2023Annual FERC Financial Report.pdf

THIS FILING IS
Item 1: ☑ An Initial (Original) Submission OR ☐ Resubmission No.
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: 2023/ Q4
FERC FORM NO. 1 (REV. 02-04)
RECEIVED
Friday, April 19, 2024 9:07 AM
IDAHO PUBLIC
UTILITIES COMMISSION
IPC-E
INSTRUCTIONS FOR FILING FERC FORM NOS. 1 and 3-Q
GENERAL INFORMATION
Purp os e
FERC Form N o. 1 (FERC Form 1) is an annual regulatory requi rement for Major electric utilities, li censees and others (18 C.F.R . § 141.1).
FERC Form N o. 3-Q ( FER C Form 3-Q) is a quarterly regulatory requirement whi ch supplements the annual financial reporting
requi rement (18 C.F.R. § 141.400). These reports are designed to collect financial and operational information from electric utilities,
licensees and others subject to the j urisdi ction of the Federal Energy Regulatory Commission. These reports are also considered to be
non-confidential public use forms.
Who Mu st Submit
Each Maj or el ectric utility, licensee, or other, as cl assified in the Commission’s Uniform System of Accounts Prescribed for Public Utilities,
Li censees, and Others Subject To the Provisions of The Federal Power Act (18 C .F.R. Part 101), must submit FERC Form 1 (18 C.F.R . §
141.1), and FERC Form 3-Q (18 C.F.R. § 141.400).
Note: Major means havi ng, in each of the three previous calendar years, sal es or transmission service that exceeds one of the following:
one million megawatt hours of total annual sales,
100 megawatt hours of annual sales for resale,
500 megawatt hours of annual pow er exchanges delivered, or
500 megawatt hours of annual wheeling for others (deliveries plus losses).
What an d Whe re to Submit
Submit FERC Form Nos. 1 and 3-Q electronical l y through the eCollecti on portal at https://eCollection.ferc.gov, and according to the
specifications in the Form 1 and 3-Q taxonomies.
The Corporate Officer Certification must be submitted electronical l y as part of the FER C Forms 1 and 3-Q filings.
Submit i mmediately upon publicati on, by either eFiling or mail, two (2) copies to the Secretary of the C ommission, the latest Annual
R eport to Stockholders. U nless eFiling the Annual Report to Stockholders, mai l the stockhol ders report to the Secretary of the
C ommission at:
Secretary
Federal Energy Regulatory Commission 888 First Street, NE
Washington, DC 20426
For the C PA Certi fication Statement, submit w ithin 30 days after filing the FERC Form 1, a letter or report (not applicabl e to filers
classified as Class C or Class D prior to January 1, 1984). The CPA C ertification Statement can be either eFiled or mailed to the
Secretary of the Commissi on at the address above.
The CPA Certification Statement should:
Attest to the conformity, in all material aspects, of the bel ow listed (schedul es and pages) with the Commission's applicabl e
Uniform System of Accounts (including applicable notes relating thereto and the Chief Accountant's published accounting
rel eases), and
Be signed by independent certified public accountants or an independent licensed publ ic accountant certified or licensed by a
regulatory authority of a State or other political subdi vision of the U . S. (See 18 C.F.R. §§ 41.10-41.12 for specific
qualifications.)
Schedules Pages
Comparative Balance Sheet 110-113
Statement of Income 114-117
Statement of Retained Earnings 118-119
Statement of Cash Flow s 120-121
Notes to Fi nanci al Statements 122-123
The follow ing format must be used for the CPA Certification Statement unless unusual ci rcumstances or condi tions, explained in the
l etter or report, demand that it be varied. Insert parenthetical phrases only when exceptions are reported.
“In connection wi th our regular examination of the financi al statements of [COMPANY NAME] for the year ended on whi ch we have
reported separately under date of [DATE], we have also review ed schedules [NAME OF SCHEDULES] of FERC Form No. 1 for the
year filed with the Federal Energy Regulatory Commission, for conformity in all material respects with the requirements of the
Federal Energy Regulatory Commission as set forth in its appl icable Uniform System of Accounts and published accounting
releases. Our review for this purpose included such tests of the accounting records and such other auditing procedures as w e
considered necessary in the circumstances.
Based on our review, in our opinion the accompanying schedules i dentified in the preceding paragraph (except as noted below)
conform in all material respects with the accounting requirements of the Federal Energy Regulatory C ommission as set forth in its
appl i cable Uniform System of Accounts and published accounting releases.” The letter or report must state which, if any, of the
pages above do not conform to the C ommission’s requirements. Descri be the discrepancies that exist.
I.
II.
1.
2.
3.
4.
III.
a.
b.
c.
d.
a.
b.
e.
Filers are encouraged to file their Annual Report to Stockholders, and the C PA Certi fication Statement using eFiling. Further
i nstructions are found on the Commissi on’s website at https://www.ferc.gov/ferc-online/ferc-online/frequently-asked-questions-faqs-
efilingferc-online.
Federal, State, and Local Governments and other authorized users may obtain additional blank copies of FERC Form 1 and 3-Q
free of charge from https://w w w.ferc.gov/general-information-0/electric-industry-forms.
When to Su bmit
FERC Forms 1 and 3-Q must be filed by the following schedule:
FERC Form 1 for each year ending D ecember 31 must be filed by Apri l 18th of the follow ing year (18 CFR § 141.1), and
FERC Form 3-Q for each calendar quarter must be filed w ithin 60 days after the reporting quarter (18 C.F.R. § 141.400).
Where to Send Comments o n Public Re portin g Burd en .
The publi c reporting burden for the FERC Form 1 collection of informati on is estimated to average 1,168 hours per response, including
the time for review i ng instructions, searching existing data sources, gathering and maintaining the data-needed, and completing and
reviewing the collection of information. The public reporting burden for the FER C Form 3-Q col lection of information is estimated to
average 168 hours per response.
Send comments regarding these burden estimates or any aspect of these col lections of information, including suggestions for reducing
burden, to the Federal Energy Regulatory Commission, 888 Fi rst Street NE, Washington, D C 20426 (Attention: Information C learance
Officer); and to the Office of Information and Regulatory Affairs, Office of Management and Budget, Washington, DC 20503 (Attention:
Desk Officer for the Federal Energy R egulatory Commission). No person shall be subject to any penalty if any collection of information
does not display a valid control number (44 U.S.C. § 3512 (a)).
GENERAL INSTRUCTIONS
Prepare this report in conformity with the U niform System of Accounts (18 CFR Part 101) (USofA). Interpret all accounting words and
phrases in accordance with the USofA.
Enter in w hole numbers (dol lars or MWH) only, except where otherwise noted. (Enter cents for averages and figures per unit where cents
are important. The truncating of cents is allowed except on the four basic financial statements where rounding is required.) The amounts
shown on all supporting pages must agree with the amounts entered on the statements that they support. When applying threshol ds to
determine significance for reporting purposes, use for balance sheet accounts the balances at the end of the current reporting period, and
use for statement of income accounts the current year's year to date amounts.
Complete each question fully and accurately, even if it has been answered i n a previous report. Enter the word "None" w here it truly and
completely states the fact.
For any page(s) that is not applicabl e to the respondent, omit the page(s) and enter "NA," "NONE," or "Not Applicable" in col umn (d) on
the List of Schedules, pages 2 and 3.
Enter the month, day, and year for all dates. Use customary abbreviations. The "Date of Report" included in the header of each page is to
be completed only for resubmissions (see VII. below).
Generally, except for certain schedul es, all numbers, w hether they are expected to be debits or credits, must be reported as positive.
Numbers having a sign that is different from the expected sign must be reported by enclosing the numbers in parentheses.
For any resubmissions, please explain the reason for the resubmission in a footnote to the data field.
Do not make references to reports of previous periods/years or to other reports in lieu of required entries, except as speci fically
authorized.
Wherever (schedule) pages refer to fi gures from a previous period/year, the figures reported must be based upon those shown by the
report of the previous period/year, or an appropriate explanation given as to why the different figures were used.
Schedule specific instructions are found in the applicable taxonomy and on the appli cable blank rendered form.
Definitions for statistical classifications used for completing schedules for transmission system reporting are as follows:
FN S - Firm Netw ork Transmission Service for Self. "Firm" means service that can not be interrupted for economic reasons and is intended to
remain reliable even under adverse conditions. "Netw ork Service" is Netw ork Transmission Service as described in Order No. 888 and the
Open Access Transmission Tariff. "Sel f" means the respondent.
FN O - Firm Network Service for Others. "Fi rm" means that service cannot be interrupted for economic reasons and is intended to remain
rel i able even under adverse conditions. "N etwork Service" is Network Transmissi on Service as described in Order N o. 888 and the Open
Access Transmission Tariff.
LFP - for Long-Term Firm Point-to-Point Transmissi on Reservations. "Long-Term" means one year or longer and” firm" means that servi ce
cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions. "Point-to-Point Transmission
Reservations" are described in Order N o. 888 and the Open Access Transmission Tari ff. For all transactions identified as LFP, provide in a
footnote the termination date of the contract defined as the earliest date either buyer or sell er can uni laterally cancel the contract.
OLF - Other Long-Term Firm Transmission Service. Report service provided under contracts which do not conform to the terms of the Open
Access Transmission Tariff. "Long-Term" means one year or longer and “fi rm” means that service cannot be interrupted for economic reasons
and is intended to remain reliable even under adverse conditions. For all transactions identified as OLF, provide i n a footnote the termination
date of the contract defined as the earliest date either buyer or seller can unilaterally get out of the contract.
SFP - Short-Term Firm Point-to-Point Transmission R eservations. Use this classifi cation for all firm point-to-point transmission reservati ons,
where the duration of each period of reservation is less than one-year.
f.
g.
IV.
a.
b.
V.
I.
II.
III.
IV.
V.
VI.
VII.
VIII.
IX.
X.
Filers are encouraged to file their Annual Report to Stockholders, and the C PA Certi fication Statement using eFiling. Furtherinstructions are found on the Commissi on’s website at https://www.ferc.gov/ferc-online/ferc-online/frequently-asked-questions-faqs-efilingferc-online.Federal, State, and Local Governments and other authorized users may obtain additional blank copies of FERC Form 1 and 3-Qfree of charge from https://w w w.ferc.gov/general-information-0/electric-industry-forms.When to Su bmitFERC Forms 1 and 3-Q must be filed by the following schedule:FERC Form 1 for each year ending D ecember 31 must be filed by Apri l 18th of the follow ing year (18 CFR § 141.1), andFERC Form 3-Q for each calendar quarter must be filed w ithin 60 days after the reporting quarter (18 C.F.R. § 141.400).Where to Send Comments o n Public Re portin g Burd en .The publi c reporting burden for the FERC Form 1 collection of informati on is estimated to average 1,168 hours per response, includingthe time for review i ng instructions, searching existing data sources, gathering and maintaining the data-needed, and completing andreviewing the collection of information. The public reporting burden for the FER C Form 3-Q col lection of information is estimated toaverage 168 hours per response.Send comments regarding these burden estimates or any aspect of these col lections of information, including suggestions for reducingburden, to the Federal Energy Regulatory Commission, 888 Fi rst Street NE, Washington, D C 20426 (Attention: Information C learanceOfficer); and to the Office of Information and Regulatory Affairs, Office of Management and Budget, Washington, DC 20503 (Attention:Desk Officer for the Federal Energy R egulatory Commission). No person shall be subject to any penalty if any collection of informationdoes not display a valid control number (44 U.S.C. § 3512 (a)).GENERAL INSTRUCTIONSPrepare this report in conformity with the U niform System of Accounts (18 CFR Part 101) (USofA). Interpret all accounting words andphrases in accordance with the USofA.Enter in w hole numbers (dol lars or MWH) only, except where otherwise noted. (Enter cents for averages and figures per unit where centsare important. The truncating of cents is allowed except on the four basic financial statements where rounding is required.) The amountsshown on all supporting pages must agree with the amounts entered on the statements that they support. When applying threshol ds todetermine significance for reporting purposes, use for balance sheet accounts the balances at the end of the current reporting period, anduse for statement of income accounts the current year's year to date amounts.Complete each question fully and accurately, even if it has been answered i n a previous report. Enter the word "None" w here it truly andcompletely states the fact.For any page(s) that is not applicabl e to the respondent, omit the page(s) and enter "NA," "NONE," or "Not Applicable" in col umn (d) onthe List of Schedules, pages 2 and 3.Enter the month, day, and year for all dates. Use customary abbreviations. The "Date of Report" included in the header of each page is tobe completed only for resubmissions (see VII. below).Generally, except for certain schedul es, all numbers, w hether they are expected to be debits or credits, must be reported as positive.Numbers having a sign that is different from the expected sign must be reported by enclosing the numbers in parentheses.For any resubmissions, please explain the reason for the resubmission in a footnote to the data field.Do not make references to reports of previous periods/years or to other reports in lieu of required entries, except as speci ficallyauthorized.Wherever (schedule) pages refer to fi gures from a previous period/year, the figures reported must be based upon those shown by thereport of the previous period/year, or an appropriate explanation given as to why the different figures were used.Schedule specific instructions are found in the applicable taxonomy and on the appli cable blank rendered form.Definitions for statistical classifications used for completing schedules for transmission system reporting are as follows:FN S - Firm Netw ork Transmission Service for Self. "Firm" means service that can not be interrupted for economic reasons and is intended toremain reliable even under adverse conditions. "Netw ork Service" is Netw ork Transmission Service as described in Order No. 888 and theOpen Access Transmission Tariff. "Sel f" means the respondent.FN O - Firm Network Service for Others. "Fi rm" means that service cannot be interrupted for economic reasons and is intended to remainreliable even under adverse conditions. "N etwork Service" is Network Transmissi on Service as described in Order N o. 888 and the OpenAccess Transmission Tariff.LFP - for Long-Term Firm Point-to-Point Transmissi on Reservations. "Long-Term" means one year or longer and” firm" means that servi cecannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions. "Point-to-Point TransmissionReservations" are described in Order N o. 888 and the Open Access Transmission Tari ff. For all transactions identified as LFP, provide in afootnote the termination date of the contract defined as the earliest date either buyer or sell er can uni laterally cancel the contract.OLF - Other Long-Term Firm Transmission Service. Report service provided under contracts which do not conform to the terms of the OpenAccess Transmission Tariff. "Long-Term" means one year or longer and “fi rm” means that service cannot be interrupted for economic reasonsand is intended to remain reliable even under adverse conditions. For all transactions identified as OLF, provide i n a footnote the terminationdate of the contract defined as the earliest date either buyer or seller can unilaterally get out of the contract.
SFP - Short-Term Firm Point-to-Point Transmission R eservations. Use this classifi cation for all firm point-to-point transmission reservati ons,
where the duration of each period of reservation is less than one-year.
f.g.IV.a.b.V.I.II.III.IV.V.VI.VII.VIII.IX.X.
where the duration of each period of reservation is less than one-year.
NF - Non-Fi rm Transmission Service, where firm means that service cannot be interrupted for economic reasons and is intended to remain
rel i able even under adverse conditions.
OS - Other Transmission Service. Use this classification only for those services w hich can not be placed in the above-mentioned
classifi cations, such as all other servi ce regardless of the length of the contract and service FERC Form. Describe the type of service in a
footnote for each entry.
AD - Out-of-Period Adjustments. U se this code for any accounting adjustments or "true-ups" for servi ce provided in prior reporting periods.
Provide an expl anati on in a footnote for each adjustment.
DEFINITION S
C ommission Authorization (Comm. Auth.) -- The authorization of the Federal Energy Regulatory C ommission, or any other Commissi on.
N ame the commission whose authorizati on was obtained and give date of the authorization.
R espondent -- The person, corporati on, licensee, agency, authority, or other Legal entity or instrumentality in whose behalf the report is
made.
EXCERPTS FROM THE LAW
Federal Power Act, 16 U .S.C . § 791a-825r
Sec. 3. The words defined in this section shall have the following meanings for purposes of this Act, to with:
’Corporation' means any corporation, joint-stock company, partnership, association, business trust, organized group of persons, whether
incorporated or not, or a receiver or receivers, trustee or trustees of any of the foregoing. It shall not include 'municipalities, as hereinafter
defined;
'Person' means an individual or a corporation;
'Licensee, means any person, State, or municipality Licensed under the provisions of section 4 of this Act, and any assignee or successor
in interest thereof;
'municipality means a city, county, irrigation district, drainage district, or other pol i tical subdivision or agency of a State competent under
the Law s thereof to carry and the business of developing, transmitti ng, unitizing, or distributing power; ......
"project' means. a complete unit of improvement or development, consisting of a power house, all w ater conduits, al l dams and
appurtenant works and structures (including navigation structures) which are a part of said unit, and all storage, diverting, or fore bay
reservoirs directly connected therewith, the primary line or lines transmi tting power there from to the point of junction with the distribution
system or with the interconnected primary transmission system, all miscellaneous structures used and useful in connection with said unit
or any part thereof, and all water rights, rights-of-way, ditches, dams, reservoirs, Lands, or interest in Lands the use and occupancy of
which are necessary or appropriate i n the maintenance and operation of such uni t;
"Sec. 4. The Commi ssion is hereby authorized and empowered
'To make i nvestigations and to collect and record data concerni ng the utilization of the w ater 'resources of any region to be developed, the
water-power industry and its relation to other industries and to interstate or foreign commerce, and concerning the location, capacity,
development costs, and relation to markets of power sites; ... to the extent the C ommission may deem necessary or useful for the
purposes of this Act."
"Sec. 304.
Every Licensee and every public utility shall file with the Commission such annual and other periodic or special* reports as the
Commissi on may by rules and regulations or other prescribe as necessary or appropriate to assist the C ommission i n the proper
administration of this Act. The Commissi on may prescribe the manner and FERC Form in which such reports shall be made, and require
from such persons specific answ ers to all questions upon which the Commission may need information. The Commission may require
that such reports shall include, among other things, full information as to assets and Liabi l i ties, capitalization, net investment, and
reduction thereof, gross receipts, interest due and paid, depreciation, and other reserves, cost of project and other facilities, cost of
maintenance and operation of the project and other facilities, cost of renewals and replacement of the project works and other facilities,
depreciation, generation, transmission, distribution, delivery, use, and sale of electric energy. The Commission may require any such
person to make adequate provision for currently determining such costs and other facts. Such reports shall be made under oath unless
the Commission otherwise speci fies*.10
"Sec. 309.
The C ommission shall have power to perform any and all acts, and to prescri be, issue, make, and rescind such orders, rules and
regul ations as it may find necessary or appropriate to carry out the provisions of this Act. Among other things, such rules and regulations
may define accounting, technical, and trade terms used in this Act; and may prescribe the FER C Form or FERC Forms of all statements,
declarations, applications, and reports to be filed w ith the Commission, the i nformation which they shall contain, and the time within which
they shall be fi eld..."
GENERAL PENALTIES
The Commission may assess up to $1 million per day per vi olation of its rules and regulations. See FPA § 316(a) (2005), 16 U.S.C. § 825o(a).
FERC FORM NO. 1 (ED . 03-07)
I.
II.
3.
4.
5.
7.
11.
a.
a.
where the duration of each period of reservation is less than one-year.NF - Non-Fi rm Transmission Service, where firm means that service cannot be interrupted for economic reasons and is intended to remainreliable even under adverse conditions.OS - Other Transmission Service. Use this classification only for those services w hich can not be placed in the above-mentionedclassifications, such as all other servi ce regardless of the length of the contract and service FERC Form. Describe the type of service in afootnote for each entry.AD - Out-of-Period Adjustments. U se this code for any accounting adjustments or "true-ups" for servi ce provided in prior reporting periods.Provide an expl anati on in a footnote for each adjustment.DEFINITION SCommission Authorization (Comm. Auth.) -- The authorization of the Federal Energy Regulatory C ommission, or any other Commissi on.N ame the commission whose authorizati on was obtained and give date of the authorization.R espondent -- The person, corporati on, licensee, agency, authority, or other Legal entity or instrumentality in whose behalf the report ismade.EXCERPTS FROM THE LAWFederal Power Act, 16 U .S.C . § 791a-825rSec. 3. The words defined in this section shall have the following meanings for purposes of this Act, to with:’Corporation' means any corporation, joint-stock company, partnership, association, business trust, organized group of persons, whetherincorporated or not, or a receiver or receivers, trustee or trustees of any of the foregoing. It shall not include 'municipalities, as hereinafterdefined;'Person' means an individual or a corporation;'Licensee, means any person, State, or municipality Licensed under the provisions of section 4 of this Act, and any assignee or successorin interest thereof;'municipality means a city, county, irrigation district, drainage district, or other pol i tical subdivision or agency of a State competent underthe Law s thereof to carry and the business of developing, transmitti ng, unitizing, or distributing power; ......"project' means. a complete unit of improvement or development, consisting of a power house, all w ater conduits, al l dams andappurtenant works and structures (including navigation structures) which are a part of said unit, and all storage, diverting, or fore bayreservoirs directly connected therewith, the primary line or lines transmi tting power there from to the point of junction with the distributionsystem or with the interconnected primary transmission system, all miscellaneous structures used and useful in connection with said unitor any part thereof, and all water rights, rights-of-way, ditches, dams, reservoirs, Lands, or interest in Lands the use and occupancy ofwhich are necessary or appropriate i n the maintenance and operation of such uni t;"Sec. 4. The Commi ssion is hereby authorized and empowered'To make i nvestigations and to collect and record data concerni ng the utilization of the w ater 'resources of any region to be developed, thewater-power industry and its relation to other industries and to interstate or foreign commerce, and concerning the location, capacity,development costs, and relation to markets of power sites; ... to the extent the C ommission may deem necessary or useful for thepurposes of this Act.""Sec. 304.Every Licensee and every public utility shall file with the Commission such annual and other periodic or special* reports as theCommission may by rules and regulations or other prescribe as necessary or appropriate to assist the C ommission i n the properadministration of this Act. The Commissi on may prescribe the manner and FERC Form in which such reports shall be made, and requirefrom such persons specific answ ers to all questions upon which the Commission may need information. The Commission may requirethat such reports shall include, among other things, full information as to assets and Liabi l i ties, capitalization, net investment, andreduction thereof, gross receipts, interest due and paid, depreciation, and other reserves, cost of project and other facilities, cost ofmaintenance and operation of the project and other facilities, cost of renewals and replacement of the project works and other facilities,depreciation, generation, transmission, distribution, delivery, use, and sale of electric energy. The Commission may require any suchperson to make adequate provision for currently determining such costs and other facts. Such reports shall be made under oath unlessthe Commission otherwise speci fies*.10"Sec. 309.The C ommission shall have power to perform any and all acts, and to prescri be, issue, make, and rescind such orders, rules andregulations as it may find necessary or appropriate to carry out the provisions of this Act. Among other things, such rules and regulationsmay define accounting, technical, and trade terms used in this Act; and may prescribe the FER C Form or FERC Forms of all statements,declarations, applications, and reports to be filed w ith the Commission, the i nformation which they shall contain, and the time within whichthey shall be fi eld..."GENERAL PENALTIESThe Commission may assess up to $1 million per day per vi olation of its rules and regulations. See FPA § 316(a) (2005), 16 U.S.C. § 825o(a).FERC FORM NO. 1 (ED . 03-07)I.II.3.4.5.7.11.a.a.
FERC FORM NO. 1
REPORT OF MAJOR ELECTRIC UTILITIES, LICENSEES AND OTHER
ID EN TIFICATION
01 Exact Legal Name of Respondent
Idaho Power Company
02 Year/ Period of Report
End of: 2023/ Q4
03 Previous Name and Date of Change (If name changed duri ng year)
/
04 Address of Principal Offi ce at End of Period (Street, C ity, State, Zip Code)
1221 W Idaho St, P.O. Box 70 Boise, Id 83707-0070
05 N ame of Contact Person
Brian Buckham
06 Title of C ontact Person
SVP & CFO
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 Area Code
[phone]
09 This Report is An Original / A Resubmission
(1) ☑ An Original
(2) ☐ A Resubmission
10 Date of R eport (Mo, Da, Yr)
04/16/2024
Annual Corporate Officer Certification
The undersigned officer certifies that:
I have examined this report and to the best of my know ledge, 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 i n all material respects to the Uniform System of Accounts.
01 Name
Brian Buckham
02 Title
SVP & C FO
03 Si gnature
Brian Buckham
04 Date Signed (Mo, Da, Yr)
04/16/2024
Title 18, U.S.C. 1001 makes it a crime for any person to know ingly and w illingly to make to any Agency or Department of the United States
any false, ficti ti ous or fraudulent statements as to any matter within its jurisdiction.
FERC FORM No. 1 (REV. 02-04)
Page 1
FERC FORM NO. 1REPORT OF MAJOR ELECTRIC UTILITIES, LICENSEES AND OTHERIDENTIFICATION01 Exact Legal Name of RespondentIdaho Power Company 02 Year/ Period of ReportEnd of: 2023/ Q403 Previous Name and Date of Change (If name changed duri ng year)/ 04 Address of Principal Offi ce at End of Period (Street, C ity, State, Zip Code)1221 W Idaho St, P.O. Box 70 Boise, Id 83707-007005 N ame of Contact PersonBrian Buckham 06 Title of C ontact PersonSVP & CFO07 Address of Contact Person (Street, City, State, Zip Code)1221 W Idaho St, P.O. Box 70 Boise, Id 83707-007008 Telephone of Contact Person, Including Area Code(208) 388-2390 09 This Report is An Original / A Resubmission(1) ☑ An Original(2) ☐ A Resubmission 10 Date of R eport (Mo, Da, Yr)04/16/2024Annual Corporate Officer CertificationThe undersigned officer certifies that:I have examined this report and to the best of my know ledge, information, and belief all statements of fact contained in this report are correctstatements of the business affairs of the respondent and the financial statements, and other financial information contained in this report,conform i n all material respects to the Uniform System of Accounts.01 NameBrian Buckham02 TitleSVP & C FO 03 Si gnatureBrian Buckham 04 Date Signed (Mo, Da, Yr)04/16/2024Title 18, U.S.C. 1001 makes it a crime for any person to know ingly and w illingly to make to any Agency or Department of the United Statesany false, ficti ti ous or fraudulent statements as to any matter within its jurisdiction.FERC FORM No. 1 (REV. 02-04)Page 1
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original
(2) ☐ A R esubmission
Date of R eport:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
LIST OF SCHEDULES (Electric U tility)
Line
No.
Title of Schedule
(a)
Reference Page N o.
(b)
Remarks
(c)
Identificati on 1
List of Schedules 2
1 General Information 101
2 Control Over Respondent 102
3 Corporations Controlled by Respondent 103
4 Officers 104
5 Directors 105
6 Information on Formula Rates 106
7 Important Changes During the Year 108
8 Comparative Balance Sheet 110
9 Statement of Income for the Year 114
10 Statement of Retained Earnings for the Year 118
12 Statement of Cash Flows 120
12 Notes to Financial Statements 122
13 Statement of Accum Other Comp Income, Comp
Income, and H edgi ng Activities 122a
14 Summary of Utility Plant & Accumulated Provisions
for Dep, Amort & Dep 200
15 Nucl ear Fuel Materials 202 NA
16 Electric Pl ant in Service 204
17 Electric Pl ant Leased to Others 213 NA
18 Electric Pl ant Held for Future Use 214
19 Constructi on Work in Progress-Electric 216
20 Accumulated Provi sion for Depreciation of Electri c
Utility Plant 219
21 Investment of Subsidiary Companies 224
22 Materials and Supplies 227
23 Allowances 228 NA
24 Extraordi nary Property Losses 230a NA
25 Unrecovered Plant and Regulatory Study Costs 230b NA
26 Transmission Service and Generation
Interconnection Study Costs 231
27 Other Regulatory Assets 232
FERC FORM No. 1 (ED . 12-96)
Page 2
Name of Respondent:Idaho Power Company This report is:(1) ☑ An Original(2) ☐ A R esubmission Date of R eport:04/16/2024 Year/Period of ReportEnd of: 2023/ Q4LIST OF SCHEDULES (Electric U tility)LineNo.Title of Schedule(a)Reference Page N o.(b)Remarks(c)Identificati on 1List of Schedules 21General Information 1012Control Over Respondent 1023Corporations Controlled by Respondent 1034Officers1045Directors1056Information on Formula Rates 1067Important Changes During the Year 1088Comparative Balance Sheet 1109Statement of Income for the Year 11410Statement of Retained Earnings for the Year 11812Statement of Cash Flows 12012Notes to Financial Statements 12213Statement of Accum Other Comp Income, CompIncome, and H edgi ng Activities 122a14Summary of Utility Plant & Accumulated Provisionsfor Dep, Amort & Dep 20015Nuclear Fuel Materials 202 NA16Electric Pl ant in Service 20417Electric Pl ant Leased to Others 213 NA18Electric Pl ant Held for Future Use 21419Construction Work in Progress-Electric 21620Accumulated Provi sion for Depreciation of Electri cUtility Plant 21921Investment of Subsidiary Companies 22422Materials and Supplies 22723Allowances228 NA24Extraordinary Property Losses 230a NA25Unrecovered Plant and Regulatory Study Costs 230b NA26Transmission Service and GenerationInterconnection Study Costs 23127Other Regulatory Assets 232FERC FORM No. 1 (ED . 12-96)
Page 2
28 Miscellaneous D eferred Debits 233
29 Accumulated Deferred Income Taxes 234
30 Capital Stock 250
31 Other Paid-in Capital 253
32 Capital Stock Expense 254b
33 Long-Term Debt 256
34 Reconciliation of Reported Net Income with Taxable
Inc for Fed Inc Tax 261
35 Taxes Accrued, Prepaid and Charged During the
Year 262
36 Accumulated Deferred Investment Tax C redi ts 266
37 Other Deferred Credits 269
38 Accumulated Deferred Income Taxes-Accelerated
Amortization Property 272 NA
39 Accumulated Deferred Income Taxes-Other Property 274
40 Accumulated Deferred Income Taxes-Other 276
41 Other Regulatory Liabilities 278
42 Electric Operating Revenues 300
43 Regional Transmi ssion Service Revenues (Account
457.1)302 NA
44 Sales of Electricity by Rate Schedules 304
45 Sales for Resale 310
46 Electric Operation and Mai ntenance Expenses 320
47 Purchased Power 326
48 Transmission of Electri city for Others 328
49 Transmission of Electri city by ISO/RTOs 331 NA
50 Transmission of Electri city by Others 332
51 Miscellaneous General Expenses-Electri c 335
52 Depreciation and Amortization of Electri c Plant
(Account 403, 404, 405)336
53 Regulatory Commission Expenses 350
54 Research, Development and D emonstration
Activities 352
55 Distri bution of Sal aries and Wages 354
56 Common Utility Plant and Expenses 356 NA
57 Amounts included in ISO/R TO Settl ement
Statements 397 NA
LIST OF SCHEDULES (Electric U tility)
Line
No.
Title of Schedule
(a)
Reference Page N o.
(b)
Remarks
(c)
FERC FORM No. 1 (ED . 12-96)
Page 2
28 Miscellaneous D eferred Debits 23329Accumulated Deferred Income Taxes 23430Capital Stock 25031Other Paid-in Capital 25332Capital Stock Expense 254b33Long-Term Debt 25634Reconciliation of Reported Net Income with TaxableInc for Fed Inc Tax 26135Taxes Accrued, Prepaid and Charged During theYear 26236Accumulated Deferred Investment Tax C redi ts 26637Other Deferred Credits 26938Accumulated Deferred Income Taxes-AcceleratedAmortization Property 272 NA39Accumulated Deferred Income Taxes-Other Property 27440Accumulated Deferred Income Taxes-Other 27641Other Regulatory Liabilities 27842Electric Operating Revenues 30043Regional Transmi ssion Service Revenues (Account457.1)302 NA44Sales of Electricity by Rate Schedules 30445Sales for Resale 31046Electric Operation and Mai ntenance Expenses 32047Purchased Power 32648Transmission of Electri city for Others 32849Transmission of Electri city by ISO/RTOs 331 NA50Transmission of Electri city by Others 33251Miscellaneous General Expenses-Electri c 33552Depreciation and Amortization of Electri c Plant(Account 403, 404, 405)33653Regulatory Commission Expenses 35054Research, Development and D emonstrationActivities 35255Distribution of Sal aries and Wages 35456Common Utility Plant and Expenses 356 NA57Amounts included in ISO/R TO Settl ementStatements 397 NALIST OF SCHEDULES (Electric U tility)LineNo.Title of Schedule(a)Reference Page N o.(b)Remarks(c)
FERC FORM No. 1 (ED . 12-96)
Page 2
58 Purchase and Sale of Ancillary Services 398
59 Monthly Transmission System Peak Load 400
60 Monthly ISO/R TO Transmission System Peak Load 400a NA
61 Electric Energy Account 401a
62 Monthly Peaks and Output 401b
63 Steam Electri c Generating Plant Statistics 402
64 Hydroelectric Generating Pl ant Stati stics 406
65 Pumped Storage Generating Plant Statistics 408 NA
66 Generating Plant Statistics Pages 410
66.1 Energy Storage Operations (Large Plants)414
66.2 Energy Storage Operations (Small Plants)419 NA
67 Transmission Line Statistics Pages 422
68 Transmission Lines Added Duri ng Year 424
69 Substations 426
70 Transactions w ith Associated (Affiliated) Companies 429
71 Footnote Data 450
Stockholders' Reports (check appropriate box)
Stockholders' Reports Check appropriate box:
☐ Tw o copies will be submitted
☐ No annual report to stockhol ders is prepared
FERC FORM No. 1 (ED . 12-96)
Page 2
LIST OF SCHEDULES (Electric U tility)
Line
No.
Title of Schedule
(a)
Reference Page N o.
(b)
Remarks
(c)
58 Purchase and Sale of Ancillary Services 39859Monthly Transmission System Peak Load 40060Monthly ISO/R TO Transmission System Peak Load 400a NA61Electric Energy Account 401a62Monthly Peaks and Output 401b63Steam Electri c Generating Plant Statistics 40264Hydroelectric Generating Pl ant Stati stics 40665Pumped Storage Generating Plant Statistics 408 NA66Generating Plant Statistics Pages 41066.1 Energy Storage Operations (Large Plants)41466.2 Energy Storage Operations (Small Plants)419 NA67Transmission Line Statistics Pages 42268Transmission Lines Added Duri ng Year 42469Substations42670Transactions w ith Associated (Affiliated) Companies 42971Footnote Data 450Stockholders' Reports (check appropriate box)Stockholders' Reports Check appropriate box:☐ Tw o copies will be submitted☐ No annual report to stockhol ders is prepared FERC FORM No. 1 (ED . 12-96)Page 2LIST OF SCHEDULES (Electric U tility)LineNo.Title of Schedule(a)Reference Page N o.(b)Remarks(c)
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original
(2) ☐ A R esubmission
Date of R eport:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
GEN ER AL 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 offi ce where any other corporate books of account are kept, i f different from that where the general
corporate books are kept.
Brian Buckham, SVP, Chief Financi al Officer & Treasurer, Idaho Pow er Company 1221 W. Idaho Street, P.O. Box 70, Boise, Idaho 83707-
0070
Brian Buckham
SVP, Chief Financial Officer & Treasurer
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 i ncorporation. If incorporated under a
speci al law, gi ve reference to such l aw. If not i ncorporated, state that fact and give the type of organization and the date organized.
Idaho, June 30, 1989
State of Incorporation: ID
Date of Incorporation: 1989-06-30
Incorporated Under Special Law:
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 recei ver or trustee took possession, (c) the authority by which the receivership or trusteeship w as created, and (d) date when
possession by receiver or trustee ceased.
Not Applicabl e
(a) Name of Receiver or Trustee Hol ding Property of the Respondent:
(b) Date R eceiver took Possessi on of Respondent Property:
(c) Authori ty by whi ch the Recei vership or Trusteeship was created:
(d) Date w hen possession by receiver or trustee ceased:
4. State the cl asses or utility and other services furnished by respondent during the year in each State in which the respondent operated.
Class of Utility Service State El ectric Idaho El ectric 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
(2) ☑ No
FERC FORM No. 1 (ED. 12-87)
Page 101
Name of Respondent:Idaho Power Company This report is:(1) ☑ An Original(2) ☐ A R esubmission Date of R eport:04/16/2024 Year/Period of ReportEnd of: 2023/ Q4GENERAL INFORMATION1. Provide name and title of officer having custody of the general corporate books of account and address of office where the generalcorporate books are kept, and address of offi ce where any other corporate books of account are kept, i f different from that where the generalcorporate books are kept.Brian Buckham, SVP, Chief Financi al Officer & Treasurer, Idaho Pow er Company 1221 W. Idaho Street, P.O. Box 70, Boise, Idaho 83707-0070Brian BuckhamSVP, Chief Financial Officer & Treasurer1221 W. Idaho Street, P.O. Box 70, Boise, Idaho 83707-00702. Provide the name of the State under the laws of which respondent is incorporated, and date of i ncorporation. If incorporated under aspecial law, gi ve reference to such l aw. If not i ncorporated, state that fact and give the type of organization and the date organized.Idaho, June 30, 1989State of Incorporation: IDDate of Incorporation: 1989-06-30Incorporated Under Special Law: 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) datesuch recei ver or trustee took possession, (c) the authority by which the receivership or trusteeship w as created, and (d) date whenpossession by receiver or trustee ceased.Not Applicabl e(a) Name of Receiver or Trustee Hol ding Property of the Respondent: (b) Date R eceiver took Possessi on of Respondent Property: (c) Authori ty by whi ch the Recei vership or Trusteeship was created: (d) Date w hen possession by receiver or trustee ceased: 4. State the cl asses or utility and other services furnished by respondent during the year in each State in which the respondent operated.Class of Utility Service State El ectric Idaho El ectric Oregon5. Have you engaged as the principal accountant to audit your financial statements an accountant who is not the principal accountant foryour previous year's certified financial statements?(1) ☐ Yes (2) ☑ NoFERC FORM No. 1 (ED. 12-87)Page 101
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original
(2) ☐ A R esubmission
Date of R eport:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
CONTROL OVER R ESPONDENT
1. If any corporation, business trust, or similar organization or a combination of such organizations jointly held control over the respondent at
the end of the year, state name of controlling corporation or organization, manner in w hich control was held, and extent of control. If control
was in a holding company organizati on, show the chai n 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 beneficiaries for whom trust was maintained, and purpose of the trust.
IDACORP owns 100% of Idaho Power Company's Common Stock.
IDACORP is a public utility Hol ding C ompany Incorporated effective October 1, 1998.
FERC FORM No. 1 (ED. 12-96)
Page 102
Name of Respondent:Idaho Power Company This report is:(1) ☑ An Original(2) ☐ A R esubmission Date of R eport:04/16/2024 Year/Period of ReportEnd of: 2023/ Q4CONTROL OVER R ESPONDENT1. If any corporation, business trust, or similar organization or a combination of such organizations jointly held control over the respondent atthe end of the year, state name of controlling corporation or organization, manner in w hich control was held, and extent of control. If controlwas in a holding company organizati on, show the chai n of ownership or control to the main parent company or organization. If control washeld by a trustee(s), state name of trustee(s), name of beneficiary or beneficiaries for whom trust was maintained, and purpose of the trust.IDACORP owns 100% of Idaho Power Company's Common Stock.IDACORP is a public utility Hol ding C ompany Incorporated effective October 1, 1998.FERC FORM No. 1 (ED. 12-96)Page 102
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original
(2) ☐ A R esubmission
Date of R eport:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
COR POR ATIONS CON TROLLED B Y RESPONDENT
Line
N o.
N ame of Company Controlled
(a)
Kind of Business
(b)
Percent
Voting Stock
Owned
(c)
Footnote R ef.
(d)
1 D irect C ontrol
2 Idaho Energy Resources Company Coal mining and mineral 100%
3 development
FERC FORM No. 1 (ED . 12-96)
Page 103
Name of Respondent:Idaho Power Company This report is:(1) ☑ An Original(2) ☐ A R esubmission Date of R eport:04/16/2024 Year/Period of ReportEnd of: 2023/ Q4CORPORATIONS CON TROLLED B Y RESPONDENTLineNo.N ame of Company Controlled(a)Kind of Business(b)PercentVoting StockOwned(c)Footnote R ef.(d)1 D irect C ontrol2Idaho Energy Resources Company Coal mining and mineral 100%3 developmentFERC FORM No. 1 (ED . 12-96)Page 103
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original
(2) ☐ A R esubmission
Date of R eport:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
OFFICER S
Line
No.
Title
(a)
Name of Officer
(b)
Salary for Year
(c)
Date Started in
Period
(d)
Date Ended in
Period
(e)
1 President & CEO Lisa Grow 920,000
2 Senior Vice President, COO Adam J. Richins 530,000
3 Senior Vice President, CFO Bri an R. Buckham 515,000
4 Senior Vice President, Public
Affairs Jeffery L. Malmen 402,000
5 Vice President, CAO &
Treasurer Ken W. Petersen 345,000
6 Vice President, Regulatory
Affairs Tim Tatum 302,500
7 Vice President, Power Supply Ryan N. Adelman 290,000
8 Vice President, Human
Resources Sarah E. Griffin 300,000
9
(a)
Corporate Secretary Patrick Harrington 300,000
10 Vice President, Customer
Operations & CSO Bo H anchey 270,500
11 Vice President, Corporate
Services & Communi cations Debra H. Lei thauser 260,650
12 Vice President, Information
Technology & CIO Jason C . Huszar 264,000
13 Vice President, Pl anni ng,
Engineering & Construction Mitch Colburn 264,000
14 Vice President, General C ounsel Julia A. Hilton 264,000
FERC FORM No. 1 (ED . 12-96)
Page 104
Name of Respondent:Idaho Power Company This report is:(1) ☑ An Original(2) ☐ A R esubmission Date of R eport:04/16/2024 Year/Period of ReportEnd of: 2023/ Q4OFFICERSLineNo.Title(a)Name of Officer(b)Salary for Year(c)Date Started inPeriod(d)Date Ended inPeriod(e)1 President & CEO Lisa Grow 920,0002Senior Vice President, COO Adam J. Richins 530,0003Senior Vice President, CFO Bri an R. Buckham 515,0004Senior Vice President, PublicAffairs Jeffery L. Malmen 402,0005Vice President, CAO &Treasurer Ken W. Petersen 345,0006Vice President, RegulatoryAffairs Tim Tatum 302,5007Vice President, Power Supply Ryan N. Adelman 290,0008Vice President, HumanResources Sarah E. Griffin 300,0009(a)Corporate Secretary Patrick Harrington 300,00010Vice President, CustomerOperations & CSO Bo H anchey 270,50011Vice President, CorporateServices & Communi cations Debra H. Lei thauser 260,65012Vice President, InformationTechnology & CIO Jason C . Huszar 264,00013Vice President, Pl anni ng,Engineering & Construction Mitch Colburn 264,00014Vice President, General C ounsel Julia A. Hilton 264,000FERC FORM No. 1 (ED . 12-96)Page 104
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original
(2) ☐ A R esubmission
Date of R eport:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
FOOTNOTE D ATA
(a) Concept: OfficerTitl e
Title change to Corporate Secretary effective 03/18/2023, previous title w as VP, General Counsel and C orporate Secretary.
FERC FORM No. 1 (ED. 12-96)
Page 104
Name of Respondent:Idaho Power Company This report is:(1) ☑ An Original(2) ☐ A R esubmission Date of R eport:04/16/2024 Year/Period of ReportEnd of: 2023/ Q4FOOTNOTE D ATA(a) Concept: OfficerTitl eTitle change to Corporate Secretary effective 03/18/2023, previous title w as VP, General Counsel and C orporate Secretary.FERC FORM No. 1 (ED. 12-96)Page 104
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original
(2) ☐ A R esubmission
Date of R eport:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
D IRECTOR S
Line
No.
Name (and Title) of Director
(a)
Principal B usiness Address
(b)
Member of the Executive
C ommittee
(c)
C hairman of the Executive
Committee
(d)
1
(a)
Nate Jorgensen
685 W. Sherington Dri ve,
Eagle, Idaho 83616 false false
2 Odette C. Bolano 1055 N . Curti s Rd., Boise,
Idaho 83706 false false
3
(b)
Thomas E. Carlil e
611 S 8th Street, U nit 503,
Boise, Idaho 83702 false false
4 Richard J. D ahl, Board Chair PO Box 2052, McCall, Idaho
83638 true false
5 Annette G. Elg 3475 E R ivernest Lane, Boise,
ID 83706 false false
6 Lisa A. Grow, President and
CEO
Idaho Power C ompany, 1221
W. Idaho Street, PO Box 70,
Boise, ID 83707
true true
7 Ronald W. Jibson 417 Aerie Circle, North Salt
Lake, Utah 84054 false false
8 Judi th A. Johansen, Comp
Committee Chair
10446 E. Palo Brea Dr,
Scottsdale, Arizona 85262 true false
9 Dennis L. Johnson, Corp Gov.
Chai r
926 West Oakhampton Dri ve,
Eagle, Idaho 83616 true false
10 Richard J. N avarro, Audit Chai r 1256 E C andl eridge Ct., Boise,
Idaho 83712 true false
11 Dr. Mark Peters 884 Neil Avenue, Col umbus,
Ohio 43215 false false
12 Jeff C. Kinneeveauk 7319 E Montebel l o Ave,
Scottsdale, AZ 85250 false false
13
(c)
Susan Morris
215 N. Bene Posto Place,
Boise, Idaho 83712 false false
FERC FORM No. 1 (ED . 12-95)
Page 105
Name of Respondent:Idaho Power Company This report is:(1) ☑ An Original(2) ☐ A R esubmission Date of R eport:04/16/2024 Year/Period of ReportEnd of: 2023/ Q4DIRECTORSLineNo.Name (and Title) of Director(a)Principal B usiness Address(b)Member of the ExecutiveCommittee(c)C hairman of the ExecutiveCommittee(d)1 (a)Nate Jorgensen 685 W. Sherington Dri ve,Eagle, Idaho 83616 false false2Odette C. Bolano 1055 N . Curti s Rd., Boise,Idaho 83706 false false3(b)Thomas E. Carlil e 611 S 8th Street, U nit 503,Boise, Idaho 83702 false false4Richard J. D ahl, Board Chair PO Box 2052, McCall, Idaho83638 true false5Annette G. Elg 3475 E R ivernest Lane, Boise,ID 83706 false false6Lisa A. Grow, President andCEO Idaho Power C ompany, 1221W. Idaho Street, PO Box 70,Boise, ID 83707 true true7Ronald W. Jibson 417 Aerie Circle, North SaltLake, Utah 84054 false false8Judith A. Johansen, CompCommittee Chair 10446 E. Palo Brea Dr,Scottsdale, Arizona 85262 true false9Dennis L. Johnson, Corp Gov.Chai r 926 West Oakhampton Dri ve,Eagle, Idaho 83616 true false10Richard J. N avarro, Audit Chai r 1256 E C andl eridge Ct., Boise,Idaho 83712 true false11Dr. Mark Peters 884 Neil Avenue, Col umbus,Ohio 43215 false false12Jeff C. Kinneeveauk 7319 E Montebel l o Ave,Scottsdale, AZ 85250 false false13(c)Susan Morris 215 N. Bene Posto Place,Boise, Idaho 83712 false falseFERC FORM No. 1 (ED . 12-95)Page 105
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original
(2) ☐ A R esubmission
Date of R eport:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
FOOTNOTE D ATA
(a) Concept: NameAndTitleOfDirector
N ate Jorgensen w as appointed to the Board on May 18, 2023.
(b) Concept: NameAndTitleOfDirector
Tom Carlile retired from the Board on May 18, 2023.
(c) C oncept: NameAndTitleOfD i rector
Susan Morris was appoi nted to the Board on May 18, 2023.
FERC FORM No. 1 (ED. 12-95)
Page 105
Name of Respondent:Idaho Power Company This report is:(1) ☑ An Original(2) ☐ A R esubmission Date of R eport:04/16/2024 Year/Period of ReportEnd of: 2023/ Q4FOOTNOTE D ATA(a) Concept: NameAndTitleOfDirectorNate Jorgensen w as appointed to the Board on May 18, 2023.(b) Concept: NameAndTitleOfDirectorTom Carlile retired from the Board on May 18, 2023.(c) C oncept: NameAndTitleOfD i rectorSusan Morris was appoi nted to the Board on May 18, 2023.FERC FORM No. 1 (ED. 12-95)Page 105
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original
(2) ☐ A R esubmission
Date of R eport:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
IN FORMATION ON FOR MULA R ATES
Line
No.
FERC Rate Schedule or Tariff Number
(a)
FERC Proceeding
(b)
Does the respondent have formula rates?
☑ Yes
☐ No
1 FERC Electric Tariff
FERC FORM No. 1 (N EW. 12-08)
Page 106
Name of Respondent:Idaho Power Company This report is:(1) ☑ An Original(2) ☐ A R esubmission Date of R eport:04/16/2024 Year/Period of ReportEnd of: 2023/ Q4INFORMATION ON FOR MULA R ATESLineNo.FERC Rate Schedule or Tariff Number(a)FERC Proceeding(b)Does the respondent have formula rates?☑ Yes☐ No1FERC Electric TariffFERC FORM No. 1 (N EW. 12-08)Page 106
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original
(2) ☐ A R esubmission
Date of R eport:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
INFORMATION ON FORMU LA RATES - FERC Rate Schedule/Tariff Number FERC Proceeding
Line
No.
A ccession
N o.
(a)
Document Date /
Filed Date
(b)
Docket No.
(c)
D escription
(d)
Formula Rate FER C Rate
Schedule Number or Tariff
N umber
(e)
Does the respondent file w i th the
Commission annual (or more
frequent) filings containing the inputs
to the formula rate(s)?
☑ Yes
☐ N o
1 20230828-
5252 08/28/2023 ER09-1641-000
Idaho Power Company 2023
Annual Informational filing
under ER09-1641-000
FERC Electric Tariff
FERC FORM NO. 1 (NEW. 12-08)
Page 106a
Name of Respondent:Idaho Power Company This report is:(1) ☑ An Original(2) ☐ A R esubmission Date of R eport:04/16/2024 Year/Period of ReportEnd of: 2023/ Q4INFORMATION ON FORMU LA RATES - FERC Rate Schedule/Tariff Number FERC ProceedingLineNo.A ccessionNo.(a)Document Date /Filed Date(b)Docket No.(c)D escription(d)Formula Rate FER C RateSchedule Number or TariffNumber(e)Does the respondent file w i th theCommission annual (or morefrequent) filings containing the inputsto the formula rate(s)?☑ Yes☐ N o120230828-5252 08/28/2023 ER09-1641-000 Idaho Power Company 2023Annual Informational filingunder ER09-1641-000 FERC Electric TariffFERC FORM NO. 1 (NEW. 12-08)Page 106a
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original
(2) ☐ A R esubmission
Date of R eport:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
IN FORMATION ON FORMULA RATES - Formula Rate Variances
Line
No.
Page No(s).
(a)
Schedule
(b)
Column
(c)
Line
No.
(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
FERC FORM No. 1 (N EW. 12-08)
Page 106b
Name of Respondent:Idaho Power Company This report is:(1) ☑ An Original(2) ☐ A R esubmission Date of R eport:04/16/2024 Year/Period of ReportEnd of: 2023/ Q4INFORMATION ON FORMULA RATES - Formula Rate VariancesLineNo.Page No(s).(a)Schedule(b)Column(c)LineNo.(d)123456789101112131415161718192021222324252627282930FERC FORM No. 1 (N EW. 12-08)Page 106b
31
32
33
34
35
36
37
38
39
40
41
42
43
44
FERC FORM No. 1 (N EW. 12-08)
Page 106b
IN FORMATION ON FORMULA RATES - Formula Rate Variances
Line
No.
Page No(s).
(a)
Schedule
(b)
Column
(c)
Line
No.
(d)
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original
(2) ☐ A R esubmission
Date of R eport:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
IMPORTA N T CH A N GES D U RING 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 answ ered. Enter "none," "not appl i cable," or "N A" where applicable. If information which answ ers
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: D escribe 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 reorgani zation, merger, or consolidation w ith other companies: Give names of
companies involved, particulars concerning the transacti ons, 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 w as 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 avai lable, period of contracts, and other parties to any such arrangements, etc.
6. Obl i gations 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 FER C or State Commission authori zation, as
appropriate, and the amount of obl i gation 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 i mportant w age scale changes during the year.
9. State briefly the status of any materially important legal proceedings pendi ng 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 elsew here in this report in which an officer,
director, security holder reported on Pages 104 or 105 of the Annual Report Form No. 1, voti ng trustee, associ ated 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 requi red by Instructions 1 to 11 above, such notes may be included on this page.
13. Describe fully any changes in officers, directors, major securi ty 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 descri be the significant events or transactions causing the proprietary capital ratio to be less than 30 percent, and the extent to
whi ch the respondent has amounts loaned or money advanced to its parent, subsidiary, or affiliated companies through a cash
management program(s). Addi tionally, please describe plans, if any to regain at least a 30 percent proprietary ratio.
None
None
None
None
None
On September 11, 2023, under the shelf registration statement with the SEC, Idaho Power issued $350 million in aggregate principal amount of 5.80% first
mortgage bonds, secured medium-term notes, Series M, maturing on April 1, 2054. On March 14, 2023, under the shelf registration statement with the SEC, Idaho
Power issued $400 million in aggregate principal amount of 5.50% first mortgage bonds, secured medium-term notes, Series M, maturing on March 15, 2053. On
March 8, 2 023, pursuant to a Bond Purchase Agreement, Idaho Power issued $60 million in aggregate principal amount of 5.06% first mortgage bonds, secured
medium-term notes, Series N, maturing on March 8, 2043; and $62 million in aggregate principal amount of 5.20% first mortgage bonds, secured medium-term
notes, Series N, maturing on March 8, 2053. In May and June 2022, Idaho Power received orders from the IPUC, OPUC, and WPSC authorizing the company to issue
and sell from time to time up to $1.2 billion in aggregate principal amount of debt securities and first mortgage bonds, subject to conditions specified in the orders.
None
Effective 12/23/2023, a 4% general wage adjustment was implemented.
None
None
None
Officer Changes in 2023:
In November 2023, Ken Petersen announced his upcoming retirement date from the company in May 2024, but stepped down as CAO and Treasurer
effective January 1, 2024.
Brian Buckham became Treasurer effective January 1, 2024, in addition to his roles as SV P and CFO.
On January 1, 2024, Amy Shaw became VP of Finance, Compliance and Risk, and became the company's chief accounting officer, although that role is not
part of her title.
Julia Hilton became VP and General Counsel on March 18, 2023.
Pat Harrington became Corporate Secretary on March 18, 2023.

Director Changes in 2023:
Nate R. Jorgensen was elected to the Board on May 18, 2023.
Susan D. Morris was elected to the Board on May 18, 2023.
Thomas Carlile retired from the Board on May 18, 2023.
Idaho Power and its unreg ulated parent, IDAC ORP, 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 IDACO RP through a cash management program.
FERC FORM No. 1 (ED. 12-96)
Page 108-109
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original
(2) ☐ A R esubmission
Date of R eport:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
COMPARATIVE BALANCE SHEET (A SSETS AND OTHER DEBITS)
Line
No.
Title of A ccount
(a)
Ref. Page No.
(b)
C urrent Year End of
Quarter/Year B alance
(c)
Prior Year End Balance 12/31
(d)
1 UTILITY PLANT
2 Utility Plant (101-106, 114)200 7,303,705,294 6,837,661,812
3 Construction Work in Progress (107)200 986,645,675 786,213,001
4 TOTAL Utility Plant (Enter Total of lines 2 and 3)8,290,350,969 7,623,874,813
5 (Less) Accum. Prov. for Depr. Amort. Depl. (108,
110, 111, 115)200 2,733,469,808 2,645,515,886
6 Net U tility Plant (Enter Total of line 4 less 5)5,556,881,161 4,978,358,927
7 Nuclear Fuel in Process of Ref., Conv., Enrich.,
and Fab. (120.1)202
8 Nuclear Fuel Materials and Assemblies-Stock
Account (120.2)
9 Nuclear Fuel Assemblies in Reactor (120.3)
10 Spent Nucl ear Fuel (120.4)
11 Nuclear Fuel Under Capital Leases (120.6)
12 (Less) Accum. Prov. for Amort. of N ucl. Fuel
Assemblies (120.5)202
13 Net N uclear Fuel (Enter Total of lines 7-11 l ess
12)
14 Net U tility Plant (Enter Total of lines 6 and 13)5,556,881,161 4,978,358,927
15 Utility Plant Adjustments (116)
16 Gas Stored Underground - N oncurrent (117)
17 OTHER PROPER TY AND INVESTMEN TS
18 Nonutility Property (121)4,548,632 4,557,979
19 (Less) Accum. Prov. for Depr. and Amort. (122)238,219 0
20 Investments in Associated Companies (123)0 0
21 Investment in Subsidiary Companies (123.1)224 22,725,506 14,691,519
23 Noncurrent Portion of Allowances 228
24 Other Investments (124)0 0
25 Sinking Funds (125)0 0
26 Depreci ation Fund (126)
27 Amortization Fund - Federal (127)
28 Other Special Funds (128)70,238,519 66,953,493
29 Special Funds (Non Maj or Only) (129)
FERC FORM No. 1 (R EV. 12-03)
Page 110-111
30 Long-Term Portion of Derivati ve Assets (175)16,853 578,438
31
Long-Term Portion of Derivati ve Assets - Hedges
(176)0 0
32 TOTAL Other Property and Investments (Lines
18-21 and 23-31)97,291,291 86,781,429
33 CURR ENT AND ACCRUED ASSETS
34 Cash and Worki ng Funds (Non-major Only)
(130)
35 Cash (131)40,910,822 74,192,042
36 Special Deposits (132-134)21,004,570 4,719,757
37 Working Fund (135)21,000 21,000
38 Temporary C ash Investments (136)230,599,652 34,468,327
39 Notes Receivabl e (141)0 0
40 Customer Accounts Receivable (142)115,976,785 119,228,349
41 Other Accounts Receivable (143)18,844,473 46,115,478
42 (Less) Accum. Prov. for Uncollecti ble Acct.-C redit
(144)5,585,326 5,545,578
43 Notes Receivabl e from Associated Companies
(145)13,778,220 14,502,758
44 Accounts Receivable from Assoc. C ompanies
(146)0 0
45 Fuel Stock (151)227 19,952,164 14,760,362
46 Fuel Stock Expenses Undistributed (152)227 0 1,691
47 Residuals (Elec) and Extracted Products (153)227
48 Plant Materials and Operating Supplies (154)227 135,988,478 91,871,314
49 Merchandise (155)227
50 Other Materi als and Supplies (156)227 0 0
51 Nuclear Materials H eld for Sale (157)202/227
52 Allowances (158.1 and 158.2)228
53 (Less) N oncurrent Portion of Allowances 228
54 Stores Expense Undistri buted (163)227 4,526,104 589,580
55 Gas Stored Underground - C urrent (164.1)
56 Liquefi ed Natural Gas Stored and Held for
Processing (164.2-164.3)
57 Prepayments (165)22,710,298 24,395,907
58 Advances for Gas (166-167)
COMPARATIVE BALANCE SHEET (A SSETS AND OTHER DEBITS)
Line
No.
Title of A ccount
(a)
Ref. Page No.
(b)
C urrent Year End of
Quarter/Year B alance
(c)
Prior Year End Balance 12/31
(d)
FERC FORM No. 1 (R EV. 12-03)
Page 110-111
59 Interest and D ividends Receivable (171)1,349,717 408,892
60 Rents Receivabl e (172)
61 Accrued Uti l ity Revenues (173)90,520,557 84,861,841
62 Mi scellaneous Current and Accrued Assets (174)
63 Derivative Instrument Assets (175)88,195 40,917,552
64
(Less) Long-Term Portion of Derivative
Instrument Assets (175)16,853 578,438
65 Derivative Instrument Assets - H edges (176)
66 (Less) Long-Term Portion of Derivative
Instrument Assets - Hedges (176)0 0
67 Total Current and Accrued Assets (Lines 34
through 66)710,668,856 544,930,834
68 DEFER R ED DEBITS
69 Unamortized Debt Expenses (181)22,397,365 14,610,380
70 Extraordinary Property Losses (182.1)230a
71 Unrecovered Plant and R egul atory Study Costs
(182.2)230b
72 Other Regulatory Assets (182.3)232 1,652,987,800 1,501,960,906
73 Prelim. Survey and Investigati on Charges
(Electric) (183)607,337 849,613
74 Preliminary Natural Gas Survey and
Investigation Charges 183.1)
75 Other Preliminary Survey and Investigation
Charges (183.2)
76 Clearing Accounts (184)3,542,993 4,883,074
77 Temporary Faci l i ties (185)0 0
78 Mi scellaneous Deferred Debi ts (186)233 81,691,788 78,408,895
79 Def. Losses from Disposition of Utility Plt. (187)
80 Research, Devel. and Demonstration Expend.
(188)352 0 0
81 Unamortized Loss on Reaqui red D ebt (189)33,990,354 36,741,730
82 Accumulated Deferred Income Taxes (190)234 302,297,606 266,405,788
83 Unrecovered Purchased Gas Costs (191)
84 Total Deferred Debits (lines 69 through 83)2,097,515,243 1,903,860,386
85 TOTAL ASSETS (lines 14-16, 32, 67, and 84)8,462,356,551 7,513,931,576
FERC FORM No. 1 (R EV. 12-03)
Page 110-111
COMPARATIVE BALANCE SHEET (A SSETS AND OTHER DEBITS)
Line
No.
Title of A ccount
(a)
Ref. Page No.
(b)
C urrent Year End of
Quarter/Year B alance
(c)
Prior Year End Balance 12/31
(d)
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original
(2) ☐ A R esubmission
Date of R eport:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
COMPARATIVE BALANCE SHEET (LIAB ILITIES A N D OTH ER C RED ITS)
Line
No.
Title of A ccount
(a)
Ref. Page No.
(b)
C urrent Year End of
Quarter/Year B alance
(c)
Prior Year End Balance 12/31
(d)
1 PROPRIETARY CAPITAL
2 Common Stock Issued (201)250 97,877,030 97,877,030
3 Preferred Stock Issued (204)250 0 0
4 Capital Stock Subscribed (202, 205)
5 Stock Liabi l i ty for Conversion (203, 206)
6 Premium on Capital Stock (207)712,257,435 712,257,435
7 Other Paid-In C apital (208-211)253 0 0
8 Installments Received on Capital Stock (212)252
9 (Less) D iscount on C apital Stock (213)254
10 (Less) C apital Stock Expense (214)254b 2,096,925 2,096,925
11 Retained Earnings (215, 215.1, 216)118 1,971,056,368 1,824,318,236
12 Unappropriated Undi stributed Subsidiary
Earnings (216.1)118 20,262,413 12,228,426
13 (Less) R eacquired Capital Stock (217)250 0 0
14 Noncorporate Proprietorship (Non-major only)
(218)
15 Accumulated Other Comprehensive Income
(219)122(a)(b)(17,184,492)(12,922,387)
16 Total Proprietary Capital (lines 2 through 15)2,782,171,829 2,631,661,815
17 LON G-TER M DEBT
18 Bonds (221)256 2,811,100,000 2,014,100,000
19 (Less) R eacquired Bonds (222)256 0 0
20 Advances from Associated Companies (223)256
21 Other Long-Term Debt (224)256 19,885,000 169,885,000
22 Unamortized Premium on Long-Term D ebt (225)26,751,569 27,858,531
23 (Less) U namortized Discount on Long-Term
Debt-Debit (226)9,749,604 3,088,412
24 Total Long-Term D ebt (lines 18 through 23)2,847,986,965 2,208,755,119
25 OTHER NONCURR ENT LIABILITIES
26 Obl igations Under C apital Leases - N oncurrent
(227)
27 Accumulated Provision for Property Insurance
(228.1)
FERC FORM No. 1 (R EV. 12-03)
Page 112-113
28 Accumulated Provision for Inj uries and D amages
(228.2)3,256,902 2,736,418
29
Accumulated Provision for Pensions and
Benefits (228.3)234,667,825 238,478,974
30 Accumulated Mi scellaneous Operating
Provisions (228.4)0 0
31 Accumulated Provision for Rate Refunds (229)228,670,163 207,527,563
32 Long-Term Portion of Derivati ve Instrument
Liabilities 0 3,271,994
33 Long-Term Portion of Derivati ve Instrument
Liabilities - Hedges
34 Asset R etirement Obligations (230)48,997,190 37,556,680
35 Total Other Noncurrent Liabil i ties (lines 26
through 34)515,592,080 489,571,629
36 CURR ENT AND ACCRUED LIABILITIES
37 Notes Payable (231)0 0
38 Accounts Payable (232)336,075,392 318,080,097
39 Notes Payable to Associated Companies (233)0 0
40 Accounts Payable to Associated Companies
(234)16,455,713 56,338,432
41 Customer Deposits (235)1,201,980 1,000,860
42 Taxes Accrued (236)262 (16,317,844)(4,258,456)
43 Interest Accrued (237)40,008,704 24,546,434
44 Dividends Declared (238)1,201,879 953,600
45 Matured Long-Term Debt (239)
46 Matured Interest (240)
47 Tax C ollecti ons Payable (241)1,362,048 1,471,843
48 Mi scellaneous Current and Accrued Liabilities
(242)175,376,104 124,973,948
49 Obl igations Under C apital Leases-Current (243)
50 Derivative Instrument Liabilities (244)5,932,393 6,787,944
51 (Less) Long-Term Portion of Derivative
Instrument Liabilities 0 3,271,994
52 Derivative Instrument Liabilities - Hedges (245)0 0
53 (Less) Long-Term Portion of Derivative
Instrument Liabilities-Hedges
54 Total Current and Accrued Liabilities (lines 37
through 53)561,296,369 526,622,708
COMPARATIVE BALANCE SHEET (LIAB ILITIES A N D OTH ER C RED ITS)
Line
No.
Title of A ccount
(a)
Ref. Page No.
(b)
C urrent Year End of
Quarter/Year B alance
(c)
Prior Year End Balance 12/31
(d)
FERC FORM No. 1 (R EV. 12-03)
Page 112-113
55 DEFER R ED CREDITS
56 Customer Advances for Constructi on (252)37,489,823 19,112,288
57 Accumulated Deferred Investment Tax C redits
(255)266 165,478,542 115,285,406
58 Deferred Gains from Disposition of Utility Plant
(256)
59 Other Deferred Credits (253)269 43,306,173 12,865,420
60 Other Regulatory Liabiliti es (254)278 313,035,279 357,700,683
61 Unamortized Gain on Reacquired D ebt (257)0 0
62 Accum. Deferred Income Taxes-Accel. Amort.
(281)272
63 Accum. Deferred Income Taxes-Other Property
(282)1,000,741,276 989,140,934
64 Accum. Deferred Income Taxes-Other (283)195,258,215 163,215,574
65 Total Deferred Credits (li nes 56 through 64)1,755,309,308 1,657,320,305
66 TOTAL LIABILITIES AND STOCKHOLDER
EQUITY (lines 16, 24, 35, 54 and 65)8,462,356,551 7,513,931,576
FERC FORM No. 1 (R EV. 12-03)
Page 112-113
COMPARATIVE BALANCE SHEET (LIAB ILITIES A N D OTH ER C RED ITS)
Line
No.
Title of A ccount
(a)
Ref. Page No.
(b)
C urrent Year End of
Quarter/Year B alance
(c)
Prior Year End Balance 12/31
(d)
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original
(2) ☐ A R esubmission
Date of R eport:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
STATEMENT OF INCOME
Line
No.
Title of Account
(a)
(Ref.)
Page No.
(b)
Total Current
Year to Date
Balance for
Quarter/Year
(c)
Total Prior Year
to Date Balance
for Quarter/Year
(d)
Current 3
Months
Ended -
Quarterly
Only - No 4th
Quarter
(e)
Prior 3
Months
Ended -
Quarterly
Only - No 4th
Quarter
(f)
Electric U tility
Current Year to
Date (in dollars)
(g)
Electric Utility
Previous Year
to Date (in
dollars)
(h)
1
UTILITY
OPER ATING
INCOME
2 Operating Revenues
(400)300 1,763,488,760 1,642,534,019 1,763,488,760 1,642,534,019
3 Operating Expenses
4 Operation Expenses
(401)320 1,134,994,194 1,021,238,677 1,134,994,194 1,021,238,677
5 Mai ntenance
Expenses (402)320 74,644,805 81,802,969 74,644,805 81,802,969
6 Depreciation
Expense (403)336 188,144,343 162,962,070 188,144,343 162,962,070
7
Depreciation
Expense for Asset
Retirement Costs
(403.1)
336
8 Amort. & D epl. of
Utility Plant (404-405)336 6,193,955 5,251,912 6,193,955 5,251,912
9 Amort. of Utility Plant
Acq. Adj. (406)336 15,018 15,018 15,018 15,018
10
Amort. Property
Losses, Unrecov
Plant and Regulatory
Study C osts (407)
11 Amort. of Conversion
Expenses (407.2)
12 Regulatory Debits
(407.3)9,434,513 10,159,686 9,434,513 10,159,686
13 (Less) Regulatory
Credits (407.4)2,536,133 2,380,983 2,536,133 2,380,983
14 Taxes Other Than
Income Taxes (408.1)262 25,081,924 28,701,677 25,081,924 28,701,677
15 Income Taxes -
Federal (409.1)262 (4,035,971)42,187,659 (4,035,971)42,187,659
16 Income Taxes - Other
(409.1)262 319,336 1,940,619 319,336 1,940,619
17 Provision for Deferred
Income Taxes (410.1)
234,
272 41,738,545 53,504,641 41,738,545 53,504,641
FERC FORM No. 1 (R EV. 02-04)
Page 114-117
18
(Less) Provision for
Deferred Income
Taxes-Cr. (411.1)
234,
272 64,257,171 64,332,926 64,257,171 64,332,926
19
Investment Tax Credit
Adj. - Net (411.4)266 50,193,136 5,825,740 50,193,136 5,825,740
20
(Less) Gains from
Disp. of Utility Plant
(411.6)
21 Losses from Disp. of
Utility Plant (411.7)
22
(Less) Gains from
Disposition of
Allowances (411.8)
769,099 414,026 769,099 414,026
23
Losses from
Disposition of
Allowances (411.9)
24 Accretion Expense
(411.10)12,995 27,141 12,995 27,141
25
TOTAL Utility
Operating Expenses
(Enter Total of lines 4
thru 24)
1,459,174,390 1,346,489,874 1,459,174,390 1,346,489,874
27
Net Util Oper Inc
(Enter Tot line 2 l ess
25)
304,314,370 296,044,145 304,314,370 296,044,145
28 Other Income and
Deductions
29 Other Income
30 Nonutilty Operati ng
Income
31
Revenues From
Merchandising,
Jobbing and C ontract
Work (415)
4,655,894 3,911,815
32
(Less) Costs and Exp.
of Merchandi sing,
Job. & C ontract Work
(416)
5,870,784 4,701,875
33
Revenues From
Nonutility Operati ons
(417)
13,734 15,581
34
(Less) Expenses of
Nonutility Operati ons
(417.1)
108,302 (49,430)
STATEMENT OF INCOME
Line
No.
Title of Account
(a)
(Ref.)
Page No.
(b)
Total Current
Year to Date
Balance for
Quarter/Year
(c)
Total Prior Year
to Date Balance
for Quarter/Year
(d)
Current 3
Months
Ended -
Quarterly
Only - No 4th
Quarter
(e)
Prior 3
Months
Ended -
Quarterly
Only - No 4th
Quarter
(f)
Electric U tility
Current Year to
Date (in dollars)
(g)
Electric Utility
Previous Year
to Date (in
dollars)
(h)
FERC FORM No. 1 (R EV. 02-04)
Page 114-117
35 Nonoperating Rental
Income (418)7,868
36
Equity in Earnings of
Subsidiary
Compani es (418.1)
119 8,033,987 8,782,042
37 Interest and Dividend
Income (419)27,448,696 12,658,172
38
Allowance for Other
Funds U sed During
Construction (419.1)
43,221,277 37,285,494
39
Miscellaneous
Nonoperating Income
(421)
6,383,537 (1,358,052)
40 Gain on Disposition
of Property (421.1)0 62,312
41
TOTAL Other Income
(Enter Total of lines
31 thru 40)
83,785,907 56,704,919
42 Other Income
Deductions
43 Loss on Disposition
of Property (421.2)
44 Miscellaneous
Amortization (425)
45 Donations (426.1)3,195,421 2,646,442
46 Life Insurance (426.2)(8,383,775)(7,106,697)
47 Penalties (426.3)53,795 94,250
48
Exp. for Certain Civic,
Political & R elated
Activities (426.4)
1,337,627 1,328,198
49 Other Deductions
(426.5)15,534,857 12,390,838
50
TOTAL Other Income
Deductions (Total of
lines 43 thru 49)
11,737,925 9,353,031
51
Taxes Applic. to Other
Income and
Deductions
52 Taxes Other Than
Income Taxes (408.2)262 33,719 36,746
53 Income Taxes-
Federal (409.2)262 2,783,669 496,189
STATEMENT OF INCOME
Line
No.
Title of Account
(a)
(Ref.)
Page No.
(b)
Total Current
Year to Date
Balance for
Quarter/Year
(c)
Total Prior Year
to Date Balance
for Quarter/Year
(d)
Current 3
Months
Ended -
Quarterly
Only - No 4th
Quarter
(e)
Prior 3
Months
Ended -
Quarterly
Only - No 4th
Quarter
(f)
Electric U tility
Current Year to
Date (in dollars)
(g)
Electric Utility
Previous Year
to Date (in
dollars)
(h)
FERC FORM No. 1 (R EV. 02-04)
Page 114-117
54 Income Taxes-Other
(409.2)262 843,344 147,450
55 Provision for Deferred
Inc. Taxes (410.2)
234,
272 0 590
56
(Less) Provision for
Deferred Income
Taxes-Cr. (411.2)
234,
272 225,761 1,192,646
57 Investment Tax Credit
Adj.-Net (411.5)
58 (Less) Investment Tax
Credits (420)
59
TOTAL Taxes on
Other Income and
Deductions (Total of
lines 52-58)
3,434,971 (511,671)
60
Net Other Income and
Deductions (Total of
lines 41, 50, 59)
68,613,011 47,863,559
61 Interest Charges
62 Interest on Long-Term
Debt (427)116,216,296 87,258,742
63 Amort. of Debt Disc.
and Expense (428)1,607,883 1,358,114
64
Amortization of Loss
on R eaquired Debt
(428.1)2,751,376 2,851,131
65
(Less) Amort. of
Premium on Debt-
Credit (429)
1,106,961 1,106,962
66
(Less) Amortizati on of
Gain on Reaquired
Debt-Credit (429.1)
67
Interest on Debt to
Assoc. Companies
(430)
0 3,248
68 Other Interest
Expense (431)16,660,726 12,591,039
69
(Less) Allow ance for
Borrowed Funds
Used During
Construction-Cr. (432)
20,012,407 13,914,276
70
Net Interest Charges
(Total of lines 62 thru
69)
116,116,913 89,041,036
STATEMENT OF INCOME
Line
No.
Title of Account
(a)
(Ref.)
Page No.
(b)
Total Current
Year to Date
Balance for
Quarter/Year
(c)
Total Prior Year
to Date Balance
for Quarter/Year
(d)
Current 3
Months
Ended -
Quarterly
Only - No 4th
Quarter
(e)
Prior 3
Months
Ended -
Quarterly
Only - No 4th
Quarter
(f)
Electric U tility
Current Year to
Date (in dollars)
(g)
Electric Utility
Previous Year
to Date (in
dollars)
(h)
FERC FORM No. 1 (R EV. 02-04)
Page 114-117
71
Income Before
Extraordinary Items
(Total of lines 27, 60
and 70)
256,810,468 254,866,668
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 0
77
Extraordinary Items
After Taxes (l i ne 75
less line 76)
0
78 Net Income (Total of
line 71 and 77)256,810,468 254,866,668
FERC FORM No. 1 (R EV. 02-04)
Page 114-117
STATEMENT OF INCOME
Line
No.
Title of Account
(a)
(Ref.)
Page No.
(b)
Total Current
Year to Date
Balance for
Quarter/Year
(c)
Total Prior Year
to Date Balance
for Quarter/Year
(d)
Current 3
Months
Ended -
Quarterly
Only - No 4th
Quarter
(e)
Prior 3
Months
Ended -
Quarterly
Only - No 4th
Quarter
(f)
Electric U tility
Current Year to
Date (in dollars)
(g)
Electric Utility
Previous Year
to Date (in
dollars)
(h)
STATEMENT OF INCOME
Line
No.
Gas U tiity Current Year to D ate
(in dollars)
(i)
Gas U tility Previous Year to
Date (in dollars)
(j)
Other Utility Current Year to
Date (in dollars)
(k)
Other U tility Previous Year to
D ate (in dollars)
(l)
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
27
28
29
30
31
32
33
34
FERC FORM No. 1 (R EV. 02-04)
Page 114-117
35
36
37
38
39
40
41
42
43
44
45
46
47
48
49
50
51
52
53
54
55
56
57
58
59
60
61
62
63
64
65
66
67
STATEMENT OF INCOME
Line
No.
Gas U tiity Current Year to D ate
(in dollars)
(i)
Gas U tility Previous Year to
Date (in dollars)
(j)
Other Utility Current Year to
Date (in dollars)
(k)
Other U tility Previous Year to
D ate (in dollars)
(l)
FERC FORM No. 1 (R EV. 02-04)
Page 114-117
68
69
70
71
72
73
74
75
76
77
78
FERC FORM No. 1 (R EV. 02-04)
Page 114-117
STATEMENT OF INCOME
Line
No.
Gas U tiity Current Year to D ate
(in dollars)
(i)
Gas U tility Previous Year to
Date (in dollars)
(j)
Other Utility Current Year to
Date (in dollars)
(k)
Other U tility Previous Year to
D ate (in dollars)
(l)
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original
(2) ☐ A R esubmission
Date of R eport:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
STATEMENT OF RETA INED EA RNINGS
Line No.Item
(a)
Contra Primary
Account Affected
(b)
Current Quarter/Year Year to
Date Balance
(c)
Previous Quarter/Year Year
to Date Balance
(d)
U NAPPROPRIATED R ETAINED EAR N INGS
(Account 216)
1 Balance-Begi nning of Period 1,811,045,130 1,657,584,781
2 C hanges
3 Adjustments to Retained Earnings (Account
439)
4 Adjustments to Retained Earnings Credit
4.1
4.2
4.3
4.4
4.5
4.6
4.7
4.8
4.9
4.10
9 TOTAL C redi ts to Retained Earnings (Acct. 439)
10 Adjustments to Retained Earnings Debit
10.1
10.2
10.3
10.4
10.5
10.6
10.7
10.8
10.9
10.10
15 TOTAL D ebits to Retai ned Earnings (Acct. 439)
16 Balance Transferred from Income (Account 433
l ess Account 418.1)248,776,483 246,084,627
FERC FORM No. 1 (R EV. 02-04)
Page 118-119
17 Appropriations of Retained Earnings (Acct. 436)
17.1
17.2
17.3
17.4
22 TOTAL Appropriations of Retai ned Earnings
(Acct. 436)
23 D ividends Declared-Preferred Stock (Account
437)
23.1
23.2
23.3
23.4
23.5
29 TOTAL D ividends Declared-Preferred Stock
(Acct. 437)
30 D ividends Declared-Common Stock (Account
438)
30.1 Acct 438 (102,038,351)(114,624,278)
30.2
30.3
30.4
30.5
36 TOTAL D ividends Declared-Common Stock
(Acct. 438)(102,038,351)(114,624,278)
37 Transfers from Acct 216.1, Unapprop. U ndistrib.
Subsidiary Earnings 0 22,000,000
38 Balance - End of Peri od (Total
1,9,15,16,22,29,36,37)1,957,783,262 1,811,045,130
39 APPROPRIATED RETAIN ED EARNIN GS
(Account 215)
39.1
39.2
39.3
39.4
39.5
39.6
STATEMENT OF RETA INED EA RNINGS
Line No.Item
(a)
Contra Primary
Account Affected
(b)
Current Quarter/Year Year to
Date Balance
(c)
Previous Quarter/Year Year
to Date Balance
(d)
FERC FORM No. 1 (R EV. 02-04)
Page 118-119
45 TOTAL Appropriated Retained Earnings
(Account 215)
APPROP. RETAINED EAR N INGS - AMOR T.
R eserve, Federal (Account 215.1)
46 TOTAL Approp. Retained Earni ngs-Amort.
R eserve, Federal (Acct. 215.1)13,273,106 13,273,106
47 TOTAL Approp. Retained Earni ngs (Acct. 215,
215.1) (Total 45,46)13,273,106 13,273,106
48 TOTAL R etained Earnings (Acct. 215, 215.1,
216) (Total 38, 47) (216.1)1,971,056,368 1,824,318,236
U NAPPROPRIATED U NDISTRIBUTED
SUBSIDIARY EARNINGS (Account Report
only on an Annual Basis, no Quarterly)
49 Balance-Begi nning of Year (Debit or Credit)12,228,426 25,446,384
50 Equity in Earnings for Year (Credit) (Account
418.1)8,033,987 8,782,042
51 (Less) Dividends R eceived (D ebit)0 22,000,000
52 TOTAL other Changes in unappropriated
undi stributed subsidiary earnings for the year
52.1
53 Balance-End of Year (Total lines 49 thru 52)20,262,413 12,228,426
FERC FORM No. 1 (R EV. 02-04)
Page 118-119
STATEMENT OF RETA INED EA RNINGS
Line No.Item
(a)
Contra Primary
Account Affected
(b)
Current Quarter/Year Year to
Date Balance
(c)
Previous Quarter/Year Year
to Date Balance
(d)
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original
(2) ☐ A R esubmission
Date of R eport:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
STATEMENT OF C ASH FLOWS
Line No.
Description (See Instructions No.1 for explanation of
codes)
(a)
Current Year to Date Quarter/Year
(b)
Previous Year to Date
Quarter/Year
(c)
1 Net Cash Flow from Operating Activities
2 Net Income (Line 78(c) on page 117)256,810,468 254,866,668
3 Noncash Charges (Credits) to Income:
4 Depreciation and Depletion 188,144,343 162,962,070
5 Amortization of (Specify) (footnote detai l s)
5.1 Plant 6,208,974 5,266,930
5.2 Unamorti zed debt expense 4,450,380 4,324,548
5.3 Unamorti zed discount (762,154)(866,599)
5.4 Water Ri ghts 1,042,009 1,042,009
5.5 Other 223,007 247,310
8 Deferred Income Taxes (N et)15,074,907 (10,454,124)
9 Investment Tax Credit Adjustment (Net)17,397,943 2,019,318
10 Net (Increase) D ecrease in Receivables (18,321,478)(72,305,949)
11 Net (Increase) D ecrease in Inventory (53,243,307)(11,626,320)
12 Net (Increase) D ecrease in Allowances Inventory 0 0
13 Net Increase (Decrease) in Payables and Accrued
Expenses
(a)(133,635,801)(e)164,086,842
14 Net (Increase) D ecrease in Other Regulatory Assets (27,414,539)(100,178,478)
15 Net Increase (Decrease) in Other Regulatory Liabilities 22,666,376 20,486,226
16 (Less) Allowance for Other Funds Used Duri ng
Construction 43,221,277 37,285,494
17 (Less) Undistributed Earni ngs from Subsidiary
Compani es 7,309,449 (4,884,745)
18 Other (provide details in footnote):
18.1 Pension and postretirement benefit plan expense 27,137,639 29,268,379
18.2 Contributi ons to pension and postretirement benefit plans (55,319,355)(44,175,136)
18.3 Changes in unbilled revenues 446,644 (8,479,542)
18.4 Changes in company owned life insurance (8,093,666)(6,763,262)
18.5 Other (987,530)2,097,770
18.6 Other (provide details in footnote):(b)15,462,270 (f)29,351,815
22 Net Cash Provided by (Used in) Operating Activities
(Total of Lines 2 thru 21)206,756,404 388,769,726
FERC FORM No. 1 (ED . 12-96)
Page 120-121
24 Cash Flow s from Investment Activities:
25 Construction and Acquisition of Plant (including l and):
26 Gross Additions to Uti l i ty Pl ant (less nuclear fuel )(c)(654,133,792)(g)(469,715,418)
27 Gross Additions to Nuclear Fuel 0 0
28 Gross Additions to Common Utility Plant 0 0
29 Gross Additions to Nonutil i ty Pl ant 0 0
30 (Less) Allowance for Other Funds Used Duri ng
Construction (43,221,277)(37,285,494)
31 Other (provide details in footnote):
31.1 Payments received from joint funding partners 26,501,460 17,778,170
31.2 Sale of renewable energy certi fi cates and emission
allow ances 6,198,155 2,042,118
31.3 Other (provide details in footnote):0 0
34 Cash Outflow s for Plant (Total of lines 26 thru 33)(578,212,900)(412,609,636)
36 Acquisiti on of Other Noncurrent Assets (d)0 0
37 Proceeds from Di sposal of Noncurrent Assets (d)0 0
39 Investments in and Advances to Assoc. and Subsidiary
Compani es 0 0
40 Contributi ons and Advances from Assoc. and Subsidiary
Compani es 0 0
41 Disposition of Investments in (and Advances to)
42 Disposition of Investments in (and Advances to)
Associated and Subsidiary Companies 0 0
44 Purchase of Investment Securi ti es (a)(12,858,324)(75,128,212)
45 Proceeds from Sal es of Investment Securities (a)8,921,330 63,857,030
46 Loans Made or Purchased 0 0
47 Collections on Loans 0 0
49 Net (Increase) D ecrease in Receivables 0 0
50 Net (Increase) D ecrease in Inventory 0 0
51 Net (Increase) D ecrease in Allowances Held for
Speculation 0 0
52 Net Increase (Decrease) in Payables and Accrued
Expenses 0 0
53 Other (provide details in footnote):
53.1 Other (provide details in footnote):0 (h)5,563,106
57 Net Cash Provided by (Used in) Investing Activiti es (Total
of lines 34 thru 55)(582,149,894)(418,317,712)
STATEMENT OF C ASH FLOWS
Line No.
Description (See Instructions No.1 for explanation of
codes)
(a)
Current Year to Date Quarter/Year
(b)
Previous Year to Date
Quarter/Year
(c)
FERC FORM No. 1 (ED . 12-96)
Page 120-121
59 Cash Flow s from Financing Activities:
60 Proceeds from Issuance of:
61 Long-Term D ebt (b)872,000,000 198,000,000
62 Preferred Stock 0 0
63 Common Stock 0 0
64 Other (provide details in footnote):
66 Net Increase in Short-Term D ebt (c)0
67 Other (provide details in footnote):
70 Cash Provided by Outside Sources (Total 61 thru 69)872,000,000 198,000,000
72 Payments for Retirement of:
73 Long-term Debt (b)(225,000,000)(4,359,999)
74 Preferred Stock
75 Common Stock
76 Other (provide details in footnote):
76.1 Other (d)(6,966,333)(738,529)
76.2 Other (provide details in footnote):0 0
78 Net Decrease in Short-Term Debt (c)
80 Dividends on Preferred Stock
81 Dividends on Common Stock (101,790,072)(114,447,348)
83 Net Cash Provided by (Used in) Financi ng Activities
(Total of lines 70 thru 81)538,243,595 78,454,124
85 Net Increase (Decrease) in Cash and Cash Equivalents
86 Net Increase (Decrease) in Cash and Cash Equivalents
(Total of line 22, 57 and 83)162,850,105 48,906,138
88 Cash and C ash Equivalents at Beginning of Period 108,681,369 59,775,231
90 Cash and C ash Equivalents at End of Period 271,531,474 108,681,369
FERC FORM No. 1 (ED . 12-96)
Page 120-121
STATEMENT OF C ASH FLOWS
Line No.
Description (See Instructions No.1 for explanation of
codes)
(a)
Current Year to Date Quarter/Year
(b)
Previous Year to Date
Quarter/Year
(c)
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original
(2) ☐ A R esubmission
Date of R eport:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
FOOTNOTE D ATA
(a) Concept: NetIncreaseD ecreaseInPayablesAndAccruedExpensesOperatingActivities
Cas h (receiv ed) paid during the period for:
Income taxes 56,971,384
Interest (net of amount c apitalized)97,402,344
(b) Concept: OtherAdjustmentsToCashFlowsFromOperatingActivities
C hanges in Accrued Interest $15,462,270
(c) C oncept: GrossAdditionsToU tilityPlantLessNuclearFuelInvestingActivities
Non-cash investing activ ities:
Additions to PP&E in accounts pay able 185,400,472
(d) Concept: OtherRetirementsOfBalancesImpactingCashFlow sFromFinancingActivi ties
Other Financing Cash Flows
Security deposits 10,000,000
Dis count on debt is suanc e (7,006,000)
Debt issuance cos t (9,960,333)
(6,966,333)
(e) Concept: NetIncreaseD ecreaseInPayablesAndAccruedExpensesOperatingActivities
Cash (received) paid during the period for:
Note 6 Income taxes (503,713)
Note 6 Interest (net of amount c apitalized)85,648,178
(f) Concept: OtherAdjustmentsToCashFl owsFromOperatingActi vities
Other l ong-term assets ($7,650,512)
Other current liabilities $23,335,227
Other l ong-term liabi lities $13,667,100
(g) Concept: GrossAddi tionsToUtilityPlantLessNuclearFuelInvestingActi vities
Non-cash inves ting ac tivities :
Note 7 Additions to PP&E in ac counts payable 84,323,931
(h) Concept: OtherAdjustmentsToCashFlowsFromInvestmentActivities
Life insurance proceeds received
FERC FORM No. 1 (ED. 12-96)
Page 120-121
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original
(2) ☐ A R esubmission
Date of R eport:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
NOTES TO FINANCIAL STATEMEN TS
1. Use the space below for important notes regarding the Balance Sheet, Statement of Income for the year, Statement of R etained
Earnings for the year, and Statement of Cash Flow s, or any account thereof. Cl assify the notes according to each basic statement,
providing a subheadi ng for each statement except where a note is applicable to more than one statement.
2. Furnish particulars (detail s) as to any si gnificant contingent assets or liabil i ties existi ng at end of year, including a brief explanation of
any action initiated by the Internal Revenue Service involving possible assessment of additi onal i ncome 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 divi dends in
arrears on cumulative preferred stock.
3. For Account 116, Utility Plant Adjustments, expl ain the ori gin of such amount, debits and credits during the year, and plan of
disposition contemplated, giving references to Commission orders or other authorizations respecting classification of amounts as plant
adjustments and requi rements 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, provi ding 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 i nformation not
misl eadi ng. Discl osures which would substantially duplicate the disclosures contai ned i n the most recent FERC Annual Report may
be omitted.
8. For the 3Q disclosures, the disclosures shall be provi ded w here events subsequent to the end of the most recent year have occurred
whi ch 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 pri nciples and practices; estimates inherent in the preparation of the financial statements;
status of long-term contracts; capitalization i ncluding significant new borrowings or modifications of existing financing agreements; and
changes resulting from business combinations or disposi tions. However were material conti ngencies exist, the disclosure of such
matters shall be provided even though a significant change si nce 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 herei n.

IDAHO POWER COMPANY
NOTES TO FINANCIAL STATEMENTS

1 . SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

Id aho Power Compan y (Idaho Po wer) is the princip al op eratin g subsidiary of IDACORP, Inc. (IDACORP), a h o lding comp any formed in 1998. Idah o Power is an electric u tility
engaged in the generation, transmission, d istribu tion, sales, and pu rchase of electric energ y an d capacity with a service area coverin g ap proximately 24,0 00 square miles in sou thern
Id aho and eastern Oreg o n. Id aho Power is regulated primarily by the state utility regulato ry co mmissions of Id aho and Oregon and the Fed eral En ergy Regulatory Commission
(FERC). Id aho Power is the parent o f Idah o Energy Resou rces Co. (IERCo), a joint-o wner of BCC, which mines and su pplies coal to the Jim Bridger plan t owned in part by Id aho
Power.

Basis of Reporting

Id aho Power's financial statements include the assets, liab ilities, rev enues, an d ex pen ses of the co mpany and have been p repared in accord ance with the acco unting requirements of
th e FERC as set forth in the applicable Uniform System of Accounts and p u blished accoun tin g releases, wh ich is a co mprehen sive basis o f accoun ting oth er than accounting
p rinciples gen erally accepted in the United States of America (U.S. GAAP). As required by th e FERC, Id aho Power accounts for its in v estments in its majority-owned subsidiary on th e
equity meth od rather th an consolidating th e assets, liabilities, revenues and exp enses of the sub sidiary as required by U.S GAAP. Th e accompanying finan cial statements include
Id aho Power's proportion ate sh are of the utility p lant and related op eratio ns resulting fro m its interest in jo intly-owned plan ts. In addition, under the requ irements of the FERC, there
are differences fro m U.S. GAAP in the presentation of (1) current portion of lon g-term deb t, (2) assets and liabilities fo r co st o f removal of assets, (3 ) regu latory assets and liabilities (4)
d eferred in come taxes, (5 ) inco me tax expense, (6) non -utility rev enu es, (7) accrued taxes, an d (8) d ebt issue costs.

Ma nagement Estimates

Manag ement makes estimates and assumptions when prep aring finan cial statements. These estimates and assu mption s includ e tho se related to rate reg ulation , retirement benefits,
conting encies, asset impairment, income taxes, u nbilled revenues, an d bad debt. These estimates and assu mption s affect the repo rted amo u nts of assets and liabilities and th e
d isclosure o f co ntingen t assets and liabilities at the d ate of the financial statements and th e reported amounts of revenues and expenses du rin g the repo rting period. These estimates
in volve judgmen ts with respect to, amo n g oth er thing s, future economic factors that are difficult to p redict an d are beyond man agement's control. Accord ingly, actual results cou ld
d iffer from those estimates.

Regulation of Utility Operations

As a regu lated utility, many of Idaho Power's fundamental b usin ess decisions are subject to th e approv al of governmental agencies, inclu ding th e prices that Idaho Po wer is auth orized
to ch arge for its electric service. Th ese appro vals are a critical factor in determin in g Idaho Po wer's resu lts o f operations and fin ancial condition .

Id aho Power meets the requirements to prepare its finan cial statements applying the sp ecialized rules to acco u nt for th e effects o f co st-based rate regulation. Id aho Power's fin ancial
statements reflect th e effects o f the different ratemaking princip les followed by the jurisdictio ns regu lating Idaho Power. Accounting for the economics of rate regulation impacts
multiple finan cial statement lin e items an d disclo su res, such as pro perty, plant, and equipment; regulatory assets and liabilities; o perating reven u es; O&M expense; depreciation
expense; and in come tax expen se. The ap plication of accoun tin g principles related to regulated operations sometimes results in Idaho Power recording ex penses and revenues in a
d ifferen t perio d than when an unreg ulated enterprise wo uld record su ch expenses an d rev enues. In th ese in stances, the amounts are d eferred or accrued as regulato ry assets o r
regulatory liabilities on the b alance sheet. Regu latory assets represent in curred co sts that have been deferred because it is pro bable they will be recovered from cu sto mers th ro ugh
fu ture rates. Regulato ry liab ilities represent o b ligation s to make refund s to cu sto mers for previo us collection s, or rep resent amo unts co llected in adv ance o f incu rrin g an ex pense. The
effects of ap plying these regulatory accountin g principles to Idaho Power's operations are d iscussed in more detail in Note 3 - "Reg ulatory M atters."

System o f Acco unts

Th e accounting records of Id aho Power conform to the Uniform System of Accounts p rescribed by the FERC and adopted by the public utility commission s o f Idah o, Oreg on, and
Wyomin g.

