transformers
Number of
Transformers
In Service
CONVERSION APPARATUS AND SPECIAL EQUIPMENT LineCapacityofSubstation
(In Service)(In MVa)No.Total Capacity
(In MVa)
Type of Equipment Number of Units
(k)ill(i)if!M (h)
1
2
3
422444
5
6
7
8
9
10
11214
12
13
14
T§~
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
Page 427.8FERCFORMNO.1 (ED.12-96)
Date of Report Year/Period of Report
(Mo,Da,Yr)
04/14/2020
Name of Respondent This Report is:
(1)X An Original
(2)_A Resubmission 2019/Q4IdahoPowerCompany
FOOTNOTE DATA
Schedule Page:426 Line No.:1 Column:a
PacifiCorp has an ownership interest in certain high-voltage transmission related and
interconnection eguipment located at Idaho Power's Adelaide station.Ownership interest
varies by terminal.100%of the capacity is reported.
Schedule Page:426 Line No.:1 Column:f
For all of column F:
Top rating capacity reported unless otherwise noted.
Schedule Page:426 Line No.:7 Column:a
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.100%of the capacity reported.
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.:26 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.100%of the capacity is reported.
Schedule Page:426.2 Line No.:39 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.100%of the capacity reported ._
Schedule Page:426.3 Line No.:11 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.100%of the capacity is reported.
Schedule Page:426.3 Line No.:27 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:426.4 Line No.:1 Column:a
Paci f i Corp has an ownership interest in certain high-voltage transmission related and
interconnection eguipment located at Idaho Power's Kinport station.Ownership interest
varies by terminal.100%of the capacity is reported.
Schedule Page:426.4 Line No.:28 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.100%of the capacity is reported.
Schedule Page:426.5 Line No.:21 Column:a
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:426.6 Line No.:16 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:426.7 Line No.:3 Column:a
Idaho Power has 32%ownership interest in certain transmission related equipment located
at Northwestern Energy's Mill Creek Station.
Schedule Page:426.7 Line No.:7 Column:a
Jointly owned with Sierra Pacific Power Company,d/b/a NV Energy.Idaho Power has a 50%
share of ownership.100%of the capacity reported.
Schedule Page:426.7 Line No.:12 Column:a
Jointly owned with'Port I and /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
FERC FORM NO.1 (ED.12-87)Page 450.1
Name of Respondent This Report is:
(1)X An Original
(2)_A Resubmission
Date of Report Year/Period of Report
(Mo,Da,Yr)
04/14/2020IdahoPowerCompany 2019/Q4
FOOTNOTE DATA
is reported.
Schedule Page;426.7 Line No.:13 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:426.7 Line No.:14 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 Pagejjt26.7 Line No.:15 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.:20 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.:37 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:426.8 Line No.:1 Column:ji
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:426.8 Line No.:4 Column:a
Jointly owned with PacificCorp.Idaho Power has a 33.3%share of ownership.100%of the
capacity is reported.
FERC FORM NO.1 (ED.12-87)Page 450.2
This Page Intentionally Left Blank
Year/Period of Report
End of
Date of Report
(Mo,Da,Yr)
04/14/2020
Name of Respondent
Idaho Power Company
This Report Is:
(1)|X|An Original
<2>n "
TRANSACTIONS WITH ASSOCIATED (AFFILIATED)COMPANIES
2019/Q4
A Resubmission
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
Amount
Charged or
Credited
Name of
Associated/Affiliated
Company
Line
No.Description of the Non-Power Good or Service
(d)(c)(b)(a)
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
417420 535,231IDACORP,INC.Managerial Expenses21
30,43292200022
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)