Name of Respondent:Idaho Power Company This report is:(1) ☑ An Original(2) ☐ A R esubmission Date of R eport:04/16/2024 Year/Period of ReportEnd of: 2023/ Q4NOTES TO FINANCIAL STATEMEN TS1. Use the space below for important notes regarding the Balance Sheet, Statement of Income for the year, Statement of R etainedEarnings for the year, and Statement of Cash Flow s, or any account thereof. Cl assify the notes according to each basic statement,providing a subheadi ng for each statement except where a note is applicable to more than one statement.2. Furnish particulars (detail s) as to any si gnificant contingent assets or liabil i ties existi ng at end of year, including a brief explanation ofany action initiated by the Internal Revenue Service involving possible assessment of additi onal i ncome taxes of material amount, orof a claim for refund of income taxes of a material amount initiated by the utility. Give also a brief explanation of any divi dends inarrears on cumulative preferred stock.3. For Account 116, Utility Plant Adjustments, expl ain the ori gin of such amount, debits and credits during the year, and plan ofdisposition contemplated, giving references to Commission orders or other authorizations respecting classification of amounts as plantadjustments and requi rements as to disposition thereof.4. Where Accounts 189, Unamortized Loss on Reacquired Debt, and 257, Unamortized Gain on Reacquired Debt, are not used, give anexplanation, provi ding 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 suchrestrictions.6. If the notes to financial statements relating to the respondent company appearing in the annual report to the stockholders areapplicable 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 i nformation notmisleading. Discl osures which would substantially duplicate the disclosures contai ned i n the most recent FERC Annual Report maybe omitted.8. For the 3Q disclosures, the disclosures shall be provi ded w here events subsequent to the end of the most recent year have occurredwhich have a material effect on the respondent. Respondent must include in the notes significant changes since the most recentlycompleted year in such items as: accounting pri nciples and practices; estimates inherent in the preparation of the financial statements;status of long-term contracts; capitalization i ncluding significant new borrowings or modifications of existing financing agreements; andchanges resulting from business combinations or disposi tions. However were material conti ngencies exist, the disclosure of suchmatters shall be provided even though a significant change si nce 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 areapplicable and furnish the data required by the above instructions, such notes may be included herei n. IDAHO POWER COMPANYNOTES TO FINANCIAL STATEMENTS 1 . SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES Id aho Power Compan y (Idaho Po wer) is the princip al op eratin g subsidiary of IDACORP, Inc. (IDACORP), a h o lding comp any formed in 1998. Idah o Power is an electric u tilityengaged in the generation, transmission, d istribu tion, sales, and pu rchase of electric energ y an d capacity with a service area coverin g ap proximately 24,0 00 square miles in sou thernIdaho and eastern Oreg o n. Id aho Power is regulated primarily by the state utility regulato ry co mmissions of Id aho and Oregon and the Fed eral En ergy Regulatory Commission(FERC). Id aho Power is the parent o f Idah o Energy Resou rces Co. (IERCo), a joint-o wner of BCC, which mines and su pplies coal to the Jim Bridger plan t owned in part by Id ahoPower. Basis of Reporting Id aho Power's financial statements include the assets, liab ilities, rev enues, an d ex pen ses of the co mpany and have been p repared in accord ance with the acco unting requirements ofthe FERC as set forth in the applicable Uniform System of Accounts and p u blished accoun tin g releases, wh ich is a co mprehen sive basis o f accoun ting oth er than accountingprinciples gen erally accepted in the United States of America (U.S. GAAP). As required by th e FERC, Id aho Power accounts for its in v estments in its majority-owned subsidiary on th eequity meth od rather th an consolidating th e assets, liabilities, revenues and exp enses of the sub sidiary as required by U.S GAAP. Th e accompanying finan cial statements includeIdaho Power's proportion ate sh are of the utility p lant and related op eratio ns resulting fro m its interest in jo intly-owned plan ts. In addition, under the requ irements of the FERC, thereare differences fro m U.S. GAAP in the presentation of (1) current portion of lon g-term deb t, (2) assets and liabilities fo r co st o f removal of assets, (3 ) regu latory assets and liabilities (4)d eferred in come taxes, (5 ) inco me tax expense, (6) non -utility rev enu es, (7) accrued taxes, an d (8) d ebt issue costs. Ma nagement Estimates Manag ement makes estimates and assumptions when prep aring finan cial statements. These estimates and assu mption s includ e tho se related to rate reg ulation , retirement benefits,conting encies, asset impairment, income taxes, u nbilled revenues, an d bad debt. These estimates and assu mption s affect the repo rted amo u nts of assets and liabilities and th edisclosure o f co ntingen t assets and liabilities at the d ate of the financial statements and th e reported amounts of revenues and expenses du rin g the repo rting period. These estimatesinvolve judgmen ts with respect to, amo n g oth er thing s, future economic factors that are difficult to p redict an d are beyond man agement's control. Accord ingly, actual results cou lddiffer from those estimates. Regulation of Utility Operations As a regu lated utility, many of Idaho Power's fundamental b usin ess decisions are subject to th e approv al of governmental agencies, inclu ding th e prices that Idaho Po wer is auth orizedto ch arge for its electric service. Th ese appro vals are a critical factor in determin in g Idaho Po wer's resu lts o f operations and fin ancial condition . Id aho Power meets the requirements to prepare its finan cial statements applying the sp ecialized rules to acco u nt for th e effects o f co st-based rate regulation. Id aho Power's fin ancialstatements reflect th e effects o f the different ratemaking princip les followed by the jurisdictio ns regu lating Idaho Power. Accounting for the economics of rate regulation impactsmultiple finan cial statement lin e items an d disclo su res, such as pro perty, plant, and equipment; regulatory assets and liabilities; o perating reven u es; O&M expense; depreciationexpense; and in come tax expen se. The ap plication of accoun tin g principles related to regulated operations sometimes results in Idaho Power recording ex penses and revenues in adifferent perio d than when an unreg ulated enterprise wo uld record su ch expenses an d rev enues. In th ese in stances, the amounts are d eferred or accrued as regulato ry assets o rregulatory liabilities on the b alance sheet. Regu latory assets represent in curred co sts that have been deferred because it is pro bable they will be recovered from cu sto mers th ro ughfuture rates. Regulato ry liab ilities represent o b ligation s to make refund s to cu sto mers for previo us collection s, or rep resent amo unts co llected in adv ance o f incu rrin g an ex pense. Theeffects of ap plying these regulatory accountin g principles to Idaho Power's operations are d iscussed in more detail in Note 3 - "Reg ulatory M atters." System o f Acco unts Th e accounting records of Id aho Power conform to the Uniform System of Accounts p rescribed by the FERC and adopted by the public utility commission s o f Idah o, Oreg on, and
Wyomin g.

Cash a nd Cash Equiv a lents

Cash and cash eq u ivalents inclu de cash o n-han d and hig h ly liquid temporary investments that mature with in 90 days o f the date of acqu isition .

Receiv ables a nd Allowance for Unco llectible Accounts

Customer receivables are recorded at the in voiced amou nts and do n o t bear interest. A late payment fee of on e percent per mo nth may b e assessed on account balances after 30 d ays.
An allowan ce is reco rded for potential unco llectib le accounts. The measurement of expected credit losses on Idah o Power accoun ts receivab le is based o n historical experience,
curren t economic cond itio ns, an d forecasted information that may affect collections on the o utstandin g balance. Generally, this includ es ad justmen ts b ased upon a comb ination of
h isto rical write-off ex perience, aging o f accou n ts receivab le, an analy sis o f sp ecific custo mer accoun ts, and an evaluatio n of whether th ere are current or forecasted economic
cond itio ns that might cau se variation in co llectio n from the histo rical exp erien ce. Adjustmen ts are charged to income. Customer acco unts receivable balances that remain o u tstanding
after reason able collection efforts are written off.

Th e follo wing table prov ides a rollforward of the allowance for un collectible accou nts related to customer receivab les (in tho usands of dollars):

Year Ended
December 31 ,
20 23 2022
Balance at beginning of period $ 5,0 34 $ 4 ,499
Add itio ns to the allo wance 3,6 17 3 ,265
Write-offs, net of reco v eries (3,7 82) (2 ,730 )
Balance at en d of p eriod $ 4,8 69 $ 5 ,034
Allowan ce for uncollectible accoun ts as a percentage of cu sto mer receivab les 4.3 % 4 .2 %

Other receivables are also rev iewed for imp airment periodically, based up on transactio n -sp ecific facts. When it is prob able that Idah o Power will b e u n able to collect all amounts due
according to the co ntractual terms of the agreement, an allowance is established for the estimated uncollectible p ortion o f the receivab le and charg ed to inco me.

Th ere were n o imp aired receivables withou t related allowances at Decemb er 31 , 202 3 an d 202 2. Once a receivable is determined to b e impaired, any fu rther in terest in come
reco gnized is fully reserved.

Derivativ e Fina ncial Instruments

Finan cial in stru men ts such as commod ity futures, forwards, o ptions, and swaps are u sed to man age ex posure to co mmo dity price risk in the electricity and natu ral gas markets. All
d erivative in stru men ts are reco gnized as either assets or liabilities at fair value on the b alance sheet unless th ey are d esignated as normal p u rchases and normal sales. With the
exception of forward con tracts fo r the purch ase o f natu ral gas for use at Id aho Power's n atural gas g eneration facilities an d a nomin al nu mber of po wer tran sactions, Idaho Power's
p hysical forward contracts are desig nated as normal purchases and normal sales. Because o f Idah o Power's reg u latory accoun tin g mech anisms, Id aho Power reco rd s the u nrealized
changes in fair v alue of derivativ e instruments related to po wer supply as reg ulatory assets or liabilities.

Revenues

Operating revenues are gen erally recorded when service is ren dered or energ y is delivered to customers. Idaho Po wer accrues estimated unbilled rev enues for electric services delivered
to cu stomers bu t not y et billed at year-end . Idaho Po wer does not report any collections of franchise fees an d similar taxes related to energy consumption o n the inco me statement. In
addition , reg ulatory mechanisms in p lace in Id aho and Oregon affect the rep orted amount o f revenue. The effects of applyin g these reg ulatory mechanisms are discu ssed in more detail
in Note 4 - "Reven ues."

Property, Plant, and Equipment and Depreciatio n

Th e cost of utility plan t in service represents the original cost o f con tracted serv ices, direct labo r and material, AFUDC, and in d irect charges fo r eng ineering, sup ervision, and similar
o verh ead items. Repair and maintenance costs asso ciated with planned major maintenan ce are ex p ensed as th e costs are in curred, as are mainten ance and repairs of property an d
replacemen ts and renewals of items determined to be less th an u nits of pro p erty. For utility prop erty replaced or renewed , the original co st p lus removal cost less salv age is charged to
accumu lated provision for depreciation , while th e cost of related rep lacements and ren ewals is ad d ed to prop erty, plan t, an d equipment.

All u tility plan t in serv ice is d epreciated u sin g the straight-line method at rates ap proved by regu latory autho rities. Annual dep reciation provisions as a percent of average dep reciable
u tility plant in serv ice app roximated 2.9 p ercent in 2023 and 2.7 percent in 202 2 .

Durin g the perio d of constructio n, costs expected to b e in cluded in th e fin al value of the co n stru cted asset, and dep reciated once the asset is comp lete and placed in service, are
classified as co nstru ction wo rk in pro gress on th e b alan ce sh eets. If the project becomes pro b able of b eing abandon ed, these costs are ex pensed in th e period such determination is
mad e. Id aho Power may seek recovery of these costs in cu stomer rates, althoug h there can be n o guaran tee su ch recov ery wou ld be gran ted.

Lo ng-lived assets are p eriodically reviewed for impairment wh en even ts or ch anges in circumstances indicate that th e carryin g amount of an asset may not be recoverable. If th e sum of
th e u n discoun ted expected future cash flows from an asset is less than the carrying v alue of the asset, impairment is recognized in the finan cial statements. Th ere were n o material
impairmen ts o f long-lived assets in 202 3 an d 202 2.

Allowance fo r Funds Used During Construction

AFUDC represents the cost o f financing construction pro jects with b o rrowed fu nds an d eq uity fun d s. With o ne exception , for the HCC relicensin g project, cash is not realized
curren tly from such allowan ce; it is realized under the ratemaking p ro cess ov er the service life of th e related prop erty th ro ugh in creased revenues resulting from a higher rate base an d
h igher dep reciation expense. Th e comp o nen t of AFUDC attributab le to borrowed funds is included as a red uction to total non o perating expense, n et. Id aho Power's weighted -average
monthly AFUDC rate was 7.4 percen t for 20 23 and 20 22.

Income Taxes

Id aho Power account fo r inco me taxes under the asset and liability metho d, which req u ires the recognition of deferred tax assets and liabilities for th e expected future tax
conseq uen ces o f events that hav e been inclu ded in the finan cial statements. Und er this method (commo n ly referred to as n ormalized acco u nting), deferred tax assets and liabilities are
d etermined based on the differences between the financial statemen ts and tax b asis of assets and liabilities using enacted tax rates in effect fo r the year in which the differences are
expected to reverse. In g eneral, deferred in come tax expen se or b enefit for a rep orting period is recog nized as th e chan ge in deferred tax assets and liabilities from th e beginnin g to th e
end of the perio d. The effect o f a change in tax rates on d eferred tax assets and liabilities is recogn ized in income in th e p eriod th at includes the enactment date unless Idaho Po wer's
p rimary reg u lator, the IPUC, orders d irect deferral o f the effect of th e chan ge in tax rates o ver a lon g er p eriod o f time.

Con sisten t with orders and directiv es of th e IPUC, u n less con trary to app licab le income tax guid ance, Id aho Power d oes no t record d eferred income tax ex pense or benefit for certain
in come tax temporary differences and in stead reco gnizes the tax impact currently (common ly referred to as flow-throu gh accounting ) for rate making and finan cial reportin g.
Th erefo re, Id aho Power's effective inco me tax rate is impacted as these differences arise an d rev erse. Idaho Power reco gnizes such adjustments as regulatory assets o r liabilities if it is
p robab le th at such amounts will be recovered fro m or returned to customers in fu tu re rates.

Id aho Power u se judg men t, estimation, and historical data in developing the provision fo r inco me taxes and the reportin g of tax-related assets and liabilities, inclu ding d evelopment
o f cu rrent y ear tax d epreciatio n, capitalized rep air costs, capitalized o verh ead s, and other items. Inco me taxes can be imp acted by ch anges in tax laws an d reg ulation s, interpretation s
b y tax ing authorities, changes to acco unting g uidan ce, an d actions b y fed eral or state public utility regulators. Actual inco me taxes cou ld vary from estimated amo unts an d may resu lt
in fav o rable or u n favo rable impacts to net in come, cash flo ws, and tax-related assets an d liab ilities.

In co mplian ce with the federal in come tax requirements for the u se of accelerated tax dep reciation, Idah o Power reco rds deferred income taxes related to its p lant assets for the
d ifferen ce between in come tax depreciation and book dep reciation used fo r financial statement p u rposes. Deferred inco me taxes are recorded for oth er temporary differences un less
accounted for usin g flow-throug h.

In vestment tax credits earned on regulated assets are deferred and amortized to in come o ver th e estimated service liv es of th e related prop erties.

In come taxes are d iscussed in more detail in Note 2 - "In come Taxes."

Cash a nd Cash Equiv a lents Cash and cash eq u ivalents inclu de cash o n-han d and hig h ly liquid temporary investments that mature with in 90 days o f the date of acqu isition . Receiv ables a nd Allowance for Unco llectible Accounts Customer receivables are recorded at the in voiced amou nts and do n o t bear interest. A late payment fee of on e percent per mo nth may b e assessed on account balances after 30 d ays.An allowan ce is reco rded for potential unco llectib le accounts. The measurement of expected credit losses on Idah o Power accoun ts receivab le is based o n historical experience,curren t economic cond itio ns, an d forecasted information that may affect collections on the o utstandin g balance. Generally, this includ es ad justmen ts b ased upon a comb ination ofhistorical write-off ex perience, aging o f accou n ts receivab le, an analy sis o f sp ecific custo mer accoun ts, and an evaluatio n of whether th ere are current or forecasted economicconditions that might cau se variation in co llectio n from the histo rical exp erien ce. Adjustmen ts are charged to income. Customer acco unts receivable balances that remain o u tstandingafter reason able collection efforts are written off. Th e follo wing table prov ides a rollforward of the allowance for un collectible accou nts related to customer receivab les (in tho usands of dollars): Year EndedDecember 31 , 20 23 2022Balance at beginning of period $ 5,0 34 $ 4 ,499Additions to the allo wance 3,6 17 3 ,265Write-offs, net of reco v eries (3,7 82) (2 ,730 )Balance at en d of p eriod $ 4,8 69 $ 5 ,034Allowance for uncollectible accoun ts as a percentage of cu sto mer receivab les 4.3 % 4 .2 % Other receivables are also rev iewed for imp airment periodically, based up on transactio n -sp ecific facts. When it is prob able that Idah o Power will b e u n able to collect all amounts dueaccording to the co ntractual terms of the agreement, an allowance is established for the estimated uncollectible p ortion o f the receivab le and charg ed to inco me. Th ere were n o imp aired receivables withou t related allowances at Decemb er 31 , 202 3 an d 202 2. Once a receivable is determined to b e impaired, any fu rther in terest in comerecognized is fully reserved. Derivativ e Fina ncial Instruments Finan cial in stru men ts such as commod ity futures, forwards, o ptions, and swaps are u sed to man age ex posure to co mmo dity price risk in the electricity and natu ral gas markets. Allderivative in stru men ts are reco gnized as either assets or liabilities at fair value on the b alance sheet unless th ey are d esignated as normal p u rchases and normal sales. With theexception of forward con tracts fo r the purch ase o f natu ral gas for use at Id aho Power's n atural gas g eneration facilities an d a nomin al nu mber of po wer tran sactions, Idaho Power'sphysical forward contracts are desig nated as normal purchases and normal sales. Because o f Idah o Power's reg u latory accoun tin g mech anisms, Id aho Power reco rd s the u nrealizedchanges in fair v alue of derivativ e instruments related to po wer supply as reg ulatory assets or liabilities. Revenues Operating revenues are gen erally recorded when service is ren dered or energ y is delivered to customers. Idaho Po wer accrues estimated unbilled rev enues for electric services deliveredto cu stomers bu t not y et billed at year-end . Idaho Po wer does not report any collections of franchise fees an d similar taxes related to energy consumption o n the inco me statement. Inaddition, reg ulatory mechanisms in p lace in Id aho and Oregon affect the rep orted amount o f revenue. The effects of applyin g these reg ulatory mechanisms are discu ssed in more detailin Note 4 - "Reven ues." Property, Plant, and Equipment and Depreciatio n Th e cost of utility plan t in service represents the original cost o f con tracted serv ices, direct labo r and material, AFUDC, and in d irect charges fo r eng ineering, sup ervision, and similaroverhead items. Repair and maintenance costs asso ciated with planned major maintenan ce are ex p ensed as th e costs are in curred, as are mainten ance and repairs of property an dreplacements and renewals of items determined to be less th an u nits of pro p erty. For utility prop erty replaced or renewed , the original co st p lus removal cost less salv age is charged toaccumulated provision for depreciation , while th e cost of related rep lacements and ren ewals is ad d ed to prop erty, plan t, an d equipment. All u tility plan t in serv ice is d epreciated u sin g the straight-line method at rates ap proved by regu latory autho rities. Annual dep reciation provisions as a percent of average dep reciableutility plant in serv ice app roximated 2.9 p ercent in 2023 and 2.7 percent in 202 2 . Durin g the perio d of constructio n, costs expected to b e in cluded in th e fin al value of the co n stru cted asset, and dep reciated once the asset is comp lete and placed in service, areclassified as co nstru ction wo rk in pro gress on th e b alan ce sh eets. If the project becomes pro b able of b eing abandon ed, these costs are ex pensed in th e period such determination ismade. Id aho Power may seek recovery of these costs in cu stomer rates, althoug h there can be n o guaran tee su ch recov ery wou ld be gran ted. Lo ng-lived assets are p eriodically reviewed for impairment wh en even ts or ch anges in circumstances indicate that th e carryin g amount of an asset may not be recoverable. If th e sum ofthe u n discoun ted expected future cash flows from an asset is less than the carrying v alue of the asset, impairment is recognized in the finan cial statements. Th ere were n o materialimpairments o f long-lived assets in 202 3 an d 202 2. Allowance fo r Funds Used During Construction AFUDC represents the cost o f financing construction pro jects with b o rrowed fu nds an d eq uity fun d s. With o ne exception , for the HCC relicensin g project, cash is not realizedcurrently from such allowan ce; it is realized under the ratemaking p ro cess ov er the service life of th e related prop erty th ro ugh in creased revenues resulting from a higher rate base an dhigher dep reciation expense. Th e comp o nen t of AFUDC attributab le to borrowed funds is included as a red uction to total non o perating expense, n et. Id aho Power's weighted -averagemonthly AFUDC rate was 7.4 percen t for 20 23 and 20 22. Income Taxes Id aho Power account fo r inco me taxes under the asset and liability metho d, which req u ires the recognition of deferred tax assets and liabilities for th e expected future taxconsequences o f events that hav e been inclu ded in the finan cial statements. Und er this method (commo n ly referred to as n ormalized acco u nting), deferred tax assets and liabilities aredetermined based on the differences between the financial statemen ts and tax b asis of assets and liabilities using enacted tax rates in effect fo r the year in which the differences areexpected to reverse. In g eneral, deferred in come tax expen se or b enefit for a rep orting period is recog nized as th e chan ge in deferred tax assets and liabilities from th e beginnin g to th eend of the perio d. The effect o f a change in tax rates on d eferred tax assets and liabilities is recogn ized in income in th e p eriod th at includes the enactment date unless Idaho Po wer'sprimary reg u lator, the IPUC, orders d irect deferral o f the effect of th e chan ge in tax rates o ver a lon g er p eriod o f time. Con sisten t with orders and directiv es of th e IPUC, u n less con trary to app licab le income tax guid ance, Id aho Power d oes no t record d eferred income tax ex pense or benefit for certainincome tax temporary differences and in stead reco gnizes the tax impact currently (common ly referred to as flow-throu gh accounting ) for rate making and finan cial reportin g.Th erefo re, Id aho Power's effective inco me tax rate is impacted as these differences arise an d rev erse. Idaho Power reco gnizes such adjustments as regulatory assets o r liabilities if it isprobable th at such amounts will be recovered fro m or returned to customers in fu tu re rates. Id aho Power u se judg men t, estimation, and historical data in developing the provision fo r inco me taxes and the reportin g of tax-related assets and liabilities, inclu ding d evelopmentof cu rrent y ear tax d epreciatio n, capitalized rep air costs, capitalized o verh ead s, and other items. Inco me taxes can be imp acted by ch anges in tax laws an d reg ulation s, interpretation sby tax ing authorities, changes to acco unting g uidan ce, an d actions b y fed eral or state public utility regulators. Actual inco me taxes cou ld vary from estimated amo unts an d may resu ltin fav o rable or u n favo rable impacts to net in come, cash flo ws, and tax-related assets an d liab ilities. In co mplian ce with the federal in come tax requirements for the u se of accelerated tax dep reciation, Idah o Power reco rds deferred income taxes related to its p lant assets for thedifference between in come tax depreciation and book dep reciation used fo r financial statement p u rposes. Deferred inco me taxes are recorded for oth er temporary differences un lessaccounted for usin g flow-throug h. In vestment tax credits earned on regulated assets are deferred and amortized to in come o ver th e estimated service liv es of th e related prop erties.

In come taxes are d iscussed in more detail in Note 2 - "In come Taxes."

Other Accounting Policies

Debt disco u nt, expense, and p remiu m are d eferred and amortized over the terms of the respective d ebt issuances. Losses on reacquired debt an d associated costs are amortized o ver th e
life of th e associated rep lacement debt, as allo wed und er regulato ry acco unting.

New a nd Recently Adopted Accounting Prono uncements

Recently Ad opted Accountin g Pronou ncements

Th ere hav e been no recently adopted acco unting pronou n cemen ts that h ave had a material impact on Idah o Power's finan cial statements.

2 . INCOME TAXES

A reco nciliation between the statutory federal income tax rate an d the effective tax rate is as follo ws (in th ousand s):

2 023 20 22

Federal in come tax expen se at statutory rate $ 5 9 ,676 $ 61,623
Change in taxes resu ltin g from:
Equity earnings of sub sid iary comp anies (1 ,687 ) (1,844)
AFUDC (1 3 ,279 ) (10,752)
Capitalized interest 3 ,097 1,633
Inv estmen t tax credits (5 ,451 ) (3,119)
Removal costs (6 ,312 ) (4,900)
Capitalized ov erhead costs (2 ,100 ) (3,150)
Capitalized rep air costs (2 4 ,360 ) (19,320)
State in come taxes, n et o f federal b enefit 1 6 ,081 18,352
Depreciation 1 8 ,041 11,897
Excess deferred inco me tax reversal (1 0 ,684 ) (11,405)
Income tax return ad ju stments (7 ,282 ) (2,034)
Other, net 1 ,619 1,596
Total income tax expense $ 2 7 ,359 $ 38,577
Effectiv e tax rate 9.6 % 13.1%

Th e items co mprising in come tax expense are as follows (in thousands):

202 3 2022

Income taxes current:
Federal $ (3,7 17) $ 3 3,05 6
State 3,6 27 11,71 5
Total (90) 4 4,77 1
Income taxes deferred:
Federal (21,6 93) (9,81 8 )
State (1,0 51) (2,20 2 )
Total (22,7 44) (1 2,02 0 )
Inv estment tax credits:
Deferred 55,6 44 8,94 5
Restored (5,4 51) (3 ,11 9 )
Total 50,1 93 5,82 6
Total in come tax expen se $ 27,3 59 $ 3 8,57 7

Th e comp onen ts o f the net deferred tax liability are as follows (in thousands):
20 23 2 022

Deferred tax a ssets:
Regu latory liabilities $ 108 ,641 $ 9 4,946
Deferred compensatio n 24 ,288 2 4,495
Deferred revenue 58 ,860 5 3,418
Tax credits 49 ,734 4 4,727
Retiremen t ben efits 44 ,803 3 8,687
Other 15 ,972 1 0,133
Total 302 ,298 26 6,406
Deferred tax lia bilities:
Pro p erty, plant an d eq uipment 266 ,992 24 9,452
Regu latory assets 774 ,672 73 9,689
Po wer co st adjustment 29 ,742 33 ,116
Retiremen t ben efits 94 ,231 8 0,777
Other 30 ,363 4 9,322
Total 1,196 ,000 1,15 2,356
Net deferred tax liabilities $ 893 ,702 $ 88 5,950

IDACORP's tax allocation agreement prov ides that each member of its consolidated g ro up comp ute its income taxes on a separate comp any basis. Amou nts pay able or refundable are
Other Accounting Policies Debt disco u nt, expense, and p remiu m are d eferred and amortized over the terms of the respective d ebt issuances. Losses on reacquired debt an d associated costs are amortized o ver th elife of th e associated rep lacement debt, as allo wed und er regulato ry acco unting. New a nd Recently Adopted Accounting Prono uncements Recently Ad opted Accountin g Pronou ncements Th ere hav e been no recently adopted acco unting pronou n cemen ts that h ave had a material impact on Idah o Power's finan cial statements. 2 . INCOME TAXES A reco nciliation between the statutory federal income tax rate an d the effective tax rate is as follo ws (in th ousand s): 2 023 20 22 Federal in come tax expen se at statutory rate $ 5 9 ,676 $ 61,623 Change in taxes resu ltin g from: Equity earnings of sub sid iary comp anies (1 ,687 ) (1,844) AFUDC (1 3 ,279 ) (10,752) Capitalized interest 3 ,097 1,633 Inv estmen t tax credits (5 ,451 ) (3,119) Removal costs (6 ,312 ) (4,900) Capitalized ov erhead costs (2 ,100 ) (3,150) Capitalized rep air costs (2 4 ,360 ) (19,320) State in come taxes, n et o f federal b enefit 1 6 ,081 18,352 Depreciation 1 8 ,041 11,897 Excess deferred inco me tax reversal (1 0 ,684 ) (11,405) Income tax return ad ju stments (7 ,282 ) (2,034) Other, net 1 ,619 1,596 Total income tax expense $ 2 7 ,359 $ 38,577 Effectiv e tax rate 9.6 % 13.1% Th e items co mprising in come tax expense are as follows (in thousands): 202 3 2022 Income taxes current: Federal $ (3,7 17) $ 3 3,05 6 State 3,6 27 11,71 5 Total (90) 4 4,77 1 Income taxes deferred: Federal (21,6 93) (9,81 8 ) State (1,0 51) (2,20 2 ) Total (22,7 44) (1 2,02 0 ) Inv estment tax credits: Deferred 55,6 44 8,94 5 Restored (5,4 51) (3 ,11 9 ) Total 50,1 93 5,82 6 Total in come tax expen se $ 27,3 59 $ 3 8,57 7 Th e comp onen ts o f the net deferred tax liability are as follows (in thousands): 20 23 2 022 Deferred tax a ssets: Regu latory liabilities $ 108 ,641 $ 9 4,946Deferred compensatio n 24 ,288 2 4,495Deferred revenue 58 ,860 5 3,418Tax credits 49 ,734 4 4,727Retirement ben efits 44 ,803 3 8,687Other 15 ,972 1 0,133Total 302 ,298 26 6,406Deferred tax lia bilities: Pro p erty, plant an d eq uipment 266 ,992 24 9,452Regulatory assets 774 ,672 73 9,689Power co st adjustment 29 ,742 33 ,116Retirement ben efits 94 ,231 8 0,777Other 30 ,363 4 9,322Total 1,196 ,000 1,15 2,356
Net deferred tax liabilities $ 893 ,702 $ 88 5,950

IDACORP's tax allocation agreement prov ides that each member of its consolidated g ro up comp ute its income taxes on a separate comp any basis. Amou nts pay able or refundable areIDACORP's tax allocation agreement prov ides that each member of its consolidated g ro up comp ute its income taxes on a separate comp any basis. Amou nts pay able or refundable are
settled th rough IDACORP and are repo rted as taxes accrued or in come taxes receivab le, respectively, on the balance sheets of Idaho Po wer. See No te 1 - "Summary of Sign ifican t
Accoun ting Po licies" for fu rth er d iscussion of accounting policies related to inco me taxes.

Uncertain Tax Positions

Id aho Power b eliev es that it has no material income tax uncertain ties for 2 0 23 and p rio r tax years. Idaho Po wer recognizes interest accru ed related to u nrecognized tax b enefits as
in terest expense and p enalties as o th er expense.

Id aho Power is subject to ex amin ation by its major tax jurisdictio ns - United States federal and th e State o f Idah o. The op en tax years for examination are 2 0 20-202 1 an d 20 2 3 for
federal and 20 22-202 3 for Id aho. In May 200 9 , IDACORP formally entered th e U.S. Intern al Rev enue Service (IRS) Compliance Assurance Pro cess (CAP) program fo r its 2009 tax y ear
and has remain ed in the CAP program fo r all subsequen t years. In 2 023, the IRS completed its ex amin ation of the 2022 tax year with no unresolved income tax issu es.

Excess Deferred Income Taxes

Following the enactmen t of income tax refo rm in 2017, Idah o Power was requ ired to remeasure its deferred tax assets an d liab ilities at th e new federal corporate in come tax rate which
resulted in lower n et d eferred tax liab ilities an d the estab lishment of a net regulatory liability for its d epreciatio n-related excess deferred in come taxes (EDIT). Id aho Power's d eferred
taxes fo r dep reciation-related temporary differences on its p ublic utility prop erty are sub ject to the normalization meth od of accoun tin g. As provid ed in the 2017 inco me tax reform
statute, the n ormalizatio n method requ ires the use o f either the average rate assumption metho d (ARAM) or th e alternative meth od for the reversal of the EDIT. In 2021, Idaho Po wer
b egan using the altern ative method fo r the EDIT reversal pursuan t to the interpretation of an In ternal Revenue Serv ice revenue procedure an d series of related private letter ruling s.
Th e alternative meth od resu lts in the ratab le return of the EDIT to customers over the remaining regu latory liv es of Id aho Power's plant assets. For fiscal y ears 2 018-20 2 0, th e ARAM
meth o d was used to reverse the EDIT.

3 . REGULATORY MATTERS

Id aho Power's financial statements reflect th e effects o f the different ratemaking p rinciples followed by the jurisdictio ns regu lating Id aho Power. Included belo w is a summary of Idaho
Power's regulatory assets and liabilities, as well as a discussion of no table regu latory matters.

Regulatory Assets and Liabilities

Th e application o f accou nting p rin ciples related to regu lated operations sometimes results in Id aho Power record ing some expen ses and revenues in a different period than when an
u nreg u lated en terprise wou ld record th ose expen ses and revenues. Regulatory assets represent incurred costs that hav e b een deferred because it is probable they will be reco v ered from
customers throug h future rates. Regulatory liabilities represen t obligations to make refu nds to customers for previous collections, or represent amoun ts collected in advan ce of
in curring an exp ense.

Th e follo wing table presents a su mmary of Idaho Power's regu latory assets and liabilities (in thou sands of d ollars):
As of December 31, 2023

Remaining
Amortization
Period
Earning a
Return(1)

Not
Earning a
Return
Tota l as of December 31,
Description 2023 20 22
Regulatory Assets:
Income tax es(2) $ $ 774 ,672 $ 774,6 72 $ 739,689
Unfund ed p ostretirement b enefits(3) 87 ,318 87,3 18 70,254
Pension expense deferrals(4 ) 2 53,74 4 1 ,500 255,2 44 249,503
Energy efficien cy program costs(5 ) 3,767
Po wer supply costs(6) 2024-2 025 1 34,81 6 (19 ,353) 115,4 63 129,309
Fix ed cost ad ju stment(6) 2024-2 025 36,03 7 15 ,248 51,2 85 41,901
North Valmy plan t settlements(6) 2024-2 028 82,91 7 82,9 17 90,747
Jim Bridger plant settlemen t(6) 2024-2 030 1 08,37 6 15 ,256 123,6 32 80,531
Wildfire Mitigatio n Plan deferral(6) 51 ,329 51,3 29 27,078
Asset retiremen t obligations(7) 35 ,270 35,2 70 28,780
Long -term service ag reemen t 2024-2 043 12,67 9 8 ,276 20,9 55 22,114
Other 2024-2 056 2,33 0 52 ,573 54,9 03 18,288
Total $ 6 30,89 9 $ 1,022 ,089 $ 1,652,9 88 $ 1 ,501,961
Regulatory Liabilities:
Income tax es(8) $ $ 108 ,641 $ 108,6 41 $ 94,946
Depreciation-related excess deferred
income tax es(9) 1 47,95 0 147,9 50 158,634
Energy efficien cy program costs(5 ) 1,50 7 1,5 07 154
Po wer supply costs(6) 1,24 0 1,2 40
Mark -to-market liabilities 88 88 59,544
Tax reform accrual fo r future
amortization(10) 40 ,891 40,8 91 32,793
Other 8,38 3 4 ,335 12,7 18 11,630
Total $ 1 59,08 0 $ 153 ,955 $ 313,0 35 $ 357,701

(1) Earning a return includes either interest or a return on the investmen t as a com po nent of rate b ase at the allo wed rate of return. The interest rate on deferral accounts is p ublished annually by the IPUC and
OPUC. The ap plicable rates fo r 2023 were 2% and 4.5%, respectively.
(2) Represents flow-through in come tax acco unting differences which h av e a correspon ding deferred tax liability disclo sed in Note 2 - "In come Taxes."
(3) Represents the unfu nd ed oblig ation of Idaho Power's p en sion and postretiremen t b en efit plans, wh ich are discu ssed in Note 10 - "Benefit Plans."
(4) Id ah o Power records a reg ulato ry asset fo r the difference between net periodic pen sion cost an d p ensio n cost considered fo r rate-making purposes relatin g to Id aho Power's defined benefit pension plan . In its
Idaho jurisdiction , Id ah o Power's inclu sion of pension co sts fo r the establishment of retail rates is based u po n contribution s mad e to the pen sion plan. This regulato ry asset acco unt represents the difference
between cumu lative cash co ntribution s and amo unts collected in rates. Deferred costs are am ortized into expense as the amou nts are p rovided for in Idah o retail revenues.
(5) The energy efficien cy asset and liability represent the separate Idaho and Oreg on jurisdiction balances at Decem ber 31, 2022, and Decemb er 31, 2023, respectiv ely. During 2023, the balances ch anged from an
asset to a liability in the Id aho jurisdictio n.
(6) This item is discussed in more detail in this Note 3 - "Regu latory Matters."
(7) Asset retirem ent o bligatio ns and removal co sts are discu ssed in Note 12 - "Asset Retirement Obligations (ARO)."
(8) Represents the tax gross-up related to th e depreciation-related excess deferred in come taxes and inv estment tax credits in cluded in this table an d h as a co rrespon ding deferred tax asset disclosed in No te 2 -
"Income Tax es."
IDACORP's tax allocation agreement prov ides that each member of its consolidated g ro up comp ute its income taxes on a separate comp any basis. Amou nts pay able or refundable aresettled th rough IDACORP and are repo rted as taxes accrued or in come taxes receivab le, respectively, on the balance sheets of Idaho Po wer. See No te 1 - "Summary of Sign ifican tAccounting Po licies" for fu rth er d iscussion of accounting policies related to inco me taxes. Uncertain Tax Positions Id aho Power b eliev es that it has no material income tax uncertain ties for 2 0 23 and p rio r tax years. Idaho Po wer recognizes interest accru ed related to u nrecognized tax b enefits asinterest expense and p enalties as o th er expense. Id aho Power is subject to ex amin ation by its major tax jurisdictio ns - United States federal and th e State o f Idah o. The op en tax years for examination are 2 0 20-202 1 an d 20 2 3 forfederal and 20 22-202 3 for Id aho. In May 200 9 , IDACORP formally entered th e U.S. Intern al Rev enue Service (IRS) Compliance Assurance Pro cess (CAP) program fo r its 2009 tax y earand has remain ed in the CAP program fo r all subsequen t years. In 2 023, the IRS completed its ex amin ation of the 2022 tax year with no unresolved income tax issu es. Excess Deferred Income Taxes Following the enactmen t of income tax refo rm in 2017, Idah o Power was requ ired to remeasure its deferred tax assets an d liab ilities at th e new federal corporate in come tax rate whichresulted in lower n et d eferred tax liab ilities an d the estab lishment of a net regulatory liability for its d epreciatio n-related excess deferred in come taxes (EDIT). Id aho Power's d eferredtaxes fo r dep reciation-related temporary differences on its p ublic utility prop erty are sub ject to the normalization meth od of accoun tin g. As provid ed in the 2017 inco me tax reformstatute, the n ormalizatio n method requ ires the use o f either the average rate assumption metho d (ARAM) or th e alternative meth od for the reversal of the EDIT. In 2021, Idaho Po werbegan using the altern ative method fo r the EDIT reversal pursuan t to the interpretation of an In ternal Revenue Serv ice revenue procedure an d series of related private letter ruling s.Th e alternative meth od resu lts in the ratab le return of the EDIT to customers over the remaining regu latory liv es of Id aho Power's plant assets. For fiscal y ears 2 018-20 2 0, th e ARAMmethod was used to reverse the EDIT. 3 . REGULATORY MATTERS Id aho Power's financial statements reflect th e effects o f the different ratemaking p rinciples followed by the jurisdictio ns regu lating Id aho Power. Included belo w is a summary of IdahoPower's regulatory assets and liabilities, as well as a discussion of no table regu latory matters. Regulatory Assets and Liabilities Th e application o f accou nting p rin ciples related to regu lated operations sometimes results in Id aho Power record ing some expen ses and revenues in a different period than when anunregulated en terprise wou ld record th ose expen ses and revenues. Regulatory assets represent incurred costs that hav e b een deferred because it is probable they will be reco v ered fromcustomers throug h future rates. Regulatory liabilities represen t obligations to make refu nds to customers for previous collections, or represent amoun ts collected in advan ce ofincurring an exp ense. Th e follo wing table presents a su mmary of Idaho Power's regu latory assets and liabilities (in thou sands of d ollars): As of December 31, 2023 RemainingAmortizationPeriod Earning aReturn(1) NotEarning aReturn Tota l as of December 31,Description 2023 20 22Regulatory Assets: Income tax es(2) $ $ 774 ,672 $ 774,6 72 $ 739,689Unfunded p ostretirement b enefits(3) 87 ,318 87,3 18 70,254Pension expense deferrals(4 ) 2 53,74 4 1 ,500 255,2 44 249,503Energy efficien cy program costs(5 ) 3,767Power supply costs(6) 2024-2 025 1 34,81 6 (19 ,353) 115,4 63 129,309Fixed cost ad ju stment(6) 2024-2 025 36,03 7 15 ,248 51,2 85 41,901North Valmy plan t settlements(6) 2024-2 028 82,91 7 82,9 17 90,747Jim Bridger plant settlemen t(6) 2024-2 030 1 08,37 6 15 ,256 123,6 32 80,531Wildfire Mitigatio n Plan deferral(6) 51 ,329 51,3 29 27,078Asset retiremen t obligations(7) 35 ,270 35,2 70 28,780Long-term service ag reemen t 2024-2 043 12,67 9 8 ,276 20,9 55 22,114Other 2024-2 056 2,33 0 52 ,573 54,9 03 18,288Total $ 6 30,89 9 $ 1,022 ,089 $ 1,652,9 88 $ 1 ,501,961Regulatory Liabilities: Income tax es(8) $ $ 108 ,641 $ 108,6 41 $ 94,946Depreciation-related excess deferredincome tax es(9) 1 47,95 0 147,9 50 158,634Energy efficien cy program costs(5 ) 1,50 7 1,5 07 154Power supply costs(6) 1,24 0 1,2 40 Mark -to-market liabilities 88 88 59,544Tax reform accrual fo r futureamortization(10) 40 ,891 40,8 91 32,793Other 8,38 3 4 ,335 12,7 18 11,630Total $ 1 59,08 0 $ 153 ,955 $ 313,0 35 $ 357,701 (1) Earning a return includes either interest or a return on the investmen t as a com po nent of rate b ase at the allo wed rate of return. The interest rate on deferral accounts is p ublished annually by the IPUC andOPUC. The ap plicable rates fo r 2023 were 2% and 4.5%, respectively.(2) Represents flow-through in come tax acco unting differences which h av e a correspon ding deferred tax liability disclo sed in Note 2 - "In come Taxes."(3) Represents the unfu nd ed oblig ation of Idaho Power's p en sion and postretiremen t b en efit plans, wh ich are discu ssed in Note 10 - "Benefit Plans."(4) Id ah o Power records a reg ulato ry asset fo r the difference between net periodic pen sion cost an d p ensio n cost considered fo r rate-making purposes relatin g to Id aho Power's defined benefit pension plan . In itsIdaho jurisdiction , Id ah o Power's inclu sion of pension co sts fo r the establishment of retail rates is based u po n contribution s mad e to the pen sion plan. This regulato ry asset acco unt represents the differencebetween cumu lative cash co ntribution s and amo unts collected in rates. Deferred costs are am ortized into expense as the amou nts are p rovided for in Idah o retail revenues.(5) The energy efficien cy asset and liability represent the separate Idaho and Oreg on jurisdiction balances at Decem ber 31, 2022, and Decemb er 31, 2023, respectiv ely. During 2023, the balances ch anged from anasset to a liability in the Id aho jurisdictio n.(6) This item is discussed in more detail in this Note 3 - "Regu latory Matters."
(7) Asset retirem ent o bligatio ns and removal co sts are discu ssed in Note 12 - "Asset Retirement Obligations (ARO)."
(8) Represents the tax gross-up related to th e depreciation-related excess deferred in come taxes and inv estment tax credits in cluded in this table an d h as a co rrespon ding deferred tax asset disclosed in No te 2 -
"Income Tax es.""Income Tax es."
(9) In 20 17 , in come tax reform redu ced deferred in co me tax assets and liabilities. For depreciation-related tem po rary differences under the no rmalized tax accoun tin g method, the resultin g excess deferred taxes
will flow back to customers ratably o ver the remaining regulatory liv es of Idah o Power's plant assets under th e alternative method provided in the statute.
(10) Represen ts amount accrued u nd er the May 2018 Idah o tax reform settlemen t stipulation (described belo w) for the future amortizatio n of existing or futu re unspecified regu latory deferrals that would oth erwise
be a fu ture liability recov erable from Idah o custom ers.

Id aho Power's regulatory assets and liabilities are typically amortized o ver th e p eriod in which they are reflected in customer rates. In the ev ent th at recov ery o f Idah o Power's co sts
th rough rates b eco mes u nlikely or un certain, regulatory accounting wo uld no longer ap ply to so me or all of Idaho Po wer's op eratio ns and the items above may represen t stranded
in vestments. If n o t allo wed full recov ery o f these items, Idah o Power wo uld be req uired to write o ff the applicable portio n , which co u ld have a materially adverse financial impact.

Po wer Cost Adjustment Mechanisms and Deferred Power Supply Costs

In both its Id aho and Oregon jurisd ictions, Idaho Power's power cost ad justmen t mechanisms ad dress the volatility of po wer supply costs and provid e for annu al adjustments to the
rates charg ed to its retail customers. The power cost adjustment mech anisms compare Id aho Power's actu al n et po wer supply costs (primarily fuel an d purchased power less wh olesale
energy sales) against net power supp ly co sts b eing reco vered in Id aho Power's retail rates. Und er the po wer co st adjustment mech anisms, certain differences between actual net p ower
sup ply costs in curred by Idaho Power and costs bein g recovered in retail rates are recorded as a deferred ch arge or credit o n the balance sheets for fu ture recov ery o r refun d. The power
sup ply costs d eferred p rimarily result from ch anges in the lev els of Id aho Power's o wn hydro electric g eneration, ch anges in contracted power p urchase prices and vo lumes, changes in
who lesale market p rices and transaction vo lumes, and ch anges in fuel prices.

Ida ho Jurisdictio n Power Cost Adjustment Mechanism: In the Idaho jurisdiction, th e annual PCA co nsists of (a) a forecast compo nent, based on a fo recast of net power su pply costs
in the coming y ear as co mpared with net p ower supply co sts included in b ase rates; and (b) a balancing component that trues u p the difference between the p reviou s year's actual net
p ower supp ly co sts and the co sts collected in the prev ious year's fo recast component. Th e latter comp onen t ensures that, over time, the actual collection or refu nd of net p ower supply
costs matches the amo u nts auth orized. The PCA mech anism includ es:

a cost or b enefit sh aring ratio th at allocates the deviation s in net power supp ly ex pen ses between customers (9 5 percent) an d Idaho Po wer (5 p ercent), with th e exceptions o f
expen ses associated with PURPA power p urchases an d deman d respo nse incentiv e payments, which are allo cated 1 00 percent to customers; and
a sales-based ad ju stment intend ed to en sure that power sup ply expen se recovery resu ltin g solely from sales volu me changes does n o t distort the results of th e mechan ism.

Th e Idaho d eferral period o r Idah o-jurisd iction PCA year runs from April 1 th rough March 31. Amounts deferred du rin g the PCA year are p rimarily reco vered or refund ed d uring the
sub sequent June 1 thro u gh May 31 period . In May 20 23, th e IPUC ap proved recovery of an in cremen tal $2 00.2 million o f Idah o-jurisdiction PCA revenues, but d irected Id aho Power
to spread recovery of th e $190.2 million deferral b alan ce component of the PCA o ver a two-year p eriod fro m June 1, 2023 to May 31, 2025, resulting in a total PCA increase o f $105 .1
million, effective for the PCA co llectio n period from June 1, 2 023 to M ay 3 1, 2 024. Th e o rder d eferred collection o f $95.1 million of deferred PCA costs to the sub sequent an nual PCA
collection p eriod from Jun e 1, 202 4 , to May 3 1 , 20 2 5. Th e net increase in PCA reven ues reflects h ig her mark et energy an d natu ral g as prices, combin ed with lo wer-than-expected
h ydropo wer generation and limited coal su pply in the prior April 20 2 2 to March 2023 PCA perio d . The net increase also reflects an expectatio n of continu ed elevated market energ y
and natural gas prices in the Ap ril 2023 to March 2 0 24 fo recast perio d .

Th e table below summarizes the three most recent Id aho -ju risd iction PCA rate adjustments, which also in clud e no n-PCA-related rate ad justmen ts as ordered b y the IPUC:
Effective Date
$ Change
(millio ns) No tes
Ju n e 1 , 202 3

$ 105.1

The $105.1 million increase in PCA rates reflects high er market en ergy and natural gas
prices, co mbined with lower-th an-expected low-cost hy d ropower generation and limited
coal supply. The increased rate also reflects an expectation o f con tin ued elevated market
energy p rices and n atural gas p rices in the fo recast perio d.
Ju n e 1 , 202 2

$ 94.9

The in crease in PCA rates reflected a forecasted reductio n in lo w-cost hydro electric
gen eratio n as well as high er costs asso ciated with market en ergy prices and natural gas
prices. The rate also reflected $0.6 million o f 2021 earnings shared with customers under
the 2 018 Settlemen t Stipulation described below.

Oreg o n Jurisdictio n Power Cost Adjustment Mechanism: Idah o Power's power cost recovery mech anism in Orego n has two components: an annu al po wer co st update (APCU) and a
p ower cost adju stment mechan ism (PCAM). The APCU allo ws Idaho Power to reestablish its Oregon base net p ower supp ly co sts annually, separate from a gen eral rate case, and to
fo recast net power sup p ly costs fo r the upco ming water y ear. The PCAM is a true-up filed annually in February. The filin g calculates the deviation between actu al net power su pply
expenses incurred for the preced ing calen dar y ear and the net power supp ly ex penses reco vered throu gh the APCU fo r the same perio d. Actu al 2 0 23 Oreg on-jurisdiction power su p ply
costs were less than the amo u nt recovered through the APCU, resu ltin g in a $0 .9 millio n refu nd d u e to customers, while in 20 22, Oreg on jurisdiction po wer supply cost exceeded the
amo unt recovered through the APCU, resu lting in a $1 .1 million deferral of costs fo r future recovery. Varian ces d uring 2 023 and 2 022 d id not have a material impact o n Idaho Po wer's
fin ancial statements. Idaho Po wer's annual June 1 APCU rate changes were $7 .7 million and $4 .0 million in 2023 and 2022, respectively.

Nota ble Idaho Base Rate Adjustments

Id aho base rates were most recently establish ed through a general rate case in 2023, with rate changes effective Janu ary 1, 2 024. Previously, base rates were established in a g eneral
rate case in 20 12 and adjusted in 201 4, 20 17, 2 018, and 2019 .

2 023 Id aho Genera l Rate Ca se: In Jun e 20 23, Id aho Power filed a general rate case with the IPUC. In December 2023 , the IPUC issued an order ap proving a settlement stipulation
amo ng parties (202 3 Settlement Stip ulation ) settling th e general rate case.

Th e Order and the 2023 Settlement Stipulation contains the following significant terms, amon g other items:

Idah o Power will implemen t revised tariff schedu les design ed to increase ann ual Id aho-ju risdictional retail revenue by $54.7 million, or 4 .25 p ercent, effective January 1, 2024.
The $54 .7 millio n of addition al annual rev enue is net of an Idaho-jurisdictio n PCA rate decrease o f $168 .3 millio n and a redu ction to an nual energy efficiency rider
collectio n of $3.5 million, each o f wh ich was transferred into base rates;
A 9.6 percent return on equity and a 7.247 p ercent authorized rate of retu rn based on a n on-specified cost of d ebt and cap ital structure, applied to an Id aho -ju risdictional rate
base of appro x imately $3.8 b illio n;
M odifications to th e Idaho-jurisdiction PCA including estab lishmen t of a new level of base net power sup ply expen se of $484.9 million , which includ es the transfer of $1 68.3
millio n from current PCA rates to b ase rates;
M odifications to th e energ y efficiency rider to sup p ort the tran sfer of $3 .5 millio n of energy efficien cy labor-related co st collection fro m the annual energy efficiency rider in to
base rates, warranting a decrease in the energy efficiency rider rate fro m 3.1 percent to 2 .35 p ercent;
M odifications to th e Idaho-jurisdiction FCA mechanism to suppo rt Idah o Power's rate desig n s and to reflect u pdated fix ed costs;
Co ntinued deferral of incremental veg etatio n manag ement and in su rance costs, as measured from 202 2 actual costs, thro u gh the earlier of Idaho Po wer's next Idaho g eneral rate
case o r 2025 ;
An ann ual $18 million increase in collection o f Idah o Po wer's reg ulatory asset associated with its defined benefit pension plan contribution s;
M odifications to Id aho Power's ADITC and revenue sharing mechanism b eginn in g in 2 024 to (1) include an add itio nal amo unt of in vestment tax credits eq ual to the
incremental investment tax credits g enerated from Idaho Power's investment in 202 3 battery storage p rojects; (2) remove the existing $25 million annual cap on the amount
of accelerated amortization o f ADITCs; (3) establish a minimu m specified Idah o ROE of 9.1 2 percent for additional amortization o f ADITCs; (4) establish a 9.6 p ercent Idaho
ROE as the thresho ld for reven u e sharing o f Idah o -jurisd iction earn ings between Idaho Power and Idaho customers; an d (5) implemen t all reven ue sharing th ro ugh th e PCA
rath er th an a portio n offsetting customer-fund ed p ension obligatio ns;
Ag reemen t that Id aho Power's capital expenditures th rough year-end 2022 were p ruden tly incurred;
Deferral an d amortization o f ann ual d ifferen ces b etween certain period ic maintenan ce costs at Idaho Power's natu ral gas-fired po wer plants; and
A residential p rice modernization p lan and updated rate d esigns.

Und er the mo dified ADITC and Revenue Sharin g mech anism, if Idaho Po wer's an nual Idah o ROE in an y year exceeds 9 .6 percent, th e amoun t of earning s exceeding 9 .6 percent will
b e allocated 80.0 percent to Idaho Po wer's Idaho customers as a rate redu ction to be effective at the time o f the su bsequent year's PCA, and 20.0 percent to Idaho Po wer.

In 2023 , Idaho Po wer recorded no amortization of ADITC. Acco rdingly, at December 31, 2023 , the full amou n t of ADITC remained available for fu ture u se und er the terms of the 202 3
Settlemen t Stipulation and the 20 1 8 Settlement Stip ulation described belo w.

"Income Tax es."(9) In 20 17 , in come tax reform redu ced deferred in co me tax assets and liabilities. For depreciation-related tem po rary differences under the no rmalized tax accoun tin g method, the resultin g excess deferred taxeswill flow back to customers ratably o ver the remaining regulatory liv es of Idah o Power's plant assets under th e alternative method provided in the statute.(10) Represen ts amount accrued u nd er the May 2018 Idah o tax reform settlemen t stipulation (described belo w) for the future amortizatio n of existing or futu re unspecified regu latory deferrals that would oth erwisebe a fu ture liability recov erable from Idah o custom ers. Id aho Power's regulatory assets and liabilities are typically amortized o ver th e p eriod in which they are reflected in customer rates. In the ev ent th at recov ery o f Idah o Power's co ststhrough rates b eco mes u nlikely or un certain, regulatory accounting wo uld no longer ap ply to so me or all of Idaho Po wer's op eratio ns and the items above may represen t strandedinvestments. If n o t allo wed full recov ery o f these items, Idah o Power wo uld be req uired to write o ff the applicable portio n , which co u ld have a materially adverse financial impact. Po wer Cost Adjustment Mechanisms and Deferred Power Supply Costs In both its Id aho and Oregon jurisd ictions, Idaho Power's power cost ad justmen t mechanisms ad dress the volatility of po wer supply costs and provid e for annu al adjustments to therates charg ed to its retail customers. The power cost adjustment mech anisms compare Id aho Power's actu al n et po wer supply costs (primarily fuel an d purchased power less wh olesaleenergy sales) against net power supp ly co sts b eing reco vered in Id aho Power's retail rates. Und er the po wer co st adjustment mech anisms, certain differences between actual net p owersupply costs in curred by Idaho Power and costs bein g recovered in retail rates are recorded as a deferred ch arge or credit o n the balance sheets for fu ture recov ery o r refun d. The powersupply costs d eferred p rimarily result from ch anges in the lev els of Id aho Power's o wn hydro electric g eneration, ch anges in contracted power p urchase prices and vo lumes, changes inwholesale market p rices and transaction vo lumes, and ch anges in fuel prices. Ida ho Jurisdictio n Power Cost Adjustment Mechanism: In the Idaho jurisdiction, th e annual PCA co nsists of (a) a forecast compo nent, based on a fo recast of net power su pply costsin the coming y ear as co mpared with net p ower supply co sts included in b ase rates; and (b) a balancing component that trues u p the difference between the p reviou s year's actual netpower supp ly co sts and the co sts collected in the prev ious year's fo recast component. Th e latter comp onen t ensures that, over time, the actual collection or refu nd of net p ower supplycosts matches the amo u nts auth orized. The PCA mech anism includ es: a cost or b enefit sh aring ratio th at allocates the deviation s in net power supp ly ex pen ses between customers (9 5 percent) an d Idaho Po wer (5 p ercent), with th e exceptions o fexpenses associated with PURPA power p urchases an d deman d respo nse incentiv e payments, which are allo cated 1 00 percent to customers; and a sales-based ad ju stment intend ed to en sure that power sup ply expen se recovery resu ltin g solely from sales volu me changes does n o t distort the results of th e mechan ism. Th e Idaho d eferral period o r Idah o-jurisd iction PCA year runs from April 1 th rough March 31. Amounts deferred du rin g the PCA year are p rimarily reco vered or refund ed d uring thesubsequent June 1 thro u gh May 31 period . In May 20 23, th e IPUC ap proved recovery of an in cremen tal $2 00.2 million o f Idah o-jurisdiction PCA revenues, but d irected Id aho Powerto spread recovery of th e $190.2 million deferral b alan ce component of the PCA o ver a two-year p eriod fro m June 1, 2023 to May 31, 2025, resulting in a total PCA increase o f $105 .1million, effective for the PCA co llectio n period from June 1, 2 023 to M ay 3 1, 2 024. Th e o rder d eferred collection o f $95.1 million of deferred PCA costs to the sub sequent an nual PCAcollection p eriod from Jun e 1, 202 4 , to May 3 1 , 20 2 5. Th e net increase in PCA reven ues reflects h ig her mark et energy an d natu ral g as prices, combin ed with lo wer-than-expectedhydropower generation and limited coal su pply in the prior April 20 2 2 to March 2023 PCA perio d . The net increase also reflects an expectatio n of continu ed elevated market energ yand natural gas prices in the Ap ril 2023 to March 2 0 24 fo recast perio d . Th e table below summarizes the three most recent Id aho -ju risd iction PCA rate adjustments, which also in clud e no n-PCA-related rate ad justmen ts as ordered b y the IPUC:Effective Date $ Change(millio ns) No tesJune 1 , 202 3 $ 105.1 The $105.1 million increase in PCA rates reflects high er market en ergy and natural gasprices, co mbined with lower-th an-expected low-cost hy d ropower generation and limitedcoal supply. The increased rate also reflects an expectation o f con tin ued elevated marketenergy p rices and n atural gas p rices in the fo recast perio d.Ju n e 1 , 202 2 $ 94.9 The in crease in PCA rates reflected a forecasted reductio n in lo w-cost hydro electricgeneration as well as high er costs asso ciated with market en ergy prices and natural gasprices. The rate also reflected $0.6 million o f 2021 earnings shared with customers underthe 2 018 Settlemen t Stipulation described below. Oreg o n Jurisdictio n Power Cost Adjustment Mechanism: Idah o Power's power cost recovery mech anism in Orego n has two components: an annu al po wer co st update (APCU) and apower cost adju stment mechan ism (PCAM). The APCU allo ws Idaho Power to reestablish its Oregon base net p ower supp ly co sts annually, separate from a gen eral rate case, and toforecast net power sup p ly costs fo r the upco ming water y ear. The PCAM is a true-up filed annually in February. The filin g calculates the deviation between actu al net power su pplyexpenses incurred for the preced ing calen dar y ear and the net power supp ly ex penses reco vered throu gh the APCU fo r the same perio d. Actu al 2 0 23 Oreg on-jurisdiction power su p plycosts were less than the amo u nt recovered through the APCU, resu ltin g in a $0 .9 millio n refu nd d u e to customers, while in 20 22, Oreg on jurisdiction po wer supply cost exceeded theamount recovered through the APCU, resu lting in a $1 .1 million deferral of costs fo r future recovery. Varian ces d uring 2 023 and 2 022 d id not have a material impact o n Idaho Po wer'sfinancial statements. Idaho Po wer's annual June 1 APCU rate changes were $7 .7 million and $4 .0 million in 2023 and 2022, respectively. Nota ble Idaho Base Rate Adjustments Id aho base rates were most recently establish ed through a general rate case in 2023, with rate changes effective Janu ary 1, 2 024. Previously, base rates were established in a g eneralrate case in 20 12 and adjusted in 201 4, 20 17, 2 018, and 2019 . 2 023 Id aho Genera l Rate Ca se: In Jun e 20 23, Id aho Power filed a general rate case with the IPUC. In December 2023 , the IPUC issued an order ap proving a settlement stipulationamong parties (202 3 Settlement Stip ulation ) settling th e general rate case. Th e Order and the 2023 Settlement Stipulation contains the following significant terms, amon g other items: Idah o Power will implemen t revised tariff schedu les design ed to increase ann ual Id aho-ju risdictional retail revenue by $54.7 million, or 4 .25 p ercent, effective January 1, 2024.The $54 .7 millio n of addition al annual rev enue is net of an Idaho-jurisdictio n PCA rate decrease o f $168 .3 millio n and a redu ction to an nual energy efficiency ridercollection of $3.5 million, each o f wh ich was transferred into base rates; A 9.6 percent return on equity and a 7.247 p ercent authorized rate of retu rn based on a n on-specified cost of d ebt and cap ital structure, applied to an Id aho -ju risdictional ratebase of appro x imately $3.8 b illio n; M odifications to th e Idaho-jurisdiction PCA including estab lishmen t of a new level of base net power sup ply expen se of $484.9 million , which includ es the transfer of $1 68.3million from current PCA rates to b ase rates; M odifications to th e energ y efficiency rider to sup p ort the tran sfer of $3 .5 millio n of energy efficien cy labor-related co st collection fro m the annual energy efficiency rider in tobase rates, warranting a decrease in the energy efficiency rider rate fro m 3.1 percent to 2 .35 p ercent; M odifications to th e Idaho-jurisdiction FCA mechanism to suppo rt Idah o Power's rate desig n s and to reflect u pdated fix ed costs; Co ntinued deferral of incremental veg etatio n manag ement and in su rance costs, as measured from 202 2 actual costs, thro u gh the earlier of Idaho Po wer's next Idaho g eneral ratecase o r 2025 ; An ann ual $18 million increase in collection o f Idah o Po wer's reg ulatory asset associated with its defined benefit pension plan contribution s; M odifications to Id aho Power's ADITC and revenue sharing mechanism b eginn in g in 2 024 to (1) include an add itio nal amo unt of in vestment tax credits eq ual to theincremental investment tax credits g enerated from Idaho Power's investment in 202 3 battery storage p rojects; (2) remove the existing $25 million annual cap on the amountof accelerated amortization o f ADITCs; (3) establish a minimu m specified Idah o ROE of 9.1 2 percent for additional amortization o f ADITCs; (4) establish a 9.6 p ercent IdahoROE as the thresho ld for reven u e sharing o f Idah o -jurisd iction earn ings between Idaho Power and Idaho customers; an d (5) implemen t all reven ue sharing th ro ugh th e PCArather th an a portio n offsetting customer-fund ed p ension obligatio ns; Ag reemen t that Id aho Power's capital expenditures th rough year-end 2022 were p ruden tly incurred; Deferral an d amortization o f ann ual d ifferen ces b etween certain period ic maintenan ce costs at Idaho Power's natu ral gas-fired po wer plants; and A residential p rice modernization p lan and updated rate d esigns. Und er the mo dified ADITC and Revenue Sharin g mech anism, if Idaho Po wer's an nual Idah o ROE in an y year exceeds 9 .6 percent, th e amoun t of earning s exceeding 9 .6 percent willbe allocated 80.0 percent to Idaho Po wer's Idaho customers as a rate redu ction to be effective at the time o f the su bsequent year's PCA, and 20.0 percent to Idaho Po wer.

In 2023 , Idaho Po wer recorded no amortization of ADITC. Acco rdingly, at December 31, 2023 , the full amou n t of ADITC remained available for fu ture u se und er the terms of the 202 3
Settlemen t Stipulation and the 20 1 8 Settlement Stip ulation described belo w.

Ma y 20 18 Idaho Tax Reform Settlement Stipulatio n: In May 201 8, the IPUC issued an ord er approvin g a settlement stipulation (2 018 Settlement Stipulatio n) related to income tax
reform. Beginn ing June 1, 2018, the 2018 Settlemen t Stipulation p rovided an an n ual (a) $1 8 .7 million reductio n to Id aho customer base rates an d (b) $7.4 million amortization of
existing regulatory deferrals fo r specified items or fu ture amo rtizatio n of o th er existing or future unspecified regulatory d eferrals that wou ld otherwise be a futu re regulato ry asset
reco verable fro m Idaho customers. The 2018 Settlement Stipu lation also prov ided for the indefinite exten sio n , with modifications, o f a p reviou s 2 014 settlement stipulation beyond
its termination d ate of Decemb er 3 1 , 20 1 9, with modified terms related to the ADITC and revenue sharing mechanism th at became effective January 1, 202 0 .

Th e 2 0 18 Settlement Stipulatio n prov ided Idaho Power th e ability to earn a minimum Id aho ROE of 9.4 p ercent b y amortizin g up to $25 million of ad ditional ADITC in any calendar
y ear. If Id aho Power's annu al Idaho ROE in any y ear exceeded 10.0 percen t, the amount o f earnings exceedin g 10.0 percen t an d up to an d including 10.5 percent wou ld be allocated
8 0 percent to Id aho Power's Id aho customers as a rate reductio n to b e effectiv e at the time of the subseq u ent year's PCA, an d 20 percent to Idaho Po wer. Id aho Power's ADITC and
revenue sh aring mechan ism was mo dified by the 20 2 3 Settlement Stip ulation .

North Valmy Base Rate Ad justment Settlement Stipula tio ns: Idah o Power has settlement stipulatio ns in place in Id aho and Oregon related to the p lanned end o f its participation in
coal-fired o p eratio ns of bo th units of its jo intly-owned No rth Valmy p ower plant. Id aho Power ceased coal-fired op eratio n s at u n it 1 in 2019, as planned, and th ese settlement
stipu lations pro vide for Idaho Po wer to cease co al-fired operations at unit 2 in 2 0 25. Th e IPUC-ap p roved settlemen t stip u lation provides for (1) accelerated depreciation for the No rth
Valmy plant to allow the coal-related p lant assets to be fully d epreciated and recov ered by December 31, 2028, (2) Idaho Power to use pru d ent and commercially reaso n able effo rts to
end its p articip ation in co al-fired operations at North Valmy as described abo ve, (3) a balancin g acco unt to track the incremental costs, ben efits, and required reg u latory accoun ting
asso ciated with ceasin g participatio n in coal-fired o p eratio ns at th e North Valmy plant, and (4) increased customer rates related to the associated incremental annual lev elized reven ue
requirement. If actual co sts incurred differ from fo recasted amo u nts inclu ded in the settlement stip u lation, co llectio n or refund o f an y differences would b e subject to regu latory
appro v al.

J im Bridger Po wer Pla nt Rate Ba se Adjustment and Recovery: In June 2022 , the IPUC issued an order ap proving , with mo difications, Idaho Po wer's amended app licatio n req uesting
autho rization to (1) accelerate depreciation for the Jim Bridger plan t to allo w the coal-related plant assets to be fully depreciated and recovered by December 31, 2 030, (2) establish a
b alancing accou n t to track th e in cremen tal costs, benefits, an d req uired regulatory accounting associated with ceasing p articip ation in co al-fired operations at the Jim Bridger plant,
and (3 ) increase customer rates related to the associated incremental annu al levelized revenue requirement (Bridger Ord er).

Th e Bridger Order allows for reg ulatory accou n ting entries and establishes balan cing accounts (record ed as regu latory assets or liabilities on Idaho Power's balance sheets) to track
d ifferen ces b etween amoun ts reco v ered in rates and actual incremental costs an d benefits associated with Idah o Po wer's plan at the time of the Brid ger Order to cease its participatio n
in co al-fired operations at the Jim Bridger plant by the end of 2028. The incremen tal costs and benefits inclu d e th e reven u e requiremen t associated with the in cremen tal Jim Bridger
p lant coal-related inv estments mad e fro m 20 12 thro u gh the end of 2020, forecasted co al-related in vestments, and n ear-term d eco mmissioning costs, offset by o ther O&M cost sav in gs.
Th e Bridger Order d eemed all coal-related inv estmen ts at the Jim Bridger plant from 2012 throug h 202 0 to b e pru dent for recovery.

In the Brid g er Order, th e IPUC red u ced Idaho Po wer's requested rate increase from 2.1 p ercent in its amended filing to 1.5 percen t, a redu ction fro m a req uested $27.1 millio n to $18.8
million annually. The Bridg er Order provides that any unco llected amou nt resulting from the reduction in the rate in crease will be recorded in th e b alan cing accoun t for future
reco very with no carrying ch arge. The uncollected amo unts tracked in this balan cing account were in cluded for reco very in the 202 3 Settlement Stip u lation. Idah o Po wer anticipates
mak in g future filings with th e IPUC that may result in perio dic adjustments to rates to tru e u p variances between revenue collection s and actu al revenu e requiremen t amounts. Th e
Bridg er Order allows Idah o Power to earn a retu rn on and recover through 2030 the net b ook v alue of coal-related assets at the Jim Bridger plan t as of December 31, 2020, as well as
fo recasted coal-related inv estments.

Other Notable Idaho Regulato ry Ma tters

Fixed Cost Adjustment: The FCA mechanism, applicable to Id aho residen tial and small co mmercial cu stomers, is d esigned to remov e a portion of Idaho Power's financial disincentive
to invest in en ergy efficiency prog rams by separating (or decou p ling) the recovery of fix ed costs from th e v ariab le kWh charge and linking it instead to a set amou nt per cu stomer.
Und er Idaho Power's curren t rate design , recovery of a po rtio n of fix ed costs is includ ed in the variable k Wh ch arge, which may resu lt in over-co llection or un der-collection of fixed
costs. To return over-collection to customers or to collect u nder-collection fro m customers, the FCA mechanism allo ws Id aho Power to accrue, or d efer, the difference b etween the
autho rized fixed -cost recovery amoun t per customer and the actual fixed costs per cu stomer reco vered by Idaho Power during th e y ear. The IPUC has discretion to cap the annual
in crease in the FCA reco very at 3 percen t of base rev enu e, with any excess deferred for co llectio n in a subseq u ent year. In M ay 2 023, the IPUC issued an order appro ving a $10 .1
million d ecrease in recovery from the FCA from $35.2 million to $2 5.1 million for the 2 022 FCA d eferral, with n ew rates effective for the period from June 1, 2 023, to May 31, 2024.
Beginning with the 2024 FCA deferral, th e 2 023 Settlement Stipulatio n up d ates th e authorized fix ed-cost recovery amount per customer an d mo difies parts of the FCA mechanism to
sup port Idaho Power's pro posed rate designs, as noted above.

Th e follo wing table summarizes FCA amoun ts approv ed fo r co llectio n in the prior three FCA years:
FCA Year Period Rates in Effect
Annua l Amount
(in millions)
20 2 2 June 1, 2023-May 31 , 202 4 $25.1
20 2 1 June 1, 2022-May 31 , 202 3 $35.2

Wildfire Mitigation Co st Recovery: In June 2021 and March 202 3, the IPUC issued o rd ers au thorizin g Idaho Po wer to d efer for future amortization incremental O&M and
d epreciation expen se for certain capital investments necessary to implement Idaho Power's WM P. As o f December 31, 2023 , Idaho Po wer's deferral balance of Idaho -jurisd iction costs
related to th e WMP was $51 .3 millio n. As a result of th e 2 0 23 Settlement Stipulatio n, Idaho Power will recover an d amortize its WMP d eferral balance th rough 2022 of $26 .7 millio n,
b egin n ing Jan uary 1, 2 0 24.

Nota ble Oregon Regulatory Matters

Oreg o n Base Rate Changes: Oregon base rates were most recently established in a general rate case in 2012 . In February 20 12, th e OPUC issued an order ap proving a settlement
stipu lation th at p ro vided for a $1.8 million base rate increase, a return on equity o f 9.9 percent, an d an overall rate of return of 7.7 57 percent in th e Oreg on jurisdiction. New rates in
confo rmity with the settlemen t stip ulation were effective M arch 1, 2012. Subsequen tly, in Sep temb er 2 0 12, th e OPUC issued an ord er approvin g an app roximately $3.0 million
in crease in ann ual Oreg on ju risdiction b ase rates, effective Octo ber 1, 20 12, fo r inclu sion of the Lan gley Gu lch p ower plant in Id aho Power's Oregon rate base. Ad ditionally, in
October 2020, the OPUC approved an increase in Oreg on customer rates of $0.4 millio n an nually associated with amo rtizatio n of d eferred Langley Gu lch power plant reven u e
requirement variances, effectiv e November 1, 2020 , throu g h Octob er 31 , 202 4.

In May 2018, the OPUC issued an o rder appro v ing a settlemen t stip ulation that p rovides for an an n ual $1.5 million reduction to Oregon customer base rates beginning Ju ne 1 , 20 1 8
th rough M ay 3 1, 20 20, related to in come tax reform. In May 2020 , the OPUC issued an order to ap prove the quantificatio n of $1.5 million in an n ualized Oregon ju risdictional
b enefits asso ciated with federal and state income tax changes resulting fro m tax refo rm and adjusting customer rates to reflect th is amo unt, effective Jun e 1 , 202 0, un til its next general
rate case or oth er pro ceeding wh ere the tax-related revenue req u irement comp onen ts are reflected in rates.

Th e OPUC has also approved settlement stipulations th at provid e for the accelerated cost recov ery of jointly-o wn ed North Valmy unit 1 throug h 2019 and unit 2 throug h 2025. Th e
n et rate impact of th e Oreg on settlement stipulatio ns is immaterial.

In Decemb er 20 23, Id aho Power filed a gen eral rate case with the OPUC. Th e filing was based on a 2 024 test year an d requested an overall annual rate increase of $1 0.7 million, or
1 9.28 percent. The filin g requested , among other items, a 1 0.4 p ercent authorized rate of retu rn on equ ity an d an ap p roximate $188.9 million Oregon -ju risdiction retail rate b ase. The
$188.9 million of rate base exclu des rate base associated with Idaho Po wer's join tly -own ed North Valmy coal facilities, the costs of which are recovered under the separate rate
mechan ism noted above. In its application, Idah o Power propo sed a capitalization stru cture of 49 percent long-term debt and 5 1 percen t commo n stock equity. Idaho Power included
an average cost o f deb t of 5.1 04 p ercent and an ov erall cost of cap ital of 7.807 percen t. If approved by the OPUC, n ew rates for Oregon -jurisd iction customers would b eco me effective
in October 202 4 or later.

Federal Reg ulatory Matters - Open Access Transmissio n Tariff Ra tes

Id aho Power u ses a fo rmula rate for transmission service p ro vided under its OATT, which allo ws transmissio n rates to be upd ated an nually based primarily on actual financial and
o perational data Idaho Po wer files with the FERC and allows Idaho Po wer to recov er costs asso ciated with its transmissio n system. Idah o Power's OATT rates su bmitted to th e FERC in
Id aho Power's three mo st recent annual OATT Final Informational Filings were as fo llows:
Applicable Perio d
OATT Rate (per
kW-y ear)
Octo ber 1 , 20 2 3 to September 30, 2024 $ 30 .74
Octo ber 1 , 20 2 2 to September 30, 2023 $ 31 .42
Ma y 20 18 Idaho Tax Reform Settlement Stipulatio n: In May 201 8, the IPUC issued an ord er approvin g a settlement stipulation (2 018 Settlement Stipulatio n) related to income taxreform. Beginn ing June 1, 2018, the 2018 Settlemen t Stipulation p rovided an an n ual (a) $1 8 .7 million reductio n to Id aho customer base rates an d (b) $7.4 million amortization ofexisting regulatory deferrals fo r specified items or fu ture amo rtizatio n of o th er existing or future unspecified regulatory d eferrals that wou ld otherwise be a futu re regulato ry assetrecoverable fro m Idaho customers. The 2018 Settlement Stipu lation also prov ided for the indefinite exten sio n , with modifications, o f a p reviou s 2 014 settlement stipulation beyondits termination d ate of Decemb er 3 1 , 20 1 9, with modified terms related to the ADITC and revenue sharing mechanism th at became effective January 1, 202 0 . Th e 2 0 18 Settlement Stipulatio n prov ided Idaho Power th e ability to earn a minimum Id aho ROE of 9.4 p ercent b y amortizin g up to $25 million of ad ditional ADITC in any calendaryear. If Id aho Power's annu al Idaho ROE in any y ear exceeded 10.0 percen t, the amount o f earnings exceedin g 10.0 percen t an d up to an d including 10.5 percent wou ld be allocated80 percent to Id aho Power's Id aho customers as a rate reductio n to b e effectiv e at the time of the subseq u ent year's PCA, an d 20 percent to Idaho Po wer. Id aho Power's ADITC andrevenue sh aring mechan ism was mo dified by the 20 2 3 Settlement Stip ulation . North Valmy Base Rate Ad justment Settlement Stipula tio ns: Idah o Power has settlement stipulatio ns in place in Id aho and Oregon related to the p lanned end o f its participation incoal-fired o p eratio ns of bo th units of its jo intly-owned No rth Valmy p ower plant. Id aho Power ceased coal-fired op eratio n s at u n it 1 in 2019, as planned, and th ese settlementstipulations pro vide for Idaho Po wer to cease co al-fired operations at unit 2 in 2 0 25. Th e IPUC-ap p roved settlemen t stip u lation provides for (1) accelerated depreciation for the No rthValmy plant to allow the coal-related p lant assets to be fully d epreciated and recov ered by December 31, 2028, (2) Idaho Power to use pru d ent and commercially reaso n able effo rts toend its p articip ation in co al-fired operations at North Valmy as described abo ve, (3) a balancin g acco unt to track the incremental costs, ben efits, and required reg u latory accoun tingassociated with ceasin g participatio n in coal-fired o p eratio ns at th e North Valmy plant, and (4) increased customer rates related to the associated incremental annual lev elized reven uerequirement. If actual co sts incurred differ from fo recasted amo u nts inclu ded in the settlement stip u lation, co llectio n or refund o f an y differences would b e subject to regu latoryapproval. J im Bridger Po wer Pla nt Rate Ba se Adjustment and Recovery: In June 2022 , the IPUC issued an order ap proving , with mo difications, Idaho Po wer's amended app licatio n req uestingauthorization to (1) accelerate depreciation for the Jim Bridger plan t to allo w the coal-related plant assets to be fully depreciated and recovered by December 31, 2 030, (2) establish abalancing accou n t to track th e in cremen tal costs, benefits, an d req uired regulatory accounting associated with ceasing p articip ation in co al-fired operations at the Jim Bridger plant,and (3 ) increase customer rates related to the associated incremental annu al levelized revenue requirement (Bridger Ord er). Th e Bridger Order allows for reg ulatory accou n ting entries and establishes balan cing accounts (record ed as regu latory assets or liabilities on Idaho Power's balance sheets) to trackdifferences b etween amoun ts reco v ered in rates and actual incremental costs an d benefits associated with Idah o Po wer's plan at the time of the Brid ger Order to cease its participatio nin co al-fired operations at the Jim Bridger plant by the end of 2028. The incremen tal costs and benefits inclu d e th e reven u e requiremen t associated with the in cremen tal Jim Bridgerplant coal-related inv estments mad e fro m 20 12 thro u gh the end of 2020, forecasted co al-related in vestments, and n ear-term d eco mmissioning costs, offset by o ther O&M cost sav in gs.Th e Bridger Order d eemed all coal-related inv estmen ts at the Jim Bridger plant from 2012 throug h 202 0 to b e pru dent for recovery. In the Brid g er Order, th e IPUC red u ced Idaho Po wer's requested rate increase from 2.1 p ercent in its amended filing to 1.5 percen t, a redu ction fro m a req uested $27.1 millio n to $18.8million annually. The Bridg er Order provides that any unco llected amou nt resulting from the reduction in the rate in crease will be recorded in th e b alan cing accoun t for futurerecovery with no carrying ch arge. The uncollected amo unts tracked in this balan cing account were in cluded for reco very in the 202 3 Settlement Stip u lation. Idah o Po wer anticipatesmaking future filings with th e IPUC that may result in perio dic adjustments to rates to tru e u p variances between revenue collection s and actu al revenu e requiremen t amounts. Th eBridger Order allows Idah o Power to earn a retu rn on and recover through 2030 the net b ook v alue of coal-related assets at the Jim Bridger plan t as of December 31, 2020, as well asforecasted coal-related inv estments. Other Notable Idaho Regulato ry Ma tters Fixed Cost Adjustment: The FCA mechanism, applicable to Id aho residen tial and small co mmercial cu stomers, is d esigned to remov e a portion of Idaho Power's financial disincentiveto invest in en ergy efficiency prog rams by separating (or decou p ling) the recovery of fix ed costs from th e v ariab le kWh charge and linking it instead to a set amou nt per cu stomer.Und er Idaho Power's curren t rate design , recovery of a po rtio n of fix ed costs is includ ed in the variable k Wh ch arge, which may resu lt in over-co llection or un der-collection of fixedcosts. To return over-collection to customers or to collect u nder-collection fro m customers, the FCA mechanism allo ws Id aho Power to accrue, or d efer, the difference b etween theauthorized fixed -cost recovery amoun t per customer and the actual fixed costs per cu stomer reco vered by Idaho Power during th e y ear. The IPUC has discretion to cap the annualincrease in the FCA reco very at 3 percen t of base rev enu e, with any excess deferred for co llectio n in a subseq u ent year. In M ay 2 023, the IPUC issued an order appro ving a $10 .1million d ecrease in recovery from the FCA from $35.2 million to $2 5.1 million for the 2 022 FCA d eferral, with n ew rates effective for the period from June 1, 2 023, to May 31, 2024.Beginning with the 2024 FCA deferral, th e 2 023 Settlement Stipulatio n up d ates th e authorized fix ed-cost recovery amount per customer an d mo difies parts of the FCA mechanism tosupport Idaho Power's pro posed rate designs, as noted above. Th e follo wing table summarizes FCA amoun ts approv ed fo r co llectio n in the prior three FCA years:FCA Year Period Rates in Effect Annua l Amount(in millions)20 2 2 June 1, 2023-May 31 , 202 4 $25.12021 June 1, 2022-May 31 , 202 3 $35.2 Wildfire Mitigation Co st Recovery: In June 2021 and March 202 3, the IPUC issued o rd ers au thorizin g Idaho Po wer to d efer for future amortization incremental O&M anddepreciation expen se for certain capital investments necessary to implement Idaho Power's WM P. As o f December 31, 2023 , Idaho Po wer's deferral balance of Idaho -jurisd iction costsrelated to th e WMP was $51 .3 millio n. As a result of th e 2 0 23 Settlement Stipulatio n, Idaho Power will recover an d amortize its WMP d eferral balance th rough 2022 of $26 .7 millio n,b egin n ing Jan uary 1, 2 0 24. Nota ble Oregon Regulatory Matters Oreg o n Base Rate Changes: Oregon base rates were most recently established in a general rate case in 2012 . In February 20 12, th e OPUC issued an order ap proving a settlementstipulation th at p ro vided for a $1.8 million base rate increase, a return on equity o f 9.9 percent, an d an overall rate of return of 7.7 57 percent in th e Oreg on jurisdiction. New rates inconformity with the settlemen t stip ulation were effective M arch 1, 2012. Subsequen tly, in Sep temb er 2 0 12, th e OPUC issued an ord er approvin g an app roximately $3.0 millionincrease in ann ual Oreg on ju risdiction b ase rates, effective Octo ber 1, 20 12, fo r inclu sion of the Lan gley Gu lch p ower plant in Id aho Power's Oregon rate base. Ad ditionally, inOctober 2020, the OPUC approved an increase in Oreg on customer rates of $0.4 millio n an nually associated with amo rtizatio n of d eferred Langley Gu lch power plant reven u erequirement variances, effectiv e November 1, 2020 , throu g h Octob er 31 , 202 4. In May 2018, the OPUC issued an o rder appro v ing a settlemen t stip ulation that p rovides for an an n ual $1.5 million reduction to Oregon customer base rates beginning Ju ne 1 , 20 1 8through M ay 3 1, 20 20, related to in come tax reform. In May 2020 , the OPUC issued an order to ap prove the quantificatio n of $1.5 million in an n ualized Oregon ju risdictionalbenefits asso ciated with federal and state income tax changes resulting fro m tax refo rm and adjusting customer rates to reflect th is amo unt, effective Jun e 1 , 202 0, un til its next generalrate case or oth er pro ceeding wh ere the tax-related revenue req u irement comp onen ts are reflected in rates. Th e OPUC has also approved settlement stipulations th at provid e for the accelerated cost recov ery of jointly-o wn ed North Valmy unit 1 throug h 2019 and unit 2 throug h 2025. Th enet rate impact of th e Oreg on settlement stipulatio ns is immaterial. In Decemb er 20 23, Id aho Power filed a gen eral rate case with the OPUC. Th e filing was based on a 2 024 test year an d requested an overall annual rate increase of $1 0.7 million, or19.28 percent. The filin g requested , among other items, a 1 0.4 p ercent authorized rate of retu rn on equ ity an d an ap p roximate $188.9 million Oregon -ju risdiction retail rate b ase. The$188.9 million of rate base exclu des rate base associated with Idaho Po wer's join tly -own ed North Valmy coal facilities, the costs of which are recovered under the separate ratemechanism noted above. In its application, Idah o Power propo sed a capitalization stru cture of 49 percent long-term debt and 5 1 percen t commo n stock equity. Idaho Power includedan average cost o f deb t of 5.1 04 p ercent and an ov erall cost of cap ital of 7.807 percen t. If approved by the OPUC, n ew rates for Oregon -jurisd iction customers would b eco me effectivein October 202 4 or later. Federal Reg ulatory Matters - Open Access Transmissio n Tariff Ra tes Id aho Power u ses a fo rmula rate for transmission service p ro vided under its OATT, which allo ws transmissio n rates to be upd ated an nually based primarily on actual financial andoperational data Idaho Po wer files with the FERC and allows Idaho Po wer to recov er costs asso ciated with its transmissio n system. Idah o Power's OATT rates su bmitted to th e FERC inIdaho Power's three mo st recent annual OATT Final Informational Filings were as fo llows:
Applicable Perio d
OATT Rate (per
kW-y ear)
Octo ber 1 , 20 2 3 to September 30, 2024 $ 30 .74
Octo ber 1 , 20 2 2 to September 30, 2023 $ 31 .42
Octo ber 1 , 20 2 1 to September 30, 2022 $ 31 .19

Id aho Power's current OATT rate is based on a n et annual tran smission revenue requ irement of $135.7 millio n, which rep resents the OATT formulaic determination o f Idah o Power's net
cost of p roviding OATT-based tran smission service.

4 . REVENUES

Revenues fro m Contra cts with Customers

Revenu es from con tracts with customers are primarily related to Idaho Power's regulated tariff-based sales o f energy o r related services. Generally, tariff-based sales do n ot invo lve a
written co ntract, but are classified as revenu es from con tracts with customers. Idah o Po wer assesses rev enues on a co ntract-by-co ntract basis to determine the nature, amou nt, timing,
and uncertainty, if any, of reven ues being reco g nized.

Retail Revenues: Idah o Power's retail revenues primarily relate to the sale o f electricity to customers based on regulated tariff-based prices. Idaho Power recogn izes retail reven ues in
amo unts for which it has the rig ht to in voice the cu stomer in the period when energy is delivered or services are provid ed to cu stomers. Th e total en ergy price gen erally has a fixed
component related to having service av ailab le and a usag e-based compo nent related to the d emand, deliv ery, an d co nsumptio n of energ y. Th e reven ues recogn ized reflect the
consideration Idaho Power expects to be entitled to in exchan ge fo r energy and services. Retail customers are classified as resid ential, commercial, in d ustrial, o r irrigation .
App ro ximately 95 percent of Id aho Power's retail revenue originates from customers located in Id aho, with the remainder originating fro m customers lo cated in Oregon. Idaho Po wer's
retail customer rates are based on Idah o Power's co st o f service and are d etermined throug h general rate case p ro ceeding s, settlement stipu lations, and o ther filin gs with the IPUC and
OPUC. Chan ges in rates and changes in customer d emand are ty pically the primary causes of fluctu ations in retail revenue from period to period. The p rimary influences on chan ges in
customer demand for electricity are weather, eco nomic conditions (in cluding growth in the n umb er of Id aho Power customers), an d en ergy efficiency. Id aho Power's utility rev enu es
are not earned evenly during the year.

Retail revenu es are billed mo nthly b ased on meter readings taken through o ut the mo nth. Payments for amo unts billed are generally due from the customer within 1 5 days of billing .
Id aho Power accrues estimated un b illed revenues fo r energy o r related services delivered to cu sto mers b u t not y et b illed at perio d-en d based on actual meter readings at perio d-en d
and estimated rates.

Resid ential Cu stomers: Idaho Power's energ y sales to residential customers typically p eak during the su mmer co oling season and winter heating season. Extreme temperatures increase
sales to resid ential cu stomers who u se electricity for cooling an d heating, compared with n ormal temperatures. Id aho Power's rate structure provides for hig h er rates du rin g the summer
when ov erall sy stem lo ads are at their highest, and inclu des tiers such that rates increase as a customer's consumption level increases. Th ese seasonal and tiered rate structu res
contribu te to the seasonal fluctu ations in revenues and earn ings. Economic and demo g raph ic condition s can also affect residen tial customer deman d; strong jo b growth and
p opulation gro wth in Idaho Po wer's serv ice area have led to higher cu sto mer growth in recent years. Residential demand is also impacted b y energy efficiency initiatives. Id aho
Power's FCA mechan ism mitigates some of the flu ctuations caused by weather and energy efficiency initiatives.

Commercial Cu stomers: Most bu sinesses are inclu ded in Idaho Po wer's commercial custo mer class, as are small industrial comp anies, an d pub lic street an d high way lightin g acco u nts.
Id aho Power's commercial customers are less influenced b y weath er condition s th an residen tial custo mers, althou gh weather does still affect commercial customer energy use.
Economic cond itio ns, including man ufacturing activity levels, an d en ergy efficiency initiativ es also affect en ergy use o f commercial customers.

In dustrial Customers: Industrial customers co n sist o f large indu strial compan ies, including sp ecial contract cu sto mers. En ergy use o f industrial customers is primarily driven by
eco nomic co nditions, with weather having little impact on this customer class.

Irrig ation Customers: Irrigatio n custo mers u se electricity to o perate irrigation p umps, p rimarily during the agricultural growing seaso n. Th e amoun t and timing of precipitation as well
as temperature levels affect the timing and amounts of sales to irrig ation customers, with increased precipitation d uring the agricultu ral growing season generally resulting in
d ecreased sales.

Provision for Sharin g: Idaho Po wer has regulatory settlement stipulatio ns in Idaho th at pro vide for the potential sharing between Idah o Po wer and its Idah o cu stomers of Idaho -
ju risd ictional earnings in excess of 10 .0 percent of Id aho ROE (in excess of 9.6 percent of Id aho ROE beginning in 20 24). Based on full-year 20 2 3 Idaho ROE, Idaho Po wer recorded
n o prov isio n ag ainst cu rrent revenues fo r sh aring of earnings with customers for 202 3. During 2022, no p rovision was record ed. The regulatory settlement stipulatio ns are described
fu rther in No te 3 - "Regulatory Matters."

Wholesale Energy Sales: As a public utility u n der th e FPA, Idaho Power has the autho rity to charge market-based rates fo r wholesale energy sales u nder its FERC tariff. Idaho Po wer's
who lesale electricity sales are p rimarily to utilities and power marketers and are predominan tly short-term an d co nsist o f a sing le performance oblig ation satisfied as energy is
transferred to th e counterparty. Idaho Power's wholesale energy sales dep end largely on the availability o f gen eratio n resou rces in ex cess of th e amou n t necessary to serve custo mer
lo ads as well as adeq uate market power prices and d emand at the time when those resources are av ailab le. A reduction in any of tho se factors may lead to lower wholesale energy sales.

Tra nsmission Wheeling-Related Revenues: As a p ublic utility und er the FPA, Idah o Power has th e authority to provid e cost-based wh olesale and retail access transmission serv ices
u nder its OATT. Services under the OATT are offered on a n ondiscriminato ry basis such that all p otential cu stomers have an equal op p ortunity to access th e transmission system. Idah o
Power's transmissio n rev enu e is primarily related to th ird parties reserv ing capacity on Idaho Power's transmissio n system to tran smit electricity throu g h Idaho Power's serv ice area.
Reservatio n s are pred ominantly short-term contracts or o n -demand wh en available, bu t may be part of a long-term capacity contract. Tran smission wheelin g -related reven ues consist
o f a sing le performance ob lig ation satisfied as capacity on Idah o Power's transmission system is prov ided to the third p arty. Tran smission wh eelin g-related revenues are affected by
changes in Idah o Power's OATT rate an d cu sto mer demand. Demand fo r transmission services can be affected by region al market factors, such as loads an d generation of utilities in
Id aho Power's region .

Energ y Efficiency Program Revenues: Id aho Power collects most o f its energy efficien cy program costs th rough an energ y efficien cy rid er on customer b ills. The rid er collections are
d eferred u ntil ex p end itu res are incurred . Energ y efficien cy p rogram ex pen d itures fun ded through the rid er are reported as an o p eratin g expen se with an eq ual amou nt recognized in
revenues, resulting in no n et impact on earn ings. The cu mulativ e v arian ce between expenditures and amo unts co llected thro ugh th e rider is recorded as a reg ulatory asset o r liability. A
liability b alan ce indicates th at Idaho Power has collected mo re than it h as spen t, an d an asset b alan ce indicates th at Idaho Power has sp ent more than it has collected . At Decemb er 31 ,
2 023, Idah o Power's en ergy efficiency rider balances were a $0 .7 millio n reg ulatory liability in the Idaho jurisdictio n and a $0.8 million regu latory liability in the Oregon jurisd iction.

Alternativ e Rev enue Pro grams and Other Revenues

Wh ile revenu es from con tracts with customers make u p mo st of Idaho Po wer's rev enu es, the IPUC has authorized the u se of an additional reg ulatory mechanism, th e Id aho FCA
mechan ism, which may increase or d ecrease tariff-based customer rates. The Idah o FCA mechanism is d escribed in Note 3 - "Reg ulatory Matters." Th e FCA mechanism revenues
in clude on ly the initial reco g nition o f FCA revenues wh en th ey meet the regu lator-specified con ditions for recog nition. Reven u e fro m contracts with customers ex cludes the portion
o f the tariff price representing FCA reven ues that Idaho Po wer initially recorded in p rio r perio ds wh en revenues met regulator-sp ecified conditio n s. When Idah o Power inclu d es those
amo unts in the price o f utility serv ice and billed to cu sto mers, Id aho Power reco rd s su ch amou nts as recovery of the asso ciated regulato ry asset o r liability and not as revenues.

Derivative rev enues inclu de g ains from settled electricity swaps an d sales o f electricity und er forward sales contracts that are bund led with RECs. Related to these forward sales, Idaho
Power simu ltaneo usly en ters into fo rward pu rchases of electricity for th e same quan tity at the same location, which are record ed in purchased power on the statemen ts o f inco me. For
more information o n settled electricity swaps, see Note 14 - "Derivative Finan cial Instru ments."

5 . LONG-TERM DEBT

Th e follo wing table summarizes Idaho Po wer's lon g-term deb t at December 31 (in thousan ds of do llars):
202 3 2022
First mortgag e bo nds:
2.50% Series d ue 2 023 $ $ 75,000
1.90% Series d ue 2 030 8 0 ,000 80,000
6.00% Series d ue 2 032 10 0 ,000 100,000
4.99% Series d ue 2 032 2 3 ,000 23,000
5.50% Series d ue 2 033 7 0 ,000 70,000
5.50% Series d ue 2 034 5 0 ,000 50,000
Octo ber 1 , 20 2 1 to September 30, 2022 $ 31 .19 Id aho Power's current OATT rate is based on a n et annual tran smission revenue requ irement of $135.7 millio n, which rep resents the OATT formulaic determination o f Idah o Power's netcost of p roviding OATT-based tran smission service. 4 . REVENUES Revenues fro m Contra cts with Customers Revenu es from con tracts with customers are primarily related to Idaho Power's regulated tariff-based sales o f energy o r related services. Generally, tariff-based sales do n ot invo lve awritten co ntract, but are classified as revenu es from con tracts with customers. Idah o Po wer assesses rev enues on a co ntract-by-co ntract basis to determine the nature, amou nt, timing,and uncertainty, if any, of reven ues being reco g nized. Retail Revenues: Idah o Power's retail revenues primarily relate to the sale o f electricity to customers based on regulated tariff-based prices. Idaho Power recogn izes retail reven ues inamounts for which it has the rig ht to in voice the cu stomer in the period when energy is delivered or services are provid ed to cu stomers. Th e total en ergy price gen erally has a fixedcomponent related to having service av ailab le and a usag e-based compo nent related to the d emand, deliv ery, an d co nsumptio n of energ y. Th e reven ues recogn ized reflect theconsideration Idaho Power expects to be entitled to in exchan ge fo r energy and services. Retail customers are classified as resid ential, commercial, in d ustrial, o r irrigation .App ro ximately 95 percent of Id aho Power's retail revenue originates from customers located in Id aho, with the remainder originating fro m customers lo cated in Oregon. Idaho Po wer'sretail customer rates are based on Idah o Power's co st o f service and are d etermined throug h general rate case p ro ceeding s, settlement stipu lations, and o ther filin gs with the IPUC andOPUC. Chan ges in rates and changes in customer d emand are ty pically the primary causes of fluctu ations in retail revenue from period to period. The p rimary influences on chan ges incustomer demand for electricity are weather, eco nomic conditions (in cluding growth in the n umb er of Id aho Power customers), an d en ergy efficiency. Id aho Power's utility rev enu esare not earned evenly during the year. Retail revenu es are billed mo nthly b ased on meter readings taken through o ut the mo nth. Payments for amo unts billed are generally due from the customer within 1 5 days of billing .Id aho Power accrues estimated un b illed revenues fo r energy o r related services delivered to cu sto mers b u t not y et b illed at perio d-en d based on actual meter readings at perio d-en dand estimated rates. Resid ential Cu stomers: Idaho Power's energ y sales to residential customers typically p eak during the su mmer co oling season and winter heating season. Extreme temperatures increasesales to resid ential cu stomers who u se electricity for cooling an d heating, compared with n ormal temperatures. Id aho Power's rate structure provides for hig h er rates du rin g the summerwhen ov erall sy stem lo ads are at their highest, and inclu des tiers such that rates increase as a customer's consumption level increases. Th ese seasonal and tiered rate structu rescontribute to the seasonal fluctu ations in revenues and earn ings. Economic and demo g raph ic condition s can also affect residen tial customer deman d; strong jo b growth andpopulation gro wth in Idaho Po wer's serv ice area have led to higher cu sto mer growth in recent years. Residential demand is also impacted b y energy efficiency initiatives. Id ahoPower's FCA mechan ism mitigates some of the flu ctuations caused by weather and energy efficiency initiatives. Commercial Cu stomers: Most bu sinesses are inclu ded in Idaho Po wer's commercial custo mer class, as are small industrial comp anies, an d pub lic street an d high way lightin g acco u nts.Id aho Power's commercial customers are less influenced b y weath er condition s th an residen tial custo mers, althou gh weather does still affect commercial customer energy use.Economic cond itio ns, including man ufacturing activity levels, an d en ergy efficiency initiativ es also affect en ergy use o f commercial customers. In dustrial Customers: Industrial customers co n sist o f large indu strial compan ies, including sp ecial contract cu sto mers. En ergy use o f industrial customers is primarily driven byeconomic co nditions, with weather having little impact on this customer class. Irrig ation Customers: Irrigatio n custo mers u se electricity to o perate irrigation p umps, p rimarily during the agricultural growing seaso n. Th e amoun t and timing of precipitation as wellas temperature levels affect the timing and amounts of sales to irrig ation customers, with increased precipitation d uring the agricultu ral growing season generally resulting indecreased sales. Provision for Sharin g: Idaho Po wer has regulatory settlement stipulatio ns in Idaho th at pro vide for the potential sharing between Idah o Po wer and its Idah o cu stomers of Idaho -ju risd ictional earnings in excess of 10 .0 percent of Id aho ROE (in excess of 9.6 percent of Id aho ROE beginning in 20 24). Based on full-year 20 2 3 Idaho ROE, Idaho Po wer recordedno prov isio n ag ainst cu rrent revenues fo r sh aring of earnings with customers for 202 3. During 2022, no p rovision was record ed. The regulatory settlement stipulatio ns are describedfurther in No te 3 - "Regulatory Matters." Wholesale Energy Sales: As a public utility u n der th e FPA, Idaho Power has the autho rity to charge market-based rates fo r wholesale energy sales u nder its FERC tariff. Idaho Po wer'swholesale electricity sales are p rimarily to utilities and power marketers and are predominan tly short-term an d co nsist o f a sing le performance oblig ation satisfied as energy istransferred to th e counterparty. Idaho Power's wholesale energy sales dep end largely on the availability o f gen eratio n resou rces in ex cess of th e amou n t necessary to serve custo merloads as well as adeq uate market power prices and d emand at the time when those resources are av ailab le. A reduction in any of tho se factors may lead to lower wholesale energy sales. Tra nsmission Wheeling-Related Revenues: As a p ublic utility und er the FPA, Idah o Power has th e authority to provid e cost-based wh olesale and retail access transmission serv icesunder its OATT. Services under the OATT are offered on a n ondiscriminato ry basis such that all p otential cu stomers have an equal op p ortunity to access th e transmission system. Idah oPower's transmissio n rev enu e is primarily related to th ird parties reserv ing capacity on Idaho Power's transmissio n system to tran smit electricity throu g h Idaho Power's serv ice area.Reservatio n s are pred ominantly short-term contracts or o n -demand wh en available, bu t may be part of a long-term capacity contract. Tran smission wheelin g -related reven ues consistof a sing le performance ob lig ation satisfied as capacity on Idah o Power's transmission system is prov ided to the third p arty. Tran smission wh eelin g-related revenues are affected bychanges in Idah o Power's OATT rate an d cu sto mer demand. Demand fo r transmission services can be affected by region al market factors, such as loads an d generation of utilities inIdaho Power's region . Energ y Efficiency Program Revenues: Id aho Power collects most o f its energy efficien cy program costs th rough an energ y efficien cy rid er on customer b ills. The rid er collections aredeferred u ntil ex p end itu res are incurred . Energ y efficien cy p rogram ex pen d itures fun ded through the rid er are reported as an o p eratin g expen se with an eq ual amou nt recognized inrevenues, resulting in no n et impact on earn ings. The cu mulativ e v arian ce between expenditures and amo unts co llected thro ugh th e rider is recorded as a reg ulatory asset o r liability. Aliability b alan ce indicates th at Idaho Power has collected mo re than it h as spen t, an d an asset b alan ce indicates th at Idaho Power has sp ent more than it has collected . At Decemb er 31 ,2 023, Idah o Power's en ergy efficiency rider balances were a $0 .7 millio n reg ulatory liability in the Idaho jurisdictio n and a $0.8 million regu latory liability in the Oregon jurisd iction. Alternativ e Rev enue Pro grams and Other Revenues Wh ile revenu es from con tracts with customers make u p mo st of Idaho Po wer's rev enu es, the IPUC has authorized the u se of an additional reg ulatory mechanism, th e Id aho FCAmechanism, which may increase or d ecrease tariff-based customer rates. The Idah o FCA mechanism is d escribed in Note 3 - "Reg ulatory Matters." Th e FCA mechanism revenuesinclude on ly the initial reco g nition o f FCA revenues wh en th ey meet the regu lator-specified con ditions for recog nition. Reven u e fro m contracts with customers ex cludes the portionof the tariff price representing FCA reven ues that Idaho Po wer initially recorded in p rio r perio ds wh en revenues met regulator-sp ecified conditio n s. When Idah o Power inclu d es thoseamounts in the price o f utility serv ice and billed to cu sto mers, Id aho Power reco rd s su ch amou nts as recovery of the asso ciated regulato ry asset o r liability and not as revenues. Derivative rev enues inclu de g ains from settled electricity swaps an d sales o f electricity und er forward sales contracts that are bund led with RECs. Related to these forward sales, IdahoPower simu ltaneo usly en ters into fo rward pu rchases of electricity for th e same quan tity at the same location, which are record ed in purchased power on the statemen ts o f inco me. Formore information o n settled electricity swaps, see Note 14 - "Derivative Finan cial Instru ments." 5 . LONG-TERM DEBT Th e follo wing table summarizes Idaho Po wer's lon g-term deb t at December 31 (in thousan ds of do llars): 202 3 2022First mortgag e bo nds: 2.50% Series d ue 2 023 $ $ 75,0001.90% Series d ue 2 030 8 0 ,000 80,0006.00% Series d ue 2 032 10 0 ,000 100,000
4.99% Series d ue 2 032 2 3 ,000 23,000
5.50% Series d ue 2 033 7 0 ,000 70,000
5.50% Series d ue 2 034 5 0 ,000 50,000
5.875% Series due 2034 5 5 ,000 55,000
5.30% Series d ue 2 035 6 0 ,000 60,000
6.30% Series d ue 2 037 14 0 ,000 140,000
6.25% Series d ue 2 037 10 0 ,000 100,000
4.85% Series d ue 2 040 10 0 ,000 100,000
4.30% Series d ue 2 042 7 5 ,000 75,000
5.06% Series d ue 2 042 2 5 ,000 25,000
5.06% Series d ue 2 043 6 0 ,000
4.00% Series d ue 2 043 7 5 ,000 75,000
3.65% Series d ue 2 045 25 0 ,000 250,000
4.05% Series d ue 2 046 12 0 ,000 120,000
4.20% Series d ue 2 048 45 0 ,000 450,000
5.20% Series d ue 2 053 6 2 ,000
5.50% Series d ue 2 053 40 0 ,000
5.80% Series d ue 2 054 35 0 ,000
Total first mortgag e bo nds 2,64 5 ,000 1 ,848,000
Po llu tion control reven ue b onds:
1.45% Series d ue 2 024(1 ) 4 9 ,800 49,800
1.70% Series d ue 2 026(1 ) 11 6 ,300 116,300
Total p ollution control revenue bond s 16 6 ,100 166,100
Flo ating Rate Term Lo an Facility due 202 4 150,000
American Falls Variab le Rate bo n d gu aran tee due 2025 1 9 ,885 19,885
Unamortized p remiu m/discou nt 17,0 02 24,770
Total Idaho Po wer outstan ding d ebt(2 ) 2,84 7 ,987 2 ,208,755

(1) Humb oldt County and Sweetwater County Po llu tion Control Rev enue Bonds are secured by th e first mortgage bonds, b ringing the total first mortgage b on ds o utstan ding at December 31 , 2 023, to $2.811
billio n.
(2) At Decemb er 31, 2023 and 20 22 , the ov erall effectiv e co st rate of Idaho Power's o utstan din g debt was 4 .98 p ercent an d 4.60 p ercent, respectively.

At December 31, 2 023, the matu rities for the ag greg ate amo unt of Idaho Power lo ng-term debt ou tstanding were as follows (in thou sands of d ollars):
202 4 202 5 2026 2 027 2 028 Therea fter
$ 4 9,800 $ 1 9,885 $ 116,3 00 $ $ $ 2,6 45,00 0

Long-Term Debt Issuances, Maturities, a nd Redemptio ns

On September 11, 20 23, u nder the shelf reg istration statement with the SEC, Idaho Power issu ed $350 million in ag g regate p rin cipal amount of 5.8 0% first mo rtgage bon ds, secured
med iu m-term no tes, Series M, maturin g on Ap ril 1, 20 54.

On April 1, 20 23, Id aho Power repaid $75 million in ag gregate p rincipal amoun t of maturing 2.50 % first mortgage bond s d ue 2 023, Series I.

On March 14, 2023, under the shelf registration statement with th e SEC, Idaho Power issued $40 0 million in aggreg ate principal amou nt of 5 .50% first mortgage b onds, secured
med iu m-term no tes, Series M, maturin g on M arch 15, 2053.

On March 8, 2 023, pursuan t to the Bond Purchase Agreement d efined below, Idaho Power issu ed $60 million in aggregate prin cipal amount o f 5.06 % first mortg age bond s, secu red
med iu m-term no tes, Series N, maturing on March 8, 20 43; and $6 2 millio n in aggregate principal amo unt of 5 .20% first mortgage bonds, secured medium-term notes, Series N,
matu rin g on M arch 8, 2 053.

On December 22, 2022 , Idaho Po wer en tered into a Bond Purch ase Agreement (Bond Purchase Ag reement) with certain institution al pu rchasers relatin g to th e sale by Idah o Power of
$170 million o f first mortgage bonds secured medium-term-term n otes, Series N (Series N Notes), as described in mo re d etail below.

On December 1, 2 022, Idah o Power redeemed at par $4.36 millio n in p rincipal amoun t of variable-rate pollution co n trol rev enue bo n ds due in 2 0 27.

On March 4, 2 022, Idaho Power entered in to a floating rate term loan credit agreement (Term Loan Facility). The Term Loan Facility was a two-year senio r unsecured term loan facility
in the agg regate prin cipal amount o f $150 million . On March 3 1 , 20 2 3, Id aho Power repaid $100 million and on May 17 , 202 3 , repaid $50 million p rin cipal amount to fully repay the
Term Loan Facility. At December 31, 2023, there was no remaining outstan d ing prin cipal balance of the Term Loan Facility.

Ida ho Power First Mo rtgag e Bonds

Id aho Power's issuance of lo n g-term indebted n ess is su bject to the approval of th e IPUC, OPUC, and WPSC. In M ay and Jun e 2 0 22, Id aho Power received orders fro m the IPUC, OPUC,
and WPSC auth orizing the company to issue and sell from time to time up to $1 .2 billion in aggreg ate princip al amou nt of d ebt securities and first mortgage b onds, subject to
cond itio ns sp ecified in the orders. Auth o rity from the IPUC is effectiv e th ro ugh May 3 1 , 20 2 5, subject to ex tensions up on request to the IPUC. Th e OPUC's an d WPSC's o rders do not
impose a time limitation for issu ances, b u t the OPUC ord er do es imp o se a number o f other con ditions, including a requirement that the interest rates for the d ebt securities or first
mortgage bonds fall with in eith er (a) design ated spreads over comparable U.S. Treasury rates o r (b) a maximu m interest rate limit of 8.0 percen t. At Decemb er 31 , 202 3, $2 80 millio n
remains av ailab le for debt issuance und er the reg ulatory orders. In Janu ary 2 024, Idah o Power su bmitted ap plications to the IPUC, OPUC, and WPSC req uesting autho rization to issue
and sell from time to time up to $1 .2 billion in aggreg ate princip al amou nt of d ebt securities and first mortgag e b onds, which if approved will rep lace the $28 0 millio n remainin g
u nder the existing regulatory ord ers. On February 8, 2024 , Idaho Po wer received an order from OPUC authorizing its request. As of th e d ate of this report, approv als from the IPUC and
WPSC are still pend ing.

In May 2022, Idah o Po wer filed a shelf registratio n statemen t with the SEC, which became effectiv e u pon filing , for th e o ffer an d sale of an un sp ecified principal amount o f its first
mortgage bonds. Th e issuan ce of first mortg age bon d s requires that Id aho Power meet interest co verage and security provisions set fo rth in Id aho Power's Inden ture o f M ortgag e and
Deed o f Trust, d ated as of October 1, 1 937, as amen d ed and su pplemented from time to time (In dentu re). Future issuances of first mo rtg age bon ds are su bject to satisfaction of
covenan ts and security provisions set forth in th e In d entu re, market co nditions, regulatory authorizations, and cov enants con tained in o ther fin ancing agreements.

In June 2022, Idah o Po wer entered into a selling agency agreement with six ban k s named in the agreement in co nnection with th e p o tential issu ance and sale from time to time o f up
to $1.2 billion aggregate principal amount o f first mortgage bonds, secured medium term no tes, Series M (Series M Notes), under Idah o Po wer's Indenture. Also in June 202 2, Idaho
Power entered into the Fiftieth Supplemen tal Ind enture, d ated effective as of Ju ne 3 0, 20 22, to the Inden ture (Fiftieth Supplemen tal Ind enture). The Fiftieth Sup plemental Indenture
p rovides for, amo n g other items, the issu ance of up to $1.2 billion in agg regate p rin cipal amount o f Series M Notes pu rsu ant to the In den tu re. In October 202 2, Idaho Power entered
in to the Fifty-first Sup p lemental Indenture to increase the limit of the amo u nt of first mortgag e b onds at any one time outstan ding to $3.5 billion as provid ed in the Inden ture. The
amo unt issu able is also restricted by p roperty, earning s, and other provisions o f the Inden ture and sup plemental indentures to the Inden ture. The In dentu re requires th at Idaho Power's
n et earnin gs be at least twice the annu al interest requirements o n all o utstandin g debt of equal or prio r rank , including the b onds that Idaho Po wer may pro p ose to issue. Under certain
circu mstances, th e net earnings test does n ot ap ply, inclu d ing the issu ance o f refun ding b onds to retire o utstandin g bon ds that matu re in less than two years or that are of an equal or
h igher interest rate, or prio r lien bonds.

In Decemb er 20 22, Id aho Power entered into the Bo n d Pu rchase Agreement with certain institu tional purch asers, relating to the sale by Id aho Power of $170 million in ag gregate
p rincipal amoun t of Series N Notes. Also in December 2022 , Idaho Po wer en tered into th e Fifty -secon d Sup plemental Indenture, dated effective as of December 30, 2 022, to the
In den tu re (Fifty -secon d Sup p lemental Indenture). The Fifty-seco nd Su pplemen tal Ind enture prov id es for, among other items, th e issuan ce of Series N Notes pu rsuant to the In den tu re.
5.875% Series due 2034 5 5 ,000 55,0005.30% Series d ue 2 035 6 0 ,000 60,0006.30% Series d ue 2 037 14 0 ,000 140,0006.25% Series d ue 2 037 10 0 ,000 100,0004.85% Series d ue 2 040 10 0 ,000 100,0004.30% Series d ue 2 042 7 5 ,000 75,0005.06% Series d ue 2 042 2 5 ,000 25,0005.06% Series d ue 2 043 6 0 ,000 4.00% Series d ue 2 043 7 5 ,000 75,0003.65% Series d ue 2 045 25 0 ,000 250,0004.05% Series d ue 2 046 12 0 ,000 120,0004.20% Series d ue 2 048 45 0 ,000 450,0005.20% Series d ue 2 053 6 2 ,000 5.50% Series d ue 2 053 40 0 ,000 5.80% Series d ue 2 054 35 0 ,000 Total first mortgag e bo nds 2,64 5 ,000 1 ,848,000Pollution control reven ue b onds: 1.45% Series d ue 2 024(1 ) 4 9 ,800 49,8001.70% Series d ue 2 026(1 ) 11 6 ,300 116,300Total p ollution control revenue bond s 16 6 ,100 166,100Floating Rate Term Lo an Facility due 202 4 150,000American Falls Variab le Rate bo n d gu aran tee due 2025 1 9 ,885 19,885Unamortized p remiu m/discou nt 17,0 02 24,770Total Idaho Po wer outstan ding d ebt(2 ) 2,84 7 ,987 2 ,208,755 (1) Humb oldt County and Sweetwater County Po llu tion Control Rev enue Bonds are secured by th e first mortgage bonds, b ringing the total first mortgage b on ds o utstan ding at December 31 , 2 023, to $2.811billion.(2) At Decemb er 31, 2023 and 20 22 , the ov erall effectiv e co st rate of Idaho Power's o utstan din g debt was 4 .98 p ercent an d 4.60 p ercent, respectively. At December 31, 2 023, the matu rities for the ag greg ate amo unt of Idaho Power lo ng-term debt ou tstanding were as follows (in thou sands of d ollars): 202 4 202 5 2026 2 027 2 028 Therea fter $ 4 9,800 $ 1 9,885 $ 116,3 00 $ $ $ 2,6 45,00 0 Long-Term Debt Issuances, Maturities, a nd Redemptio ns On September 11, 20 23, u nder the shelf reg istration statement with the SEC, Idaho Power issu ed $350 million in ag g regate p rin cipal amount of 5.8 0% first mo rtgage bon ds, securedmedium-term no tes, Series M, maturin g on Ap ril 1, 20 54. On April 1, 20 23, Id aho Power repaid $75 million in ag gregate p rincipal amoun t of maturing 2.50 % first mortgage bond s d ue 2 023, Series I. On March 14, 2023, under the shelf registration statement with th e SEC, Idaho Power issued $40 0 million in aggreg ate principal amou nt of 5 .50% first mortgage b onds, securedmedium-term no tes, Series M, maturin g on M arch 15, 2053. On March 8, 2 023, pursuan t to the Bond Purchase Agreement d efined below, Idaho Power issu ed $60 million in aggregate prin cipal amount o f 5.06 % first mortg age bond s, secu redmedium-term no tes, Series N, maturing on March 8, 20 43; and $6 2 millio n in aggregate principal amo unt of 5 .20% first mortgage bonds, secured medium-term notes, Series N,matu rin g on M arch 8, 2 053. On December 22, 2022 , Idaho Po wer en tered into a Bond Purch ase Agreement (Bond Purchase Ag reement) with certain institution al pu rchasers relatin g to th e sale by Idah o Power of$170 million o f first mortgage bonds secured medium-term-term n otes, Series N (Series N Notes), as described in mo re d etail below. On December 1, 2 022, Idah o Power redeemed at par $4.36 millio n in p rincipal amoun t of variable-rate pollution co n trol rev enue bo n ds due in 2 0 27. On March 4, 2 022, Idaho Power entered in to a floating rate term loan credit agreement (Term Loan Facility). The Term Loan Facility was a two-year senio r unsecured term loan facilityin the agg regate prin cipal amount o f $150 million . On March 3 1 , 20 2 3, Id aho Power repaid $100 million and on May 17 , 202 3 , repaid $50 million p rin cipal amount to fully repay theTerm Loan Facility. At December 31, 2023, there was no remaining outstan d ing prin cipal balance of the Term Loan Facility. Ida ho Power First Mo rtgag e Bonds Id aho Power's issuance of lo n g-term indebted n ess is su bject to the approval of th e IPUC, OPUC, and WPSC. In M ay and Jun e 2 0 22, Id aho Power received orders fro m the IPUC, OPUC,and WPSC auth orizing the company to issue and sell from time to time up to $1 .2 billion in aggreg ate princip al amou nt of d ebt securities and first mortgage b onds, subject toconditions sp ecified in the orders. Auth o rity from the IPUC is effectiv e th ro ugh May 3 1 , 20 2 5, subject to ex tensions up on request to the IPUC. Th e OPUC's an d WPSC's o rders do notimpose a time limitation for issu ances, b u t the OPUC ord er do es imp o se a number o f other con ditions, including a requirement that the interest rates for the d ebt securities or firstmortgage bonds fall with in eith er (a) design ated spreads over comparable U.S. Treasury rates o r (b) a maximu m interest rate limit of 8.0 percen t. At Decemb er 31 , 202 3, $2 80 millio nremains av ailab le for debt issuance und er the reg ulatory orders. In Janu ary 2 024, Idah o Power su bmitted ap plications to the IPUC, OPUC, and WPSC req uesting autho rization to issueand sell from time to time up to $1 .2 billion in aggreg ate princip al amou nt of d ebt securities and first mortgag e b onds, which if approved will rep lace the $28 0 millio n remainin gunder the existing regulatory ord ers. On February 8, 2024 , Idaho Po wer received an order from OPUC authorizing its request. As of th e d ate of this report, approv als from the IPUC andWPSC are still pend ing. In May 2022, Idah o Po wer filed a shelf registratio n statemen t with the SEC, which became effectiv e u pon filing , for th e o ffer an d sale of an un sp ecified principal amount o f its firstmortgage bonds. Th e issuan ce of first mortg age bon d s requires that Id aho Power meet interest co verage and security provisions set fo rth in Id aho Power's Inden ture o f M ortgag e andDeed o f Trust, d ated as of October 1, 1 937, as amen d ed and su pplemented from time to time (In dentu re). Future issuances of first mo rtg age bon ds are su bject to satisfaction ofcovenants and security provisions set forth in th e In d entu re, market co nditions, regulatory authorizations, and cov enants con tained in o ther fin ancing agreements. In June 2022, Idah o Po wer entered into a selling agency agreement with six ban k s named in the agreement in co nnection with th e p o tential issu ance and sale from time to time o f upto $1.2 billion aggregate principal amount o f first mortgage bonds, secured medium term no tes, Series M (Series M Notes), under Idah o Po wer's Indenture. Also in June 202 2, IdahoPower entered into the Fiftieth Supplemen tal Ind enture, d ated effective as of Ju ne 3 0, 20 22, to the Inden ture (Fiftieth Supplemen tal Ind enture). The Fiftieth Sup plemental Indentureprovides for, amo n g other items, the issu ance of up to $1.2 billion in agg regate p rin cipal amount o f Series M Notes pu rsu ant to the In den tu re. In October 202 2, Idaho Power enteredinto the Fifty-first Sup p lemental Indenture to increase the limit of the amo u nt of first mortgag e b onds at any one time outstan ding to $3.5 billion as provid ed in the Inden ture. Theamount issu able is also restricted by p roperty, earning s, and other provisions o f the Inden ture and sup plemental indentures to the Inden ture. The In dentu re requires th at Idaho Power'snet earnin gs be at least twice the annu al interest requirements o n all o utstandin g debt of equal or prio r rank , including the b onds that Idaho Po wer may pro p ose to issue. Under certaincircumstances, th e net earnings test does n ot ap ply, inclu d ing the issu ance o f refun ding b onds to retire o utstandin g bon ds that matu re in less than two years or that are of an equal or
h igher interest rate, or prio r lien bonds.

In Decemb er 20 22, Id aho Power entered into the Bo n d Pu rchase Agreement with certain institu tional purch asers, relating to the sale by Id aho Power of $170 million in ag gregate
p rincipal amoun t of Series N Notes. Also in December 2022 , Idaho Po wer en tered into th e Fifty -secon d Sup plemental Indenture, dated effective as of December 30, 2 022, to the
In den tu re (Fifty -secon d Sup p lemental Indenture). The Fifty-seco nd Su pplemen tal Ind enture prov id es for, among other items, th e issuan ce of Series N Notes pu rsuant to the In den tu re.In den tu re (Fifty -secon d Sup p lemental Indenture). The Fifty-seco nd Su pplemen tal Ind enture prov id es for, among other items, th e issuan ce of Series N Notes pu rsuant to the In den tu re.
Th e Series N Notes consist of:

$23 million in agg regate p rin cipal amount of Idaho Po wer's 4.9 9% first mo rtgag e bo nds due 203 2 , Series N Notes, Tranche 1 (Tranche 1 Bon ds);
$25 million in agg regate p rin cipal amount of Idaho Po wer's 5.0 6% first mo rtgag e bo nds due 204 2 , Series N Notes, Tranche 2 (Tranche 2 Bon ds);
$60 million in agg regate p rin cipal amount of Idaho Po wer's 5.0 6% first mo rtgag e bo nds due 204 3 , Series N Notes, Tranche 3 (Tranche 3 Bon ds); and
$62 million in agg regate p rin cipal amount of Idaho Po wer's 5.2 0% first mo rtgag e bo nds due 205 3 , Series N Notes, Tranche 4 (Tranche 4 Bon ds).

Th e Tranche 1 Bo nds an d Tranch e 2 Bo n ds were issued on December 22, 2022 , an d the Tranche 3 Bon ds and Tran che 4 Bond s were issued on March 8 , 20 23, each un der th e Ind enture.

Th e mortgag e o f the Inden ture secures all bo nds issued u n der th e In dentu re equally an d ratably, with out preference, prio rity, o r distin ction . First mo rtg age bon ds issued in the fu ture
will also be secu red b y the mortg age of the Indenture. The lien con stitutes a first mortgag e o n all th e p ro perties of Idaho Po wer, sub ject only to certain limited exception s includ ing
liens for taxes and assessments that are not delinq uent and minor excepted encu mbrances. Certain of the prop erties of Idaho Power are su bject to easements, leases, contracts,
covenan ts, wo rkmen's comp ensation award s, and similar encumbrances an d min o r defects common to properties. The mortgag e of the In dentu re do es not create a lien on revenues o r
p rofits, or n o tes or accounts receivable, contracts or choses in actio n, except as permitted b y law d u ring a co mpleted d efau lt, securities, o r cash , ex cept when pledg ed, or merch andise
o r eq u ipment manufactured or acquired for resale. Th e mortgage o f the Inden ture creates a lien on the interest of Id aho Power in property subseq u ently acquired , other than ex cepted
p roperty, subject to limitations in the case o f con so lid ation, merger, or sale of all or su b stantially all o f the assets of Idaho Power. The In dentu re requires Id aho Power to sp end or
appro p riate 15 p ercent of its annu al gro ss op eratin g rev enues for maintenance, retiremen t, or amo rtization of its pro p erties. Idaho Power may, h owever, anticipate o r make up these
expenditures or ap propriations with in the 5 y ears th at immed iately follow or p recede a p articu lar year.

As of December 31, 2023, the maximum amount of ad ditional first mortgage bonds Id aho Power could issue app roximately $700 million, thoug h as of the d ate of this report the
amo unt is limited to the $280 million amou nt au thorized by the IPUC, OPUC, and WPSC. Sep arately, the Inden ture also limits the amoun t of additional first mortgage bond s th at
Id aho Power may issue to th e sum of (a) the princip al amoun t of retired first mortgag e bo nds an d (b) 6 0 percen t of total unfu nded property additions, as defin ed in the Indenture. As o f
December 31, 2023, Idah o Power cou ld issu e approximately $1 .9 billion of additional first mortg age bond s based on retired first mortgage b onds and total unfu nded property
addition s.

6 . COMMON STOCK

Ida ho Power Commo n Stock

No contrib u tions were made to Idah o Po wer in 20 23 and 20 22 and n o ad ditional sh ares o f Idah o Power common sto ck were issued .
Restrictions o n Dividends

Id aho Power's ability to pay divid ends o n its common stock held by IDACORP is limited to the extent payment of such d iv idend s wou ld violate th e covenants in its Credit Facility o r
Id aho Power's Revised Cod e of Co n duct. A coven ant u nder Idaho Power's credit facility requires Idaho Power to main tain a leverage ratio of con solid ated indebtedn ess to consolidated
to tal capitalizatio n, as defin ed th erein , of n o mo re than 6 5 percen t at th e end o f each fiscal q u arter. At Decemb er 3 1, 20 23, th e leverage ratio fo r Idah o Power was 51 p ercent. Based on
th ese restrictions, Id aho Power's dividends were limited to $1 .2 billio n at December 31, 2023. There are additional facility coven ants, sub ject to ex cep tions, that proh ib it or restrict the
sale o r disposition of property with out consen t and any agreements restricting d iv iden d payments to Idaho Po wer from any material su bsid iary. At Decemb er 31 , 202 3, Idaho Power
was in co mpliance with those cov enants.

Id aho Power's Revised Policy and Co de o f Conduct relating to transactions between and among Id aho Power, IDACORP, and other affiliates, which was appro ved by the IPUC in April
2 008, provides that Idaho Power will n ot pay an y divid ends to IDACORP that will reduce Id aho Power's common equity capital b elow 35 percent of its total adjusted capital with o ut
IPUC approval. At December 3 1, 2 0 23, Id aho Power's common equ ity capital was 50 p ercent of its to tal adjusted cap ital. Further, Idaho Power mu st obtain app roval from th e OPUC
b efore it can d irectly or ind irectly loan funds or issue notes or give credit o n its book s to IDACORP.

Id aho Power's articles of incorporation contain restrictio ns on the payment of dividends on its common stock if p referred stock divid ends are in arrears. As of the date of this repo rt,
Id aho Power h as no preferred stock ou tstanding.

In ad d ition to contractual restrictio ns on th e amou nt an d payment of d ividen ds, the FPA prohibits the payment of dividen ds from "capital acco unts." The term "capital acco unt" is
u ndefin ed in the FPA or its regu lations, b ut Idaho Po wer does not b eliev e the restriction would limit Idaho Power's ability to pay dividends out o f cu rrent y ear earn ings or retained
earn in gs.

In accord ance with Sectio n 10(d ) of the Federal Power Act, Idaho Power has $13.3 million of amortization reserves estab lished for certain of its licen sed hy d roelectric facilities.

7 . SHARE-BASED COMPENSATION

Th rough its p aren t co mpany IDACORP, Idah o Power has on e share-based comp ensatio n plan the 2000 Long-Term In centive and Co mpensation Plan (LTICP). The LTICP (for o fficers,
k ey emp loyees, an d directors) permits the gran t of stock optio ns, restricted stock an d restricted stock un its, performance shares and p erformance-based un its, and several oth er typ es of
share-based awards. At December 3 1, 2 023, the max imum numb er o f sh ares available under the LTICP was 2 44,93 8.

Restricted Sto ck Unit a nd Perfo rmance-Based Unit Awards

Restricted stock un it award s h ave three-year v esting periods, entitle th e recipients to d iv idend eq u ivalents, an d un its d o not have vo tin g rights un til the units are vested and settled in
shares. Unv ested awards are restricted as to d ispo sition an d subject to fo rfeiture under certain circu mstances. Th e fair valu e o f these award s is b ased on the clo sin g market price of
common stock o n the gran t date an d is ch arged to compensation expen se over the vesting perio d, reduced fo r any forfeitures during the vesting p eriod.

Performance-based u nit award s have three-year v esting p eriods and d o not h ave votin g rights un til the u nits are vested an d settled in shares. Unvested awards are restricted as to
d isp ositio n, subject to forfeiture und er certain circumstances, and subject to th e attainment o f specific p erformance condition s o ver th e th ree-y ear vesting period . The perfo rman ce
cond itio ns are two eq ually-weig hted metrics, cu mulative earn in gs per sh are (CEPS) an d total sh areh older return (TSR) relativ e to a p eer group. Depending o n the lev el of attain men t of
th e p erformance condition s and the y ear issued, th e final number of shares award ed can rang e from zero to 200 p ercent o f the target award . Dividen d eq uivalents are accru ed d uring th e
v esting p eriod and paid out based o n the final numb er o f sh ares awarded.

Th e g rant-date fair valu e o f the CEPS portion is based on th e closing market valu e at the date of grant, redu ced by th e lo ss in time-v alue of the estimated future dividend p ayments.
Th e fair valu e o f this portion of the award s is charged to co mpensation exp ense o ver th e requisite service perio d based o n the estimated ach ievement of p erformance targets, reduced
fo r an y forfeitu res during the vesting period . The gran t-date fair v alue of th e TSR po rtio n is estimated using the market valu e at the date of g rant and a statistical mo del th at
in corpo rates th e pro bability of meetin g performance targ ets based on historical return s relative to th e p eer group. The fair value of this po rtio n of th e awards is charged to
compensatio n expen se over the requ isite service p eriod, provid ed th e requisite serv ice perio d is rend ered , regardless o f the level of TSR metric attained.

A su mmary of restricted stock units an d performance-based units award activity is p resented below. Id aho Power u nit amounts represen t units of IDACORP:

Number of
Units
Weighted-
Av erage
Gra nt Date
Fair Value
Non v ested units at January 1, 2023 187,8 16 $ 9 9 .91
Units granted 94,118 10 3 .98
Units forfeited (2,6 04) 9 9 .37
Units vested (70,1 06) 11 3 .07
Non v ested units at December 31, 2023 209,2 24 $ 9 7 .34

Th e total fair value of shares vested was $7.5 million in 2023 and $6.9 million in 20 22. At December 31, 2 023, Idaho Power had $8.0 million of total unrecogn ized co mpensation cost
related to nonvested share-based comp ensatio n . These costs are expected to b e recog nized over a weighted-averag e period o f 1.6 years. Orig inal issue sh ares o f IDACORP are used for
In den tu re (Fifty -secon d Sup p lemental Indenture). The Fifty-seco nd Su pplemen tal Ind enture prov id es for, among other items, th e issuan ce of Series N Notes pu rsuant to the In den tu re.Th e Series N Notes consist of: $23 million in agg regate p rin cipal amount of Idaho Po wer's 4.9 9% first mo rtgag e bo nds due 203 2 , Series N Notes, Tranche 1 (Tranche 1 Bon ds); $25 million in agg regate p rin cipal amount of Idaho Po wer's 5.0 6% first mo rtgag e bo nds due 204 2 , Series N Notes, Tranche 2 (Tranche 2 Bon ds); $60 million in agg regate p rin cipal amount of Idaho Po wer's 5.0 6% first mo rtgag e bo nds due 204 3 , Series N Notes, Tranche 3 (Tranche 3 Bon ds); and $62 million in agg regate p rin cipal amount of Idaho Po wer's 5.2 0% first mo rtgag e bo nds due 205 3 , Series N Notes, Tranche 4 (Tranche 4 Bon ds). Th e Tranche 1 Bo nds an d Tranch e 2 Bo n ds were issued on December 22, 2022 , an d the Tranche 3 Bon ds and Tran che 4 Bond s were issued on March 8 , 20 23, each un der th e Ind enture. Th e mortgag e o f the Inden ture secures all bo nds issued u n der th e In dentu re equally an d ratably, with out preference, prio rity, o r distin ction . First mo rtg age bon ds issued in the fu turewill also be secu red b y the mortg age of the Indenture. The lien con stitutes a first mortgag e o n all th e p ro perties of Idaho Po wer, sub ject only to certain limited exception s includ ingliens for taxes and assessments that are not delinq uent and minor excepted encu mbrances. Certain of the prop erties of Idaho Power are su bject to easements, leases, contracts,covenan ts, wo rkmen's comp ensation award s, and similar encumbrances an d min o r defects common to properties. The mortgag e of the In dentu re do es not create a lien on revenues o rprofits, or n o tes or accounts receivable, contracts or choses in actio n, except as permitted b y law d u ring a co mpleted d efau lt, securities, o r cash , ex cept when pledg ed, or merch andiseor eq u ipment manufactured or acquired for resale. Th e mortgage o f the Inden ture creates a lien on the interest of Id aho Power in property subseq u ently acquired , other than ex ceptedproperty, subject to limitations in the case o f con so lid ation, merger, or sale of all or su b stantially all o f the assets of Idaho Power. The In dentu re requires Id aho Power to sp end orappropriate 15 p ercent of its annu al gro ss op eratin g rev enues for maintenance, retiremen t, or amo rtization of its pro p erties. Idaho Power may, h owever, anticipate o r make up theseexpenditures or ap propriations with in the 5 y ears th at immed iately follow or p recede a p articu lar year. As of December 31, 2023, the maximum amount of ad ditional first mortgage bonds Id aho Power could issue app roximately $700 million, thoug h as of the d ate of this report theamount is limited to the $280 million amou nt au thorized by the IPUC, OPUC, and WPSC. Sep arately, the Inden ture also limits the amoun t of additional first mortgage bond s th atIdaho Power may issue to th e sum of (a) the princip al amoun t of retired first mortgag e bo nds an d (b) 6 0 percen t of total unfu nded property additions, as defin ed in the Indenture. As o fDecember 31, 2023, Idah o Power cou ld issu e approximately $1 .9 billion of additional first mortg age bond s based on retired first mortgage b onds and total unfu nded propertyadditions. 6 . COMMON STOCK Ida ho Power Commo n Stock No contrib u tions were made to Idah o Po wer in 20 23 and 20 22 and n o ad ditional sh ares o f Idah o Power common sto ck were issued .Restrictions o n Dividends Id aho Power's ability to pay divid ends o n its common stock held by IDACORP is limited to the extent payment of such d iv idend s wou ld violate th e covenants in its Credit Facility o rIdaho Power's Revised Cod e of Co n duct. A coven ant u nder Idaho Power's credit facility requires Idaho Power to main tain a leverage ratio of con solid ated indebtedn ess to consolidatedtotal capitalizatio n, as defin ed th erein , of n o mo re than 6 5 percen t at th e end o f each fiscal q u arter. At Decemb er 3 1, 20 23, th e leverage ratio fo r Idah o Power was 51 p ercent. Based onthese restrictions, Id aho Power's dividends were limited to $1 .2 billio n at December 31, 2023. There are additional facility coven ants, sub ject to ex cep tions, that proh ib it or restrict thesale o r disposition of property with out consen t and any agreements restricting d iv iden d payments to Idaho Po wer from any material su bsid iary. At Decemb er 31 , 202 3, Idaho Powerwas in co mpliance with those cov enants. Id aho Power's Revised Policy and Co de o f Conduct relating to transactions between and among Id aho Power, IDACORP, and other affiliates, which was appro ved by the IPUC in April2008, provides that Idaho Power will n ot pay an y divid ends to IDACORP that will reduce Id aho Power's common equity capital b elow 35 percent of its total adjusted capital with o utIPUC approval. At December 3 1, 2 0 23, Id aho Power's common equ ity capital was 50 p ercent of its to tal adjusted cap ital. Further, Idaho Power mu st obtain app roval from th e OPUCbefore it can d irectly or ind irectly loan funds or issue notes or give credit o n its book s to IDACORP. Id aho Power's articles of incorporation contain restrictio ns on the payment of dividends on its common stock if p referred stock divid ends are in arrears. As of the date of this repo rt,Id aho Power h as no preferred stock ou tstanding. In ad d ition to contractual restrictio ns on th e amou nt an d payment of d ividen ds, the FPA prohibits the payment of dividen ds from "capital acco unts." The term "capital acco unt" isundefined in the FPA or its regu lations, b ut Idaho Po wer does not b eliev e the restriction would limit Idaho Power's ability to pay dividends out o f cu rrent y ear earn ings or retainedearnings. In accord ance with Sectio n 10(d ) of the Federal Power Act, Idaho Power has $13.3 million of amortization reserves estab lished for certain of its licen sed hy d roelectric facilities. 7 . SHARE-BASED COMPENSATION Th rough its p aren t co mpany IDACORP, Idah o Power has on e share-based comp ensatio n plan the 2000 Long-Term In centive and Co mpensation Plan (LTICP). The LTICP (for o fficers,k ey emp loyees, an d directors) permits the gran t of stock optio ns, restricted stock an d restricted stock un its, performance shares and p erformance-based un its, and several oth er typ es ofshare-based awards. At December 3 1, 2 023, the max imum numb er o f sh ares available under the LTICP was 2 44,93 8. Restricted Sto ck Unit a nd Perfo rmance-Based Unit Awards Restricted stock un it award s h ave three-year v esting periods, entitle th e recipients to d iv idend eq u ivalents, an d un its d o not have vo tin g rights un til the units are vested and settled inshares. Unv ested awards are restricted as to d ispo sition an d subject to fo rfeiture under certain circu mstances. Th e fair valu e o f these award s is b ased on the clo sin g market price ofcommon stock o n the gran t date an d is ch arged to compensation expen se over the vesting perio d, reduced fo r any forfeitures during the vesting p eriod. Performance-based u nit award s have three-year v esting p eriods and d o not h ave votin g rights un til the u nits are vested an d settled in shares. Unvested awards are restricted as todisposition, subject to forfeiture und er certain circumstances, and subject to th e attainment o f specific p erformance condition s o ver th e th ree-y ear vesting period . The perfo rman ceconditions are two eq ually-weig hted metrics, cu mulative earn in gs per sh are (CEPS) an d total sh areh older return (TSR) relativ e to a p eer group. Depending o n the lev el of attain men t ofthe p erformance condition s and the y ear issued, th e final number of shares award ed can rang e from zero to 200 p ercent o f the target award . Dividen d eq uivalents are accru ed d uring th evesting p eriod and paid out based o n the final numb er o f sh ares awarded. Th e g rant-date fair valu e o f the CEPS portion is based on th e closing market valu e at the date of grant, redu ced by th e lo ss in time-v alue of the estimated future dividend p ayments.Th e fair valu e o f this portion of the award s is charged to co mpensation exp ense o ver th e requisite service perio d based o n the estimated ach ievement of p erformance targets, reducedfor an y forfeitu res during the vesting period . The gran t-date fair v alue of th e TSR po rtio n is estimated using the market valu e at the date of g rant and a statistical mo del th atincorporates th e pro bability of meetin g performance targ ets based on historical return s relative to th e p eer group. The fair value of this po rtio n of th e awards is charged tocompensation expen se over the requ isite service p eriod, provid ed th e requisite serv ice perio d is rend ered , regardless o f the level of TSR metric attained. A su mmary of restricted stock units an d performance-based units award activity is p resented below. Id aho Power u nit amounts represen t units of IDACORP: Number ofUnits Weighted-Av erageGrant DateFair ValueNonvested units at January 1, 2023 187,8 16 $ 9 9 .91Units granted 94,118 10 3 .98Units forfeited (2,6 04) 9 9 .37
Units vested (70,1 06) 11 3 .07
Non v ested units at December 31, 2023 209,2 24 $ 9 7 .34

Th e total fair value of shares vested was $7.5 million in 2023 and $6.9 million in 20 22. At December 31, 2 023, Idaho Power had $8.0 million of total unrecogn ized co mpensation cost
related to nonvested share-based comp ensatio n . These costs are expected to b e recog nized over a weighted-averag e period o f 1.6 years. Orig inal issue sh ares o f IDACORP are used forrelated to nonvested share-based comp ensatio n . These costs are expected to b e recog nized over a weighted-averag e period o f 1.6 years. Orig inal issue sh ares o f IDACORP are used for
th ese awards.

In 2023 , a total of 12,459 shares of IDACORP common stock were awarded to directors of IDACORP and Idah o Power at an average g rant d ate fair v alue of $1 03.48 per sh are. Directo rs
elected to defer receipt of 4 ,640 of these shares, which are bein g held as d eferred stock units with div idend eq u ivalents reinv ested in ad ditional sto ck u nits.

Compensa tio n Expense: The following table sh ows Id aho Power's compen sation cost recognized in inco me and the tax b enefits resulting fro m the LTICP (in thousands of d o llars):

2023 202 2
Compen sation cost $ 9 ,508 $ 1 0,204
In come tax benefit 2 ,447 2,627

No equity compen sation costs hav e been capitalized. These costs are primarily reported with in "Oth er o p eratio ns and mainten ance" ex pen se on th e statements of income.

8 . COMMITMENTS

Purchase Obligations

At December 31, 2 023, Idah o Power had the fo llowin g long -term commitments relating to purchases o f energy, capacity, transmission rig hts, an d fuel (in thou sands of d ollars):
2024 2025 2 026 2 027 2 028 Therea fter
Cog eneration and power p ro ductio n(1) $ 324,738 $ 336,7 02 $ 3 58,113 $ 371,9 80 $ 3 45,7 4 0 $ 2 ,999,760
Fuel 155,474 25,6 72 15,2 71 15,4 39 15,5 0 7 84,004

(1) As o f Decem ber 31, 202 3, Idaho Power had a $43 1 million comm itment related to an agreement to utilize the storage capacity of a 150 MW battery storage facility, ov er a 20-year term, sch ed uled to be o nline
in Jun e 2025.

As of December 31, 2023, Idah o Power had power purch ase o bligatio n s with respect to 1 ,432 M W nameplate cap acity of on line PURPA and non-PURPA p ro jects, with an additio nal
4 28 MW n ameplate capacity o f projects that are scheduled to b e on lin e th ro ugh 2 026. The agreements for th ese p ro jects h ave origin al contract terms rang in g from one to 3 5 years.
Id aho Power's purch ased power expense associated with long -term agreements (including PURPA) was appro x imately $258 million in 2023 and $238 million in 202 2.

Id aho Power also has th e fo llo win g long -term commitments (in tho usands of dollars):
2024 2025 2026 202 7 20 28 Therea fter
Join t-o perating agreement payments(1) $ 2,834 $ 2 ,834 $ 2 ,834 $ 2,83 4 $ 2,8 3 4 $ 14,172
Easements an d other payments(1) 2,119 2 ,163 2 ,209 2,25 5 2,3 0 2 12,258
Mainten ance, service, and materials
agreements(1)(2 ) 321,776 29 ,042 11 ,273 1 3,38 6 3,4 5 0 41,118
FERC and oth er ind ustry -related fees(1) 18,514 17 ,020 1 6 ,830 1 6,78 0 15,9 4 9 83,032

(1) Approxim ately $28 million, $1 m illion, $20 million, an d $16 6 million of the comm itments included in join t-op erating agreement payments, easemen ts and other payments, maintenan ce, service, and materials
agreements, and FERC and other in dustry-related fees, respectively, have con tracts that do no t specify terms related to expiration . As these co ntracts are presumed to contin ue indefin itely, ten years of
in form ation , estimated b ased on current contract terms, h as been includ ed in th e table fo r presentation purposes.
(2) As o f Decem ber 31, 202 3, Idaho Power had a rem aining $115 million co mmitment related to fou r con tracts to acquire and own battery storag e assets with in-service dates through 2025 .

Id aho Power's expense fo r operating leases was not material for th e y ears ended 202 3 an d 20 2 2.

Acquisition of Additional Interest in Bo ardman-to-Heming way Transmission Project

In March 202 3, Idaho Power executed a p urch ase, sale, and security agreement with the BPA to tran sfer BPA's 24 percen t interest in the Boardman-to -Hemingway tran smission line
p roject to Idaho Power, bringing Idah o Power's interest in the project to ap p roximately 45 p ercent. Pursu ant to the agreement, Idah o Power has a co mmitment to prov ide lo ng-term
transmission serv ice to BPA. The ag reemen t also required BPA to mak e a $10 million secu rity payment to Id aho Power. On Idah o Po wer's balance sheet, the agreement increased
construction work in progress b y $31 .4 million for th e acqu ired p ermittin g interest, cash and cash equivalents by $10.0 millio n for the additional secu rity payment, and o ther n on-
curren t liab ilities by $4 1.4 million fo r Idah o Power's obligation to pay for the permitting interest and to retu rn the secu rity deposit to BPA. Payments to BPA for the permitting interest
are expected to be mad e ov er a 15-year p eriod beg in ning 1 0 years after energization of the tran smission line p roject, while the security depo sit is d ue to be returned to BPA upo n
energization.

Guarantees

Id aho Power g uarantees its portion o f reclamation activ ities an d obligations at BCC, o f wh ich IERCo owns a one-th ird interest. This gu aran tee, which is renewed annually with the
WDEQ, was $4 7.6 million at Decemb er 31 , 20 2 3, represen ting IERCo 's on e-third share o f BCC's total reclamation obligation o f $142.9 millio n. BCC h as a reclamation tru st fu nd set
aside specifically fo r the purpose of paying these reclamation costs. At December 31, 2023 , the valu e o f the reclamation trust fun d was $2 5 3.3 million. Du rin g 202 3, the reclamation
tru st fu nd made $6.0 millio n of d istribu tio ns for reclamation activity costs asso ciated with the BCC surface mine. BCC period ically assesses the adequacy o f the reclamation tru st fu nd
and its estimate of fu ture reclamatio n costs. To ensure th at the reclamation trust fund main tains adequ ate reserves, BCC h as the ability to, and d o es, add a per-ton surcharge to coal
sales, all of which are made to the Jim Bridger plant. Because of the ex istence of th e fu n d and the ab ility to apply a per-ton surcharg e, th e estimated fair value of th is guarantee is
minimal.

Id aho Power enters in to finan cial agreements and p o wer purchase an d sale agreements that include indemnification p rovisions relating to vario u s forms of claims or liab ilities that
may arise fro m th e transactio n s contemp lated by th ese agreements. Generally, a maximum oblig ation is n ot ex plicitly stated in the indemnification provisions and, th erefo re, th e
o verall maximu m amoun t of the oblig ation under su ch indemnification p ro visions cannot be reasonably estimated. Id aho Power p eriodically evaluates the lik elihoo d of in curring
costs under such indemnities b ased on their historical experience and the ev aluation o f the specific indemnities. As o f Decemb er 31 , 202 3, management believes the likelihood is
remo te that Idaho Po wer would b e required to perform under such indemnification p rovisions or o th erwise incur any significant lo sses with respect to such indemnification
o bligatio ns. Idaho Po wer has n ot recorded any liability on its balance sheets with respect to th ese in demnification ob ligation s.

9 . CONTINGENCIES

Id aho Power h as in th e past and ex p ect in the future to b eco me involved in vario u s claims, co ntroversies, disputes, and other con tingen t matters, some of which inv olve litigation and
regulatory or other con tested p roceedin g s. The ultimate reso lution and o utcome o f litigatio n an d reg ulatory proceed ings is inherently difficult to determin e, p articu larly where (a) the
remedies o r pen alties soug ht are indeterminate, (b) th e p ro ceeding s are in the early stages or the substan tiv e issues have not b een well develo ped, or (c) the matters involv e comp lex o r
n ovel legal theories or a large n umber of p arties. In acco rd ance with applicable acco unting g uidan ce, Idaho Po wer, as ap p licable, establishes an accrual for leg al pro ceeding s when
th ose matters p roceed to a stage where th ey presen t loss contin g encies that are both probable and reaso n ably estimable. If the loss contin gency at issue is not both p robab le and
reasonably estimab le, Id aho Power d oes no t estab lish an accrual and the matter will co n tinue to be mo nitored for an y develo pments that wou ld make the loss conting ency both
p robab le and reasonably estimab le. As of th e date of this rep ort, Idaho Power's accruals for lo ss conting encies are not material to their financial statements as a whole; however, future
accruals could be material in a g iven period . Idaho Po wer's determination is based on currently available in formatio n, and estimates presen ted in finan cial statements and o th er
fin ancial d isclosu res invo lve sign ifican t judgment and may be su bject to significant uncertainty. Fo r matters that affect Idaho Power's o perations, Idaho Power intends to seek, to the
extent permissib le and appropriate, recovery throug h the ratemak ing pro cess of costs incu rred, althou gh there is n o assuran ce that su ch recov ery wou ld be gran ted.

Id aho Power is p arty to legal claims and legal, tax, and regu latory actio ns and proceedings in th e ord inary course of bu siness and, as no ted abov e, record s an accrual for associated loss
conting encies when they are prob able and reaso nab ly estimable. In connection with its utility op eratio n s, Idah o Po wer is su bject to claims b y indiv iduals, entities, and governmental
agencies for damag es for alleged p ersonal injury, property damage, and economic lo sses, relatin g to th e comp any's provision of electric service and the op eratio n of its po wer supply,
related to nonvested share-based comp ensatio n . These costs are expected to b e recog nized over a weighted-averag e period o f 1.6 years. Orig inal issue sh ares o f IDACORP are used forthese awards. In 2023 , a total of 12,459 shares of IDACORP common stock were awarded to directors of IDACORP and Idah o Power at an average g rant d ate fair v alue of $1 03.48 per sh are. Directo rselected to defer receipt of 4 ,640 of these shares, which are bein g held as d eferred stock units with div idend eq u ivalents reinv ested in ad ditional sto ck u nits. Compensa tio n Expense: The following table sh ows Id aho Power's compen sation cost recognized in inco me and the tax b enefits resulting fro m the LTICP (in thousands of d o llars): 2023 202 2 Compen sation cost $ 9 ,508 $ 1 0,204 In come tax benefit 2 ,447 2,627 No equity compen sation costs hav e been capitalized. These costs are primarily reported with in "Oth er o p eratio ns and mainten ance" ex pen se on th e statements of income. 8 . COMMITMENTS Purchase Obligations At December 31, 2 023, Idah o Power had the fo llowin g long -term commitments relating to purchases o f energy, capacity, transmission rig hts, an d fuel (in thou sands of d ollars): 2024 2025 2 026 2 027 2 028 Therea fterCogeneration and power p ro ductio n(1) $ 324,738 $ 336,7 02 $ 3 58,113 $ 371,9 80 $ 3 45,7 4 0 $ 2 ,999,760Fuel 155,474 25,6 72 15,2 71 15,4 39 15,5 0 7 84,004 (1) As o f Decem ber 31, 202 3, Idaho Power had a $43 1 million comm itment related to an agreement to utilize the storage capacity of a 150 MW battery storage facility, ov er a 20-year term, sch ed uled to be o nlinein Jun e 2025. As of December 31, 2023, Idah o Power had power purch ase o bligatio n s with respect to 1 ,432 M W nameplate cap acity of on line PURPA and non-PURPA p ro jects, with an additio nal428 MW n ameplate capacity o f projects that are scheduled to b e on lin e th ro ugh 2 026. The agreements for th ese p ro jects h ave origin al contract terms rang in g from one to 3 5 years.Id aho Power's purch ased power expense associated with long -term agreements (including PURPA) was appro x imately $258 million in 2023 and $238 million in 202 2. Id aho Power also has th e fo llo win g long -term commitments (in tho usands of dollars): 2024 2025 2026 202 7 20 28 Therea fterJoint-o perating agreement payments(1) $ 2,834 $ 2 ,834 $ 2 ,834 $ 2,83 4 $ 2,8 3 4 $ 14,172Easements an d other payments(1) 2,119 2 ,163 2 ,209 2,25 5 2,3 0 2 12,258Maintenance, service, and materialsagreements(1)(2 ) 321,776 29 ,042 11 ,273 1 3,38 6 3,4 5 0 41,118FERC and oth er ind ustry -related fees(1) 18,514 17 ,020 1 6 ,830 1 6,78 0 15,9 4 9 83,032 (1) Approxim ately $28 million, $1 m illion, $20 million, an d $16 6 million of the comm itments included in join t-op erating agreement payments, easemen ts and other payments, maintenan ce, service, and materialsagreements, and FERC and other in dustry-related fees, respectively, have con tracts that do no t specify terms related to expiration . As these co ntracts are presumed to contin ue indefin itely, ten years ofinformation, estimated b ased on current contract terms, h as been includ ed in th e table fo r presentation purposes.(2) As o f Decem ber 31, 202 3, Idaho Power had a rem aining $115 million co mmitment related to fou r con tracts to acquire and own battery storag e assets with in-service dates through 2025 . Id aho Power's expense fo r operating leases was not material for th e y ears ended 202 3 an d 20 2 2. Acquisition of Additional Interest in Bo ardman-to-Heming way Transmission Project In March 202 3, Idaho Power executed a p urch ase, sale, and security agreement with the BPA to tran sfer BPA's 24 percen t interest in the Boardman-to -Hemingway tran smission lineproject to Idaho Power, bringing Idah o Power's interest in the project to ap p roximately 45 p ercent. Pursu ant to the agreement, Idah o Power has a co mmitment to prov ide lo ng-termtransmission serv ice to BPA. The ag reemen t also required BPA to mak e a $10 million secu rity payment to Id aho Power. On Idah o Po wer's balance sheet, the agreement increasedconstruction work in progress b y $31 .4 million for th e acqu ired p ermittin g interest, cash and cash equivalents by $10.0 millio n for the additional secu rity payment, and o ther n on-curren t liab ilities by $4 1.4 million fo r Idah o Power's obligation to pay for the permitting interest and to retu rn the secu rity deposit to BPA. Payments to BPA for the permitting interestare expected to be mad e ov er a 15-year p eriod beg in ning 1 0 years after energization of the tran smission line p roject, while the security depo sit is d ue to be returned to BPA upo nenergization. Guarantees Id aho Power g uarantees its portion o f reclamation activ ities an d obligations at BCC, o f wh ich IERCo owns a one-th ird interest. This gu aran tee, which is renewed annually with theWDEQ, was $4 7.6 million at Decemb er 31 , 20 2 3, represen ting IERCo 's on e-third share o f BCC's total reclamation obligation o f $142.9 millio n. BCC h as a reclamation tru st fu nd setaside specifically fo r the purpose of paying these reclamation costs. At December 31, 2023 , the valu e o f the reclamation trust fun d was $2 5 3.3 million. Du rin g 202 3, the reclamationtrust fu nd made $6.0 millio n of d istribu tio ns for reclamation activity costs asso ciated with the BCC surface mine. BCC period ically assesses the adequacy o f the reclamation tru st fu ndand its estimate of fu ture reclamatio n costs. To ensure th at the reclamation trust fund main tains adequ ate reserves, BCC h as the ability to, and d o es, add a per-ton surcharge to coalsales, all of which are made to the Jim Bridger plant. Because of the ex istence of th e fu n d and the ab ility to apply a per-ton surcharg e, th e estimated fair value of th is guarantee isminimal. Id aho Power enters in to finan cial agreements and p o wer purchase an d sale agreements that include indemnification p rovisions relating to vario u s forms of claims or liab ilities thatmay arise fro m th e transactio n s contemp lated by th ese agreements. Generally, a maximum oblig ation is n ot ex plicitly stated in the indemnification provisions and, th erefo re, th eoverall maximu m amoun t of the oblig ation under su ch indemnification p ro visions cannot be reasonably estimated. Id aho Power p eriodically evaluates the lik elihoo d of in curringcosts under such indemnities b ased on their historical experience and the ev aluation o f the specific indemnities. As o f Decemb er 31 , 202 3, management believes the likelihood isremote that Idaho Po wer would b e required to perform under such indemnification p rovisions or o th erwise incur any significant lo sses with respect to such indemnificationobligations. Idaho Po wer has n ot recorded any liability on its balance sheets with respect to th ese in demnification ob ligation s. 9 . CONTINGENCIES Id aho Power h as in th e past and ex p ect in the future to b eco me involved in vario u s claims, co ntroversies, disputes, and other con tingen t matters, some of which inv olve litigation andregulatory or other con tested p roceedin g s. The ultimate reso lution and o utcome o f litigatio n an d reg ulatory proceed ings is inherently difficult to determin e, p articu larly where (a) theremedies o r pen alties soug ht are indeterminate, (b) th e p ro ceeding s are in the early stages or the substan tiv e issues have not b een well develo ped, or (c) the matters involv e comp lex o rnovel legal theories or a large n umber of p arties. In acco rd ance with applicable acco unting g uidan ce, Idaho Po wer, as ap p licable, establishes an accrual for leg al pro ceeding s whenthose matters p roceed to a stage where th ey presen t loss contin g encies that are both probable and reaso n ably estimable. If the loss contin gency at issue is not both p robab le andreasonably estimab le, Id aho Power d oes no t estab lish an accrual and the matter will co n tinue to be mo nitored for an y develo pments that wou ld make the loss conting ency bothprobable and reasonably estimab le. As of th e date of this rep ort, Idaho Power's accruals for lo ss conting encies are not material to their financial statements as a whole; however, futureaccruals could be material in a g iven period . Idaho Po wer's determination is based on currently available in formatio n, and estimates presen ted in finan cial statements and o th er
fin ancial d isclosu res invo lve sign ifican t judgment and may be su bject to significant uncertainty. Fo r matters that affect Idaho Power's o perations, Idaho Power intends to seek, to the
extent permissib le and appropriate, recovery throug h the ratemak ing pro cess of costs incu rred, althou gh there is n o assuran ce that su ch recov ery wou ld be gran ted.

Id aho Power is p arty to legal claims and legal, tax, and regu latory actio ns and proceedings in th e ord inary course of bu siness and, as no ted abov e, record s an accrual for associated loss
conting encies when they are prob able and reaso nab ly estimable. In connection with its utility op eratio n s, Idah o Po wer is su bject to claims b y indiv iduals, entities, and governmental
agencies for damag es for alleged p ersonal injury, property damage, and economic lo sses, relatin g to th e comp any's provision of electric service and the op eratio n of its po wer supply,agencies for damag es for alleged p ersonal injury, property damage, and economic lo sses, relatin g to th e comp any's provision of electric service and the op eratio n of its po wer supply,
transmission, and d istribu tion facilities. Some of th o se claims relate to electrical contacts, serv ice quality, p roperty damage, and wildfires. In recen t years, utilities in the western
United States have been subject to sig nificant liab ility for perso nal in jury, loss of life, property damage, trespass, and eco n omic losses, and in so me cases, punitive damages and
criminal charges, associated with wild fires that originated fro m utility property, most co mmo nly transmissio n an d distribution lines. Id aho Power h as also regularly receiv ed claims by
g overn mental agen cies and p rivate lan downers for d amages for fires allegedly o rig inating from Idaho Power's transmission and d istribu tion system. As of the date of this report, Idah o
Power believes that resolution of ex istin g claims will not h ave a material adverse effect on its financial statemen ts.

Id aho Power is also actively mon ito ring various pending env iro nmental regulations an d executive orders related to environ men tal matters th at may have a sig nificant imp act on its
fu ture o perations. Given uncertainties reg arding the outco me, timin g, and comp liance plans for th ese environ men tal matters, Id aho Power is u nable to estimate the finan cial impact o f
th ese regulations.

1 0. BENEFIT PLANS

Id aho Power spo n so rs d efined benefit and other postretiremen t ben efit plans that cov er the majority o f its emp loyees. Idaho Power also sp o nsors a d efined co ntribution 401(k)
emp lo yee savin gs plan and provid es certain post-emp loyment benefits.

Pension Plans

Id aho Power h as a noncontributo ry defin ed benefit pensio n plan (pension plan) and two n onqualified defined benefit plans fo r certain senior management emp loyees, the SMSP. Idaho
Power also has a non qualified defined ben efit pension p lan fo r directors that was frozen in 2002. Remaining v ested ben efits from that p lan are in clud ed with th e SMSP in the
d isclosures below. Th e benefits u nder these plans are b ased on years of service an d the employee's final average earnings.

Th e follo wing table summarizes the ch anges in benefit obligatio ns and plan assets of th ese p lans (in thousan d s of dollars):
Pension Plan SMSP
2023 2022 2 023 2 022

Cha nge in projected benefit obliga tion:
Benefit o bligation at January 1 $ 9 5 3,76 9 $ 1,34 6,530 $ 99 ,976 $ 13 3 ,012
Service cost 2 9,84 3 5 2,025 612 1 ,185
In terest cost 5 1,27 7 3 9,670 5 ,322 3 ,897
Actuarial loss (gain) 4 1,53 9 (43 8,297 ) 6 ,518 (3 2 ,009 )
Plan amendment 11
Benefits paid (48,41 2) (4 6,159 ) (6 ,630) (6 ,109 )
Projected b enefit obligation at December 3 1 1,0 2 8,01 6 95 3,769 105 ,809 9 9 ,976
Cha nge in plan assets:
Fair value at January 1 8 3 9,72 8 98 4,464
Actual return o n plan assets 7 8,19 7 (13 8,577 )
Employer co ntributions 4 8,00 0 4 0,000
Benefits paid (48,41 2) (4 6,159 )
Fair value at December 31 9 1 7,51 3 83 9,728
Funded status at en d of y ear $ (110,50 3) $ (11 4,041 ) $ (105 ,809) $ (9 9 ,976 )

Amo unts recog nized in AOCI consist o f:
Net loss $ 1 0 8,33 4 $ 8 3,263 $ 21 ,074 $ 1 5 ,127
Prior service cost 3 1 37 2 ,200 2 ,408
Subtotal 1 0 8,36 5 8 3,300 23 ,274 1 7 ,535
Less amo unt recorded as regulatory asset(1) (1 08,36 5) (8 3,300 )
Net amount reco g nized in AOCI $ $ $ 23 ,274 $ 1 7 ,535
Accumulated benefit oblig a tion $ 8 9 2,32 5 $ 83 7,377 $ 99 ,786 $ 9 3 ,995

(1) Changes in the fun ded status o f th e pension plan that would b e recorded in AOCI fo r an unregulated entity are record ed as a regu latory asset for Id aho Power as Id ah o Power b elieves it is probable that an
amo un t equ al to the regulato ry asset will be collected th rough the setting of fu ture rates.

Th e actuarial lo sses reflected in the ben efit ob lig ations fo r the p ension and SMSP plan s in 2023 are due primarily to decreases in the assumed d iscount rates of both p lans from
December 31, 2022, to December 3 1, 2 023. Th e actuarial g ains reflected in the benefit oblig ations for th e p ension and SM SP plans in 2022 are due primarily to in creases in th e
assu med discou nt rates of bo th plan s from December 31, 2 021, to December 3 1, 20 22. For mo re in fo rmatio n on discoun t rates, see "Plan Assu mption s" below in this Note 10.

As a non-q u alified plan , the SMSP has no plan assets. Ho wever, Idaho Po wer has a Rab b i trust design ated to p ro vide funding for SMSP ob lig ations. Th e Rab bi trust ho ld s investments
in marketable securities and corp orate-own ed life insurance. The recorded value o f these investments was approx imately $1 46.2 million and $134.2 millio n at December 31, 2023 and
2 022, respectively.

Th e follo wing table shows the components of net periodic pen sion cost fo r these plan s (in thousan ds of do llars). Fo r purposes o f calculating th e expected return on p lan assets, the
mark et-related value of assets is equal to th e fair valu e o f the assets.
Pensio n Plan SMSP
2 023 2 022 2 0 21 20 23 2022 202 1
Service cost $ 29,8 43 $ 52,0 2 5 $ 54,20 2 $ 612 $ 1,1 85 $ 813
In terest cost 51,2 77 39,6 7 0 37,31 7 5,322 3,8 97 3,557
Ex pected return o n assets (61,7 28) (72,3 48) (64,0 9 0)
Amortizatio n of n et lo ss 12,2 7 3 23,79 6 570 4,2 29 4,205
Amortizatio n of p rior service cost 6 6 6 219 2 79 296
Net perio dic p ension cost 19,3 98 31,6 2 6 51,23 1 6,723 9,5 90 8,871
Regulato ry deferral of net perio dic p ension cost(1) (18,5 53) (30,1 97) (48,9 6 2)
Previou sly deferred pension cost recog n ized(1) 17,1 54 17,1 5 4 17,15 4
Net periodic pension cost recognized for financial reporting(1 ) $ 17,9 99 $ 18,5 8 3 $ 19,42 3 $ 6,723 $ 9,5 90 $ 8,871

(1) Net p eriodic pension co sts fo r the pensio n p lan are recogn ized for financial rep orting based u po n the auth orizatio n of each regulatory jurisdictio n in wh ich Id aho Power operates. Under an IPUC ord er, the
Idaho p ortion of n et perio dic p ension cost is recorded as a regulatory asset and is recognized in the incom e statement as those costs are reco vered throu gh rates.

agencies for damag es for alleged p ersonal injury, property damage, and economic lo sses, relatin g to th e comp any's provision of electric service and the op eratio n of its po wer supply,transmission, and d istribu tion facilities. Some of th o se claims relate to electrical contacts, serv ice quality, p roperty damage, and wildfires. In recen t years, utilities in the westernUnited States have been subject to sig nificant liab ility for perso nal in jury, loss of life, property damage, trespass, and eco n omic losses, and in so me cases, punitive damages andcriminal charges, associated with wild fires that originated fro m utility property, most co mmo nly transmissio n an d distribution lines. Id aho Power h as also regularly receiv ed claims bygovernmental agen cies and p rivate lan downers for d amages for fires allegedly o rig inating from Idaho Power's transmission and d istribu tion system. As of the date of this report, Idah oPower believes that resolution of ex istin g claims will not h ave a material adverse effect on its financial statemen ts. Id aho Power is also actively mon ito ring various pending env iro nmental regulations an d executive orders related to environ men tal matters th at may have a sig nificant imp act on itsfuture o perations. Given uncertainties reg arding the outco me, timin g, and comp liance plans for th ese environ men tal matters, Id aho Power is u nable to estimate the finan cial impact o fthese regulations. 1 0. BENEFIT PLANS Id aho Power spo n so rs d efined benefit and other postretiremen t ben efit plans that cov er the majority o f its emp loyees. Idaho Power also sp o nsors a d efined co ntribution 401(k)emp lo yee savin gs plan and provid es certain post-emp loyment benefits. Pension Plans Id aho Power h as a noncontributo ry defin ed benefit pensio n plan (pension plan) and two n onqualified defined benefit plans fo r certain senior management emp loyees, the SMSP. IdahoPower also has a non qualified defined ben efit pension p lan fo r directors that was frozen in 2002. Remaining v ested ben efits from that p lan are in clud ed with th e SMSP in thedisclosures below. Th e benefits u nder these plans are b ased on years of service an d the employee's final average earnings. Th e follo wing table summarizes the ch anges in benefit obligatio ns and plan assets of th ese p lans (in thousan d s of dollars): Pension Plan SMSP 2023 2022 2 023 2 022 Cha nge in projected benefit obliga tion: Benefit o bligation at January 1 $ 9 5 3,76 9 $ 1,34 6,530 $ 99 ,976 $ 13 3 ,012Service cost 2 9,84 3 5 2,025 612 1 ,185Interest cost 5 1,27 7 3 9,670 5 ,322 3 ,897Actuarial loss (gain) 4 1,53 9 (43 8,297 ) 6 ,518 (3 2 ,009 )Plan amendment 11 Benefits paid (48,41 2) (4 6,159 ) (6 ,630) (6 ,109 )Projected b enefit obligation at December 3 1 1,0 2 8,01 6 95 3,769 105 ,809 9 9 ,976Change in plan assets: Fair value at January 1 8 3 9,72 8 98 4,464 Actual return o n plan assets 7 8,19 7 (13 8,577 ) Employer co ntributions 4 8,00 0 4 0,000 Benefits paid (48,41 2) (4 6,159 ) Fair value at December 31 9 1 7,51 3 83 9,728 Funded status at en d of y ear $ (110,50 3) $ (11 4,041 ) $ (105 ,809) $ (9 9 ,976 ) Amo unts recog nized in AOCI consist o f: Net loss $ 1 0 8,33 4 $ 8 3,263 $ 21 ,074 $ 1 5 ,127Prior service cost 3 1 37 2 ,200 2 ,408Subtotal 1 0 8,36 5 8 3,300 23 ,274 1 7 ,535Less amo unt recorded as regulatory asset(1) (1 08,36 5) (8 3,300 ) Net amount reco g nized in AOCI $ $ $ 23 ,274 $ 1 7 ,535Accumulated benefit oblig a tion $ 8 9 2,32 5 $ 83 7,377 $ 99 ,786 $ 9 3 ,995 (1) Changes in the fun ded status o f th e pension plan that would b e recorded in AOCI fo r an unregulated entity are record ed as a regu latory asset for Id aho Power as Id ah o Power b elieves it is probable that anamount equ al to the regulato ry asset will be collected th rough the setting of fu ture rates. Th e actuarial lo sses reflected in the ben efit ob lig ations fo r the p ension and SMSP plan s in 2023 are due primarily to decreases in the assumed d iscount rates of both p lans fromDecember 31, 2022, to December 3 1, 2 023. Th e actuarial g ains reflected in the benefit oblig ations for th e p ension and SM SP plans in 2022 are due primarily to in creases in th eassumed discou nt rates of bo th plan s from December 31, 2 021, to December 3 1, 20 22. For mo re in fo rmatio n on discoun t rates, see "Plan Assu mption s" below in this Note 10. As a non-q u alified plan , the SMSP has no plan assets. Ho wever, Idaho Po wer has a Rab b i trust design ated to p ro vide funding for SMSP ob lig ations. Th e Rab bi trust ho ld s investmentsin marketable securities and corp orate-own ed life insurance. The recorded value o f these investments was approx imately $1 46.2 million and $134.2 millio n at December 31, 2023 and2022, respectively. Th e follo wing table shows the components of net periodic pen sion cost fo r these plan s (in thousan ds of do llars). Fo r purposes o f calculating th e expected return on p lan assets, themarket-related value of assets is equal to th e fair valu e o f the assets. Pensio n Plan SMSP 2 023 2 022 2 0 21 20 23 2022 202 1Service cost $ 29,8 43 $ 52,0 2 5 $ 54,20 2 $ 612 $ 1,1 85 $ 813Interest cost 51,2 77 39,6 7 0 37,31 7 5,322 3,8 97 3,557Expected return o n assets (61,7 28) (72,3 48) (64,0 9 0) Amortizatio n of n et lo ss 12,2 7 3 23,79 6 570 4,2 29 4,205Amortization of p rior service cost 6 6 6 219 2 79 296Net perio dic p ension cost 19,3 98 31,6 2 6 51,23 1 6,723 9,5 90 8,871Regulatory deferral of net perio dic p ension cost(1) (18,5 53) (30,1 97) (48,9 6 2) Previou sly deferred pension cost recog n ized(1) 17,1 54 17,1 5 4 17,15 4
Net periodic pension cost recognized for financial reporting(1 ) $ 17,9 99 $ 18,5 8 3 $ 19,42 3 $ 6,723 $ 9,5 90 $ 8,871

(1) Net p eriodic pension co sts fo r the pensio n p lan are recogn ized for financial rep orting based u po n the auth orizatio n of each regulatory jurisdictio n in wh ich Id aho Power operates. Under an IPUC ord er, the
Idaho p ortion of n et perio dic p ension cost is recorded as a regulatory asset and is recognized in the incom e statement as those costs are reco vered throu gh rates.

Th e follo wing table shows the components of oth er comp rehensiv e income (loss) for the plans (in tho usands of dollars):
Pension Plan SMSP
2023 20 2 2 2 023 2 022
Actuarial (loss) g ain during th e y ear $ (25 ,071) $ 227,3 72 $ (6,517 ) $ 32 ,009
Plan amen dment service cost (11 )
Reclassification adjustments for:
Amortization of net loss 12,2 73 570 4 ,229
Amortization of prio r service cost 6 6 219 279
Adju stment fo r deferred tax effects 6 ,452 (61,6 86) 1,477 (9 ,399)
Adju stment d ue to the effects of regulatio n 18 ,613 (177,9 65)
Other co mprehensive income (loss)
recog nized related to pension b enefit
p lans $ $ $ (4,262 ) $ 27,118

Th e follo wing table summarizes the ex pected fu ture b enefit pay ments of these plans (in tho u sands of dollars):
202 4 20 25 2 0 26 2 027 2028 2 0 29-203 3
Pension Plan $ 4 9,31 6 $ 50,73 6 $ 52,2 75 $ 53,7 77 $ 55,322 $ 303,171
SM SP 6,60 8 6,76 1 6,8 47 6,8 87 6,975 36,320

Id aho Power's funding policy for the pension plan is to contrib u te at least the minimum required und er the Emp loyee Retiremen t Inco me Security Act of 197 4 (ERISA) but no t more
th an th e maximum amo unt d eductible fo r inco me tax purposes. In 20 2 3 and 20 22, Id aho Power elected to co n tribute more than the minimum required amoun ts in order to b rin g the
p ension plan to a more fund ed p ositio n, to reduce fu ture required contribution s, and to reduce Pension Ben efit Guaranty Corp o ration premiums. As of th e date of this rep ort, Idaho
Power have no estimated min imum req uired contrib u tions to th e pension p lan fo r 2024. Depending on market co nditions and cash flow considerations in 2023, Idah o Power cou ld
contribu te up to $3 0 millio n to th e pension p lan d uring 2 0 24 in order to help balance th e regulato ry collectio n of th ese expenditures with the amo unt and timing of contrib u tions an d
to mitigate th e cost of being in an underfunded po sition .

Po stretirement Benefits

Id aho Power maintains a defined b enefit postretiremen t ben efit plan (consistin g of h ealth care and d eath benefits) that co v ers all emp loyees who were en rolled in the active-employ ee
g roup p lan at the time of retirement as well as th eir spou ses and qualify ing depen den ts. Retirees hired on or after January 1, 1999, hav e access to the stand ard medical o ption at full
cost, with n o co ntribution by Idaho Power. Benefits for emp loyees wh o retire after December 3 1, 2 0 02, are limited to a fixed amount, wh ich h as limited the growth o f Idah o Power's
fu ture o bligatio ns under this plan.

Th e follo wing table summarizes the ch anges in benefit obligatio n and plan assets (in thousan ds of do llars):
20 2 3 2022
Cha nge in accumulated benefit oblig ation:
Benefit o bligation at January 1 $ 5 9,099 $ 74,075
Service cost 658 1,071
In terest cost 2,980 2,112
Actuarial gain (2,004 ) (21,845)
Benefits paid(1) (4,669 ) (4,379)
Plan amendments 8,065
Benefit o bligation at December 31 5 6,064 59,099
Cha nge in plan assets:
Fair value of plan assets at Janu ary 1 2 8,565 41,464
Actual return o n plan assets 7,219 (6,586)
Employer co ntributions(1 ) 690 (1,934)
Benefits paid(1) (4,670 ) (4,379)
Fair value of plan assets at Decemb er 3 1 3 1,804 28,565
Funded status at en d of y ear (includ ed in non curren t liab ilities) $ (2 4,260 ) $ (30,534)

(1) Contribu tions and ben efits paid are each net of $2.6 million and $2.9 million of p lan p articipant contribu tio ns fo r 2023 and 20 22 , respectively.

Amounts recogn ized in AOCI consist of the following (in thou sands of d ollars):
2 0 23 20 22
Net gain $ (27 ,231) $ (20,896)
Prior service cost 6 ,184 7,849
Su b total (21 ,047) (13,047)
Less amo unt recogn ized in regulato ry assets 21 ,047 13,047
Net amount reco g nized in AOCI $ $

Th e n et periodic postretiremen t ben efit cost was as follo ws (in th ousand s of dollars):

20 23 20 22
Service cost $ 658 $ 1,071
In terest cost 2,980 2,112
Ex pected return o n plan assets (1 ,650) (2,351)
Amortizatio n of n et lo ss (1 ,237) (31)
Amortizatio n of p rior service cost 1,665 295
Net perio dic p ostretirement b enefit co st $ 2,416 $ 1,096

Th e follo wing table shows the components of oth er comp rehensiv e income for th e p lan (in thousan ds of do llars):
Th e follo wing table shows the components of oth er comp rehensiv e income (loss) for the plans (in tho usands of dollars): Pension Plan SMSP 2023 20 2 2 2 023 2 022 Actuarial (loss) g ain during th e y ear $ (25 ,071) $ 227,3 72 $ (6,517 ) $ 32 ,009 Plan amen dment service cost (11 ) Reclassification adjustments for: Amortization of net loss 12,2 73 570 4 ,229 Amortization of prio r service cost 6 6 219 279 Adju stment fo r deferred tax effects 6 ,452 (61,6 86) 1,477 (9 ,399) Adju stment d ue to the effects of regulatio n 18 ,613 (177,9 65) Other co mprehensive income (loss)recog nized related to pension b enefitplans $ $ $ (4,262 ) $ 27,118 Th e follo wing table summarizes the ex pected fu ture b enefit pay ments of these plans (in tho u sands of dollars): 202 4 20 25 2 0 26 2 027 2028 2 0 29-203 3Pension Plan $ 4 9,31 6 $ 50,73 6 $ 52,2 75 $ 53,7 77 $ 55,322 $ 303,171SMSP 6,60 8 6,76 1 6,8 47 6,8 87 6,975 36,320 Id aho Power's funding policy for the pension plan is to contrib u te at least the minimum required und er the Emp loyee Retiremen t Inco me Security Act of 197 4 (ERISA) but no t morethan th e maximum amo unt d eductible fo r inco me tax purposes. In 20 2 3 and 20 22, Id aho Power elected to co n tribute more than the minimum required amoun ts in order to b rin g thepension plan to a more fund ed p ositio n, to reduce fu ture required contribution s, and to reduce Pension Ben efit Guaranty Corp o ration premiums. As of th e date of this rep ort, IdahoPower have no estimated min imum req uired contrib u tions to th e pension p lan fo r 2024. Depending on market co nditions and cash flow considerations in 2023, Idah o Power cou ldcontribute up to $3 0 millio n to th e pension p lan d uring 2 0 24 in order to help balance th e regulato ry collectio n of th ese expenditures with the amo unt and timing of contrib u tions an dto mitigate th e cost of being in an underfunded po sition . Po stretirement Benefits Id aho Power maintains a defined b enefit postretiremen t ben efit plan (consistin g of h ealth care and d eath benefits) that co v ers all emp loyees who were en rolled in the active-employ eegroup p lan at the time of retirement as well as th eir spou ses and qualify ing depen den ts. Retirees hired on or after January 1, 1999, hav e access to the stand ard medical o ption at fullcost, with n o co ntribution by Idaho Power. Benefits for emp loyees wh o retire after December 3 1, 2 0 02, are limited to a fixed amount, wh ich h as limited the growth o f Idah o Power'sfuture o bligatio ns under this plan. Th e follo wing table summarizes the ch anges in benefit obligatio n and plan assets (in thousan ds of do llars): 20 2 3 2022Change in accumulated benefit oblig ation: Benefit o bligation at January 1 $ 5 9,099 $ 74,075Service cost 658 1,071Interest cost 2,980 2,112Actuarial gain (2,004 ) (21,845)Benefits paid(1) (4,669 ) (4,379)Plan amendments 8,065Benefit o bligation at December 31 5 6,064 59,099Change in plan assets: Fair value of plan assets at Janu ary 1 2 8,565 41,464Actual return o n plan assets 7,219 (6,586)Employer co ntributions(1 ) 690 (1,934)Benefits paid(1) (4,670 ) (4,379)Fair value of plan assets at Decemb er 3 1 3 1,804 28,565Funded status at en d of y ear (includ ed in non curren t liab ilities) $ (2 4,260 ) $ (30,534) (1) Contribu tions and ben efits paid are each net of $2.6 million and $2.9 million of p lan p articipant contribu tio ns fo r 2023 and 20 22 , respectively. Amounts recogn ized in AOCI consist of the following (in thou sands of d ollars): 2 0 23 20 22Net gain $ (27 ,231) $ (20,896)Prior service cost 6 ,184 7,849Subtotal (21 ,047) (13,047)Less amo unt recogn ized in regulato ry assets 21 ,047 13,047Net amount reco g nized in AOCI $ $ Th e n et periodic postretiremen t ben efit cost was as follo ws (in th ousand s of dollars): 20 23 20 22 Service cost $ 658 $ 1,071 In terest cost 2,980 2,112 Ex pected return o n plan assets (1 ,650) (2,351) Amortizatio n of n et lo ss (1 ,237) (31)
Amortizatio n of p rior service cost 1,665 295
Net perio dic p ostretirement b enefit co st $ 2,416 $ 1,096

Th e follo wing table shows the components of oth er comp rehensiv e income for th e p lan (in thousan ds of do llars):
202 3 2022
Actuarial gain during the year $ 7 ,572 $ 12,9 08
Prior service cost arising during th e y ear (8,0 65)
Reclassification adjustments for:
Amortization of net loss (1 ,237) (31)
Amo rtizatio n of p rior service cost 1 ,665 2 95
Adju stment fo r deferred tax effects (2 ,059) (1,3 15)
Adju stment d ue to the effects of regulatio n (5 ,941) (3,7 92)
Other co mprehensive income related to postretirement benefit p lans $ $

Th e follo wing table summarizes the ex pected fu ture b enefit pay ments of the postretirement benefit p lan (in thousan ds of do llars):
2024 2025 202 6 202 7 2 0 28 202 9 -2033
Ex pected b enefit payments $ 4,909 $ 4,734 $ 4 ,556 $ 4,38 6 $ 4,2 77 $ 19,98 8

Pla n Assumptions

Th e follo wing table sets forth the weighted -average assump tions used at th e end of each y ear to determin e b enefit obligations for all Idaho Po wer-sp onsored pen sion and
p ostretirement benefits plan s:
Pensio n Plan SMSP
Postretirement
Benefits
2023 2022 20 2 3 2 022 202 3 2 022
Discou nt rate 5.10 % 5.45 % 5 .20 % 5 .50 % 5 .15 % 5 .45 %
Rate of compen sation increase(1) 4.43 % 4.49 % 4 .75 % 4 .75 %
Medical tren d rate 7.1 % 6 .7 %
Dental trend rate 3.5 % 3 .5 %
Measuremen t date 12/31 /2 023 12/31 /2022 1 2/31/20 23 12/31/2 0 22 12/31/2 023 1 2/31/20 22

(1) The 20 23 rate of compen sation in crease assu mptio n for th e pension plan inclu des an inflation component of 2.40 % plu s a 2.03% comp osite merit increase component th at is b ased on emp loyees' years of
service. Merit salary increases are assumed to be 10 .6% fo r emp loyees in their first year of serv ice an d scale do wn to 3 .4% fo r emp loyees in their fo rtieth year of service and b eyon d.

Th e follo wing table sets forth the weighted -average assump tions used to determin e n et periodic ben efit cost for all Idah o Power-spo n so red p ension and postretiremen t ben efit plans:
Pensio n Plan SMSP
Postretirement
Benefits

2023 20 2 2 2023 2022 2 0 23 2022
Discou nt rate 5.45 % 3.0 5 % 5.50 % 3 .00 % 5.4 5 % 2.95 %
Ex pected lo ng-term rate of return
o n assets 7.40 % 7.4 0 % 6.0 0 % 6.00 %
Rate of compen sation increase 4.49 % 4.4 9 % 4.75 % 4 .75 % %
Medical tren d rate 6.7 % 5 .8 %
Dental trend rate 3.5 % 3 .5 %
Th e assumed health care cost trend rate used to measu re the expected cost of health benefits covered b y the postretiremen t plan was 6.7 percen t in 20 2 3 and is assumed to increase to
7 .1 p ercent in 2024, 6.5 percent in 202 5, decrease to 5.8 percen t in 202 6, and to grad ually decrease to 3 .8 percent by 2074. The assumed dental cost tren d rate used to measure the
expected co st of dental b enefits covered by th e plan was 3.5 percent, or equal to th e medical trend rate if lower, for all years.

Pla n Assets

Pension Asset Alloca tio n Policy: The targ et allocation and actual allo catio ns at December 31, 2023, for the pension asset portfolio b y asset class is set fo rth below:
Asset Class
Ta rget
Alloca tio n
Actual
Allocation
December 31 ,
2 023
Debt securities 2 5 % 2 4 %
Eq uity securities 5 6 % 6 0 %
Real estate 8 % 8 %
Other plan assets 11 % 8 %
Total 10 0 % 10 0 %

Assets are reb alan ced as n ecessary to keep the portfolio close to target allocations. Th e plan's p rincipal investmen t objective is to maximize total return (d efined as th e sum of realized
in terest and d ividen d income an d realized and un realized gain or loss in market price) consistent with p ru den t parameters of risk and th e liability pro file of th e p o rtfolio. Emphasis is
p laced o n preservatio n an d growth o f capital along with adequacy of cash flow sufficient to fu nd curren t and future pay men ts to plan participants.

Th e three majo r goals in Idah o Po wer's asset allocation process are to:

determine if the investmen ts h ave the potential to earn the rate of return assumed in the actuarial liab ility calculations;
match th e cash flow n eed s of the plan . Idaho Po wer sets debt security allocations sufficient to cover ap p roximately five y ears o f benefit p ayments. Id aho Power then u tilizes
growth in stru men ts (equities, real estate, v enture capital) to fund the longer-term liabilities o f the plan; and
maintain a pru dent risk profile consistent with ERISA fiduciary stan d ards.

Allowab le plan inv estments inclu d e stocks an d stock funds, in v estment-grad e b o nds an d bo n d fund s, real estate fund s, private infrastru cture funds, private direct lending funds,
p rivate eq uity fund s, and cash an d cash eq uivalents. With the exception of real estate h oldings, private infrastructure holding s, private direct lending loan s, and private equity,
in vestments mu st b e readily marketable so that an entire h olding can be disposed of quickly with o nly a min o r effect u pon market price.

Rate-of-retu rn projection s for plan assets are b ased o n historical risk/retu rn relationships among asset classes. The primary measu re is the historical risk premium each asset class has
d elivered versus the yield on th e Moo dy's AA Corporate Bon d Index. Th is h isto rical risk premium is th en added to th e curren t yield on th e Moo d y's AA Corporate Bond Index.
Add itio nal analysis is performed to measure th e expected ran ge o f return s, as well as wo rst-case and best-case scenario s. Based o n the cu rrent in terest rate environmen t, cu rrent rate-of-
return expectations are lower th an th e n o minal retu rn s generated ov er the past 30 years when interest rates were g enerally h igher.

202 3 2022 Actuarial gain during the year $ 7 ,572 $ 12,9 08 Prior service cost arising during th e y ear (8,0 65) Reclassification adjustments for: Amortization of net loss (1 ,237) (31) Amo rtizatio n of p rior service cost 1 ,665 2 95 Adju stment fo r deferred tax effects (2 ,059) (1,3 15) Adju stment d ue to the effects of regulatio n (5 ,941) (3,7 92) Other co mprehensive income related to postretirement benefit p lans $ $ Th e follo wing table summarizes the ex pected fu ture b enefit pay ments of the postretirement benefit p lan (in thousan ds of do llars): 2024 2025 202 6 202 7 2 0 28 202 9 -2033Expected b enefit payments $ 4,909 $ 4,734 $ 4 ,556 $ 4,38 6 $ 4,2 77 $ 19,98 8 Pla n Assumptions Th e follo wing table sets forth the weighted -average assump tions used at th e end of each y ear to determin e b enefit obligations for all Idaho Po wer-sp onsored pen sion andpostretirement benefits plan s: Pensio n Plan SMSP PostretirementBenefits 2023 2022 20 2 3 2 022 202 3 2 022Discount rate 5.10 % 5.45 % 5 .20 % 5 .50 % 5 .15 % 5 .45 %Rate of compen sation increase(1) 4.43 % 4.49 % 4 .75 % 4 .75 % Medical tren d rate 7.1 % 6 .7 %Dental trend rate 3.5 % 3 .5 %Measuremen t date 12/31 /2 023 12/31 /2022 1 2/31/20 23 12/31/2 0 22 12/31/2 023 1 2/31/20 22 (1) The 20 23 rate of compen sation in crease assu mptio n for th e pension plan inclu des an inflation component of 2.40 % plu s a 2.03% comp osite merit increase component th at is b ased on emp loyees' years ofservice. Merit salary increases are assumed to be 10 .6% fo r emp loyees in their first year of serv ice an d scale do wn to 3 .4% fo r emp loyees in their fo rtieth year of service and b eyon d. Th e follo wing table sets forth the weighted -average assump tions used to determin e n et periodic ben efit cost for all Idah o Power-spo n so red p ension and postretiremen t ben efit plans: Pensio n Plan SMSP PostretirementBenefits 2023 20 2 2 2023 2022 2 0 23 2022 Discou nt rate 5.45 % 3.0 5 % 5.50 % 3 .00 % 5.4 5 % 2.95 % Ex pected lo ng-term rate of returnon assets 7.40 % 7.4 0 % 6.0 0 % 6.00 % Rate of compen sation increase 4.49 % 4.4 9 % 4.75 % 4 .75 % % Medical tren d rate 6.7 % 5 .8 % Dental trend rate 3.5 % 3 .5 % Th e assumed health care cost trend rate used to measu re the expected cost of health benefits covered b y the postretiremen t plan was 6.7 percen t in 20 2 3 and is assumed to increase to7.1 p ercent in 2024, 6.5 percent in 202 5, decrease to 5.8 percen t in 202 6, and to grad ually decrease to 3 .8 percent by 2074. The assumed dental cost tren d rate used to measure theexpected co st of dental b enefits covered by th e plan was 3.5 percent, or equal to th e medical trend rate if lower, for all years. Pla n Assets Pension Asset Alloca tio n Policy: The targ et allocation and actual allo catio ns at December 31, 2023, for the pension asset portfolio b y asset class is set fo rth below:Asset Class Ta rgetAllocatio n ActualAllocationDecember 31 ,2 023Debt securities 2 5 % 2 4 %Eq uity securities 5 6 % 6 0 %Real estate 8 % 8 %Other plan assets 11 % 8 %Total 10 0 % 10 0 % Assets are reb alan ced as n ecessary to keep the portfolio close to target allocations. Th e plan's p rincipal investmen t objective is to maximize total return (d efined as th e sum of realizedinterest and d ividen d income an d realized and un realized gain or loss in market price) consistent with p ru den t parameters of risk and th e liability pro file of th e p o rtfolio. Emphasis isplaced o n preservatio n an d growth o f capital along with adequacy of cash flow sufficient to fu nd curren t and future pay men ts to plan participants. Th e three majo r goals in Idah o Po wer's asset allocation process are to: determine if the investmen ts h ave the potential to earn the rate of return assumed in the actuarial liab ility calculations; match th e cash flow n eed s of the plan . Idaho Po wer sets debt security allocations sufficient to cover ap p roximately five y ears o f benefit p ayments. Id aho Power then u tilizesgrowth in stru men ts (equities, real estate, v enture capital) to fund the longer-term liabilities o f the plan; and maintain a pru dent risk profile consistent with ERISA fiduciary stan d ards. Allowab le plan inv estments inclu d e stocks an d stock funds, in v estment-grad e b o nds an d bo n d fund s, real estate fund s, private infrastru cture funds, private direct lending funds,p rivate eq uity fund s, and cash an d cash eq uivalents. With the exception of real estate h oldings, private infrastructure holding s, private direct lending loan s, and private equity,in vestments mu st b e readily marketable so that an entire h olding can be disposed of quickly with o nly a min o r effect u pon market price.

Rate-of-retu rn projection s for plan assets are b ased o n historical risk/retu rn relationships among asset classes. The primary measu re is the historical risk premium each asset class has
d elivered versus the yield on th e Moo dy's AA Corporate Bon d Index. Th is h isto rical risk premium is th en added to th e curren t yield on th e Moo d y's AA Corporate Bond Index.
Add itio nal analysis is performed to measure th e expected ran ge o f return s, as well as wo rst-case and best-case scenario s. Based o n the cu rrent in terest rate environmen t, cu rrent rate-of-
return expectations are lower th an th e n o minal retu rn s generated ov er the past 30 years when interest rates were g enerally h igher.

Id aho Power's asset modelin g process also u tilizes h istorical market retu rns to measure the portfolio's ex p osure to a "worst-case" mark et scenario, to determine how much performance
could vary from th e expected "average" perfo rman ce over vario u s time period s. This "worst-case" mo deling , in addition to cash flow match ing and d iv ersification by asset class and
in vestment style, prov id es the basis for man aging the risk associated with in vesting portfolio assets.

Fair Va lue o f Plan Assets: Idah o Power classifies its pension p lan and p ostretirement b enefit plan investmen ts u sin g the three-level fair value hierarch y described in Note 15 - "Fair
Value Measu rements." The following table presen ts th e fair valu e o f the plans' investments b y asset category (in thousands of d o llars).
Lev el 1 Lev el 2 Lev el 3 To tal
Assets at December 31, 2023
Cash and cash equiv alen ts $ 2 8,830 $ $ $ 28,830
Intermediate bond s 3 5,747 182 ,280 218,027
Equity Securities: Large-Cap 9 3,879 93,879
Equity Securities: Mid-Cap 10 5,700 105,700
Equity Securities: Small-Cap 7 5,596 75,596
Equity Securities: Micro-Cap 3 7,759 37,759
Equity Securities: Global an d Internation al 5 8,401 58,401
Equity Securities: Emerging Markets 7,850 7,850
Pla n assets measured at NAV (no t subject to hiera rchy disclo sure)
Commingled Fun d: Equity Securities: Global an d Intern ational 131,921
Commingled Fun d: Equity Securities: Emerging M arkets 40,398
Direct Lend ing Fu nd: Fix ed In come 2,970
Real estate 74,426
Private mark et inv estments 41,756
To tal $ 44 3,762 $ 182 ,280 $ $ 917,513
Postretirement plan assets(1) $ 1,726 $ 30 ,078 $ $ 31,804

Lev el 1 Lev el 2 Lev el 3 To tal
Assets at December 31, 2022
Cash and cash equiv alen ts $ 11,679 $ $ $ 11,679
Intermediate bond s 3 3,305 166 ,530 199,835
Equity Securities: Large-Cap 8 5,617 85,617
Equity Securities: Mid-Cap 9 0,049 90,049
Equity Securities: Small-Cap 6 5,505 65,505
Equity Securities: Micro-Cap 3 3,438 33,438
Equity Securities: Global an d Internation al 5 2,876 52,876
Equity Securities: Emerging Markets 6,964 6,964
Pla n assets measured at NAV (no t subject to hiera rchy disclo sure)
Commingled Fun d: Equity Securities: Global an d Intern ational 117,631
Commingled Fun d: Equity Securities: Emerging M arkets 42,119
Real estate 83,676
Private mark et inv estments 50,339
To tal $ 37 9,433 $ 166 ,530 $ $ 839,728
Postretirement plan assets(1) $ 2,009 $ 26 ,556 $ $ 28,565

(1) The po stretirement benefits assets are p rimarily life insurance co ntracts.

For the years en ded December 31, 2023 and 2022 , there were no material transfers into or ou t of Lev els 1, 2, o r 3.

Fair Va lue Measurement o f Level 2 Plan assets and Plan a ssets mea sured at NAV:

Level 2 Bonds: These inv estments represent United States gov ernment, agency bond s, and corp orate bond s. The United States go vernmen t and agency bond s, as well as the corp orate
b onds, are n ot trad ed on an ex change an d are valued utilizing market p rices fo r similar assets or liab ilities in active markets.

Level 2 Po stretirement Asset: This asset represents an investment in a life insuran ce co n tract and is recorded at fair value, wh ich is th e cash surren der v alue, less any u npaid exp enses.
Th e cash surrender value of th is insu rance contract is contractually equ al to the in su rance contract's p roportionate share o f the market v alue of an associated investment accoun t held
b y the insurer. The investments h eld b y the insurer's investment account are all instruments traded on exch anges with readily d eterminab le market prices.

Comming led Funds: These fund s, made u p of g lobal, intern ational an d emerg ing markets equity secu rities are measured at NAV, are no t publicly traded, an d therefore no p ublicly
q uoted market price is readily available. The v alues of the co mmin gled funds are presented at estimated fair value, wh ich is d etermined based on the u nit value of the fund. The values
o f these investments are calculated by the custodian for th e fu nd company o n a mon thly or more frequ ent b asis, an d are based on market prices o f the assets held by each o f the
commingled fun d s divided by the n umb er of fu nd shares outstan ding fo r the respective fund. The in vestments in commingled fund s h ave red emp tion limitations that permit monthly
redemption following no tice requ irements of 5 to 7 d ays.

Direct Lending Funds: Direct len ding strategies are closed-end fu nds that provid e sen io r secu red lo ans primarily to private, non-inv estmen t-grade companies. Direct lending fund
in vestments are valued by th e fun d co mpanies, o r an indep end ent extern al advisor based o n the estimated fair value of the und erlying loans d ivided by th e fun d shares outstand ing.
Th ese d irect lend in g fund s also furnish annu al audited finan cial statements that are used to furth er validate the information provided. Th ese closed-end fu nds are formed with a stated
life of 6 to 10 years, which can be further ex tended with the approval of th e limited p artners. There are generally no redemptio n rights associated with these fund s. The limited partner
must hold the fund fo r the life of th e fu nd or fin d a third-party buy er.

Real Estate: Real estate hold in gs represent in v estments in op en-end and closed-end commingled real estate fun ds. As the p roperty interests h eld in these real estate fund s are not
frequently traded , estab lish in g the market value of th e p ro perty interests h eld b y the fund, and the resulting unit value of fund sh areh olders, is based on u nobservable inputs including
p roperty ap p raisals by the fund comp anies, property appraisals b y independen t app raisal firms, an alysis of the rep lacement cost of the property, discoun ted cash flo ws generated by
p roperty rents and chan ges in property values, and comparisons with sale prices of similar prop erties in similar markets. These real estate fun ds also furn ish ann ual audited financial
statements that are also u sed to further validate th e info rmatio n prov id ed. Redemption s o n the open-en d fund s are g enerally available on a qu arterly basis, with 10 to 35 days written
n otice, depen ding o n the individ ual fu nd. If th e fu nd has su fficien t liquidity, the red emp tion will be processed at the fund NAV o r the fund's estimate of fair value at th e end of the
q uarter. If th e fu nd do es not h ave sufficient liquid ity to h o nor the full redemption, the remainder will be set for redemption the fo llowin g quarter o n a pro-rata basis with o ther
redemption requ ests. This same process will repeat u ntil the red emp tio n req uest has been comp leted . To protect oth er fun d holders, real estate fu n ds hav e n o duty to liquid ate or
encumber fund s to meet redemption requests. The closed -end fu nds are formed fo r a stated life of 7 to 1 0 years. The fund can be further ex tended with the ap proval of the limited
Id aho Power's asset modelin g process also u tilizes h istorical market retu rns to measure the portfolio's ex p osure to a "worst-case" mark et scenario, to determine how much performancecould vary from th e expected "average" perfo rman ce over vario u s time period s. This "worst-case" mo deling , in addition to cash flow match ing and d iv ersification by asset class andinvestment style, prov id es the basis for man aging the risk associated with in vesting portfolio assets. Fair Va lue o f Plan Assets: Idah o Power classifies its pension p lan and p ostretirement b enefit plan investmen ts u sin g the three-level fair value hierarch y described in Note 15 - "FairValue Measu rements." The following table presen ts th e fair valu e o f the plans' investments b y asset category (in thousands of d o llars). Lev el 1 Lev el 2 Lev el 3 To talAssets at December 31, 2023 Cash and cash equiv alen ts $ 2 8,830 $ $ $ 28,830Intermediate bond s 3 5,747 182 ,280 218,027Equity Securities: Large-Cap 9 3,879 93,879Equity Securities: Mid-Cap 10 5,700 105,700Equity Securities: Small-Cap 7 5,596 75,596Equity Securities: Micro-Cap 3 7,759 37,759Equity Securities: Global an d Internation al 5 8,401 58,401Equity Securities: Emerging Markets 7,850 7,850Plan assets measured at NAV (no t subject to hiera rchy disclo sure) Commingled Fun d: Equity Securities: Global an d Intern ational 131,921Commingled Fun d: Equity Securities: Emerging M arkets 40,398Direct Lend ing Fu nd: Fix ed In come 2,970Real estate 74,426Private mark et inv estments 41,756Total $ 44 3,762 $ 182 ,280 $ $ 917,513Postretirement plan assets(1) $ 1,726 $ 30 ,078 $ $ 31,804 Lev el 1 Lev el 2 Lev el 3 To talAssets at December 31, 2022 Cash and cash equiv alen ts $ 11,679 $ $ $ 11,679Intermediate bond s 3 3,305 166 ,530 199,835Equity Securities: Large-Cap 8 5,617 85,617Equity Securities: Mid-Cap 9 0,049 90,049Equity Securities: Small-Cap 6 5,505 65,505Equity Securities: Micro-Cap 3 3,438 33,438Equity Securities: Global an d Internation al 5 2,876 52,876Equity Securities: Emerging Markets 6,964 6,964Plan assets measured at NAV (no t subject to hiera rchy disclo sure) Commingled Fun d: Equity Securities: Global an d Intern ational 117,631Commingled Fun d: Equity Securities: Emerging M arkets 42,119Real estate 83,676Private mark et inv estments 50,339Total $ 37 9,433 $ 166 ,530 $ $ 839,728Postretirement plan assets(1) $ 2,009 $ 26 ,556 $ $ 28,565 (1) The po stretirement benefits assets are p rimarily life insurance co ntracts. For the years en ded December 31, 2023 and 2022 , there were no material transfers into or ou t of Lev els 1, 2, o r 3. Fair Va lue Measurement o f Level 2 Plan assets and Plan a ssets mea sured at NAV: Level 2 Bonds: These inv estments represent United States gov ernment, agency bond s, and corp orate bond s. The United States go vernmen t and agency bond s, as well as the corp oratebonds, are n ot trad ed on an ex change an d are valued utilizing market p rices fo r similar assets or liab ilities in active markets. Level 2 Po stretirement Asset: This asset represents an investment in a life insuran ce co n tract and is recorded at fair value, wh ich is th e cash surren der v alue, less any u npaid exp enses.Th e cash surrender value of th is insu rance contract is contractually equ al to the in su rance contract's p roportionate share o f the market v alue of an associated investment accoun t heldby the insurer. The investments h eld b y the insurer's investment account are all instruments traded on exch anges with readily d eterminab le market prices. Comming led Funds: These fund s, made u p of g lobal, intern ational an d emerg ing markets equity secu rities are measured at NAV, are no t publicly traded, an d therefore no p ubliclyquoted market price is readily available. The v alues of the co mmin gled funds are presented at estimated fair value, wh ich is d etermined based on the u nit value of the fund. The valuesof these investments are calculated by the custodian for th e fu nd company o n a mon thly or more frequ ent b asis, an d are based on market prices o f the assets held by each o f thecommingled fun d s divided by the n umb er of fu nd shares outstan ding fo r the respective fund. The in vestments in commingled fund s h ave red emp tion limitations that permit monthlyredemption following no tice requ irements of 5 to 7 d ays. Direct Lending Funds: Direct len ding strategies are closed-end fu nds that provid e sen io r secu red lo ans primarily to private, non-inv estmen t-grade companies. Direct lending fundinvestments are valued by th e fun d co mpanies, o r an indep end ent extern al advisor based o n the estimated fair value of the und erlying loans d ivided by th e fun d shares outstand ing.Th ese d irect lend in g fund s also furnish annu al audited finan cial statements that are used to furth er validate the information provided. Th ese closed-end fu nds are formed with a statedlife of 6 to 10 years, which can be further ex tended with the approval of th e limited p artners. There are generally no redemptio n rights associated with these fund s. The limited partnermust hold the fund fo r the life of th e fu nd or fin d a third-party buy er. Real Estate: Real estate hold in gs represent in v estments in op en-end and closed-end commingled real estate fun ds. As the p roperty interests h eld in these real estate fund s are notfrequently traded , estab lish in g the market value of th e p ro perty interests h eld b y the fund, and the resulting unit value of fund sh areh olders, is based on u nobservable inputs includingproperty ap p raisals by the fund comp anies, property appraisals b y independen t app raisal firms, an alysis of the rep lacement cost of the property, discoun ted cash flo ws generated by
p roperty rents and chan ges in property values, and comparisons with sale prices of similar prop erties in similar markets. These real estate fun ds also furn ish ann ual audited financial
statements that are also u sed to further validate th e info rmatio n prov id ed. Redemption s o n the open-en d fund s are g enerally available on a qu arterly basis, with 10 to 35 days written
n otice, depen ding o n the individ ual fu nd. If th e fu nd has su fficien t liquidity, the red emp tion will be processed at the fund NAV o r the fund's estimate of fair value at th e end of the
q uarter. If th e fu nd do es not h ave sufficient liquid ity to h o nor the full redemption, the remainder will be set for redemption the fo llowin g quarter o n a pro-rata basis with o ther
redemption requ ests. This same process will repeat u ntil the red emp tio n req uest has been comp leted . To protect oth er fun d holders, real estate fu n ds hav e n o duty to liquid ate or
encumber fund s to meet redemption requests. The closed -end fu nds are formed fo r a stated life of 7 to 1 0 years. The fund can be further ex tended with the ap proval of the limitedencumber fund s to meet redemption requests. The closed -end fu nds are formed fo r a stated life of 7 to 1 0 years. The fund can be further ex tended with the ap proval of the limited
p artners. There are generally no redemp tio n rights associated with these fund s. The limited partn er must hold th e fu n d for th e life of the fund or find a th ird-party buyer.

Private Market Investmen ts: Private market investments rep resent two categories: ven tu re capital fund s and fu nd o f hed ge fu nds. These fund s are valued b y the fund companies based
o n the estimated fair v alues o f the underlying fu nd ho ldings divid ed b y the fund sh ares o utstanding or multiplied by th e ownersh ip percen tages of the holder. Ventu re capital fund
in vestments are valued by th e fun d co mpanies based o n estimated fair v alue of the un d erlying fund holding s d ivided by th e fu n d shares outstan d ing. Some venture cap ital
in vestments have p rogressed to the poin t that th ey h ave readily available exchan ge-b ased mark et valuatio ns. Early stage ven tu re in v estments are valu ed based on u nobserv able inputs
in cludin g co st, operating results, disco unted cash flows, the price of recent fund in g events, o r pending o ffers from other viab le entities. Th ese p riv ate market in vestments furnish
annu al audited finan cial statements that are also used to further valid ate the in formatio n pro v ided . These funds are fo rmed for a stated life o f 10 to 15 y ears. The g eneral p artner can
extend the fund life fo r 2 or 3 one-year periods. The fund can be further ex tended with the ap proval of the limited p artners. There are generally no redemption rights associated with
th ese fu nds. The limited partner must ho ld the fund fo r the life of the fu nd or find a third-party bu y er. The value of th e fu n d of h edg e fun ds investment is th e residu al v alue of an
immaterial non-liqu id position in a sin gle fu nd of hedg e fun ds.

Emplo yee Sav ings Plan

Id aho Power h as a defined contributio n plan desig ned to co mply with Section 4 0 1(k) of the In ternal Revenue Co de and th at covers sub stantially all emplo y ees. Idah o Power matches
specified percentages of employ ee con trib utions to th e p lan. Match in g annual con tributions were ap proximately $9.8 million and $8.8 million in 20 2 3 and 20 22, respectively.

Po st-employment Benefits

Id aho Power p rovides certain benefits to former or inactiv e employ ees, their b eneficiaries, an d covered dependen ts after emp loyment bu t befo re retirement, in ad d ition to the h ealth
care benefits required under the Co nsolidated Omn ib us Bu dget Reco n ciliatio n Act (COBRA). These benefits include salary co n tinuatio n, health care and life insuran ce for those
emp lo yees found to be disab led u n der Id aho Power's disability p lans, and h ealth care fo r surviving sp ouses an d depen dents. Idaho Power accrues a liab ility for such benefits. Th e po st-
emp lo yment benefits included in o ther liabilities o n Idaho Po wer's balance sheets at December 31 , 202 3 an d 202 2, were ap proximately $3 million and $2 millio n .

11. PROPERTY, PLANT AND EQUIPMENT AND JOINTLY-OWNED PROJECTS

Th e follo wing table presents the major classifications o f Idah o Power's utility p lant in service, annual depreciation provisions as a p ercent of average depreciable balance, and
accumu lated provision for depreciation for the years en ded December 31, 2023 and 2022 (in tho usands of dollars):
20 2 3 202 2
Ba lance Av g Rate Ba lance Avg Ra te
Production $ 2,794 ,534 3 .50 % $ 2 ,700,494 2 .89 %
Transmission 1,392 ,338 1 .90 % 1 ,346,463 1 .91 %
Distribution 2,454 ,458 2 .18 % 2 ,192,135 2 .15 %
General an d Other 662 ,375 5 .21 % 598, 570 5 .36 %
Total in service 7,303 ,705 2 .89 % 6 ,837,662 2 .66 %
Accumulated prov isio n for depreciatio n (2,733 ,470) (2 ,645,516)
In service - n et $ 4,570 ,235 $ 4 ,192,146

At December 31, 2 023, Idah o Power's co n stru ction work in pro g ress balance of $986.6 million inclu ded relicensing costs of $4 5 9.8 million fo r the HCC, Idaho Po wer's largest
h ydropo wer co mplex. In 2023 and 2022 , Idaho Po wer had IPUC auth o rizatio n to in clude in its Id aho jurisd iction rates $6 .5 million annually ($8.8 millio n when grossed-up for the
effect of in come taxes) of AFUDC relatin g to th e HCC relicensing p ro ject. Collecting these amou n ts will reduce th e amoun t co llected in th e fu tu re o nce the HCC relicensing costs are
appro v ed fo r recovery in b ase rates. At December 31, 2 023, Idaho Power's provision for rate refu nd for collection of AFUDC relating to the HCC was $22 8.7 million.

Id aho Power's own ership in terest in two jointly-owned generating facilities is in cluded in the table abo v e. Un d er th e join t operating agreements for these facilities, each p articip ating
u tility is respon sible for fin ancing its share of construction, o perating, and leasing costs. Idaho Power's pro portionate share o f operating expenses for each facility is in cluded in the
statements of in come. Th ese jo intly-owned facilities, including balance sheet amoun ts and th e exten t of Idaho Power's p articip ation, were as follows at December 31, 2023 (in
th ousand s o f dollars):
Na me o f Plant Location
Utility
Plant in
Service
Construction
Work in
Progress
Accumulated
Pro visio n for
Deprecia tion Ownership % MW(1)(2 )
Jim Brid ger u nits 1-4 Rock Sp rin gs, WY $ 770,1 79 $ 12,89 1 $ 500 ,685 3 3 77 5
North Valmy un it 2(2) Win nemucca, NV 262,5 44 2,23 7 225 ,147 5 0 14 5

(1) Id ah o Power's share of n ameplate capacity.
(2) Pursuan t to an agreemen t with NV Energy, Id aho Power's particip ation in coal-fired operatio ns of North Valmy end ed in Decem ber 2019 at u nit 1 an d is planned to end n o later than the end of 2025 at un it 2 .

IERCo, Id aho Power's who lly -owned su b sid iary, is a jo int-owner o f BCC. Idaho Power's coal purch ases from BCC were $67 .9 million in 2023 and $60.4 million in 20 22.

1 2. ASSET RETIREMENT OBLIGATIONS (ARO)

Th e g u idan ce relatin g to accounting for AROs requires th at legal o bligatio n s asso ciated with th e retirement o f property, p lant, and equ ipment be recognized as a liability at fair valu e
when incurred an d when a reasonable estimate of the fair value o f the liability can be made. Un der th e g u idan ce, wh en a liability is initially recorded, the en tity increases the carryin g
amo unt of th e related long -liv ed asset to reflect the future retiremen t cost. Over time, the liab ility is accreted to its estimated settlement v alue an d paid , and the capitalized cost is
d epreciated o ver th e u seful life of the related asset. If, at the end of the asset's life, the recorded liability differs from the actual o bligatio ns paid , a gain or loss would b e recogn ized. As
a rate-reg ulated en tity, Id aho Power d efers accretion , depreciation, an d gain s or losses as regulatory assets, as ap proved by the IPUC, u ntil such ARO co sts are in cluded in customer
rates for collection. The regu latory assets recorded under this order do not earn a return on investment.

Id aho Power's reco rded AROs relate to th e reclamatio n and removal co sts at its jointly-owned coal-fired generation facilities. In 202 3 , chang es in estimates at th e coal-fired generation
facilities resulted in a net increase o f $11 .3 million in the reco rd ed AROs. The increase is p rimarily related to cost estimates for a flue g as desu lfu rizatio n pon d placed in-service during
2 023 at the Jim Bridger plant.

Id aho Power also has additio n al AROs associated with its tran smission sy stem and g eneration facilities; however, due to the indetermin ate removal date, the fair v alue of th e
asso ciated liabilities cu rrently cannot b e estimated an d no amounts are recogn ized in the financial statemen ts.

Id aho Power also co llects remov al costs in rates for certain assets that do n o t have asso ciated AROs. Id aho Power is required to classify these removal costs as regulatory liabilities, see
Note 3 - "Reg ulatory M atters" for th e remov al costs reco rd ed as reg ulatory liabilities on Idaho Power's b alan ce sh eets as of December 3 1, 2 0 23 and 2 022.

Th e follo wing table presents the changes in the carrying amo unt of AROs (in thousands of d o llars):
2023 2022
Balance at beginning of year $ 37 ,557 $ 36,698
Accretio n ex pen se 1 ,176 1,106
Revisio ns in estimated cash flows 11 ,348 1,412
Liability settled (1 ,084) (1,659)
Balance at en d of y ear $ 48 ,997 $ 37,557

encumber fund s to meet redemption requests. The closed -end fu nds are formed fo r a stated life of 7 to 1 0 years. The fund can be further ex tended with the ap proval of the limitedpartners. There are generally no redemp tio n rights associated with these fund s. The limited partn er must hold th e fu n d for th e life of the fund or find a th ird-party buyer. Private Market Investmen ts: Private market investments rep resent two categories: ven tu re capital fund s and fu nd o f hed ge fu nds. These fund s are valued b y the fund companies basedon the estimated fair v alues o f the underlying fu nd ho ldings divid ed b y the fund sh ares o utstanding or multiplied by th e ownersh ip percen tages of the holder. Ventu re capital fundinvestments are valued by th e fun d co mpanies based o n estimated fair v alue of the un d erlying fund holding s d ivided by th e fu n d shares outstan d ing. Some venture cap italinvestments have p rogressed to the poin t that th ey h ave readily available exchan ge-b ased mark et valuatio ns. Early stage ven tu re in v estments are valu ed based on u nobserv able inputsincluding co st, operating results, disco unted cash flows, the price of recent fund in g events, o r pending o ffers from other viab le entities. Th ese p riv ate market in vestments furnishannual audited finan cial statements that are also used to further valid ate the in formatio n pro v ided . These funds are fo rmed for a stated life o f 10 to 15 y ears. The g eneral p artner canextend the fund life fo r 2 or 3 one-year periods. The fund can be further ex tended with the ap proval of the limited p artners. There are generally no redemption rights associated withthese fu nds. The limited partner must ho ld the fund fo r the life of the fu nd or find a third-party bu y er. The value of th e fu n d of h edg e fun ds investment is th e residu al v alue of animmaterial non-liqu id position in a sin gle fu nd of hedg e fun ds. Emplo yee Sav ings Plan Id aho Power h as a defined contributio n plan desig ned to co mply with Section 4 0 1(k) of the In ternal Revenue Co de and th at covers sub stantially all emplo y ees. Idah o Power matchesspecified percentages of employ ee con trib utions to th e p lan. Match in g annual con tributions were ap proximately $9.8 million and $8.8 million in 20 2 3 and 20 22, respectively. Po st-employment Benefits Id aho Power p rovides certain benefits to former or inactiv e employ ees, their b eneficiaries, an d covered dependen ts after emp loyment bu t befo re retirement, in ad d ition to the h ealthcare benefits required under the Co nsolidated Omn ib us Bu dget Reco n ciliatio n Act (COBRA). These benefits include salary co n tinuatio n, health care and life insuran ce for thoseemployees found to be disab led u n der Id aho Power's disability p lans, and h ealth care fo r surviving sp ouses an d depen dents. Idaho Power accrues a liab ility for such benefits. Th e po st-emp lo yment benefits included in o ther liabilities o n Idaho Po wer's balance sheets at December 31 , 202 3 an d 202 2, were ap proximately $3 million and $2 millio n . 11. PROPERTY, PLANT AND EQUIPMENT AND JOINTLY-OWNED PROJECTS Th e follo wing table presents the major classifications o f Idah o Power's utility p lant in service, annual depreciation provisions as a p ercent of average depreciable balance, andaccumulated provision for depreciation for the years en ded December 31, 2023 and 2022 (in tho usands of dollars): 20 2 3 202 2 Ba lance Av g Rate Ba lance Avg Ra teProduction $ 2,794 ,534 3 .50 % $ 2 ,700,494 2 .89 %Transmission 1,392 ,338 1 .90 % 1 ,346,463 1 .91 %Distribution 2,454 ,458 2 .18 % 2 ,192,135 2 .15 %General an d Other 662 ,375 5 .21 % 598, 570 5 .36 %Total in service 7,303 ,705 2 .89 % 6 ,837,662 2 .66 %Accumulated prov isio n for depreciatio n (2,733 ,470) (2 ,645,516) In service - n et $ 4,570 ,235 $ 4 ,192,146 At December 31, 2 023, Idah o Power's co n stru ction work in pro g ress balance of $986.6 million inclu ded relicensing costs of $4 5 9.8 million fo r the HCC, Idaho Po wer's largesthydropower co mplex. In 2023 and 2022 , Idaho Po wer had IPUC auth o rizatio n to in clude in its Id aho jurisd iction rates $6 .5 million annually ($8.8 millio n when grossed-up for theeffect of in come taxes) of AFUDC relatin g to th e HCC relicensing p ro ject. Collecting these amou n ts will reduce th e amoun t co llected in th e fu tu re o nce the HCC relicensing costs areapproved fo r recovery in b ase rates. At December 31, 2 023, Idaho Power's provision for rate refu nd for collection of AFUDC relating to the HCC was $22 8.7 million. Id aho Power's own ership in terest in two jointly-owned generating facilities is in cluded in the table abo v e. Un d er th e join t operating agreements for these facilities, each p articip atingutility is respon sible for fin ancing its share of construction, o perating, and leasing costs. Idaho Power's pro portionate share o f operating expenses for each facility is in cluded in thestatements of in come. Th ese jo intly-owned facilities, including balance sheet amoun ts and th e exten t of Idaho Power's p articip ation, were as follows at December 31, 2023 (inthousands o f dollars):Na me o f Plant Location UtilityPlant inService ConstructionWork inProgress AccumulatedProvision forDepreciation Ownership % MW(1)(2 )Jim Brid ger u nits 1-4 Rock Sp rin gs, WY $ 770,1 79 $ 12,89 1 $ 500 ,685 3 3 77 5North Valmy un it 2(2) Win nemucca, NV 262,5 44 2,23 7 225 ,147 5 0 14 5 (1) Id ah o Power's share of n ameplate capacity.(2) Pursuan t to an agreemen t with NV Energy, Id aho Power's particip ation in coal-fired operatio ns of North Valmy end ed in Decem ber 2019 at u nit 1 an d is planned to end n o later than the end of 2025 at un it 2 . IERCo, Id aho Power's who lly -owned su b sid iary, is a jo int-owner o f BCC. Idaho Power's coal purch ases from BCC were $67 .9 million in 2023 and $60.4 million in 20 22. 1 2. ASSET RETIREMENT OBLIGATIONS (ARO) Th e g u idan ce relatin g to accounting for AROs requires th at legal o bligatio n s asso ciated with th e retirement o f property, p lant, and equ ipment be recognized as a liability at fair valu ewhen incurred an d when a reasonable estimate of the fair value o f the liability can be made. Un der th e g u idan ce, wh en a liability is initially recorded, the en tity increases the carryin gamount of th e related long -liv ed asset to reflect the future retiremen t cost. Over time, the liab ility is accreted to its estimated settlement v alue an d paid , and the capitalized cost isdepreciated o ver th e u seful life of the related asset. If, at the end of the asset's life, the recorded liability differs from the actual o bligatio ns paid , a gain or loss would b e recogn ized. Asa rate-reg ulated en tity, Id aho Power d efers accretion , depreciation, an d gain s or losses as regulatory assets, as ap proved by the IPUC, u ntil such ARO co sts are in cluded in customerrates for collection. The regu latory assets recorded under this order do not earn a return on investment. Id aho Power's reco rded AROs relate to th e reclamatio n and removal co sts at its jointly-owned coal-fired generation facilities. In 202 3 , chang es in estimates at th e coal-fired generationfacilities resulted in a net increase o f $11 .3 million in the reco rd ed AROs. The increase is p rimarily related to cost estimates for a flue g as desu lfu rizatio n pon d placed in-service during2023 at the Jim Bridger plant. Id aho Power also has additio n al AROs associated with its tran smission sy stem and g eneration facilities; however, due to the indetermin ate removal date, the fair v alue of th eassociated liabilities cu rrently cannot b e estimated an d no amounts are recogn ized in the financial statemen ts. Id aho Power also co llects remov al costs in rates for certain assets that do n o t have asso ciated AROs. Id aho Power is required to classify these removal costs as regulatory liabilities, seeNote 3 - "Reg ulatory M atters" for th e remov al costs reco rd ed as reg ulatory liabilities on Idaho Power's b alan ce sh eets as of December 3 1, 2 0 23 and 2 022. Th e follo wing table presents the changes in the carrying amo unt of AROs (in thousands of d o llars): 2023 2022Balance at beginning of year $ 37 ,557 $ 36,698Accretion ex pen se 1 ,176 1,106
Revisio ns in estimated cash flows 11 ,348 1,412
Liability settled (1 ,084) (1,659)
Balance at en d of y ear $ 48 ,997 $ 37,557

1 3. INVESTMENTS

Th e table below summarizes Idaho Power's in v estments as of December 31 (in thousands of do llars):
2023 2022
Id aho Power in vestments:
IERCO $ 22 ,726 $ 14,692
Exchan ge traded short-term bon d funds and cash equiv alen ts 36 ,617 33,687
Held-to -Maturity securities 31 ,639 30,475
Executiv e deferred co mpensation plan investments 703 442
Total Idaho Power in vestments $ 91 ,685 $ 79,296

Inv estments in Equity Securities

In vestments in equity securities are repo rted at fair v alue. Any u nrealized gains or losses on equ ity securities are included in in come. Unrealized g ains and losses on equ ity securities
were immaterial at December 3 1, 2 0 23 and 2 022. Th e fo llo win g tab le summarizes sales of eq uity securities (in thousan ds of do llars):
2 023 2 022 2021
Proceeds from sales $ 8,9 21 $ 63,8 57 $ 11,328
Gross realized gains from sales

Held-to -Ma turity Securities

Id aho Power h as a rabb i trust designated to prov ide fu nding for oblig ations related to the SMSP. Durin g 202 3 an d 202 2, the rab bi trust pu rchased $1 .6 millio n and $3 1.2 million,
respectively of held-to-maturity in v estments in corporate fixed-income an d asset-back ed d ebt securities. Substan tially all of th ese d ebt securities mature between 2027 and 2037 .
Held-to-maturity inv estments are carried at amortized cost, reflectin g Idaho Po wer's ability an d intent to h old the securities to matu rity. Held -to-maturity investmen ts are adjusted for
th e amortization or accretion o f premiums o r discou n ts, wh ich are amo rtized or accreted over the life o f the related held-to-maturity security. Su ch amortization and accretion are
in cluded in the "Other inco me, net" lin e in the statements of in come. Due to in creases in market interest rates in 20 2 3 and 20 22, all held-to-maturity securities were in a gro ss
u nrealized hold in g loss position to taling $3.3 million and $5.0 million at December 31, 2 023 and December 31, 2022, respectively. Based on ongo ing credit evalu ations o f these
h oldings, Id aho Power d oes no t ex p ect material pay men t defaults or delinquencies an d has n ot recorded an allo wance for cred it losses for these securities as o f December 31 , 202 3 an d
2 022.

1 4. DERIVATIVE FINANCIAL INSTRUMENTS

Commodity Price Risk

Id aho Power is exposed to market risk relating to electricity, n atural gas, and other fuel commodity prices, all o f which are heavily in flu enced by supply an d deman d. Market risk may
b e in flu enced by market participan ts' no n performan ce of their con tractu al ob ligation s and commitments, which affects the supply of or d emand fo r the commod ity. Id aho Power u ses
d erivative in stru men ts, su ch as physical and financial forward con tracts, for both electricity and fuel to manag e th e risks relating to these commod ity price exposures. The primary
o bjectives of Idaho Power's energy p urchase and sale activity are to meet th e d emand o f retail electric customers, maintain appropriate p hysical reserves to ensure reliability, and make
eco nomic use of temporary surpluses th at may d evelop.

All o f Idah o Power's deriv ative instruments hav e b een en tered into fo r the p urpose of securing energ y resou rces fo r future perio d s or econo mically hedging forecasted purchases and
sales, tho ugh n one of these instruments have b een desig nated as cash flo w h edg es. Idaho Power offsets fair valu e amou nts recognized o n its balance sheet and applies collateral related
to deriv ative instruments ex ecu ted with th e same coun terparty und er the same master n etting agreement. Idah o Power does n ot offset a counterparty's current derivativ e contracts with
th e counterparty 's long -term d erivative contracts, althoug h Idah o Po wer's master netting arrang ements would allow cu rrent and lo ng-term positions to be offset in th e even t of default.
Also, in the event of default, Idaho Power's master netting arrangements would allow for the o ffsetting o f all transactio ns execu ted u n der th e master netting arrangement. These types
o f transactions may includ e no n-deriv ative instruments, derivatives qualify ing for scope ex cep tions, receiv ables and pay ables arising from settled positions, and o ther fo rms of n on-
cash collateral (such as letters o f credit). These typ es of transactio ns are ex cluded from the offsetting presen ted in the derivative fair value and offsetting table that follows.

Th e table below presents the gains and losses on d erivativ es no t designated as hedging instru ments for the years en d ed December 31, 2023 and 2022 (in thou sands of d ollars):
Location of Realized Gain/(Loss) on
Derivatives Recog nized in Income

Gain/(Loss) o n Derivatives Recog nized in
Income(1)
2023 2 0 22
Financial swap s Operating revenu es $ 4 ,216 $ (6,249)
Financial swap s Purchased po wer (8,542 ) 2,373
Financial swap s Fuel expense (1 6,209 ) 68,489
Forward contracts Operating revenu es 2 ,280 1,090
Forward contracts Purchased po wer (4,035 ) (2,994)
Forward contracts Fuel expense (866 ) (136)

(1) Excludes un realized gains or losses on deriv atives, which are recorded on th e balance sheet as regulatory assets or regu latory liab ilities.

Settlemen t gain s and lo sses o n electricity swap contracts are recorded on the income statement in operating revenues o r purchased power d epending on th e forecasted po sition bein g
eco nomically hedg ed b y the derivative co ntract. Settlement g ains and losses on con tracts fo r natu ral gas are reflected in fuel ex pen se. Settlement g ains and losses on diesel deriv atives
are reco rded in other O&M expense. See No te 15 - "Fair Value Measurements" for additional information con cern ing the determin ation of fair value for Id aho Power's assets and
liabilities from price risk managemen t activities.

Credit Risk

At December 31, 2 023, Idah o Power did no t hav e material credit risk expo sure from finan cial instru ments, inclu ding d erivatives. Id aho Power monitors credit risk exposure throu gh
reviews of coun terparty credit qu ality, corp orate-wide counterparty cred it exp osu re, and corpo rate-wide co unterp arty concentration levels. Id aho Power manages th ese risks by
establishing credit an d co ncentration limits on transactions with counterparties and requirin g co ntractual g uarantees, cash deposits, or letters of credit fro m counterparties or their
affiliates, as deemed necessary. Idah o Po wer's phy sical p ower co ntracts are common ly und er WSPP, Inc. agreements, p hysical gas contracts are usually und er North American Energy
Stand ards Board con tracts, and financial transactions are usually und er Internation al Swaps and Derivativ es Association , Inc. co ntracts. These con tracts ty pically co ntain adequate
assu rance clauses requiring collateralizatio n if a co u nterp arty h as deb t that is downgrad ed below inv estment grade b y at least o ne rating agency.

Credit-Conting ent Features

Certain o f Idah o Power's deriv ative instruments co ntain provisions that req u ire Idaho Power's u nsecu red d ebt to maintain an investment g rade credit ratin g from M oody's an d Standard
& Po o r's Rating s Services. If Id aho Power's unsecured deb t were to fall b elow inv estmen t grad e, it wo uld be in v iolation of these pro v isio ns, an d the cou nterparties to th e d erivative
in stru men ts could requ est immediate p ayment o r deman d immediate and ongoin g full ov ernigh t collateralizatio n on derivative instru ments in net liability positions. The aggreg ate
fair value of all derivative instru men ts with cred it-risk-related co ntingent features th at were in a liab ility position at December 3 1, 2 0 23, was $63.9 million . Idaho Po wer posted $53.3
million cash collateral related to th is amo unt. If the cred it-risk-related co ntingent features u n derly in g these ag reemen ts were trigg ered on December 31, 2023, Idah o Power wo uld have
b een req uired to pay or p ost collateral to its co unterp arties u p to an additional $14 .2 million to cover open liability po sition s as well as completed tran saction s th at h ave not y et been
p aid.

Derivativ e Instrument Summary

1 3. INVESTMENTS Th e table below summarizes Idaho Power's in v estments as of December 31 (in thousands of do llars): 2023 2022Idaho Power in vestments: IERCO $ 22 ,726 $ 14,692Exchange traded short-term bon d funds and cash equiv alen ts 36 ,617 33,687Held-to -Maturity securities 31 ,639 30,475Executive deferred co mpensation plan investments 703 442Total Idaho Power in vestments $ 91 ,685 $ 79,296 Inv estments in Equity Securities In vestments in equity securities are repo rted at fair v alue. Any u nrealized gains or losses on equ ity securities are included in in come. Unrealized g ains and losses on equ ity securitieswere immaterial at December 3 1, 2 0 23 and 2 022. Th e fo llo win g tab le summarizes sales of eq uity securities (in thousan ds of do llars): 2 023 2 022 2021Proceeds from sales $ 8,9 21 $ 63,8 57 $ 11,328Gross realized gains from sales Held-to -Ma turity Securities Id aho Power h as a rabb i trust designated to prov ide fu nding for oblig ations related to the SMSP. Durin g 202 3 an d 202 2, the rab bi trust pu rchased $1 .6 millio n and $3 1.2 million,respectively of held-to-maturity in v estments in corporate fixed-income an d asset-back ed d ebt securities. Substan tially all of th ese d ebt securities mature between 2027 and 2037 .Held-to-maturity inv estments are carried at amortized cost, reflectin g Idaho Po wer's ability an d intent to h old the securities to matu rity. Held -to-maturity investmen ts are adjusted forthe amortization or accretion o f premiums o r discou n ts, wh ich are amo rtized or accreted over the life o f the related held-to-maturity security. Su ch amortization and accretion areincluded in the "Other inco me, net" lin e in the statements of in come. Due to in creases in market interest rates in 20 2 3 and 20 22, all held-to-maturity securities were in a gro ssunrealized hold in g loss position to taling $3.3 million and $5.0 million at December 31, 2 023 and December 31, 2022, respectively. Based on ongo ing credit evalu ations o f theseholdings, Id aho Power d oes no t ex p ect material pay men t defaults or delinquencies an d has n ot recorded an allo wance for cred it losses for these securities as o f December 31 , 202 3 an d2022. 1 4. DERIVATIVE FINANCIAL INSTRUMENTS Commodity Price Risk Id aho Power is exposed to market risk relating to electricity, n atural gas, and other fuel commodity prices, all o f which are heavily in flu enced by supply an d deman d. Market risk maybe in flu enced by market participan ts' no n performan ce of their con tractu al ob ligation s and commitments, which affects the supply of or d emand fo r the commod ity. Id aho Power u sesderivative in stru men ts, su ch as physical and financial forward con tracts, for both electricity and fuel to manag e th e risks relating to these commod ity price exposures. The primaryobjectives of Idaho Power's energy p urchase and sale activity are to meet th e d emand o f retail electric customers, maintain appropriate p hysical reserves to ensure reliability, and makeeconomic use of temporary surpluses th at may d evelop. All o f Idah o Power's deriv ative instruments hav e b een en tered into fo r the p urpose of securing energ y resou rces fo r future perio d s or econo mically hedging forecasted purchases andsales, tho ugh n one of these instruments have b een desig nated as cash flo w h edg es. Idaho Power offsets fair valu e amou nts recognized o n its balance sheet and applies collateral relatedto deriv ative instruments ex ecu ted with th e same coun terparty und er the same master n etting agreement. Idah o Power does n ot offset a counterparty's current derivativ e contracts withthe counterparty 's long -term d erivative contracts, althoug h Idah o Po wer's master netting arrang ements would allow cu rrent and lo ng-term positions to be offset in th e even t of default.Also, in the event of default, Idaho Power's master netting arrangements would allow for the o ffsetting o f all transactio ns execu ted u n der th e master netting arrangement. These typesof transactions may includ e no n-deriv ative instruments, derivatives qualify ing for scope ex cep tions, receiv ables and pay ables arising from settled positions, and o ther fo rms of n on-cash collateral (such as letters o f credit). These typ es of transactio ns are ex cluded from the offsetting presen ted in the derivative fair value and offsetting table that follows. Th e table below presents the gains and losses on d erivativ es no t designated as hedging instru ments for the years en d ed December 31, 2023 and 2022 (in thou sands of d ollars): Location of Realized Gain/(Loss) onDerivatives Recog nized in Income Gain/(Loss) o n Derivatives Recog nized inIncome(1) 2023 2 0 22 Financial swap s Operating revenu es $ 4 ,216 $ (6,249) Financial swap s Purchased po wer (8,542 ) 2,373 Financial swap s Fuel expense (1 6,209 ) 68,489 Forward contracts Operating revenu es 2 ,280 1,090 Forward contracts Purchased po wer (4,035 ) (2,994) Forward contracts Fuel expense (866 ) (136) (1) Excludes un realized gains or losses on deriv atives, which are recorded on th e balance sheet as regulatory assets or regu latory liab ilities. Settlemen t gain s and lo sses o n electricity swap contracts are recorded on the income statement in operating revenues o r purchased power d epending on th e forecasted po sition bein geconomically hedg ed b y the derivative co ntract. Settlement g ains and losses on con tracts fo r natu ral gas are reflected in fuel ex pen se. Settlement g ains and losses on diesel deriv ativesare reco rded in other O&M expense. See No te 15 - "Fair Value Measurements" for additional information con cern ing the determin ation of fair value for Id aho Power's assets andliabilities from price risk managemen t activities. Credit Risk At December 31, 2 023, Idah o Power did no t hav e material credit risk expo sure from finan cial instru ments, inclu ding d erivatives. Id aho Power monitors credit risk exposure throu ghreviews of coun terparty credit qu ality, corp orate-wide counterparty cred it exp osu re, and corpo rate-wide co unterp arty concentration levels. Id aho Power manages th ese risks byestablishing credit an d co ncentration limits on transactions with counterparties and requirin g co ntractual g uarantees, cash deposits, or letters of credit fro m counterparties or theiraffiliates, as deemed necessary. Idah o Po wer's phy sical p ower co ntracts are common ly und er WSPP, Inc. agreements, p hysical gas contracts are usually und er North American EnergyStandards Board con tracts, and financial transactions are usually und er Internation al Swaps and Derivativ es Association , Inc. co ntracts. These con tracts ty pically co ntain adequateassurance clauses requiring collateralizatio n if a co u nterp arty h as deb t that is downgrad ed below inv estment grade b y at least o ne rating agency. Credit-Conting ent Features Certain o f Idah o Power's deriv ative instruments co ntain provisions that req u ire Idaho Power's u nsecu red d ebt to maintain an investment g rade credit ratin g from M oody's an d Standard& Po o r's Rating s Services. If Id aho Power's unsecured deb t were to fall b elow inv estmen t grad e, it wo uld be in v iolation of these pro v isio ns, an d the cou nterparties to th e d erivativeinstruments could requ est immediate p ayment o r deman d immediate and ongoin g full ov ernigh t collateralizatio n on derivative instru ments in net liability positions. The aggreg ate
fair value of all derivative instru men ts with cred it-risk-related co ntingent features th at were in a liab ility position at December 3 1, 2 0 23, was $63.9 million . Idaho Po wer posted $53.3
million cash collateral related to th is amo unt. If the cred it-risk-related co ntingent features u n derly in g these ag reemen ts were trigg ered on December 31, 2023, Idah o Power wo uld have
b een req uired to pay or p ost collateral to its co unterp arties u p to an additional $14 .2 million to cover open liability po sition s as well as completed tran saction s th at h ave not y et been
p aid.

Derivativ e Instrument Summary

Th e table below presents the fair values and locations of d erivative in stru men ts n ot desig nated as h edg in g instruments recorded on the balance sheets and reconciles the gross
amo unts of derivativ es recognized as assets and as liabilities to the net amo unts presented in the balance sheets at December 31, 202 3 an d 202 2 (in tho usands o f dollars):
Asset Deriva tiv es Liability Deriva tives

Ba la nce Sheet
Loca tio n
Gross
Fair
Value
Amo unts
Offset
Net
Assets
Gross
Fair
Value
Amo unts
Offset
Net
Liabilities
December 31,
2 023
Current:
Finan cial swap s Other cu rrent assets $ 241 $ (169) $ 7 2 $ 169 $ (169) $
Finan cial swap s
Other cu rrent
liabilities 1 ,476 (1,476) 41 ,977 (38 ,045)
(1)
3,93 2
Forward
contracts
Other cu rrent
liabilities 2 ,000 2,00 0
Lo ng-term:
Finan cial swap s Other assets 106 (89) 1 7 89 (89)
Finan cial swap s Other liab ilities 376 (376) 2 ,123 (2 ,123)(2)
Total $ 2 ,199 $ (2,110) $ 8 9 $ 46 ,358 $ (40 ,426) $ 5,93 2

December 31,
2 022
Current:
Finan cial swap s Other cu rrent assets $ 72 ,548 $ (32,609)(3)$ 39,93 9 $ 13 ,982 $ (13 ,982) $
Finan cial swap s
Other cu rrent
liabilities 132 (132) 1 ,577 (132) 1,44 5
Forward
contracts Other cu rrent assets 400 40 0
Forward
contracts
Other cu rrent
liabilities 2 ,071 2,07 1
Lo ng-term:
Finan cial swap s Other assets 622 (43) 57 9 43 (43)
Finan cial swap s Other liab ilities 644 (644) 2 ,136 (644) 1,49 2
Forward
contracts Other liab ilities
1 ,780

1,78 0
Total $ 74 ,346 $ (33,428) $ 40,91 8 $ 21 ,589 $ (14 ,801) $ 6,78 8

(1) Current liability derivative amo un ts offset inclu de $36.6 million of collateral receivable at December 31, 20 23.
(2) Long -term liability derivative amoun ts o ffset inclu de $1.7 m illion of collateral receivab le at Decem ber 31, 202 3.
(3) Current asset d erivativ e amounts offset includ e $18.6 million of collateral payable at December 31 , 2 022.

Th e table below presents the volu mes o f deriv ative commod ity forward contracts and swaps ou tstanding at December 31, 2 023 and 2 022 (in thousands of un its):
December 31,
Co mmodity Units 2 023 2 022
Electricity purchases MWh 440 898
Electricity sales MWh 57 32
Natural g as purchases MM Btu 24 ,593 2 6 ,773
Natural g as sales MM Btu 310

1 5. FAIR VALUE MEASUREMENTS

Id aho Power h as categ o rized their finan cial instru men ts in to a three-level fair value hierarchy, based on th e p rio rity of th e inp uts to the valu ation technique. The fair value hierarch y
g ives the high est priority to quo ted p rices in active mark ets for identical assets o r liabilities (Level 1) an d the lowest prio rity to un observable inputs (Lev el 3). If the inputs used to
measu re th e financial instruments fall within different levels of th e h ierarchy, the categorization is based on th e lo west level input that is significant to the fair v alue measuremen t of
th e in strument.

Finan cial assets and liabilities reco rded on th e balance sh eets are categorized b ased on the inpu ts to the valu ation tech niques as follows:

Level 1 : Financial assets and liabilities whose v alues are based on unad justed q uoted prices for identical assets or liabilities in an activ e market that Idah o Power has th e ability to
access.

Level 2 : Financial assets and liabilities whose v alues are based on the fo llowin g:
a) quoted prices for similar assets or liabilities in active mark ets;
b) q u oted prices for identical or similar assets or liabilities in non-active markets;
c) pricing mod els whose in p uts are observ able for substan tially th e full term of the asset o r liability; and
d) p ricing models wh o se inpu ts are derived prin cipally from or corroborated by ob servab le market data thro u gh correlation o r other means for sub stantially the fu ll term
of the asset or liab ility.

Idaho Po wer Lev el 2 inputs for d erivative in stru men ts are based on q uoted market p rices adjusted for location using corroborated , observ able market data or using quoted
price which may b e in non-active markets.

Level 3 : Financial assets and liabilities whose v alues are based on prices or valuation techniques that require inpu ts th at are b oth un observable and sign ifican t to the overall fair
value measurement. These inputs reflect man agement's own assu mption s about the assu mption s a market participan t wo uld use in pricing th e asset or liab ility.

Id aho Power's assessment of a particular in put's sign ifican ce to the fair v alue measuremen t requ ires judg men t and may affect the v aluation of fair value assets an d liab ilities and their
p lacement within th e fair valu e h ierarchy. There were no transfers between levels or material ch anges in valuatio n techniqu es or in puts during the years ended December 31, 2 023 and
2 022.

Th e follo wing table presents information abo u t Idah o Po wer's assets and liabilities measured at fair v alue on a recurring basis as o f December 31 , 202 3 an d 202 2 (in th o usands o f
d ollars):
December 31, 2023 December 31, 2022
Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Total
Th e table below presents the fair values and locations of d erivative in stru men ts n ot desig nated as h edg in g instruments recorded on the balance sheets and reconciles the grossamounts of derivativ es recognized as assets and as liabilities to the net amo unts presented in the balance sheets at December 31, 202 3 an d 202 2 (in tho usands o f dollars): Asset Deriva tiv es Liability Deriva tives Ba la nce SheetLocation GrossFairValue Amo untsOffset NetAssets GrossFairValue Amo untsOffset NetLiabilities December 31,2 023 Current: Finan cial swap s Other cu rrent assets $ 241 $ (169) $ 7 2 $ 169 $ (169) $Finan cial swap s Other cu rrentliabilities 1 ,476 (1,476) 41 ,977 (38 ,045)(1)3,93 2Forwardcontracts Other cu rrentliabilities 2 ,000 2,00 0Long-term: Finan cial swap s Other assets 106 (89) 1 7 89 (89) Finan cial swap s Other liab ilities 376 (376) 2 ,123 (2 ,123)(2)Total $ 2 ,199 $ (2,110) $ 8 9 $ 46 ,358 $ (40 ,426) $ 5,93 2 December 31,2 022 Current: Finan cial swap s Other cu rrent assets $ 72 ,548 $ (32,609)(3)$ 39,93 9 $ 13 ,982 $ (13 ,982) $Finan cial swap s Other cu rrentliabilities 132 (132) 1 ,577 (132) 1,44 5Forwardcontracts Other cu rrent assets 400 40 0 Forwardcontracts Other cu rrentliabilities 2 ,071 2,07 1Long-term: Finan cial swap s Other assets 622 (43) 57 9 43 (43) Finan cial swap s Other liab ilities 644 (644) 2 ,136 (644) 1,49 2Forwardcontracts Other liab ilities 1 ,780 1,78 0Total $ 74 ,346 $ (33,428) $ 40,91 8 $ 21 ,589 $ (14 ,801) $ 6,78 8 (1) Current liability derivative amo un ts offset inclu de $36.6 million of collateral receivable at December 31, 20 23.(2) Long -term liability derivative amoun ts o ffset inclu de $1.7 m illion of collateral receivab le at Decem ber 31, 202 3.(3) Current asset d erivativ e amounts offset includ e $18.6 million of collateral payable at December 31 , 2 022. Th e table below presents the volu mes o f deriv ative commod ity forward contracts and swaps ou tstanding at December 31, 2 023 and 2 022 (in thousands of un its): December 31,Co mmodity Units 2 023 2 022Electricity purchases MWh 440 898Electricity sales MWh 57 32Natural g as purchases MM Btu 24 ,593 2 6 ,773Natural g as sales MM Btu 310 1 5. FAIR VALUE MEASUREMENTS Id aho Power h as categ o rized their finan cial instru men ts in to a three-level fair value hierarchy, based on th e p rio rity of th e inp uts to the valu ation technique. The fair value hierarch ygives the high est priority to quo ted p rices in active mark ets for identical assets o r liabilities (Level 1) an d the lowest prio rity to un observable inputs (Lev el 3). If the inputs used tomeasure th e financial instruments fall within different levels of th e h ierarchy, the categorization is based on th e lo west level input that is significant to the fair v alue measuremen t ofthe in strument. Finan cial assets and liabilities reco rded on th e balance sh eets are categorized b ased on the inpu ts to the valu ation tech niques as follows: Level 1 : Financial assets and liabilities whose v alues are based on unad justed q uoted prices for identical assets or liabilities in an activ e market that Idah o Power has th e ability toaccess. Level 2 : Financial assets and liabilities whose v alues are based on the fo llowin g:a) quoted prices for similar assets or liabilities in active mark ets;b) q u oted prices for identical or similar assets or liabilities in non-active markets;c) pricing mod els whose in p uts are observ able for substan tially th e full term of the asset o r liability; andd) p ricing models wh o se inpu ts are derived prin cipally from or corroborated by ob servab le market data thro u gh correlation o r other means for sub stantially the fu ll termof the asset or liab ility. Idaho Po wer Lev el 2 inputs for d erivative in stru men ts are based on q uoted market p rices adjusted for location using corroborated , observ able market data or using quotedprice which may b e in non-active markets. Level 3 : Financial assets and liabilities whose v alues are based on prices or valuation techniques that require inpu ts th at are b oth un observable and sign ifican t to the overall fairvalue measurement. These inputs reflect man agement's own assu mption s about the assu mption s a market participan t wo uld use in pricing th e asset or liab ility. Id aho Power's assessment of a particular in put's sign ifican ce to the fair v alue measuremen t requ ires judg men t and may affect the v aluation of fair value assets an d liab ilities and their
p lacement within th e fair valu e h ierarchy. There were no transfers between levels or material ch anges in valuatio n techniqu es or in puts during the years ended December 31, 2 023 and
2 022.

Th e follo wing table presents information abo u t Idah o Po wer's assets and liabilities measured at fair v alue on a recurring basis as o f December 31 , 202 3 an d 202 2 (in th o usands o f
d ollars):
December 31, 2023 December 31, 2022
Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Total
Assets:
Money market funds and commercial
paper $
230,600

$

$
230,600
$ 34,468

$

$
$ 34,468
Derivatives 89 89 40,518 400 40,918
Equity securities 37,320 37,320 34,129 34,129
Liabilities:
Derivatives $ 3,932 $ 2,000 $ $ 5,932 $ 2,937 $ 3,851 $ $ 6,788

(1) Holding co mpany on ly. Does n ot inclu de amounts h eld b y Idaho Po wer.

Id aho Power's derivatives are contracts en tered into as part of its manag ement o f load s and resources. Electricity swap deriv atives are valu ed o n the Intercontinental Exchange (ICE)
with q uoted prices in an active market. Electricity forward co ntract deriv atives are valued u sing a b lend of two electricity exch anges, ad justed for location basis, as specified in the
fo rward contract. Natu ral gas and diesel deriv atives are valued using New York Mercan tile Exchan ge (NYMEX) and ICE p ricing, ad ju sted for location basis, wh ich are also quo ted
u nder NYMEX and ICE pricing . Equity secu rities at Id aho Power consist of employ ee-d irected in v estments related to an execu tiv e d eferred compensation plan and actively traded
money market an d ex change traded fun d s related to the SM SP. The investments are measu red u sin g quo ted p rices in activ e markets and are held in a rab bi trust.

Th e table below presents the carrying value an d estimated fair v alue of fin ancial instruments that are no t repo rted at fair v alue, as of Decemb er 3 1 , 20 2 3 and 20 22, u sing av ailab le
mark et info rmation an d ap propriate valuatio n methodo logies (in thousan ds of dollars).
December 31, 2023 December 3 1, 2 022

Ca rrying
Amount
Estima ted Fair
Value
Carry ing
Amo unt
Estimated Fair
Value
(thousands o f dollars)
Assets:
Held -to -matu rity securities(1) $ 3 1,639 $ 28 ,341 $ 30 ,475 $ 25,4 52
Liabilities:
Lon g-term deb t (inclu ding curren t
po rtion)(1) 2,82 5,590 2,684 ,278 2,194 ,145 1,953,4 70

(1) Held-to-m aturity securities and lon g-term debt are catego rized as Level 2 o f the fair value h ierarchy, as defined earlier in this Note 15 - "Fair Valu e Measurements."

Held-to-maturity securities are h eld in a rabbi tru st and are gen erally valu ed u sin g quo ted p rices, which may b e in non-active markets. Long-term debt is not traded on an exchan ge
and is v alued using quoted rates for similar deb t in active markets. Carrying v alues for cash an d cash equivalents, d eposits, custo mer and other receivables, n otes payab le, accoun ts
p ayable, interest accrued, and taxes accrued app roximate fair value.

1 6. CHANGES IN ACCUMULATED OTHER COMPREHENSIVE INCOME

Compreh ensive inco me includ es net inco me and amounts related to the SMSP. Th e table below p resents chan g es in comp onents of AOCI, n et o f tax, during the years ended December
3 1, 2 0 23 and 2 022 (in thousan ds of do llars). Items in parenth eses ind icate red uction s to AOCI.
Year Ended December 3 1,
2 023 2022
Defin ed benefit pensio n items
Balance at beg in ning o f perio d $ (1 2,922 ) $ (40,04 0)
Other co mprehen sive income before reclassifications, n et o f tax of
$(1,68 0) an d $8,239 (4,848 ) 23,77 0
Amounts reclassified out of AOCI to net income, net of tax of $203
and $1,16 0 586 3,34 8
Net curren t-period other compreh ensive inco me (4,262 ) 2 7 ,11 8
Balance at end of period $ (1 7,184 ) $ (12,92 2)

Th e table below presents the effects on net income o f amounts reclassified out o f components of AOCI and the in come statement location of tho se amounts reclassified during the
y ears ended December 3 1, 2 0 23 and 2 022 (in thousan ds of do llars). Items in parenth eses ind icate increases to net inco me.
Amount Reclassified fro m AOCI
Year Ended December 31,
2 023 2022
Amortizatio n of d efined benefit pension items
Prior service co st $ 219 $ 27 9
Net lo ss 570 4,22 9
Total b efore tax 789 4,50 8
Tax b enefit (203 ) (1,16 0)
Net o f tax 586 3,34 8
Total reclassification fo r the perio d $ 586 $ 3,34 8

1 7. RELATED PARTY TRANSACTIONS

IDACORP: Idah o Power performs corp orate functions such as financial, leg al, and man agement services for IDACORP and its sub sid iaries. Id aho Power charg es IDACORP for th e costs
o f these services based on service agreements and other sp ecifically iden tified costs. For th ese serv ices, Idah o Power billed IDACORP $1.1 million in 202 3 an d $0.9 millio n in 2 022.

At December 31, 2 023 and 2022, Idah o Power had a $16.2 million and $56.2 million pay able to IDACORP, respectively, which was included in its accounts payab le to affiliates
b alance on its b alan ce sh eets, primarily related to income tax pay men ts.

Ida -West: Ida-West Energy Company (Ida-West) is a who lly -own ed sub sid iary o f IDACORP and is an operator of small h y dropower gen eratio n projects that satisfy the req uirements of
th e Pu blic Utility Regulato ry Policies Act o f 1978 . Idaho Po wer purchases all of th e p o wer generated by fou r of Ida-West's 5 0 percent owned PURPA qualifying hydropo wer projects
lo cated in Idah o. Idaho Power pu rchased $9 .1 millio n in 2 023 and $7.9 million in 202 2 of p o wer from Ida-West.

Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 TotalAssets: Money market funds and commercialpaper $230,600 $ $ 230,600 $ 34,468 $ $ $ 34,468Derivatives 89 89 40,518 400 40,918Equity securities 37,320 37,320 34,129 34,129Liabilities: Derivatives $ 3,932 $ 2,000 $ $ 5,932 $ 2,937 $ 3,851 $ $ 6,788 (1) Holding co mpany on ly. Does n ot inclu de amounts h eld b y Idaho Po wer. Id aho Power's derivatives are contracts en tered into as part of its manag ement o f load s and resources. Electricity swap deriv atives are valu ed o n the Intercontinental Exchange (ICE)with q uoted prices in an active market. Electricity forward co ntract deriv atives are valued u sing a b lend of two electricity exch anges, ad justed for location basis, as specified in theforward contract. Natu ral gas and diesel deriv atives are valued using New York Mercan tile Exchan ge (NYMEX) and ICE p ricing, ad ju sted for location basis, wh ich are also quo tedunder NYMEX and ICE pricing . Equity secu rities at Id aho Power consist of employ ee-d irected in v estments related to an execu tiv e d eferred compensation plan and actively tradedmoney market an d ex change traded fun d s related to the SM SP. The investments are measu red u sin g quo ted p rices in activ e markets and are held in a rab bi trust. Th e table below presents the carrying value an d estimated fair v alue of fin ancial instruments that are no t repo rted at fair v alue, as of Decemb er 3 1 , 20 2 3 and 20 22, u sing av ailab lemarket info rmation an d ap propriate valuatio n methodo logies (in thousan ds of dollars). December 31, 2023 December 3 1, 2 022 Ca rryingAmount Estima ted FairValue Carry ingAmount Estimated FairValue (thousands o f dollars)Assets: Held -to -matu rity securities(1) $ 3 1,639 $ 28 ,341 $ 30 ,475 $ 25,4 52Liabilities: Lon g-term deb t (inclu ding curren tportion)(1) 2,82 5,590 2,684 ,278 2,194 ,145 1,953,4 70 (1) Held-to-m aturity securities and lon g-term debt are catego rized as Level 2 o f the fair value h ierarchy, as defined earlier in this Note 15 - "Fair Valu e Measurements." Held-to-maturity securities are h eld in a rabbi tru st and are gen erally valu ed u sin g quo ted p rices, which may b e in non-active markets. Long-term debt is not traded on an exchan geand is v alued using quoted rates for similar deb t in active markets. Carrying v alues for cash an d cash equivalents, d eposits, custo mer and other receivables, n otes payab le, accoun tspayable, interest accrued, and taxes accrued app roximate fair value. 1 6. CHANGES IN ACCUMULATED OTHER COMPREHENSIVE INCOME Compreh ensive inco me includ es net inco me and amounts related to the SMSP. Th e table below p resents chan g es in comp onents of AOCI, n et o f tax, during the years ended December31, 2 0 23 and 2 022 (in thousan ds of do llars). Items in parenth eses ind icate red uction s to AOCI. Year Ended December 3 1, 2 023 2022 Defin ed benefit pensio n items Balance at beg in ning o f perio d $ (1 2,922 ) $ (40,04 0) Other co mprehen sive income before reclassifications, n et o f tax of$(1,68 0) an d $8,239 (4,848 ) 23,77 0 Amounts reclassified out of AOCI to net income, net of tax of $203and $1,16 0 586 3,34 8 Net curren t-period other compreh ensive inco me (4,262 ) 2 7 ,11 8 Balance at end of period $ (1 7,184 ) $ (12,92 2) Th e table below presents the effects on net income o f amounts reclassified out o f components of AOCI and the in come statement location of tho se amounts reclassified during theyears ended December 3 1, 2 0 23 and 2 022 (in thousan ds of do llars). Items in parenth eses ind icate increases to net inco me. Amount Reclassified fro m AOCI Year Ended December 31, 2 023 2022 Amortizatio n of d efined benefit pension items Prior service co st $ 219 $ 27 9 Net lo ss 570 4,22 9 Total b efore tax 789 4,50 8 Tax b enefit (203 ) (1,16 0) Net o f tax 586 3,34 8 Total reclassification fo r the perio d $ 586 $ 3,34 8 1 7. RELATED PARTY TRANSACTIONS IDACORP: Idah o Power performs corp orate functions such as financial, leg al, and man agement services for IDACORP and its sub sid iaries. Id aho Power charg es IDACORP for th e costsof these services based on service agreements and other sp ecifically iden tified costs. For th ese serv ices, Idah o Power billed IDACORP $1.1 million in 202 3 an d $0.9 millio n in 2 022.
At December 31, 2 023 and 2022, Idah o Power had a $16.2 million and $56.2 million pay able to IDACORP, respectively, which was included in its accounts payab le to affiliates
b alance on its b alan ce sh eets, primarily related to income tax pay men ts.

Ida -West: Ida-West Energy Company (Ida-West) is a who lly -own ed sub sid iary o f IDACORP and is an operator of small h y dropower gen eratio n projects that satisfy the req uirements of
th e Pu blic Utility Regulato ry Policies Act o f 1978 . Idaho Po wer purchases all of th e p o wer generated by fou r of Ida-West's 5 0 percent owned PURPA qualifying hydropo wer projects
lo cated in Idah o. Idaho Power pu rchased $9 .1 millio n in 2 023 and $7.9 million in 202 2 of p o wer from Ida-West.

40
FERC FORM No. 1 (ED. 12-96)
Page 122-123
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original
(2) ☐ A Resubmission
Date of Report:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
STATEMENTS OF ACCUMULATED COMPREHENSIVE INCOME, COMPREHENSIVE INCOME, AND HEDGING ACTIVITIES
Line
No.
Item
(a)
Unrealized Gains
and Losses on
Available-For-
Sale Securities
(b)
Minimum Pension
Liability
Adjustment (net
amount)
(c)
Foreign
Currency
Hedges
(d)
Other Adjustments
(e)
Other Cash
Flow Hedges
Interest Rate
Swaps
(f)
Other
Cash
Flow
Hedges
[Specify]
(g)
Totals for
each category
of items
recorded in
Account 219
(h)
Net Income
(Carried
Forward from
Page 116,
Line 78)
(i)
Total
Comprehensive
Income
(j)
1 Balance of Account 219 at
Beginning of Preceding Year 0 0 0 (40,039,894)0 0 (40,039,894)
2
Preceding Quarter/Year to
Date Reclassifications from
Account 219 to Net Income
3,347,820 3,347,820
3 Preceding Quarter/Year to
Date Changes in Fair Value 23,769,687 23,769,687
4 Total (lines 2 and 3)27,117,507 27,117,507 254,866,668 281,984,175
5
Balance of Account 219 at
End of Preceding
Quarter/Year
(12,922,387)(12,922,387)
6 Balance of Account 219 at
Beginning of Current Year (12,922,387)(12,922,387)
7
Current Quarter/Year to Date
Reclassifications from
Account 219 to Net Income
586,110 586,110
8 Current Quarter/Year to Date
Changes in Fair Value (4,848,215)(4,848,215)
9 Total (lines 7 and 8)(4,262,105)(4,262,105)256,810,468 252,548,363
10 Balance of Account 219 at
End of Current Quarter/Year (17,184,492)(17,184,492)
FERC FORM No. 1 (NEW 06-02)
Page 122 (a)(b)
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original
(2) ☐ A Resubmission
Date of Report:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
SUMMARY OF UTILITY PLANT AND ACCUMULATED PROVISIONS FOR DEPRECIATION. AMORTIZATION AND DEPLETION
Line
No.
Classification
(a)
Total Company For the
Current Year/Quarter
Ended
(b)
Electric
(c)
Gas
(d)
Other (Specify)
(e)
Other (Specify)
(f)
Other
(Specify)
(g)
Common
(h)
1 UTILITY PLANT
2 In Service
3 Plant in Service (Classified)7,293,443,644 7,293,443,644
4 Property Under Capital Leases
5 Plant Purchased or Sold
6 Completed Construction not Classified
7 Experimental Plant Unclassified
8 Total (3 thru 7)7,293,443,644 7,293,443,644
9 Leased to Others
10 Held for Future Use 9,510,757 9,510,757
11 Construction Work in Progress 986,645,675 986,645,675
12 Acquisition Adjustments 750,893 750,893
13 Total Utility Plant (8 thru 12)8,290,350,969 8,290,350,969
14
Accumulated Provisions for
Depreciation, Amortization, &
Depletion
2,733,469,808 2,733,469,808
15 Net Utility Plant (13 less 14)5,556,881,161 5,556,881,161
16
DETAIL OF ACCUMULATED
PROVISIONS FOR DEPRECIATION,
AMORTIZATION AND DEPLETION
17 In Service:
18 Depreciation 2,688,859,595 2,688,859,595
19
Amortization and Depletion of
Producing Natural Gas Land and Land
Rights
20 Amortization of Underground Storage
Land and Land Rights
21 Amortization of Other Utility Plant 44,487,567 44,487,567
22 Total in Service (18 thru 21)2,733,347,162 2,733,347,162
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 Amortization of Plant Acquisition
Adjustment 122,646 122,646
33 Total Accum Prov (equals 14)
(22,26,30,31,32)2,733,469,808 2,733,469,808
FERC FORM No. 1 (ED. 12-89)
Page 200-201
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original
(2) ☐ A Resubmission
Date of Report:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
ELECTRIC PLANT IN SERVICE (Account 101, 102, 103 and 106)
Line
No.
Account
(a)
Balance Beginning of
Year
(b)
Additions
(c)
Retirements
(d)
Adjustments
(e)
Transfers
(f)
Balance at End
of Year
(g)
1 1. INTANGIBLE PLANT
2 (301) Organization 5,703 0 0 5,703
3 (302) Franchise and Consents 51,262,387 2,802,162 54,064,549
4 (303) Miscellaneous Intangible Plant 51,011,344 11,532,152 1,038,586 61,504,910
5 TOTAL Intangible Plant (Enter Total of
lines 2, 3, and 4)102,279,434 14,334,314 1,038,586 115,575,162
6 2. PRODUCTION PLANT
7 A. Steam Production Plant
8 (310) Land and Land Rights 1,722,421 0 0 1,722,421
9 (311) Structures and Improvements 121,196,047 1,280,531 341,166 122,135,412
10 (312) Boiler Plant Equipment 652,039,040 29,388,593 45,422,693 636,004,940
11 (313) Engines and Engine-Driven
Generators 0
12 (314) Turbogenerator Units 141,070,031 2,588,981 613,171 143,045,841
13 (315) Accessory Electric Equipment 55,116,343 (397,100)49,945 54,669,298
14 (316) Misc. Power Plant Equipment 20,196,162 1,266,362 1,531,756 19,930,768
15 (317) Asset Retirement Costs for
Steam Production 28,236,601 11,683,135 39,919,736
16 TOTAL Steam Production Plant (Enter
Total of lines 8 thru 15)1,019,576,645 45,810,502 47,958,731 1,017,428,416
17 B. Nuclear Production Plant
18 (320) Land and Land Rights 0
19 (321) Structures and Improvements 0
20 (322) Reactor Plant Equipment 0
21 (323) Turbogenerator Units 0
22 (324) Accessory Electric Equipment 0
23 (325) Misc. Power Plant Equipment 0
24 (326) Asset Retirement Costs for
Nuclear Production 0
25 TOTAL Nuclear Production Plant
(Enter Total of lines 18 thru 24)0
26 C. Hydraulic Production Plant
27 (330) Land and Land Rights 32,130,309 70,417 504,985 31,695,741
28 (331) Structures and Improvements 251,694,485 18,239,795 1,031,172 268,903,108
29 (332) Reservoirs, Dams, and
Waterways 306,795,629 5,673,299 181,189 312,287,739
30 (333) Water Wheels, Turbines, and
Generators 363,713,896 35,165,658 112,512 398,767,042
31 (334) Accessory Electric Equipment 72,052,750 4,526,737 389,038 76,190,449
32 (335) Misc. Power Plant Equipment 31,226,785 2,310,248 458,616 33,078,417
33 (336) Roads, Railroads, and Bridges 14,790,198 4,552,003 19,342,201
34 (337) Asset Retirement Costs for
Hydraulic Production 0
35 TOTAL Hydraulic Production Plant
(Enter Total of lines 27 thru 34)1,072,404,052 70,538,157 2,677,512 1,140,264,697
36 D. Other Production Plant
37 (340) Land and Land Rights 2,699,794 0 0 2,699,794
FERC FORM No. 1 (REV. 12-05)
Page 204-207
38 (341) Structures and Improvements 154,610,482 527,626 197,725 154,940,383
39
(342) Fuel Holders, Products, and
Accessories 10,438,247 0 0 10,438,247
40 (343) Prime Movers 273,426,259 59,789,837 38,496,848 294,719,248
41 (344) Generators 66,678,480 5,770,484 72,448,964
42 (345) Accessory Electric Equipment 93,629,469 565,040 374,908 93,819,601
43 (346) Misc. Power Plant Equipment 7,030,214 879,515 135,487 7,774,242
44 (347) Asset Retirement Costs for
Other Production 0
44.1 (348) Energy Storage Equipment -
Production
45 TOTAL Other Prod. Plant (Enter Total
of lines 37 thru 44)608,512,945 67,532,502 39,204,968 636,840,479
46 TOTAL Prod. Plant (Enter Total of
lines 16, 25, 35, and 45)2,700,493,642 183,881,161 89,841,211 2,794,533,592
47 3. Transmission Plant
48 (350) Land and Land Rights 40,478,393 2,685,649 43,164,042
48.1 (351) Energy Storage Equipment -
Transmission
49 (352) Structures and Improvements 100,889,219 5,499,703 95,562 106,293,360
50 (353) Station Equipment 474,044,847 20,081,696 1,091,247 493,035,296
51 (354) Towers and Fixtures 232,820,516 34,411 253,086 232,601,841
52 (355) Poles and Fixtures 230,116,925 16,426,785 1,241,885 245,301,825
53 (356) Overhead Conductors and
Devices 267,722,978 5,353,287 1,539,956 271,536,309
54 (357) Underground Conduit 0
55 (358) Underground Conductors and
Devices 0
56 (359) Roads and Trails 390,266 14,825 405,091
57 (359.1) Asset Retirement Costs for
Transmission Plant 0
58 TOTAL Transmission Plant (Enter
Total of lines 48 thru 57)1,346,463,144 50,096,356 4,221,736 1,392,337,764
59 4. Distribution Plant
60 (360) Land and Land Rights 9,014,430 61,127 9,075,557
61 (361) Structures and Improvements 59,517,798 6,769,589 203,039 66,084,348
62 (362) Station Equipment 327,836,697 12,782,925 1,824,463 338,795,159
63 (363) Energy Storage Equipment –
Distribution 0 140,772,713 140,772,713
64 (364) Poles, Towers, and Fixtures 326,364,004 21,197,740 3,257,218 344,304,526
65 (365) Overhead Conductors and
Devices 159,600,980 7,515,050 2,101,882 165,014,148
66 (366) Underground Conduit 54,625,690 3,185,533 96,297 57,714,926
67 (367) Underground Conductors and
Devices 331,603,490 21,409,174 1,908,440 351,104,224
68 (368) Line Transformers 730,455,194 55,113,652 8,265,271 777,303,575
69 (369) Services 69,113,735 3,365,746 41,378 72,438,103
70 (370) Meters 113,345,257 9,147,199 3,570,734 118,921,722
71 (371) Installations on Customer
Premises 4,629,374 1,331,740 117,101 5,844,013
72 (372) Leased Property on Customer
Premises 0
ELECTRIC PLANT IN SERVICE (Account 101, 102, 103 and 106)
Line
No.
Account
(a)
Balance Beginning of
Year
(b)
Additions
(c)
Retirements
(d)
Adjustments
(e)
Transfers
(f)
Balance at End
of Year
(g)
FERC FORM No. 1 (REV. 12-05)
Page 204-207
73 (373) Street Lighting and Signal
Systems 6,028,622 998,635 (58,016)7,085,273
74 (374) Asset Retirement Costs for
Distribution Plant 0
75 TOTAL Distribution Plant (Enter Total
of lines 60 thru 74)2,192,135,271 283,650,823 21,327,807 2,454,458,287
76 5. REGIONAL TRANSMISSION AND
MARKET OPERATION PLANT
77 (380) Land and Land Rights 0
78 (381) Structures and Improvements 0
79 (382) Computer Hardware 0
80 (383) Computer Software 0
81 (384) Communication Equipment 0
82
(385) Miscellaneous Regional
Transmission and Market Operation
Plant
0
83
(386) Asset Retirement Costs for
Regional Transmission and Market
Oper
0
84
TOTAL Transmission and Market
Operation Plant (Total lines 77 thru
83)
0
85 6. General Plant
86 (389) Land and Land Rights 20,811,566 265,608 21,077,174
87 (390) Structures and Improvements 156,834,664 24,049,217 2,475,327 178,408,554
88 (391) Office Furniture and Equipment 42,441,444 7,007,144 7,302,415 42,146,173
89 (392) Transportation Equipment 114,871,490 18,902,145 2,757,656 131,015,979
90 (393) Stores Equipment 4,957,470 2,852,680 56,646 7,753,504
91 (394) Tools, Shop and Garage
Equipment 15,057,356 850,488 150,206 15,757,638
92 (395) Laboratory Equipment 14,785,168 2,196,410 529,682 16,451,896
93 (396) Power Operated Equipment 26,399,205 5,606,557 673,348 31,332,414
94 (397) Communication Equipment 81,474,627 1,564,766 1,358,815 81,680,578
95 (398) Miscellaneous Equipment 10,776,662 542,062 403,795 10,914,929
96 SUBTOTAL (Enter Total of lines 86
thru 95)488,409,652 63,837,077 15,707,890 536,538,839
97 (399) Other Tangible Property 0
98 (399.1) Asset Retirement Costs for
General Plant 0
99 TOTAL General Plant (Enter Total of
lines 96, 97, and 98)488,409,652 63,837,077 15,707,890 536,538,839
100 TOTAL (Accounts 101 and 106)6,829,781,143 595,799,731 132,137,230 7,293,443,644
101 (102) Electric Plant Purchased (See
Instr. 8)0
102 (Less) (102) Electric Plant Sold (See
Instr. 8)0
103 (103) Experimental Plant Unclassified 0
104 TOTAL Electric Plant in Service (Enter
Total of lines 100 thru 103)6,829,781,143 595,799,731 132,137,230 7,293,443,644
FERC FORM No. 1 (REV. 12-05)
Page 204-207
ELECTRIC PLANT IN SERVICE (Account 101, 102, 103 and 106)
Line
No.
Account
(a)
Balance Beginning of
Year
(b)
Additions
(c)
Retirements
(d)
Adjustments
(e)
Transfers
(f)
Balance at End
of Year
(g)
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original
(2) ☐ A Resubmission
Date of Report:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
ELECTRIC PLANT HELD FOR FUTURE USE (Account 105)
Line
No.
Description and Location of Property
(a)
Date Originally Included in This
Account
(b)
Date Expected to be used in Utility
Service
(c)
Balance at End of Year
(d)
1 Land and Rights:
2 Transmission Stations (a)(f)424,115
3 Transmission Lines (b)(g)68,592
4 Pallette Junction Substation 03/15/2021 12/31/2028 778,595
5 Distribution Lines (c)(h)25,581
6 Distribution Stations (d)(i)1,378,006
7 Farmway Station 12/22/2022 06/30/2029 947,032
8 Northside Substation 02/01/2023 06/30/2027 1,383,742
9
10 McDermott Substation 10/26/2022 06/30/2026 1,330,604
11 Midpoint Transmission Station 12/15/2022 09/30/2027 870,843
12 Line #854 500 Kv 03/31/2009 06/30/2029 308,066
13
14 Production (e)(j)104,155
15 Sawmill Substation 09/18/2023 06/30/2026 618,477
16
17 Line #853 500 Kv 12/16/2011 12/31/2026 575,774
21 Other Property:
22 Transmission Stations (k)(m)199,069
23 Distribution Stations (l)(n)54,561
24 Underground Vault, Blaine County 08/30/2016 12/31/2026 443,545
47 TOTAL 9,510,757
FERC FORM No. 1 (ED. 12-96)
Page 214
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original
(2) ☐ A Resubmission
Date of Report:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
FOOTNOTE DATA
(a) Concept: ElectricPlantPropertyClassifiedAsHeldForFutureUseOriginalDate
Various Dates
(b) Concept: ElectricPlantPropertyClassifiedAsHeldForFutureUseOriginalDate
Various Dates
(c) Concept: ElectricPlantPropertyClassifiedAsHeldForFutureUseOriginalDate
Various Dates
(d) Concept: ElectricPlantPropertyClassifiedAsHeldForFutureUseOriginalDate
Various Dates
(e) Concept: ElectricPlantPropertyClassifiedAsHeldForFutureUseOriginalDate
Various Dates
(f) Concept: ElectricPlantPropertyClassifiedAsHeldForFutureUseExpectedUseInServiceDate
Various Dates
(g) Concept: ElectricPlantPropertyClassifiedAsHeldForFutureUseExpectedUseInServiceDate
Various Dates
(h) Concept: ElectricPlantPropertyClassifiedAsHeldForFutureUseExpectedUseInServiceDate
Various Dates
(i) Concept: ElectricPlantPropertyClassifiedAsHeldForFutureUseExpectedUseInServiceDate
Various Dates
(j) Concept: ElectricPlantPropertyClassifiedAsHeldForFutureUseExpectedUseInServiceDate
Various Dates
(k) Concept: ElectricPlantPropertyClassifiedAsHeldForFutureUseOriginalDate
Various Dates
(l) Concept: ElectricPlantPropertyClassifiedAsHeldForFutureUseOriginalDate
Various Dates
(m) Concept: ElectricPlantPropertyClassifiedAsHeldForFutureUseExpectedUseInServiceDate
Various Dates
(n) Concept: ElectricPlantPropertyClassifiedAsHeldForFutureUseExpectedUseInServiceDate
Various Dates
FERC FORM No. 1 (ED. 12-96)
Page 214
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original
(2) ☐ A Resubmission
Date of Report:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
CONSTRUCTION WORK IN PROGRESS - - ELECTRIC (Account 107)
Line No.Description of Project
(a)
Construction work in progress - Electric (Account 107)
(b)
1 PURCHASE CORPORATE PLANE 1,002,539
2 AUD MODERNIZATION 1,032,074
3 BMP EXHAUST BAFFLE REPLACEMENT 1,041,876
4 NTSD220001 - NEW T-LINE FOR NO 1,070,339
5 SKPR220011 - POWER PLANT/DAM P 1,073,807
6 JOOA IPC ONLY REPLACE 102A 138 1,138,645
7 LINE 902 DESIGN & PERMIT 1,139,967
8 BROWNLEE SPILLWAY REHABILITATI 1,237,539
9 LANGLEY GULCH WELL #3 INSTALL 1,247,730
10 HELLS CANYON NOAA BIOLOGICAL A 1,335,295
11 RAPID RIVER HATCHERY RENOVATIO 1,359,954
12 T226170001 PHASE 3 REPAIR VALE 1,373,194
13 BORA240001 - SUBSTATION PERIME 1,384,647
14 HCC MERCURY NUMERIC MODEL DEVE 1,395,589
15 FILR220001 - BESS REGULATOR AN 1,474,075
16 HCPR190001 - BOP 1,499,123
17 GRID MOD SINGLE VENDOR PLATFOR 1,499,677
18 FALL CHINOOK PROGRAM - ENTRAPM 1,517,213
19 T412200001 - REBUILD BOBN-EMET 1,576,044
20 GIGE V3 CARDS REPLACEMENTS 202 1,577,290
21 OXBOW UNIT 3 TURBINE AND GENER 1,617,117
22 OXBOW UNIT 4 TURBINE AND GENER 1,617,117
23 T423190001 HGTN-QUTZ 138KV REB 1,780,485
24 JOINT ASSETS: RPL FAILED 1-PH 1,892,405
25 BSPO TURBINE & GENERATOR REFUR 2,231,111
26 HGTN180001 - CONVERT TO 138KV 2,254,837
27 T902 LINE WORK ASSOCIATED WITH 2,269,495
28 HGTN012 35KV FEEDER TO LIME 2,313,834
29 OXBOW SPILLWAY REHABILITATION 2,372,438
30 OBPR UNIT 2 TURBINE AND GENERA 2,403,515
31 OXBOW UNIT 1 TURBINE AND GENER 2,403,941
32 COLE STATION - TRANSMISSION WO 2,423,678
33 AFPR UNIT 3 TURBINE REFURB 2,438,630
34 COMMON ASSET: MPSN 345KV FENCE 2,520,511
35 COMMON ASSET: RPL MPSN C506 SE 2,619,746
36 MNHM230001 - BESS PROJECT 2,906,134
37 NTSD220001- NEW NORTHSIDE SUBS 3,055,161
38 LNDN190001 - ADD 138KV BREAKER 3,080,792
39 T533230001- 138KV WDRI-KCHM UG 3,168,896
40 AFPR UNIT 2 REFURB 3,242,621
41 FILR220001 - ADD 2MW BATTERY S 3,641,487
42 KPRT240001 - SUBSTATION PERIME 3,871,095
43 REPORTING MODEL FOR SNAKE RIVE 4,168,037
FERC FORM No. 1 (ED. 12-87)
Page 216
44 COMMON ASSET: MPSN 500KV FENCE 4,244,840
45 AFPR PLANT CONTROLS MODERNIZAT 4,249,597
46 FALL CHINOOK PROGRAM - REDD SU 4,587,170
47 MLBA220001 - ADD 2MW BATTERY S 4,809,768
48 BRIDGER 2022C301 U1 CONVERSION 4,822,036
49 BRIDGER 2022C302 U2 CONVERSION 4,873,580
50 JOINT ASSET: RPL MPSN C506 SER 5,062,127
51 HC SEDIMENT PROGRAMS 5,214,127
52 B2H TLINE CONSTRUCTION COSTS 5,293,705
53 DISTRIBUTION WORK FOR 2ND WDRI 5,366,563
54 LINE 902 10 YEAR MAINTENANCE 5,545,044
55 LINE 902 REBUILD - RTSN TO DRA 6,147,755
56 REL-HCC OREGON REAUTHORIZATION 6,545,504
57 GRID MOD SINGLE VENDOR PLATFOR 6,618,693
58 AFPR UNIT 1 REFURB 6,690,558
59 ELMR220001 - ADD 4MW BATTERY S 6,902,457
60 B2H: RIGHTS OF WAY 7,133,286
61 WESR220001 - ADD 2MW BATTERY S 7,326,225
62 BULL TROUT PROGRAM - ADMINISTR 7,691,158
63 LEGAL DEPT. LABOR FOR RELICENS 8,666,611
64 B2H: LIMITED CONSTRUCTION FUND 9,156,941
65 HCC WATERSHED ENHANCEMENT PROG 11,744,784
66 T423190001-REBUILD FROM HGTN T 12,106,398
67 BOARDMAN - HEMINGWAY 500 KV LI 13,526,054
68 WQ HCC401 CERTIFICATION OPS AN 14,524,248
69 OXBOW HATCHERY RENOVATION 16,066,993
70 BMSU220002- 2021 RFP NEW ENERG 26,272,801
71 HPVY BESS DEVELOPMENT - 2025 R 28,296,909
72 HMWY BESS - 12MW EXPANSION 32,124,893
73 B2H PERMITTING 11/1/2011 & FOR 35,388,729
74 IPC FUNDING - BPA PERMITTING/P 41,128,859
75 HELLS CANYON RELICENSING OUTSI 49,236,179
76 ROLLUP RELIC COST OXBOW 56,320,382
77 GATEWAY WEST 500KV LINE 59,684,477
78 ROLLUP RELIC COST HELLS CANYON 120,690,527
79 ROLLUP RELIC COST BROWNLEE 177,461,753
80 Other Minor Projects Under $1,000,000 78,854,244
43 Total 986,645,675
FERC FORM No. 1 (ED. 12-87)
Page 216
CONSTRUCTION WORK IN PROGRESS - - ELECTRIC (Account 107)
Line No.Description of Project
(a)
Construction work in progress - Electric (Account 107)
(b)
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original
(2) ☐ A Resubmission
Date of Report:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
ACCUMULATED PROVISION FOR DEPRECIATION OF ELECTRIC UTILITY PLANT (Account 108)
Line
No.
Item
(a)
Total (c + d + e)
(b)
Electric Plant in Service
(c)
Electric Plant Held for Future
Use
(d)
Electric Plant Leased To
Others
(e)
Section A. Balances and Changes During Year
1 Balance Beginning of Year 2,606,079,117 2,606,079,117
2 Depreciation Provisions for Year, Charged to
3 (403) Depreciation Expense 188,144,343 188,144,343
4 (403.1) Depreciation Expense for Asset
Retirement Costs 0
5 (413) Exp. of Elec. Plt. Leas. to Others 0 0
6 Transportation Expenses-Clearing 6,873,504 6,873,504
7 Other Clearing Accounts 0 0
8 Other Accounts (Specify, details in footnote):
9.1 Fuel Stock 40,426 40,426
10 TOTAL Deprec. Prov for Year (Enter Total of lines
3 thru 9)195,058,273 195,058,273 0 0
11 Net Charges for Plant Retired:
12 Book Cost of Plant Retired (130,593,659)(130,593,659)
13 Cost of Removal (30,055,989)(30,055,989)
14 Salvage (Credit)16,268,032 16,268,032
15 TOTAL Net Chrgs. for Plant Ret. (Enter Total of
lines 12 thru 14)(144,381,616)(144,381,616)0 0
16 Other Debit or Cr. Items (Describe, details in
footnote):
17.1
(a)
Depreciation Adjustments 32,103,821 32,103,821
18 Book Cost or Asset Retirement Costs Retired 0
19 Balance End of Year (Enter Totals of lines 1, 10,
15, 16, and 18)2,688,859,595 2,688,859,595 0 0
Section B. Balances at End of Year According to Functional Classification
20 Steam Production 721,207,878 721,207,878
21 Nuclear Production 0
22 Hydraulic Production-Conventional 522,472,554 522,472,554
23 Hydraulic Production-Pumped Storage 0
24 Other Production 145,606,785 145,606,785
25 Transmission 431,545,321 431,545,321
26 Distribution 722,571,735 722,571,735
27 Regional Transmission and Market Operation 0
28 General 145,455,322 145,455,322
29 TOTAL (Enter Total of lines 20 thru 28)2,688,859,595 2,688,859,595 0 0
FERC FORM No. 1 (REV. 12-05)
Page 219
FOOTNOTE DATA
(a) Concept: OtherAdjustmentsToAccumulatedDepreciationDescription
Valmy depreciation adjustments (ID Order No. 33771 and OR Order No. 17-235)
Bridger depreciation adjustments (ID Order No. 35423)
Wildfire Mitigation depreciation adjustments (ID Order No. 35077)
CIAC and Asset Retirement Obligation activity
FERC FORM No. 1 (REV. 12-05)
Page 219
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original
(2) ☐ A Resubmission
Date of Report:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
INVESTMENTS IN SUBSIDIARY COMPANIES (Account 123.1)
Line
No.
Description of Investment
(a)
Date Acquired
(b)
Date of Maturity
(c)
Amount of Investment
at Beginning of Year
(d)
Equity in Subsidiary
Earnings of Year
(e)
Revenues
for Year
(f)
Amount of
Investment
at End of
Year
(g)
Gain or
Loss from
Investment
Disposed
of
(h)
1 COMMON STOCK 02/01/1974 500 500
2 CAPITAL CONTRIBUTIONS 2,462,594 2,462,594
3 EQUITY IN EARNINGS 12,228,425 8,033,987 0 20,262,412
42 Total Cost of Account 123.1 $Total 14,691,519 8,033,987 0 22,725,506
FERC FORM No. 1 (ED. 12-89)
Page 224-225
This report is:
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original
(2) ☐ A Resubmission
Date of Report:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
MATERIALS AND SUPPLIES
Line
No.
Account
(a)
Balance Beginning of Year
(b)
Balance End of Year
(c)
Department or Departments which Use Material
(d)
1 Fuel Stock (Account 151)14,760,362 19,952,164
2 Fuel Stock Expenses Undistributed (Account 152)1,691 0
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)14,645,220 14,101,636
8 Transmission Plant (Estimated)15,826,350 48,400,412
9 Distribution Plant (Estimated)59,743,149 71,718,154
10 Regional Transmission and Market Operation Plant
(Estimated)
11 Assigned to - Other (provide details in footnote)(a)1,656,595 (b)1,768,276
12 TOTAL Account 154 (Enter Total of lines 5 thru 11)91,871,314 135,988,478
13 Merchandise (Account 155)
14 Other Materials and Supplies (Account 156)0 0
15 Nuclear Materials Held for Sale (Account 157) (Not
applic to Gas Util)
16 Stores Expense Undistributed (Account 163)589,580 4,526,104
17
18
19
20 TOTAL Materials and Supplies 107,222,947 160,466,746
FERC FORM No. 1 (REV. 12-05)
Page 227
This report is:
Name of Respondent:Idaho Power Company This report is:(1) ☑ An Original(2) ☐ A Resubmission Date of Report:04/16/2024 Year/Period of ReportEnd of: 2023/ Q4MATERIALS AND SUPPLIESLineNo.Account(a)Balance Beginning of Year(b)Balance End of Year(c)Department or Departments which Use Material(d)1 Fuel Stock (Account 151)14,760,362 19,952,1642Fuel Stock Expenses Undistributed (Account 152)1,691 03Residuals and Extracted Products (Account 153)4 Plant Materials and Operating Supplies (Account 154)5 Assigned to - Construction (Estimated)6 Assigned to - Operations and Maintenance7Production Plant (Estimated)14,645,220 14,101,6368Transmission Plant (Estimated)15,826,350 48,400,4129Distribution Plant (Estimated)59,743,149 71,718,15410Regional Transmission and Market Operation Plant(Estimated)11 Assigned to - Other (provide details in footnote)(a)1,656,595 (b)1,768,27612TOTAL Account 154 (Enter Total of lines 5 thru 11)91,871,314 135,988,47813Merchandise (Account 155)14 Other Materials and Supplies (Account 156)0 015Nuclear Materials Held for Sale (Account 157) (Notapplic to Gas Util)16 Stores Expense Undistributed (Account 163)589,580 4,526,10417181920TOTAL Materials and Supplies 107,222,947 160,466,746FERC FORM No. 1 (REV. 12-05)Page 227
This report is:
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original
(2) ☐ A Resubmission
Date of Report:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
FOOTNOTE DATA
(a) Concept: PlantMaterialsAndOperatingSuppliesOther
This amount represents miscellaneous inventory that is not yet assigned to a particular function.
(b) Concept: PlantMaterialsAndOperatingSuppliesOther
This amount represents miscellaneous inventory that is not yet assigned to a particular function.
FERC FORM No. 1 (REV. 12-05)
Page 227
This report is:
Name of Respondent:Idaho Power Company This report is:(1) ☑ An Original(2) ☐ A Resubmission Date of Report:04/16/2024 Year/Period of ReportEnd of: 2023/ Q4FOOTNOTE DATA(a) Concept: PlantMaterialsAndOperatingSuppliesOtherThis amount represents miscellaneous inventory that is not yet assigned to a particular function.(b) Concept: PlantMaterialsAndOperatingSuppliesOtherThis amount represents miscellaneous inventory that is not yet assigned to a particular function.FERC FORM No. 1 (REV. 12-05)Page 227
This report is:
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original
(2) ☐ A Resubmission
Date of Report:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
Transmission Service and Generation Interconnection Study Costs
Line
No.
Description
(a)
Costs Incurred During Period
(b)
Account Charged
(c)
Reimbursements Received
During the Period
(d)
Account Credited
With Reimbursement
(e)
1 Transmission Studies
2 BPA LTF PTP 97456622 STUDY (335)186623 (a)5,320 186623
3 PWX 92502052 CF BIENNIAL REASSESSMENT 0 186623 (273)186623
4 BPA LTF PTP 97887976 STUDY 0 186623 8,858 186623
5 PAC LTF PTP 98184887 STUDY 2,973 186623 7,027 186623
6 PWX LTF PTP B2H STUDIES 13,589 186623 65,976 186623
7 IPCL LTF NETWORK 99097009 STUDY 11,698 186623 (11,698)186623
8 FPLP LTF PTP TSR 99497490 10,122 186623 (10,122)186623
9 IPCL LTF NETWORK 99642253 STUDY 4,227 186623 (4,227)186623
10 FPLP LTF PTP TSR 99989758 6,741 186623 (6,741)186623
11 PWX LTF PTP TSR 100104285 3,431 186623 (25,607)186623
12 PWX LTF PTP TSR 100104286 2,841 186623 (25,357)186623
13 PWX LTF PTP TSR 100104289 3,184 186623 (25,971)186623
14 PWX LTF PTP TSR 100104297 3,282 186623 (25,485)186623
15 PWX LTF PTP TSR 99137594 2,515 186623 (2,515)186623
16 PWX LTF PTP TSR 99137596 2,224 186623 (2,224)186623
17 PWX LTF PTP TSR 99137597 2,192 186623 (2,192)186623
18 PWX LTF PTP TSR 99137598 2,298 186623 (2,298)186623
19 FPLP LTF PTP TSR 99298192 2,673 186623 (2,673)186623
20 FPLP LTF PTP TSR 100875435 1,273 186623 (10,000)186623
21 MEAI LTF PTP TSR 101041691 1,165 186623 (10,000)186623
22 BPA CF REASSESSMENT TSR 91629850 AND
91629500 939 186623 0 186623
23 MEAI LTF PTP TSR 100455881 103 186623 (103)186623
24 PAC LTF PTP TSR 100715919 551 186623 (501)186623
25 PAC LTF PTP TSR 100715926 551 186623 (501)186623
20 Total 78,237 (81,307)
21 Generation Studies
22 ARCO WIND 2 #580 6,713 186623 50,158 186623
23 APPALOOSA WIND & SOLAR #1 400MW 33,595 186623 (17,046)186623
24 CRIMSON ORCHARD #604 240MW 0 186623 81,607 186623
25 SOUTH BENNETT #605 240MW 15,981 186623 76,323 186623
26 JACKALOPE 1 #607 300 MW 2,955 186623 112,732 186623
27 JACKALOPE 2 #608 300 MW 4,175 186623 95,645 186623
28 JACKALOPE 2 #609 300 MW 2,886 186623 96,729 186623
29 OLD OREGON TRAIL PV3 #613 0 186623 95,577 186623
30 SALMON FALLS WIND #614 22,964 186623 76,723 186623
31 SALMON FALLS WIND 2 #616 21,733 186623 78,267 186623
32 OWYHEE PUMPED STORAGE #622 2,335 186623 94,332 186623
33 MOSBY BUTTE SOLAR #623 0 186623 86,260 186623
34 GEM VALE 1 #624 16,208 186623 76,905 186623
35 GEM VALE 2 #625 2,411 186623 96,480 186623
36 HMWY ENERGY STORAGE 2 #629 1,015 186623 0 186623
FERC FORM No. 1 (NEW. 03-07)
Page 231
Name of Respondent:Idaho Power Company This report is:(1) ☑ An Original(2) ☐ A Resubmission Date of Report:04/16/2024 Year/Period of ReportEnd of: 2023/ Q4Transmission Service and Generation Interconnection Study CostsLineNo.Description(a)Costs Incurred During Period(b)Account Charged(c)Reimbursements ReceivedDuring the Period(d)Account CreditedWith Reimbursement(e)1 Transmission Studies2BPA LTF PTP 97456622 STUDY (335)186623 (a)5,320 1866233PWX 92502052 CF BIENNIAL REASSESSMENT 0 186623 (273)1866234BPA LTF PTP 97887976 STUDY 0 186623 8,858 1866235PAC LTF PTP 98184887 STUDY 2,973 186623 7,027 1866236PWX LTF PTP B2H STUDIES 13,589 186623 65,976 1866237IPCL LTF NETWORK 99097009 STUDY 11,698 186623 (11,698)1866238FPLP LTF PTP TSR 99497490 10,122 186623 (10,122)1866239IPCL LTF NETWORK 99642253 STUDY 4,227 186623 (4,227)18662310FPLP LTF PTP TSR 99989758 6,741 186623 (6,741)18662311PWX LTF PTP TSR 100104285 3,431 186623 (25,607)18662312PWX LTF PTP TSR 100104286 2,841 186623 (25,357)18662313PWX LTF PTP TSR 100104289 3,184 186623 (25,971)18662314PWX LTF PTP TSR 100104297 3,282 186623 (25,485)18662315PWX LTF PTP TSR 99137594 2,515 186623 (2,515)18662316PWX LTF PTP TSR 99137596 2,224 186623 (2,224)18662317PWX LTF PTP TSR 99137597 2,192 186623 (2,192)18662318PWX LTF PTP TSR 99137598 2,298 186623 (2,298)18662319FPLP LTF PTP TSR 99298192 2,673 186623 (2,673)18662320FPLP LTF PTP TSR 100875435 1,273 186623 (10,000)18662321MEAI LTF PTP TSR 101041691 1,165 186623 (10,000)18662322BPA CF REASSESSMENT TSR 91629850 AND91629500 939 186623 0 18662323MEAI LTF PTP TSR 100455881 103 186623 (103)18662324PAC LTF PTP TSR 100715919 551 186623 (501)18662325PAC LTF PTP TSR 100715926 551 186623 (501)18662320Total78,237 (81,307)21 Generation Studies22ARCO WIND 2 #580 6,713 186623 50,158 18662323APPALOOSA WIND & SOLAR #1 400MW 33,595 186623 (17,046)18662324CRIMSON ORCHARD #604 240MW 0 186623 81,607 18662325SOUTH BENNETT #605 240MW 15,981 186623 76,323 18662326JACKALOPE 1 #607 300 MW 2,955 186623 112,732 18662327JACKALOPE 2 #608 300 MW 4,175 186623 95,645 18662328JACKALOPE 2 #609 300 MW 2,886 186623 96,729 18662329OLD OREGON TRAIL PV3 #613 0 186623 95,577 18662330SALMON FALLS WIND #614 22,964 186623 76,723 18662331SALMON FALLS WIND 2 #616 21,733 186623 78,267 18662332OWYHEE PUMPED STORAGE #622 2,335 186623 94,332 18662333MOSBY BUTTE SOLAR #623 0 186623 86,260 18662334GEM VALE 1 #624 16,208 186623 76,905 18662335GEM VALE 2 #625 2,411 186623 96,480 18662336HMWY ENERGY STORAGE 2 #629 1,015 186623 0 186623FERC FORM No. 1 (NEW. 03-07)Page 231
37 ELKO COUNTY SOLAR 1 GI #630 15,139 186623 80,949 186623
38 WILSON #632 18,374 186623 100,264 186623
39 GATHER #633 674 186623 110,625 186623
40 HMWY ENERGY STORAGE EXPANSION #634 254 186623 (11,678)186623
41 TAURUS WIND #635 39,240 186623 100,819 186623
42 SOLES REST #636 19,555 186623 (47,503)186623
43 HPVY ENERGY STORAGE #638 10,410 186623 (15,161)186623
44 BOBN ENERGY STORAGE 1 #639 9,592 186623 0 186623
45 BOBN ENERGY STORAGE 2 #640 8,867 186623 (11,722)186623
46 AMERICAN FALLS ESC #641 10,719 186623 86,945 186623
47 SHOESTRING #643 7,010 186623 140,844 186623
48 JASPER #646 53,323 186623 92,704 186623
49 HASHBROWN #647 26,022 186623 119,518 186623
50 MOON CRATER II #648 17,152 186623 100,332 186623
51 VIZCAYA GI PROJECT #649 20,858 186623 133,186 186623
52 DRAGONFLY GI PROJECT #650 28,299 186623 126,016 186623
53 MAGIC VALLEY ENERGY STORAGE GI PROJECT
#652 1,140 186623 42,811 186623
54 PINGREE SOLAR GI PROJECT #654 16,156 186623 49,916 186623
55 BEAR LAKE GI PROJECT #655 1,712 186623 (34,913)186623
56 RED BRIDGE SOLAR & STORAGE GI PROJECT #656 8,357 186623 41,470 186623
57 KUNA STORAGE GI PROJECT #657 55,797 186623 (55,277)186623
58 BLUEBUNCH SOLAR 1 GI PROJECT #658 21,389 186623 (56,145)186623
59 FALCON GI PROJECT #659 8,214 186623 51,676 186623
60 FITZ GI PROJECT #660 9,443 186623 57,899 186623
61 JACQUELINE GI PROJECT #661 2,516 186623 63,603 186623
62 OLNEY GI PROJECT #662 34,407 186623 (47,506)186623
63 VIZCAYA 230KV GI PROJECT #663 36,688 186623 13,193 186623
64 BLACKS CREEK EC GI PROJECT #665 32,710 186623 (49,170)186623
65 POWERS BUTTE EC GI PROJECT #666 17,373 186623 36,014 186623
66 MARTHA FIELDS EC I GI PROJECT #667 31,438 186623 (50,000)186623
67 MARTHA FIELDS EC II GI PROJECT #668 5,269 186623 60,652 186623
68 BRIDGERS PVS GI PROJECT #669 19,410 186623 35,950 186623
69 FLATIRON HILLS WIND I GI PROJECT #670 19,964 186623 (1,046)186623
70 KIMAMA FLATTS SOLAR GI PROJECT #671 7,533 186623 9,354 186623
71 EDEN WEST SOLAR GI PROJECT #672 5,235 186623 13,182 186623
72 EDEN NORTH SOLAR GI PROJECT #673 (6)186623 10,000 186623
73 KUNA MATATA SOLAR GI PROJECT #674 4,399 186623 13,927 186623
74 OMG WIND GI PROJECT #675 (5)186623 10,000 186623
75 OMG WIND II GI PROJECT #676 (5)186623 10,000 186623
76 BEAR DEN SOLAR 1 GI PROJECT #677 2,171 186623 17,571 186623
77 SOUTH FALLS GI PROJECT #678 3,611 186623 12,396 186623
78 SOUTH HILLS SOLAR GI PROJECT #680 8,086 186623 (134)186623
79 BEAR DEN SOLAR II GI PROJECT #682 1,012 186623 18,924 186623
80 MOON CRATER SOLAR GI PROJECT #573 417 186623 19,583 186623
Transmission Service and Generation Interconnection Study Costs
Line
No.
Description
(a)
Costs Incurred During Period
(b)
Account Charged
(c)
Reimbursements Received
During the Period
(d)
Account Credited
With Reimbursement
(e)
FERC FORM No. 1 (NEW. 03-07)
Page 231
37 ELKO COUNTY SOLAR 1 GI #630 15,139 186623 80,949 18662338WILSON #632 18,374 186623 100,264 18662339GATHER #633 674 186623 110,625 18662340HMWY ENERGY STORAGE EXPANSION #634 254 186623 (11,678)18662341TAURUS WIND #635 39,240 186623 100,819 18662342SOLES REST #636 19,555 186623 (47,503)18662343HPVY ENERGY STORAGE #638 10,410 186623 (15,161)18662344BOBN ENERGY STORAGE 1 #639 9,592 186623 0 18662345BOBN ENERGY STORAGE 2 #640 8,867 186623 (11,722)18662346AMERICAN FALLS ESC #641 10,719 186623 86,945 18662347SHOESTRING #643 7,010 186623 140,844 18662348JASPER #646 53,323 186623 92,704 18662349HASHBROWN #647 26,022 186623 119,518 18662350MOON CRATER II #648 17,152 186623 100,332 18662351VIZCAYA GI PROJECT #649 20,858 186623 133,186 18662352DRAGONFLY GI PROJECT #650 28,299 186623 126,016 18662353MAGIC VALLEY ENERGY STORAGE GI PROJECT#652 1,140 186623 42,811 18662354PINGREE SOLAR GI PROJECT #654 16,156 186623 49,916 18662355BEAR LAKE GI PROJECT #655 1,712 186623 (34,913)18662356RED BRIDGE SOLAR & STORAGE GI PROJECT #656 8,357 186623 41,470 18662357KUNA STORAGE GI PROJECT #657 55,797 186623 (55,277)18662358BLUEBUNCH SOLAR 1 GI PROJECT #658 21,389 186623 (56,145)18662359FALCON GI PROJECT #659 8,214 186623 51,676 18662360FITZ GI PROJECT #660 9,443 186623 57,899 18662361JACQUELINE GI PROJECT #661 2,516 186623 63,603 18662362OLNEY GI PROJECT #662 34,407 186623 (47,506)18662363VIZCAYA 230KV GI PROJECT #663 36,688 186623 13,193 18662364BLACKS CREEK EC GI PROJECT #665 32,710 186623 (49,170)18662365POWERS BUTTE EC GI PROJECT #666 17,373 186623 36,014 18662366MARTHA FIELDS EC I GI PROJECT #667 31,438 186623 (50,000)18662367MARTHA FIELDS EC II GI PROJECT #668 5,269 186623 60,652 18662368BRIDGERS PVS GI PROJECT #669 19,410 186623 35,950 18662369FLATIRON HILLS WIND I GI PROJECT #670 19,964 186623 (1,046)18662370KIMAMA FLATTS SOLAR GI PROJECT #671 7,533 186623 9,354 18662371EDEN WEST SOLAR GI PROJECT #672 5,235 186623 13,182 18662372EDEN NORTH SOLAR GI PROJECT #673 (6)186623 10,000 18662373KUNA MATATA SOLAR GI PROJECT #674 4,399 186623 13,927 18662374OMG WIND GI PROJECT #675 (5)186623 10,000 18662375OMG WIND II GI PROJECT #676 (5)186623 10,000 18662376BEAR DEN SOLAR 1 GI PROJECT #677 2,171 186623 17,571 18662377SOUTH FALLS GI PROJECT #678 3,611 186623 12,396 18662378SOUTH HILLS SOLAR GI PROJECT #680 8,086 186623 (134)18662379BEAR DEN SOLAR II GI PROJECT #682 1,012 186623 18,924 18662380MOON CRATER SOLAR GI PROJECT #573 417 186623 19,583 186623Transmission Service and Generation Interconnection Study CostsLineNo.Description(a)Costs Incurred During Period(b)Account Charged(c)Reimbursements ReceivedDuring the Period(d)Account CreditedWith Reimbursement(e)FERC FORM No. 1 (NEW. 03-07)Page 231
81 BRIDGERS PVS 2 GI PROJECT #683 0 186623 9,814 186623
82 JTA SOLAR 138KV GI PROJECT #684 10,347 186623 (90,000)186623
83 JTA SOLAR 345KV GI PROJECT #685 8,168 186623 11,475 186623
84 MOONSTONE SOLAR GI PROJECT #686 2,157 186623 7,744 186623
85 BOISE BENCH GRID GI PROJECT #688 1,502 186623 18,498 186623
86 DOVE SPRINGS SOLAR GI PROJECT #689 2,347 186623 7,653 186623
87 RUGG SPRINGS SOLAR GI PROJECT #690 10,160 186623 (90,000)186623
88 RUGG SPRINGS WIND GI PROJECT #691 8,884 186623 (90,000)186623
89 MARLIN SOLAR GI PROJECT #692 6,292 186623 13,708 186623
90 RIGGS SOLAR GI PROJECT #693 4,078 186623 15,922 186623
91 SANTIAGO SOLAR GI PROJECT #694 2,988 186623 17,012 186623
92 KCE ID 1 GI PROJECT #696 33,542 186623 (90,000)186623
93 KCE ID 2 GI PROJECT #697 9,637 186623 (40,000)186623
94 KCE ID 3 GI PROJECT #698 3,749 186623 16,251 186623
95 BLUE SPRINGS SOLAR GI PROJECT #704 11,233 186623 (111,233)186623
96 DESERT RIDGE WIND 230KV GI PROJECT #707 8,690 186623 (8,690)186623
97 MOONSTONE ENERGY GI PROJECT #718 3,242 186623 (53,016)186623
98 MOONSTONE ENERGY 2 GI PROJECT #719 3,102 186623 (52,876)186623
99 POWERS BUTTE ENERGY CENTER II GI PROJECT
#720 4,953 186623 (54,953)186623
100 POWERS BUTTE ENERGY CENTER III GI PROJECT
#721 2,170 186623 (52,170)186623
101 POWERS BUTTE ENERGY CENTER V GI PROJECT
#723 2,045 186623 (52,045)186623
102 CLOVER CREEK STORAGE GI PROJECT #728 2,353 186623 (2,353)186623
103 NAMPA WWTP (DER) GI PROJECT #702 1,159 186623 (1,159)186623
104 BLUEBUNCH SOLAR 2 GI PROJECT #711 3,398 186623 (53,398)186623
105 COYOTE SPRING GI PROJECT #713 3,958 186623 (60,000)186623
106 SR BINGHAM GI PROJECT #715 3,712 186623 (53,712)186623
107 JASPER 2 GI PROJECT #716 6,139 186623 (60,000)186623
108 HEMINGWAY RENEWABLE POWER 2 GI PROJECT
#726 2,084 186623 (20,000)186623
109 LANGLEY SUMMER INCREASE GI PROJECT #695 1,828 186623 (1,828)186623
110 POWERS BUTTE ENERGY CENTER IV GI PROJECT
#722 2,050 186623 (52,050)186623
111 POWERS BUTTE ENERGY CENTER VI GI PROJECT
#724 1,925 186623 (51,925)186623
112 TREASURE CANYON SOLAR GI PROJECT #699 2,578 186623 (2,578)186623
113 BRONCO SOLAR GI PROJECT #700 3,015 186623 (3,015)186623
114 GARTER SOLAR GI PROJECT #703 574 186623 (574)186623
115 DESERT RIDGE WIND 138KV GI PROJECT #706 11,791 186623 (57,681)186623
116 HORNSTONE GI PROJECT #708 6,643 186623 (54,421)186623
117 BLACK MESA GI PROJECT #557 ESS STUDY 653 186623 (10,000)186623
118 CRIMSON ORCHARD SOLAR GI PROJECT #604 ESS
STUDY 857 186623 (857)186623
119 STELLAR SOLAR RESTUDY GI PROJECT #648 8,186 186623 (10,000)186623
120 SUNNYSLOPE SOLAR GI PROJECT #732 1,103 186623 (20,000)186623
121 FAREWELL BEND SOLAR GI PROJECT #733 325 186623 (20,000)186623
Transmission Service and Generation Interconnection Study Costs
Line
No.
Description
(a)
Costs Incurred During Period
(b)
Account Charged
(c)
Reimbursements Received
During the Period
(d)
Account Credited
With Reimbursement
(e)
FERC FORM No. 1 (NEW. 03-07)
Page 231
81 BRIDGERS PVS 2 GI PROJECT #683 0 186623 9,814 18662382JTA SOLAR 138KV GI PROJECT #684 10,347 186623 (90,000)18662383JTA SOLAR 345KV GI PROJECT #685 8,168 186623 11,475 18662384MOONSTONE SOLAR GI PROJECT #686 2,157 186623 7,744 18662385BOISE BENCH GRID GI PROJECT #688 1,502 186623 18,498 18662386DOVE SPRINGS SOLAR GI PROJECT #689 2,347 186623 7,653 18662387RUGG SPRINGS SOLAR GI PROJECT #690 10,160 186623 (90,000)18662388RUGG SPRINGS WIND GI PROJECT #691 8,884 186623 (90,000)18662389MARLIN SOLAR GI PROJECT #692 6,292 186623 13,708 18662390RIGGS SOLAR GI PROJECT #693 4,078 186623 15,922 18662391SANTIAGO SOLAR GI PROJECT #694 2,988 186623 17,012 18662392KCE ID 1 GI PROJECT #696 33,542 186623 (90,000)18662393KCE ID 2 GI PROJECT #697 9,637 186623 (40,000)18662394KCE ID 3 GI PROJECT #698 3,749 186623 16,251 18662395BLUE SPRINGS SOLAR GI PROJECT #704 11,233 186623 (111,233)18662396DESERT RIDGE WIND 230KV GI PROJECT #707 8,690 186623 (8,690)18662397MOONSTONE ENERGY GI PROJECT #718 3,242 186623 (53,016)18662398MOONSTONE ENERGY 2 GI PROJECT #719 3,102 186623 (52,876)18662399POWERS BUTTE ENERGY CENTER II GI PROJECT#720 4,953 186623 (54,953)186623100POWERS BUTTE ENERGY CENTER III GI PROJECT#721 2,170 186623 (52,170)186623101POWERS BUTTE ENERGY CENTER V GI PROJECT#723 2,045 186623 (52,045)186623102CLOVER CREEK STORAGE GI PROJECT #728 2,353 186623 (2,353)186623103NAMPA WWTP (DER) GI PROJECT #702 1,159 186623 (1,159)186623104BLUEBUNCH SOLAR 2 GI PROJECT #711 3,398 186623 (53,398)186623105COYOTE SPRING GI PROJECT #713 3,958 186623 (60,000)186623106SR BINGHAM GI PROJECT #715 3,712 186623 (53,712)186623107JASPER 2 GI PROJECT #716 6,139 186623 (60,000)186623108HEMINGWAY RENEWABLE POWER 2 GI PROJECT#726 2,084 186623 (20,000)186623109LANGLEY SUMMER INCREASE GI PROJECT #695 1,828 186623 (1,828)186623110POWERS BUTTE ENERGY CENTER IV GI PROJECT#722 2,050 186623 (52,050)186623111POWERS BUTTE ENERGY CENTER VI GI PROJECT#724 1,925 186623 (51,925)186623112TREASURE CANYON SOLAR GI PROJECT #699 2,578 186623 (2,578)186623113BRONCO SOLAR GI PROJECT #700 3,015 186623 (3,015)186623114GARTER SOLAR GI PROJECT #703 574 186623 (574)186623115DESERT RIDGE WIND 138KV GI PROJECT #706 11,791 186623 (57,681)186623116HORNSTONE GI PROJECT #708 6,643 186623 (54,421)186623117BLACK MESA GI PROJECT #557 ESS STUDY 653 186623 (10,000)186623118CRIMSON ORCHARD SOLAR GI PROJECT #604 ESSSTUDY 857 186623 (857)186623119STELLAR SOLAR RESTUDY GI PROJECT #648 8,186 186623 (10,000)186623120SUNNYSLOPE SOLAR GI PROJECT #732 1,103 186623 (20,000)186623121FAREWELL BEND SOLAR GI PROJECT #733 325 186623 (20,000)186623Transmission Service and Generation Interconnection Study CostsLineNo.Description(a)Costs Incurred During Period(b)Account Charged(c)Reimbursements ReceivedDuring the Period(d)Account CreditedWith Reimbursement(e)FERC FORM No. 1 (NEW. 03-07)Page 231
122 FARELY HILLS SOLAR GI PROJECT #734 325 186623 (20,000)186623
123 STURNELLA SOLAR GI PROJECT #735 255 186623 (20,000)186623
124 SOLSTICE SOLAR GI PROJECT #738 1,547 186623 (10,000)186623
125 AMERICAN FALLS ESC 2 GI PROJECT #705 6,458 186623 (60,000)186623
126 HMWY ESS 3 GI PROJECT #709 4,893 186623 0 186623
127 GEOBELLA GI PROJECT #710 7,258 186623 (60,000)186623
128 FRANKLIN SOLAR GI PROJECT #549 ESS STUDY 709 186623 (10,000)186623
129 BOARDMAN HYBRID GI PROJECT #730 4,577 186623 (20,000)186623
130 KUNA II BESS GI PROJECT #731 5,240 186623 (20,000)186623
131 SR MIDVALE GI PROJECT #741 155 186623 (20,000)186623
132 BLACKBIRD STORAGE GI PROJECT #727 711 186623 (711)186623
133 MOUNTAIN HOME SOLAR (SAMSUNG) GI PROJECT
#729 4,393 186623 (4,393)186623
134 APPALOOSA WIND & SOLAR LOS/OIS STUDIES #590 3,733 186623 (30,000)186623
135 MARIGOLD BESS GI PROJECT #736 355 186623 (20,000)186623
136 MILVA SOLAR GI PROJECT #744 235 186623 (20,000)186623
137 BINTJE BESS GI PROJECT #745 157 186623 (20,000)186623
138 HEMINGWAY RENEWABLE POWER GI PROJECT
#714 1,891 186623 (1,891)186623
139 WESTERN RUSSET HYBRID GI PROJECT #725 1,108 186623 (60,000)186623
140 LIGHTHOUSE ENERGY CENTER GI PROJECT #701 2,918 186623 (2,918)186623
141 HMWY ESS 4 GI PROJECT 717 1,806 186623 (1,806)186623
142 BENNETT 1 SOLAR GI PROJECT #551 ESS STUDY 198 186623 (10,000)186623
143 SR ABERDEEN GI PROJECT #737 0 186623 (10,000)186623
144 JEROME SOLAR GI PROJECT #742 0 186623 (20,000)186623
145 TABOR ROAD SOLAR GI PROJECT #743 0 186623 (20,000)186623
39 Total 1,025,429 836,584
40 Grand Total 1,103,666 755,277
FERC FORM No. 1 (NEW. 03-07)
Page 231
Transmission Service and Generation Interconnection Study Costs
Line
No.
Description
(a)
Costs Incurred During Period
(b)
Account Charged
(c)
Reimbursements Received
During the Period
(d)
Account Credited
With Reimbursement
(e)
This report is:
122 FARELY HILLS SOLAR GI PROJECT #734 325 186623 (20,000)186623123STURNELLA SOLAR GI PROJECT #735 255 186623 (20,000)186623124SOLSTICE SOLAR GI PROJECT #738 1,547 186623 (10,000)186623125AMERICAN FALLS ESC 2 GI PROJECT #705 6,458 186623 (60,000)186623126HMWY ESS 3 GI PROJECT #709 4,893 186623 0 186623127GEOBELLA GI PROJECT #710 7,258 186623 (60,000)186623128FRANKLIN SOLAR GI PROJECT #549 ESS STUDY 709 186623 (10,000)186623129BOARDMAN HYBRID GI PROJECT #730 4,577 186623 (20,000)186623130KUNA II BESS GI PROJECT #731 5,240 186623 (20,000)186623131SR MIDVALE GI PROJECT #741 155 186623 (20,000)186623132BLACKBIRD STORAGE GI PROJECT #727 711 186623 (711)186623133MOUNTAIN HOME SOLAR (SAMSUNG) GI PROJECT#729 4,393 186623 (4,393)186623134APPALOOSA WIND & SOLAR LOS/OIS STUDIES #590 3,733 186623 (30,000)186623135MARIGOLD BESS GI PROJECT #736 355 186623 (20,000)186623136MILVA SOLAR GI PROJECT #744 235 186623 (20,000)186623137BINTJE BESS GI PROJECT #745 157 186623 (20,000)186623138HEMINGWAY RENEWABLE POWER GI PROJECT#714 1,891 186623 (1,891)186623139WESTERN RUSSET HYBRID GI PROJECT #725 1,108 186623 (60,000)186623140LIGHTHOUSE ENERGY CENTER GI PROJECT #701 2,918 186623 (2,918)186623141HMWY ESS 4 GI PROJECT 717 1,806 186623 (1,806)186623142BENNETT 1 SOLAR GI PROJECT #551 ESS STUDY 198 186623 (10,000)186623143SR ABERDEEN GI PROJECT #737 0 186623 (10,000)186623144JEROME SOLAR GI PROJECT #742 0 186623 (20,000)186623145TABOR ROAD SOLAR GI PROJECT #743 0 186623 (20,000)18662339Total1,025,429 836,58440Grand Total 1,103,666 755,277FERC FORM No. 1 (NEW. 03-07)Page 231Transmission Service and Generation Interconnection Study CostsLineNo.Description(a)Costs Incurred During Period(b)Account Charged(c)Reimbursements ReceivedDuring the Period(d)Account CreditedWith Reimbursement(e)
This report is:
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original
(2) ☐ A Resubmission
Date of Report:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
FOOTNOTE DATA
(a) Concept: StudyCostsReimbursements
Amounts in column (d) represent both reimbursements received (credits amounts) and refunds back to the counterparty (debit amounts). Refunds are initiated when studies are complete and
the initial deposit exceeds the final expenses.
FERC FORM No. 1 (NEW. 03-07)
Page 231
This report is:
Name of Respondent:Idaho Power Company This report is:(1) ☑ An Original(2) ☐ A Resubmission Date of Report:04/16/2024 Year/Period of ReportEnd of: 2023/ Q4FOOTNOTE DATA(a) Concept: StudyCostsReimbursementsAmounts in column (d) represent both reimbursements received (credits amounts) and refunds back to the counterparty (debit amounts). Refunds are initiated when studies are complete andthe initial deposit exceeds the final expenses.FERC FORM No. 1 (NEW. 03-07)Page 231
This report is:
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original
(2) ☐ A Resubmission
Date of Report:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
OTHER REGULATORY ASSETS (Account 182.3)
CREDITS CREDITS
Line
No.
Description and Purpose of Other
Regulatory Assets
(a)
Balance at Beginning of
Current Quarter/Year
(b)
Debits
(c)
Written off During
Quarter/Year
Account
Charged
(d)
Written off During the
Period Amount
(e)
Balance at end of Current
Quarter/Year
(f)
1 Fixed Cost Adjustment (FCA) (182302)24,859,074 36,037,108 1823 24,859,074 36,037,108
2 IPUC Order Pending (Amort period 06/23
thru 05/24)0 0
3 COVID Incremental Expenses-ID (182303)460,869 401 460,869 0
4 IPUC Order #34718 0 0
5 Arrearage Management Program-OR
(182304)305,413 2,941 401 240,368 67,986
6 OPUC Order #20-377 0 0
7
(a)
AOCI Impact of Unfunded Pension Liability (13,046,719)2283 8,000,002 (21,046,721)
8 IPUC Order #30256 (182320)0 0
9 FCA Calendar Mo Adjustment (182308)1,317,707 2,828,425 400 4,146,132
10 Prior Year FCA (182309)15,724,226 400 4,622,474 11,101,752
11 IPUC Order #35799 (Amort period 06/23 thru
05/24)0 0
12 ID Intervenor Funding Amort (182388)0 268,376 400 268,376
13 IPUC Order #36042 (Amort period 01/24 thru
12/30)0 0
14 AOCI Impact of Unfunded Pension Liability 83,300,319 25,071,050 2283 6,244 108,365,125
15 IPUC Order #30256 (182320)0 0
16 Deferred Pension Expense Net of
Contributions 28,855,121 18,535,298 1823 45,890,678 1,499,741
17 IPUC Order #30333 (182321)0 0
18 FAS 109 Unfunded (182322)526,069,263 49,370,829 575,440,092
19 Accum Deferred Income Noncurrent 0 0
20 Idaho Pension Cash - IPUC Order #32248
(182327)220,648,422 50,248,936 Various 17,153,713 253,743,645
21 Amort period 06/11 thru indefinite 0 0
22 Mark- to Market Short Term (182330)3,515,949 38,985,630 42,501,579
23 Oregon Pension Expense Capitalized
(182339)7,000,878 330,303 4073 234,346 7,096,835
24 OPUC Order #10-064 0 0
25 Asset Retirement Obligations (182341)28,780,382 6,489,937 35,270,319
26 IPUC Order #29414; OPUC Order #04-585 0 0
27 RA-Hells Canyon-Baker Co (182360)313,506 313,506
28 IPUC Order #33948 0 0
29 Oregon Corporate Activity Tax (182355)434,255 369,914 Various 309,039 495,130
30 OPUC Order #20-397 0 0
31 Oregon Community Solar (182378)219,285 53,369 272,654
32 OPUC Order #16-410 0 0
33 Intervenor Funding-Idaho (182387)290,956 1823 290,956 0
34 Multiple IPUC Orders 0 0
35 RA-CONTRA-DEF INC TAX (182389)213,619,773 282 14,387,498 199,232,275
36 Langley Revenue Accrual (182398)746,857 15,025 4073 369,172 392,710
37 OPUC Order #12-226 0 0
Name of Respondent:Idaho Power Company This report is:(1) ☑ An Original(2) ☐ A Resubmission Date of Report:04/16/2024 Year/Period of ReportEnd of: 2023/ Q4OTHER REGULATORY ASSETS (Account 182.3)CREDITS CREDITSLineNo.Description and Purpose of OtherRegulatory Assets(a)Balance at Beginning ofCurrent Quarter/Year(b)Debits(c)Written off DuringQuarter/YearAccountCharged(d)Written off During thePeriod Amount(e)Balance at end of CurrentQuarter/Year(f)1 Fixed Cost Adjustment (FCA) (182302)24,859,074 36,037,108 1823 24,859,074 36,037,1082IPUC Order Pending (Amort period 06/23thru 05/24)0 03COVID Incremental Expenses-ID (182303)460,869 401 460,869 04IPUC Order #34718 0 05Arrearage Management Program-OR(182304)305,413 2,941 401 240,368 67,9866OPUC Order #20-377 0 07(a)AOCI Impact of Unfunded Pension Liability (13,046,719)2283 8,000,002 (21,046,721)8 IPUC Order #30256 (182320)0 09FCA Calendar Mo Adjustment (182308)1,317,707 2,828,425 400 4,146,13210Prior Year FCA (182309)15,724,226 400 4,622,474 11,101,75211IPUC Order #35799 (Amort period 06/23 thru05/24)0 012ID Intervenor Funding Amort (182388)0 268,376 400 268,37613IPUC Order #36042 (Amort period 01/24 thru12/30)0 014AOCI Impact of Unfunded Pension Liability 83,300,319 25,071,050 2283 6,244 108,365,12515IPUC Order #30256 (182320)0 016Deferred Pension Expense Net ofContributions 28,855,121 18,535,298 1823 45,890,678 1,499,74117IPUC Order #30333 (182321)0 018FAS 109 Unfunded (182322)526,069,263 49,370,829 575,440,09219Accum Deferred Income Noncurrent 0 020Idaho Pension Cash - IPUC Order #32248(182327)220,648,422 50,248,936 Various 17,153,713 253,743,64521Amort period 06/11 thru indefinite 0 022Mark- to Market Short Term (182330)3,515,949 38,985,630 42,501,57923Oregon Pension Expense Capitalized(182339)7,000,878 330,303 4073 234,346 7,096,83524OPUC Order #10-064 0 025Asset Retirement Obligations (182341)28,780,382 6,489,937 35,270,31926IPUC Order #29414; OPUC Order #04-585 0 027RA-Hells Canyon-Baker Co (182360)313,506 313,50628IPUC Order #33948 0 029Oregon Corporate Activity Tax (182355)434,255 369,914 Various 309,039 495,13030OPUC Order #20-397 0 031Oregon Community Solar (182378)219,285 53,369 272,65432OPUC Order #16-410 0 033Intervenor Funding-Idaho (182387)290,956 1823 290,956 034Multiple IPUC Orders 0 035RA-CONTRA-DEF INC TAX (182389)213,619,773 282 14,387,498 199,232,27536Langley Revenue Accrual (182398)746,857 15,025 4073 369,172 392,71037OPUC Order #12-226 0 0
38 RA-OR LANGLEY REV INT RES (182399)(106,798)58,254 (48,544)
39
Siemens Long Term Deferred Rate Base
(182410)8,612,493 4073 431,488 8,181,005
40 IPUC Order #33420 (Amort period 01/16 thru
12/43)0 0
41 Siemens Long Term Deferred Rate Based
(182411)12,851,572 4073 643,867 12,207,705
42 IPUC Order #33420 (Amort period 01/16 thru
12/43)0 0
43 Siemens Long Term Deferred Rate Base
(182412)360,013 27,341 4073 44,047 343,307
44 OPUC Order #15-387 (Amort period 01/16
thru 12/36)0 0
45 Siemens Long Term Deferred Rate Based
(182413)511,105 4073 39,316 471,789
46 OPUC Order #15-387 (Amort period 01/16
thru 12/36)0 0
47 Siemens Long Term Interest Reserve
(182414)(221,464)4190 27,340 (248,804)
48 Valmy O&M ID (182432)3,864,208 3,056,654 6,920,862
49 IPUC Order #33771 0 0
50 Valmy Acctg Adj ID (182435)88,310,313 400 9,745,585 78,564,728
51 IPUC Order #33771 0 0
52 Valmy Decomm Oregon (182436)194,153 4,305 400 290,202 (91,744)
53 OPUC Order #17-235 (Amort period 06/17
thru 12/25)0 0
54 Idaho DSM Rider 3,767,319 254 3,767,319 0
55 IPUC Order#28661 0 0
56 COVID Incremental Expenses-OR (182305)63,736 401 63,736 0
57 OPUC Order #20-377 0 0
58 PCA Deferral Idaho (multiple 182 accounts)128,239,506 61,660,460 Various 74,351,334 115,548,632
59 IPUC Order Pending (Amort period 06/23
thru 05/25)0 0
60 Mark-to-Market Long Term (182333)3,271,995 244 1,524,437 1,747,558
61
(b)
ID Valmy Collections (182430)(1,621,386)400 855,148 (2,476,534)
62 IPUC Order #33771 0 0
63 Wildfire Mitigation-ID (182310)27,078,227 24,651,249 1823 27,078,227 24,651,249
64 IPUC Order #35077 0 0
65 Cloud Computing (182315)1,616,918 4073 366,835 1,250,083
66 IPUC Order #34707 0 0
67 Bridger Decommissioning (multiple 182
accounts)80,531,163 43,100,737 123,631,900
68 IPUC Order #35423 0
69 Oregon PCAM (182384)1,120,595 254 1,120,595 0
70 OPUC Order pending 0
71 Wildfire Mitigation Amort (182311)0 26,678,227 26,678,227
72 IPUC Order #36042 (Amort period 01/24-
12/30)
73 Minor items (4)101,702 98,403 Various 209,447 (9,342)
OTHER REGULATORY ASSETS (Account 182.3)
CREDITS CREDITS
Line
No.
Description and Purpose of Other
Regulatory Assets
(a)
Balance at Beginning of
Current Quarter/Year
(b)
Debits
(c)
Written off During
Quarter/Year
Account
Charged
(d)
Written off During the
Period Amount
(e)
Balance at end of Current
Quarter/Year
(f)
38 RA-OR LANGLEY REV INT RES (182399)(106,798)58,254 (48,544)39 Siemens Long Term Deferred Rate Base(182410)8,612,493 4073 431,488 8,181,00540IPUC Order #33420 (Amort period 01/16 thru12/43)0 041Siemens Long Term Deferred Rate Based(182411)12,851,572 4073 643,867 12,207,70542IPUC Order #33420 (Amort period 01/16 thru12/43)0 043Siemens Long Term Deferred Rate Base(182412)360,013 27,341 4073 44,047 343,30744OPUC Order #15-387 (Amort period 01/16thru 12/36)0 045Siemens Long Term Deferred Rate Based(182413)511,105 4073 39,316 471,78946OPUC Order #15-387 (Amort period 01/16thru 12/36)0 047Siemens Long Term Interest Reserve(182414)(221,464)4190 27,340 (248,804)48 Valmy O&M ID (182432)3,864,208 3,056,654 6,920,86249IPUC Order #33771 0 050Valmy Acctg Adj ID (182435)88,310,313 400 9,745,585 78,564,72851IPUC Order #33771 0 052Valmy Decomm Oregon (182436)194,153 4,305 400 290,202 (91,744)53 OPUC Order #17-235 (Amort period 06/17thru 12/25)0 054Idaho DSM Rider 3,767,319 254 3,767,319 055IPUC Order#28661 0 056COVID Incremental Expenses-OR (182305)63,736 401 63,736 057OPUC Order #20-377 0 058PCA Deferral Idaho (multiple 182 accounts)128,239,506 61,660,460 Various 74,351,334 115,548,63259IPUC Order Pending (Amort period 06/23thru 05/25)0 060Mark-to-Market Long Term (182333)3,271,995 244 1,524,437 1,747,55861(b)ID Valmy Collections (182430)(1,621,386)400 855,148 (2,476,534)62 IPUC Order #33771 0 063Wildfire Mitigation-ID (182310)27,078,227 24,651,249 1823 27,078,227 24,651,24964IPUC Order #35077 0 065Cloud Computing (182315)1,616,918 4073 366,835 1,250,08366IPUC Order #34707 0 067Bridger Decommissioning (multiple 182accounts)80,531,163 43,100,737 123,631,90068IPUC Order #35423 069Oregon PCAM (182384)1,120,595 254 1,120,595 070OPUC Order pending 071Wildfire Mitigation Amort (182311)0 26,678,227 26,678,22772IPUC Order #36042 (Amort period 01/24-12/30)73 Minor items (4)101,702 98,403 Various 209,447 (9,342)OTHER REGULATORY ASSETS (Account 182.3)CREDITS CREDITSLineNo.Description and Purpose of OtherRegulatory Assets(a)Balance at Beginning ofCurrent Quarter/Year(b)Debits(c)Written off DuringQuarter/YearAccountCharged(d)Written off During thePeriod Amount(e)Balance at end of CurrentQuarter/Year(f)
74 OR Rate Mitigation (182301)0 35,567 35,567
75 OPUC Order #23-055
76 OR Annual Reg Expense (182340)0 223,267 401 61,511 161,756
77 OPUC Order #23-185
78 WRAP Deferral (182345)0 270,156 270,156
79 IPUC Order #35920
44 TOTAL 1,501,960,906 388,471,761 237,444,867 1,652,987,800
FERC FORM No. 1 (REV. 02-04)
Page 232
OTHER REGULATORY ASSETS (Account 182.3)
CREDITS CREDITS
Line
No.
Description and Purpose of Other
Regulatory Assets
(a)
Balance at Beginning of
Current Quarter/Year
(b)
Debits
(c)
Written off During
Quarter/Year
Account
Charged
(d)
Written off During the
Period Amount
(e)
Balance at end of Current
Quarter/Year
(f)
This report is:
74 OR Rate Mitigation (182301)0 35,567 35,56775OPUC Order #23-05576OR Annual Reg Expense (182340)0 223,267 401 61,511 161,75677OPUC Order #23-18578WRAP Deferral (182345)0 270,156 270,15679IPUC Order #3592044TOTAL 1,501,960,906 388,471,761 237,444,867 1,652,987,800FERC FORM No. 1 (REV. 02-04)Page 232OTHER REGULATORY ASSETS (Account 182.3)CREDITS CREDITSLineNo.Description and Purpose of OtherRegulatory Assets(a)Balance at Beginning ofCurrent Quarter/Year(b)Debits(c)Written off DuringQuarter/YearAccountCharged(d)Written off During thePeriod Amount(e)Balance at end of CurrentQuarter/Year(f)
This report is:
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original
(2) ☐ A Resubmission
Date of Report:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
FOOTNOTE DATA
(a) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets
Regulatory Asset is in a credit position, but is netted with the other Postretirement regulatory accounts for presentation as a net Regulatory Asset on the year-end financial statements.
(b) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets
Regulatory asset is in a credit position, but it is netted against other Valmy related regulatory asset accounts for a net Regulatory Asset on the year-end financial statements.
FERC FORM No. 1 (REV. 02-04)
Page 232
This report is:
Name of Respondent:Idaho Power Company This report is:(1) ☑ An Original(2) ☐ A Resubmission Date of Report:04/16/2024 Year/Period of ReportEnd of: 2023/ Q4FOOTNOTE DATA(a) Concept: DescriptionAndPurposeOfOtherRegulatoryAssetsRegulatory Asset is in a credit position, but is netted with the other Postretirement regulatory accounts for presentation as a net Regulatory Asset on the year-end financial statements.(b) Concept: DescriptionAndPurposeOfOtherRegulatoryAssetsRegulatory asset is in a credit position, but it is netted against other Valmy related regulatory asset accounts for a net Regulatory Asset on the year-end financial statements.FERC FORM No. 1 (REV. 02-04)Page 232
This report is:
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original
(2) ☐ A Resubmission
Date of Report:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
MISCELLANEOUS DEFFERED DEBITS (Account 186)
CREDITS CREDITS
Line
No.
Description of Miscellaneous Deferred
Debits
(a)
Balance at Beginning of
Year
(b)
Debits
(c)
Credits Account
Charged
(d)
Credits Amount
(e)
Balance at End of Year
(f)
1 Prepaid Credit Facility (186025)853,960 1,281,371 Various 665,479 1,469,852
2 Amortization period 12/19-12/26
3 Prepaid Services (LT) (186052)2,746,459 2,503,089 5,249,548
4 Amortization periods - multiple
5 Workers Compensation (186121)843,045 321,714 1,164,759
6 Prepaid ROW (LT) (186160)443,052 401 43,902 399,150
7 Amortization periods - multiple
8 CARB Inventory (186650)802,237 344,363 242 124,349 1,022,251
9 Coal Royalties/Fly Ash (186709)714,017 151 223,007 491,010
10 Stable Value Life Inv (186719)63,965,819 8,121,550 72,087,369
11 Security Plan Net Insurance Asset 186720 5,658,503 106,992 4262 304,920 5,460,575
12 Retiree Medical-COLI (186726)4,319,757 172,863 4262 2,820 4,489,800
13 American Falls Water Rts (186727)2,170,852 401 1,042,009 1,128,843
14 Amortization period 01/06-02/25
15 American Falls Bond Refi (186770)103,999 401 47,999 56,000
16 Amortization period 12/09-02/25
17 Regulatory Reserves (186800)(4,460,868)Various 7,111,997 (11,572,865)
18 Prepaid Service Contract (186255)0 128,984 128,984
19 Amortization periods - multiple
20 Minor Items (5)248,063 17,786,035 Various 17,917,586 116,512
47 Miscellaneous Work in Progress
48 Deferred Regulatory Comm. Expenses (See
pages 350 - 351)
49 TOTAL 78,408,895 81,691,788
FERC FORM No. 1 (ED. 12-94)
Page 233
This report is:
Name of Respondent:Idaho Power Company This report is:(1) ☑ An Original(2) ☐ A Resubmission Date of Report:04/16/2024 Year/Period of ReportEnd of: 2023/ Q4MISCELLANEOUS DEFFERED DEBITS (Account 186)CREDITS CREDITSLineNo.Description of Miscellaneous DeferredDebits(a)Balance at Beginning ofYear(b)Debits(c)Credits AccountCharged(d)Credits Amount(e)Balance at End of Year(f)1 Prepaid Credit Facility (186025)853,960 1,281,371 Various 665,479 1,469,8522Amortization period 12/19-12/263Prepaid Services (LT) (186052)2,746,459 2,503,089 5,249,5484Amortization periods - multiple5Workers Compensation (186121)843,045 321,714 1,164,7596Prepaid ROW (LT) (186160)443,052 401 43,902 399,1507Amortization periods - multiple8CARB Inventory (186650)802,237 344,363 242 124,349 1,022,2519Coal Royalties/Fly Ash (186709)714,017 151 223,007 491,01010Stable Value Life Inv (186719)63,965,819 8,121,550 72,087,36911Security Plan Net Insurance Asset 186720 5,658,503 106,992 4262 304,920 5,460,57512Retiree Medical-COLI (186726)4,319,757 172,863 4262 2,820 4,489,80013American Falls Water Rts (186727)2,170,852 401 1,042,009 1,128,84314Amortization period 01/06-02/2515American Falls Bond Refi (186770)103,999 401 47,999 56,00016Amortization period 12/09-02/2517Regulatory Reserves (186800)(4,460,868)Various 7,111,997 (11,572,865)18 Prepaid Service Contract (186255)0 128,984 128,98419Amortization periods - multiple20Minor Items (5)248,063 17,786,035 Various 17,917,586 116,51247Miscellaneous Work in Progress48Deferred Regulatory Comm. Expenses (Seepages 350 - 351)49 TOTAL 78,408,895 81,691,788FERC FORM No. 1 (ED. 12-94)Page 233
This report is:
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original
(2) ☐ A Resubmission
Date of Report:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
ACCUMULATED DEFERRED INCOME TAXES (Account 190)
Line No.Description and Location
(a)
Balance at Beginning of Year
(b)
Balance at End of Year
(c)
1 Electric
2 Unrealized Loss on Investments 259 1,031
3 Tax Reform Regulatory Stipulation 8,440,979 10,525,372
4 Postretirement Benefits 396,050 419,294
5 Deferred Idaho ITC 35,334,005 39,290,035
6 USBR-American Falls O&M Costs Settlement 28,489 193,316
7 Non-VEBA Pension and Benefits Non-VEBA Pension and Benefits (804,568)(883,710)
8 Executive Deferred Compensation 90,889 113,697
9 Stock Based Compensation 3,184,240 2,929,524
10 Pension Expense-Oregon 4,456,667 4,649,465
11 Asset Retirement Obligation (ARO)1,533,029 1,575,094
12 Incentive Deferral-Profit Sharing-Not in Rates 3,882,562 4,163,668
13 Rate Case Disallowance 963,150 886,883
14 Revenue Sharing 146,402
15 Customer Advances 2,563,899 5,144,319
16 Covid Deferral 49,900 (95,019)
17 Bridger Revenue Deferral 1,114,435 1,005,079
18 OR Reconnect Fees Adv 3,262 3,787
19 Prov for Rate Refund - HC Relicensing (AFUDC)53,417,595 58,859,700
20 Soft Cap Battery Reserve 720,720
21 VEBA-Post Retirement Benefits 12,042,335 12,151,690
22 PCA Coal Usage Reserve 2,934,360
7 Other 117,542,752 (a)137,107,166
8 TOTAL Electric (Enter Total of lines 2 thru 7)245,107,051 280,974,751
9 Gas
15 Other
16 TOTAL Gas (Enter Total of lines 10 thru 15)
17.1
(b)
Other Non Electric (See footnote)21,298,737 21,322,855
17 Other (Specify)
18 TOTAL (Acct 190) (Total of lines 8, 16 and 17)266,405,788 302,297,606
FERC FORM NO. 1 (ED. 12-88)
Page 234
Notes
This report is:
Name of Respondent:Idaho Power Company This report is:(1) ☑ An Original(2) ☐ A Resubmission Date of Report:04/16/2024 Year/Period of ReportEnd of: 2023/ Q4ACCUMULATED DEFERRED INCOME TAXES (Account 190)Line No.Description and Location(a)Balance at Beginning of Year(b)Balance at End of Year(c)1 Electric2Unrealized Loss on Investments 259 1,0313Tax Reform Regulatory Stipulation 8,440,979 10,525,3724Postretirement Benefits 396,050 419,2945Deferred Idaho ITC 35,334,005 39,290,0356USBR-American Falls O&M Costs Settlement 28,489 193,3167Non-VEBA Pension and Benefits Non-VEBA Pension and Benefits (804,568)(883,710)8 Executive Deferred Compensation 90,889 113,6979Stock Based Compensation 3,184,240 2,929,52410Pension Expense-Oregon 4,456,667 4,649,46511Asset Retirement Obligation (ARO)1,533,029 1,575,09412Incentive Deferral-Profit Sharing-Not in Rates 3,882,562 4,163,66813Rate Case Disallowance 963,150 886,88314Revenue Sharing 146,40215Customer Advances 2,563,899 5,144,31916Covid Deferral 49,900 (95,019)17 Bridger Revenue Deferral 1,114,435 1,005,07918OR Reconnect Fees Adv 3,262 3,78719Prov for Rate Refund - HC Relicensing (AFUDC)53,417,595 58,859,70020Soft Cap Battery Reserve 720,72021VEBA-Post Retirement Benefits 12,042,335 12,151,69022PCA Coal Usage Reserve 2,934,3607Other117,542,752 (a)137,107,1668TOTAL Electric (Enter Total of lines 2 thru 7)245,107,051 280,974,7519Gas15Other16TOTAL Gas (Enter Total of lines 10 thru 15)17.1 (b)Other Non Electric (See footnote)21,298,737 21,322,85517Other (Specify)18 TOTAL (Acct 190) (Total of lines 8, 16 and 17)266,405,788 302,297,606FERC FORM NO. 1 (ED. 12-88)Page 234Notes
This report is:
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original
(2) ☐ A Resubmission
Date of Report:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
FOOTNOTE DATA
(a) Concept: AccumulatedDeferredIncomeTaxes
Line No.: 7 Beginning Balance Ending Balance
Pension-FAS 158 21,441,502 27,893,183
Regulatory Liability-FAS 109 94,945,955 108,640,557
Minimum Pension Liability 4,513,521 5,990,852
Postretirement Plan-FAS 158 (3,358,226)(5,417,426)
Total Other 117,542,752 137,107,166
(b) Concept: DescriptionOfAccumulatedDeferredIncomeTax
Line No.: 17 Beginning Balance Ending Balance
CIAC as Taxable inc Closed to nonutility Plant 78,534 78,534
Senior Management Security Plan 21,220,203 21,244,321
Total Non Electric 21,298,737 21,322,855
FERC FORM NO. 1 (ED. 12-88)
Page 234
This report is:
Name of Respondent:Idaho Power Company This report is:(1) ☑ An Original(2) ☐ A Resubmission Date of Report:04/16/2024 Year/Period of ReportEnd of: 2023/ Q4FOOTNOTE DATA(a) Concept: AccumulatedDeferredIncomeTaxesLine No.: 7 Beginning Balance Ending BalancePension-FAS 158 21,441,502 27,893,183Regulatory Liability-FAS 109 94,945,955 108,640,557Minimum Pension Liability 4,513,521 5,990,852Postretirement Plan-FAS 158 (3,358,226)(5,417,426)Total Other 117,542,752 137,107,166(b) Concept: DescriptionOfAccumulatedDeferredIncomeTaxLine No.: 17 Beginning Balance Ending BalanceCIAC as Taxable inc Closed to nonutility Plant 78,534 78,534Senior Management Security Plan 21,220,203 21,244,321Total Non Electric 21,298,737 21,322,855FERC FORM NO. 1 (ED. 12-88)Page 234
This report is:
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original
(2) ☐ A Resubmission
Date of Report:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
CAPITAL STOCKS (Account 201 and 204)
Line
No.
Class and Series of Stock and Name of
Stock Series
(a)
Number of Shares
Authorized by Charter
(b)
Par or Stated Value per
Share
(c)
Call Price at End of Year
(d)
Outstanding per Bal.
Sheet (Total amount
outstanding without
reduction for amounts
held by respondent)
Shares
(e)
Outstanding per Bal.
Sheet (Total amount
outstanding without
reduction for amounts
held by respondent)
Amount
(f)
1 Common Stock (Account 201)
2 Account 201
3 Common Stock all of which is held by
IdaCorp, Inc. and not traded 50,000,000 2.5 39,150,812 97,877,030
4 Account 204 - None
12 Total 50,000,000 39,150,812 97,877,030
13 Preferred Stock (Account 204)
14
15
16
17 Total 0
1 Capital Stock (Accounts 201 and 204) -
Data Conversion
2
3
4
5 Total
FERC FORM NO. 1 (ED. 12-91)
Page 250-251
CAPITAL STOCKS (Account 201 and 204)
Name of Respondent:Idaho Power Company This report is:(1) ☑ An Original(2) ☐ A Resubmission Date of Report:04/16/2024 Year/Period of ReportEnd of: 2023/ Q4CAPITAL STOCKS (Account 201 and 204)LineNo.Class and Series of Stock and Name ofStock Series(a)Number of SharesAuthorized by Charter(b)Par or Stated Value perShare(c)Call Price at End of Year(d)Outstanding per Bal.Sheet (Total amountoutstanding withoutreduction for amountsheld by respondent)Shares(e)Outstanding per Bal.Sheet (Total amountoutstanding withoutreduction for amountsheld by respondent)Amount(f)1 Common Stock (Account 201)2 Account 2013Common Stock all of which is held byIdaCorp, Inc. and not traded 50,000,000 2.5 39,150,812 97,877,0304Account 204 - None12Total 50,000,000 39,150,812 97,877,03013Preferred Stock (Account 204)14151617 Total 01Capital Stock (Accounts 201 and 204) -Data Conversion2345TotalFERC FORM NO. 1 (ED. 12-91)Page 250-251
CAPITAL STOCKS (Account 201 and 204)CAPITAL STOCKS (Account 201 and 204)
Line
No.
Held by Respondent As Reacquired
Stock (Acct 217) Shares
(g)
Held by Respondent As Reacquired
Stock (Acct 217) Cost
(h)
Held by Respondent In Sinking and Other
Funds Shares
(i)
Held by Respondent In Sinking and Other
Funds Amount
(j)
1
2
3
4
12
13
14
15
16
17
1
2
3
4
5
FERC FORM NO. 1 (ED. 12-91)
Page 250-251
This report is:
CAPITAL STOCKS (Account 201 and 204)LineNo.Held by Respondent As ReacquiredStock (Acct 217) Shares(g)Held by Respondent As ReacquiredStock (Acct 217) Cost(h)Held by Respondent In Sinking and OtherFunds Shares(i)Held by Respondent In Sinking and OtherFunds Amount(j)123412131415161712345FERC FORM NO. 1 (ED. 12-91)Page 250-251
This report is:
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original
(2) ☐ A Resubmission
Date of Report:
2024-04-16
Year/Period of Report
End of: 2023/ Q4
Other Paid-in Capital
Line No.Item
(a)
Amount
(b)
1 Donations Received from Stockholders (Account 208)
2 Beginning Balance Amount 0
3 Increases (Decreases) from Sales of Donations Received from Stockholders
4 Ending Balance Amount 0
5 Reduction in Par or Stated Value of Capital Stock (Account 209)
6 Beginning Balance Amount 0
7 Increases (Decreases) Due to Reductions in Par or Stated Value of Capital Stock
8 Ending Balance Amount 0
9 Gain or Resale or Cancellation of Reacquired Capital Stock (Account 210)
10 Beginning Balance Amount 0
11 Increases (Decreases) from Gain or Resale or Cancellation of Reacquired Capital Stock
12 Ending Balance Amount 0
13 Miscellaneous Paid-In Capital (Account 211)
14 Beginning Balance Amount 0
15 Increases (Decreases) Due to Miscellaneous Paid-In Capital
16 Ending Balance Amount 0
17 Historical Data - Other Paid in Capital
18 Beginning Balance Amount 0
19 Increases (Decreases) in Other Paid-In Capital
20 Ending Balance Amount 0
40 Total 0
FERC FORM No. 1 (ED. 12-87)
Page 253
This report is:
Name of Respondent:Idaho Power Company This report is:(1) ☑ An Original(2) ☐ A Resubmission Date of Report:2024-04-16 Year/Period of ReportEnd of: 2023/ Q4Other Paid-in CapitalLine No.Item(a)Amount(b)1 Donations Received from Stockholders (Account 208)2 Beginning Balance Amount 03Increases (Decreases) from Sales of Donations Received from Stockholders4Ending Balance Amount 05Reduction in Par or Stated Value of Capital Stock (Account 209)6 Beginning Balance Amount 07Increases (Decreases) Due to Reductions in Par or Stated Value of Capital Stock8Ending Balance Amount 09Gain or Resale or Cancellation of Reacquired Capital Stock (Account 210)10 Beginning Balance Amount 011Increases (Decreases) from Gain or Resale or Cancellation of Reacquired Capital Stock12Ending Balance Amount 013Miscellaneous Paid-In Capital (Account 211)14 Beginning Balance Amount 015Increases (Decreases) Due to Miscellaneous Paid-In Capital16Ending Balance Amount 017Historical Data - Other Paid in Capital18Beginning Balance Amount 019Increases (Decreases) in Other Paid-In Capital20Ending Balance Amount 040Total0FERC FORM No. 1 (ED. 12-87)Page 253
This report is:
Name of Respondent:
Idaho Power Company
(1) ☑ An Original
(2) ☐ A Resubmission
Date of Report:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
CAPITAL STOCK EXPENSE (Account 214)
Line No.Class and Series of Stock
(a)
Balance at End of Year
(b)
1 Common Stock 2,096,925
22 TOTAL 2,096,925
FERC FORM No. 1 (ED. 12-87)
Page 254b
Name of Respondent:
This report is:
Date of Report:Year/Period of Report
Name of Respondent:Idaho Power Company (1) ☑ An Original(2) ☐ A Resubmission Date of Report:04/16/2024 Year/Period of ReportEnd of: 2023/ Q4CAPITAL STOCK EXPENSE (Account 214)Line No.Class and Series of Stock(a)Balance at End of Year(b)1 Common Stock 2,096,92522TOTAL2,096,925FERC FORM No. 1 (ED. 12-87)Page 254b
Name of Respondent:
This report is:
Date of Report:Year/Period of ReportName of Respondent:
Idaho Power Company
(1) ☑ An Original
(2) ☐ A Resubmission
Date of Report:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
LONG-TERM DEBT (Account 221, 222, 223 and 224)
Line
No.
Class and Series of Obligation, Coupon
Rate (For new issue, give commission
Authorization numbers and dates)
(a)
Related
Account
Number
(b)
Principal Amount of
Debt Issued
(c)
Total Expense, Premium
or Discount
(d)
Total Expense
(e)
Total Premium
(f)
Total
Discount
(g)
1 Bonds (Account 221)
2 4.00% Series due 2043 221101 75,000,000 741,728 194,250
3 2.50% Series due 2023 221102 75,000,000 647,978 374,250
4 3.65% Series Due 2045 221107 250,000,000 2,559,510 1,715,000
5 4.20% Series Due 2048 221110 (a)450,000,000 4,629,516 (31,654,900)814,000
6 4.99% PRP Due 2032 221111 23,000,000 169,158 0 0
7 5.06% PRP Due 2042 221112 25,000,000 183,842 0 0
8 5.06% PRP Due 2043 221113 60,000,000 441,200 0 0
9 5.20% PRP Due 2053 221114 62,000,000 455,883 0 0
10 5.875% Series due 2034 221116 55,000,000 585,759 748,000
11 6.00% Series due 2032 221133 100,000,000 1,191,216 544,000
12 5.30% Series Due 2035 221134 60,000,000 3,849,739 408,600
13 5.50% Series due 2033 221135 70,000,000 728,701 36,400
14 6.30% Series due 2037 221141 140,000,000 1,500,031 278,600
15 6.25% Series due 2037 221142 100,000,000 1,227,490 268,000
16 5.50% Series due 2034 221145 50,000,000 524,419 383,500
17 4.85% Series Due 2040 221146 100,000,000 1,284,871 170,000
18 4.30% Series Due 2042 221147 75,000,000 802,240 49,500
19 4.05% Series Due 2046 221148 120,000,000 1,321,383 309,600
20 1.90% Series Due 2030 221149 80,000,000 980,949 328,000
21 5.50% Series Due 2053 221222 400,000,000 4,381,222 3,772,000
22 Humboldt 1.45 % Variable due 2024 221325 49,800,000 396,278 0 0
23 5.80% Series Due 2054 221333 350,000,000 3,769,611 3,234,000
24 Sweetwater 1.7% Variable due 2026 221335 116,300,000 908,982 0 0
25 Subtotal 2,886,100,000 33,281,706 (31,654,900)13,627,700
26 Reacquired Bonds (Account 222)
27
28
29
30 Subtotal
31 Advances from Associated Companies
(Account 223)
32
33
34
35 Subtotal
36 Other Long Term Debt (Account 224)
37 AM FALLS BOND OBLIG 224200 19,885,000 309,011
38 MULTI YEAR NOTE 224015 (b)150,000,000
39 Subtotal 169,885,000 309,011 0 0
33 TOTAL 3,055,985,000
FERC FORM No. 1 (ED. 12-96)
Page 256-257
LONG-TERM DEBT (Account 221, 222, 223 and 224)
Name of Respondent:Idaho Power Company (1) ☑ An Original(2) ☐ A Resubmission Date of Report:04/16/2024 Year/Period of ReportEnd of: 2023/ Q4LONG-TERM DEBT (Account 221, 222, 223 and 224)LineNo.Class and Series of Obligation, CouponRate (For new issue, give commissionAuthorization numbers and dates)(a)RelatedAccountNumber(b)Principal Amount ofDebt Issued(c)Total Expense, Premiumor Discount(d)Total Expense(e)Total Premium(f)TotalDiscount(g)1 Bonds (Account 221)2 4.00% Series due 2043 221101 75,000,000 741,728 194,25032.50% Series due 2023 221102 75,000,000 647,978 374,25043.65% Series Due 2045 221107 250,000,000 2,559,510 1,715,00054.20% Series Due 2048 221110 (a)450,000,000 4,629,516 (31,654,900)814,00064.99% PRP Due 2032 221111 23,000,000 169,158 0 075.06% PRP Due 2042 221112 25,000,000 183,842 0 085.06% PRP Due 2043 221113 60,000,000 441,200 0 095.20% PRP Due 2053 221114 62,000,000 455,883 0 0105.875% Series due 2034 221116 55,000,000 585,759 748,000116.00% Series due 2032 221133 100,000,000 1,191,216 544,000125.30% Series Due 2035 221134 60,000,000 3,849,739 408,600135.50% Series due 2033 221135 70,000,000 728,701 36,400146.30% Series due 2037 221141 140,000,000 1,500,031 278,600156.25% Series due 2037 221142 100,000,000 1,227,490 268,000165.50% Series due 2034 221145 50,000,000 524,419 383,500174.85% Series Due 2040 221146 100,000,000 1,284,871 170,000184.30% Series Due 2042 221147 75,000,000 802,240 49,500194.05% Series Due 2046 221148 120,000,000 1,321,383 309,600201.90% Series Due 2030 221149 80,000,000 980,949 328,000215.50% Series Due 2053 221222 400,000,000 4,381,222 3,772,00022Humboldt 1.45 % Variable due 2024 221325 49,800,000 396,278 0 0235.80% Series Due 2054 221333 350,000,000 3,769,611 3,234,00024Sweetwater 1.7% Variable due 2026 221335 116,300,000 908,982 0 025Subtotal2,886,100,000 33,281,706 (31,654,900)13,627,70026Reacquired Bonds (Account 222)27282930 Subtotal31Advances from Associated Companies(Account 223)32333435 Subtotal36Other Long Term Debt (Account 224)37 AM FALLS BOND OBLIG 224200 19,885,000 309,01138MULTI YEAR NOTE 224015 (b)150,000,00039Subtotal169,885,000 309,011 0 033TOTAL3,055,985,000FERC FORM No. 1 (ED. 12-96)Page 256-257
LONG-TERM DEBT (Account 221, 222, 223 and 224)
Line
No.
Nominal Date of Issue
(h)
Date of Maturity
(i)
AMORTIZATION PERIOD
Date From
(j)
AMORTIZATION PERIOD
Date To
(k)
Outstanding (Total amount
outstanding without
reduction for amounts held
by respondent)
(l)
Interest for Year Amount
(m)
1
2 04/08/2013 04/01/2043 04/08/2013 04/01/2043 75,000,000 3,000,000
3 04/08/2013 04/01/2023 04/08/2013 04/01/2023 0 468,750
4 03/06/2015 03/01/2045 03/06/2015 03/01/2045 250,000,000 9,125,000
5 03/16/2018 03/01/2048 03/16/2018 03/01/2048 450,000,000 18,900,000
6 12/22/2022 12/22/2032 12/22/2022 12/22/2032 23,000,000 1,147,700
7 12/22/2022 12/22/2042 12/22/2022 12/22/2042 25,000,000 1,265,000
8 03/08/2023 03/08/2043 03/08/2023 03/08/2043 60,000,000 2,470,967
9 03/08/2023 03/15/2053 03/08/2023 03/15/2053 62,000,000 2,623,978
10 08/16/2004 08/15/2034 08/16/2004 08/15/2034 55,000,000 3,231,250
11 11/15/2002 11/15/2032 11/15/2002 11/15/2032 100,000,000 6,000,000
12 08/26/2005 08/15/2035 08/26/2005 08/15/2035 60,000,000 3,180,000
13 05/13/2003 04/01/2033 05/13/2003 04/01/2033 70,000,000 3,850,000
14 06/22/2007 06/15/2037 06/22/2007 06/15/2037 140,000,000 8,820,000
15 10/18/2007 10/15/2037 10/18/2007 10/15/2037 100,000,000 6,250,000
16 03/26/2004 03/15/2034 03/26/2004 03/15/2034 50,000,000 2,750,000
17 08/30/2010 08/15/2040 08/30/2010 08/15/2040 100,000,000 4,850,000
18 04/13/2012 04/01/2042 04/13/2012 04/01/2042 75,000,000 3,225,000
19 03/10/2016 03/01/2046 03/10/2016 03/01/2046 120,000,000 4,860,000
20 06/22/2020 07/15/2030 06/22/2020 07/15/2030 80,000,000 1,520,000
21 03/14/2023 03/15/2053 03/14/2023 03/15/2053 400,000,000 17,538,889
22 08/21/2019 12/01/2024 08/21/2019 12/01/2024 49,800,000 722,100
23 09/11/2023 04/01/2054 09/11/2023 04/01/2054 350,000,000 6,202,778
24 08/21/2019 07/15/2026 08/21/2019 07/15/2026 116,300,000 1,977,100
25 2,811,100,000 113,978,512
26
27
28
29
30 0
31
32
33
34
35
36
37 04/26/2000 02/01/2025 04/26/2000 02/01/2025 19,885,000
38 03/04/2022 03/04/2024 03/04/2022 05/17/2023 2,237,785
39 19,885,000 2,237,785
33 2,830,985,000 116,216,297
FERC FORM No. 1 (ED. 12-96)
Page 256-257
Name of Respondent:
This report is:
(1) ☑ An Original Date of Report:Year/Period of Report
LineNo.Nominal Date of Issue(h)Date of Maturity(i)AMORTIZATION PERIODDate From(j)AMORTIZATION PERIODDate To(k)Outstanding (Total amountoutstanding withoutreduction for amounts heldby respondent)(l)Interest for Year Amount(m)12 04/08/2013 04/01/2043 04/08/2013 04/01/2043 75,000,000 3,000,000304/08/2013 04/01/2023 04/08/2013 04/01/2023 0 468,750403/06/2015 03/01/2045 03/06/2015 03/01/2045 250,000,000 9,125,000503/16/2018 03/01/2048 03/16/2018 03/01/2048 450,000,000 18,900,000612/22/2022 12/22/2032 12/22/2022 12/22/2032 23,000,000 1,147,700712/22/2022 12/22/2042 12/22/2022 12/22/2042 25,000,000 1,265,000803/08/2023 03/08/2043 03/08/2023 03/08/2043 60,000,000 2,470,967903/08/2023 03/15/2053 03/08/2023 03/15/2053 62,000,000 2,623,9781008/16/2004 08/15/2034 08/16/2004 08/15/2034 55,000,000 3,231,2501111/15/2002 11/15/2032 11/15/2002 11/15/2032 100,000,000 6,000,0001208/26/2005 08/15/2035 08/26/2005 08/15/2035 60,000,000 3,180,0001305/13/2003 04/01/2033 05/13/2003 04/01/2033 70,000,000 3,850,0001406/22/2007 06/15/2037 06/22/2007 06/15/2037 140,000,000 8,820,0001510/18/2007 10/15/2037 10/18/2007 10/15/2037 100,000,000 6,250,0001603/26/2004 03/15/2034 03/26/2004 03/15/2034 50,000,000 2,750,0001708/30/2010 08/15/2040 08/30/2010 08/15/2040 100,000,000 4,850,0001804/13/2012 04/01/2042 04/13/2012 04/01/2042 75,000,000 3,225,0001903/10/2016 03/01/2046 03/10/2016 03/01/2046 120,000,000 4,860,0002006/22/2020 07/15/2030 06/22/2020 07/15/2030 80,000,000 1,520,0002103/14/2023 03/15/2053 03/14/2023 03/15/2053 400,000,000 17,538,8892208/21/2019 12/01/2024 08/21/2019 12/01/2024 49,800,000 722,1002309/11/2023 04/01/2054 09/11/2023 04/01/2054 350,000,000 6,202,7782408/21/2019 07/15/2026 08/21/2019 07/15/2026 116,300,000 1,977,100252,811,100,000 113,978,512262728293003132333435363704/26/2000 02/01/2025 04/26/2000 02/01/2025 19,885,0003803/04/2022 03/04/2024 03/04/2022 05/17/2023 2,237,7853919,885,000 2,237,785332,830,985,000 116,216,297FERC FORM No. 1 (ED. 12-96)Page 256-257
Name of Respondent:
This report is:
(1) ☑ An Original Date of Report:Year/Period of ReportName of Respondent:
Idaho Power Company
(1) ☑ An Original
(2) ☐ A Resubmission
Date of Report:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
FOOTNOTE DATA
(a) Concept: BondsPrincipalAmountIssued
Additional $230 million of 4.20% bonds due 3/1/2048 issued on 4/3/2020 with a premium of $31,654,900, bringing total 4.20% series outstanding to $450 million.
(b) Concept: OtherLongTermDebtPrincipalAmountIssued
Multi year note: $50 million, issued 03-04-2022, due 03-04-2024, paid in full 05-17-2023
Multi year note: $100 million, issued 05-24-2022, due 03-04-2024, paid in full 03-31-2023
FERC FORM No. 1 (ED. 12-96)
Page 256-257
Name of Respondent:
This report is:
(1) ☑ An Original Date of Report:Year/Period of Report
Name of Respondent:Idaho Power Company (1) ☑ An Original(2) ☐ A Resubmission Date of Report:04/16/2024 Year/Period of ReportEnd of: 2023/ Q4FOOTNOTE DATA(a) Concept: BondsPrincipalAmountIssuedAdditional $230 million of 4.20% bonds due 3/1/2048 issued on 4/3/2020 with a premium of $31,654,900, bringing total 4.20% series outstanding to $450 million.(b) Concept: OtherLongTermDebtPrincipalAmountIssuedMulti year note: $50 million, issued 03-04-2022, due 03-04-2024, paid in full 05-17-2023Multi year note: $100 million, issued 05-24-2022, due 03-04-2024, paid in full 03-31-2023FERC FORM No. 1 (ED. 12-96)Page 256-257
Name of Respondent:
This report is:
(1) ☑ An Original Date of Report:Year/Period of ReportName of Respondent:
Idaho Power Company
(1) ☑ An Original
(2) ☐ A Resubmission
Date of Report:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
RECONCILIATION OF REPORTED NET INCOME WITH TAXABLE INCOME FOR FEDERAL INCOME TAXES
Line No.Particulars (Details)
(a)
Amount
(b)
1 Net Income for the Year (Page 117)256,810,468
2 Reconciling Items for the Year
3
4 Taxable Income Not Reported on Books
5 CONSTRUCTION ADVANCES 12,287,716
6 AVOIDED COST 14,748,839
7 CIAC - TAXABLE - ACCT 107 73,204,450
8 ENGINEERING FEES - TAXABLE - ACCT 107 71,123
9 VALMY SETTLEMENT ADJUSTMENT 6,436,592
9 Deductions Recorded on Books Not Deducted for Return
10 NON-DEDUCTIBLE MEALS 820,000
11 VACATION ACCRUAL 2,000,000
12 PCA EXPENSE DEFERRAL 13,104,695
13 STOCK BASED COMPENSATION 714,047
14 OREGON - PCAM 1,068,787
15 PENSION EXPENSES - OREGON 749,024
16 ASSET RETIREMENT OBLIGATION (ARO)12,995
17 INCENTIVE DEFERRAL-PROFIT SHARING-NOT IN RATES 1,594,649
18 VALMY DEPRECIATION ADJUSTMENT 4,129,844
19 TAX REFORM REGULATORY STIPULATION 8,097,874
20 NON-DEDUCTIBLE POLITICAL EXPENSES 1,056,725
21 SMSP - NET 93,696
22 INCENTIVE DEFERRAL - CRI & RELIABILITY-INCLUDED IN RATES 1,742,730
23 PROV FOR RATE REFUND - HC RELICENSING (AFUDC)21,142,600
24 PCA COAL USAGE RESERVE 11,400,000
25 VEBA - POST RETIREMENT BENEFITS 195,182
26 DEPR TIMING DIFF - OPERATING - FEDERAL 149,815,747
27 CONSERVATION EXPENSES 3,601,750
28 GAIN/LOSS ON REACQUIRED DEBT 2,469,514
29 IPCO-162(m) $1M THRESHOLD 4,950,370
30 VALMY1 BOOK BASIS ADJUSTMENT 3,081,950
31 TOTAL FEDERAL & STATE TAXES DEDUCTED ON BOOKS 27,359,126
14 Income Recorded on Books Not Included in Return
15 SMSP - INSURANCE COSTS 8,182,498
16 REVERSE EQUITY EARNINGS OF SUBSIDIARIES 8,033,987
17 ALLOWANCE FOR OFUDC 43,221,277
18 ALLOWANCE FOR BFUDC 20,012,407
19 SMSP - INSURANCE PROCEEDS 31,232
19 Deductions on Return Not Charged Against Book Income
20 263A CAPITALIZED OVERHEADS 10,000,000
21 PENSION EXPENSE 35,204,545
22 FIXED COST ADJUSTMENT 9,383,986
23 WILDFIRE MITIGATION 35077 DEFERRAL 28,251,249
FERC FORM NO. 1 (ED. 12-96)
Page 261
Name of Respondent:Idaho Power Company (1) ☑ An Original(2) ☐ A Resubmission Date of Report:04/16/2024 Year/Period of ReportEnd of: 2023/ Q4RECONCILIATION OF REPORTED NET INCOME WITH TAXABLE INCOME FOR FEDERAL INCOME TAXESLine No.Particulars (Details)(a)Amount(b)1 Net Income for the Year (Page 117)256,810,4682Reconciling Items for the Year34Taxable Income Not Reported on Books5CONSTRUCTION ADVANCES 12,287,7166AVOIDED COST 14,748,8397CIAC - TAXABLE - ACCT 107 73,204,4508ENGINEERING FEES - TAXABLE - ACCT 107 71,1239VALMY SETTLEMENT ADJUSTMENT 6,436,5929Deductions Recorded on Books Not Deducted for Return10NON-DEDUCTIBLE MEALS 820,00011VACATION ACCRUAL 2,000,00012PCA EXPENSE DEFERRAL 13,104,69513STOCK BASED COMPENSATION 714,04714OREGON - PCAM 1,068,78715PENSION EXPENSES - OREGON 749,02416ASSET RETIREMENT OBLIGATION (ARO)12,99517INCENTIVE DEFERRAL-PROFIT SHARING-NOT IN RATES 1,594,64918VALMY DEPRECIATION ADJUSTMENT 4,129,84419TAX REFORM REGULATORY STIPULATION 8,097,87420NON-DEDUCTIBLE POLITICAL EXPENSES 1,056,72521SMSP - NET 93,69622INCENTIVE DEFERRAL - CRI & RELIABILITY-INCLUDED IN RATES 1,742,73023PROV FOR RATE REFUND - HC RELICENSING (AFUDC)21,142,60024PCA COAL USAGE RESERVE 11,400,00025VEBA - POST RETIREMENT BENEFITS 195,18226DEPR TIMING DIFF - OPERATING - FEDERAL 149,815,74727CONSERVATION EXPENSES 3,601,75028GAIN/LOSS ON REACQUIRED DEBT 2,469,51429IPCO-162(m) $1M THRESHOLD 4,950,37030VALMY1 BOOK BASIS ADJUSTMENT 3,081,95031TOTAL FEDERAL & STATE TAXES DEDUCTED ON BOOKS 27,359,12614Income Recorded on Books Not Included in Return15SMSP - INSURANCE COSTS 8,182,49816REVERSE EQUITY EARNINGS OF SUBSIDIARIES 8,033,98717ALLOWANCE FOR OFUDC 43,221,27718ALLOWANCE FOR BFUDC 20,012,40719SMSP - INSURANCE PROCEEDS 31,23219Deductions on Return Not Charged Against Book Income20263A CAPITALIZED OVERHEADS 10,000,00021PENSION EXPENSE 35,204,54522FIXED COST ADJUSTMENT 9,383,98623WILDFIRE MITIGATION 35077 DEFERRAL 28,251,249FERC FORM NO. 1 (ED. 12-96)Page 261
24 BOARDMAN DECOMMISSION 434,757
25 SOFT CAP BATTERY RESERVE 2,800,000
26 BRIDGER DEPRECIATION ADJUST - 283 27,428,383
27 STOCK BASED COMP - STOCK 27,247
28 REMOVAL COSTS 30,055,988
29 RELICENSING - LABOR COSTS DEDUCTED - ACCT 107 2,035,000
30 REPAIRS DEDUCTION 116,000,000
31 STOCK BASED COMP - DIVIDENDS 714,720
32 OR CAT 340,288
33 STATE INCOME TAX DEDUCTED ON FEDERAL RETURN 10,178,760
27 Federal Tax Net Income 270,424,169
28 Show Computation of Tax:
29 TENTATIVE FEDERAL TAX @ 21%56,789,076
FERC FORM NO. 1 (ED. 12-96)
Page 261
RECONCILIATION OF REPORTED NET INCOME WITH TAXABLE INCOME FOR FEDERAL INCOME TAXES
Line No.Particulars (Details)
(a)
Amount
(b)
Name of Respondent:
This report is:
(1) ☑ An Original Date of Report:Year/Period of Report
24 BOARDMAN DECOMMISSION 434,75725SOFT CAP BATTERY RESERVE 2,800,00026BRIDGER DEPRECIATION ADJUST - 283 27,428,38327STOCK BASED COMP - STOCK 27,24728REMOVAL COSTS 30,055,98829RELICENSING - LABOR COSTS DEDUCTED - ACCT 107 2,035,00030REPAIRS DEDUCTION 116,000,00031STOCK BASED COMP - DIVIDENDS 714,72032OR CAT 340,28833STATE INCOME TAX DEDUCTED ON FEDERAL RETURN 10,178,76027Federal Tax Net Income 270,424,16928Show Computation of Tax:29 TENTATIVE FEDERAL TAX @ 21%56,789,076FERC FORM NO. 1 (ED. 12-96)Page 261RECONCILIATION OF REPORTED NET INCOME WITH TAXABLE INCOME FOR FEDERAL INCOME TAXESLine No.Particulars (Details)(a)Amount(b)
Name of Respondent:
This report is:
(1) ☑ An Original Date of Report:Year/Period of ReportName of Respondent:
Idaho Power Company
(1) ☑ An Original
(2) ☐ A Resubmission
Date of Report:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
TAXES ACCRUED, PREPAID AND CHARGES DURING YEAR
BALANCE AT
BEGINNING
OF YEAR
BALANCE
AT
BEGINNING
OF YEAR
Line
No.
Kind of Tax (See Instruction 5)
(a)
Type of Tax
(b)
State
(c)
Tax Year
(d)
Taxes
Accrued
(Account 236)
(e)
Prepaid
Taxes
(Include in
Account
165)
(f)
1 Federal Income Tax (11,994,822)0
2 State Income Tax Idaho (1,364,532)0
3 State Income Tax Oregon 516,831 0
4 Other Income Tax Other 242,247 0
5 Subtotal Income Tax (12,600,276)0
6 Federal Other Taxes (115,819)0
7 Other Other Taxes Other (69,361)0
8 Subtotal Other Taxes (185,180)0
9 State Other State Tax Oregon 0 0
10 State Other State Tax Oregon 0 835
11 State Other State Tax Idaho 0 0
12 State Other State Tax Idaho 80,439 0
13 State Other State Tax Idaho 17,279 0
14 Subtotal Other State Tax 97,718 835
15 State Other License And Fees Tax Idaho 0 0
16 State Other License And Fees Tax Wyoming 0 0
17 Subtotal Other License And Fees
Tax 0 0
18 Federal Unemployment Tax (2,226)0
19 State Unemployment Tax Idaho (1,566)0
20 State Unemployment Tax Oregon 242 0
21 Subtotal Unemployment Tax (3,550)0
22 State Property Tax Idaho 7,266,142 0
23 State Property Tax Oregon 0 2,740,584
24 State Property Tax Montana 236,500 0
25 State Property Tax Nevada 0 146,658
26 State Property Tax Wyoming 695,910 0
27 State Property Tax Washington 5,379 0
28 Subtotal Property Tax 8,203,931 2,887,242
29 State Franchise Tax Oregon 228,901 0
30 Subtotal Franchise Tax 228,901 0
31 Other Payroll Tax Other 0 0
32 Subtotal Payroll Tax 0 0
40 TOTAL (4,258,456)2,888,077
FERC FORM NO. 1 (ED. 12-96)
Page 262-263
TAXES ACCRUED, PREPAID AND CHARGES DURING YEAR
Name of Respondent:Idaho Power Company (1) ☑ An Original(2) ☐ A Resubmission Date of Report:04/16/2024 Year/Period of ReportEnd of: 2023/ Q4TAXES ACCRUED, PREPAID AND CHARGES DURING YEAR BALANCE ATBEGINNINGOF YEAR BALANCEATBEGINNINGOF YEARLineNo.Kind of Tax (See Instruction 5)(a)Type of Tax(b)State(c)Tax Year(d)TaxesAccrued(Account 236)(e)PrepaidTaxes(Include inAccount165)(f)1 Federal Income Tax (11,994,822)02StateIncome Tax Idaho (1,364,532)03StateIncome Tax Oregon 516,831 04OtherIncome Tax Other 242,247 05Subtotal Income Tax (12,600,276)06FederalOther Taxes (115,819)07OtherOther Taxes Other (69,361)08Subtotal Other Taxes (185,180)09StateOther State Tax Oregon 0 010StateOther State Tax Oregon 0 83511StateOther State Tax Idaho 0 012StateOther State Tax Idaho 80,439 013StateOther State Tax Idaho 17,279 014Subtotal Other State Tax 97,718 83515StateOther License And Fees Tax Idaho 0 016StateOther License And Fees Tax Wyoming 0 017Subtotal Other License And FeesTax 0 018FederalUnemployment Tax (2,226)019StateUnemployment Tax Idaho (1,566)020StateUnemployment Tax Oregon 242 021Subtotal Unemployment Tax (3,550)022StateProperty Tax Idaho 7,266,142 023StateProperty Tax Oregon 0 2,740,58424StateProperty Tax Montana 236,500 025StateProperty Tax Nevada 0 146,65826StateProperty Tax Wyoming 695,910 027StateProperty Tax Washington 5,379 028Subtotal Property Tax 8,203,931 2,887,24229StateFranchise Tax Oregon 228,901 030Subtotal Franchise Tax 228,901 031OtherPayroll Tax Other 0 032Subtotal Payroll Tax 0 040TOTAL(4,258,456)2,888,077FERC FORM NO. 1 (ED. 12-96)Page 262-263
TAXES ACCRUED, PREPAID AND CHARGES DURING YEAR
BALANCE AT END OF
YEAR
BALANCE AT END OF
YEAR
DISTRIBUTION OF TAXES
CHARGED
Line
No.
Taxes Charged During Year
(g)
Taxes Paid During Year
(h)
Adjustments
(i)
Taxes Accrued (Account
236)
(j)
Prepaid Taxes (Included in
Account 165)
(k)
Electric (Account 408.1,
409.1)
(l)
1 (1,313,159)(4,681,759)0 (8,626,222)0 (7,322,767)
2 3,511,866 15,958,336 0 (13,811,002)0 2,724,410
3 959,054 2,190,831 0 (714,946)0 858,815
4 36,620 20,346 0 258,521 0 22,907
5 3,194,381 13,487,754 0 (22,893,649)0 (3,716,635)
6 20,013,325 20,054,764 0 (157,258)0 20,013,326
7 0 (49,408)4,353 (15,600)0 0
8 20,013,325 20,005,356 4,353 (172,858)0 20,013,326
9 260,575 375,919 115,344 0 0 260,575
10 1,696 1,722 0 0 861 0
11 2,837,473 2,837,473 0 0 0 2,837,473
12 1,480,897 1,468,829 0 92,507 0 1,480,897
13 32,023 33,290 0 16,012 0 0
14 4,612,664 4,717,233 115,344 108,519 861 4,578,945
15 150 150 0 0 0 150
16 4,226 4,226 0 0 0 4,226
17 4,376 4,376 0 0 0 4,376
18 94,181 94,222 0 (2,267)0 94,181
19 216,569 217,135 0 (2,132)0 216,569
20 60,956 61,249 0 (51)0 60,956
21 371,706 372,606 0 (4,450)0 371,706
22 12,597,703 14,372,685 0 5,491,160 0 12,596,115
23 5,265,308 5,047,591 0 0 2,522,867 4,848,263
24 396,112 434,780 0 197,832 0 396,112
25 286,026 298,657 0 0 159,289 286,026
26 1,424,328 1,408,074 0 712,164 0 1,424,328
27 3,455 4,417 0 4,417 0 3,455
28 19,972,932 21,566,204 0 6,405,573 2,682,156 19,554,299
29 944,305 934,185 0 239,021 0 944,305
30 944,305 934,185 0 239,021 0 944,305
31 (20,385,033)0 20,385,033 0 0 (20,385,033)
32 (20,385,033)0 20,385,033 0 0 (20,385,033)
40 28,728,656 61,087,714 20,504,730 (16,317,844)2,683,017 21,365,289
FERC FORM NO. 1 (ED. 12-96)
Page 262-263
TAXES ACCRUED, PREPAID AND CHARGES DURING YEAR
BALANCE AT END OFYEAR BALANCE AT END OFYEAR DISTRIBUTION OF TAXESCHARGEDLineNo.Taxes Charged During Year(g)Taxes Paid During Year(h)Adjustments(i)Taxes Accrued (Account236)(j)Prepaid Taxes (Included inAccount 165)(k)Electric (Account 408.1,409.1)(l)1 (1,313,159)(4,681,759)0 (8,626,222)0 (7,322,767)2 3,511,866 15,958,336 0 (13,811,002)0 2,724,4103959,054 2,190,831 0 (714,946)0 858,815436,620 20,346 0 258,521 0 22,90753,194,381 13,487,754 0 (22,893,649)0 (3,716,635)6 20,013,325 20,054,764 0 (157,258)0 20,013,32670(49,408)4,353 (15,600)0 0820,013,325 20,005,356 4,353 (172,858)0 20,013,3269260,575 375,919 115,344 0 0 260,575101,696 1,722 0 0 861 0112,837,473 2,837,473 0 0 0 2,837,473121,480,897 1,468,829 0 92,507 0 1,480,8971332,023 33,290 0 16,012 0 0144,612,664 4,717,233 115,344 108,519 861 4,578,94515150150000150164,226 4,226 0 0 0 4,226174,376 4,376 0 0 0 4,3761894,181 94,222 0 (2,267)0 94,18119216,569 217,135 0 (2,132)0 216,5692060,956 61,249 0 (51)0 60,95621371,706 372,606 0 (4,450)0 371,7062212,597,703 14,372,685 0 5,491,160 0 12,596,115235,265,308 5,047,591 0 0 2,522,867 4,848,26324396,112 434,780 0 197,832 0 396,11225286,026 298,657 0 0 159,289 286,026261,424,328 1,408,074 0 712,164 0 1,424,328273,455 4,417 0 4,417 0 3,4552819,972,932 21,566,204 0 6,405,573 2,682,156 19,554,29929944,305 934,185 0 239,021 0 944,30530944,305 934,185 0 239,021 0 944,30531(20,385,033)0 20,385,033 0 0 (20,385,033)32 (20,385,033)0 20,385,033 0 0 (20,385,033)40 28,728,656 61,087,714 20,504,730 (16,317,844)2,683,017 21,365,289FERC FORM NO. 1 (ED. 12-96)Page 262-263
TAXES ACCRUED, PREPAID AND CHARGES DURING YEAR
DISTRIBUTION OF TAXES CHARGED DISTRIBUTION OF TAXES CHARGED DISTRIBUTION OF TAXES CHARGED
Line No.Extraordinary Items (Account 409.3)
(m)
Adjustment to Ret. Earnings (Account 439)
(n)
Other
(o)
1 0 0 6,009,608
2 0 0 787,456
3 0 0 100,240
4 0 0 13,713
5 0 0 6,911,017
6 0 0 0
7 0 0 0
8 0 0 0
9 0 0 0
10 0 0 1,696
11 0 0 0
12 0 0 0
13 0 0 32,023
14 0 0 33,719
15 0 0 0
16 0 0 0
17 0 0 0
18 0 0 0
19 0 0 0
20 0 0 0
21 0 0 0
22 0 0 1,587
23 0 0 417,046
24 0 0 0
25 0 0 0
26 0 0 0
27 0 0 0
28 0 0 418,633
29 0 0 0
30 0 0 0
31 0 0 0
32 0 0 0
40 0 7,363,369
FERC FORM NO. 1 (ED. 12-96)
Page 262-263
Name of Respondent:
This report is:
(1) ☑ An Original Date of Report:Year/Period of Report
DISTRIBUTION OF TAXES CHARGED DISTRIBUTION OF TAXES CHARGED DISTRIBUTION OF TAXES CHARGEDLine No.Extraordinary Items (Account 409.3)(m)Adjustment to Ret. Earnings (Account 439)(n)Other(o)1 0 0 6,009,608200787,456300100,24040013,7135006,911,017600070008000900010001,6961100012000130032,023140033,7191500016000170001800019000200002100022001,5872300417,046240002500026000270002800418,633290003000031000320004007,363,369FERC FORM NO. 1 (ED. 12-96)Page 262-263
Name of Respondent:
This report is:
(1) ☑ An Original Date of Report:Year/Period of ReportName of Respondent:
Idaho Power Company
(1) ☑ An Original
(2) ☐ A Resubmission
Date of Report:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
ACCUMULATED DEFERRED INVESTMENT TAX CREDITS (Account 255)
Deferred for Year Deferred for Year
Allocations to
Current Year's
Income
Allocations to Current
Year's Income
Line
No.
Account Subdivisions
(a)
Balance at Beginning of
Year
(b)
Account No.
(c)
Amount
(d)
Account No.
(e)
Amount
(f)
1 Electric Utility
2 0.03
3 0.04 108,557 411.401 9,764
4 0.07
5 0.10 8,549,765 411.401 890,454
6 Other - Federal 24,121,585 45,586,783 1,443,342
7 Other - State 82,505,500 411.402 10,057,246 411.402 3,107,335
8 TOTAL Electric (Enter Total of lines 2 thru 7)115,285,407 55,644,029 5,450,895
9 Other (List separately and show 3%, 4%, 7%,
10% and TOTAL)
10 0.11 975,557 411.401 21,552
11 0.30 23,146,028 411.401 45,586,783 411.401 1,421,790
47 OTHER TOTAL 24,121,585 45,586,783 1,443,342
48 GRAND TOTAL 115,285,406
FERC FORM NO. 1 (ED. 12-89)
Page 266-267
ACCUMULATED DEFERRED INVESTMENT TAX CREDITS (Account 255)
Name of Respondent:Idaho Power Company (1) ☑ An Original(2) ☐ A Resubmission Date of Report:04/16/2024 Year/Period of ReportEnd of: 2023/ Q4ACCUMULATED DEFERRED INVESTMENT TAX CREDITS (Account 255)Deferred for Year Deferred for Year Allocations toCurrent Year'sIncome Allocations to CurrentYear's IncomeLineNo.Account Subdivisions(a)Balance at Beginning ofYear(b)Account No.(c)Amount(d)Account No.(e)Amount(f)1 Electric Utility20.0330.04 108,557 411.401 9,76440.0750.10 8,549,765 411.401 890,4546Other - Federal 24,121,585 45,586,783 1,443,3427Other - State 82,505,500 411.402 10,057,246 411.402 3,107,3358TOTAL Electric (Enter Total of lines 2 thru 7)115,285,407 55,644,029 5,450,8959Other (List separately and show 3%, 4%, 7%,10% and TOTAL)10 0.11 975,557 411.401 21,552110.30 23,146,028 411.401 45,586,783 411.401 1,421,79047OTHER TOTAL 24,121,585 45,586,783 1,443,34248GRAND TOTAL 115,285,406FERC FORM NO. 1 (ED. 12-89)Page 266-267
ACCUMULATED DEFERRED INVESTMENT TAX CREDITS (Account 255)
Line
No.
Adjustments
(g)
Balance at End of Year
(h)
Average Period of Allocation to Income
(i)
ADJUSTMENT EXPLANATION
(j)
1
2
3 98,793 11.12
4
5 7,659,311 9.60
6 68,265,026
7 89,455,411 26.55
8 0 165,478,541
9
10 954,005 45.27
11 67,311,021 16.28
47 0 68,265,026
48 165,478,542
FERC FORM NO. 1 (ED. 12-89)
Page 266-267
Name of Respondent:
This report is:
(1) ☑ An Original Date of Report:Year/Period of Report
LineNo.Adjustments(g)Balance at End of Year(h)Average Period of Allocation to Income(i)ADJUSTMENT EXPLANATION(j)123 98,793 11.12457,659,311 9.60668,265,026789,455,411 26.5580165,478,541910954,005 45.271167,311,021 16.2847068,265,02648165,478,542FERC FORM NO. 1 (ED. 12-89)Page 266-267
Name of Respondent:
This report is:
(1) ☑ An Original Date of Report:Year/Period of ReportName of Respondent:
Idaho Power Company
(1) ☑ An Original
(2) ☐ A Resubmission
Date of Report:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
OTHER DEFERRED CREDITS (Account 253)
DEBITS DEBITS
Line
No.
Description and Other Deferred Credits
(a)
Balance at Beginning of
Year
(b)
Contra Account
(c)
Amount
(d)
Credits
(e)
Balance at End of Year
(f)
1 PTP Transmission Deposits 253201 6,913,508 131 9,603,052 8,334,018 5,644,474
2 Cogen Deposits 253360 147,000 147,000
3 Sho-Ban Scholarships 253480 82,500 242 15,000 67,500
4 Amortization period 01/05-12/27 0 0
5 Operations Accruals 253550 921,073 131 212,850 31,423,557 32,131,780
6 Postretirement Benefits 253960 1,628,959 545,017 2,173,976
7 Directors Deferred Compensation 3,172,380 131 311,500 280,563 3,141,443
8 253970-253999 0 0
47 TOTAL 12,865,420 10,142,402 40,583,155 43,306,173
FERC FORM NO. 1 (ED. 12-94)
Page 269
Name of Respondent:
This report is:
(1) ☑ An Original Date of Report:Year/Period of Report
Name of Respondent:Idaho Power Company (1) ☑ An Original(2) ☐ A Resubmission Date of Report:04/16/2024 Year/Period of ReportEnd of: 2023/ Q4OTHER DEFERRED CREDITS (Account 253)DEBITS DEBITSLineNo.Description and Other Deferred Credits(a)Balance at Beginning ofYear(b)Contra Account(c)Amount(d)Credits(e)Balance at End of Year(f)1 PTP Transmission Deposits 253201 6,913,508 131 9,603,052 8,334,018 5,644,4742Cogen Deposits 253360 147,000 147,0003Sho-Ban Scholarships 253480 82,500 242 15,000 67,5004Amortization period 01/05-12/27 0 05Operations Accruals 253550 921,073 131 212,850 31,423,557 32,131,7806Postretirement Benefits 253960 1,628,959 545,017 2,173,9767Directors Deferred Compensation 3,172,380 131 311,500 280,563 3,141,4438253970-253999 0 047TOTAL12,865,420 10,142,402 40,583,155 43,306,173FERC FORM NO. 1 (ED. 12-94)Page 269
Name of Respondent:
This report is:
(1) ☑ An Original Date of Report:Year/Period of ReportName of Respondent:
Idaho Power Company
(1) ☑ An Original
(2) ☐ A Resubmission
Date of Report:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
ACCUMULATED DEFERRED INCOME TAXES - OTHER PROPERTY (Account 282)
CHANGES DURING
YEAR
CHANGES DURING
YEAR
CHANGES DURING
YEAR
CHANGES DURING
YEAR
Line
No.
Account
(a)
Balance at Beginning of
Year
(b)
Amounts Debited to
Account 410.1
(c)
Amounts Credited to
Account 411.1
(d)
Amounts Debited to
Account 410.2
(e)
Amounts Credited to
Account 411.2
(f)
1 Account 282
2 Electric 245,150,963 2,856,797 36,923,940 0 0
3 Gas 0
4 Other (Specify)0
5 Total (Total of lines 2 thru 4)245,150,963 2,856,797 36,923,940 0 0
6 Non-Operating Property
7 Other - Regulatory Asset for Income Taxes 739,689,037
8 Like Kind Exchange - Reclass Non-Rate
Base 4,300,934
9 TOTAL Account 282 (Total of Lines 5 thru 8)989,140,934 2,856,797 36,923,940 0 0
10 Classification of TOTAL
11 Federal Income Tax 784,930,552 2,806,998 36,796,100
12 State Income Tax 204,210,380 49,799 127,840
13 Local Income Tax
FERC FORM NO. 1 (ED. 12-96)
Page 274-275
ACCUMULATED DEFERRED INCOME TAXES - OTHER PROPERTY (Account 282)
Name of Respondent:Idaho Power Company (1) ☑ An Original(2) ☐ A Resubmission Date of Report:04/16/2024 Year/Period of ReportEnd of: 2023/ Q4ACCUMULATED DEFERRED INCOME TAXES - OTHER PROPERTY (Account 282)CHANGES DURINGYEAR CHANGES DURINGYEAR CHANGES DURINGYEAR CHANGES DURINGYEARLineNo.Account(a)Balance at Beginning ofYear(b)Amounts Debited toAccount 410.1(c)Amounts Credited toAccount 411.1(d)Amounts Debited toAccount 410.2(e)Amounts Credited toAccount 411.2(f)1 Account 2822Electric 245,150,963 2,856,797 36,923,940 0 03Gas04Other (Specify)05Total (Total of lines 2 thru 4)245,150,963 2,856,797 36,923,940 0 06Non-Operating Property7Other - Regulatory Asset for Income Taxes 739,689,0378Like Kind Exchange - Reclass Non-RateBase 4,300,9349TOTAL Account 282 (Total of Lines 5 thru 8)989,140,934 2,856,797 36,923,940 0 010Classification of TOTAL11Federal Income Tax 784,930,552 2,806,998 36,796,10012State Income Tax 204,210,380 49,799 127,84013Local Income TaxFERC FORM NO. 1 (ED. 12-96)Page 274-275
ACCUMULATED DEFERRED INCOME TAXES - OTHER PROPERTY (Account 282)
ADJUSTMENTS ADJUSTMENTS ADJUSTMENTS ADJUSTMENTS
Debits Debits Credits Credits
Line
No.
Account Credited
(g)
Amount
(h)
Account Debited
(i)
Amount
(j)
Balance at End of Year
(k)
1
2 0 282/254 10,905,854 (a)221,989,674
3 0
4 0
5 0 10,905,854 221,989,674
6 0
7 182 34,983,330 774,672,367
8 282 221,699 4,079,235
9 221,699 45,889,184 1,000,741,276
10
11 182/254 40,719,160 791,660,610
12 182 4,948,327 209,080,666
13
FERC FORM NO. 1 (ED. 12-96)
Page 274-275
Name of Respondent:
This report is:
(1) ☑ An Original Date of Report:Year/Period of Report
ADJUSTMENTS ADJUSTMENTS ADJUSTMENTS ADJUSTMENTSDebitsDebitsCreditsCreditsLineNo.Account Credited(g)Amount(h)Account Debited(i)Amount(j)Balance at End of Year(k)12 0 282/254 10,905,854 (a)221,989,67430405010,905,854 221,989,67460718234,983,330 774,672,3678282221,699 4,079,2359221,699 45,889,184 1,000,741,2761011182/254 40,719,160 791,660,610121824,948,327 209,080,66613FERC FORM NO. 1 (ED. 12-96)Page 274-275
Name of Respondent:
This report is:
(1) ☑ An Original Date of Report:Year/Period of ReportName of Respondent:
Idaho Power Company
(1) ☑ An Original
(2) ☐ A Resubmission
Date of Report:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
FOOTNOTE DATA
(a) Concept: AccumulatedDeferredIncomeTaxesOtherProperty
2023 Changes during Year Adjustments Debits Adjustments Credits 2023
Beginning DR to CR to DR to CR to Acct.Acct.Ending
Line Account Balance 410.1 411.1 410.2 411.2 credited Amount debited Amount Balance
No.(a)b c d e f g h i j k
Line 2:Depreciation Timing Diff-Operating 413,656,057 3,632,749 21,526,123 ----395,762,683
Like Kind Exchange - Reclass Non-Rate Base (4,300,933)-----282111221,698 (4,079,235)
Excess Deferred Tax on Depreciation (Reg Liab)(158,634,043)-----25496710,684,156 (147,949,887)
4013 CIAC-Taxable-Acct 107 (18,434,402)-15,382,882 ----(33,817,284)
4021 Engineering Fees-Taxable-Acct 107 (940,165)-14,936 ----(955,101)
8072 Intangible-Labor Costs Deducted-Acct 107 13,804,450 (775,952)-----13,028,498
TOTAL Line 2 245,150,964 2,856,797 36,923,941 0 0 0 10,905,854 221,989,674
FERC FORM NO. 1 (ED. 12-96)
Page 274-275
Name of Respondent:
This report is:
(1) ☑ An Original Date of Report:Year/Period of Report
Name of Respondent:Idaho Power Company (1) ☑ An Original(2) ☐ A Resubmission Date of Report:04/16/2024 Year/Period of ReportEnd of: 2023/ Q4FOOTNOTE DATA(a) Concept: AccumulatedDeferredIncomeTaxesOtherProperty2023 Changes during Year Adjustments Debits Adjustments Credits 2023BeginningDR to CR to DR to CR to Acct.Acct.EndingLineAccountBalance410.1 411.1 410.2 411.2 credited Amount debited Amount BalanceNo.(a)b c d e f g h i j kLine 2:Depreciation Timing Diff-Operating 413,656,057 3,632,749 21,526,123 ----395,762,683Like Kind Exchange - Reclass Non-Rate Base (4,300,933)-----282111221,698 (4,079,235)Excess Deferred Tax on Depreciation (Reg Liab)(158,634,043)-----25496710,684,156 (147,949,887)4013 CIAC-Taxable-Acct 107 (18,434,402)-15,382,882 ----(33,817,284)4021 Engineering Fees-Taxable-Acct 107 (940,165)-14,936 ----(955,101)8072 Intangible-Labor Costs Deducted-Acct 107 13,804,450 (775,952)-----13,028,498TOTAL Line 2 245,150,964 2,856,797 36,923,941 0 0 0 10,905,854 221,989,674FERC FORM NO. 1 (ED. 12-96)Page 274-275
Name of Respondent:
This report is:
(1) ☑ An Original Date of Report:Year/Period of ReportName of Respondent:
Idaho Power Company
(1) ☑ An Original
(2) ☐ A Resubmission
Date of Report:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
ACCUMULATED DEFERRED INCOME TAXES - OTHER (Account 283)
CHANGES DURING
YEAR
CHANGES DURING
YEAR
CHANGES DURING
YEAR
CHANGES DURING
YEAR
Line
No.
Account
(a)
Balance at Beginning of
Year
(b)
Amounts Debited to
Account 410.1
(c)
Amounts Credited to
Account 411.1
(d)
Amounts Debited to
Account 410.2
(e)
Amounts Credited to
Account 411.2
(f)
1 Account 283
2 Electric
3
(a)
Other Electric 145,190,859 35,301,478 7,449,674
4
(b)
Other 18,083,278
9 TOTAL Electric (Total of lines 3 thru 8)163,274,137 35,301,478 7,449,674
10 Gas
11
12
13
14
15
16
17 TOTAL Gas (Total of lines 11 thru 16)
18 TOTAL Other (58,563)201,644
19 TOTAL (Acct 283) (Enter Total of lines 9, 17
and 18)163,215,574 35,301,478 7,449,674 0 201,644
20 Classification of TOTAL
21 Federal Income Tax 125,201,634 27,068,875 5,713,153 154,640
22 State Income Tax 38,013,939 8,232,603 1,736,521 47,003
23 Local Income Tax
NOTES
FERC FORM NO. 1 (ED. 12-96)
Page 276-277
ACCUMULATED DEFERRED INCOME TAXES - OTHER (Account 283)
ADJUSTMENTS ADJUSTMENTS ADJUSTMENTS ADJUSTMENTS
Name of Respondent:Idaho Power Company (1) ☑ An Original(2) ☐ A Resubmission Date of Report:04/16/2024 Year/Period of ReportEnd of: 2023/ Q4ACCUMULATED DEFERRED INCOME TAXES - OTHER (Account 283)CHANGES DURINGYEAR CHANGES DURINGYEAR CHANGES DURINGYEAR CHANGES DURINGYEARLineNo.Account(a)Balance at Beginning ofYear(b)Amounts Debited toAccount 410.1(c)Amounts Credited toAccount 411.1(d)Amounts Debited toAccount 410.2(e)Amounts Credited toAccount 411.2(f)1 Account 2832Electric3(a)Other Electric 145,190,859 35,301,478 7,449,6744(b)Other 18,083,2789TOTAL Electric (Total of lines 3 thru 8)163,274,137 35,301,478 7,449,67410Gas11121314151617TOTAL Gas (Total of lines 11 thru 16)18 TOTAL Other (58,563)201,64419TOTAL (Acct 283) (Enter Total of lines 9, 17and 18)163,215,574 35,301,478 7,449,674 0 201,64420Classification of TOTAL21Federal Income Tax 125,201,634 27,068,875 5,713,153 154,64022State Income Tax 38,013,939 8,232,603 1,736,521 47,00323Local Income Tax NOTESFERC FORM NO. 1 (ED. 12-96)Page 276-277
ACCUMULATED DEFERRED INCOME TAXES - OTHER (Account 283)
ADJUSTMENTS ADJUSTMENTS ADJUSTMENTS ADJUSTMENTSADJUSTMENTSADJUSTMENTSADJUSTMENTSADJUSTMENTS
Debits Debits Credits Credits
Line
No.
Account Credited
(g)
Amount
(h)
Account Debited
(i)
Amount
(j)
Balance at End of Year
(k)
1
2
3 173,042,663
4 190 4,392,481 22,475,759
9 4,392,481 195,518,422
10
11
12
13
14
15
16
17
18 (c)(260,207)
19 0 4,392,481 195,258,215
20
21 190 3,368,593 149,771,309
22 190 1,023,888 45,486,906
23
NOTES
FERC FORM NO. 1 (ED. 12-96)
Page 276-277
FOOTNOTE DATA
ADJUSTMENTS ADJUSTMENTS ADJUSTMENTS ADJUSTMENTSDebitsDebitsCreditsCreditsLineNo.Account Credited(g)Amount(h)Account Debited(i)Amount(j)Balance at End of Year(k)123 173,042,66341904,392,481 22,475,75994,392,481 195,518,422101112131415161718(c)(260,207)19 0 4,392,481 195,258,21520211903,368,593 149,771,309221901,023,888 45,486,90623NOTESFERC FORM NO. 1 (ED. 12-96)Page 276-277
FOOTNOTE DATA
(a) Concept: DescriptionOfAccumulatedDeferredIncomeTaxOther
2023 Changes during Year Adjustments Debits Adjustments Credits 2023
Beginning DR to CR to DR to CR to Acct.Acct.Ending
Line Account Balance 410.1 411.1 410.2 411.2 credited Amount debited Amount Balance
No.(a)b c d e f g h i j k
Line 3:
4024 Renewable Energy Certificates (REC) Sales 835,647 503,819 -----1,339,466
4501 Royalty Income 247,446 -63,657 ----183,789
5008 Gain/Loss on Reaqcuired Debt 212,170 9,067 -----221,237
5023 Pension Expense 62,693,123 9,061,650 -----71,754,773
5035 PCA Expense 33,115,366 -3,373,149 ----29,742,217
5045 Wildfire Mitigation 35077 Deferral 5,940,336 7,271,871 -----13,212,207
5057 Intervenor Funding Orders 88,722 1,148 -----89,870
5058 Fixed Cost Adjustment 10,785,319 2,415,438 -----13,200,757
5060 Oregon PCAM 267,007 8,099 275,106 -----
5066 Boardman Decommission (442,307)240,772 -----(201,535)
5074 Valmy Settlement Adjustment 3,313,557 -1,656,779 ----1,656,778
5077 Valmy Depreciation Adjustment 16,745,775 -1,063,022 ----15,682,753
5079 Community Solar Deferral 43,785 12,658 -----56,443
5081 EIM PCA Offset Estimate (24,097)24,097 ------
5082 Bridger Depreciation Adjust - 283 9,709,816 15,530,259 -----25,240,075
7013 Langley Revenue Accrual 238,101 -73,350 ----164,751
8020 Conservation Expenses 628,535 -927,091 ----(298,556)
8082 Siemens LTP Contract 127,703 17,214 -----144,917
8082 Prepaid Credit Facility 125,281 -10,162 ----115,119
8083 Siemens OR DRB Interest Reserve (49,648)-7,358 ----(57,006)
8704 Boardman Removal Costs 442,667 208,027 -----650,694
8706 OR Annual Reg Exp 10,788 13,749 -----24,537
N/A Oregon CAT Deferral 135,767 (16,390)-----119,377
TOTAL Line 3 145,190,85935,301,478 7,449,674 ----173,042,663
(b) Concept: DescriptionOfAccumulatedDeferredIncomeTaxOther
2023 Changes during Year Adjustments Debits Adjustments Credits 2023
Beginning DR to CR to DR to CR to Acct.Acct.Ending
Line Account Balance 410.1 411.1 410.2 411.2 credited Amount debited Amount Balance
No.(a)b c d e f g h i j k
Line 8:Pension-FAS 158 21,441,503 -----190 6,451,681 27,893,184
Postretirement Plan-FAS 158 (3,358,225)-----190 (2,059,200)(5,417,425)
TOTAL Line 8 18,083,278-----190 4,392,481 22,475,759
(c) Concept: AccumulatedDeferredIncomeTaxesOther
2023 Changes during Year Adjustments Debits Adjustments Credits 2023
Beginning DR to CR to DR to CR to Acct.Acct.Ending
Line Account Balance 410.1 411.1 410.2 411.2 credited Amount debited Amount Balance
No.(a)b c d e f g h i j k
Line 18:EDC-Unrealized Gain/Loss From Rabbi Trust 12,504 ---19,220 ---(6,716)
SMSP-Unrealized Gain/Loss From Rabbi Trust (71,331)---182,375 ---(253,706)
Oregon Non-Op Prop Tax Adj 263 ---48 ---215
TOTAL Line 18 (58,564)---201,643 --(260,207)
FERC FORM NO. 1 (ED. 12-96)
Page 276-277
Name of Respondent:
This report is:
(1) ☑ An Original Date of Report:Year/Period of Report
(a) Concept: DescriptionOfAccumulatedDeferredIncomeTaxOther2023Changes during Year Adjustments Debits Adjustments Credits 2023BeginningDR to CR to DR to CR to Acct.Acct.EndingLineAccountBalance410.1 411.1 410.2 411.2 credited Amount debited Amount BalanceNo.(a)b c d e f g h i j kLine 3:4024 Renewable Energy Certificates (REC) Sales 835,647 503,819 -----1,339,4664501Royalty Income 247,446 -63,657 ----183,7895008Gain/Loss on Reaqcuired Debt 212,170 9,067 -----221,2375023Pension Expense 62,693,123 9,061,650 -----71,754,7735035PCA Expense 33,115,366 -3,373,149 ----29,742,2175045Wildfire Mitigation 35077 Deferral 5,940,336 7,271,871 -----13,212,2075057Intervenor Funding Orders 88,722 1,148 -----89,8705058Fixed Cost Adjustment 10,785,319 2,415,438 -----13,200,7575060Oregon PCAM 267,007 8,099 275,106 -----5066 Boardman Decommission (442,307)240,772 -----(201,535)5074 Valmy Settlement Adjustment 3,313,557 -1,656,779 ----1,656,7785077Valmy Depreciation Adjustment 16,745,775 -1,063,022 ----15,682,7535079Community Solar Deferral 43,785 12,658 -----56,4435081EIM PCA Offset Estimate (24,097)24,097 ------5082 Bridger Depreciation Adjust - 283 9,709,816 15,530,259 -----25,240,0757013Langley Revenue Accrual 238,101 -73,350 ----164,7518020Conservation Expenses 628,535 -927,091 ----(298,556)8082 Siemens LTP Contract 127,703 17,214 -----144,9178082Prepaid Credit Facility 125,281 -10,162 ----115,1198083Siemens OR DRB Interest Reserve (49,648)-7,358 ----(57,006)8704 Boardman Removal Costs 442,667 208,027 -----650,6948706OR Annual Reg Exp 10,788 13,749 -----24,537N/A Oregon CAT Deferral 135,767 (16,390)-----119,377TOTAL Line 3 145,190,85935,301,478 7,449,674 ----173,042,663(b) Concept: DescriptionOfAccumulatedDeferredIncomeTaxOther2023Changes during Year Adjustments Debits Adjustments Credits 2023BeginningDR to CR to DR to CR to Acct.Acct.EndingLineAccountBalance410.1 411.1 410.2 411.2 credited Amount debited Amount BalanceNo.(a)b c d e f g h i j kLine 8:Pension-FAS 158 21,441,503 -----190 6,451,681 27,893,184Postretirement Plan-FAS 158 (3,358,225)-----190 (2,059,200)(5,417,425)TOTAL Line 8 18,083,278-----190 4,392,481 22,475,759(c) Concept: AccumulatedDeferredIncomeTaxesOther2023 Changes during Year Adjustments Debits Adjustments Credits 2023BeginningDR to CR to DR to CR to Acct.Acct.EndingLineAccountBalance410.1 411.1 410.2 411.2 credited Amount debited Amount BalanceNo.(a)b c d e f g h i j kLine 18:EDC-Unrealized Gain/Loss From Rabbi Trust 12,504 ---19,220 ---(6,716)SMSP-Unrealized Gain/Loss From Rabbi Trust (71,331)---182,375 ---(253,706)Oregon Non-Op Prop Tax Adj 263 ---48 ---215TOTAL Line 18 (58,564)---201,643 --(260,207)FERC FORM NO. 1 (ED. 12-96)Page 276-277
Name of Respondent:
This report is:
(1) ☑ An Original Date of Report:Year/Period of Report
Idaho Power Company
(1) ☑ An Original
(2) ☐ A Resubmission
04/16/2024 End of: 2023/ Q4
OTHER REGULATORY LIABILITIES (Account 254)
DEBITS DEBITS
Line
No.
Description and Purpose of Other
Regulatory Liabilities
(a)
Balance at Beginning of
Current Quarter/Year
(b)
Account Credited
(c)
Amount
(d)
Credits
(e)
Balance at End of Current
Quarter/Year
(f)
1 Market to Market Short Term (254001)58,965,734 175 58,894,391 71,343
2 IPUC Order #28661 0 0
3 Oregon Solar Rider (254005)287,173 401 10,053 147,629 424,749
4 OPUC Order #10-198 0 0
5 BPA Credit Residential Idaho (254401)2,021,653 142 15,252,995 16,935,442 3,704,100
6 OPUC Advice #15-13 0 0
7 BPA Credit Residential Oregon (254402)91,246 142 612,826 577,564 55,984
8 OPUC Advice #15-11 0 0
9 BPA Credit Farm Idaho (254403)786,335 142 2,063,102 2,555,047 1,278,280
10 OPUC Advice #15-13 0 0
11 BPA Credit Farm Oregon (254404)119,112 142 165,224 151,228 105,116
12 OPUC Advice #15-11 0 0
13 Idaho Tax Settlement (254451)32,215,180 8,097,874 40,313,054
14 IPUC Order #34071 0 0
15 Oregon Tax Settlement (254452)578,057 578,057
16 OPUC Order #18-199 0 0
17 Bridger Depreciation (254800)3,904,735 400 730,174 3,174,561
18 OPUC Order #12-296 0 0
19 RL-WAQC CRYOVR (254901)1,171,404 401 65,865 54,349 1,159,888
20 Revenue Sharing (254101)0 0
21 Unfunded Accum Def Income Tax (254966)39,960,225 17,397,944 57,358,169
22 RL-DEF INC TAX-ARAM (254967)158,634,044 282 10,684,156 147,949,888
23 RL-DEF INC TAX-ARAM GROSS-UP
(254968)54,985,729 190 3,703,342 51,282,387
24
(a)
Boardman Decommissioning 3,232,854 Various 434,757 2,798,097
25 OPUC Order #12-235, IPUC Order #32457 0 0
26 Market-to-Market Short Term (254203)578,438 175 561,585 16,853
27 Oregon DSM Rider (254202)154,052 Various 1,489,400 2,142,378 807,030
28 OPUC Advice #05-03 0 0
29 Oregon Green Tags (254415)0 Various 401,115 1,012,352 611,237
30 OPUC Order #11-086 0
31 Oregon PCAM (182384)0 Various 236,468 (236,468)
32 OPUC Order #23-185 (Amortization 06/23-
05/24)0
33 Oregon PCAM (182384)0 Various 0 865,126 865,126
34 OPUC Order Pending 0
35 Idaho DSM Rider (254201)0 Various 30,229,460 30,929,822 700,362
36 IPUC Order #28661 0
37 Minor Items (1)14,712 2,754 17,466
41 TOTAL 357,700,683 125,534,913 80,869,509 313,035,279
FERC FORM NO. 1 (REV 02-04)
Page 278
Name of Respondent:
This report is:
(1) ☑ An Original Date of Report:Year/Period of Report
Idaho Power Company (1) ☑ An Original(2) ☐ A Resubmission 04/16/2024 End of: 2023/ Q4OTHER REGULATORY LIABILITIES (Account 254)DEBITS DEBITSLineNo.Description and Purpose of OtherRegulatory Liabilities(a)Balance at Beginning ofCurrent Quarter/Year(b)Account Credited(c)Amount(d)Credits(e)Balance at End of CurrentQuarter/Year(f)1 Market to Market Short Term (254001)58,965,734 175 58,894,391 71,3432IPUC Order #28661 0 03Oregon Solar Rider (254005)287,173 401 10,053 147,629 424,7494OPUC Order #10-198 0 05BPA Credit Residential Idaho (254401)2,021,653 142 15,252,995 16,935,442 3,704,1006OPUC Advice #15-13 0 07BPA Credit Residential Oregon (254402)91,246 142 612,826 577,564 55,9848OPUC Advice #15-11 0 09BPA Credit Farm Idaho (254403)786,335 142 2,063,102 2,555,047 1,278,28010OPUC Advice #15-13 0 011BPA Credit Farm Oregon (254404)119,112 142 165,224 151,228 105,11612OPUC Advice #15-11 0 013Idaho Tax Settlement (254451)32,215,180 8,097,874 40,313,05414IPUC Order #34071 0 015Oregon Tax Settlement (254452)578,057 578,05716OPUC Order #18-199 0 017Bridger Depreciation (254800)3,904,735 400 730,174 3,174,56118OPUC Order #12-296 0 019RL-WAQC CRYOVR (254901)1,171,404 401 65,865 54,349 1,159,88820Revenue Sharing (254101)0 021Unfunded Accum Def Income Tax (254966)39,960,225 17,397,944 57,358,16922RL-DEF INC TAX-ARAM (254967)158,634,044 282 10,684,156 147,949,88823RL-DEF INC TAX-ARAM GROSS-UP(254968)54,985,729 190 3,703,342 51,282,38724(a)Boardman Decommissioning 3,232,854 Various 434,757 2,798,09725OPUC Order #12-235, IPUC Order #32457 0 026Market-to-Market Short Term (254203)578,438 175 561,585 16,85327Oregon DSM Rider (254202)154,052 Various 1,489,400 2,142,378 807,03028OPUC Advice #05-03 0 029Oregon Green Tags (254415)0 Various 401,115 1,012,352 611,23730OPUC Order #11-086 031Oregon PCAM (182384)0 Various 236,468 (236,468)32 OPUC Order #23-185 (Amortization 06/23-05/24)033Oregon PCAM (182384)0 Various 0 865,126 865,12634OPUC Order Pending 035Idaho DSM Rider (254201)0 Various 30,229,460 30,929,822 700,36236IPUC Order #28661 037Minor Items (1)14,712 2,754 17,46641TOTAL357,700,683 125,534,913 80,869,509 313,035,279FERC FORM NO. 1 (REV 02-04)Page 278
Name of Respondent:
This report is:
(1) ☑ An Original Date of Report:Year/Period of Report
Idaho Power Company
(1) ☑ An Original
(2) ☐ A Resubmission
04/16/2024 End of: 2023/ Q4
FOOTNOTE DATA
(a) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities
The Boardman Decommissioning is composed of multiple accounts aggregated into one line for clean presentation in the year-end financial statements.
FERC FORM NO. 1 (REV 02-04)
Page 278
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original Date of Report:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
Idaho Power Company (1) ☑ An Original(2) ☐ A Resubmission 04/16/2024 End of: 2023/ Q4FOOTNOTE DATA(a) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilitiesThe Boardman Decommissioning is composed of multiple accounts aggregated into one line for clean presentation in the year-end financial statements.FERC FORM NO. 1 (REV 02-04)Page 278
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original Date of Report:
04/16/2024
Year/Period of Report
End of: 2023/ Q4Idaho Power Company
(1) ☑ An Original
(2) ☐ A Resubmission
04/16/2024 End of: 2023/ Q4
Electric Operating Revenues
Line
No.
Title of Account
(a)
Operating Revenues
Year to Date
Quarterly/Annual
(b)
Operating Revenues
Previous year (no
Quarterly)
(c)
MEGAWATT HOURS
SOLD Year to Date
Quarterly/Annual
(d)
MEGAWATT HOURS
SOLD Amount
Previous year (no
Quarterly)
(e)
AVG.NO.
CUSTOMERS PER
MONTH Current
Year (no Quarterly)
(f)
AVG.NO.
CUSTOMERS
PER MONTH
Previous
Year (no
Quarterly)
(g)
1 Sales of Electricity
2 (440) Residential Sales 686,508,368 647,174,173 5,902,715 6,056,124 525,110 512,803
3 (442) Commercial and Industrial Sales
4 Small (or Comm.) (See Instr. 4)550,342,565 517,216,222 6,049,846 6,230,687 95,522 94,237
5 Large (or Ind.) (See Instr. 4)245,662,658 218,518,077 3,537,648 3,509,694 131 126
6 (444) Public Street and Highway
Lighting 4,183,813 4,035,747 24,783 25,950 4,677 4,431
7 (445) Other Sales to Public Authorities
8 (446) Sales to Railroads and Railways
9 (448) Interdepartmental Sales
10 TOTAL Sales to Ultimate Consumers 1,486,697,404 1,386,944,219 15,514,992 15,822,455 625,440 611,597
11 (447) Sales for Resale 167,834,037 145,798,279 2,095,145 1,318,132
12 TOTAL Sales of Electricity 1,654,531,441 1,532,742,498 17,610,137 17,140,587 625,440 611,597
13 (Less) (449.1) Provision for Rate
Refunds 8,780,127 8,780,127
14 TOTAL Revenues Before Prov. for
Refunds 1,645,751,314 1,523,962,371 17,610,137 17,140,587 625,440 611,597
15 Other Operating Revenues
16 (450) Forfeited Discounts
17 (451) Miscellaneous Service
Revenues
(a)5,220,513 (c)4,936,204
18 (453) Sales of Water and Water Power
19 (454) Rent from Electric Property 19,164,739 18,827,074
20 (455) Interdepartmental Rents
21 (456) Other Electric Revenues (b)32,698,057 (d)34,010,537
22 (456.1) Revenues from Transmission
of Electricity of Others 60,654,137 60,797,833
23 (457.1) Regional Control Service
Revenues
24 (457.2) Miscellaneous Revenues
25 Other Miscellaneous Operating
Revenues
26 TOTAL Other Operating Revenues 117,737,446 118,571,648
27 TOTAL Electric Operating Revenues 1,763,488,760 1,642,534,019
Line12, column (b) includes $ (735,211) of unbilled revenues.
Line12, column (d) includes (64,947) MWH relating to unbilled revenues
FERC FORM NO. 1 (REV. 12-05)
Page 300-301
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original Date of Report:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
Idaho Power Company (1) ☑ An Original(2) ☐ A Resubmission 04/16/2024 End of: 2023/ Q4Electric Operating RevenuesLineNo.Title of Account(a)Operating RevenuesYear to DateQuarterly/Annual(b)Operating RevenuesPrevious year (noQuarterly)(c)MEGAWATT HOURSSOLD Year to DateQuarterly/Annual(d)MEGAWATT HOURSSOLD AmountPrevious year (noQuarterly)(e)AVG.NO.CUSTOMERS PERMONTH CurrentYear (no Quarterly)(f)AVG.NO.CUSTOMERSPER MONTHPreviousYear (noQuarterly)(g)1 Sales of Electricity2(440) Residential Sales 686,508,368 647,174,173 5,902,715 6,056,124 525,110 512,8033(442) Commercial and Industrial Sales4Small (or Comm.) (See Instr. 4)550,342,565 517,216,222 6,049,846 6,230,687 95,522 94,2375Large (or Ind.) (See Instr. 4)245,662,658 218,518,077 3,537,648 3,509,694 131 1266(444) Public Street and HighwayLighting 4,183,813 4,035,747 24,783 25,950 4,677 4,4317(445) Other Sales to Public Authorities8(446) Sales to Railroads and Railways9(448) Interdepartmental Sales10TOTAL Sales to Ultimate Consumers 1,486,697,404 1,386,944,219 15,514,992 15,822,455 625,440 611,59711(447) Sales for Resale 167,834,037 145,798,279 2,095,145 1,318,13212TOTAL Sales of Electricity 1,654,531,441 1,532,742,498 17,610,137 17,140,587 625,440 611,59713(Less) (449.1) Provision for RateRefunds 8,780,127 8,780,12714TOTAL Revenues Before Prov. forRefunds 1,645,751,314 1,523,962,371 17,610,137 17,140,587 625,440 611,59715Other Operating Revenues16(450) Forfeited Discounts17(451) Miscellaneous ServiceRevenues (a)5,220,513 (c)4,936,20418(453) Sales of Water and Water Power19(454) Rent from Electric Property 19,164,739 18,827,07420(455) Interdepartmental Rents21(456) Other Electric Revenues (b)32,698,057 (d)34,010,53722(456.1) Revenues from Transmissionof Electricity of Others 60,654,137 60,797,83323(457.1) Regional Control ServiceRevenues24(457.2) Miscellaneous Revenues25Other Miscellaneous OperatingRevenues26TOTAL Other Operating Revenues 117,737,446 118,571,64827TOTAL Electric Operating Revenues 1,763,488,760 1,642,534,019Line12, column (b) includes $ (735,211) of unbilled revenues.Line12, column (d) includes (64,947) MWH relating to unbilled revenuesFERC FORM NO. 1 (REV. 12-05)Page 300-301
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original Date of Report:
04/16/2024
Year/Period of Report
End of: 2023/ Q4Idaho Power Company
(1) ☑ An Original
(2) ☐ A Resubmission
04/16/2024 End of: 2023/ Q4
FOOTNOTE DATA
(a) Concept: MiscellaneousServiceRevenues
This amount consists of:
Service Establishment/Connection Charges: $4,774,906
(Includes late and after hour charges)
Misc.: $445,607
(b) Concept: OtherElectricRevenue
This amount consists of:
DSM Activity: $31,947,854
Alternate Distribution Services: $745,427
Misc. Under $250,000: $4,776
(c) Concept: MiscellaneousServiceRevenues
This amount consists of:
Service Establishment/Connection Charges: $4,305,005
(Includes late and after hour charges)
Misc. Under $250,000: $631,199
(d) Concept: OtherElectricRevenue
This amount consists of:
DSM Activity: $33,197,113
Alternate Distribution Services: $813,619
Misc. Under $250,000: ($195.00)
FERC FORM NO. 1 (REV. 12-05)
Page 300-301
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original Date of Report:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
Idaho Power Company (1) ☑ An Original(2) ☐ A Resubmission 04/16/2024 End of: 2023/ Q4FOOTNOTE DATA(a) Concept: MiscellaneousServiceRevenuesThis amount consists of:Service Establishment/Connection Charges: $4,774,906(Includes late and after hour charges)Misc.: $445,607(b) Concept: OtherElectricRevenueThis amount consists of:DSM Activity: $31,947,854Alternate Distribution Services: $745,427Misc. Under $250,000: $4,776(c) Concept: MiscellaneousServiceRevenuesThis amount consists of:Service Establishment/Connection Charges: $4,305,005(Includes late and after hour charges)Misc. Under $250,000: $631,199(d) Concept: OtherElectricRevenueThis amount consists of:DSM Activity: $33,197,113Alternate Distribution Services: $813,619Misc. Under $250,000: ($195.00)FERC FORM NO. 1 (REV. 12-05)Page 300-301
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original Date of Report:
04/16/2024
Year/Period of Report
End of: 2023/ Q4Idaho Power Company
(1) ☑ An Original
(2) ☐ A Resubmission
04/16/2024 End of: 2023/ Q4
SALES OF ELECTRICITY BY RATE SCHEDULES
Line
No.
Number and Title of Rate Schedule
(a)
MWh Sold
(b)
Revenue
(c)
Average Number of
Customers
(d)
KWh of Sales Per
Customer
(e)
Revenue Per KWh
Sold
(f)
1 01 RESIDENTIAL 5,846,607 669,565,340 508,778 11,491.4698 0.1145
2 03 Residential Master Meter 5,174 567,835 19 272,315.7895 0.1097
3 04 Residential EW 0 0 0
4 05 Residential TOD 18,137 2,005,274 991 18,301.7154 0.1106
5 06 Residential On-Site Generation 78,449 9,456,567 15,322 5,120.0235 0.1205
6 15 Dusk to Dawn Light 1,059 655,071 0 0.6186
7 Other 0 7,233,769 0
41 TOTAL Billed Residential Sales 5,949,426 689,483,856 525,110 11,329.8661 0.1159
42 TOTAL Unbilled Rev. (See Instr. 6)(46,711)(2,975,488)0.0637
43 TOTAL 5,902,715 686,508,368 525,110 11,240.9114 0.1163
FERC FORM NO. 1 (ED. 12-95)
Page 304
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original Date of Report:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
Idaho Power Company (1) ☑ An Original(2) ☐ A Resubmission 04/16/2024 End of: 2023/ Q4SALES OF ELECTRICITY BY RATE SCHEDULESLineNo.Number and Title of Rate Schedule(a)MWh Sold(b)Revenue(c)Average Number ofCustomers(d)KWh of Sales PerCustomer(e)Revenue Per KWhSold(f)1 01 RESIDENTIAL 5,846,607 669,565,340 508,778 11,491.4698 0.1145203 Residential Master Meter 5,174 567,835 19 272,315.7895 0.1097304 Residential EW 0 0 0405 Residential TOD 18,137 2,005,274 991 18,301.7154 0.1106506 Residential On-Site Generation 78,449 9,456,567 15,322 5,120.0235 0.1205615 Dusk to Dawn Light 1,059 655,071 0 0.61867Other07,233,769 041TOTAL Billed Residential Sales 5,949,426 689,483,856 525,110 11,329.8661 0.115942TOTAL Unbilled Rev. (See Instr. 6)(46,711)(2,975,488)0.063743TOTAL5,902,715 686,508,368 525,110 11,240.9114 0.1163FERC FORM NO. 1 (ED. 12-95)Page 304
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original Date of Report:
04/16/2024
Year/Period of Report
End of: 2023/ Q4Idaho Power Company
(1) ☑ An Original
(2) ☐ A Resubmission
04/16/2024 End of: 2023/ Q4
SALES OF ELECTRICITY BY RATE SCHEDULES
Line
No.
Number and Title of Rate Schedule
(a)
MWh Sold
(b)
Revenue
(c)
Average Number of
Customers
(d)
KWh of Sales Per
Customer
(e)
Revenue Per KWh
Sold
(f)
1 07 General Service 157,462 21,698,224 32,408 4,858.7386 0.1378
2 08 General Service On-Site Generation 174 26,198 72 2,416.6667 0.1506
3 09P General Service 649,317 50,642,827 297 2,186,252.5253 0.078
4 09S General Service 3,423,963 299,664,734 39,230 87,279.1996 0.0875
5 09T General Service 7,545 593,589 4 1,886,250 0.0787
6 15 Dusk to Dawn Light 1,776 764,340 0 0.4304
7 24S Irrigation & Pump 1,805,855 174,173,637 22,246 81,176.616 0.0964
8 24T Irrigation & Pump 0 0 0
9 40 General Service 13,607 1,356,840 1,265 10,756.5217 0.0997
41 TOTAL Billed Small or Commercial 6,059,699 548,920,389 95,522 63,437.7316 0.0906
42 TOTAL Unbilled Rev. Small or Commercial
(See Instr. 6)(9,853)1,422,176 (0.1443)
43 TOTAL Small or Commercial 6,049,846 550,342,565 95,522 63,334.5826 0.091
FERC FORM NO. 1 (ED. 12-95)
Page 304
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original Date of Report:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
Idaho Power Company (1) ☑ An Original(2) ☐ A Resubmission 04/16/2024 End of: 2023/ Q4SALES OF ELECTRICITY BY RATE SCHEDULESLineNo.Number and Title of Rate Schedule(a)MWh Sold(b)Revenue(c)Average Number ofCustomers(d)KWh of Sales PerCustomer(e)Revenue Per KWhSold(f)1 07 General Service 157,462 21,698,224 32,408 4,858.7386 0.1378208 General Service On-Site Generation 174 26,198 72 2,416.6667 0.1506309P General Service 649,317 50,642,827 297 2,186,252.5253 0.078409S General Service 3,423,963 299,664,734 39,230 87,279.1996 0.0875509T General Service 7,545 593,589 4 1,886,250 0.0787615 Dusk to Dawn Light 1,776 764,340 0 0.4304724S Irrigation & Pump 1,805,855 174,173,637 22,246 81,176.616 0.0964824T Irrigation & Pump 0 0 0940 General Service 13,607 1,356,840 1,265 10,756.5217 0.099741TOTAL Billed Small or Commercial 6,059,699 548,920,389 95,522 63,437.7316 0.090642TOTAL Unbilled Rev. Small or Commercial(See Instr. 6)(9,853)1,422,176 (0.1443)43 TOTAL Small or Commercial 6,049,846 550,342,565 95,522 63,334.5826 0.091FERC FORM NO. 1 (ED. 12-95)Page 304
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original Date of Report:
04/16/2024
Year/Period of Report
End of: 2023/ Q4Idaho Power Company
(1) ☑ An Original
(2) ☐ A Resubmission
04/16/2024 End of: 2023/ Q4
SALES OF ELECTRICITY BY RATE SCHEDULES
Line
No.
Number and Title of Rate Schedule
(a)
MWh Sold
(b)
Revenue
(c)
Average Number of
Customers
(d)
KWh of Sales Per
Customer
(e)
Revenue Per KWh
Sold
(f)
1 19P Uniform Rate 2,319,468 163,863,474 123 18,857,463.4146 0.0706
2 19S Uniform Rate 6,730 513,623 1 6,730,000 0.0763
3 19T Uniform Rate 128,404 9,697,405 3 42,801,333.3333 0.0755
4 Special Contracts 1,091,371 69,592,710 4 272,842,750 0.0638
5 Other 0 1,186,358 0
41 TOTAL Billed Large (or Ind.) Sales 3,545,973 244,853,570 131 27,068,496.1832 0.0691
42 TOTAL Unbilled Rev. Large (or Ind.) (See
Instr. 6)(8,325)809,088 (0.0972)
43 TOTAL Large (or Ind.)3,537,648 245,662,658 131 27,004,946.5649 0.0694
FERC FORM NO. 1 (ED. 12-95)
Page 304
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original Date of Report:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
Idaho Power Company (1) ☑ An Original(2) ☐ A Resubmission 04/16/2024 End of: 2023/ Q4SALES OF ELECTRICITY BY RATE SCHEDULESLineNo.Number and Title of Rate Schedule(a)MWh Sold(b)Revenue(c)Average Number ofCustomers(d)KWh of Sales PerCustomer(e)Revenue Per KWhSold(f)1 19P Uniform Rate 2,319,468 163,863,474 123 18,857,463.4146 0.0706219S Uniform Rate 6,730 513,623 1 6,730,000 0.0763319T Uniform Rate 128,404 9,697,405 3 42,801,333.3333 0.07554Special Contracts 1,091,371 69,592,710 4 272,842,750 0.06385Other01,186,358 041TOTAL Billed Large (or Ind.) Sales 3,545,973 244,853,570 131 27,068,496.1832 0.069142TOTAL Unbilled Rev. Large (or Ind.) (SeeInstr. 6)(8,325)809,088 (0.0972)43 TOTAL Large (or Ind.)3,537,648 245,662,658 131 27,004,946.5649 0.0694FERC FORM NO. 1 (ED. 12-95)Page 304
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original Date of Report:
04/16/2024
Year/Period of Report
End of: 2023/ Q4Idaho Power Company
(1) ☑ An Original
(2) ☐ A Resubmission
04/16/2024 End of: 2023/ Q4
SALES OF ELECTRICITY BY RATE SCHEDULES
Line
No.
Number and Title of Rate Schedule
(a)
MWh Sold
(b)
Revenue
(c)
Average Number of
Customers
(d)
KWh of Sales Per
Customer
(e)
Revenue Per KWh
Sold
(f)
1 40 General Service 780 78,188 494 1,578.9474 0.1002
2 41 Municipal Lighting (A,B,C)21,055 3,867,376 3,369 6,249.629 0.1837
3 42 Signal Lighting 3,005 228,713 814 3,691.6462 0.0761
4 Other 0 524 0
41 TOTAL Billed Public Street and Highway
Lighting 24,840 4,174,801 4,677 5,311.0969 0.1681
42 TOTAL Unbilled Rev. (See Instr. 6)(57)9,012 (0.1581)
43 TOTAL 24,783 4,183,813 4,677 5,298.9096 0.1688
FERC FORM NO. 1 (ED. 12-95)
Page 304
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original Date of Report:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
Idaho Power Company (1) ☑ An Original(2) ☐ A Resubmission 04/16/2024 End of: 2023/ Q4SALES OF ELECTRICITY BY RATE SCHEDULESLineNo.Number and Title of Rate Schedule(a)MWh Sold(b)Revenue(c)Average Number ofCustomers(d)KWh of Sales PerCustomer(e)Revenue Per KWhSold(f)1 40 General Service 780 78,188 494 1,578.9474 0.1002241 Municipal Lighting (A,B,C)21,055 3,867,376 3,369 6,249.629 0.1837342 Signal Lighting 3,005 228,713 814 3,691.6462 0.07614Other0524041TOTAL Billed Public Street and HighwayLighting 24,840 4,174,801 4,677 5,311.0969 0.168142TOTAL Unbilled Rev. (See Instr. 6)(57)9,012 (0.1581)43 TOTAL 24,783 4,183,813 4,677 5,298.9096 0.1688FERC FORM NO. 1 (ED. 12-95)Page 304
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original Date of Report:
04/16/2024
Year/Period of Report
End of: 2023/ Q4Idaho Power Company
(1) ☑ An Original
(2) ☐ A Resubmission
04/16/2024 End of: 2023/ Q4
SALES OF ELECTRICITY BY RATE SCHEDULES
Line
No.
Number and Title of Rate Schedule
(a)
MWh Sold
(b)
Revenue
(c)
Average Number of
Customers
(d)
KWh of Sales Per
Customer
(e)
Revenue Per KWh
Sold
(f)
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41 TOTAL Billed Provision For Rate Refunds
42 TOTAL Unbilled Rev. (See Instr. 6)
Idaho Power Company (1) ☑ An Original(2) ☐ A Resubmission 04/16/2024 End of: 2023/ Q4SALES OF ELECTRICITY BY RATE SCHEDULESLineNo.Number and Title of Rate Schedule(a)MWh Sold(b)Revenue(c)Average Number ofCustomers(d)KWh of Sales PerCustomer(e)Revenue Per KWhSold(f)1234567891011121314151617181920212223242526272829303132333435363738394041 TOTAL Billed Provision For Rate Refunds42TOTAL Unbilled Rev. (See Instr. 6)
43 TOTAL 8,780,127
FERC FORM NO. 1 (ED. 12-95)
Page 304
SALES OF ELECTRICITY BY RATE SCHEDULES
Line
No.
Number and Title of Rate Schedule
(a)
MWh Sold
(b)
Revenue
(c)
Average Number of
Customers
(d)
KWh of Sales Per
Customer
(e)
Revenue Per KWh
Sold
(f)
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original Date of Report:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
43 TOTAL 8,780,127FERC FORM NO. 1 (ED. 12-95)Page 304SALES OF ELECTRICITY BY RATE SCHEDULESLineNo.Number and Title of Rate Schedule(a)MWh Sold(b)Revenue(c)Average Number ofCustomers(d)KWh of Sales PerCustomer(e)Revenue Per KWhSold(f)
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original Date of Report:
04/16/2024
Year/Period of Report
End of: 2023/ Q4Idaho Power Company
(1)
(2) ☐ A Resubmission
04/16/2024 End of: 2023/ Q4
SALES OF ELECTRICITY BY RATE SCHEDULES
Line
No.
Number and Title of Rate Schedule
(a)
MWh Sold
(b)
Revenue
(c)
Average Number of
Customers
(d)
KWh of Sales Per
Customer
(e)
Revenue Per KWh
Sold
(f)
41 TOTAL Billed - All Accounts 15,579,938 1,487,432,616 625,440 24,910.3639 0.0955
42 TOTAL Unbilled Rev. (See Instr. 6) - All
Accounts (64,946)(735,212)0.0113
43 TOTAL - All Accounts 15,514,992 1,486,697,404 625,440 24,806.5234 0.0958
FERC FORM NO. 1 (ED. 12-95)
Page 304
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original Date of Report:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
Idaho Power Company (1) (2) ☐ A Resubmission 04/16/2024 End of: 2023/ Q4SALES OF ELECTRICITY BY RATE SCHEDULESLineNo.Number and Title of Rate Schedule(a)MWh Sold(b)Revenue(c)Average Number ofCustomers(d)KWh of Sales PerCustomer(e)Revenue Per KWhSold(f)41 TOTAL Billed - All Accounts 15,579,938 1,487,432,616 625,440 24,910.3639 0.095542TOTAL Unbilled Rev. (See Instr. 6) - AllAccounts (64,946)(735,212)0.011343TOTAL - All Accounts 15,514,992 1,486,697,404 625,440 24,806.5234 0.0958FERC FORM NO. 1 (ED. 12-95)Page 304
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original Date of Report:
04/16/2024
Year/Period of Report
End of: 2023/ Q4Idaho Power Company
(2) ☐ A Resubmission
04/16/2024 End of: 2023/ Q4
SALES FOR RESALE (Account 447)
ACTUAL DEMAND (MW)ACTUAL DEMAND (MW)
Line
No.
Name of Company or Public Authority
(Footnote Affiliations)
(a)
Statistical
Classification
(b)
FERC Rate
Schedule or Tariff
Number
(c)
Average Monthly Billing
Demand (MW)
(d)
Average Monthly NCP
Demand
(e)
Average Monthly CP
Demand
(f)
1 3PR Trading Inc SF WSPP
2 ADM Investor Services, Inc.
(a)
OS WSPP
3 AmpRenew Offtake 1 LLC
(b)
OS OATT
4 Avangrid Renewables, LLC
(c)
OS OATT
5 AVANGRID RENEWABLES, LLC SF WSPP
6 Avista Corp.SF WSPP
7 Avista Corp. - WWP Div.
(d)
OS OATT
8 Basin Electric Power Cooperative
(e)
OS OATT
9 Basin Electric Power Cooperative SF WSPP
10 Black Hills Power Inc.
(f)
OS OATT
11 Black Hills Power Inc.SF WSPP
12 Bonneville Power
(g)
OS OATT
13 Bonneville Power Administration SF WSPP
14 BP Energy Company
(h)
OS OATT
15 BP Energy Company SF WSPP
16 Brookfield Renewable Trading & Marketing
(i)
OS OATT
17 Brookfield Renewable Trading and Marketing
LP SF WSPP
18 California Independent System Operator
(j)
SF CAISO
19 Calpine Energy Solutions, LLC
(k)
OS OATT
20 Calpine Energy Solutions, LLC SF WSPP
21 Chelan Co PUD SF WSPP
22 Citigroup Energy Inc.SF ISDA
23 City of Glendale SF WSPP
24 Clatskanie PUD SF WSPP
25 ConocoPhillips Company
(l)
OS OATT
26 ConocoPhillips Company SF WSPP
27 Constellation Energy Generation, LLC SF WSPP
28 CP Energy Marking Inc
(m)
OS OATT
29 Direct Energy Business Marketing, LLC SF WSPP
30 Dynasty Power Inc.
(n)
OS OATT
31 Dynasty Power Inc.SF WSPP
32 EDF Trading North America
(o)
OS OATT
33 EDF Trading North America, LLC SF WSPP
34 Energy Keepers, Inc SF WSPP
35 Energy Keepers, Inc.
(p)
OS OATT
FERC FORM NO. 1 (ED. 12-90)
Page 310-311
Idaho Power Company (2) ☐ A Resubmission 04/16/2024 End of: 2023/ Q4SALES FOR RESALE (Account 447)ACTUAL DEMAND (MW)ACTUAL DEMAND (MW)LineNo.Name of Company or Public Authority(Footnote Affiliations)(a)StatisticalClassification(b)FERC RateSchedule or TariffNumber(c)Average Monthly BillingDemand (MW)(d)Average Monthly NCPDemand(e)Average Monthly CPDemand(f)1 3PR Trading Inc SF WSPP2ADM Investor Services, Inc.(a)OS WSPP3AmpRenew Offtake 1 LLC (b)OS OATT4Avangrid Renewables, LLC (c)OS OATT5AVANGRID RENEWABLES, LLC SF WSPP6Avista Corp.SF WSPP7Avista Corp. - WWP Div.(d)OS OATT8Basin Electric Power Cooperative (e)OS OATT9Basin Electric Power Cooperative SF WSPP10Black Hills Power Inc.(f)OS OATT11Black Hills Power Inc.SF WSPP12Bonneville Power (g)OS OATT13Bonneville Power Administration SF WSPP14BP Energy Company (h)OS OATT15BP Energy Company SF WSPP16Brookfield Renewable Trading & Marketing (i)OS OATT17Brookfield Renewable Trading and MarketingLP SF WSPP18California Independent System Operator (j)SF CAISO19Calpine Energy Solutions, LLC (k)OS OATT20Calpine Energy Solutions, LLC SF WSPP21Chelan Co PUD SF WSPP22Citigroup Energy Inc.SF ISDA23City of Glendale SF WSPP24Clatskanie PUD SF WSPP25ConocoPhillips Company (l)OS OATT26ConocoPhillips Company SF WSPP27Constellation Energy Generation, LLC SF WSPP28CP Energy Marking Inc (m)OS OATT29Direct Energy Business Marketing, LLC SF WSPP30Dynasty Power Inc.(n)OS OATT31Dynasty Power Inc.SF WSPP32EDF Trading North America (o)OS OATT33EDF Trading North America, LLC SF WSPP34Energy Keepers, Inc SF WSPP35Energy Keepers, Inc.(p)OS OATTFERC FORM NO. 1 (ED. 12-90)Page 310-311
36 Eugene Water & Electric Board SF WSPP
37 Guzman Energy Group LLC
(q)
OS OATT
38 Guzman Energy LLC SF WSPP
39 Macquarie Energy LLC
(r)
OS OATT
40 Macquarie Energy LLC SF WSPP
41 MAG Energy Solutions
(s)
OS OATT
42 Mercuria Energy America, LLC
(t)
OS OATT
43 Mercuria Energy America, LLC SF WSPP
44 Morgan Stanley Capital Group Inc.
(u)
OS OATT
45 Morgan Stanley Capital Group Inc.SF ISDA
46 NorthWestern Energy SF WSPP
47 PacifiCorp
(v)
OS T-7
48 PacifiCorp SF WSPP
49 PacifiCorp Inc.
(w)
OS OATT
50 Phillips 66 Energy Trading LLC
(x)
OS OATT
51 Phillips 66 Energy Trading LLC SF WSPP
52 Portland General Electric Company
(y)
OS OATT
53 Portland General Electric Company SF WSPP
54 Powerex Corp.
(z)
OS OATT
55 Powerex Corp.SF WSPP
56 Public Service Company of Colorado SF WSPP
57 Puget Sound Energy
(aa)
OS OATT
58 Puget Sound Energy, Inc.SF WSPP
59 Rainbow Energy Marketing Corporation
(ab)
OS OATT
60 Rainbow Energy Marketing Corporation SF WSPP
61 Riley Solar I
(ac)
OS OATT
62 Seattle City Light SF WSPP
63 Shell Energy North America (US), L.P.
(ad)
OS OATT
64 Shell Energy North America (US), L.P.SF WSPP
65 Sierra Pacific Power Co., dba NV Energy
(ae)
OS T-7
66 Snohomish County PUD SF WSPP
67 Starvation Solar I, LLC
(af)
OS OATT
68 Suntex Solar, LLC
(ag)
OS OATT
69 Tacoma Power SF WSPP
70 TEC Energy Inc.
(ah)
OS OATT
71 Tenaska Power Services Co.
(ai)
OS OATT
SALES FOR RESALE (Account 447)
ACTUAL DEMAND (MW)ACTUAL DEMAND (MW)
Line
No.
Name of Company or Public Authority
(Footnote Affiliations)
(a)
Statistical
Classification
(b)
FERC Rate
Schedule or Tariff
Number
(c)
Average Monthly Billing
Demand (MW)
(d)
Average Monthly NCP
Demand
(e)
Average Monthly CP
Demand
(f)
FERC FORM NO. 1 (ED. 12-90)
Page 310-311
36 Eugene Water & Electric Board SF WSPP37Guzman Energy Group LLC (q)OS OATT38Guzman Energy LLC SF WSPP39Macquarie Energy LLC (r)OS OATT40Macquarie Energy LLC SF WSPP41MAG Energy Solutions (s)OS OATT42Mercuria Energy America, LLC (t)OS OATT43Mercuria Energy America, LLC SF WSPP44Morgan Stanley Capital Group Inc.(u)OS OATT45Morgan Stanley Capital Group Inc.SF ISDA46NorthWestern Energy SF WSPP47PacifiCorp(v)OS T-748PacifiCorpSFWSPP49PacifiCorp Inc.(w)OS OATT50Phillips 66 Energy Trading LLC (x)OS OATT51Phillips 66 Energy Trading LLC SF WSPP52Portland General Electric Company (y)OS OATT53Portland General Electric Company SF WSPP54Powerex Corp.(z)OS OATT55Powerex Corp.SF WSPP56Public Service Company of Colorado SF WSPP57Puget Sound Energy (aa)OS OATT58Puget Sound Energy, Inc.SF WSPP59Rainbow Energy Marketing Corporation (ab)OS OATT60Rainbow Energy Marketing Corporation SF WSPP61Riley Solar I (ac)OS OATT62Seattle City Light SF WSPP63Shell Energy North America (US), L.P.(ad)OS OATT64Shell Energy North America (US), L.P.SF WSPP65Sierra Pacific Power Co., dba NV Energy (ae)OS T-766Snohomish County PUD SF WSPP67Starvation Solar I, LLC (af)OS OATT68Suntex Solar, LLC (ag)OS OATT69Tacoma Power SF WSPP70TEC Energy Inc.(ah)OS OATT71Tenaska Power Services Co.(ai)OS OATTSALES FOR RESALE (Account 447)ACTUAL DEMAND (MW)ACTUAL DEMAND (MW)LineNo.Name of Company or Public Authority(Footnote Affiliations)(a)StatisticalClassification(b)FERC RateSchedule or TariffNumber(c)Average Monthly BillingDemand (MW)(d)Average Monthly NCPDemand(e)Average Monthly CPDemand(f)FERC FORM NO. 1 (ED. 12-90)Page 310-311
72 Tenaska Power Services Co.SF WSPP
73 The Energy Authority, Inc.
(aj)
OS OATT
74 The Energy Authority, Inc.SF WSPP
75 TransAlta Energy Marketing (U.S.) Inc.
(ak)
OS OATT
76 TransAlta Energy Marketing (U.S.) Inc.SF WSPP
77 Transmission Penalty Distribution
(al)
OS -
78 Uniper Global Commodities
(am)
OS OATT
79 Vitol Inc.
(an)
OS OATT
80 Vitol Inc.SF WSPP
81 West Hines Solar, LLC
(ao)
OS OATT
82 Western Area Power Administration (WACM)
(ap)
OS T-7
83 Western Area Power Administration (WACM)
(aq)
OS WSPP
15 Subtotal - RQ
16 Subtotal-Non-RQ
17 Total
FERC FORM NO. 1 (ED. 12-90)
Page 310-311
SALES FOR RESALE (Account 447)
ACTUAL DEMAND (MW)ACTUAL DEMAND (MW)
Line
No.
Name of Company or Public Authority
(Footnote Affiliations)
(a)
Statistical
Classification
(b)
FERC Rate
Schedule or Tariff
Number
(c)
Average Monthly Billing
Demand (MW)
(d)
Average Monthly NCP
Demand
(e)
Average Monthly CP
Demand
(f)
SALES FOR RESALE (Account 447)
REVENUE REVENUE REVENUEFERC FORM NO. 1 (ED. 12-90)
72 Tenaska Power Services Co.SF WSPP73The Energy Authority, Inc.(aj)OS OATT74The Energy Authority, Inc.SF WSPP75TransAlta Energy Marketing (U.S.) Inc.(ak)OS OATT76TransAlta Energy Marketing (U.S.) Inc.SF WSPP77Transmission Penalty Distribution (al)OS -78 Uniper Global Commodities (am)OS OATT79Vitol Inc.(an)OS OATT80Vitol Inc.SF WSPP81West Hines Solar, LLC (ao)OS OATT82Western Area Power Administration (WACM)(ap)OS T-783Western Area Power Administration (WACM)(aq)OS WSPP15Subtotal - RQ16Subtotal-Non-RQ17TotalFERC FORM NO. 1 (ED. 12-90)Page 310-311SALES FOR RESALE (Account 447)ACTUAL DEMAND (MW)ACTUAL DEMAND (MW)LineNo.Name of Company or Public Authority(Footnote Affiliations)(a)StatisticalClassification(b)FERC RateSchedule or TariffNumber(c)Average Monthly BillingDemand (MW)(d)Average Monthly NCPDemand(e)Average Monthly CPDemand(f)
SALES FOR RESALE (Account 447)
REVENUE REVENUE REVENUEFERC FORM NO. 1 (ED. 12-90)
Line
No.
Megawatt Hours Sold
(g)
Demand Charges ($)
(h)
Energy Charges ($)
(i)
Other Charges ($)
(j)
Total ($) (h+i+j)
(k)
1 477,375 0 34,284,190 0 34,284,190
2 0 0 0 4,444,818 4,444,818
3 0 0 0 17,152 17,152
4 0 0 0 23,614 23,614
5 14,227 0 911,321 0 911,321
6 44,165 0 2,804,959 0 2,804,959
7 0 0 0 5,835 5,835
8 0 0 0 81,253 81,253
9 775 0 44,500 0 44,500
10 0 0 0 14,437 14,437
11 622 0 4,177 0 4,177
12 0 0 0 5,787,496 5,787,496
13 235,495 0 13,537,113 0 13,537,113
14 0 0 0 158 158
15 20,287 0 2,869,453 0 2,869,453
16 0 0 0 657 657
17 78 0 (7,513)0 (7,513)
18 50,010 0 11,555,808 0 11,555,808
19 0 0 0 4,499 4,499
20 111,600 0 1,767,684 0 1,767,684
21 30 0 (45,631)0 (45,631)
22 17,544 0 2,240,329 0 2,240,329
23 48,800 0 8,372,400 0 8,372,400
24 812 0 37,850 0 37,850
25 0 0 0 4,599 4,599
26 47,672 0 6,531,040 0 6,531,040
27 219,363 0 11,367,737 0 11,367,737
28 0 0 0 1,296 1,296
29 18,600 0 2,535,174 0 2,535,174
30 0 0 0 365,191 365,191
31 2,698 0 174,257 0 174,257
32 0 0 0 43 43
33 10,774 0 1,182,749 0 1,182,749
34 90 0 10,287 0 10,287
35 0 0 0 121,232 121,232
36 3,340 0 184,377 0 184,377
37 0 0 0 221,705 221,705
38 1,338 0 115,940 0 115,940
39 0 0 0 101,078 101,078
40 7 0 1,077 0 1,077
41 0 0 0 398,454 398,454
42 0 0 0 50,616 50,616
43 78 0 75,456 0 75,456
44 0 0 0 609,725 609,725
45 445 0 30,300 0 30,300
FERC FORM NO. 1 (ED. 12-90)
Page 310-311
LineNo.Megawatt Hours Sold(g)Demand Charges ($)(h)Energy Charges ($)(i)Other Charges ($)(j)Total ($) (h+i+j)(k)1 477,375 0 34,284,190 0 34,284,19020004,444,818 4,444,818300017,152 17,152400023,614 23,614514,227 0 911,321 0 911,321644,165 0 2,804,959 0 2,804,95970005,835 5,835800081,253 81,2539775044,500 0 44,5001000014,437 14,4371162204,177 0 4,177120005,787,496 5,787,49613235,495 0 13,537,113 0 13,537,113140001581581520,287 0 2,869,453 0 2,869,4531600065765717780(7,513)0 (7,513)18 50,010 0 11,555,808 0 11,555,808190004,499 4,49920111,600 0 1,767,684 0 1,767,68421300(45,631)0 (45,631)22 17,544 0 2,240,329 0 2,240,3292348,800 0 8,372,400 0 8,372,40024812037,850 0 37,850250004,599 4,5992647,672 0 6,531,040 0 6,531,04027219,363 0 11,367,737 0 11,367,737280001,296 1,2962918,600 0 2,535,174 0 2,535,17430000365,191 365,191312,698 0 174,257 0 174,2573200043433310,774 0 1,182,749 0 1,182,7493490010,287 0 10,28735000121,232 121,232363,340 0 184,377 0 184,37737000221,705 221,705381,338 0 115,940 0 115,94039000101,078 101,07840701,077 0 1,07741000398,454 398,4544200050,616 50,6164378075,456 0 75,45644000609,725 609,72545445030,300 0 30,300FERC FORM NO. 1 (ED. 12-90)
Page 310-311
46 1,310 0 43,945 0 43,945
47 67 0 0 8,418 8,418
48 12,976 0 642,820 0 642,820
49 0 0 0 7,804,823 7,804,823
50 0 0 0 235,624 235,624
51 160 0 8,410 0 8,410
52 0 0 0 56,794 56,794
53 67,842 0 2,710,704 0 2,710,704
54 0 0 0 1,856,489 1,856,489
55 64,020 0 2,967,334 0 2,967,334
56 0 0 5,411 0 5,411
57 0 0 0 3,895 3,895
58 3,442 0 205,377 0 205,377
59 0 0 0 323,203 323,203
60 51,616 0 2,298,247 0 2,298,247
61 0 0 0 336 336
62 10,215 0 1,051,183 0 1,051,183
63 0 0 0 829,427 829,427
64 98,311 0 4,840,441 0 4,840,441
65 40 0 0 2,965 2,965
66 1,630 68,280 0 68,280
67 0 0 0 436 436
68 0 0 0 234 234
69 200 9,275 0 9,275
70 0 0 0 1,635 1,635
71 0 0 0 3,739 3,739
72 20,283 1,558,893 0 1,558,893
73 0 0 0 464,643 464,643
74 12,121 687,860 0 687,860
75 0 0 0 237,617 237,617
76 6,156 0 322,556 0 322,556
77 0 0 0 13,988 13,988
78 0 0 0 106 106
79 0 0 0 74,417 74,417
80 418,250 0 25,629,251 0 25,629,251
81 0 0 0 439 439
82 221 0 0 21,520 21,520
83 60 0 0 4,410 4,410
15 0
16 2,095,145 0 143,635,021 24,199,016 167,834,037
17 2,095,145 0 143,635,021 24,199,016 167,834,037
FERC FORM NO. 1 (ED. 12-90)
Page 310-311
SALES FOR RESALE (Account 447)
REVENUE REVENUE REVENUE
Line
No.
Megawatt Hours Sold
(g)
Demand Charges ($)
(h)
Energy Charges ($)
(i)
Other Charges ($)
(j)
Total ($) (h+i+j)
(k)
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original
(2) ☐ A Resubmission
Date of Report:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
46 1,310 0 43,945 0 43,9454767008,418 8,4184812,976 0 642,820 0 642,820490007,804,823 7,804,82350000235,624 235,6245116008,410 0 8,4105200056,794 56,7945367,842 0 2,710,704 0 2,710,704540001,856,489 1,856,4895564,020 0 2,967,334 0 2,967,33456005,411 0 5,411570003,895 3,895583,442 0 205,377 0 205,37759000323,203 323,2036051,616 0 2,298,247 0 2,298,247610003363366210,215 0 1,051,183 0 1,051,18363000829,427 829,4276498,311 0 4,840,441 0 4,840,4416540002,965 2,965661,630 68,280 0 68,2806700043643668000234234692009,275 0 9,275700001,635 1,635710003,739 3,7397220,283 1,558,893 0 1,558,89373000464,643 464,6437412,121 687,860 0 687,86075000237,617 237,617766,156 0 322,556 0 322,5567700013,988 13,988780001061067900074,417 74,41780418,250 0 25,629,251 0 25,629,25181000439439822210021,520 21,5208360004,410 4,410150162,095,145 0 143,635,021 24,199,016 167,834,037172,095,145 0 143,635,021 24,199,016 167,834,037FERC FORM NO. 1 (ED. 12-90)Page 310-311SALES FOR RESALE (Account 447)REVENUE REVENUE REVENUELineNo.Megawatt Hours Sold(g)Demand Charges ($)(h)Energy Charges ($)(i)Other Charges ($)(j)Total ($) (h+i+j)(k)
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original
(2) ☐ A Resubmission
Date of Report:
04/16/2024
Year/Period of Report
End of: 2023/ Q4Idaho Power Company
(2) ☐ A Resubmission
04/16/2024 End of: 2023/ Q4
FOOTNOTE DATA
(a) Concept: StatisticalClassificationCode
ADM Investor Services, Inc Futures Account Document, dated May 6, 2015
(b) Concept: StatisticalClassificationCode
Financial Transmission Losses
(c) Concept: StatisticalClassificationCode
Financial Transmission Losses
(d) Concept: StatisticalClassificationCode
Financial Transmission Losses
(e) Concept: StatisticalClassificationCode
Financial Transmission Losses
(f) Concept: StatisticalClassificationCode
Financial Transmission Losses
(g) Concept: StatisticalClassificationCode
Financial Transmission Losses
(h) Concept: StatisticalClassificationCode
Financial Transmission Losses
(i) Concept: StatisticalClassificationCode
Financial Transmission Losses
(j) Concept: StatisticalClassificationCode
Includes actual billing and estimate accrual
(k) Concept: StatisticalClassificationCode
Financial Transmission Losses
(l) Concept: StatisticalClassificationCode
Financial Transmission Losses
(m) Concept: StatisticalClassificationCode
Financial Transmission Losses
(n) Concept: StatisticalClassificationCode
Financial Transmission Losses
(o) Concept: StatisticalClassificationCode
Financial Transmission Losses
(p) Concept: StatisticalClassificationCode
Financial Transmission Losses
(q) Concept: StatisticalClassificationCode
Financial Transmission Losses
(r) Concept: StatisticalClassificationCode
Financial Transmission Losses
(s) Concept: StatisticalClassificationCode
Financial Transmission Losses
(t) Concept: StatisticalClassificationCode
Financial Transmission Losses
(u) Concept: StatisticalClassificationCode
Financial Transmission Losses
(v) Concept: StatisticalClassificationCode
Spinning or Operating Reserves
(w) Concept: StatisticalClassificationCode
Financial Transmission Losses
(x) Concept: StatisticalClassificationCode
Financial Transmission Losses
(y) Concept: StatisticalClassificationCode
Financial Transmission Losses
(z) Concept: StatisticalClassificationCode
Financial Transmission Losses
(aa) Concept: StatisticalClassificationCode
Financial Transmission Losses
(ab) Concept: StatisticalClassificationCode
Financial Transmission Losses
(ac) Concept: StatisticalClassificationCode
Financial Transmission Losses
(ad) Concept: StatisticalClassificationCode
Financial Transmission Losses
Idaho Power Company (2) ☐ A Resubmission 04/16/2024 End of: 2023/ Q4FOOTNOTE DATA(a) Concept: StatisticalClassificationCodeADM Investor Services, Inc Futures Account Document, dated May 6, 2015(b) Concept: StatisticalClassificationCodeFinancial Transmission Losses(c) Concept: StatisticalClassificationCodeFinancial Transmission Losses(d) Concept: StatisticalClassificationCodeFinancial Transmission Losses(e) Concept: StatisticalClassificationCodeFinancial Transmission Losses(f) Concept: StatisticalClassificationCodeFinancial Transmission Losses(g) Concept: StatisticalClassificationCodeFinancial Transmission Losses(h) Concept: StatisticalClassificationCodeFinancial Transmission Losses(i) Concept: StatisticalClassificationCodeFinancial Transmission Losses(j) Concept: StatisticalClassificationCodeIncludes actual billing and estimate accrual(k) Concept: StatisticalClassificationCodeFinancial Transmission Losses(l) Concept: StatisticalClassificationCodeFinancial Transmission Losses(m) Concept: StatisticalClassificationCodeFinancial Transmission Losses(n) Concept: StatisticalClassificationCodeFinancial Transmission Losses(o) Concept: StatisticalClassificationCodeFinancial Transmission Losses(p) Concept: StatisticalClassificationCodeFinancial Transmission Losses(q) Concept: StatisticalClassificationCodeFinancial Transmission Losses(r) Concept: StatisticalClassificationCodeFinancial Transmission Losses(s) Concept: StatisticalClassificationCodeFinancial Transmission Losses(t) Concept: StatisticalClassificationCodeFinancial Transmission Losses(u) Concept: StatisticalClassificationCodeFinancial Transmission Losses(v) Concept: StatisticalClassificationCodeSpinning or Operating Reserves(w) Concept: StatisticalClassificationCodeFinancial Transmission Losses(x) Concept: StatisticalClassificationCodeFinancial Transmission Losses(y) Concept: StatisticalClassificationCodeFinancial Transmission Losses(z) Concept: StatisticalClassificationCodeFinancial Transmission Losses(aa) Concept: StatisticalClassificationCodeFinancial Transmission Losses(ab) Concept: StatisticalClassificationCodeFinancial Transmission Losses(ac) Concept: StatisticalClassificationCode
Financial Transmission Losses
(ad) Concept: StatisticalClassificationCode
Financial Transmission Losses
(ae) Concept: StatisticalClassificationCode
Spinning or Operating Reserves
(af) Concept: StatisticalClassificationCode
Financial Transmission Losses
(ag) Concept: StatisticalClassificationCode
Financial Transmission Losses
(ah) Concept: StatisticalClassificationCode
Financial Transmission Losses
(ai) Concept: StatisticalClassificationCode
Financial Transmission Losses
(aj) Concept: StatisticalClassificationCode
Financial Transmission Losses
(ak) Concept: StatisticalClassificationCode
Financial Transmission Losses
(al) Concept: StatisticalClassificationCode
Transmission penalty distribution credits
(am) Concept: StatisticalClassificationCode
Financial Transmission Losses
(an) Concept: StatisticalClassificationCode
Financial Transmission Losses
(ao) Concept: StatisticalClassificationCode
Financial Transmission Losses
(ap) Concept: StatisticalClassificationCode
Spinning or Operating Reserves
(aq) Concept: StatisticalClassificationCode
Spinning or Operating Reserves
FERC FORM NO. 1 (ED. 12-90)
Page 310-311
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original
(2) ☐ A Resubmission
Date of Report:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
(ae) Concept: StatisticalClassificationCodeSpinning or Operating Reserves(af) Concept: StatisticalClassificationCodeFinancial Transmission Losses(ag) Concept: StatisticalClassificationCodeFinancial Transmission Losses(ah) Concept: StatisticalClassificationCodeFinancial Transmission Losses(ai) Concept: StatisticalClassificationCodeFinancial Transmission Losses(aj) Concept: StatisticalClassificationCodeFinancial Transmission Losses(ak) Concept: StatisticalClassificationCodeFinancial Transmission Losses(al) Concept: StatisticalClassificationCodeTransmission penalty distribution credits(am) Concept: StatisticalClassificationCodeFinancial Transmission Losses(an) Concept: StatisticalClassificationCodeFinancial Transmission Losses(ao) Concept: StatisticalClassificationCodeFinancial Transmission Losses(ap) Concept: StatisticalClassificationCodeSpinning or Operating Reserves(aq) Concept: StatisticalClassificationCodeSpinning or Operating ReservesFERC FORM NO. 1 (ED. 12-90)Page 310-311
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original
(2) ☐ A Resubmission
Date of Report:
04/16/2024
Year/Period of Report
End of: 2023/ Q4Idaho Power Company
(2) ☐ A Resubmission
04/16/2024 End of: 2023/ Q4
ELECTRIC OPERATION AND MAINTENANCE EXPENSES
Line No.Account
(a)
Amount for Current Year
(b)
Amount for Previous Year (c)
(c)
1 1. POWER PRODUCTION EXPENSES
2 A. Steam Power Generation
3 Operation
4 (500) Operation Supervision and Engineering 628,608 632,248
5 (501) Fuel 95,499,326 105,551,917
6 (502) Steam Expenses 10,150,211 9,298,487
7 (503) Steam from Other Sources 0 0
8 (Less) (504) Steam Transferred-Cr.0 0
9 (505) Electric Expenses 1,589,402 1,128,466
10 (506) Miscellaneous Steam Power Expenses 8,128,600 8,586,281
11 (507) Rents 233,996 229,461
12 (509) Allowances 0 0
13 TOTAL Operation (Enter Total of Lines 4 thru 12)116,230,143 125,426,860
14 Maintenance
15 (510) Maintenance Supervision and Engineering (264,424)(238,936)
16 (511) Maintenance of Structures 1,142,007 2,540,010
17 (512) Maintenance of Boiler Plant 7,697,177 8,774,081
18 (513) Maintenance of Electric Plant 3,019,375 2,306,519
19 (514) Maintenance of Miscellaneous Steam Plant 8,846,353 9,592,111
20 TOTAL Maintenance (Enter Total of Lines 15 thru 19)20,440,488 22,973,785
21 TOTAL Power Production Expenses-Steam Power (Enter Total of Lines 13 &
20)136,670,631 148,400,645
22 B. Nuclear Power Generation
23 Operation
24 (517) Operation Supervision and Engineering 0 0
25 (518) Fuel 0 0
26 (519) Coolants and Water 0 0
27 (520) Steam Expenses 0 0
28 (521) Steam from Other Sources 0 0
29 (Less) (522) Steam Transferred-Cr.0 0
30 (523) Electric Expenses 0 0
31 (524) Miscellaneous Nuclear Power Expenses 0 0
32 (525) Rents 0 0
33 TOTAL Operation (Enter Total of lines 24 thru 32)0 0
34 Maintenance
35 (528) Maintenance Supervision and Engineering 0 0
36 (529) Maintenance of Structures 0 0
37 (530) Maintenance of Reactor Plant Equipment 0 0
38 (531) Maintenance of Electric Plant 0 0
39 (532) Maintenance of Miscellaneous Nuclear Plant 0 0
40 TOTAL Maintenance (Enter Total of lines 35 thru 39)0 0
41 TOTAL Power Production Expenses-Nuclear. Power (Enter Total of lines 33 &
40)0 0
42 C. Hydraulic Power Generation
FERC FORM NO. 1 (ED. 12-93)
Page 320-323
Idaho Power Company (2) ☐ A Resubmission 04/16/2024 End of: 2023/ Q4ELECTRIC OPERATION AND MAINTENANCE EXPENSESLine No.Account(a)Amount for Current Year(b)Amount for Previous Year (c)(c)1 1. POWER PRODUCTION EXPENSES2A. Steam Power Generation3Operation4(500) Operation Supervision and Engineering 628,608 632,2485(501) Fuel 95,499,326 105,551,9176(502) Steam Expenses 10,150,211 9,298,4877(503) Steam from Other Sources 0 08(Less) (504) Steam Transferred-Cr.0 09(505) Electric Expenses 1,589,402 1,128,46610(506) Miscellaneous Steam Power Expenses 8,128,600 8,586,28111(507) Rents 233,996 229,46112(509) Allowances 0 013TOTAL Operation (Enter Total of Lines 4 thru 12)116,230,143 125,426,86014Maintenance15(510) Maintenance Supervision and Engineering (264,424)(238,936)16 (511) Maintenance of Structures 1,142,007 2,540,01017(512) Maintenance of Boiler Plant 7,697,177 8,774,08118(513) Maintenance of Electric Plant 3,019,375 2,306,51919(514) Maintenance of Miscellaneous Steam Plant 8,846,353 9,592,11120TOTAL Maintenance (Enter Total of Lines 15 thru 19)20,440,488 22,973,78521TOTAL Power Production Expenses-Steam Power (Enter Total of Lines 13 &20)136,670,631 148,400,64522B. Nuclear Power Generation23Operation24(517) Operation Supervision and Engineering 0 025(518) Fuel 0 026(519) Coolants and Water 0 027(520) Steam Expenses 0 028(521) Steam from Other Sources 0 029(Less) (522) Steam Transferred-Cr.0 030(523) Electric Expenses 0 031(524) Miscellaneous Nuclear Power Expenses 0 032(525) Rents 0 033TOTAL Operation (Enter Total of lines 24 thru 32)0 034Maintenance35(528) Maintenance Supervision and Engineering 0 036(529) Maintenance of Structures 0 037(530) Maintenance of Reactor Plant Equipment 0 038(531) Maintenance of Electric Plant 0 039(532) Maintenance of Miscellaneous Nuclear Plant 0 040TOTAL Maintenance (Enter Total of lines 35 thru 39)0 041TOTAL Power Production Expenses-Nuclear. Power (Enter Total of lines 33 &40)0 042C. Hydraulic Power GenerationFERC FORM NO. 1 (ED. 12-93)Page 320-323
43 Operation
44 (535) Operation Supervision and Engineering 5,340,529 5,758,397
45 (536) Water for Power 3,307,266 6,627,500
46 (537) Hydraulic Expenses 19,018,910 18,433,658
47 (538) Electric Expenses 2,172,360 1,959,732
48 (539) Miscellaneous Hydraulic Power Generation Expenses 5,528,687 5,131,196
49 (540) Rents 311,854 303,402
50 TOTAL Operation (Enter Total of Lines 44 thru 49)35,679,606 38,213,885
51 C. Hydraulic Power Generation (Continued)
52 Maintenance
53 (541) Mainentance Supervision and Engineering 198,386 110,982
54 (542) Maintenance of Structures 926,513 932,291
55 (543) Maintenance of Reservoirs, Dams, and Waterways 2,272,689 454,092
56 (544) Maintenance of Electric Plant 2,421,400 2,611,843
57 (545) Maintenance of Miscellaneous Hydraulic Plant 3,510,965 3,919,209
58 TOTAL Maintenance (Enter Total of lines 53 thru 57)9,329,953 8,028,417
59 TOTAL Power Production Expenses-Hydraulic Power (Total of Lines 50 & 58)45,009,559 46,242,302
60 D. Other Power Generation
61 Operation
62 (546) Operation Supervision and Engineering 655,573 627,106
63 (547) Fuel 179,905,516 124,658,377
64 (548) Generation Expenses 5,285,971 4,902,489
64.1 (548.1) Operation of Energy Storage Equipment
65 (549) Miscellaneous Other Power Generation Expenses 757,159 9,124
66 (550) Rents 0 0
67 TOTAL Operation (Enter Total of Lines 62 thru 67)186,604,219 130,197,096
68 Maintenance
69 (551) Maintenance Supervision and Engineering 0 0
70 (552) Maintenance of Structures 144,293 159,030
71 (553) Maintenance of Generating and Electric Plant (25,505)927,810
71.1 (553.1) Maintenance of Energy Storage Equipment
72 (554) Maintenance of Miscellaneous Other Power Generation Plant 5,193,505 6,730,627
73 TOTAL Maintenance (Enter Total of Lines 69 thru 72)5,312,293 7,817,467
74 TOTAL Power Production Expenses-Other Power (Enter Total of Lines 67 &
73)191,916,512 138,014,563
75 E. Other Power Supply Expenses
76 (555) Purchased Power 490,480,562 533,032,204
76.1 (555.1) Power Purchased for Storage Operations
77 (556) System Control and Load Dispatching 0 0
78 (557) Other Expenses 9,162,073 (94,515,705)
79 TOTAL Other Power Supply Exp (Enter Total of Lines 76 thru 78)499,642,635 438,516,499
80 TOTAL Power Production Expenses (Total of Lines 21, 41, 59, 74 & 79)873,239,337 771,174,009
81 2. TRANSMISSION EXPENSES
82 Operation
83 (560) Operation Supervision and Engineering 3,073,109 3,193,933
85 (561.1) Load Dispatch-Reliability 57,744 20,864
ELECTRIC OPERATION AND MAINTENANCE EXPENSES
Line No.Account
(a)
Amount for Current Year
(b)
Amount for Previous Year (c)
(c)
FERC FORM NO. 1 (ED. 12-93)
Page 320-323
43 Operation44(535) Operation Supervision and Engineering 5,340,529 5,758,39745(536) Water for Power 3,307,266 6,627,50046(537) Hydraulic Expenses 19,018,910 18,433,65847(538) Electric Expenses 2,172,360 1,959,73248(539) Miscellaneous Hydraulic Power Generation Expenses 5,528,687 5,131,19649(540) Rents 311,854 303,40250TOTAL Operation (Enter Total of Lines 44 thru 49)35,679,606 38,213,88551C. Hydraulic Power Generation (Continued)52 Maintenance53(541) Mainentance Supervision and Engineering 198,386 110,98254(542) Maintenance of Structures 926,513 932,29155(543) Maintenance of Reservoirs, Dams, and Waterways 2,272,689 454,09256(544) Maintenance of Electric Plant 2,421,400 2,611,84357(545) Maintenance of Miscellaneous Hydraulic Plant 3,510,965 3,919,20958TOTAL Maintenance (Enter Total of lines 53 thru 57)9,329,953 8,028,41759TOTAL Power Production Expenses-Hydraulic Power (Total of Lines 50 & 58)45,009,559 46,242,30260D. Other Power Generation61Operation62(546) Operation Supervision and Engineering 655,573 627,10663(547) Fuel 179,905,516 124,658,37764(548) Generation Expenses 5,285,971 4,902,48964.1 (548.1) Operation of Energy Storage Equipment65(549) Miscellaneous Other Power Generation Expenses 757,159 9,12466(550) Rents 0 067TOTAL Operation (Enter Total of Lines 62 thru 67)186,604,219 130,197,09668Maintenance69(551) Maintenance Supervision and Engineering 0 070(552) Maintenance of Structures 144,293 159,03071(553) Maintenance of Generating and Electric Plant (25,505)927,81071.1 (553.1) Maintenance of Energy Storage Equipment72(554) Maintenance of Miscellaneous Other Power Generation Plant 5,193,505 6,730,62773TOTAL Maintenance (Enter Total of Lines 69 thru 72)5,312,293 7,817,46774TOTAL Power Production Expenses-Other Power (Enter Total of Lines 67 &73)191,916,512 138,014,56375E. Other Power Supply Expenses76(555) Purchased Power 490,480,562 533,032,20476.1 (555.1) Power Purchased for Storage Operations77(556) System Control and Load Dispatching 0 078(557) Other Expenses 9,162,073 (94,515,705)79 TOTAL Other Power Supply Exp (Enter Total of Lines 76 thru 78)499,642,635 438,516,49980TOTAL Power Production Expenses (Total of Lines 21, 41, 59, 74 & 79)873,239,337 771,174,009812. TRANSMISSION EXPENSES82Operation83(560) Operation Supervision and Engineering 3,073,109 3,193,93385(561.1) Load Dispatch-Reliability 57,744 20,864ELECTRIC OPERATION AND MAINTENANCE EXPENSESLine No.Account(a)Amount for Current Year(b)Amount for Previous Year (c)(c)FERC FORM NO. 1 (ED. 12-93)
Page 320-323
86 (561.2) Load Dispatch-Monitor and Operate Transmission System 3,125,411 2,721,791
87 (561.3) Load Dispatch-Transmission Service and Scheduling 619,816 1,175,087
88 (561.4) Scheduling, System Control and Dispatch Services 13,722 18,769
89 (561.5) Reliability, Planning and Standards Development 0 0
90 (561.6) Transmission Service Studies 18,816 0
91 (561.7) Generation Interconnection Studies 263,743 124,783
92 (561.8) Reliability, Planning and Standards Development Services 1,315,392 1,314,282
93 (562) Station Expenses 2,751,453 2,788,678
93.1 (562.1) Operation of Energy Storage Equipment
94 (563) Overhead Lines Expenses 1,204,912 1,121,678
95 (564) Underground Lines Expenses
96 (565) Transmission of Electricity by Others 11,050,622 11,322,964
97 (566) Miscellaneous Transmission Expenses 0 8
98 (567) Rents 5,051,708 4,855,402
99 TOTAL Operation (Enter Total of Lines 83 thru 98)28,546,448 28,658,239
100 Maintenance
101 (568) Maintenance Supervision and Engineering 316,322 206,814
102 (569) Maintenance of Structures 11,197 43,860
103 (569.1) Maintenance of Computer Hardware 41,446 40,374
104 (569.2) Maintenance of Computer Software 1,788,095 1,795,651
105 (569.3) Maintenance of Communication Equipment 14,991 27,750
106 (569.4) Maintenance of Miscellaneous Regional Transmission Plant 0 0
107 (570) Maintenance of Station Equipment 3,214,321 2,611,391
107.1 (570.1) Maintenance of Energy Storage Equipment
108 (571) Maintenance of Overhead Lines 1,223,568 2,274,243
109 (572) Maintenance of Underground Lines 0 0
110 (573) Maintenance of Miscellaneous Transmission Plant 2,834 5,113
111 TOTAL Maintenance (Total of Lines 101 thru 110)6,612,774 7,005,196
112 TOTAL Transmission Expenses (Total of Lines 99 and 111)35,159,222 35,663,435
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
121 (575.7) Market Facilitation, Monitoring and Compliance Services 703,023 686,880
122 (575.8) Rents
123 Total Operation (Lines 115 thru 122)703,023 686,880
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
ELECTRIC OPERATION AND MAINTENANCE EXPENSES
Line No.Account
(a)
Amount for Current Year
(b)
Amount for Previous Year (c)
(c)
FERC FORM NO. 1 (ED. 12-93)
Page 320-323
86 (561.2) Load Dispatch-Monitor and Operate Transmission System 3,125,411 2,721,79187(561.3) Load Dispatch-Transmission Service and Scheduling 619,816 1,175,08788(561.4) Scheduling, System Control and Dispatch Services 13,722 18,76989(561.5) Reliability, Planning and Standards Development 0 090(561.6) Transmission Service Studies 18,816 091(561.7) Generation Interconnection Studies 263,743 124,78392(561.8) Reliability, Planning and Standards Development Services 1,315,392 1,314,28293(562) Station Expenses 2,751,453 2,788,67893.1 (562.1) Operation of Energy Storage Equipment94(563) Overhead Lines Expenses 1,204,912 1,121,67895(564) Underground Lines Expenses96(565) Transmission of Electricity by Others 11,050,622 11,322,96497(566) Miscellaneous Transmission Expenses 0 898(567) Rents 5,051,708 4,855,40299TOTAL Operation (Enter Total of Lines 83 thru 98)28,546,448 28,658,239100Maintenance101(568) Maintenance Supervision and Engineering 316,322 206,814102(569) Maintenance of Structures 11,197 43,860103(569.1) Maintenance of Computer Hardware 41,446 40,374104(569.2) Maintenance of Computer Software 1,788,095 1,795,651105(569.3) Maintenance of Communication Equipment 14,991 27,750106(569.4) Maintenance of Miscellaneous Regional Transmission Plant 0 0107(570) Maintenance of Station Equipment 3,214,321 2,611,391107.1 (570.1) Maintenance of Energy Storage Equipment108(571) Maintenance of Overhead Lines 1,223,568 2,274,243109(572) Maintenance of Underground Lines 0 0110(573) Maintenance of Miscellaneous Transmission Plant 2,834 5,113111TOTAL Maintenance (Total of Lines 101 thru 110)6,612,774 7,005,196112TOTAL Transmission Expenses (Total of Lines 99 and 111)35,159,222 35,663,4351133. REGIONAL MARKET EXPENSES114Operation115(575.1) Operation Supervision116(575.2) Day-Ahead and Real-Time Market Facilitation117(575.3) Transmission Rights Market Facilitation118(575.4) Capacity Market Facilitation119(575.5) Ancillary Services Market Facilitation120(575.6) Market Monitoring and Compliance121(575.7) Market Facilitation, Monitoring and Compliance Services 703,023 686,880122(575.8) Rents123Total Operation (Lines 115 thru 122)703,023 686,880124Maintenance125(576.1) Maintenance of Structures and Improvements126(576.2) Maintenance of Computer Hardware127(576.3) Maintenance of Computer Software128(576.4) Maintenance of Communication EquipmentELECTRIC OPERATION AND MAINTENANCE EXPENSESLine No.Account(a)Amount for Current Year(b)Amount for Previous Year (c)(c)FERC FORM NO. 1 (ED. 12-93)Page 320-323
129 (576.5) Maintenance of Miscellaneous Market Operation Plant
130 Total Maintenance (Lines 125 thru 129)
131 TOTAL Regional Transmission and Market Operation Expenses (Enter Total
of Lines 123 and 130)703,023 686,880
132 4. DISTRIBUTION EXPENSES
133 Operation
134 (580) Operation Supervision and Engineering 4,454,785 5,911,141
135 (581) Load Dispatching 5,797,830 5,170,071
136 (582) Station Expenses 1,798,005 1,862,473
137 (583) Overhead Line Expenses 5,617,399 5,421,238
138 (584) Underground Line Expenses 5,370,499 4,717,552
138.1 (584.1) Operation of Energy Storage Equipment
139 (585) Street Lighting and Signal System Expenses 4,822 44,756
140 (586) Meter Expenses 6,557,689 5,719,569
141 (587) Customer Installations Expenses 1,271,643 1,095,297
142 (588) Miscellaneous Expenses 4,413,695 4,687,903
143 (589) Rents 639,456 741,341
144 TOTAL Operation (Enter Total of Lines 134 thru 143)35,925,823 35,371,341
145 Maintenance
146 (590) Maintenance Supervision and Engineering 7,280 11,968
147 (591) Maintenance of Structures 0 0
148 (592) Maintenance of Station Equipment 5,071,241 4,120,742
148.1 (592.2) Maintenance of Energy Storage Equipment
149 (593) Maintenance of Overhead Lines 17,770,697 21,931,803
150 (594) Maintenance of Underground Lines 707,482 751,577
151 (595) Maintenance of Line Transformers 64,482 94,087
152 (596) Maintenance of Street Lighting and Signal Systems 182,003 204,924
153 (597) Maintenance of Meters 984,112 862,000
154 (598) Maintenance of Miscellaneous Distribution Plant 150,957 123,766
155 TOTAL Maintenance (Total of Lines 146 thru 154)24,938,254 28,100,867
156 TOTAL Distribution Expenses (Total of Lines 144 and 155)60,864,077 63,472,208
157 5. CUSTOMER ACCOUNTS EXPENSES
158 Operation
159 (901) Supervision 898,226 845,854
160 (902) Meter Reading Expenses 2,122,543 1,819,788
161 (903) Customer Records and Collection Expenses 16,141,973 15,041,848
162 (904) Uncollectible Accounts 3,830,484 3,069,311
163 (905) Miscellaneous Customer Accounts Expenses (358)(3,030)
164 TOTAL Customer Accounts Expenses (Enter Total of Lines 159 thru 163)22,992,868 20,773,771
165 6. CUSTOMER SERVICE AND INFORMATIONAL EXPENSES
166 Operation
167 (907) Supervision 1,040,924 1,009,780
168 (908) Customer Assistance Expenses 39,828,397 40,483,172
169 (909) Informational and Instructional Expenses 282,865 295,103
170 (910) Miscellaneous Customer Service and Informational Expenses 789,281 746,645
ELECTRIC OPERATION AND MAINTENANCE EXPENSES
Line No.Account
(a)
Amount for Current Year
(b)
Amount for Previous Year (c)
(c)
FERC FORM NO. 1 (ED. 12-93)
Page 320-323
129 (576.5) Maintenance of Miscellaneous Market Operation Plant130Total Maintenance (Lines 125 thru 129)131 TOTAL Regional Transmission and Market Operation Expenses (Enter Totalof Lines 123 and 130)703,023 686,8801324. DISTRIBUTION EXPENSES133Operation134(580) Operation Supervision and Engineering 4,454,785 5,911,141135(581) Load Dispatching 5,797,830 5,170,071136(582) Station Expenses 1,798,005 1,862,473137(583) Overhead Line Expenses 5,617,399 5,421,238138(584) Underground Line Expenses 5,370,499 4,717,552138.1 (584.1) Operation of Energy Storage Equipment139(585) Street Lighting and Signal System Expenses 4,822 44,756140(586) Meter Expenses 6,557,689 5,719,569141(587) Customer Installations Expenses 1,271,643 1,095,297142(588) Miscellaneous Expenses 4,413,695 4,687,903143(589) Rents 639,456 741,341144TOTAL Operation (Enter Total of Lines 134 thru 143)35,925,823 35,371,341145Maintenance146(590) Maintenance Supervision and Engineering 7,280 11,968147(591) Maintenance of Structures 0 0148(592) Maintenance of Station Equipment 5,071,241 4,120,742148.1 (592.2) Maintenance of Energy Storage Equipment149(593) Maintenance of Overhead Lines 17,770,697 21,931,803150(594) Maintenance of Underground Lines 707,482 751,577151(595) Maintenance of Line Transformers 64,482 94,087152(596) Maintenance of Street Lighting and Signal Systems 182,003 204,924153(597) Maintenance of Meters 984,112 862,000154(598) Maintenance of Miscellaneous Distribution Plant 150,957 123,766155TOTAL Maintenance (Total of Lines 146 thru 154)24,938,254 28,100,867156TOTAL Distribution Expenses (Total of Lines 144 and 155)60,864,077 63,472,2081575. CUSTOMER ACCOUNTS EXPENSES158Operation159(901) Supervision 898,226 845,854160(902) Meter Reading Expenses 2,122,543 1,819,788161(903) Customer Records and Collection Expenses 16,141,973 15,041,848162(904) Uncollectible Accounts 3,830,484 3,069,311163(905) Miscellaneous Customer Accounts Expenses (358)(3,030)164 TOTAL Customer Accounts Expenses (Enter Total of Lines 159 thru 163)22,992,868 20,773,7711656. CUSTOMER SERVICE AND INFORMATIONAL EXPENSES166Operation167(907) Supervision 1,040,924 1,009,780168(908) Customer Assistance Expenses 39,828,397 40,483,172169(909) Informational and Instructional Expenses 282,865 295,103170(910) Miscellaneous Customer Service and Informational Expenses 789,281 746,645ELECTRIC OPERATION AND MAINTENANCE EXPENSESLine No.Account(a)Amount for Current Year(b)Amount for Previous Year (c)(c)FERC FORM NO. 1 (ED. 12-93)Page 320-323
171 TOTAL Customer Service and Information Expenses (Total Lines 167 thru
170)41,941,467 42,534,700
172 7. SALES EXPENSES
173 Operation
174 (911) Supervision 0 0
175 (912) Demonstrating and Selling Expenses 0 0
176 (913) Advertising Expenses 0 0
177 (916) Miscellaneous Sales Expenses 0 0
178 TOTAL Sales Expenses (Enter Total of Lines 174 thru 177)0 0
179 8. ADMINISTRATIVE AND GENERAL EXPENSES
180 Operation
181 (920) Administrative and General Salaries 103,542,129 95,790,672
182 (921) Office Supplies and Expenses 16,350,808 15,137,531
183 (Less) (922) Administrative Expenses Transferred-Credit 42,660,535 35,131,943
184 (923) Outside Services Employed 10,180,054 8,733,229
185 (924) Property Insurance 3,330,773 3,925,608
186 (925) Injuries and Damages 4,152,400 6,544,597
187 (926) Employee Pensions and Benefits 61,208,683 54,443,509
188 (927) Franchise Requirements 0 0
189 (928) Regulatory Commission Expenses 6,154,682 6,545,806
190 (929) (Less) Duplicate Charges-Cr.0 0
191 (930.1) General Advertising Expenses 36,746 491,473
192 (930.2) Miscellaneous General Expenses 4,432,222 4,378,924
193 (931) Rents 0 0
194 TOTAL Operation (Enter Total of Lines 181 thru 193)166,727,962 160,859,406
195 Maintenance
196 (935) Maintenance of General Plant 8,011,043 7,877,237
197 TOTAL Administrative & General Expenses (Total of Lines 194 and 196)174,739,005 168,736,643
198 TOTAL Electric Operation and Maintenance Expenses (Total of Lines 80, 112,
131, 156, 164, 171, 178, and 197)1,209,638,999 1,103,041,646
FERC FORM NO. 1 (ED. 12-93)
Page 320-323
ELECTRIC OPERATION AND MAINTENANCE EXPENSES
Line No.Account
(a)
Amount for Current Year
(b)
Amount for Previous Year (c)
(c)
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original
(2) ☐ A Resubmission
Date of Report:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
171 TOTAL Customer Service and Information Expenses (Total Lines 167 thru170)41,941,467 42,534,7001727. SALES EXPENSES173Operation174(911) Supervision 0 0175(912) Demonstrating and Selling Expenses 0 0176(913) Advertising Expenses 0 0177(916) Miscellaneous Sales Expenses 0 0178TOTAL Sales Expenses (Enter Total of Lines 174 thru 177)0 01798. ADMINISTRATIVE AND GENERAL EXPENSES180Operation181(920) Administrative and General Salaries 103,542,129 95,790,672182(921) Office Supplies and Expenses 16,350,808 15,137,531183(Less) (922) Administrative Expenses Transferred-Credit 42,660,535 35,131,943184(923) Outside Services Employed 10,180,054 8,733,229185(924) Property Insurance 3,330,773 3,925,608186(925) Injuries and Damages 4,152,400 6,544,597187(926) Employee Pensions and Benefits 61,208,683 54,443,509188(927) Franchise Requirements 0 0189(928) Regulatory Commission Expenses 6,154,682 6,545,806190(929) (Less) Duplicate Charges-Cr.0 0191(930.1) General Advertising Expenses 36,746 491,473192(930.2) Miscellaneous General Expenses 4,432,222 4,378,924193(931) Rents 0 0194TOTAL Operation (Enter Total of Lines 181 thru 193)166,727,962 160,859,406195Maintenance196(935) Maintenance of General Plant 8,011,043 7,877,237197TOTAL Administrative & General Expenses (Total of Lines 194 and 196)174,739,005 168,736,643198TOTAL Electric Operation and Maintenance Expenses (Total of Lines 80, 112,131, 156, 164, 171, 178, and 197)1,209,638,999 1,103,041,646FERC FORM NO. 1 (ED. 12-93)Page 320-323ELECTRIC OPERATION AND MAINTENANCE EXPENSESLine No.Account(a)Amount for Current Year(b)Amount for Previous Year (c)(c)
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original
(2) ☐ A Resubmission
Date of Report:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
(2) ☐ A Resubmission
PURCHASED POWER (Account 555)
Actual Demand (MW)Actual Demand (MW)
Line
No.
Name of Company or Public Authority
(Footnote Affiliations)
(a)
Statistical
Classification
(b)
Ferc Rate
Schedule or
Tariff Number
(c)
Average Monthly Billing
Demand (MW)
(d)
Average Monthly NCP
Demand
(e)
Average Monthly CP
Demand
(f)
MegaWatt
Hours
Purchased
(Excluding
for Energy
Storage)
(g)
1 American Falls Solar, LLC LU 40,090
2 American Falls Solar II, LLC LU 40,529
3 Allan Ravenscroft/Malad River LU -1,223
4 Baker City Hydro LU 648
5 Bannock County Landfill LU 12,526
6 Barber Dam LU 9,081
7 Bennett Creek Wind Farm LU 38,296
8 Benson Creek Windfarm LU 26,775
9 Black Canyon Bliss Hydro LU -63
10 Blind Canyon LU -4,258
11 Branchflower - Trout Company LU -675
12 Burley Butte Wind Park LU 49,481
13 CAFCO Idaho Refuse Management LLC -
SISW LFGE LU -18,690
14 Camp Reed Wind Park LU 63,690
15 Cassia Wind Farm LLC LU 17,576
16 CCP OR Tenant 1, LLC
17 Grove Solar Center, LLC LU 13,187
18 Hyline Solar Center, LLC LU 19,127
19 Open Range Solar Center, LLC LU 22,246
20 Railroad Solar Center, LLC LU 9,749
21 Thunderegg Solar Center, LLC LU 18,900
22 Vale Air Solar Center, LLC LU 20,697
23 City of Hailey LU -81
24 City of Pocatello LU -1,510
25 Clear Springs Trout LU -3,089
26 Clifton E. Jenson - Birch Creek LU -341
27 Cold Springs Windfarm LU -50,837
28 Coleman Hydro LU -115
29 College of Southern Idaho - Pristine
Springs #1 LU -745
30 College of Southern Idaho - Pristine
Springs #3 LU -1,584
31 Crystal Springs LU -8,869
32 Curry Cattle Company LU -554
33 Cycle Horseshoe Bend Wind LU -23,630
34 Desert Meadow Windfarm LU -55,655
35 Durbin Creek Windfarm LU 22,940
36 Eightmile Hydro Project LU -1,347
37 Enerparc Solar Development LLC
38 Baker Solar Center LU 30,501
(2) ☐ A ResubmissionPURCHASED POWER (Account 555)Actual Demand (MW)Actual Demand (MW)LineNo.Name of Company or Public Authority(Footnote Affiliations)(a)StatisticalClassification(b)Ferc RateSchedule orTariff Number(c)Average Monthly BillingDemand (MW)(d)Average Monthly NCPDemand(e)Average Monthly CPDemand(f)MegaWattHoursPurchased(Excludingfor EnergyStorage)(g)1 American Falls Solar, LLC LU 40,0902American Falls Solar II, LLC LU 40,5293Allan Ravenscroft/Malad River LU -1,2234Baker City Hydro LU 6485Bannock County Landfill LU 12,5266Barber Dam LU 9,0817Bennett Creek Wind Farm LU 38,2968Benson Creek Windfarm LU 26,7759Black Canyon Bliss Hydro LU -6310Blind Canyon LU -4,25811Branchflower - Trout Company LU -67512Burley Butte Wind Park LU 49,48113CAFCO Idaho Refuse Management LLC -SISW LFGE LU -18,69014Camp Reed Wind Park LU 63,69015Cassia Wind Farm LLC LU 17,57616CCP OR Tenant 1, LLC17Grove Solar Center, LLC LU 13,18718Hyline Solar Center, LLC LU 19,12719Open Range Solar Center, LLC LU 22,24620Railroad Solar Center, LLC LU 9,74921Thunderegg Solar Center, LLC LU 18,90022Vale Air Solar Center, LLC LU 20,69723City of Hailey LU -8124City of Pocatello LU -1,51025Clear Springs Trout LU -3,08926Clifton E. Jenson - Birch Creek LU -34127Cold Springs Windfarm LU -50,83728Coleman Hydro LU -11529College of Southern Idaho - PristineSprings #1 LU -74530College of Southern Idaho - PristineSprings #3 LU -1,58431Crystal Springs LU -8,86932Curry Cattle Company LU -55433Cycle Horseshoe Bend Wind LU -23,63034Desert Meadow Windfarm LU -55,65535Durbin Creek Windfarm LU 22,94036Eightmile Hydro Project LU -1,34737Enerparc Solar Development LLC38Baker Solar Center LU 30,501
39 Brush Solar LU 6,097
40 Morgan Solar LU 6,307
41 Ontario Solar Center LU 6,794
42 Vale I Solar LU 5,706
43 Faulkner Ranch Hydro LU -2,645
44 Fisheries Development LU -461
45 Fossil Gulch Wind LU -24,481
46 Hidden Hollow Landfill Gas LU -21,968
47 Golden Valley Wind Park LU -27,828
48 Grand View PV Solar Two LU -176,149
49 Hammett Hill Windfarm LU -57,208
50 Hazelton B
(a)
LU -21,655
51 High Mesa Wind Project
(b)
LU -84,015
52 H.K. Hydro Mud Creek S & S LU -1,423
53 Horseshoe Bend Hydro LU -36,433
54 Hot Springs Wind Farm LU 34,677
55 Hydroland
56 Elk Creek Hydro LU 2,205
57 Rock Creek #2 LU -5,470
58 ID Solar 1 LU 91,224
59 Idaho Winds - Sawtooth Wind Project LU -56,456
60 J R Simplot Co.LU -72,418
61 J.M. Miller/Sahko Hydro LU 1,145
62 Jett Creek Windfarm LU 25,727
63 Kootenai Electric Cooperative - Fighting
Creek LU -16,497
64 Koosh Inc. Geo Bon #2 LU -3,564
65 Koyle Small Hydro LU -3,637
66 Lateral #10 LU -5,439
67 Lemhi Hydro LU -1,148
68 Lemoyne Power LU -649
69 Lime Wind Energy LU 4,776
70 Little Mac Power Co./Cedar Draw LU -4,501
71 Little Wood River Irrigation District LU -6,705
72 Low Line Midway Hydro LU 8,029
73 Lowline #2 LU 7,857
74 Mainline Windfarm LU -54,926
75 Marco Ranches LU -2,283
76 Marysville Hydro Partners- Falls River
(c)
LU -44,249
77 McCollum Enterprises -Canyon Springs LU -556
78 MC6 Hydro LU -7,802
79 Milner Dam Wind LU 46,645
PURCHASED POWER (Account 555)
Actual Demand (MW)Actual Demand (MW)
Line
No.
Name of Company or Public Authority
(Footnote Affiliations)
(a)
Statistical
Classification
(b)
Ferc Rate
Schedule or
Tariff Number
(c)
Average Monthly Billing
Demand (MW)
(d)
Average Monthly NCP
Demand
(e)
Average Monthly CP
Demand
(f)
MegaWatt
Hours
Purchased
(Excluding
for Energy
Storage)
(g)
39 Brush Solar LU 6,09740Morgan Solar LU 6,30741Ontario Solar Center LU 6,79442Vale I Solar LU 5,70643Faulkner Ranch Hydro LU -2,64544Fisheries Development LU -46145Fossil Gulch Wind LU -24,48146Hidden Hollow Landfill Gas LU -21,96847Golden Valley Wind Park LU -27,82848Grand View PV Solar Two LU -176,14949Hammett Hill Windfarm LU -57,20850Hazelton B (a)LU -21,65551High Mesa Wind Project (b)LU -84,01552H.K. Hydro Mud Creek S & S LU -1,42353Horseshoe Bend Hydro LU -36,43354Hot Springs Wind Farm LU 34,67755Hydroland56Elk Creek Hydro LU 2,20557Rock Creek #2 LU -5,47058ID Solar 1 LU 91,22459Idaho Winds - Sawtooth Wind Project LU -56,45660J R Simplot Co.LU -72,41861J.M. Miller/Sahko Hydro LU 1,14562Jett Creek Windfarm LU 25,72763Kootenai Electric Cooperative - FightingCreek LU -16,49764Koosh Inc. Geo Bon #2 LU -3,56465Koyle Small Hydro LU -3,63766Lateral #10 LU -5,43967Lemhi Hydro LU -1,14868Lemoyne Power LU -64969Lime Wind Energy LU 4,77670Little Mac Power Co./Cedar Draw LU -4,50171Little Wood River Irrigation District LU -6,70572Low Line Midway Hydro LU 8,02973Lowline #2 LU 7,85774Mainline Windfarm LU -54,92675Marco Ranches LU -2,28376Marysville Hydro Partners- Falls River (c)LU -44,24977McCollum Enterprises -Canyon Springs LU -55678MC6 Hydro LU -7,80279Milner Dam Wind LU 46,645PURCHASED POWER (Account 555)Actual Demand (MW)Actual Demand (MW)LineNo.Name of Company or Public Authority(Footnote Affiliations)(a)StatisticalClassification(b)Ferc RateSchedule orTariff Number(c)Average Monthly BillingDemand (MW)(d)Average Monthly NCPDemand(e)Average Monthly CPDemand(f)MegaWattHoursPurchased(Excludingfor EnergyStorage)(g)
80 Moore's Hollow
(d)
LU 0
81 Mt. Home Solar 1, LLC LU 37,904
82 Mud Creek White Hydro, Inc LU -374
83 Murphy Flat Power, LLC LU 43,802
84 North Gooding Main Hydro LU -3,298
85 North Side Energy Company Inc
86 Bypass LU -26,149
87 Hazelton A LU -22,962
88 Head of U Canal Project LU -4,341
89 Orchard Ranch Solar, LLC LU 45,049
90 Oregon Trail Wind Park LU 34,576
91 Owyhee Irrigation District
92 Mitchell Butte LU -4,452
93 Owyhee Dam Cspp LU -13,886
94 Tunnel #1 LU -15,530
95 Payne's Ferry Wind Park LU -59,767
96 Pico Energy, LLC LU -6,354
97 Pigeon Cove LU -7,370
98 Pilgrim Stage Station Wind Park LU -31,798
99 Prarie City Solar
(e)
LU -0
100 Prospector Windfarm LU 25,189
101 Reynolds Irrigation LU -1,281
102 Richard Kaster
103 Box Canyon LU -1,831
104 Briggs Creek LU -3,676
105 Riverside Hydro - Mora Drop LU 4,339
106 Riverside Investments
107 Arena Drop LU 1,594
108 Fargo Drop Hydroelectric LU 3,480
109 Rockland Wind Farm LU 219,436
110 Ryegrass Windfarm LU 52,370
111 Salmon Falls Wind LU 57,229
112 Shingle Creek LU -1,021
113 Shorock Hydro Inc.
114 Rock Creek #1 LU 9,622
115 Shoshone CSPP LU -1,470
116 Shoshone #2 LU -2,230
117 Simcoe Solar, LLC LU 46,535
118 Snake River Pottery LU -406
119 Snedigar Ranch Hydro LU -1,107
120 South Forks Joint Venture-Lowline Canal
(f)
LU -26,606
PURCHASED POWER (Account 555)
Actual Demand (MW)Actual Demand (MW)
Line
No.
Name of Company or Public Authority
(Footnote Affiliations)
(a)
Statistical
Classification
(b)
Ferc Rate
Schedule or
Tariff Number
(c)
Average Monthly Billing
Demand (MW)
(d)
Average Monthly NCP
Demand
(e)
Average Monthly CP
Demand
(f)
MegaWatt
Hours
Purchased
(Excluding
for Energy
Storage)
(g)
80 Moore's Hollow (d)LU 081Mt. Home Solar 1, LLC LU 37,90482Mud Creek White Hydro, Inc LU -37483Murphy Flat Power, LLC LU 43,80284North Gooding Main Hydro LU -3,29885North Side Energy Company Inc86Bypass LU -26,14987Hazelton A LU -22,96288Head of U Canal Project LU -4,34189Orchard Ranch Solar, LLC LU 45,04990Oregon Trail Wind Park LU 34,57691Owyhee Irrigation District92Mitchell Butte LU -4,45293Owyhee Dam Cspp LU -13,88694Tunnel #1 LU -15,53095Payne's Ferry Wind Park LU -59,76796Pico Energy, LLC LU -6,35497Pigeon Cove LU -7,37098Pilgrim Stage Station Wind Park LU -31,79899Prarie City Solar (e)LU -0100Prospector Windfarm LU 25,189101Reynolds Irrigation LU -1,281102Richard Kaster103Box Canyon LU -1,831104Briggs Creek LU -3,676105Riverside Hydro - Mora Drop LU 4,339106Riverside Investments107Arena Drop LU 1,594108Fargo Drop Hydroelectric LU 3,480109Rockland Wind Farm LU 219,436110Ryegrass Windfarm LU 52,370111Salmon Falls Wind LU 57,229112Shingle Creek LU -1,021113Shorock Hydro Inc.114 Rock Creek #1 LU 9,622115Shoshone CSPP LU -1,470116Shoshone #2 LU -2,230117Simcoe Solar, LLC LU 46,535118Snake River Pottery LU -406119Snedigar Ranch Hydro LU -1,107120South Forks Joint Venture-Lowline Canal (f)LU -26,606PURCHASED POWER (Account 555)Actual Demand (MW)Actual Demand (MW)LineNo.Name of Company or Public Authority(Footnote Affiliations)(a)StatisticalClassification(b)Ferc RateSchedule orTariff Number(c)Average Monthly BillingDemand (MW)(d)Average Monthly NCPDemand(e)Average Monthly CPDemand(f)MegaWattHoursPurchased(Excludingfor EnergyStorage)(g)
121 Tamarack Energy Partnership LU -14,144
122 Tasco - Nampa
(g)
OS -13
123 Tasco - Twin Falls
(h)
OS 2
124 Thousand Springs Wind Park LU 32,231
125 Tiber Montana LLC - Tiber Dam LU 22,755
126 Tuana Gulch Wind Park LU 28,820
127 Tuana Springs Expansion
(i)
LU 68,297
128 Two Ponds Windfarm LU -56,184
129 White Water Ranch LU -673
130 William Arkoosh-Littlewood River Ranch I LU -3,462
131 William Arkoosh- Littlewood River Ranch II LU 3,938
132 Willow Spring Windfarm LU 28,990
133 Wilson Power Company
(j)
LU -25,641
134 Wood Hydro
135 Black Canyon #3 LU 158
136 Dietrich Drop LU 8,706
137 Jim Knight LU 1,355
138 Magic Reservoir LU -20,026
139 Mile 28 LU 3,681
140 Sagebrush LU 1,875
141 Yahoo Creek Wind Park LU 60,922
142 Scheduling Deviation (k)17,098
143 3PR Trading Inc SF WSPP 131,475
144 ADM Investor Services, Inc.
(l)
OS WSPP 0
145 AVANGRID RENEWABLES, LLC
(m)
OS WSPP 14
146 AVANGRID RENEWABLES, LLC SF WSPP 220,350
147 Avista Corp.
(n)
OS WSPP 43
148 Avista Corp.
(o)
OS WSPP 0
149 Avista Corp.SF WSPP 686
150 Basin Electric Power Cooperative SF WSPP 800
151 Black Mesa Energy, LLC LU -64,470
152 Bonneville Power Administration
(p)
OS WSPP 0
153 Bonneville Power Administration SF WSPP 15,339
154 Bonneville Power Administration
(Transmission)
(q)
OS WSPP 215
155 BP Energy Company SF WSPP 263,675
156 Brookfield Renewable Trading and
Marketing LP SF WSPP 24,575
157 California Independent System Operator
(r)
SF CAISO 1,112,714
158 Calpine Energy Services, LP SF WSPP 2,400
PURCHASED POWER (Account 555)
Actual Demand (MW)Actual Demand (MW)
Line
No.
Name of Company or Public Authority
(Footnote Affiliations)
(a)
Statistical
Classification
(b)
Ferc Rate
Schedule or
Tariff Number
(c)
Average Monthly Billing
Demand (MW)
(d)
Average Monthly NCP
Demand
(e)
Average Monthly CP
Demand
(f)
MegaWatt
Hours
Purchased
(Excluding
for Energy
Storage)
(g)
121 Tamarack Energy Partnership LU -14,144122Tasco - Nampa (g)OS -13123Tasco - Twin Falls (h)OS 2124Thousand Springs Wind Park LU 32,231125Tiber Montana LLC - Tiber Dam LU 22,755126Tuana Gulch Wind Park LU 28,820127Tuana Springs Expansion (i)LU 68,297128Two Ponds Windfarm LU -56,184129White Water Ranch LU -673130William Arkoosh-Littlewood River Ranch I LU -3,462131William Arkoosh- Littlewood River Ranch II LU 3,938132Willow Spring Windfarm LU 28,990133Wilson Power Company (j)LU -25,641134Wood Hydro135Black Canyon #3 LU 158136Dietrich Drop LU 8,706137Jim Knight LU 1,355138Magic Reservoir LU -20,026139Mile 28 LU 3,681140SagebrushLU1,875141Yahoo Creek Wind Park LU 60,922142Scheduling Deviation (k)17,0981433PR Trading Inc SF WSPP 131,475144ADM Investor Services, Inc.(l)OS WSPP 0145AVANGRID RENEWABLES, LLC (m)OS WSPP 14146AVANGRID RENEWABLES, LLC SF WSPP 220,350147Avista Corp.(n)OS WSPP 43148Avista Corp.(o)OS WSPP 0149Avista Corp.SF WSPP 686150Basin Electric Power Cooperative SF WSPP 800151Black Mesa Energy, LLC LU -64,470152Bonneville Power Administration (p)OS WSPP 0153Bonneville Power Administration SF WSPP 15,339154Bonneville Power Administration(Transmission)(q)OS WSPP 215155BP Energy Company SF WSPP 263,675156Brookfield Renewable Trading andMarketing LP SF WSPP 24,575157California Independent System Operator (r)SF CAISO 1,112,714158Calpine Energy Services, LP SF WSPP 2,400PURCHASED POWER (Account 555)Actual Demand (MW)Actual Demand (MW)LineNo.Name of Company or Public Authority(Footnote Affiliations)(a)StatisticalClassification(b)Ferc RateSchedule orTariff Number(c)Average Monthly BillingDemand (MW)(d)Average Monthly NCPDemand(e)Average Monthly CPDemand(f)MegaWattHoursPurchased(Excludingfor EnergyStorage)(g)
159 Calpine Energy Solutions, LLC SF WSPP 5
160 Chelan Co PUD
(s)
OS WSPP 10
161 Chelan Co PUD SF WSPP 8,800
162 Citigroup Energy Inc.
(t)
OS ISDA 0
163 Citigroup Energy Inc.SF ISDA 94,750
164 City of Glendale SF WSPP 1,068
165 Clatskanie PUD SF WSPP 488
166 ConocoPhillips Company SF WSPP 64,450
167 Constellation Energy Generation, LLC SF WSPP 44,134
168 Direct Energy Business Marketing, LLC SF WSPP 15
169 Douglas County PUD
(u)
OS WSPP 2
170 Dynasty Power Inc.SF WSPP 31,225
171 EDF Trading North America, LLC
(v)
OS ISDA 0
172 EDF Trading North America, LLC SF WSPP 158,889
173 Energy Keepers, Inc SF WSPP 47,640
174 Grant CO Public Utility District #2 -- Electric
System
(w)
OS WSPP 18
175 Gridforce Energy Management, LLC
(x)
OS WSPP 15
176 Guzman Energy LLC SF WSPP 55,200
177 Jackpot Holdings, LLC LU -268,375
178 Macquarie Energy LLC
(y)
OS ISDA 0
179 Macquarie Energy LLC SF WSPP 400
180 Mercuria Energy America, LLC SF WSPP 2,400
181 Merrill Lynch Commodities, Inc.
(z)
OS ISDA 0
182 Neal Hot Springs Unit #1 LU -175,975
183 Nevada Power Company, dba NV Energy
(aa)
OS 1,080
184 Nevada Power Company, dba NV Energy SF WSPP 3,251
185 NorthWestern Energy SF WSPP 1,650
186 NorthWestern Energy (Transmission)
(ab)
OS WSPP 0
187 NorthWestern Energy (Transmission)
(ac)
OS WSPP 35
188 Oregon Solar Customers
(ad)
OS -694
189 PacifiCorp
(ae)
OS WSPP 237
190 PacifiCorp SF WSPP 40
191 PacifiCorp Inc.
(af)
OS WSPP 0
192 Portland General Electric Company
(ag)
OS WSPP 67
193 Portland General Electric Company SF WSPP 196,937
194 Powerex Corp.SF WSPP 105,771
195 Public Service Company of Colorado SF WSPP 20,000
PURCHASED POWER (Account 555)
Actual Demand (MW)Actual Demand (MW)
Line
No.
Name of Company or Public Authority
(Footnote Affiliations)
(a)
Statistical
Classification
(b)
Ferc Rate
Schedule or
Tariff Number
(c)
Average Monthly Billing
Demand (MW)
(d)
Average Monthly NCP
Demand
(e)
Average Monthly CP
Demand
(f)
MegaWatt
Hours
Purchased
(Excluding
for Energy
Storage)
(g)
159 Calpine Energy Solutions, LLC SF WSPP 5160Chelan Co PUD (s)OS WSPP 10161Chelan Co PUD SF WSPP 8,800162Citigroup Energy Inc.(t)OS ISDA 0163Citigroup Energy Inc.SF ISDA 94,750164City of Glendale SF WSPP 1,068165Clatskanie PUD SF WSPP 488166ConocoPhillips Company SF WSPP 64,450167Constellation Energy Generation, LLC SF WSPP 44,134168Direct Energy Business Marketing, LLC SF WSPP 15169Douglas County PUD (u)OS WSPP 2170Dynasty Power Inc.SF WSPP 31,225171EDF Trading North America, LLC (v)OS ISDA 0172EDF Trading North America, LLC SF WSPP 158,889173Energy Keepers, Inc SF WSPP 47,640174Grant CO Public Utility District #2 -- ElectricSystem (w)OS WSPP 18175Gridforce Energy Management, LLC (x)OS WSPP 15176Guzman Energy LLC SF WSPP 55,200177Jackpot Holdings, LLC LU -268,375178Macquarie Energy LLC (y)OS ISDA 0179Macquarie Energy LLC SF WSPP 400180Mercuria Energy America, LLC SF WSPP 2,400181Merrill Lynch Commodities, Inc.(z)OS ISDA 0182Neal Hot Springs Unit #1 LU -175,975183Nevada Power Company, dba NV Energy (aa)OS 1,080184Nevada Power Company, dba NV Energy SF WSPP 3,251185NorthWestern Energy SF WSPP 1,650186NorthWestern Energy (Transmission)(ab)OS WSPP 0187NorthWestern Energy (Transmission)(ac)OS WSPP 35188Oregon Solar Customers (ad)OS -694189PacifiCorp(ae)OS WSPP 237190PacifiCorpSFWSPP40191PacifiCorp Inc.(af)OS WSPP 0192Portland General Electric Company (ag)OS WSPP 67193Portland General Electric Company SF WSPP 196,937194Powerex Corp.SF WSPP 105,771195Public Service Company of Colorado SF WSPP 20,000PURCHASED POWER (Account 555)Actual Demand (MW)Actual Demand (MW)LineNo.Name of Company or Public Authority(Footnote Affiliations)(a)StatisticalClassification(b)Ferc RateSchedule orTariff Number(c)Average Monthly BillingDemand (MW)(d)Average Monthly NCPDemand(e)Average Monthly CPDemand(f)MegaWattHoursPurchased(Excludingfor EnergyStorage)(g)
196 Puget Sound Energy, Inc.
(ah)
OS WSPP 70
197 Puget Sound Energy, Inc.SF WSPP 28,650
198 Raft River Energy I LLC LU -88,334
199 Rainbow Energy Marketing Corporation SF WSPP 743
200 Salt River Project SF WSPP 400
201 Seattle City Light
(ai)
OS WSPP 22
202 Shell Energy North America (US), L.P.SF WSPP 531,529
203 Sierra Pacific Power Co., dba NV Energy
(aj)
OS WSPP 130
204 Sierra Pacific Power Co., dba NV Energy
(ak)
OS WSPP 0
205 Tacoma Power
(al)
OS WSPP 10
206 Telocaset Wind Power Partners LLC LU APP-A 312,870
207 Tenaska Power Services Co.SF WSPP 15,930
208 The Energy Authority, Inc.SF WSPP 4,618
209 TransAlta Energy Marketing (U.S.) Inc.SF WSPP 82,292
210 Vitol Inc.SF WSPP 1,814
211 Western Area Power Administration
(WACM)
(am)
OS WSPP 109
212 Western Area Power Administration (UGP
Marketing)
(an)
OS WSPP 1
213 PacifiCorp Inc.
(ao)
EX -
214 Clatskanie PUD
(ap)
EX 153
215 Hells Canyon
(aq)
OS
216 Acctg Valuation of Clatskanie PUD
(ar)
EX 0
217 Demand Response Avoided Energy
(as)
OS -0
15 TOTAL 7,020,964
FERC FORM NO. 1 (ED. 12-90)
Page 326-327
PURCHASED POWER (Account 555)
Actual Demand (MW)Actual Demand (MW)
Line
No.
Name of Company or Public Authority
(Footnote Affiliations)
(a)
Statistical
Classification
(b)
Ferc Rate
Schedule or
Tariff Number
(c)
Average Monthly Billing
Demand (MW)
(d)
Average Monthly NCP
Demand
(e)
Average Monthly CP
Demand
(f)
MegaWatt
Hours
Purchased
(Excluding
for Energy
Storage)
(g)
PURCHASED POWER (Account 555)
POWER EXCHANGES POWER EXCHANGES COST/SETTLEMENT OF
POWER
COST/SETTLEMENT OF
POWER
COST/SETTLEMENT OF
POWER
COST/SETTLEMENT
OF POWER
FERC FORM NO. 1 (ED. 12-90)
Page 326-327
196 Puget Sound Energy, Inc.(ah)OS WSPP 70197Puget Sound Energy, Inc.SF WSPP 28,650198Raft River Energy I LLC LU -88,334199Rainbow Energy Marketing Corporation SF WSPP 743200Salt River Project SF WSPP 400201Seattle City Light (ai)OS WSPP 22202Shell Energy North America (US), L.P.SF WSPP 531,529203Sierra Pacific Power Co., dba NV Energy (aj)OS WSPP 130204Sierra Pacific Power Co., dba NV Energy (ak)OS WSPP 0205Tacoma Power (al)OS WSPP 10206Telocaset Wind Power Partners LLC LU APP-A 312,870207Tenaska Power Services Co.SF WSPP 15,930208The Energy Authority, Inc.SF WSPP 4,618209TransAlta Energy Marketing (U.S.) Inc.SF WSPP 82,292210Vitol Inc.SF WSPP 1,814211Western Area Power Administration(WACM)(am)OS WSPP 109212Western Area Power Administration (UGPMarketing)(an)OS WSPP 1213PacifiCorp Inc.(ao)EX -214 Clatskanie PUD (ap)EX 153215Hells Canyon (aq)OS216Acctg Valuation of Clatskanie PUD (ar)EX 0217Demand Response Avoided Energy (as)OS -015TOTAL7,020,964FERC FORM NO. 1 (ED. 12-90)Page 326-327PURCHASED POWER (Account 555)Actual Demand (MW)Actual Demand (MW)LineNo.Name of Company or Public Authority(Footnote Affiliations)(a)StatisticalClassification(b)Ferc RateSchedule orTariff Number(c)Average Monthly BillingDemand (MW)(d)Average Monthly NCPDemand(e)Average Monthly CPDemand(f)MegaWattHoursPurchased(Excludingfor EnergyStorage)(g)
PURCHASED POWER (Account 555)
POWER EXCHANGES POWER EXCHANGES COST/SETTLEMENT OF
POWER
COST/SETTLEMENT OF
POWER
COST/SETTLEMENT OF
POWER
COST/SETTLEMENT
OF POWER
FERC FORM NO. 1 (ED. 12-90)
Page 326-327POWER POWER POWER OF POWER
Line
No.
MegaWatt Hours
Purchased for Energy
Storage
(h)
MegaWatt Hours
Received
(i)
MegaWatt Hours
Delivered
(j)
Demand Charges ($)
(k)
Energy Charges ($)
(l)
Other Charges ($)
(m)
Total (k+l+m) of
Settlement ($)
(n)
1 2,364,684 2,364,684
2 2,862,309 2,862,309
3 78,927 78,927
4 47,965 47,965
5 968,574 968,574
6 451,331 451,331
7 2,799,533 2,799,533
8 1,903,153 1,903,153
9 2,940 2,940
10 265,789 265,789
11 35,642 35,642
12 3,317,330 3,317,330
13 763,725 763,725
14 5,140,608 5,140,608
15 1,122,937 1,122,937
16 0
17 1,016,155 1,016,155
18 1,477,005 1,477,005
19 1,715,084 1,715,084
20 751,369 751,369
21 1,434,429 1,434,429
22 1,598,229 1,598,229
23 4,503 4,503
24 60,291 60,291
25 170,804 170,804
26 21,137 21,137
27 4,455,454 4,455,454
28 3,992 (64,982)(60,990)
29 45,820 45,820
30 92,253 92,253
31 463,364 463,364
32 43,484 43,484
33 1,629,228 1,629,228
34 4,840,079 4,840,079
35 1,643,994 1,643,994
36 112,468 112,468
37 0
38 1,220,108 1,220,108
39 193,634 193,634
40 201,536 201,536
41 199,128 199,128
42 181,389 181,389
43 141,548 141,548
FERC FORM NO. 1 (ED. 12-90)
Page 326-327
POWER POWER POWER OF POWERLineNo.MegaWatt HoursPurchased for EnergyStorage(h)MegaWatt HoursReceived(i)MegaWatt HoursDelivered(j)Demand Charges ($)(k)Energy Charges ($)(l)Other Charges ($)(m)Total (k+l+m) ofSettlement ($)(n)1 2,364,684 2,364,68422,862,309 2,862,309378,927 78,927447,965 47,9655968,574 968,5746451,331 451,33172,799,533 2,799,53381,903,153 1,903,15392,940 2,94010265,789 265,7891135,642 35,642123,317,330 3,317,33013763,725 763,725145,140,608 5,140,608151,122,937 1,122,937160171,016,155 1,016,155181,477,005 1,477,005191,715,084 1,715,08420751,369 751,369211,434,429 1,434,429221,598,229 1,598,229234,503 4,5032460,291 60,29125170,804 170,8042621,137 21,137274,455,454 4,455,454283,992 (64,982)(60,990)29 45,820 45,8203092,253 92,25331463,364 463,3643243,484 43,484331,629,228 1,629,228344,840,079 4,840,079351,643,994 1,643,99436112,468 112,468370381,220,108 1,220,10839193,634 193,63440201,536 201,53641199,128 199,12842181,389 181,38943141,548 141,548FERC FORM NO. 1 (ED. 12-90)Page 326-327
44 23,196 23,196
45 1,680,242 1,680,242
46 1,662,887 1,662,887
47 1,858,760 1,858,760
48 11,595,434 11,595,434
49 4,921,141 4,921,141
50 1,684,093 1,684,093
51 5,121,808 (3,987)5,117,821
52 97,627 97,627
53 2,880,497 2,880,497
54 2,514,509 2,514,509
55 0
56 80,822 80,822
57 293,439 293,439
58 5,671,999 5,671,999
59 5,253,271 5,253,271
60 3,439,084 3,439,084
61 60,802 60,802
62 1,838,576 1,838,576
63 1,530,084 1,530,084
64 199,939 199,939
65 243,052 243,052
66 248,358 248,358
67 59,873 59,873
68 39,909 39,909
69 428,617 428,617
70 263,320 263,320
71 405,512 405,512
72 503,681 503,681
73 633,229 633,229
74 4,764,928 4,764,928
75 138,136 138,136
76 3,223,749 3,223,749
77 38,207 38,207
78 288,280 288,280
79 3,118,479 3,118,479
80 0 (358,735)(358,735)
81 1,634,953 1,634,953
82 19,473 19,473
83 2,910,682 2,910,682
84 275,289 275,289
85 0
86 2,019,789 2,019,789
PURCHASED POWER (Account 555)
POWER EXCHANGES POWER EXCHANGES COST/SETTLEMENT OF
POWER
COST/SETTLEMENT OF
POWER
COST/SETTLEMENT OF
POWER
COST/SETTLEMENT
OF POWER
Line
No.
MegaWatt Hours
Purchased for Energy
Storage
(h)
MegaWatt Hours
Received
(i)
MegaWatt Hours
Delivered
(j)
Demand Charges ($)
(k)
Energy Charges ($)
(l)
Other Charges ($)
(m)
Total (k+l+m) of
Settlement ($)
(n)
FERC FORM NO. 1 (ED. 12-90)
Page 326-327
44 23,196 23,196451,680,242 1,680,242461,662,887 1,662,887471,858,760 1,858,7604811,595,434 11,595,434494,921,141 4,921,141501,684,093 1,684,093515,121,808 (3,987)5,117,8215297,627 97,627532,880,497 2,880,497542,514,509 2,514,5095505680,822 80,82257293,439 293,439585,671,999 5,671,999595,253,271 5,253,271603,439,084 3,439,0846160,802 60,802621,838,576 1,838,576631,530,084 1,530,08464199,939 199,93965243,052 243,05266248,358 248,3586759,873 59,8736839,909 39,90969428,617 428,61770263,320 263,32071405,512 405,51272503,681 503,68173633,229 633,229744,764,928 4,764,92875138,136 138,136763,223,749 3,223,7497738,207 38,20778288,280 288,280793,118,479 3,118,479800(358,735)(358,735)81 1,634,953 1,634,9538219,473 19,473832,910,682 2,910,68284275,289 275,289850862,019,789 2,019,789PURCHASED POWER (Account 555)POWER EXCHANGES POWER EXCHANGES COST/SETTLEMENT OFPOWER COST/SETTLEMENT OFPOWER COST/SETTLEMENT OFPOWER COST/SETTLEMENTOF POWERLineNo.MegaWatt HoursPurchased for EnergyStorage(h)MegaWatt HoursReceived(i)MegaWatt HoursDelivered(j)Demand Charges ($)(k)Energy Charges ($)(l)Other Charges ($)(m)Total (k+l+m) ofSettlement ($)(n)FERC FORM NO. 1 (ED. 12-90)Page 326-327
87 2,231,566 2,231,566
88 465,162 465,162
89 2,801,969 2,801,969
90 2,315,044 2,315,044
91 0
92 139,405 139,405
93 363,679 363,679
94 538,428 538,428
95 4,821,772 4,821,772
96 374,794 374,794
97 444,375 444,375
98 2,144,925 2,144,925
99 0 (242,209)(242,209)
100 1,791,564 1,791,564
101 67,401 67,401
102 0
103 121,108 121,108
104 226,069 226,069
105 330,333 330,333
106 0
107 165,388 165,388
108 265,921 265,921
109 16,696,992 16,696,992
110 4,575,154 4,575,154
111 3,852,878 3,852,878
112 57,108 57,108
113 0
114 633,780 633,780
115 98,315 98,315
116 171,178 171,178
117 3,134,908 3,134,908
118 24,872 24,872
119 62,256 62,256
120 2,159,529 2,159,529
121 844,194 844,194
122 225 225
123 0 0
124 2,165,130 2,165,130
125 1,535,036 1,535,036
126 1,932,696 1,932,696
127 5,536,750 (28,011)5,508,739
128 4,896,308 4,896,308
129 40,682 40,682
PURCHASED POWER (Account 555)
POWER EXCHANGES POWER EXCHANGES COST/SETTLEMENT OF
POWER
COST/SETTLEMENT OF
POWER
COST/SETTLEMENT OF
POWER
COST/SETTLEMENT
OF POWER
Line
No.
MegaWatt Hours
Purchased for Energy
Storage
(h)
MegaWatt Hours
Received
(i)
MegaWatt Hours
Delivered
(j)
Demand Charges ($)
(k)
Energy Charges ($)
(l)
Other Charges ($)
(m)
Total (k+l+m) of
Settlement ($)
(n)
FERC FORM NO. 1 (ED. 12-90)
Page 326-327
87 2,231,566 2,231,56688465,162 465,162892,801,969 2,801,969902,315,044 2,315,04491092139,405 139,40593363,679 363,67994538,428 538,428954,821,772 4,821,77296374,794 374,79497444,375 444,375982,144,925 2,144,925990(242,209)(242,209)100 1,791,564 1,791,56410167,401 67,4011020103121,108 121,108104226,069 226,069105330,333 330,3331060107165,388 165,388108265,921 265,92110916,696,992 16,696,9921104,575,154 4,575,1541113,852,878 3,852,87811257,108 57,1081130114633,780 633,78011598,315 98,315116171,178 171,1781173,134,908 3,134,90811824,872 24,87211962,256 62,2561202,159,529 2,159,529121844,194 844,194122225225123001242,165,130 2,165,1301251,535,036 1,535,0361261,932,696 1,932,6961275,536,750 (28,011)5,508,7391284,896,308 4,896,30812940,682 40,682PURCHASED POWER (Account 555)POWER EXCHANGES POWER EXCHANGES COST/SETTLEMENT OFPOWER COST/SETTLEMENT OFPOWER COST/SETTLEMENT OFPOWER COST/SETTLEMENTOF POWERLineNo.MegaWatt HoursPurchased for EnergyStorage(h)MegaWatt HoursReceived(i)MegaWatt HoursDelivered(j)Demand Charges ($)(k)Energy Charges ($)(l)Other Charges ($)(m)Total (k+l+m) ofSettlement ($)(n)FERC FORM NO. 1 (ED. 12-90)Page 326-327
130 185,719 185,719
131 331,961 331,961
132 2,065,909 2,065,909
133 1,984,095 1,984,095
134 0
135 11,217 11,217
136 564,291 564,291
137 101,399 101,399
138 1,125,652 1,125,652
139 274,459 274,459
140 136,543 136,543
141 4,903,299 4,903,299
142 0
143 0 0 0 16,725,660 0 16,725,660
144 0 0 0 4,905,962 4,905,962
145 0 0 0 0 710 710
146 0 0 0 16,134,018 0 16,134,018
147 0 0 0 0 2,240 2,240
148 0 0 0 0 742,983 742,983
149 0 0 0 93,567 0 93,567
150 0 0 0 48,000 0 48,000
151 0 0 0 2,001,808 0 2,001,808
152 0 0 0 0 167,321 167,321
153 0 0 0 1,632,847 0 1,632,847
154 0 0 0 0 11,255 11,255
155 0 0 0 20,214,781 0 20,214,781
156 0 0 0 2,197,775 0 2,197,775
157 0 0 0 44,449,949 0 44,449,949
158 0 0 0 353,968 0 353,968
159 0 0 0 172 0 172
160 0 0 0 0 485 485
161 0 0 0 1,334,276 0 1,334,276
162 1,656,625 1,656,625
163 0 0 0 6,188,645 0 6,188,645
164 0 0 0 84,990 0 84,990
165 0 0 0 31,702 0 31,702
166 0 0 0 3,025,684 0 3,025,684
167 0 0 0 2,094,529 0 2,094,529
168 0 0 0 2,550 0 2,550
169 0 0 0 0 109 109
170 0 0 0 2,714,499 0 2,714,499
171 (226,606)(226,606)
172 0 0 0 9,514,983 0 9,514,983
PURCHASED POWER (Account 555)
POWER EXCHANGES POWER EXCHANGES COST/SETTLEMENT OF
POWER
COST/SETTLEMENT OF
POWER
COST/SETTLEMENT OF
POWER
COST/SETTLEMENT
OF POWER
Line
No.
MegaWatt Hours
Purchased for Energy
Storage
(h)
MegaWatt Hours
Received
(i)
MegaWatt Hours
Delivered
(j)
Demand Charges ($)
(k)
Energy Charges ($)
(l)
Other Charges ($)
(m)
Total (k+l+m) of
Settlement ($)
(n)
FERC FORM NO. 1 (ED. 12-90)
Page 326-327
130 185,719 185,719131331,961 331,9611322,065,909 2,065,9091331,984,095 1,984,095134013511,217 11,217136564,291 564,291137101,399 101,3991381,125,652 1,125,652139274,459 274,459140136,543 136,5431414,903,299 4,903,299142014300016,725,660 0 16,725,6601440004,905,962 4,905,962145000071071014600016,134,018 0 16,134,01814700002,240 2,2401480000742,983 742,98314900093,567 0 93,56715000048,000 0 48,0001510002,001,808 0 2,001,8081520000167,321 167,3211530001,632,847 0 1,632,847154000011,255 11,25515500020,214,781 0 20,214,7811560002,197,775 0 2,197,77515700044,449,949 0 44,449,949158000353,968 0 353,968159000172017216000004854851610001,334,276 0 1,334,2761621,656,625 1,656,6251630006,188,645 0 6,188,64516400084,990 0 84,99016500031,702 0 31,7021660003,025,684 0 3,025,6841670002,094,529 0 2,094,5291680002,550 0 2,55016900001091091700002,714,499 0 2,714,499171(226,606)(226,606)172 0 0 0 9,514,983 0 9,514,983PURCHASED POWER (Account 555)POWER EXCHANGES POWER EXCHANGES COST/SETTLEMENT OFPOWER COST/SETTLEMENT OFPOWER COST/SETTLEMENT OFPOWER COST/SETTLEMENTOF POWERLineNo.MegaWatt HoursPurchased for EnergyStorage(h)MegaWatt HoursReceived(i)MegaWatt HoursDelivered(j)Demand Charges ($)(k)Energy Charges ($)(l)Other Charges ($)(m)Total (k+l+m) ofSettlement ($)(n)FERC FORM NO. 1 (ED. 12-90)Page 326-327
173 0 0 0 6,733,498 0 6,733,498
174 0 0 0 0 875 875
175 0 0 0 0 755 755
176 0 0 0 4,344,502 0 4,344,502
177 0 0 0 5,734,591 0 5,734,591
178 0 0 0 50,959 50,959
179 0 0 0 61,568 0 61,568
180 0 0 0 1,348,164 0 1,348,164
181 2,155,142 2,155,142
182 0 0 0 21,772,277 0 21,772,277
183 35,640 35,640
184 0 0 0 157,310 0 157,310
185 0 0 0 81,139 0 81,139
186 0 0 0 0 235 235
187 0 0 0 0 1,876 1,876
188 0 0 0 0 77,075 77,075
189 0 0 0 0 11,733 11,733
190 0 0 0 1,400 0 1,400
191 0 0 0 0 181,772 181,772
192 0 0 0 0 3,501 3,501
193 0 0 0 15,629,042 0 15,629,042
194 0 0 0 11,379,464 0 11,379,464
195 0 0 0 808,960 0 808,960
196 0 0 0 0 3,674 3,674
197 0 0 0 2,116,282 0 2,116,282
198 0 0 0 6,521,037 0 6,521,037
199 0 0 0 33,905 0 33,905
200 0 0 0 31,000 0 31,000
201 0 0 0 0 1,081 1,081
202 0 0 0 43,406,694 0 43,406,694
203 0 0 0 0 6,415 6,415
204 0 0 0 0 3,795 3,795
205 0 0 0 0 485 485
206 0 0 0 22,783,969 0 22,783,969
207 0 0 0 687,330 0 687,330
208 0 0 0 682,192 0 682,192
209 0 0 0 2,083,892 0 2,083,892
210 0 0 0 88,726 0 88,726
211 0 0 0 0 5,487 5,487
212 0 0 0 0 69 69
213 0 133,911 0
214 57,686 52,200 0
215 (2,506,212)(2,506,212)
PURCHASED POWER (Account 555)
POWER EXCHANGES POWER EXCHANGES COST/SETTLEMENT OF
POWER
COST/SETTLEMENT OF
POWER
COST/SETTLEMENT OF
POWER
COST/SETTLEMENT
OF POWER
Line
No.
MegaWatt Hours
Purchased for Energy
Storage
(h)
MegaWatt Hours
Received
(i)
MegaWatt Hours
Delivered
(j)
Demand Charges ($)
(k)
Energy Charges ($)
(l)
Other Charges ($)
(m)
Total (k+l+m) of
Settlement ($)
(n)
FERC FORM NO. 1 (ED. 12-90)
Page 326-327
173 0 0 0 6,733,498 0 6,733,498174000087587517500007557551760004,344,502 0 4,344,5021770005,734,591 0 5,734,59117800050,959 50,95917900061,568 0 61,5681800001,348,164 0 1,348,1641812,155,142 2,155,14218200021,772,277 0 21,772,27718335,640 35,640184000157,310 0 157,31018500081,139 0 81,139186000023523518700001,876 1,876188000077,075 77,075189000011,733 11,7331900001,400 0 1,4001910000181,772 181,77219200003,501 3,50119300015,629,042 0 15,629,04219400011,379,464 0 11,379,464195000808,960 0 808,96019600003,674 3,6741970002,116,282 0 2,116,2821980006,521,037 0 6,521,03719900033,905 0 33,90520000031,000 0 31,00020100001,081 1,08120200043,406,694 0 43,406,69420300006,415 6,41520400003,795 3,795205000048548520600022,783,969 0 22,783,969207000687,330 0 687,330208000682,192 0 682,1922090002,083,892 0 2,083,89221000088,726 0 88,72621100005,487 5,487212000069692130133,911 021457,686 52,200 0215(2,506,212)(2,506,212)PURCHASED POWER (Account 555)POWER EXCHANGES POWER EXCHANGES COST/SETTLEMENT OFPOWER COST/SETTLEMENT OFPOWER COST/SETTLEMENT OFPOWER COST/SETTLEMENTOF POWERLineNo.MegaWatt HoursPurchased for EnergyStorage(h)MegaWatt HoursReceived(i)MegaWatt HoursDelivered(j)Demand Charges ($)(k)Energy Charges ($)(l)Other Charges ($)(m)Total (k+l+m) ofSettlement ($)(n)FERC FORM NO. 1 (ED. 12-90)Page 326-327
216 0 0 877,497 877,497
217 0 0 8,455,107 8,455,107
15 0 57,686 186,111 0 474,586,081 15,894,481 490,480,562
FERC FORM NO. 1 (ED. 12-90)
Page 326-327
PURCHASED POWER (Account 555)
POWER EXCHANGES POWER EXCHANGES COST/SETTLEMENT OF
POWER
COST/SETTLEMENT OF
POWER
COST/SETTLEMENT OF
POWER
COST/SETTLEMENT
OF POWER
Line
No.
MegaWatt Hours
Purchased for Energy
Storage
(h)
MegaWatt Hours
Received
(i)
MegaWatt Hours
Delivered
(j)
Demand Charges ($)
(k)
Energy Charges ($)
(l)
Other Charges ($)
(m)
Total (k+l+m) of
Settlement ($)
(n)
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original
(2) ☐ A Resubmission
Date of Report:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
216 0 0 877,497 877,497217008,455,107 8,455,10715057,686 186,111 0 474,586,081 15,894,481 490,480,562FERC FORM NO. 1 (ED. 12-90)Page 326-327PURCHASED POWER (Account 555)POWER EXCHANGES POWER EXCHANGES COST/SETTLEMENT OFPOWER COST/SETTLEMENT OFPOWER COST/SETTLEMENT OFPOWER COST/SETTLEMENTOF POWERLineNo.MegaWatt HoursPurchased for EnergyStorage(h)MegaWatt HoursReceived(i)MegaWatt HoursDelivered(j)Demand Charges ($)(k)Energy Charges ($)(l)Other Charges ($)(m)Total (k+l+m) ofSettlement ($)(n)
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original
(2) ☐ A Resubmission
Date of Report:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
(2) ☐ A Resubmission
FOOTNOTE DATA
(a) Concept: StatisticalClassificationCode
Ida West, a subsidiary of IdaCorp (Idaho Power Company's parent company), has partial ownership of these projects.
(b) Concept: StatisticalClassificationCode
Mechanical Availability Guarantee Damages
(c) Concept: StatisticalClassificationCode
Ida West, a subsidiary of IdaCorp (Idaho Power Company's parent company), has partial ownership of these projects.
(d) Concept: StatisticalClassificationCode
Mechanical Availability Guarantee Damages
(e) Concept: StatisticalClassificationCode
Mechanical Availability Guarantee Damages
(f) Concept: StatisticalClassificationCode
Ida West, a subsidiary of IdaCorp (Idaho Power Company's parent company), has partial ownership of these projects.
(g) Concept: StatisticalClassificationCode
Non Firm Purchases
(h) Concept: StatisticalClassificationCode
Non Firm Purchases
(i) Concept: StatisticalClassificationCode
Mechanical Availability Guarantee Damages
(j) Concept: StatisticalClassificationCode
Ida West, a subsidiary of IdaCorp (Idaho Power Company's parent company), has partial ownership of these projects.
(k) Concept: StatisticalClassificationCode
Difference between booked and scheduled energy
(l) Concept: StatisticalClassificationCode
Spinning or Operating Reserves
(m) Concept: StatisticalClassificationCode
Spinning or Operating Reserves
(n) Concept: StatisticalClassificationCode
Spinning or Operating Reserves
(o) Concept: StatisticalClassificationCode
Financial Transmission Losses
(p) Concept: StatisticalClassificationCode
Financial Transmission Losses
(q) Concept: StatisticalClassificationCode
Financial Transmission Losses
(r) Concept: StatisticalClassificationCode
Includes actual billing and estimate accrual
(s) Concept: StatisticalClassificationCode
Spinning or Operating Reserves
(t) Concept: StatisticalClassificationCode
ISDA Master Agreement With Citigroup Energy Inc. dated March 7, 2011
(u) Concept: StatisticalClassificationCode
Spinning or Operating Reserves
(v) Concept: StatisticalClassificationCode
ISDA Master Agreement With EDF Trading North America, LLC, dated October 25, 2012
(w) Concept: StatisticalClassificationCode
Spinning or Operating Reserves
(x) Concept: StatisticalClassificationCode
Spinning or Operating Reserves
(y) Concept: StatisticalClassificationCode
ISDA Master Agreement With Macquarie Energy, LLC date April 12, 2011
(z) Concept: StatisticalClassificationCode
ISDA Master Agreement With Merrill Lynch Commodities, Inc. dated September 24, 2013
(aa) Concept: StatisticalClassificationCode
Non Firm Purchases
(ab) Concept: StatisticalClassificationCode
Financial Transmission Losses
(ac) Concept: StatisticalClassificationCode
Spinning or Operating Reserves
(ad) Concept: StatisticalClassificationCode
Schedule 88 Oregon Solar
(ae) Concept: StatisticalClassificationCode
(2) ☐ A Resubmission FOOTNOTE DATA(a) Concept: StatisticalClassificationCodeIda West, a subsidiary of IdaCorp (Idaho Power Company's parent company), has partial ownership of these projects.(b) Concept: StatisticalClassificationCodeMechanical Availability Guarantee Damages(c) Concept: StatisticalClassificationCodeIda West, a subsidiary of IdaCorp (Idaho Power Company's parent company), has partial ownership of these projects.(d) Concept: StatisticalClassificationCodeMechanical Availability Guarantee Damages(e) Concept: StatisticalClassificationCodeMechanical Availability Guarantee Damages(f) Concept: StatisticalClassificationCodeIda West, a subsidiary of IdaCorp (Idaho Power Company's parent company), has partial ownership of these projects.(g) Concept: StatisticalClassificationCodeNon Firm Purchases(h) Concept: StatisticalClassificationCodeNon Firm Purchases(i) Concept: StatisticalClassificationCodeMechanical Availability Guarantee Damages(j) Concept: StatisticalClassificationCodeIda West, a subsidiary of IdaCorp (Idaho Power Company's parent company), has partial ownership of these projects.(k) Concept: StatisticalClassificationCodeDifference between booked and scheduled energy(l) Concept: StatisticalClassificationCodeSpinning or Operating Reserves(m) Concept: StatisticalClassificationCodeSpinning or Operating Reserves(n) Concept: StatisticalClassificationCodeSpinning or Operating Reserves(o) Concept: StatisticalClassificationCodeFinancial Transmission Losses(p) Concept: StatisticalClassificationCodeFinancial Transmission Losses(q) Concept: StatisticalClassificationCodeFinancial Transmission Losses(r) Concept: StatisticalClassificationCodeIncludes actual billing and estimate accrual(s) Concept: StatisticalClassificationCodeSpinning or Operating Reserves(t) Concept: StatisticalClassificationCodeISDA Master Agreement With Citigroup Energy Inc. dated March 7, 2011(u) Concept: StatisticalClassificationCodeSpinning or Operating Reserves(v) Concept: StatisticalClassificationCodeISDA Master Agreement With EDF Trading North America, LLC, dated October 25, 2012(w) Concept: StatisticalClassificationCodeSpinning or Operating Reserves(x) Concept: StatisticalClassificationCodeSpinning or Operating Reserves(y) Concept: StatisticalClassificationCodeISDA Master Agreement With Macquarie Energy, LLC date April 12, 2011(z) Concept: StatisticalClassificationCodeISDA Master Agreement With Merrill Lynch Commodities, Inc. dated September 24, 2013(aa) Concept: StatisticalClassificationCodeNon Firm Purchases(ab) Concept: StatisticalClassificationCodeFinancial Transmission Losses(ac) Concept: StatisticalClassificationCode
Spinning or Operating Reserves
(ad) Concept: StatisticalClassificationCode
Schedule 88 Oregon Solar
(ae) Concept: StatisticalClassificationCode(ae) Concept: StatisticalClassificationCode
Spinning or Operating Reserves
(af) Concept: StatisticalClassificationCode
Financial Transmission Losses
(ag) Concept: StatisticalClassificationCode
Spinning or Operating Reserves
(ah) Concept: StatisticalClassificationCode
Spinning or Operating Reserves
(ai) Concept: StatisticalClassificationCode
Spinning or Operating Reserves
(aj) Concept: StatisticalClassificationCode
Spinning or Operating Reserves
(ak) Concept: StatisticalClassificationCode
Financial Transmission Losses
(al) Concept: StatisticalClassificationCode
Spinning or Operating Reserves
(am) Concept: StatisticalClassificationCode
Spinning or Operating Reserves
(an) Concept: StatisticalClassificationCode
Spinning or Operating Reserves
(ao) Concept: StatisticalClassificationCode
Physical Transmission Losses
(ap) Concept: StatisticalClassificationCode
Energy exchange between Clatskanie PUD and Idaho Power Company at Arrowrock Dam
(aq) Concept: StatisticalClassificationCode
Liquidated Damages for Lost Energy Production
(ar) Concept: StatisticalClassificationCode
Energy exchange between Clatskanie PUD and Idaho Power Company at Arrowrock Dam
(as) Concept: StatisticalClassificationCode
Incentive program for customers to reduce demand during peak hours
FERC FORM NO. 1 (ED. 12-90)
Page 326-327
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original
(2) ☐ A Resubmission
Date of Report:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
(ae) Concept: StatisticalClassificationCodeSpinning or Operating Reserves(af) Concept: StatisticalClassificationCodeFinancial Transmission Losses(ag) Concept: StatisticalClassificationCodeSpinning or Operating Reserves(ah) Concept: StatisticalClassificationCodeSpinning or Operating Reserves(ai) Concept: StatisticalClassificationCodeSpinning or Operating Reserves(aj) Concept: StatisticalClassificationCodeSpinning or Operating Reserves(ak) Concept: StatisticalClassificationCodeFinancial Transmission Losses(al) Concept: StatisticalClassificationCodeSpinning or Operating Reserves(am) Concept: StatisticalClassificationCodeSpinning or Operating Reserves(an) Concept: StatisticalClassificationCodeSpinning or Operating Reserves(ao) Concept: StatisticalClassificationCodePhysical Transmission Losses(ap) Concept: StatisticalClassificationCodeEnergy exchange between Clatskanie PUD and Idaho Power Company at Arrowrock Dam(aq) Concept: StatisticalClassificationCodeLiquidated Damages for Lost Energy Production(ar) Concept: StatisticalClassificationCodeEnergy exchange between Clatskanie PUD and Idaho Power Company at Arrowrock Dam(as) Concept: StatisticalClassificationCodeIncentive program for customers to reduce demand during peak hoursFERC FORM NO. 1 (ED. 12-90)Page 326-327
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original
(2) ☐ A Resubmission
Date of Report:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
(2) ☐ A Resubmission
TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456.1) (Including transactions referred to as "wheeling")
Line
No.
Payment By (Company of Public
Authority) (Footnote Affiliation)
(a)
Energy Received From (Company of
Public Authority) (Footnote
Affiliation)
(b)
Energy Delivered To (Company of
Public Authority) (Footnote
Affiliation)
(c)
Statistical
Classification
(d)
Ferc Rate
Schedule of
Tariff Number
(e)
Point of Receipt
(Substation or
Other
Designation)
(f)
Point of
Delivery
(Substation or
Other
Designation)
(g)
1
(a)
Bonneville Power Administration
- OTEC
Bonneville Power Administration Oregon Trails Electric Co-op FNO
(h)
9
2
(b)
Bonneville Power Administration
- USBR
Bonneville Power Administration United States Bureau of
Reclamation FNO 9
3
(c)
Bonneville Power Administration
- PF
Bonneville Power Administration Priority Firm Customers FNO 9
4
(d)
Milner Irrigation District
United States Bureau of
Reclamation Milner Irrigation District OLF
(i)
Legacy
Minidoka,
Idaho
Various in
Idaho
5
(e)
Shell Energy North America
(US), L.P.
Seattle City Light Bonneville Power Administration OS
(j)
5/6
6
(f)
PacifiCorp PacifiCorp West PacifiCorp West FNO 9
7
(g)
United States Bureau of Indian
Affairs
Bonneville Power Administration United States Bureau of Indian
Affairs OS Legacy LaGrande,
Oregon
Various in
Idaho
8 AmpRenew Offtake I LLC OS 5/6
9 PacifiCorp Inc.PacifiCorp East Bonneville Power Administration LFP
(k)
7/8 BORA LAGRANDE
10 PacifiCorp Inc.PacifiCorp East PacifiCorp West LFP 7/8 KPRT HURR
11 PacifiCorp Inc.PacifiCorp East PacifiCorp West LFP 7/8 BORA HURR
12 Shell Energy North America
(US), L.P.Idaho Power Company Bonneville Power Administration LFP 7/8 LYPK LAGRANDE
13 Bonneville Power Administration PacifiCorp West PacifiCorp East LFP 7/8 M500 KPRT
14 Bonneville Power Administration PacifiCorp West PacifiCorp East LFP 7/8 SMLK KPRT
15 Powerex Corporation Avista PacifiCorp East LFP 7/8 LOLO BORA
16 Powerex Corporation PacifiCorp East PacifiCorp East LFP 7/8 JEFF BORA
17 Vitol Inc.Idaho Power Company Sierra Pacific Power LFP 7/8 MDSK M345
18 AmpRenew Offtake I LLC Idaho Power Company Sierra Pacific Power LFP 7/8 MDSK M345
19 Altop Energy Trading, LLC PacifiCorp East PacifiCorp East NF 7/8 JBSN BORA
20 American Falls Solar, LLC NF
(l)
11
21 American Falls Solar II, LLC NF 11
22 Avangrid Renewables, LLC NorthWestern/PacifiCorp East Sierra Pacific Power NF 7/8 AVAT.NWMT M345
23 Avangrid Renewables, LLC PacifiCorp East Bonneville Power Administration NF 7/8 BORA LAGRANDE
24 Avangrid Renewables, LLC NorthWestern/PacifiCorp East Sierra Pacific Power NF 7/8 BPAT.NWMT M345
25 Avangrid Renewables, LLC PacifiCorp East NorthWestern/PacifiCorp East NF 7/8 BRDY BPAT.NWMT
26 Avangrid Renewables, LLC PacifiCorp East Bonneville Power Administration NF 7/8 BRDY LAGRANDE
27 Avangrid Renewables, LLC PacifiCorp East Sierra Pacific Power NF 7/8 BRDY M345
28 Avangrid Renewables, LLC Bonneville Power Administration Sierra Pacific Power NF 7/8 LAGRANDE M345
29 Avangrid Renewables, LLC Avista Sierra Pacific Power NF 7/8 LOLO M345
30 Avangrid Renewables, LLC Sierra Pacific Power Bonneville Power Administration NF 7/8 M345 LAGRANDE
31 Avangrid Renewables, LLC PacifiCorp West Sierra Pacific Power NF 7/8 SMLK M345
32 Avista Corporation NorthWestern/PacifiCorp East Avista NF 7/8 AVAT.NWMT LOLO
33 Avista Corporation PacifiCorp East Bonneville Power Administration NF 7/8 BRDY LAGRANDE
34 Avista Corporation PacifiCorp East Avista NF 7/8 BRDY LOLO
35 Avista Corporation Avista Sierra Pacific Power NF 7/8 LOLO M345
FERC FORM NO. 1 (ED. 12-90)
Page 328-330
(2) ☐ A ResubmissionTRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456.1) (Including transactions referred to as "wheeling")LineNo.Payment By (Company of PublicAuthority) (Footnote Affiliation)(a)Energy Received From (Company ofPublic Authority) (FootnoteAffiliation)(b)Energy Delivered To (Company ofPublic Authority) (FootnoteAffiliation)(c)StatisticalClassification(d)Ferc RateSchedule ofTariff Number(e)Point of Receipt(Substation orOtherDesignation)(f)Point ofDelivery(Substation orOtherDesignation)(g)1 (a)Bonneville Power Administration- OTEC Bonneville Power Administration Oregon Trails Electric Co-op FNO (h)92(b)Bonneville Power Administration- USBR Bonneville Power Administration United States Bureau ofReclamation FNO 93(c)Bonneville Power Administration- PF Bonneville Power Administration Priority Firm Customers FNO 94(d)Milner Irrigation District United States Bureau ofReclamation Milner Irrigation District OLF (i)Legacy Minidoka,Idaho Various inIdaho5(e)Shell Energy North America(US), L.P.Seattle City Light Bonneville Power Administration OS (j)5/66(f)PacifiCorp PacifiCorp West PacifiCorp West FNO 97(g)United States Bureau of IndianAffairs Bonneville Power Administration United States Bureau of IndianAffairs OS Legacy LaGrande,Oregon Various inIdaho8AmpRenew Offtake I LLC OS 5/69PacifiCorp Inc.PacifiCorp East Bonneville Power Administration LFP (k)7/8 BORA LAGRANDE10PacifiCorp Inc.PacifiCorp East PacifiCorp West LFP 7/8 KPRT HURR11PacifiCorp Inc.PacifiCorp East PacifiCorp West LFP 7/8 BORA HURR12Shell Energy North America(US), L.P.Idaho Power Company Bonneville Power Administration LFP 7/8 LYPK LAGRANDE13Bonneville Power Administration PacifiCorp West PacifiCorp East LFP 7/8 M500 KPRT14Bonneville Power Administration PacifiCorp West PacifiCorp East LFP 7/8 SMLK KPRT15Powerex Corporation Avista PacifiCorp East LFP 7/8 LOLO BORA16Powerex Corporation PacifiCorp East PacifiCorp East LFP 7/8 JEFF BORA17Vitol Inc.Idaho Power Company Sierra Pacific Power LFP 7/8 MDSK M34518AmpRenew Offtake I LLC Idaho Power Company Sierra Pacific Power LFP 7/8 MDSK M34519Altop Energy Trading, LLC PacifiCorp East PacifiCorp East NF 7/8 JBSN BORA20American Falls Solar, LLC NF (l)1121American Falls Solar II, LLC NF 1122Avangrid Renewables, LLC NorthWestern/PacifiCorp East Sierra Pacific Power NF 7/8 AVAT.NWMT M34523Avangrid Renewables, LLC PacifiCorp East Bonneville Power Administration NF 7/8 BORA LAGRANDE24Avangrid Renewables, LLC NorthWestern/PacifiCorp East Sierra Pacific Power NF 7/8 BPAT.NWMT M34525Avangrid Renewables, LLC PacifiCorp East NorthWestern/PacifiCorp East NF 7/8 BRDY BPAT.NWMT26Avangrid Renewables, LLC PacifiCorp East Bonneville Power Administration NF 7/8 BRDY LAGRANDE27Avangrid Renewables, LLC PacifiCorp East Sierra Pacific Power NF 7/8 BRDY M34528Avangrid Renewables, LLC Bonneville Power Administration Sierra Pacific Power NF 7/8 LAGRANDE M34529Avangrid Renewables, LLC Avista Sierra Pacific Power NF 7/8 LOLO M34530Avangrid Renewables, LLC Sierra Pacific Power Bonneville Power Administration NF 7/8 M345 LAGRANDE31Avangrid Renewables, LLC PacifiCorp West Sierra Pacific Power NF 7/8 SMLK M34532Avista Corporation NorthWestern/PacifiCorp East Avista NF 7/8 AVAT.NWMT LOLO33Avista Corporation PacifiCorp East Bonneville Power Administration NF 7/8 BRDY LAGRANDE34Avista Corporation PacifiCorp East Avista NF 7/8 BRDY LOLO35Avista Corporation Avista Sierra Pacific Power NF 7/8 LOLO M345FERC FORM NO. 1 (ED. 12-90)
Page 328-330
36 Avista Corporation Sierra Pacific Power Avista NF 7/8 M345 LOLO
37 Basin Electric Power
Cooperative PacifiCorp East NorthWestern/PacifiCorp East NF 7/8 BRDY BPAT.NWMT
38 Basin Electric Power
Cooperative PacifiCorp East PacifiCorp East NF 7/8 BRDY JBSN
39 Basin Electric Power
Cooperative PacifiCorp East NorthWestern/PacifiCorp East NF 7/8 BRDY MLCK
40 Basin Electric Power
Cooperative PacifiCorp East NorthWestern/PacifiCorp East NF 7/8 JBSN BPAT.NWMT
41 Basin Electric Power
Cooperative PacifiCorp East PacifiCorp East NF 7/8 JBSN BRDY
42 Basin Electric Power
Cooperative NorthWestern/PacifiCorp East PacifiCorp East NF 7/8 MLCK JBSN
43 Basin Electric Power
Cooperative PacifiCorp West PacifiCorp East SFP 7/8 POP BRDY
44 Benson Creek Windfarm, LLC NF 11
45 Bonneville Power Administration PacifiCorp East Bonneville Power Administration NF 7/8 BORA BPASID
46 Bonneville Power Administration NorthWestern/PacifiCorp East PacifiCorp East NF 7/8 BPAT.NWMT ANTE
47 Bonneville Power Administration NorthWestern/PacifiCorp East PacifiCorp East NF 7/8 BPAT.NWMT BORA
48 Bonneville Power Administration NorthWestern/PacifiCorp East Sierra Pacific Power NF 7/8 BPAT.NWMT M345
49 Bonneville Power Administration PacifiCorp East Sierra Pacific Power NF 7/8 BRDY M345
50 Bonneville Power Administration Bonneville Power Administration PacifiCorp East NF 7/8 LAGRANDE BORA
51 Bonneville Power Administration Bonneville Power Administration PacifiCorp East NF 7/8 LAGRANDE KPRT
52 Bonneville Power Administration Bonneville Power Administration Bonneville Power Administration NF 7/8 LAGRANDE LAGRANDE
53 Bonneville Power Administration Bonneville Power Administration Sierra Pacific Power NF 7/8 LAGRANDE M345
54 Bonneville Power Administration Avista PacifiCorp East NF 7/8 LOLO BORA
55 Bonneville Power Administration Avista PacifiCorp East NF 7/8 LOLO KPRT
56 Bonneville Power Administration Avista Bonneville Power Administration NF 7/8 LOLO LAGRANDE
57 Bonneville Power Administration Avista Sierra Pacific Power NF 7/8 LOLO M345
58 Bonneville Power Administration PacifiCorp West PacifiCorp East NF 7/8 SMLK BORA
59 Bonneville Power Administration PacifiCorp West PacifiCorp East SFP 7/8 SMLK BRDY
60 Bonneville Power Administration PacifiCorp West Bonneville Power Administration NF 7/8 SMLK LAGRANDE
61 BP Energy Company PacifiCorp East PacifiCorp East NF 7/8 JBSN BORA
62 Brookfield Renewable Trading &
Marketing PacifiCorp East NorthWestern/PacifiCorp East NF 7/8 BRDY BPAT.NWMT
63 Brookfield Renewable Trading &
Marketing PacifiCorp East Bonneville Power Administration SFP 7/8 GSHN LAGRANDE
64 Brookfield Renewable Trading &
Marketing Sierra Pacific Power PacifiCorp East NF 7/8 M345 BRDY
65 Calpine Energy Services, L.P.NorthWestern/PacifiCorp East PacifiCorp East NF 7/8 BPAT.NWMT BRDY
66 Calpine Energy Services, L.P.PacifiCorp East Sierra Pacific Power NF 7/8 BRDY M345
67 Calpine Energy Services, L.P.Sierra Pacific Power Bonneville Power Administration NF 7/8 M345 LAGRANDE
68 Calpine Energy Services, L.P.Sierra Pacific Power Bonneville Power Administration SFP 7/8 M345 LAGRANDE
69 ConocoPhillips Company PacifiCorp East Bonneville Power Administration NF 7/8 BORA LAGRANDE
70 ConocoPhillips Company PacifiCorp East Bonneville Power Administration NF 7/8 BRDY LAGRANDE
71 ConocoPhillips Company Sierra Pacific Power PacifiCorp East NF 7/8 M345 BRDY
72 ConocoPhillips Company Sierra Pacific Power Bonneville Power Administration NF 7/8 M345 LAGRANDE
73 CP Energy Marketing (US) Inc.PacifiCorp East Avista SFP 7/8 BORA LOLO
TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456.1) (Including transactions referred to as "wheeling")
Line
No.
Payment By (Company of Public
Authority) (Footnote Affiliation)
(a)
Energy Received From (Company of
Public Authority) (Footnote
Affiliation)
(b)
Energy Delivered To (Company of
Public Authority) (Footnote
Affiliation)
(c)
Statistical
Classification
(d)
Ferc Rate
Schedule of
Tariff Number
(e)
Point of Receipt
(Substation or
Other
Designation)
(f)
Point of
Delivery
(Substation or
Other
Designation)
(g)
FERC FORM NO. 1 (ED. 12-90)
Page 328-330
36 Avista Corporation Sierra Pacific Power Avista NF 7/8 M345 LOLO37Basin Electric PowerCooperative PacifiCorp East NorthWestern/PacifiCorp East NF 7/8 BRDY BPAT.NWMT38Basin Electric PowerCooperative PacifiCorp East PacifiCorp East NF 7/8 BRDY JBSN39Basin Electric PowerCooperative PacifiCorp East NorthWestern/PacifiCorp East NF 7/8 BRDY MLCK40Basin Electric PowerCooperative PacifiCorp East NorthWestern/PacifiCorp East NF 7/8 JBSN BPAT.NWMT41Basin Electric PowerCooperative PacifiCorp East PacifiCorp East NF 7/8 JBSN BRDY42Basin Electric PowerCooperative NorthWestern/PacifiCorp East PacifiCorp East NF 7/8 MLCK JBSN43Basin Electric PowerCooperative PacifiCorp West PacifiCorp East SFP 7/8 POP BRDY44Benson Creek Windfarm, LLC NF 1145Bonneville Power Administration PacifiCorp East Bonneville Power Administration NF 7/8 BORA BPASID46Bonneville Power Administration NorthWestern/PacifiCorp East PacifiCorp East NF 7/8 BPAT.NWMT ANTE47Bonneville Power Administration NorthWestern/PacifiCorp East PacifiCorp East NF 7/8 BPAT.NWMT BORA48Bonneville Power Administration NorthWestern/PacifiCorp East Sierra Pacific Power NF 7/8 BPAT.NWMT M34549Bonneville Power Administration PacifiCorp East Sierra Pacific Power NF 7/8 BRDY M34550Bonneville Power Administration Bonneville Power Administration PacifiCorp East NF 7/8 LAGRANDE BORA51Bonneville Power Administration Bonneville Power Administration PacifiCorp East NF 7/8 LAGRANDE KPRT52Bonneville Power Administration Bonneville Power Administration Bonneville Power Administration NF 7/8 LAGRANDE LAGRANDE53Bonneville Power Administration Bonneville Power Administration Sierra Pacific Power NF 7/8 LAGRANDE M34554Bonneville Power Administration Avista PacifiCorp East NF 7/8 LOLO BORA55Bonneville Power Administration Avista PacifiCorp East NF 7/8 LOLO KPRT56Bonneville Power Administration Avista Bonneville Power Administration NF 7/8 LOLO LAGRANDE57Bonneville Power Administration Avista Sierra Pacific Power NF 7/8 LOLO M34558Bonneville Power Administration PacifiCorp West PacifiCorp East NF 7/8 SMLK BORA59Bonneville Power Administration PacifiCorp West PacifiCorp East SFP 7/8 SMLK BRDY60Bonneville Power Administration PacifiCorp West Bonneville Power Administration NF 7/8 SMLK LAGRANDE61BP Energy Company PacifiCorp East PacifiCorp East NF 7/8 JBSN BORA62Brookfield Renewable Trading &Marketing PacifiCorp East NorthWestern/PacifiCorp East NF 7/8 BRDY BPAT.NWMT63Brookfield Renewable Trading &Marketing PacifiCorp East Bonneville Power Administration SFP 7/8 GSHN LAGRANDE64Brookfield Renewable Trading &Marketing Sierra Pacific Power PacifiCorp East NF 7/8 M345 BRDY65Calpine Energy Services, L.P.NorthWestern/PacifiCorp East PacifiCorp East NF 7/8 BPAT.NWMT BRDY66Calpine Energy Services, L.P.PacifiCorp East Sierra Pacific Power NF 7/8 BRDY M34567Calpine Energy Services, L.P.Sierra Pacific Power Bonneville Power Administration NF 7/8 M345 LAGRANDE68Calpine Energy Services, L.P.Sierra Pacific Power Bonneville Power Administration SFP 7/8 M345 LAGRANDE69ConocoPhillips Company PacifiCorp East Bonneville Power Administration NF 7/8 BORA LAGRANDE70ConocoPhillips Company PacifiCorp East Bonneville Power Administration NF 7/8 BRDY LAGRANDE71ConocoPhillips Company Sierra Pacific Power PacifiCorp East NF 7/8 M345 BRDY72ConocoPhillips Company Sierra Pacific Power Bonneville Power Administration NF 7/8 M345 LAGRANDE73CP Energy Marketing (US) Inc.PacifiCorp East Avista SFP 7/8 BORA LOLOTRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456.1) (Including transactions referred to as "wheeling")LineNo.Payment By (Company of PublicAuthority) (Footnote Affiliation)(a)Energy Received From (Company ofPublic Authority) (FootnoteAffiliation)(b)Energy Delivered To (Company ofPublic Authority) (FootnoteAffiliation)(c)StatisticalClassification(d)Ferc RateSchedule ofTariff Number(e)Point of Receipt(Substation orOtherDesignation)(f)Point ofDelivery(Substation orOtherDesignation)(g)FERC FORM NO. 1 (ED. 12-90)Page 328-330
74 CP Energy Marketing (US) Inc.PacifiCorp East Bonneville Power Administration NF 7/8 BRDY LAGRANDE
75 CP Energy Marketing (US) Inc.PacifiCorp East Sierra Pacific Power NF 7/8 BRDY M345
76 CP Energy Marketing (US) Inc.PacifiCorp East Sierra Pacific Power NF 7/8 JEFF M345
77 Durbin Creek Windfarm, LLC NF 11
78 Dynasty Power Inc.PacifiCorp East NorthWestern/PacifiCorp East NF 7/8 BORA BPAT.NWMT
79 Dynasty Power Inc.PacifiCorp East PacifiCorp East NF 7/8 BORA BRDY
80 Dynasty Power Inc.PacifiCorp East PacifiCorp West NF 7/8 BORA H500
81 Dynasty Power Inc.PacifiCorp East PacifiCorp West SFP 7/8 BORA H500
82 Dynasty Power Inc.PacifiCorp East PacifiCorp West NF 7/8 BORA HURR
83 Dynasty Power Inc.PacifiCorp East PacifiCorp West SFP 7/8 BORA HURR
84 Dynasty Power Inc.PacifiCorp East PacifiCorp East NF 7/8 BORA JBSN
85 Dynasty Power Inc.PacifiCorp East Bonneville Power Administration NF 7/8 BORA LAGRANDE
86 Dynasty Power Inc.PacifiCorp East Bonneville Power Administration SFP 7/8 BORA LAGRANDE
87 Dynasty Power Inc.PacifiCorp East Avista NF 7/8 BORA LOLO
88 Dynasty Power Inc.PacifiCorp East Avista SFP 7/8 BORA LOLO
89 Dynasty Power Inc.PacifiCorp East Sierra Pacific Power NF 7/8 BORA M345
90 Dynasty Power Inc.NorthWestern/PacifiCorp East PacifiCorp East NF 7/8 BPAT.NWMT BORA
91 Dynasty Power Inc.NorthWestern/PacifiCorp East Bonneville Power Administration NF 7/8 BPAT.NWMT LAGRANDE
92 Dynasty Power Inc.PacifiCorp East PacifiCorp East NF 7/8 BRDY BORA
93 Dynasty Power Inc.PacifiCorp East PacifiCorp West SFP 7/8 BRDY H500
94 Dynasty Power Inc.PacifiCorp East PacifiCorp West SFP 7/8 BRDY HURR
95 Dynasty Power Inc.PacifiCorp East Bonneville Power Administration NF 7/8 BRDY LAGRANDE
96 Dynasty Power Inc.PacifiCorp East Sierra Pacific Power NF 7/8 BRDY M345
97 Dynasty Power Inc.PacifiCorp East PacifiCorp East NF 7/8 JBSN BORA
98 Dynasty Power Inc.PacifiCorp East PacifiCorp East SFP 7/8 JBSN BORA
99 Dynasty Power Inc.PacifiCorp East NorthWestern/PacifiCorp East NF 7/8 JBSN BPAT.NWMT
100 Dynasty Power Inc.PacifiCorp East PacifiCorp West NF 7/8 JBSN HURR
101 Dynasty Power Inc.PacifiCorp East Bonneville Power Administration NF 7/8 JBSN LAGRANDE
102 Dynasty Power Inc.PacifiCorp East Sierra Pacific Power NF 7/8 JBSN M345
103 Dynasty Power Inc.PacifiCorp East Sierra Pacific Power SFP 7/8 JBSN M345
104 Dynasty Power Inc.PacifiCorp East NorthWestern/PacifiCorp East NF 7/8 JBSN MLCK
105 Dynasty Power Inc.PacifiCorp East PacifiCorp West NF 7/8 JBSN POP
106 Dynasty Power Inc.PacifiCorp East PacifiCorp East NF 7/8 JEFF BORA
107 Dynasty Power Inc.Bonneville Power Administration PacifiCorp East NF 7/8 LAGRANDE BORA
108 Dynasty Power Inc.Bonneville Power Administration PacifiCorp East NF 7/8 LAGRANDE JBSN
109 Dynasty Power Inc.Bonneville Power Administration Avista NF 7/8 LAGRANDE LOLO
110 Dynasty Power Inc.Bonneville Power Administration Sierra Pacific Power NF 7/8 LAGRANDE M345
111 Dynasty Power Inc.Avista Bonneville Power Administration NF 7/8 LOLO LAGRANDE
112 Dynasty Power Inc.Sierra Pacific Power PacifiCorp East NF 7/8 M345 BORA
113 Dynasty Power Inc.Sierra Pacific Power PacifiCorp West NF 7/8 M345 H500
114 Dynasty Power Inc.Sierra Pacific Power Bonneville Power Administration NF 7/8 M345 LAGRANDE
115 Dynasty Power Inc.Sierra Pacific Power Avista NF 7/8 M345 LOLO
116 Dynasty Power Inc.Sierra Pacific Power NorthWestern/PacifiCorp East NF 7/8 M345 MLCK
TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456.1) (Including transactions referred to as "wheeling")
Line
No.
Payment By (Company of Public
Authority) (Footnote Affiliation)
(a)
Energy Received From (Company of
Public Authority) (Footnote
Affiliation)
(b)
Energy Delivered To (Company of
Public Authority) (Footnote
Affiliation)
(c)
Statistical
Classification
(d)
Ferc Rate
Schedule of
Tariff Number
(e)
Point of Receipt
(Substation or
Other
Designation)
(f)
Point of
Delivery
(Substation or
Other
Designation)
(g)
FERC FORM NO. 1 (ED. 12-90)
Page 328-330
74 CP Energy Marketing (US) Inc.PacifiCorp East Bonneville Power Administration NF 7/8 BRDY LAGRANDE75CP Energy Marketing (US) Inc.PacifiCorp East Sierra Pacific Power NF 7/8 BRDY M34576CP Energy Marketing (US) Inc.PacifiCorp East Sierra Pacific Power NF 7/8 JEFF M34577Durbin Creek Windfarm, LLC NF 1178Dynasty Power Inc.PacifiCorp East NorthWestern/PacifiCorp East NF 7/8 BORA BPAT.NWMT79Dynasty Power Inc.PacifiCorp East PacifiCorp East NF 7/8 BORA BRDY80Dynasty Power Inc.PacifiCorp East PacifiCorp West NF 7/8 BORA H50081Dynasty Power Inc.PacifiCorp East PacifiCorp West SFP 7/8 BORA H50082Dynasty Power Inc.PacifiCorp East PacifiCorp West NF 7/8 BORA HURR83Dynasty Power Inc.PacifiCorp East PacifiCorp West SFP 7/8 BORA HURR84Dynasty Power Inc.PacifiCorp East PacifiCorp East NF 7/8 BORA JBSN85Dynasty Power Inc.PacifiCorp East Bonneville Power Administration NF 7/8 BORA LAGRANDE86Dynasty Power Inc.PacifiCorp East Bonneville Power Administration SFP 7/8 BORA LAGRANDE87Dynasty Power Inc.PacifiCorp East Avista NF 7/8 BORA LOLO88Dynasty Power Inc.PacifiCorp East Avista SFP 7/8 BORA LOLO89Dynasty Power Inc.PacifiCorp East Sierra Pacific Power NF 7/8 BORA M34590Dynasty Power Inc.NorthWestern/PacifiCorp East PacifiCorp East NF 7/8 BPAT.NWMT BORA91Dynasty Power Inc.NorthWestern/PacifiCorp East Bonneville Power Administration NF 7/8 BPAT.NWMT LAGRANDE92Dynasty Power Inc.PacifiCorp East PacifiCorp East NF 7/8 BRDY BORA93Dynasty Power Inc.PacifiCorp East PacifiCorp West SFP 7/8 BRDY H50094Dynasty Power Inc.PacifiCorp East PacifiCorp West SFP 7/8 BRDY HURR95Dynasty Power Inc.PacifiCorp East Bonneville Power Administration NF 7/8 BRDY LAGRANDE96Dynasty Power Inc.PacifiCorp East Sierra Pacific Power NF 7/8 BRDY M34597Dynasty Power Inc.PacifiCorp East PacifiCorp East NF 7/8 JBSN BORA98Dynasty Power Inc.PacifiCorp East PacifiCorp East SFP 7/8 JBSN BORA99Dynasty Power Inc.PacifiCorp East NorthWestern/PacifiCorp East NF 7/8 JBSN BPAT.NWMT100Dynasty Power Inc.PacifiCorp East PacifiCorp West NF 7/8 JBSN HURR101Dynasty Power Inc.PacifiCorp East Bonneville Power Administration NF 7/8 JBSN LAGRANDE102Dynasty Power Inc.PacifiCorp East Sierra Pacific Power NF 7/8 JBSN M345103Dynasty Power Inc.PacifiCorp East Sierra Pacific Power SFP 7/8 JBSN M345104Dynasty Power Inc.PacifiCorp East NorthWestern/PacifiCorp East NF 7/8 JBSN MLCK105Dynasty Power Inc.PacifiCorp East PacifiCorp West NF 7/8 JBSN POP106Dynasty Power Inc.PacifiCorp East PacifiCorp East NF 7/8 JEFF BORA107Dynasty Power Inc.Bonneville Power Administration PacifiCorp East NF 7/8 LAGRANDE BORA108Dynasty Power Inc.Bonneville Power Administration PacifiCorp East NF 7/8 LAGRANDE JBSN109Dynasty Power Inc.Bonneville Power Administration Avista NF 7/8 LAGRANDE LOLO110Dynasty Power Inc.Bonneville Power Administration Sierra Pacific Power NF 7/8 LAGRANDE M345111Dynasty Power Inc.Avista Bonneville Power Administration NF 7/8 LOLO LAGRANDE112Dynasty Power Inc.Sierra Pacific Power PacifiCorp East NF 7/8 M345 BORA113Dynasty Power Inc.Sierra Pacific Power PacifiCorp West NF 7/8 M345 H500114Dynasty Power Inc.Sierra Pacific Power Bonneville Power Administration NF 7/8 M345 LAGRANDE115Dynasty Power Inc.Sierra Pacific Power Avista NF 7/8 M345 LOLO116Dynasty Power Inc.Sierra Pacific Power NorthWestern/PacifiCorp East NF 7/8 M345 MLCKTRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456.1) (Including transactions referred to as "wheeling")LineNo.Payment By (Company of PublicAuthority) (Footnote Affiliation)(a)Energy Received From (Company ofPublic Authority) (FootnoteAffiliation)(b)Energy Delivered To (Company ofPublic Authority) (FootnoteAffiliation)(c)StatisticalClassification(d)Ferc RateSchedule ofTariff Number(e)Point of Receipt(Substation orOtherDesignation)(f)Point ofDelivery(Substation orOtherDesignation)(g)FERC FORM NO. 1 (ED. 12-90)Page 328-330
117 Dynasty Power Inc.PacifiCorp West PacifiCorp East NF 7/8 SMLK BORA
118 Dynasty Power Inc.PacifiCorp West Sierra Pacific Power NF 7/8 SMLK M345
119 Dynasty Power Inc.Idaho Power Company PacifiCorp East NF 7/8 WALLAWALLA BORA
120 Dynasty Power Inc.Idaho Power Company Sierra Pacific Power NF 7/8 WALLAWALLA M345
121 Dynasty Power Inc.Idaho Power Company NorthWestern/PacifiCorp East NF 7/8 WALLAWALLA MLCK
122 EDF Trading North America,
LLC PacifiCorp East PacifiCorp East NF 7/8 JEFF GSHN
123 Energy Keepers, Inc.PacifiCorp East PacifiCorp East NF 7/8 BORA BRDY
124 Energy Keepers, Inc.PacifiCorp East NorthWestern/PacifiCorp East SFP 7/8 BRDY AVAT.NWMT
125 Energy Keepers, Inc.PacifiCorp East NorthWestern/PacifiCorp East NF 7/8 BRDY BPAT.NWMT
126 Energy Keepers, Inc.PacifiCorp East NorthWestern/PacifiCorp East SFP 7/8 BRDY BPAT.NWMT
127 Energy Keepers, Inc.PacifiCorp East PacifiCorp West SFP 7/8 BRDY H500
128 Energy Keepers, Inc.PacifiCorp East Bonneville Power Administration NF 7/8 BRDY LAGRANDE
129 Energy Keepers, Inc.PacifiCorp East Bonneville Power Administration SFP 7/8 BRDY LAGRANDE
130 Energy Keepers, Inc.PacifiCorp East Avista NF 7/8 BRDY LOLO
131 Energy Keepers, Inc.PacifiCorp East Avista SFP 7/8 BRDY LOLO
132 Energy Keepers, Inc.PacifiCorp East Sierra Pacific Power NF 7/8 BRDY M345
133 Energy Keepers, Inc.PacifiCorp East Sierra Pacific Power SFP 7/8 BRDY M345
134 Energy Keepers, Inc.PacifiCorp East PacifiCorp West NF 7/8 JBSN POP
135 Energy Keepers, Inc.PacifiCorp East Sierra Pacific Power NF 7/8 JEFF M345
136 Energy Keepers, Inc.Avista PacifiCorp East NF 7/8 LOLO BRDY
137 Energy Keepers, Inc.Avista Sierra Pacific Power NF 7/8 LOLO M345
138 Energy Keepers, Inc.Sierra Pacific Power PacifiCorp East NF 7/8 M345 BRDY
139 Energy Keepers, Inc.Sierra Pacific Power PacifiCorp East SFP 7/8 M345 BRDY
140 Energy Keepers, Inc.Sierra Pacific Power Bonneville Power Administration SFP 7/8 M345 LAGRANDE
141 Energy Keepers, Inc.Idaho Power Company PacifiCorp East NF 7/8 WALLAWALLA BRDY
142 Energy Keepers, Inc.Idaho Power Company Sierra Pacific Power NF 7/8 WALLAWALLA M345
143 Grove Solar Center, LLC NF 11
144 Guzman Energy Group LLC PacifiCorp East NorthWestern/PacifiCorp East NF 7/8 BORA BPAT.NWMT
145 Guzman Energy Group LLC PacifiCorp East PacifiCorp East NF 7/8 BORA BRDY
146 Guzman Energy Group LLC PacifiCorp East PacifiCorp West NF 7/8 BORA H500
147 Guzman Energy Group LLC PacifiCorp East PacifiCorp West SFP 7/8 BORA H500
148 Guzman Energy Group LLC PacifiCorp East Bonneville Power Administration NF 7/8 BORA LAGRANDE
149 Guzman Energy Group LLC PacifiCorp East Avista NF 7/8 BORA LOLO
150 Guzman Energy Group LLC PacifiCorp East Avista SFP 7/8 BORA LOLO
151 Guzman Energy Group LLC NorthWestern/PacifiCorp East PacifiCorp East NF 7/8 BPAT.NWMT BRDY
152 Guzman Energy Group LLC NorthWestern/PacifiCorp East PacifiCorp East NF 7/8 BPAT.NWMT JBSN
153 Guzman Energy Group LLC NorthWestern/PacifiCorp East Bonneville Power Administration NF 7/8 BPAT.NWMT LAGRANDE
154 Guzman Energy Group LLC PacifiCorp East NorthWestern/PacifiCorp East NF 7/8 BRDY AVAT.NWMT
155 Guzman Energy Group LLC PacifiCorp East NorthWestern/PacifiCorp East NF 7/8 BRDY BPAT.NWMT
156 Guzman Energy Group LLC PacifiCorp East PacifiCorp West NF 7/8 BRDY HURR
157 Guzman Energy Group LLC PacifiCorp East Idaho Power Company NF 7/8 BRDY IPCO
158 Guzman Energy Group LLC PacifiCorp East Idaho Power Company NF 7/8 BRDY IPCOEAST
159 Guzman Energy Group LLC PacifiCorp East Bonneville Power Administration NF 7/8 BRDY LAGRANDE
TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456.1) (Including transactions referred to as "wheeling")
Line
No.
Payment By (Company of Public
Authority) (Footnote Affiliation)
(a)
Energy Received From (Company of
Public Authority) (Footnote
Affiliation)
(b)
Energy Delivered To (Company of
Public Authority) (Footnote
Affiliation)
(c)
Statistical
Classification
(d)
Ferc Rate
Schedule of
Tariff Number
(e)
Point of Receipt
(Substation or
Other
Designation)
(f)
Point of
Delivery
(Substation or
Other
Designation)
(g)
FERC FORM NO. 1 (ED. 12-90)
Page 328-330
117 Dynasty Power Inc.PacifiCorp West PacifiCorp East NF 7/8 SMLK BORA118Dynasty Power Inc.PacifiCorp West Sierra Pacific Power NF 7/8 SMLK M345119Dynasty Power Inc.Idaho Power Company PacifiCorp East NF 7/8 WALLAWALLA BORA120Dynasty Power Inc.Idaho Power Company Sierra Pacific Power NF 7/8 WALLAWALLA M345121Dynasty Power Inc.Idaho Power Company NorthWestern/PacifiCorp East NF 7/8 WALLAWALLA MLCK122EDF Trading North America,LLC PacifiCorp East PacifiCorp East NF 7/8 JEFF GSHN123Energy Keepers, Inc.PacifiCorp East PacifiCorp East NF 7/8 BORA BRDY124Energy Keepers, Inc.PacifiCorp East NorthWestern/PacifiCorp East SFP 7/8 BRDY AVAT.NWMT125Energy Keepers, Inc.PacifiCorp East NorthWestern/PacifiCorp East NF 7/8 BRDY BPAT.NWMT126Energy Keepers, Inc.PacifiCorp East NorthWestern/PacifiCorp East SFP 7/8 BRDY BPAT.NWMT127Energy Keepers, Inc.PacifiCorp East PacifiCorp West SFP 7/8 BRDY H500128Energy Keepers, Inc.PacifiCorp East Bonneville Power Administration NF 7/8 BRDY LAGRANDE129Energy Keepers, Inc.PacifiCorp East Bonneville Power Administration SFP 7/8 BRDY LAGRANDE130Energy Keepers, Inc.PacifiCorp East Avista NF 7/8 BRDY LOLO131Energy Keepers, Inc.PacifiCorp East Avista SFP 7/8 BRDY LOLO132Energy Keepers, Inc.PacifiCorp East Sierra Pacific Power NF 7/8 BRDY M345133Energy Keepers, Inc.PacifiCorp East Sierra Pacific Power SFP 7/8 BRDY M345134Energy Keepers, Inc.PacifiCorp East PacifiCorp West NF 7/8 JBSN POP135Energy Keepers, Inc.PacifiCorp East Sierra Pacific Power NF 7/8 JEFF M345136Energy Keepers, Inc.Avista PacifiCorp East NF 7/8 LOLO BRDY137Energy Keepers, Inc.Avista Sierra Pacific Power NF 7/8 LOLO M345138Energy Keepers, Inc.Sierra Pacific Power PacifiCorp East NF 7/8 M345 BRDY139Energy Keepers, Inc.Sierra Pacific Power PacifiCorp East SFP 7/8 M345 BRDY140Energy Keepers, Inc.Sierra Pacific Power Bonneville Power Administration SFP 7/8 M345 LAGRANDE141Energy Keepers, Inc.Idaho Power Company PacifiCorp East NF 7/8 WALLAWALLA BRDY142Energy Keepers, Inc.Idaho Power Company Sierra Pacific Power NF 7/8 WALLAWALLA M345143Grove Solar Center, LLC NF 11144Guzman Energy Group LLC PacifiCorp East NorthWestern/PacifiCorp East NF 7/8 BORA BPAT.NWMT145Guzman Energy Group LLC PacifiCorp East PacifiCorp East NF 7/8 BORA BRDY146Guzman Energy Group LLC PacifiCorp East PacifiCorp West NF 7/8 BORA H500147Guzman Energy Group LLC PacifiCorp East PacifiCorp West SFP 7/8 BORA H500148Guzman Energy Group LLC PacifiCorp East Bonneville Power Administration NF 7/8 BORA LAGRANDE149Guzman Energy Group LLC PacifiCorp East Avista NF 7/8 BORA LOLO150Guzman Energy Group LLC PacifiCorp East Avista SFP 7/8 BORA LOLO151Guzman Energy Group LLC NorthWestern/PacifiCorp East PacifiCorp East NF 7/8 BPAT.NWMT BRDY152Guzman Energy Group LLC NorthWestern/PacifiCorp East PacifiCorp East NF 7/8 BPAT.NWMT JBSN153Guzman Energy Group LLC NorthWestern/PacifiCorp East Bonneville Power Administration NF 7/8 BPAT.NWMT LAGRANDE154Guzman Energy Group LLC PacifiCorp East NorthWestern/PacifiCorp East NF 7/8 BRDY AVAT.NWMT155Guzman Energy Group LLC PacifiCorp East NorthWestern/PacifiCorp East NF 7/8 BRDY BPAT.NWMT156Guzman Energy Group LLC PacifiCorp East PacifiCorp West NF 7/8 BRDY HURR157Guzman Energy Group LLC PacifiCorp East Idaho Power Company NF 7/8 BRDY IPCO158Guzman Energy Group LLC PacifiCorp East Idaho Power Company NF 7/8 BRDY IPCOEAST159Guzman Energy Group LLC PacifiCorp East Bonneville Power Administration NF 7/8 BRDY LAGRANDETRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456.1) (Including transactions referred to as "wheeling")LineNo.Payment By (Company of PublicAuthority) (Footnote Affiliation)(a)Energy Received From (Company ofPublic Authority) (FootnoteAffiliation)(b)Energy Delivered To (Company ofPublic Authority) (FootnoteAffiliation)(c)StatisticalClassification(d)Ferc RateSchedule ofTariff Number(e)Point of Receipt(Substation orOtherDesignation)(f)Point ofDelivery(Substation orOtherDesignation)(g)FERC FORM NO. 1 (ED. 12-90)Page 328-330
160 Guzman Energy Group LLC PacifiCorp East Avista NF 7/8 BRDY LOLO
161 Guzman Energy Group LLC PacifiCorp East Avista SFP 7/8 BRDY LOLO
162 Guzman Energy Group LLC PacifiCorp East Sierra Pacific Power NF 7/8 BRDY M345
163 Guzman Energy Group LLC PacifiCorp East NorthWestern/PacifiCorp East NF 7/8 BRDY MLCK
164 Guzman Energy Group LLC PacifiCorp East NorthWestern/PacifiCorp East NF 7/8 GSHN BPAT.NWMT
165 Guzman Energy Group LLC PacifiCorp East Avista NF 7/8 GSHN LOLO
166 Guzman Energy Group LLC PacifiCorp East NorthWestern/PacifiCorp East NF 7/8 JBSN AVAT.NWMT
167 Guzman Energy Group LLC PacifiCorp East NorthWestern/PacifiCorp East SFP 7/8 JBSN AVAT.NWMT
168 Guzman Energy Group LLC PacifiCorp East PacifiCorp East NF 7/8 JBSN BORA
169 Guzman Energy Group LLC PacifiCorp East NorthWestern/PacifiCorp East NF 7/8 JBSN BPAT.NWMT
170 Guzman Energy Group LLC PacifiCorp East NorthWestern/PacifiCorp East SFP 7/8 JBSN BPAT.NWMT
171 Guzman Energy Group LLC PacifiCorp East PacifiCorp East NF 7/8 JBSN BRDY
172 Guzman Energy Group LLC PacifiCorp East PacifiCorp East SFP 7/8 JBSN BRDY
173 Guzman Energy Group LLC PacifiCorp East PacifiCorp East NF 7/8 JBSN GSHN
174 Guzman Energy Group LLC PacifiCorp East PacifiCorp West NF 7/8 JBSN H500
175 Guzman Energy Group LLC PacifiCorp East PacifiCorp West NF 7/8 JBSN HURR
176 Guzman Energy Group LLC PacifiCorp East Bonneville Power Administration NF 7/8 JBSN LAGRANDE
177 Guzman Energy Group LLC PacifiCorp East Bonneville Power Administration SFP 7/8 JBSN LAGRANDE
178 Guzman Energy Group LLC PacifiCorp East Avista NF 7/8 JBSN LOLO
179 Guzman Energy Group LLC PacifiCorp East Avista SFP 7/8 JBSN LOLO
180 Guzman Energy Group LLC PacifiCorp East Sierra Pacific Power NF 7/8 JBSN M345
181 Guzman Energy Group LLC PacifiCorp East Sierra Pacific Power SFP 7/8 JBSN M345
182 Guzman Energy Group LLC PacifiCorp East PacifiCorp West NF 7/8 JBSN POP
183 Guzman Energy Group LLC Bonneville Power Administration PacifiCorp East NF 7/8 LAGRANDE BORA
184 Guzman Energy Group LLC Bonneville Power Administration PacifiCorp East NF 7/8 LAGRANDE JBSN
185 Guzman Energy Group LLC Avista PacifiCorp East NF 7/8 LOLO BORA
186 Guzman Energy Group LLC Avista PacifiCorp East NF 7/8 LOLO BRDY
187 Guzman Energy Group LLC Avista PacifiCorp West NF 7/8 LOLO H500
188 Guzman Energy Group LLC Avista Sierra Pacific Power NF 7/8 LOLO M345
189 Guzman Energy Group LLC Sierra Pacific Power NorthWestern/PacifiCorp East NF 7/8 M345 BPAT.NWMT
190 Guzman Energy Group LLC Sierra Pacific Power PacifiCorp West SFP 7/8 M345 H500
191 Guzman Energy Group LLC Sierra Pacific Power Bonneville Power Administration NF 7/8 M345 LAGRANDE
192 Guzman Energy Group LLC Sierra Pacific Power Bonneville Power Administration SFP 7/8 M345 LAGRANDE
193 Guzman Energy Group LLC Sierra Pacific Power Avista NF 7/8 M345 LOLO
194 Guzman Energy Group LLC Sierra Pacific Power Avista SFP 7/8 M345 LOLO
195 Guzman Energy Group LLC PacifiCorp West NorthWestern/PacifiCorp East NF 7/8 POP BPAT.NWMT
196 Guzman Energy Group LLC PacifiCorp West Avista NF 7/8 POP LOLO
197 Guzman Energy Group LLC Idaho Power Company PacifiCorp East NF 7/8 WALLAWALLA BORA
198 Idaho Wind Partners 1, LLC
(Camp Reed Wind Park)NF 11
199 Idaho Wind Partners 1, LLC
(Oregon Trail Wind Park)NF 11
200 Idaho Wind Partners 1, LLC
(Payne's Ferry Wind Park)NF 11
TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456.1) (Including transactions referred to as "wheeling")
Line
No.
Payment By (Company of Public
Authority) (Footnote Affiliation)
(a)
Energy Received From (Company of
Public Authority) (Footnote
Affiliation)
(b)
Energy Delivered To (Company of
Public Authority) (Footnote
Affiliation)
(c)
Statistical
Classification
(d)
Ferc Rate
Schedule of
Tariff Number
(e)
Point of Receipt
(Substation or
Other
Designation)
(f)
Point of
Delivery
(Substation or
Other
Designation)
(g)
FERC FORM NO. 1 (ED. 12-90)
Page 328-330
160 Guzman Energy Group LLC PacifiCorp East Avista NF 7/8 BRDY LOLO161Guzman Energy Group LLC PacifiCorp East Avista SFP 7/8 BRDY LOLO162Guzman Energy Group LLC PacifiCorp East Sierra Pacific Power NF 7/8 BRDY M345163Guzman Energy Group LLC PacifiCorp East NorthWestern/PacifiCorp East NF 7/8 BRDY MLCK164Guzman Energy Group LLC PacifiCorp East NorthWestern/PacifiCorp East NF 7/8 GSHN BPAT.NWMT165Guzman Energy Group LLC PacifiCorp East Avista NF 7/8 GSHN LOLO166Guzman Energy Group LLC PacifiCorp East NorthWestern/PacifiCorp East NF 7/8 JBSN AVAT.NWMT167Guzman Energy Group LLC PacifiCorp East NorthWestern/PacifiCorp East SFP 7/8 JBSN AVAT.NWMT168Guzman Energy Group LLC PacifiCorp East PacifiCorp East NF 7/8 JBSN BORA169Guzman Energy Group LLC PacifiCorp East NorthWestern/PacifiCorp East NF 7/8 JBSN BPAT.NWMT170Guzman Energy Group LLC PacifiCorp East NorthWestern/PacifiCorp East SFP 7/8 JBSN BPAT.NWMT171Guzman Energy Group LLC PacifiCorp East PacifiCorp East NF 7/8 JBSN BRDY172Guzman Energy Group LLC PacifiCorp East PacifiCorp East SFP 7/8 JBSN BRDY173Guzman Energy Group LLC PacifiCorp East PacifiCorp East NF 7/8 JBSN GSHN174Guzman Energy Group LLC PacifiCorp East PacifiCorp West NF 7/8 JBSN H500175Guzman Energy Group LLC PacifiCorp East PacifiCorp West NF 7/8 JBSN HURR176Guzman Energy Group LLC PacifiCorp East Bonneville Power Administration NF 7/8 JBSN LAGRANDE177Guzman Energy Group LLC PacifiCorp East Bonneville Power Administration SFP 7/8 JBSN LAGRANDE178Guzman Energy Group LLC PacifiCorp East Avista NF 7/8 JBSN LOLO179Guzman Energy Group LLC PacifiCorp East Avista SFP 7/8 JBSN LOLO180Guzman Energy Group LLC PacifiCorp East Sierra Pacific Power NF 7/8 JBSN M345181Guzman Energy Group LLC PacifiCorp East Sierra Pacific Power SFP 7/8 JBSN M345182Guzman Energy Group LLC PacifiCorp East PacifiCorp West NF 7/8 JBSN POP183Guzman Energy Group LLC Bonneville Power Administration PacifiCorp East NF 7/8 LAGRANDE BORA184Guzman Energy Group LLC Bonneville Power Administration PacifiCorp East NF 7/8 LAGRANDE JBSN185Guzman Energy Group LLC Avista PacifiCorp East NF 7/8 LOLO BORA186Guzman Energy Group LLC Avista PacifiCorp East NF 7/8 LOLO BRDY187Guzman Energy Group LLC Avista PacifiCorp West NF 7/8 LOLO H500188Guzman Energy Group LLC Avista Sierra Pacific Power NF 7/8 LOLO M345189Guzman Energy Group LLC Sierra Pacific Power NorthWestern/PacifiCorp East NF 7/8 M345 BPAT.NWMT190Guzman Energy Group LLC Sierra Pacific Power PacifiCorp West SFP 7/8 M345 H500191Guzman Energy Group LLC Sierra Pacific Power Bonneville Power Administration NF 7/8 M345 LAGRANDE192Guzman Energy Group LLC Sierra Pacific Power Bonneville Power Administration SFP 7/8 M345 LAGRANDE193Guzman Energy Group LLC Sierra Pacific Power Avista NF 7/8 M345 LOLO194Guzman Energy Group LLC Sierra Pacific Power Avista SFP 7/8 M345 LOLO195Guzman Energy Group LLC PacifiCorp West NorthWestern/PacifiCorp East NF 7/8 POP BPAT.NWMT196Guzman Energy Group LLC PacifiCorp West Avista NF 7/8 POP LOLO197Guzman Energy Group LLC Idaho Power Company PacifiCorp East NF 7/8 WALLAWALLA BORA198Idaho Wind Partners 1, LLC(Camp Reed Wind Park)NF 11199Idaho Wind Partners 1, LLC(Oregon Trail Wind Park)NF 11200Idaho Wind Partners 1, LLC(Payne's Ferry Wind Park)NF 11TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456.1) (Including transactions referred to as "wheeling")LineNo.Payment By (Company of PublicAuthority) (Footnote Affiliation)(a)Energy Received From (Company ofPublic Authority) (FootnoteAffiliation)(b)Energy Delivered To (Company ofPublic Authority) (FootnoteAffiliation)(c)StatisticalClassification(d)Ferc RateSchedule ofTariff Number(e)Point of Receipt(Substation orOtherDesignation)(f)Point ofDelivery(Substation orOtherDesignation)(g)FERC FORM NO. 1 (ED. 12-90)Page 328-330
201 Idaho Wind Partners 1, LLC
(Thousand Springs Wind Park)NF 11
202 Idaho Wind Partners 1, LLC
(Tuana Gulch Wind Park)NF 11
203 Idaho Wind Partners 1, LLC
(Yahoo Creek Wind Park)NF 11
204 Jett Creek Windfarm, LLC NF 11
205 Lime Wind LLC NF 11
206 Macquarie Energy, LLC NorthWestern/PacifiCorp East Sierra Pacific Power SFP 7/8 AVAT.NWMT M345
207 Macquarie Energy, LLC PacifiCorp East NorthWestern/PacifiCorp East NF 7/8 BORA AVAT.NWMT
208 Macquarie Energy, LLC PacifiCorp East NorthWestern/PacifiCorp East NF 7/8 BORA BPAT.NWMT
209 Macquarie Energy, LLC PacifiCorp East PacifiCorp East SFP 7/8 BORA BRDY
210 Macquarie Energy, LLC PacifiCorp East Bonneville Power Administration NF 7/8 BORA LAGRANDE
211 Macquarie Energy, LLC PacifiCorp East Bonneville Power Administration SFP 7/8 BORA LAGRANDE
212 Macquarie Energy, LLC PacifiCorp East Avista NF 7/8 BORA LOLO
213 Macquarie Energy, LLC PacifiCorp East Sierra Pacific Power SFP 7/8 BORA M345
214 Macquarie Energy, LLC NorthWestern/PacifiCorp East Avista SFP 7/8 BPAT.NWMT LOLO
215 Macquarie Energy, LLC NorthWestern/PacifiCorp East Sierra Pacific Power NF 7/8 BPAT.NWMT M345
216 Macquarie Energy, LLC NorthWestern/PacifiCorp East Sierra Pacific Power SFP 7/8 BPAT.NWMT M345
217 Macquarie Energy, LLC PacifiCorp East NorthWestern/PacifiCorp East NF 7/8 BRDY AVAT.NWMT
218 Macquarie Energy, LLC PacifiCorp East NorthWestern/PacifiCorp East SFP 7/8 BRDY BPAT.NWMT
219 Macquarie Energy, LLC PacifiCorp East Avista NF 7/8 BRDY LOLO
220 Macquarie Energy, LLC PacifiCorp East Avista SFP 7/8 BRDY LOLO
221 Macquarie Energy, LLC PacifiCorp East Sierra Pacific Power SFP 7/8 BRDY M345
222 Macquarie Energy, LLC PacifiCorp East NorthWestern/PacifiCorp East SFP 7/8 BRDY MLCK
223 Macquarie Energy, LLC PacifiCorp East PacifiCorp East NF 7/8 JBSN BORA
224 Macquarie Energy, LLC PacifiCorp East PacifiCorp East NF 7/8 JBSN BRDY
225 Macquarie Energy, LLC PacifiCorp East PacifiCorp East SFP 7/8 JBSN BRDY
226 Macquarie Energy, LLC PacifiCorp East Sierra Pacific Power NF 7/8 JBSN M345
227 Macquarie Energy, LLC PacifiCorp East NorthWestern/PacifiCorp East NF 7/8 JBSN MLCK
228 Macquarie Energy, LLC Sierra Pacific Power NorthWestern/PacifiCorp East NF 7/8 M345 AVAT.NWMT
229 Macquarie Energy, LLC Sierra Pacific Power NorthWestern/PacifiCorp East SFP 7/8 M345 AVAT.NWMT
230 Macquarie Energy, LLC Sierra Pacific Power NorthWestern/PacifiCorp East SFP 7/8 M345 BPAT.NWMT
231 Macquarie Energy, LLC Sierra Pacific Power PacifiCorp East NF 7/8 M345 BRDY
232 Macquarie Energy, LLC Sierra Pacific Power PacifiCorp East SFP 7/8 M345 BRDY
233 Macquarie Energy, LLC Sierra Pacific Power Bonneville Power Administration NF 7/8 M345 LAGRANDE
234 Macquarie Energy, LLC Sierra Pacific Power Bonneville Power Administration SFP 7/8 M345 LAGRANDE
235 Macquarie Energy, LLC Sierra Pacific Power Avista NF 7/8 M345 LOLO
236 Macquarie Energy, LLC Sierra Pacific Power Avista SFP 7/8 M345 LOLO
237 Macquarie Energy, LLC Sierra Pacific Power NorthWestern/PacifiCorp East SFP 7/8 M345 MLCK
238 Mag Energy Solutions NorthWestern/PacifiCorp East Sierra Pacific Power NF 7/8 AVAT.NWMT M345
239 Mag Energy Solutions Idaho Power Company PacifiCorp East NF 7/8 BGSY JEFF
240 Mag Energy Solutions NorthWestern/PacifiCorp East Sierra Pacific Power NF 7/8 BPAT.NWMT M345
241 Mag Energy Solutions PacifiCorp East Sierra Pacific Power NF 7/8 BRDY M345
242 Mag Energy Solutions PacifiCorp East Sierra Pacific Power NF 7/8 JBSN M345
TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456.1) (Including transactions referred to as "wheeling")
Line
No.
Payment By (Company of Public
Authority) (Footnote Affiliation)
(a)
Energy Received From (Company of
Public Authority) (Footnote
Affiliation)
(b)
Energy Delivered To (Company of
Public Authority) (Footnote
Affiliation)
(c)
Statistical
Classification
(d)
Ferc Rate
Schedule of
Tariff Number
(e)
Point of Receipt
(Substation or
Other
Designation)
(f)
Point of
Delivery
(Substation or
Other
Designation)
(g)
FERC FORM NO. 1 (ED. 12-90)
Page 328-330
201 Idaho Wind Partners 1, LLC(Thousand Springs Wind Park)NF 11202Idaho Wind Partners 1, LLC(Tuana Gulch Wind Park)NF 11203Idaho Wind Partners 1, LLC(Yahoo Creek Wind Park)NF 11204Jett Creek Windfarm, LLC NF 11205Lime Wind LLC NF 11206Macquarie Energy, LLC NorthWestern/PacifiCorp East Sierra Pacific Power SFP 7/8 AVAT.NWMT M345207Macquarie Energy, LLC PacifiCorp East NorthWestern/PacifiCorp East NF 7/8 BORA AVAT.NWMT208Macquarie Energy, LLC PacifiCorp East NorthWestern/PacifiCorp East NF 7/8 BORA BPAT.NWMT209Macquarie Energy, LLC PacifiCorp East PacifiCorp East SFP 7/8 BORA BRDY210Macquarie Energy, LLC PacifiCorp East Bonneville Power Administration NF 7/8 BORA LAGRANDE211Macquarie Energy, LLC PacifiCorp East Bonneville Power Administration SFP 7/8 BORA LAGRANDE212Macquarie Energy, LLC PacifiCorp East Avista NF 7/8 BORA LOLO213Macquarie Energy, LLC PacifiCorp East Sierra Pacific Power SFP 7/8 BORA M345214Macquarie Energy, LLC NorthWestern/PacifiCorp East Avista SFP 7/8 BPAT.NWMT LOLO215Macquarie Energy, LLC NorthWestern/PacifiCorp East Sierra Pacific Power NF 7/8 BPAT.NWMT M345216Macquarie Energy, LLC NorthWestern/PacifiCorp East Sierra Pacific Power SFP 7/8 BPAT.NWMT M345217Macquarie Energy, LLC PacifiCorp East NorthWestern/PacifiCorp East NF 7/8 BRDY AVAT.NWMT218Macquarie Energy, LLC PacifiCorp East NorthWestern/PacifiCorp East SFP 7/8 BRDY BPAT.NWMT219Macquarie Energy, LLC PacifiCorp East Avista NF 7/8 BRDY LOLO220Macquarie Energy, LLC PacifiCorp East Avista SFP 7/8 BRDY LOLO221Macquarie Energy, LLC PacifiCorp East Sierra Pacific Power SFP 7/8 BRDY M345222Macquarie Energy, LLC PacifiCorp East NorthWestern/PacifiCorp East SFP 7/8 BRDY MLCK223Macquarie Energy, LLC PacifiCorp East PacifiCorp East NF 7/8 JBSN BORA224Macquarie Energy, LLC PacifiCorp East PacifiCorp East NF 7/8 JBSN BRDY225Macquarie Energy, LLC PacifiCorp East PacifiCorp East SFP 7/8 JBSN BRDY226Macquarie Energy, LLC PacifiCorp East Sierra Pacific Power NF 7/8 JBSN M345227Macquarie Energy, LLC PacifiCorp East NorthWestern/PacifiCorp East NF 7/8 JBSN MLCK228Macquarie Energy, LLC Sierra Pacific Power NorthWestern/PacifiCorp East NF 7/8 M345 AVAT.NWMT229Macquarie Energy, LLC Sierra Pacific Power NorthWestern/PacifiCorp East SFP 7/8 M345 AVAT.NWMT230Macquarie Energy, LLC Sierra Pacific Power NorthWestern/PacifiCorp East SFP 7/8 M345 BPAT.NWMT231Macquarie Energy, LLC Sierra Pacific Power PacifiCorp East NF 7/8 M345 BRDY232Macquarie Energy, LLC Sierra Pacific Power PacifiCorp East SFP 7/8 M345 BRDY233Macquarie Energy, LLC Sierra Pacific Power Bonneville Power Administration NF 7/8 M345 LAGRANDE234Macquarie Energy, LLC Sierra Pacific Power Bonneville Power Administration SFP 7/8 M345 LAGRANDE235Macquarie Energy, LLC Sierra Pacific Power Avista NF 7/8 M345 LOLO236Macquarie Energy, LLC Sierra Pacific Power Avista SFP 7/8 M345 LOLO237Macquarie Energy, LLC Sierra Pacific Power NorthWestern/PacifiCorp East SFP 7/8 M345 MLCK238Mag Energy Solutions NorthWestern/PacifiCorp East Sierra Pacific Power NF 7/8 AVAT.NWMT M345239Mag Energy Solutions Idaho Power Company PacifiCorp East NF 7/8 BGSY JEFF240Mag Energy Solutions NorthWestern/PacifiCorp East Sierra Pacific Power NF 7/8 BPAT.NWMT M345241Mag Energy Solutions PacifiCorp East Sierra Pacific Power NF 7/8 BRDY M345242Mag Energy Solutions PacifiCorp East Sierra Pacific Power NF 7/8 JBSN M345TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456.1) (Including transactions referred to as "wheeling")LineNo.Payment By (Company of PublicAuthority) (Footnote Affiliation)(a)Energy Received From (Company ofPublic Authority) (FootnoteAffiliation)(b)Energy Delivered To (Company ofPublic Authority) (FootnoteAffiliation)(c)StatisticalClassification(d)Ferc RateSchedule ofTariff Number(e)Point of Receipt(Substation orOtherDesignation)(f)Point ofDelivery(Substation orOtherDesignation)(g)FERC FORM NO. 1 (ED. 12-90)Page 328-330
243 Mag Energy Solutions PacifiCorp East Sierra Pacific Power NF 7/8 JEFF M345
244 Mag Energy Solutions Sierra Pacific Power NorthWestern/PacifiCorp East NF 7/8 M345 BPAT.NWMT
245 Mag Energy Solutions Sierra Pacific Power PacifiCorp East NF 7/8 M345 BRDY
246 Mag Energy Solutions Sierra Pacific Power PacifiCorp East NF 7/8 M345 GSHN
247 Mercuria Energy America, LLC NorthWestern/PacifiCorp East Bonneville Power Administration NF 7/8 BPAT.NWMT LAGRANDE
248 Mercuria Energy America, LLC NorthWestern/PacifiCorp East Sierra Pacific Power NF 7/8 BPAT.NWMT M345
249 Mercuria Energy America, LLC PacifiCorp East PacifiCorp East NF 7/8 BRDY ANTE
250 Mercuria Energy America, LLC PacifiCorp East NorthWestern/PacifiCorp East NF 7/8 BRDY BPAT.NWMT
251 Mercuria Energy America, LLC PacifiCorp East Sierra Pacific Power NF 7/8 BRDY M345
252 Mercuria Energy America, LLC PacifiCorp East PacifiCorp East NF 7/8 JBSN BORA
253 Mercuria Energy America, LLC PacifiCorp East Bonneville Power Administration NF 7/8 JBSN LAGRANDE
254 Mercuria Energy America, LLC PacifiCorp East Sierra Pacific Power NF 7/8 JBSN M345
255 Mercuria Energy America, LLC PacifiCorp East PacifiCorp East NF 7/8 JEFF BRDY
256 Mercuria Energy America, LLC PacifiCorp East Sierra Pacific Power NF 7/8 JEFF M345
257 Mercuria Energy America, LLC Idaho Power Company PacifiCorp East NF 7/8 WALLAWALLA BRDY
258 Milner Dam Wind Park, LLC NF 11
259 Morgan Stanley Capital Group,
Inc.NorthWestern/PacifiCorp East PacifiCorp East SFP 7/8 AVAT.NWMT BORA
260 Morgan Stanley Capital Group,
Inc.NorthWestern/PacifiCorp East Bonneville Power Administration NF 7/8 AVAT.NWMT LAGRANDE
261 Morgan Stanley Capital Group,
Inc.NorthWestern/PacifiCorp East Sierra Pacific Power NF 7/8 AVAT.NWMT M345
262 Morgan Stanley Capital Group,
Inc.NorthWestern/PacifiCorp East Sierra Pacific Power SFP 7/8 AVAT.NWMT M345
263 Morgan Stanley Capital Group,
Inc.PacifiCorp East NorthWestern/PacifiCorp East NF 7/8 BORA AVAT.NWMT
264 Morgan Stanley Capital Group,
Inc.PacifiCorp East PacifiCorp East NF 7/8 BORA BRDY
265 Morgan Stanley Capital Group,
Inc.PacifiCorp East PacifiCorp East SFP 7/8 BORA BRDY
266 Morgan Stanley Capital Group,
Inc.PacifiCorp East PacifiCorp West NF 7/8 BORA H500
267 Morgan Stanley Capital Group,
Inc.PacifiCorp East PacifiCorp West SFP 7/8 BORA H500
268 Morgan Stanley Capital Group,
Inc.PacifiCorp East Bonneville Power Administration NF 7/8 BORA LAGRANDE
269 Morgan Stanley Capital Group,
Inc.PacifiCorp East Bonneville Power Administration SFP 7/8 BORA LAGRANDE
270 Morgan Stanley Capital Group,
Inc.PacifiCorp East Avista NF 7/8 BORA LOLO
271 Morgan Stanley Capital Group,
Inc.PacifiCorp East Avista SFP 7/8 BORA LOLO
272 Morgan Stanley Capital Group,
Inc.PacifiCorp East Sierra Pacific Power NF 7/8 BORA M345
273 Morgan Stanley Capital Group,
Inc.NorthWestern/PacifiCorp East PacifiCorp East SFP 7/8 BPAT.NWMT BORA
274 Morgan Stanley Capital Group,
Inc.NorthWestern/PacifiCorp East PacifiCorp East NF 7/8 BPAT.NWMT BRDY
275 Morgan Stanley Capital Group,
Inc.NorthWestern/PacifiCorp East PacifiCorp East SFP 7/8 BPAT.NWMT BRDY
276 Morgan Stanley Capital Group,
Inc.NorthWestern/PacifiCorp East Bonneville Power Administration NF 7/8 BPAT.NWMT LAGRANDE
TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456.1) (Including transactions referred to as "wheeling")
Line
No.
Payment By (Company of Public
Authority) (Footnote Affiliation)
(a)
Energy Received From (Company of
Public Authority) (Footnote
Affiliation)
(b)
Energy Delivered To (Company of
Public Authority) (Footnote
Affiliation)
(c)
Statistical
Classification
(d)
Ferc Rate
Schedule of
Tariff Number
(e)
Point of Receipt
(Substation or
Other
Designation)
(f)
Point of
Delivery
(Substation or
Other
Designation)
(g)
FERC FORM NO. 1 (ED. 12-90)
Page 328-330
243 Mag Energy Solutions PacifiCorp East Sierra Pacific Power NF 7/8 JEFF M345244Mag Energy Solutions Sierra Pacific Power NorthWestern/PacifiCorp East NF 7/8 M345 BPAT.NWMT245Mag Energy Solutions Sierra Pacific Power PacifiCorp East NF 7/8 M345 BRDY246Mag Energy Solutions Sierra Pacific Power PacifiCorp East NF 7/8 M345 GSHN247Mercuria Energy America, LLC NorthWestern/PacifiCorp East Bonneville Power Administration NF 7/8 BPAT.NWMT LAGRANDE248Mercuria Energy America, LLC NorthWestern/PacifiCorp East Sierra Pacific Power NF 7/8 BPAT.NWMT M345249Mercuria Energy America, LLC PacifiCorp East PacifiCorp East NF 7/8 BRDY ANTE250Mercuria Energy America, LLC PacifiCorp East NorthWestern/PacifiCorp East NF 7/8 BRDY BPAT.NWMT251Mercuria Energy America, LLC PacifiCorp East Sierra Pacific Power NF 7/8 BRDY M345252Mercuria Energy America, LLC PacifiCorp East PacifiCorp East NF 7/8 JBSN BORA253Mercuria Energy America, LLC PacifiCorp East Bonneville Power Administration NF 7/8 JBSN LAGRANDE254Mercuria Energy America, LLC PacifiCorp East Sierra Pacific Power NF 7/8 JBSN M345255Mercuria Energy America, LLC PacifiCorp East PacifiCorp East NF 7/8 JEFF BRDY256Mercuria Energy America, LLC PacifiCorp East Sierra Pacific Power NF 7/8 JEFF M345257Mercuria Energy America, LLC Idaho Power Company PacifiCorp East NF 7/8 WALLAWALLA BRDY258Milner Dam Wind Park, LLC NF 11259Morgan Stanley Capital Group,Inc.NorthWestern/PacifiCorp East PacifiCorp East SFP 7/8 AVAT.NWMT BORA260Morgan Stanley Capital Group,Inc.NorthWestern/PacifiCorp East Bonneville Power Administration NF 7/8 AVAT.NWMT LAGRANDE261Morgan Stanley Capital Group,Inc.NorthWestern/PacifiCorp East Sierra Pacific Power NF 7/8 AVAT.NWMT M345262Morgan Stanley Capital Group,Inc.NorthWestern/PacifiCorp East Sierra Pacific Power SFP 7/8 AVAT.NWMT M345263Morgan Stanley Capital Group,Inc.PacifiCorp East NorthWestern/PacifiCorp East NF 7/8 BORA AVAT.NWMT264Morgan Stanley Capital Group,Inc.PacifiCorp East PacifiCorp East NF 7/8 BORA BRDY265Morgan Stanley Capital Group,Inc.PacifiCorp East PacifiCorp East SFP 7/8 BORA BRDY266Morgan Stanley Capital Group,Inc.PacifiCorp East PacifiCorp West NF 7/8 BORA H500267Morgan Stanley Capital Group,Inc.PacifiCorp East PacifiCorp West SFP 7/8 BORA H500268Morgan Stanley Capital Group,Inc.PacifiCorp East Bonneville Power Administration NF 7/8 BORA LAGRANDE269Morgan Stanley Capital Group,Inc.PacifiCorp East Bonneville Power Administration SFP 7/8 BORA LAGRANDE270Morgan Stanley Capital Group,Inc.PacifiCorp East Avista NF 7/8 BORA LOLO271Morgan Stanley Capital Group,Inc.PacifiCorp East Avista SFP 7/8 BORA LOLO272Morgan Stanley Capital Group,Inc.PacifiCorp East Sierra Pacific Power NF 7/8 BORA M345273Morgan Stanley Capital Group,Inc.NorthWestern/PacifiCorp East PacifiCorp East SFP 7/8 BPAT.NWMT BORA274Morgan Stanley Capital Group,Inc.NorthWestern/PacifiCorp East PacifiCorp East NF 7/8 BPAT.NWMT BRDY275Morgan Stanley Capital Group,Inc.NorthWestern/PacifiCorp East PacifiCorp East SFP 7/8 BPAT.NWMT BRDY276Morgan Stanley Capital Group,Inc.NorthWestern/PacifiCorp East Bonneville Power Administration NF 7/8 BPAT.NWMT LAGRANDETRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456.1) (Including transactions referred to as "wheeling")LineNo.Payment By (Company of PublicAuthority) (Footnote Affiliation)(a)Energy Received From (Company ofPublic Authority) (FootnoteAffiliation)(b)Energy Delivered To (Company ofPublic Authority) (FootnoteAffiliation)(c)StatisticalClassification(d)Ferc RateSchedule ofTariff Number(e)Point of Receipt(Substation orOtherDesignation)(f)Point ofDelivery(Substation orOtherDesignation)(g)FERC FORM NO. 1 (ED. 12-90)Page 328-330
277 Morgan Stanley Capital Group,
Inc.NorthWestern/PacifiCorp East Avista NF 7/8 BPAT.NWMT LOLO
278 Morgan Stanley Capital Group,
Inc.NorthWestern/PacifiCorp East Sierra Pacific Power NF 7/8 BPAT.NWMT M345
279 Morgan Stanley Capital Group,
Inc.NorthWestern/PacifiCorp East Sierra Pacific Power SFP 7/8 BPAT.NWMT M345
280 Morgan Stanley Capital Group,
Inc.PacifiCorp East NorthWestern/PacifiCorp East NF 7/8 BRDY AVAT.NWMT
281 Morgan Stanley Capital Group,
Inc.PacifiCorp East PacifiCorp East NF 7/8 BRDY BORA
282 Morgan Stanley Capital Group,
Inc.PacifiCorp East PacifiCorp East SFP 7/8 BRDY BORA
283 Morgan Stanley Capital Group,
Inc.PacifiCorp East NorthWestern/PacifiCorp East NF 7/8 BRDY BPAT.NWMT
284 Morgan Stanley Capital Group,
Inc.PacifiCorp East PacifiCorp West NF 7/8 BRDY H500
285 Morgan Stanley Capital Group,
Inc.PacifiCorp East Bonneville Power Administration NF 7/8 BRDY LAGRANDE
286 Morgan Stanley Capital Group,
Inc.PacifiCorp East Avista NF 7/8 BRDY LOLO
287 Morgan Stanley Capital Group,
Inc.PacifiCorp East Avista SFP 7/8 BRDY LOLO
288 Morgan Stanley Capital Group,
Inc.PacifiCorp East Sierra Pacific Power NF 7/8 BRDY M345
289 Morgan Stanley Capital Group,
Inc.PacifiCorp East Sierra Pacific Power SFP 7/8 BRDY M345
290 Morgan Stanley Capital Group,
Inc.PacifiCorp East Bonneville Power Administration NF 7/8 GSHN LAGRANDE
291 Morgan Stanley Capital Group,
Inc.PacifiCorp East NorthWestern/PacifiCorp East NF 7/8 JBSN BPAT.NWMT
292 Morgan Stanley Capital Group,
Inc.PacifiCorp East Bonneville Power Administration NF 7/8 JBSN LAGRANDE
293 Morgan Stanley Capital Group,
Inc.PacifiCorp East Avista NF 7/8 JBSN LOLO
294 Morgan Stanley Capital Group,
Inc.PacifiCorp East PacifiCorp East NF 7/8 JEFF BORA
295 Morgan Stanley Capital Group,
Inc.PacifiCorp East Bonneville Power Administration NF 7/8 JEFF LAGRANDE
296 Morgan Stanley Capital Group,
Inc.PacifiCorp East Avista NF 7/8 JEFF LOLO
297 Morgan Stanley Capital Group,
Inc.PacifiCorp East Sierra Pacific Power NF 7/8 JEFF M345
298 Morgan Stanley Capital Group,
Inc.PacifiCorp East Sierra Pacific Power SFP 7/8 JEFF M345
299 Morgan Stanley Capital Group,
Inc.Bonneville Power Administration PacifiCorp East NF 7/8 LAGRANDE BRDY
300 Morgan Stanley Capital Group,
Inc.Bonneville Power Administration Sierra Pacific Power NF 7/8 LAGRANDE M345
301 Morgan Stanley Capital Group,
Inc.Avista PacifiCorp East NF 7/8 LOLO BORA
302 Morgan Stanley Capital Group,
Inc.Avista PacifiCorp East NF 7/8 LOLO BRDY
303 Morgan Stanley Capital Group,
Inc.Avista Sierra Pacific Power NF 7/8 LOLO M345
304 Morgan Stanley Capital Group,
Inc.Avista Sierra Pacific Power SFP 7/8 LOLO M345
305 Morgan Stanley Capital Group,
Inc.Sierra Pacific Power NorthWestern/PacifiCorp East NF 7/8 M345 AVAT.NWMT
TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456.1) (Including transactions referred to as "wheeling")
Line
No.
Payment By (Company of Public
Authority) (Footnote Affiliation)
(a)
Energy Received From (Company of
Public Authority) (Footnote
Affiliation)
(b)
Energy Delivered To (Company of
Public Authority) (Footnote
Affiliation)
(c)
Statistical
Classification
(d)
Ferc Rate
Schedule of
Tariff Number
(e)
Point of Receipt
(Substation or
Other
Designation)
(f)
Point of
Delivery
(Substation or
Other
Designation)
(g)
FERC FORM NO. 1 (ED. 12-90)
Page 328-330
277 Morgan Stanley Capital Group,Inc.NorthWestern/PacifiCorp East Avista NF 7/8 BPAT.NWMT LOLO278Morgan Stanley Capital Group,Inc.NorthWestern/PacifiCorp East Sierra Pacific Power NF 7/8 BPAT.NWMT M345279Morgan Stanley Capital Group,Inc.NorthWestern/PacifiCorp East Sierra Pacific Power SFP 7/8 BPAT.NWMT M345280Morgan Stanley Capital Group,Inc.PacifiCorp East NorthWestern/PacifiCorp East NF 7/8 BRDY AVAT.NWMT281Morgan Stanley Capital Group,Inc.PacifiCorp East PacifiCorp East NF 7/8 BRDY BORA282Morgan Stanley Capital Group,Inc.PacifiCorp East PacifiCorp East SFP 7/8 BRDY BORA283Morgan Stanley Capital Group,Inc.PacifiCorp East NorthWestern/PacifiCorp East NF 7/8 BRDY BPAT.NWMT284Morgan Stanley Capital Group,Inc.PacifiCorp East PacifiCorp West NF 7/8 BRDY H500285Morgan Stanley Capital Group,Inc.PacifiCorp East Bonneville Power Administration NF 7/8 BRDY LAGRANDE286Morgan Stanley Capital Group,Inc.PacifiCorp East Avista NF 7/8 BRDY LOLO287Morgan Stanley Capital Group,Inc.PacifiCorp East Avista SFP 7/8 BRDY LOLO288Morgan Stanley Capital Group,Inc.PacifiCorp East Sierra Pacific Power NF 7/8 BRDY M345289Morgan Stanley Capital Group,Inc.PacifiCorp East Sierra Pacific Power SFP 7/8 BRDY M345290Morgan Stanley Capital Group,Inc.PacifiCorp East Bonneville Power Administration NF 7/8 GSHN LAGRANDE291Morgan Stanley Capital Group,Inc.PacifiCorp East NorthWestern/PacifiCorp East NF 7/8 JBSN BPAT.NWMT292Morgan Stanley Capital Group,Inc.PacifiCorp East Bonneville Power Administration NF 7/8 JBSN LAGRANDE293Morgan Stanley Capital Group,Inc.PacifiCorp East Avista NF 7/8 JBSN LOLO294Morgan Stanley Capital Group,Inc.PacifiCorp East PacifiCorp East NF 7/8 JEFF BORA295Morgan Stanley Capital Group,Inc.PacifiCorp East Bonneville Power Administration NF 7/8 JEFF LAGRANDE296Morgan Stanley Capital Group,Inc.PacifiCorp East Avista NF 7/8 JEFF LOLO297Morgan Stanley Capital Group,Inc.PacifiCorp East Sierra Pacific Power NF 7/8 JEFF M345298Morgan Stanley Capital Group,Inc.PacifiCorp East Sierra Pacific Power SFP 7/8 JEFF M345299Morgan Stanley Capital Group,Inc.Bonneville Power Administration PacifiCorp East NF 7/8 LAGRANDE BRDY300Morgan Stanley Capital Group,Inc.Bonneville Power Administration Sierra Pacific Power NF 7/8 LAGRANDE M345301Morgan Stanley Capital Group,Inc.Avista PacifiCorp East NF 7/8 LOLO BORA302Morgan Stanley Capital Group,Inc.Avista PacifiCorp East NF 7/8 LOLO BRDY303Morgan Stanley Capital Group,Inc.Avista Sierra Pacific Power NF 7/8 LOLO M345304Morgan Stanley Capital Group,Inc.Avista Sierra Pacific Power SFP 7/8 LOLO M345305Morgan Stanley Capital Group,Inc.Sierra Pacific Power NorthWestern/PacifiCorp East NF 7/8 M345 AVAT.NWMTTRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456.1) (Including transactions referred to as "wheeling")LineNo.Payment By (Company of PublicAuthority) (Footnote Affiliation)(a)Energy Received From (Company ofPublic Authority) (FootnoteAffiliation)(b)Energy Delivered To (Company ofPublic Authority) (FootnoteAffiliation)(c)StatisticalClassification(d)Ferc RateSchedule ofTariff Number(e)Point of Receipt(Substation orOtherDesignation)(f)Point ofDelivery(Substation orOtherDesignation)(g)FERC FORM NO. 1 (ED. 12-90)Page 328-330
306 Morgan Stanley Capital Group,
Inc.Sierra Pacific Power PacifiCorp East NF 7/8 M345 BORA
307 Morgan Stanley Capital Group,
Inc.Sierra Pacific Power PacifiCorp East SFP 7/8 M345 BORA
308 Morgan Stanley Capital Group,
Inc.Sierra Pacific Power NorthWestern/PacifiCorp East NF 7/8 M345 BPAT.NWMT
309 Morgan Stanley Capital Group,
Inc.Sierra Pacific Power PacifiCorp East NF 7/8 M345 BRDY
310 Morgan Stanley Capital Group,
Inc.Sierra Pacific Power PacifiCorp East SFP 7/8 M345 BRDY
311 Morgan Stanley Capital Group,
Inc.Sierra Pacific Power PacifiCorp West NF 7/8 M345 H500
312 Morgan Stanley Capital Group,
Inc.Sierra Pacific Power PacifiCorp East NF 7/8 M345 JEFF
313 Morgan Stanley Capital Group,
Inc.Sierra Pacific Power Bonneville Power Administration NF 7/8 M345 LAGRANDE
314 Morgan Stanley Capital Group,
Inc.Sierra Pacific Power Bonneville Power Administration SFP 7/8 M345 LAGRANDE
315 Morgan Stanley Capital Group,
Inc.Sierra Pacific Power Avista NF 7/8 M345 LOLO
316 Morgan Stanley Capital Group,
Inc.PacifiCorp West PacifiCorp East NF 7/8 SMLK BORA
317 Morgan Stanley Capital Group,
Inc.PacifiCorp West Sierra Pacific Power NF 7/8 SMLK M345
318 Morgan Stanley Capital Group,
Inc.Idaho Power Company PacifiCorp East NF 7/8 WALLAWALLA BRDY
319 PacifiCorp PacifiCorp East NorthWestern/PacifiCorp East NF 7/8 ANTE MLCK
320 PacifiCorp PacifiCorp East PacifiCorp East NF 7/8 BORA GSHN
321 PacifiCorp PacifiCorp East PacifiCorp East SFP 7/8 BORA GSHN
322 PacifiCorp PacifiCorp East Avista NF 7/8 BORA LOLO
323 PacifiCorp PacifiCorp East Avista SFP 7/8 BORA LOLO
324 PacifiCorp PacifiCorp East Sierra Pacific Power NF 7/8 BORA M345
325 PacifiCorp PacifiCorp East PacifiCorp East NF 7/8 BRDY BORA
326 PacifiCorp PacifiCorp East PacifiCorp East NF 7/8 BRDY BRDY
327 PacifiCorp PacifiCorp East Bonneville Power Administration NF 7/8 BRDY LAGRANDE
328 PacifiCorp PacifiCorp East Idaho Power Company NF 7/8 JEFF BGSY
329 PacifiCorp PacifiCorp East Idaho Power Company SFP 7/8 JEFF BGSY
330 PacifiCorp Bonneville Power Administration PacifiCorp East NF 7/8 LAGRANDE BORA
331 PacifiCorp Bonneville Power Administration PacifiCorp East NF 7/8 LAGRANDE BRDY
332 PacifiCorp PacifiCorp West PacifiCorp East NF 7/8 SMLK BRDY
333 PacifiCorp Idaho Power Company PacifiCorp East NF 7/8 WALLAWALLA BORA
334 Phillips 66 Energy Trading LLC PacifiCorp East Avista SFP 7/8 BORA LOLO
335 Phillips 66 Energy Trading LLC NorthWestern/PacifiCorp East PacifiCorp East SFP 7/8 BPAT.NWMT BRDY
336 Phillips 66 Energy Trading LLC PacifiCorp East NorthWestern/PacifiCorp East SFP 7/8 BRDY AVAT.NWMT
337 Phillips 66 Energy Trading LLC PacifiCorp East PacifiCorp West SFP 7/8 BRDY HURR
338 Phillips 66 Energy Trading LLC PacifiCorp East PacifiCorp East NF 7/8 BRDY JBSN
339 Phillips 66 Energy Trading LLC PacifiCorp East Bonneville Power Administration NF 7/8 BRDY LAGRANDE
340 Phillips 66 Energy Trading LLC PacifiCorp East Bonneville Power Administration SFP 7/8 BRDY LAGRANDE
341 Phillips 66 Energy Trading LLC PacifiCorp East Avista NF 7/8 BRDY LOLO
342 Phillips 66 Energy Trading LLC PacifiCorp East Avista SFP 7/8 BRDY LOLO
TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456.1) (Including transactions referred to as "wheeling")
Line
No.
Payment By (Company of Public
Authority) (Footnote Affiliation)
(a)
Energy Received From (Company of
Public Authority) (Footnote
Affiliation)
(b)
Energy Delivered To (Company of
Public Authority) (Footnote
Affiliation)
(c)
Statistical
Classification
(d)
Ferc Rate
Schedule of
Tariff Number
(e)
Point of Receipt
(Substation or
Other
Designation)
(f)
Point of
Delivery
(Substation or
Other
Designation)
(g)
FERC FORM NO. 1 (ED. 12-90)
Page 328-330
306 Morgan Stanley Capital Group,Inc.Sierra Pacific Power PacifiCorp East NF 7/8 M345 BORA307Morgan Stanley Capital Group,Inc.Sierra Pacific Power PacifiCorp East SFP 7/8 M345 BORA308Morgan Stanley Capital Group,Inc.Sierra Pacific Power NorthWestern/PacifiCorp East NF 7/8 M345 BPAT.NWMT309Morgan Stanley Capital Group,Inc.Sierra Pacific Power PacifiCorp East NF 7/8 M345 BRDY310Morgan Stanley Capital Group,Inc.Sierra Pacific Power PacifiCorp East SFP 7/8 M345 BRDY311Morgan Stanley Capital Group,Inc.Sierra Pacific Power PacifiCorp West NF 7/8 M345 H500312Morgan Stanley Capital Group,Inc.Sierra Pacific Power PacifiCorp East NF 7/8 M345 JEFF313Morgan Stanley Capital Group,Inc.Sierra Pacific Power Bonneville Power Administration NF 7/8 M345 LAGRANDE314Morgan Stanley Capital Group,Inc.Sierra Pacific Power Bonneville Power Administration SFP 7/8 M345 LAGRANDE315Morgan Stanley Capital Group,Inc.Sierra Pacific Power Avista NF 7/8 M345 LOLO316Morgan Stanley Capital Group,Inc.PacifiCorp West PacifiCorp East NF 7/8 SMLK BORA317Morgan Stanley Capital Group,Inc.PacifiCorp West Sierra Pacific Power NF 7/8 SMLK M345318Morgan Stanley Capital Group,Inc.Idaho Power Company PacifiCorp East NF 7/8 WALLAWALLA BRDY319PacifiCorpPacifiCorp East NorthWestern/PacifiCorp East NF 7/8 ANTE MLCK320PacifiCorpPacifiCorp East PacifiCorp East NF 7/8 BORA GSHN321PacifiCorpPacifiCorp East PacifiCorp East SFP 7/8 BORA GSHN322PacifiCorpPacifiCorp East Avista NF 7/8 BORA LOLO323PacifiCorpPacifiCorp East Avista SFP 7/8 BORA LOLO324PacifiCorpPacifiCorp East Sierra Pacific Power NF 7/8 BORA M345325PacifiCorpPacifiCorp East PacifiCorp East NF 7/8 BRDY BORA326PacifiCorpPacifiCorp East PacifiCorp East NF 7/8 BRDY BRDY327PacifiCorpPacifiCorp East Bonneville Power Administration NF 7/8 BRDY LAGRANDE328PacifiCorpPacifiCorp East Idaho Power Company NF 7/8 JEFF BGSY329PacifiCorpPacifiCorp East Idaho Power Company SFP 7/8 JEFF BGSY330PacifiCorpBonneville Power Administration PacifiCorp East NF 7/8 LAGRANDE BORA331PacifiCorpBonneville Power Administration PacifiCorp East NF 7/8 LAGRANDE BRDY332PacifiCorpPacifiCorp West PacifiCorp East NF 7/8 SMLK BRDY333PacifiCorpIdaho Power Company PacifiCorp East NF 7/8 WALLAWALLA BORA334Phillips 66 Energy Trading LLC PacifiCorp East Avista SFP 7/8 BORA LOLO335Phillips 66 Energy Trading LLC NorthWestern/PacifiCorp East PacifiCorp East SFP 7/8 BPAT.NWMT BRDY336Phillips 66 Energy Trading LLC PacifiCorp East NorthWestern/PacifiCorp East SFP 7/8 BRDY AVAT.NWMT337Phillips 66 Energy Trading LLC PacifiCorp East PacifiCorp West SFP 7/8 BRDY HURR338Phillips 66 Energy Trading LLC PacifiCorp East PacifiCorp East NF 7/8 BRDY JBSN339Phillips 66 Energy Trading LLC PacifiCorp East Bonneville Power Administration NF 7/8 BRDY LAGRANDE340Phillips 66 Energy Trading LLC PacifiCorp East Bonneville Power Administration SFP 7/8 BRDY LAGRANDE341Phillips 66 Energy Trading LLC PacifiCorp East Avista NF 7/8 BRDY LOLO342Phillips 66 Energy Trading LLC PacifiCorp East Avista SFP 7/8 BRDY LOLOTRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456.1) (Including transactions referred to as "wheeling")LineNo.Payment By (Company of PublicAuthority) (Footnote Affiliation)(a)Energy Received From (Company ofPublic Authority) (FootnoteAffiliation)(b)Energy Delivered To (Company ofPublic Authority) (FootnoteAffiliation)(c)StatisticalClassification(d)Ferc RateSchedule ofTariff Number(e)Point of Receipt(Substation orOtherDesignation)(f)Point ofDelivery(Substation orOtherDesignation)(g)FERC FORM NO. 1 (ED. 12-90)Page 328-330
343 Phillips 66 Energy Trading LLC PacifiCorp East NorthWestern/PacifiCorp East SFP 7/8 JBSN AVAT.NWMT
344 Phillips 66 Energy Trading LLC PacifiCorp East NorthWestern/PacifiCorp East SFP 7/8 JBSN BPAT.NWMT
345 Phillips 66 Energy Trading LLC PacifiCorp East PacifiCorp East NF 7/8 JBSN BRDY
346 Phillips 66 Energy Trading LLC PacifiCorp East PacifiCorp East SFP 7/8 JBSN BRDY
347 Phillips 66 Energy Trading LLC PacifiCorp East PacifiCorp West SFP 7/8 JBSN HURR
348 Phillips 66 Energy Trading LLC PacifiCorp East Avista SFP 7/8 JBSN LOLO
349 Phillips 66 Energy Trading LLC PacifiCorp East NorthWestern/PacifiCorp East SFP 7/8 JBSN MLCK
350 Phillips 66 Energy Trading LLC Bonneville Power Administration PacifiCorp East NF 7/8 LAGRANDE BRDY
351 Phillips 66 Energy Trading LLC Avista PacifiCorp East SFP 7/8 LOLO BRDY
352 Phillips 66 Energy Trading LLC Sierra Pacific Power Avista SFP 7/8 M345 LOLO
353 Phillips 66 Energy Trading LLC Idaho Power Company PacifiCorp East NF 7/8 WALLAWALLA BRDY
354 Portland General Electric PacifiCorp East Bonneville Power Administration NF 7/8 BORA LAGRANDE
355 Portland General Electric NorthWestern/PacifiCorp East PacifiCorp East NF 7/8 BPAT.NWMT BRDY
356 Portland General Electric NorthWestern/PacifiCorp East Bonneville Power Administration NF 7/8 BPAT.NWMT LAGRANDE
357 Portland General Electric NorthWestern/PacifiCorp East Sierra Pacific Power NF 7/8 BPAT.NWMT M345
358 Portland General Electric PacifiCorp East PacifiCorp East NF 7/8 BRDY BORA
359 Portland General Electric PacifiCorp East NorthWestern/PacifiCorp East NF 7/8 BRDY BPAT.NWMT
360 Portland General Electric PacifiCorp East Bonneville Power Administration NF 7/8 BRDY LAGRANDE
361 Portland General Electric PacifiCorp East Sierra Pacific Power NF 7/8 BRDY M345
362 Portland General Electric PacifiCorp East NorthWestern/PacifiCorp East NF 7/8 JBSN BPAT.NWMT
363 Portland General Electric PacifiCorp East PacifiCorp West NF 7/8 JBSN HURR
364 Portland General Electric PacifiCorp East Bonneville Power Administration NF 7/8 JBSN LAGRANDE
365 Portland General Electric PacifiCorp East Bonneville Power Administration NF 7/8 JEFF LAGRANDE
366 Portland General Electric PacifiCorp East Avista NF 7/8 JEFF LOLO
367 Portland General Electric PacifiCorp East Sierra Pacific Power NF 7/8 JEFF M345
368 Portland General Electric Bonneville Power Administration PacifiCorp East NF 7/8 LAGRANDE BORA
369 Portland General Electric Bonneville Power Administration NorthWestern/PacifiCorp East NF 7/8 LAGRANDE BPAT.NWMT
370 Portland General Electric Bonneville Power Administration Sierra Pacific Power NF 7/8 LAGRANDE M345
371 Portland General Electric Avista Sierra Pacific Power NF 7/8 LOLO M345
372 Portland General Electric Sierra Pacific Power NorthWestern/PacifiCorp East NF 7/8 M345 BPAT.NWMT
373 Portland General Electric Sierra Pacific Power PacifiCorp East NF 7/8 M345 BRDY
374 Portland General Electric Sierra Pacific Power PacifiCorp West NF 7/8 M345 H500
375 Portland General Electric Sierra Pacific Power PacifiCorp West NF 7/8 M345 HURR
376 Portland General Electric Sierra Pacific Power Bonneville Power Administration NF 7/8 M345 LAGRANDE
377 Portland General Electric Sierra Pacific Power Avista NF 7/8 M345 LOLO
378 Portland General Electric NorthWestern/PacifiCorp East PacifiCorp East NF 7/8 MLCK BRDY
379 Portland General Electric PacifiCorp West PacifiCorp East NF 7/8 SMLK BORA
380 Powerex Corp.NorthWestern/PacifiCorp East PacifiCorp East NF 7/8 AVAT.NWMT BORA
381 Powerex Corp.NorthWestern/PacifiCorp East PacifiCorp East NF 7/8 AVAT.NWMT BRDY
382 Powerex Corp.NorthWestern/PacifiCorp East PacifiCorp East NF 7/8 AVAT.NWMT GSHN
383 Powerex Corp.NorthWestern/PacifiCorp East PacifiCorp West NF 7/8 AVAT.NWMT H500
384 Powerex Corp.NorthWestern/PacifiCorp East Bonneville Power Administration NF 7/8 AVAT.NWMT LAGRANDE
385 Powerex Corp.Idaho Power Company PacifiCorp East NF 7/8 BGSY JBSN
TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456.1) (Including transactions referred to as "wheeling")
Line
No.
Payment By (Company of Public
Authority) (Footnote Affiliation)
(a)
Energy Received From (Company of
Public Authority) (Footnote
Affiliation)
(b)
Energy Delivered To (Company of
Public Authority) (Footnote
Affiliation)
(c)
Statistical
Classification
(d)
Ferc Rate
Schedule of
Tariff Number
(e)
Point of Receipt
(Substation or
Other
Designation)
(f)
Point of
Delivery
(Substation or
Other
Designation)
(g)
FERC FORM NO. 1 (ED. 12-90)
Page 328-330
343 Phillips 66 Energy Trading LLC PacifiCorp East NorthWestern/PacifiCorp East SFP 7/8 JBSN AVAT.NWMT344Phillips 66 Energy Trading LLC PacifiCorp East NorthWestern/PacifiCorp East SFP 7/8 JBSN BPAT.NWMT345Phillips 66 Energy Trading LLC PacifiCorp East PacifiCorp East NF 7/8 JBSN BRDY346Phillips 66 Energy Trading LLC PacifiCorp East PacifiCorp East SFP 7/8 JBSN BRDY347Phillips 66 Energy Trading LLC PacifiCorp East PacifiCorp West SFP 7/8 JBSN HURR348Phillips 66 Energy Trading LLC PacifiCorp East Avista SFP 7/8 JBSN LOLO349Phillips 66 Energy Trading LLC PacifiCorp East NorthWestern/PacifiCorp East SFP 7/8 JBSN MLCK350Phillips 66 Energy Trading LLC Bonneville Power Administration PacifiCorp East NF 7/8 LAGRANDE BRDY351Phillips 66 Energy Trading LLC Avista PacifiCorp East SFP 7/8 LOLO BRDY352Phillips 66 Energy Trading LLC Sierra Pacific Power Avista SFP 7/8 M345 LOLO353Phillips 66 Energy Trading LLC Idaho Power Company PacifiCorp East NF 7/8 WALLAWALLA BRDY354Portland General Electric PacifiCorp East Bonneville Power Administration NF 7/8 BORA LAGRANDE355Portland General Electric NorthWestern/PacifiCorp East PacifiCorp East NF 7/8 BPAT.NWMT BRDY356Portland General Electric NorthWestern/PacifiCorp East Bonneville Power Administration NF 7/8 BPAT.NWMT LAGRANDE357Portland General Electric NorthWestern/PacifiCorp East Sierra Pacific Power NF 7/8 BPAT.NWMT M345358Portland General Electric PacifiCorp East PacifiCorp East NF 7/8 BRDY BORA359Portland General Electric PacifiCorp East NorthWestern/PacifiCorp East NF 7/8 BRDY BPAT.NWMT360Portland General Electric PacifiCorp East Bonneville Power Administration NF 7/8 BRDY LAGRANDE361Portland General Electric PacifiCorp East Sierra Pacific Power NF 7/8 BRDY M345362Portland General Electric PacifiCorp East NorthWestern/PacifiCorp East NF 7/8 JBSN BPAT.NWMT363Portland General Electric PacifiCorp East PacifiCorp West NF 7/8 JBSN HURR364Portland General Electric PacifiCorp East Bonneville Power Administration NF 7/8 JBSN LAGRANDE365Portland General Electric PacifiCorp East Bonneville Power Administration NF 7/8 JEFF LAGRANDE366Portland General Electric PacifiCorp East Avista NF 7/8 JEFF LOLO367Portland General Electric PacifiCorp East Sierra Pacific Power NF 7/8 JEFF M345368Portland General Electric Bonneville Power Administration PacifiCorp East NF 7/8 LAGRANDE BORA369Portland General Electric Bonneville Power Administration NorthWestern/PacifiCorp East NF 7/8 LAGRANDE BPAT.NWMT370Portland General Electric Bonneville Power Administration Sierra Pacific Power NF 7/8 LAGRANDE M345371Portland General Electric Avista Sierra Pacific Power NF 7/8 LOLO M345372Portland General Electric Sierra Pacific Power NorthWestern/PacifiCorp East NF 7/8 M345 BPAT.NWMT373Portland General Electric Sierra Pacific Power PacifiCorp East NF 7/8 M345 BRDY374Portland General Electric Sierra Pacific Power PacifiCorp West NF 7/8 M345 H500375Portland General Electric Sierra Pacific Power PacifiCorp West NF 7/8 M345 HURR376Portland General Electric Sierra Pacific Power Bonneville Power Administration NF 7/8 M345 LAGRANDE377Portland General Electric Sierra Pacific Power Avista NF 7/8 M345 LOLO378Portland General Electric NorthWestern/PacifiCorp East PacifiCorp East NF 7/8 MLCK BRDY379Portland General Electric PacifiCorp West PacifiCorp East NF 7/8 SMLK BORA380Powerex Corp.NorthWestern/PacifiCorp East PacifiCorp East NF 7/8 AVAT.NWMT BORA381Powerex Corp.NorthWestern/PacifiCorp East PacifiCorp East NF 7/8 AVAT.NWMT BRDY382Powerex Corp.NorthWestern/PacifiCorp East PacifiCorp East NF 7/8 AVAT.NWMT GSHN383Powerex Corp.NorthWestern/PacifiCorp East PacifiCorp West NF 7/8 AVAT.NWMT H500384Powerex Corp.NorthWestern/PacifiCorp East Bonneville Power Administration NF 7/8 AVAT.NWMT LAGRANDE385Powerex Corp.Idaho Power Company PacifiCorp East NF 7/8 BGSY JBSNTRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456.1) (Including transactions referred to as "wheeling")LineNo.Payment By (Company of PublicAuthority) (Footnote Affiliation)(a)Energy Received From (Company ofPublic Authority) (FootnoteAffiliation)(b)Energy Delivered To (Company ofPublic Authority) (FootnoteAffiliation)(c)StatisticalClassification(d)Ferc RateSchedule ofTariff Number(e)Point of Receipt(Substation orOtherDesignation)(f)Point ofDelivery(Substation orOtherDesignation)(g)FERC FORM NO. 1 (ED. 12-90)Page 328-330
386 Powerex Corp.Idaho Power Company PacifiCorp East NF 7/8 BGSY JEFF
387 Powerex Corp.Idaho Power Company PacifiCorp East SFP 7/8 BGSY JEFF
388 Powerex Corp.PacifiCorp East PacifiCorp East NF 7/8 BORA ANTE
389 Powerex Corp.PacifiCorp East PacifiCorp East SFP 7/8 BORA ANTE
390 Powerex Corp.PacifiCorp East NorthWestern/PacifiCorp East NF 7/8 BORA AVAT.NWMT
391 Powerex Corp.PacifiCorp East NorthWestern/PacifiCorp East NF 7/8 BORA BPAT.NWMT
392 Powerex Corp.PacifiCorp East NorthWestern/PacifiCorp East SFP 7/8 BORA BPAT.NWMT
393 Powerex Corp.PacifiCorp East PacifiCorp East NF 7/8 BORA BRDY
394 Powerex Corp.PacifiCorp East PacifiCorp East NF 7/8 BORA GSHN
395 Powerex Corp.PacifiCorp East PacifiCorp West NF 7/8 BORA H500
396 Powerex Corp.PacifiCorp East PacifiCorp West SFP 7/8 BORA H500
397 Powerex Corp.PacifiCorp East PacifiCorp West NF 7/8 BORA HURR
398 Powerex Corp.PacifiCorp East PacifiCorp West SFP 7/8 BORA HURR
399 Powerex Corp.PacifiCorp East Bonneville Power Administration NF 7/8 BORA LAGRANDE
400 Powerex Corp.PacifiCorp East Bonneville Power Administration SFP 7/8 BORA LAGRANDE
401 Powerex Corp.PacifiCorp East Avista NF 7/8 BORA LOLO
402 Powerex Corp.PacifiCorp East Avista SFP 7/8 BORA LOLO
403 Powerex Corp.PacifiCorp East Sierra Pacific Power NF 7/8 BORA M345
404 Powerex Corp.NorthWestern/PacifiCorp East PacifiCorp East NF 7/8 BPAT.NWMT BORA
405 Powerex Corp.NorthWestern/PacifiCorp East PacifiCorp East SFP 7/8 BPAT.NWMT BORA
406 Powerex Corp.NorthWestern/PacifiCorp East PacifiCorp West NF 7/8 BPAT.NWMT H500
407 Powerex Corp.NorthWestern/PacifiCorp East PacifiCorp West NF 7/8 BPAT.NWMT HURR
408 Powerex Corp.NorthWestern/PacifiCorp East Bonneville Power Administration NF 7/8 BPAT.NWMT LAGRANDE
409 Powerex Corp.NorthWestern/PacifiCorp East Avista NF 7/8 BPAT.NWMT LOLO
410 Powerex Corp.NorthWestern/PacifiCorp East Sierra Pacific Power NF 7/8 BPAT.NWMT M345
411 Powerex Corp.NorthWestern/PacifiCorp East Sierra Pacific Power SFP 7/8 BPAT.NWMT M345
412 Powerex Corp.PacifiCorp East NorthWestern/PacifiCorp East NF 7/8 BRDY AVAT.NWMT
413 Powerex Corp.PacifiCorp East PacifiCorp East NF 7/8 BRDY BORA
414 Powerex Corp.PacifiCorp East NorthWestern/PacifiCorp East NF 7/8 BRDY BPAT.NWMT
415 Powerex Corp.PacifiCorp East PacifiCorp West NF 7/8 BRDY H500
416 Powerex Corp.PacifiCorp East PacifiCorp West NF 7/8 BRDY HURR
417 Powerex Corp.PacifiCorp East PacifiCorp West SFP 7/8 BRDY HURR
418 Powerex Corp.PacifiCorp East Bonneville Power Administration NF 7/8 BRDY LAGRANDE
419 Powerex Corp.PacifiCorp East Bonneville Power Administration SFP 7/8 BRDY LAGRANDE
420 Powerex Corp.PacifiCorp East Avista NF 7/8 BRDY LOLO
421 Powerex Corp.PacifiCorp East Avista SFP 7/8 BRDY LOLO
422 Powerex Corp.PacifiCorp East Sierra Pacific Power NF 7/8 BRDY M345
423 Powerex Corp.PacifiCorp East PacifiCorp East NF 7/8 GSHN BORA
424 Powerex Corp.PacifiCorp East PacifiCorp East SFP 7/8 GSHN BORA
425 Powerex Corp.PacifiCorp East NorthWestern/PacifiCorp East NF 7/8 GSHN BPAT.NWMT
426 Powerex Corp.PacifiCorp East NorthWestern/PacifiCorp East SFP 7/8 GSHN BPAT.NWMT
427 Powerex Corp.PacifiCorp East PacifiCorp East NF 7/8 GSHN BRDY
428 Powerex Corp.PacifiCorp East PacifiCorp East SFP 7/8 GSHN BRDY
TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456.1) (Including transactions referred to as "wheeling")
Line
No.
Payment By (Company of Public
Authority) (Footnote Affiliation)
(a)
Energy Received From (Company of
Public Authority) (Footnote
Affiliation)
(b)
Energy Delivered To (Company of
Public Authority) (Footnote
Affiliation)
(c)
Statistical
Classification
(d)
Ferc Rate
Schedule of
Tariff Number
(e)
Point of Receipt
(Substation or
Other
Designation)
(f)
Point of
Delivery
(Substation or
Other
Designation)
(g)
FERC FORM NO. 1 (ED. 12-90)
Page 328-330
386 Powerex Corp.Idaho Power Company PacifiCorp East NF 7/8 BGSY JEFF387Powerex Corp.Idaho Power Company PacifiCorp East SFP 7/8 BGSY JEFF388Powerex Corp.PacifiCorp East PacifiCorp East NF 7/8 BORA ANTE389Powerex Corp.PacifiCorp East PacifiCorp East SFP 7/8 BORA ANTE390Powerex Corp.PacifiCorp East NorthWestern/PacifiCorp East NF 7/8 BORA AVAT.NWMT391Powerex Corp.PacifiCorp East NorthWestern/PacifiCorp East NF 7/8 BORA BPAT.NWMT392Powerex Corp.PacifiCorp East NorthWestern/PacifiCorp East SFP 7/8 BORA BPAT.NWMT393Powerex Corp.PacifiCorp East PacifiCorp East NF 7/8 BORA BRDY394Powerex Corp.PacifiCorp East PacifiCorp East NF 7/8 BORA GSHN395Powerex Corp.PacifiCorp East PacifiCorp West NF 7/8 BORA H500396Powerex Corp.PacifiCorp East PacifiCorp West SFP 7/8 BORA H500397Powerex Corp.PacifiCorp East PacifiCorp West NF 7/8 BORA HURR398Powerex Corp.PacifiCorp East PacifiCorp West SFP 7/8 BORA HURR399Powerex Corp.PacifiCorp East Bonneville Power Administration NF 7/8 BORA LAGRANDE400Powerex Corp.PacifiCorp East Bonneville Power Administration SFP 7/8 BORA LAGRANDE401Powerex Corp.PacifiCorp East Avista NF 7/8 BORA LOLO402Powerex Corp.PacifiCorp East Avista SFP 7/8 BORA LOLO403Powerex Corp.PacifiCorp East Sierra Pacific Power NF 7/8 BORA M345404Powerex Corp.NorthWestern/PacifiCorp East PacifiCorp East NF 7/8 BPAT.NWMT BORA405Powerex Corp.NorthWestern/PacifiCorp East PacifiCorp East SFP 7/8 BPAT.NWMT BORA406Powerex Corp.NorthWestern/PacifiCorp East PacifiCorp West NF 7/8 BPAT.NWMT H500407Powerex Corp.NorthWestern/PacifiCorp East PacifiCorp West NF 7/8 BPAT.NWMT HURR408Powerex Corp.NorthWestern/PacifiCorp East Bonneville Power Administration NF 7/8 BPAT.NWMT LAGRANDE409Powerex Corp.NorthWestern/PacifiCorp East Avista NF 7/8 BPAT.NWMT LOLO410Powerex Corp.NorthWestern/PacifiCorp East Sierra Pacific Power NF 7/8 BPAT.NWMT M345411Powerex Corp.NorthWestern/PacifiCorp East Sierra Pacific Power SFP 7/8 BPAT.NWMT M345412Powerex Corp.PacifiCorp East NorthWestern/PacifiCorp East NF 7/8 BRDY AVAT.NWMT413Powerex Corp.PacifiCorp East PacifiCorp East NF 7/8 BRDY BORA414Powerex Corp.PacifiCorp East NorthWestern/PacifiCorp East NF 7/8 BRDY BPAT.NWMT415Powerex Corp.PacifiCorp East PacifiCorp West NF 7/8 BRDY H500416Powerex Corp.PacifiCorp East PacifiCorp West NF 7/8 BRDY HURR417Powerex Corp.PacifiCorp East PacifiCorp West SFP 7/8 BRDY HURR418Powerex Corp.PacifiCorp East Bonneville Power Administration NF 7/8 BRDY LAGRANDE419Powerex Corp.PacifiCorp East Bonneville Power Administration SFP 7/8 BRDY LAGRANDE420Powerex Corp.PacifiCorp East Avista NF 7/8 BRDY LOLO421Powerex Corp.PacifiCorp East Avista SFP 7/8 BRDY LOLO422Powerex Corp.PacifiCorp East Sierra Pacific Power NF 7/8 BRDY M345423Powerex Corp.PacifiCorp East PacifiCorp East NF 7/8 GSHN BORA424Powerex Corp.PacifiCorp East PacifiCorp East SFP 7/8 GSHN BORA425Powerex Corp.PacifiCorp East NorthWestern/PacifiCorp East NF 7/8 GSHN BPAT.NWMT426Powerex Corp.PacifiCorp East NorthWestern/PacifiCorp East SFP 7/8 GSHN BPAT.NWMT427Powerex Corp.PacifiCorp East PacifiCorp East NF 7/8 GSHN BRDY428Powerex Corp.PacifiCorp East PacifiCorp East SFP 7/8 GSHN BRDYTRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456.1) (Including transactions referred to as "wheeling")LineNo.Payment By (Company of PublicAuthority) (Footnote Affiliation)(a)Energy Received From (Company ofPublic Authority) (FootnoteAffiliation)(b)Energy Delivered To (Company ofPublic Authority) (FootnoteAffiliation)(c)StatisticalClassification(d)Ferc RateSchedule ofTariff Number(e)Point of Receipt(Substation orOtherDesignation)(f)Point ofDelivery(Substation orOtherDesignation)(g)FERC FORM NO. 1 (ED. 12-90)Page 328-330
429 Powerex Corp.PacifiCorp East PacifiCorp West NF 7/8 GSHN HURR
430 Powerex Corp.PacifiCorp East Bonneville Power Administration NF 7/8 GSHN LAGRANDE
431 Powerex Corp.PacifiCorp East Bonneville Power Administration SFP 7/8 GSHN LAGRANDE
432 Powerex Corp.PacifiCorp East Avista NF 7/8 GSHN LOLO
433 Powerex Corp.PacifiCorp East Avista SFP 7/8 GSHN LOLO
434 Powerex Corp.PacifiCorp East Sierra Pacific Power NF 7/8 GSHN M345
435 Powerex Corp.PacifiCorp West PacifiCorp East NF 7/8 HURR BORA
436 Powerex Corp.PacifiCorp West PacifiCorp East NF 7/8 HURR BRDY
437 Powerex Corp.PacifiCorp West PacifiCorp West NF 7/8 HURR H500
438 Powerex Corp.PacifiCorp West Bonneville Power Administration NF 7/8 HURR LAGRANDE
439 Powerex Corp.PacifiCorp West Sierra Pacific Power NF 7/8 HURR M345
440 Powerex Corp.PacifiCorp East PacifiCorp East NF 7/8 JBSN BORA
441 Powerex Corp.PacifiCorp East NorthWestern/PacifiCorp East NF 7/8 JBSN BPAT.NWMT
442 Powerex Corp.PacifiCorp East PacifiCorp East NF 7/8 JBSN BRDY
443 Powerex Corp.PacifiCorp East PacifiCorp East NF 7/8 JBSN GSHN
444 Powerex Corp.PacifiCorp East PacifiCorp West NF 7/8 JBSN HURR
445 Powerex Corp.PacifiCorp East PacifiCorp West SFP 7/8 JBSN HURR
446 Powerex Corp.PacifiCorp East Bonneville Power Administration NF 7/8 JBSN LAGRANDE
447 Powerex Corp.PacifiCorp East Avista NF 7/8 JBSN LOLO
448 Powerex Corp.PacifiCorp East Avista SFP 7/8 JBSN LOLO
449 Powerex Corp.PacifiCorp East Sierra Pacific Power NF 7/8 JBSN M345
450 Powerex Corp.PacifiCorp East PacifiCorp East NF 7/8 JEFF BRDY
451 Powerex Corp.PacifiCorp East PacifiCorp West NF 7/8 JEFF H500
452 Powerex Corp.PacifiCorp East Bonneville Power Administration NF 7/8 JEFF LAGRANDE
453 Powerex Corp.PacifiCorp East Avista NF 7/8 JEFF LOLO
454 Powerex Corp.PacifiCorp East Avista SFP 7/8 JEFF LOLO
455 Powerex Corp.PacifiCorp East Sierra Pacific Power NF 7/8 JEFF M345
456 Powerex Corp.PacifiCorp East Sierra Pacific Power SFP 7/8 JEFF M345
457 Powerex Corp.Bonneville Power Administration PacifiCorp East NF 7/8 LAGRANDE BORA
458 Powerex Corp.Bonneville Power Administration NorthWestern/PacifiCorp East NF 7/8 LAGRANDE BPAT.NWMT
459 Powerex Corp.Bonneville Power Administration PacifiCorp East NF 7/8 LAGRANDE BRDY
460 Powerex Corp.Bonneville Power Administration PacifiCorp East NF 7/8 LAGRANDE JBSN
461 Powerex Corp.Bonneville Power Administration Avista NF 7/8 LAGRANDE LOLO
462 Powerex Corp.Bonneville Power Administration Sierra Pacific Power NF 7/8 LAGRANDE M345
463 Powerex Corp.Bonneville Power Administration Sierra Pacific Power SFP 7/8 LAGRANDE M345
464 Powerex Corp.Avista PacifiCorp East NF 7/8 LOLO BRDY
465 Powerex Corp.Avista PacifiCorp East SFP 7/8 LOLO BRDY
466 Powerex Corp.Avista PacifiCorp West NF 7/8 LOLO H500
467 Powerex Corp.Avista PacifiCorp West NF 7/8 LOLO HURR
468 Powerex Corp.Avista Bonneville Power Administration NF 7/8 LOLO LAGRANDE
469 Powerex Corp.Avista Sierra Pacific Power NF 7/8 LOLO M345
470 Powerex Corp.Avista Sierra Pacific Power SFP 7/8 LOLO M345
471 Powerex Corp.Sierra Pacific Power NorthWestern/PacifiCorp East NF 7/8 M345 AVAT.NWMT
TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456.1) (Including transactions referred to as "wheeling")
Line
No.
Payment By (Company of Public
Authority) (Footnote Affiliation)
(a)
Energy Received From (Company of
Public Authority) (Footnote
Affiliation)
(b)
Energy Delivered To (Company of
Public Authority) (Footnote
Affiliation)
(c)
Statistical
Classification
(d)
Ferc Rate
Schedule of
Tariff Number
(e)
Point of Receipt
(Substation or
Other
Designation)
(f)
Point of
Delivery
(Substation or
Other
Designation)
(g)
FERC FORM NO. 1 (ED. 12-90)
Page 328-330
429 Powerex Corp.PacifiCorp East PacifiCorp West NF 7/8 GSHN HURR430Powerex Corp.PacifiCorp East Bonneville Power Administration NF 7/8 GSHN LAGRANDE431Powerex Corp.PacifiCorp East Bonneville Power Administration SFP 7/8 GSHN LAGRANDE432Powerex Corp.PacifiCorp East Avista NF 7/8 GSHN LOLO433Powerex Corp.PacifiCorp East Avista SFP 7/8 GSHN LOLO434Powerex Corp.PacifiCorp East Sierra Pacific Power NF 7/8 GSHN M345435Powerex Corp.PacifiCorp West PacifiCorp East NF 7/8 HURR BORA436Powerex Corp.PacifiCorp West PacifiCorp East NF 7/8 HURR BRDY437Powerex Corp.PacifiCorp West PacifiCorp West NF 7/8 HURR H500438Powerex Corp.PacifiCorp West Bonneville Power Administration NF 7/8 HURR LAGRANDE439Powerex Corp.PacifiCorp West Sierra Pacific Power NF 7/8 HURR M345440Powerex Corp.PacifiCorp East PacifiCorp East NF 7/8 JBSN BORA441Powerex Corp.PacifiCorp East NorthWestern/PacifiCorp East NF 7/8 JBSN BPAT.NWMT442Powerex Corp.PacifiCorp East PacifiCorp East NF 7/8 JBSN BRDY443Powerex Corp.PacifiCorp East PacifiCorp East NF 7/8 JBSN GSHN444Powerex Corp.PacifiCorp East PacifiCorp West NF 7/8 JBSN HURR445Powerex Corp.PacifiCorp East PacifiCorp West SFP 7/8 JBSN HURR446Powerex Corp.PacifiCorp East Bonneville Power Administration NF 7/8 JBSN LAGRANDE447Powerex Corp.PacifiCorp East Avista NF 7/8 JBSN LOLO448Powerex Corp.PacifiCorp East Avista SFP 7/8 JBSN LOLO449Powerex Corp.PacifiCorp East Sierra Pacific Power NF 7/8 JBSN M345450Powerex Corp.PacifiCorp East PacifiCorp East NF 7/8 JEFF BRDY451Powerex Corp.PacifiCorp East PacifiCorp West NF 7/8 JEFF H500452Powerex Corp.PacifiCorp East Bonneville Power Administration NF 7/8 JEFF LAGRANDE453Powerex Corp.PacifiCorp East Avista NF 7/8 JEFF LOLO454Powerex Corp.PacifiCorp East Avista SFP 7/8 JEFF LOLO455Powerex Corp.PacifiCorp East Sierra Pacific Power NF 7/8 JEFF M345456Powerex Corp.PacifiCorp East Sierra Pacific Power SFP 7/8 JEFF M345457Powerex Corp.Bonneville Power Administration PacifiCorp East NF 7/8 LAGRANDE BORA458Powerex Corp.Bonneville Power Administration NorthWestern/PacifiCorp East NF 7/8 LAGRANDE BPAT.NWMT459Powerex Corp.Bonneville Power Administration PacifiCorp East NF 7/8 LAGRANDE BRDY460Powerex Corp.Bonneville Power Administration PacifiCorp East NF 7/8 LAGRANDE JBSN461Powerex Corp.Bonneville Power Administration Avista NF 7/8 LAGRANDE LOLO462Powerex Corp.Bonneville Power Administration Sierra Pacific Power NF 7/8 LAGRANDE M345463Powerex Corp.Bonneville Power Administration Sierra Pacific Power SFP 7/8 LAGRANDE M345464Powerex Corp.Avista PacifiCorp East NF 7/8 LOLO BRDY465Powerex Corp.Avista PacifiCorp East SFP 7/8 LOLO BRDY466Powerex Corp.Avista PacifiCorp West NF 7/8 LOLO H500467Powerex Corp.Avista PacifiCorp West NF 7/8 LOLO HURR468Powerex Corp.Avista Bonneville Power Administration NF 7/8 LOLO LAGRANDE469Powerex Corp.Avista Sierra Pacific Power NF 7/8 LOLO M345470Powerex Corp.Avista Sierra Pacific Power SFP 7/8 LOLO M345471Powerex Corp.Sierra Pacific Power NorthWestern/PacifiCorp East NF 7/8 M345 AVAT.NWMTTRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456.1) (Including transactions referred to as "wheeling")LineNo.Payment By (Company of PublicAuthority) (Footnote Affiliation)(a)Energy Received From (Company ofPublic Authority) (FootnoteAffiliation)(b)Energy Delivered To (Company ofPublic Authority) (FootnoteAffiliation)(c)StatisticalClassification(d)Ferc RateSchedule ofTariff Number(e)Point of Receipt(Substation orOtherDesignation)(f)Point ofDelivery(Substation orOtherDesignation)(g)FERC FORM NO. 1 (ED. 12-90)Page 328-330
472 Powerex Corp.Sierra Pacific Power PacifiCorp East NF 7/8 M345 BORA
473 Powerex Corp.Sierra Pacific Power NorthWestern/PacifiCorp East NF 7/8 M345 BPAT.NWMT
474 Powerex Corp.Sierra Pacific Power PacifiCorp East NF 7/8 M345 BRDY
475 Powerex Corp.Sierra Pacific Power PacifiCorp East SFP 7/8 M345 BRDY
476 Powerex Corp.Sierra Pacific Power PacifiCorp West NF 7/8 M345 HURR
477 Powerex Corp.Sierra Pacific Power Bonneville Power Administration NF 7/8 M345 LAGRANDE
478 Powerex Corp.Sierra Pacific Power Bonneville Power Administration SFP 7/8 M345 LAGRANDE
479 Powerex Corp.Sierra Pacific Power Avista NF 7/8 M345 LOLO
480 Powerex Corp.Sierra Pacific Power Avista SFP 7/8 M345 LOLO
481 Powerex Corp.NorthWestern/PacifiCorp East NorthWestern/PacifiCorp East SFP 7/8 MLCK BPAT.NWMT
482 Powerex Corp.PacifiCorp West PacifiCorp East NF 7/8 SMLK BORA
483 Powerex Corp.PacifiCorp West PacifiCorp East SFP 7/8 SMLK BORA
484 Powerex Corp.PacifiCorp West Sierra Pacific Power NF 7/8 SMLK M345
485 Powerex Corp.PacifiCorp West Sierra Pacific Power SFP 7/8 SMLK M345
486 Powerex Corp.Idaho Power Company PacifiCorp East NF 7/8 WALLAWALLA BORA
487 Powerex Corp.Idaho Power Company PacifiCorp East SFP 7/8 WALLAWALLA BORA
488 Powerex Corp.Idaho Power Company PacifiCorp East NF 7/8 WALLAWALLA BRDY
489 Powerex Corp.Idaho Power Company PacifiCorp East NF 7/8 WALLAWALLA JBSN
490 Powerex Corp.Idaho Power Company Bonneville Power Administration NF 7/8 WALLAWALLA LAGRANDE
491 Powerex Corp.Idaho Power Company Sierra Pacific Power NF 7/8 WALLAWALLA M345
492 Powerex Corp.Idaho Power Company Sierra Pacific Power SFP 7/8 WALLAWALLA M345
493 Prospector Windfarm, LLC NF 11
494 Puget Sound Energy PacifiCorp East Bonneville Power Administration NF 7/8 BRDY LAGRANDE
495 Puget Sound Energy PacifiCorp East Avista NF 7/8 JEFF LOLO
496 Rainbow Energy Marketing
Corporation Idaho Power Company PacifiCorp East NF 7/8 BGSY JEFF
497 Rainbow Energy Marketing
Corporation PacifiCorp East PacifiCorp East NF 7/8 BORA ANTE
498 Rainbow Energy Marketing
Corporation PacifiCorp East NorthWestern/PacifiCorp East NF 7/8 BORA AVAT.NWMT
499 Rainbow Energy Marketing
Corporation PacifiCorp East Bonneville Power Administration NF 7/8 BORA BPASID
500 Rainbow Energy Marketing
Corporation PacifiCorp East NorthWestern/PacifiCorp East NF 7/8 BORA BPAT.NWMT
501 Rainbow Energy Marketing
Corporation PacifiCorp East Bonneville Power Administration NF 7/8 BORA LAGRANDE
502 Rainbow Energy Marketing
Corporation PacifiCorp East Bonneville Power Administration SFP 7/8 BORA LAGRANDE
503 Rainbow Energy Marketing
Corporation PacifiCorp East Avista NF 7/8 BORA LOLO
504 Rainbow Energy Marketing
Corporation PacifiCorp East Avista SFP 7/8 BORA LOLO
505 Rainbow Energy Marketing
Corporation PacifiCorp East Sierra Pacific Power NF 7/8 BORA M345
506 Rainbow Energy Marketing
Corporation PacifiCorp East NorthWestern/PacifiCorp East NF 7/8 BORA MLCK
507 Rainbow Energy Marketing
Corporation NorthWestern/PacifiCorp East Sierra Pacific Power NF 7/8 BPAT.NWMT M345
508 Rainbow Energy Marketing
Corporation PacifiCorp East NorthWestern/PacifiCorp East NF 7/8 BRDY AVAT.NWMT
TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456.1) (Including transactions referred to as "wheeling")
Line
No.
Payment By (Company of Public
Authority) (Footnote Affiliation)
(a)
Energy Received From (Company of
Public Authority) (Footnote
Affiliation)
(b)
Energy Delivered To (Company of
Public Authority) (Footnote
Affiliation)
(c)
Statistical
Classification
(d)
Ferc Rate
Schedule of
Tariff Number
(e)
Point of Receipt
(Substation or
Other
Designation)
(f)
Point of
Delivery
(Substation or
Other
Designation)
(g)
FERC FORM NO. 1 (ED. 12-90)
Page 328-330
472 Powerex Corp.Sierra Pacific Power PacifiCorp East NF 7/8 M345 BORA473Powerex Corp.Sierra Pacific Power NorthWestern/PacifiCorp East NF 7/8 M345 BPAT.NWMT474Powerex Corp.Sierra Pacific Power PacifiCorp East NF 7/8 M345 BRDY475Powerex Corp.Sierra Pacific Power PacifiCorp East SFP 7/8 M345 BRDY476Powerex Corp.Sierra Pacific Power PacifiCorp West NF 7/8 M345 HURR477Powerex Corp.Sierra Pacific Power Bonneville Power Administration NF 7/8 M345 LAGRANDE478Powerex Corp.Sierra Pacific Power Bonneville Power Administration SFP 7/8 M345 LAGRANDE479Powerex Corp.Sierra Pacific Power Avista NF 7/8 M345 LOLO480Powerex Corp.Sierra Pacific Power Avista SFP 7/8 M345 LOLO481Powerex Corp.NorthWestern/PacifiCorp East NorthWestern/PacifiCorp East SFP 7/8 MLCK BPAT.NWMT482Powerex Corp.PacifiCorp West PacifiCorp East NF 7/8 SMLK BORA483Powerex Corp.PacifiCorp West PacifiCorp East SFP 7/8 SMLK BORA484Powerex Corp.PacifiCorp West Sierra Pacific Power NF 7/8 SMLK M345485Powerex Corp.PacifiCorp West Sierra Pacific Power SFP 7/8 SMLK M345486Powerex Corp.Idaho Power Company PacifiCorp East NF 7/8 WALLAWALLA BORA487Powerex Corp.Idaho Power Company PacifiCorp East SFP 7/8 WALLAWALLA BORA488Powerex Corp.Idaho Power Company PacifiCorp East NF 7/8 WALLAWALLA BRDY489Powerex Corp.Idaho Power Company PacifiCorp East NF 7/8 WALLAWALLA JBSN490Powerex Corp.Idaho Power Company Bonneville Power Administration NF 7/8 WALLAWALLA LAGRANDE491Powerex Corp.Idaho Power Company Sierra Pacific Power NF 7/8 WALLAWALLA M345492Powerex Corp.Idaho Power Company Sierra Pacific Power SFP 7/8 WALLAWALLA M345493Prospector Windfarm, LLC NF 11494Puget Sound Energy PacifiCorp East Bonneville Power Administration NF 7/8 BRDY LAGRANDE495Puget Sound Energy PacifiCorp East Avista NF 7/8 JEFF LOLO496Rainbow Energy MarketingCorporation Idaho Power Company PacifiCorp East NF 7/8 BGSY JEFF497Rainbow Energy MarketingCorporation PacifiCorp East PacifiCorp East NF 7/8 BORA ANTE498Rainbow Energy MarketingCorporation PacifiCorp East NorthWestern/PacifiCorp East NF 7/8 BORA AVAT.NWMT499Rainbow Energy MarketingCorporation PacifiCorp East Bonneville Power Administration NF 7/8 BORA BPASID500Rainbow Energy MarketingCorporation PacifiCorp East NorthWestern/PacifiCorp East NF 7/8 BORA BPAT.NWMT501Rainbow Energy MarketingCorporation PacifiCorp East Bonneville Power Administration NF 7/8 BORA LAGRANDE502Rainbow Energy MarketingCorporation PacifiCorp East Bonneville Power Administration SFP 7/8 BORA LAGRANDE503Rainbow Energy MarketingCorporation PacifiCorp East Avista NF 7/8 BORA LOLO504Rainbow Energy MarketingCorporation PacifiCorp East Avista SFP 7/8 BORA LOLO505Rainbow Energy MarketingCorporation PacifiCorp East Sierra Pacific Power NF 7/8 BORA M345506Rainbow Energy MarketingCorporation PacifiCorp East NorthWestern/PacifiCorp East NF 7/8 BORA MLCK507Rainbow Energy MarketingCorporation NorthWestern/PacifiCorp East Sierra Pacific Power NF 7/8 BPAT.NWMT M345508Rainbow Energy MarketingCorporation PacifiCorp East NorthWestern/PacifiCorp East NF 7/8 BRDY AVAT.NWMTTRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456.1) (Including transactions referred to as "wheeling")LineNo.Payment By (Company of PublicAuthority) (Footnote Affiliation)(a)Energy Received From (Company ofPublic Authority) (FootnoteAffiliation)(b)Energy Delivered To (Company ofPublic Authority) (FootnoteAffiliation)(c)StatisticalClassification(d)Ferc RateSchedule ofTariff Number(e)Point of Receipt(Substation orOtherDesignation)(f)Point ofDelivery(Substation orOtherDesignation)(g)FERC FORM NO. 1 (ED. 12-90)Page 328-330
509 Rainbow Energy Marketing
Corporation PacifiCorp East Bonneville Power Administration NF 7/8 BRDY LAGRANDE
510 Rainbow Energy Marketing
Corporation PacifiCorp East Avista NF 7/8 BRDY LOLO
511 Rainbow Energy Marketing
Corporation PacifiCorp East Sierra Pacific Power NF 7/8 BRDY M345
512 Rainbow Energy Marketing
Corporation PacifiCorp East NorthWestern/PacifiCorp East NF 7/8 GSHN AVAT.NWMT
513 Rainbow Energy Marketing
Corporation PacifiCorp East PacifiCorp West NF 7/8 GSHN HURR
514 Rainbow Energy Marketing
Corporation PacifiCorp East Sierra Pacific Power NF 7/8 GSHN M345
515 Rainbow Energy Marketing
Corporation PacifiCorp East Sierra Pacific Power SFP 7/8 GSHN M345
516 Rainbow Energy Marketing
Corporation PacifiCorp East PacifiCorp East NF 7/8 JBSN BORA
517 Rainbow Energy Marketing
Corporation PacifiCorp East NorthWestern/PacifiCorp East NF 7/8 JBSN BPAT.NWMT
518 Rainbow Energy Marketing
Corporation PacifiCorp East PacifiCorp East NF 7/8 JBSN GSHN
519 Rainbow Energy Marketing
Corporation PacifiCorp East PacifiCorp West NF 7/8 JBSN HURR
520 Rainbow Energy Marketing
Corporation PacifiCorp East Bonneville Power Administration NF 7/8 JBSN LAGRANDE
521 Rainbow Energy Marketing
Corporation PacifiCorp East Avista NF 7/8 JBSN LOLO
522 Rainbow Energy Marketing
Corporation PacifiCorp East Sierra Pacific Power NF 7/8 JBSN M345
523 Rainbow Energy Marketing
Corporation PacifiCorp East PacifiCorp West NF 7/8 JBSN POP
524 Rainbow Energy Marketing
Corporation PacifiCorp East Sierra Pacific Power NF 7/8 KPRT M345
525 Rainbow Energy Marketing
Corporation Bonneville Power Administration NorthWestern/PacifiCorp East NF 7/8 LAGRANDE BPAT.NWMT
526 Rainbow Energy Marketing
Corporation Bonneville Power Administration PacifiCorp East NF 7/8 LAGRANDE BRDY
527 Rainbow Energy Marketing
Corporation Bonneville Power Administration PacifiCorp West NF 7/8 LAGRANDE H500
528 Rainbow Energy Marketing
Corporation Bonneville Power Administration Sierra Pacific Power NF 7/8 LAGRANDE M345
529 Rainbow Energy Marketing
Corporation Avista PacifiCorp East NF 7/8 LOLO BORA
530 Rainbow Energy Marketing
Corporation Avista Bonneville Power Administration NF 7/8 LOLO LAGRANDE
531 Rainbow Energy Marketing
Corporation Avista Sierra Pacific Power NF 7/8 LOLO M345
532 Rainbow Energy Marketing
Corporation Sierra Pacific Power PacifiCorp East NF 7/8 M345 BORA
533 Rainbow Energy Marketing
Corporation Sierra Pacific Power NorthWestern/PacifiCorp East NF 7/8 M345 BPAT.NWMT
534 Rainbow Energy Marketing
Corporation Sierra Pacific Power PacifiCorp East NF 7/8 M345 JBSN
535 Rainbow Energy Marketing
Corporation Sierra Pacific Power Bonneville Power Administration NF 7/8 M345 LAGRANDE
536 Rainbow Energy Marketing
Corporation Sierra Pacific Power Bonneville Power Administration SFP 7/8 M345 LAGRANDE
537 Rainbow Energy Marketing
Corporation Sierra Pacific Power Avista NF 7/8 M345 LOLO
TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456.1) (Including transactions referred to as "wheeling")
Line
No.
Payment By (Company of Public
Authority) (Footnote Affiliation)
(a)
Energy Received From (Company of
Public Authority) (Footnote
Affiliation)
(b)
Energy Delivered To (Company of
Public Authority) (Footnote
Affiliation)
(c)
Statistical
Classification
(d)
Ferc Rate
Schedule of
Tariff Number
(e)
Point of Receipt
(Substation or
Other
Designation)
(f)
Point of
Delivery
(Substation or
Other
Designation)
(g)
FERC FORM NO. 1 (ED. 12-90)
Page 328-330
509 Rainbow Energy MarketingCorporation PacifiCorp East Bonneville Power Administration NF 7/8 BRDY LAGRANDE510Rainbow Energy MarketingCorporation PacifiCorp East Avista NF 7/8 BRDY LOLO511Rainbow Energy MarketingCorporation PacifiCorp East Sierra Pacific Power NF 7/8 BRDY M345512Rainbow Energy MarketingCorporation PacifiCorp East NorthWestern/PacifiCorp East NF 7/8 GSHN AVAT.NWMT513Rainbow Energy MarketingCorporation PacifiCorp East PacifiCorp West NF 7/8 GSHN HURR514Rainbow Energy MarketingCorporation PacifiCorp East Sierra Pacific Power NF 7/8 GSHN M345515Rainbow Energy MarketingCorporation PacifiCorp East Sierra Pacific Power SFP 7/8 GSHN M345516Rainbow Energy MarketingCorporation PacifiCorp East PacifiCorp East NF 7/8 JBSN BORA517Rainbow Energy MarketingCorporation PacifiCorp East NorthWestern/PacifiCorp East NF 7/8 JBSN BPAT.NWMT518Rainbow Energy MarketingCorporation PacifiCorp East PacifiCorp East NF 7/8 JBSN GSHN519Rainbow Energy MarketingCorporation PacifiCorp East PacifiCorp West NF 7/8 JBSN HURR520Rainbow Energy MarketingCorporation PacifiCorp East Bonneville Power Administration NF 7/8 JBSN LAGRANDE521Rainbow Energy MarketingCorporation PacifiCorp East Avista NF 7/8 JBSN LOLO522Rainbow Energy MarketingCorporation PacifiCorp East Sierra Pacific Power NF 7/8 JBSN M345523Rainbow Energy MarketingCorporation PacifiCorp East PacifiCorp West NF 7/8 JBSN POP524Rainbow Energy MarketingCorporation PacifiCorp East Sierra Pacific Power NF 7/8 KPRT M345525Rainbow Energy MarketingCorporation Bonneville Power Administration NorthWestern/PacifiCorp East NF 7/8 LAGRANDE BPAT.NWMT526Rainbow Energy MarketingCorporation Bonneville Power Administration PacifiCorp East NF 7/8 LAGRANDE BRDY527Rainbow Energy MarketingCorporation Bonneville Power Administration PacifiCorp West NF 7/8 LAGRANDE H500528Rainbow Energy MarketingCorporation Bonneville Power Administration Sierra Pacific Power NF 7/8 LAGRANDE M345529Rainbow Energy MarketingCorporation Avista PacifiCorp East NF 7/8 LOLO BORA530Rainbow Energy MarketingCorporation Avista Bonneville Power Administration NF 7/8 LOLO LAGRANDE531Rainbow Energy MarketingCorporation Avista Sierra Pacific Power NF 7/8 LOLO M345532Rainbow Energy MarketingCorporation Sierra Pacific Power PacifiCorp East NF 7/8 M345 BORA533Rainbow Energy MarketingCorporation Sierra Pacific Power NorthWestern/PacifiCorp East NF 7/8 M345 BPAT.NWMT534Rainbow Energy MarketingCorporation Sierra Pacific Power PacifiCorp East NF 7/8 M345 JBSN535Rainbow Energy MarketingCorporation Sierra Pacific Power Bonneville Power Administration NF 7/8 M345 LAGRANDE536Rainbow Energy MarketingCorporation Sierra Pacific Power Bonneville Power Administration SFP 7/8 M345 LAGRANDE537Rainbow Energy MarketingCorporation Sierra Pacific Power Avista NF 7/8 M345 LOLOTRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456.1) (Including transactions referred to as "wheeling")LineNo.Payment By (Company of PublicAuthority) (Footnote Affiliation)(a)Energy Received From (Company ofPublic Authority) (FootnoteAffiliation)(b)Energy Delivered To (Company ofPublic Authority) (FootnoteAffiliation)(c)StatisticalClassification(d)Ferc RateSchedule ofTariff Number(e)Point of Receipt(Substation orOtherDesignation)(f)Point ofDelivery(Substation orOtherDesignation)(g)FERC FORM NO. 1 (ED. 12-90)Page 328-330
538 Rainbow Energy Marketing
Corporation Sierra Pacific Power Avista SFP 7/8 M345 LOLO
539 Rainbow Energy Marketing
Corporation PacifiCorp West PacifiCorp East NF 7/8 SMLK BORA
540 Rainbow Energy Marketing
Corporation PacifiCorp West Sierra Pacific Power NF 7/8 SMLK M345
541 Rainbow Energy Marketing
Corporation Idaho Power Company PacifiCorp East NF 7/8 WALLAWALLA BORA
542 Rainbow Energy Marketing
Corporation Idaho Power Company PacifiCorp East NF 7/8 WALLAWALLA GSHN
543 Rainbow Energy Marketing
Corporation Idaho Power Company PacifiCorp East NF 7/8 WALLAWALLA JBSN
544 Rainbow Energy Marketing
Corporation Idaho Power Company Sierra Pacific Power NF 7/8 WALLAWALLA M345
545 Rockland Wind Farm, LLC NF 11
546 Riley Solar I Bonneville Power Administration Bonneville Power Administration NF 7/8 LAGRANDE LAGRANDE
547 Shell Energy North America
(US), L.P.NF 11
548 Shell Energy North America
(US), L.P.PacifiCorp East NorthWestern/PacifiCorp East NF 7/8 BORA BPAT.NWMT
549 Shell Energy North America
(US), L.P.PacifiCorp East PacifiCorp West NF 7/8 BORA H500
550 Shell Energy North America
(US), L.P.PacifiCorp East PacifiCorp West NF 7/8 BORA HURR
551 Shell Energy North America
(US), L.P.PacifiCorp East Bonneville Power Administration NF 7/8 BORA LAGRANDE
552 Shell Energy North America
(US), L.P.PacifiCorp East Avista NF 7/8 BORA LOLO
553 Shell Energy North America
(US), L.P.PacifiCorp East Sierra Pacific Power NF 7/8 BORA M345
554 Shell Energy North America
(US), L.P.NorthWestern/PacifiCorp East PacifiCorp East NF 7/8 BPAT.NWMT BRDY
555 Shell Energy North America
(US), L.P.NorthWestern/PacifiCorp East PacifiCorp West NF 7/8 BPAT.NWMT HURR
556 Shell Energy North America
(US), L.P.NorthWestern/PacifiCorp East Bonneville Power Administration NF 7/8 BPAT.NWMT LAGRANDE
557 Shell Energy North America
(US), L.P.NorthWestern/PacifiCorp East Sierra Pacific Power NF 7/8 BPAT.NWMT M345
558
Shell Energy North America
(US), L.P.PacifiCorp East NorthWestern/PacifiCorp East NF 7/8 BRDY BPAT.NWMT
559 Shell Energy North America
(US), L.P.PacifiCorp East PacifiCorp West NF 7/8 BRDY HURR
560 Shell Energy North America
(US), L.P.PacifiCorp East Bonneville Power Administration NF 7/8 BRDY LAGRANDE
561 Shell Energy North America
(US), L.P.PacifiCorp East Avista NF 7/8 BRDY LOLO
562 Shell Energy North America
(US), L.P.PacifiCorp East Sierra Pacific Power NF 7/8 BRDY M345
563 Shell Energy North America
(US), L.P.PacifiCorp East Sierra Pacific Power SFP 7/8 BRDY M345
564 Shell Energy North America
(US), L.P.PacifiCorp East NorthWestern/PacifiCorp East NF 7/8 GSHN BPAT.NWMT
565 Shell Energy North America
(US), L.P.PacifiCorp East Bonneville Power Administration NF 7/8 GSHN LAGRANDE
566 Shell Energy North America
(US), L.P.PacifiCorp West PacifiCorp East NF 7/8 HURR BORA
TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456.1) (Including transactions referred to as "wheeling")
Line
No.
Payment By (Company of Public
Authority) (Footnote Affiliation)
(a)
Energy Received From (Company of
Public Authority) (Footnote
Affiliation)
(b)
Energy Delivered To (Company of
Public Authority) (Footnote
Affiliation)
(c)
Statistical
Classification
(d)
Ferc Rate
Schedule of
Tariff Number
(e)
Point of Receipt
(Substation or
Other
Designation)
(f)
Point of
Delivery
(Substation or
Other
Designation)
(g)
FERC FORM NO. 1 (ED. 12-90)
Page 328-330
538 Rainbow Energy MarketingCorporation Sierra Pacific Power Avista SFP 7/8 M345 LOLO539Rainbow Energy MarketingCorporation PacifiCorp West PacifiCorp East NF 7/8 SMLK BORA540Rainbow Energy MarketingCorporation PacifiCorp West Sierra Pacific Power NF 7/8 SMLK M345541Rainbow Energy MarketingCorporation Idaho Power Company PacifiCorp East NF 7/8 WALLAWALLA BORA542Rainbow Energy MarketingCorporation Idaho Power Company PacifiCorp East NF 7/8 WALLAWALLA GSHN543Rainbow Energy MarketingCorporation Idaho Power Company PacifiCorp East NF 7/8 WALLAWALLA JBSN544Rainbow Energy MarketingCorporation Idaho Power Company Sierra Pacific Power NF 7/8 WALLAWALLA M345545Rockland Wind Farm, LLC NF 11546Riley Solar I Bonneville Power Administration Bonneville Power Administration NF 7/8 LAGRANDE LAGRANDE547Shell Energy North America(US), L.P.NF 11548Shell Energy North America(US), L.P.PacifiCorp East NorthWestern/PacifiCorp East NF 7/8 BORA BPAT.NWMT549Shell Energy North America(US), L.P.PacifiCorp East PacifiCorp West NF 7/8 BORA H500550Shell Energy North America(US), L.P.PacifiCorp East PacifiCorp West NF 7/8 BORA HURR551Shell Energy North America(US), L.P.PacifiCorp East Bonneville Power Administration NF 7/8 BORA LAGRANDE552Shell Energy North America(US), L.P.PacifiCorp East Avista NF 7/8 BORA LOLO553Shell Energy North America(US), L.P.PacifiCorp East Sierra Pacific Power NF 7/8 BORA M345554Shell Energy North America(US), L.P.NorthWestern/PacifiCorp East PacifiCorp East NF 7/8 BPAT.NWMT BRDY555Shell Energy North America(US), L.P.NorthWestern/PacifiCorp East PacifiCorp West NF 7/8 BPAT.NWMT HURR556Shell Energy North America(US), L.P.NorthWestern/PacifiCorp East Bonneville Power Administration NF 7/8 BPAT.NWMT LAGRANDE557Shell Energy North America(US), L.P.NorthWestern/PacifiCorp East Sierra Pacific Power NF 7/8 BPAT.NWMT M345558Shell Energy North America(US), L.P.PacifiCorp East NorthWestern/PacifiCorp East NF 7/8 BRDY BPAT.NWMT559Shell Energy North America(US), L.P.PacifiCorp East PacifiCorp West NF 7/8 BRDY HURR560Shell Energy North America(US), L.P.PacifiCorp East Bonneville Power Administration NF 7/8 BRDY LAGRANDE561Shell Energy North America(US), L.P.PacifiCorp East Avista NF 7/8 BRDY LOLO562Shell Energy North America(US), L.P.PacifiCorp East Sierra Pacific Power NF 7/8 BRDY M345563Shell Energy North America(US), L.P.PacifiCorp East Sierra Pacific Power SFP 7/8 BRDY M345564Shell Energy North America(US), L.P.PacifiCorp East NorthWestern/PacifiCorp East NF 7/8 GSHN BPAT.NWMT565Shell Energy North America(US), L.P.PacifiCorp East Bonneville Power Administration NF 7/8 GSHN LAGRANDE566Shell Energy North America(US), L.P.PacifiCorp West PacifiCorp East NF 7/8 HURR BORATRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456.1) (Including transactions referred to as "wheeling")LineNo.Payment By (Company of PublicAuthority) (Footnote Affiliation)(a)Energy Received From (Company ofPublic Authority) (FootnoteAffiliation)(b)Energy Delivered To (Company ofPublic Authority) (FootnoteAffiliation)(c)StatisticalClassification(d)Ferc RateSchedule ofTariff Number(e)Point of Receipt(Substation orOtherDesignation)(f)Point ofDelivery(Substation orOtherDesignation)(g)FERC FORM NO. 1 (ED. 12-90)Page 328-330
567 Shell Energy North America
(US), L.P.PacifiCorp West NorthWestern/PacifiCorp East NF 7/8 HURR BPAT.NWMT
568 Shell Energy North America
(US), L.P.PacifiCorp West Bonneville Power Administration NF 7/8 HURR LAGRANDE
569 Shell Energy North America
(US), L.P.PacifiCorp West Sierra Pacific Power NF 7/8 HURR M345
570 Shell Energy North America
(US), L.P.PacifiCorp East PacifiCorp West NF 7/8 JBSN H500
571 Shell Energy North America
(US), L.P.PacifiCorp East PacifiCorp West NF 7/8 JBSN HURR
572 Shell Energy North America
(US), L.P.PacifiCorp East Bonneville Power Administration NF 7/8 JBSN LAGRANDE
573 Shell Energy North America
(US), L.P.Bonneville Power Administration PacifiCorp East NF 7/8 LAGRANDE BORA
574 Shell Energy North America
(US), L.P.Bonneville Power Administration NorthWestern/PacifiCorp East NF 7/8 LAGRANDE BPAT.NWMT
575 Shell Energy North America
(US), L.P.Bonneville Power Administration PacifiCorp East NF 7/8 LAGRANDE BRDY
576 Shell Energy North America
(US), L.P.Bonneville Power Administration PacifiCorp East NF 7/8 LAGRANDE JBSN
577 Shell Energy North America
(US), L.P.Bonneville Power Administration Sierra Pacific Power NF 7/8 LAGRANDE M345
578 Shell Energy North America
(US), L.P.Idaho Power Company PacifiCorp East NF 7/8 LYPK ANTE
579 Shell Energy North America
(US), L.P.Idaho Power Company PacifiCorp East NF 7/8 LYPK BORA
580 Shell Energy North America
(US), L.P.Idaho Power Company NorthWestern/PacifiCorp East NF 7/8 LYPK BPAT.NWMT
581 Shell Energy North America
(US), L.P.Idaho Power Company PacifiCorp East NF 7/8 LYPK BRDY
582 Shell Energy North America
(US), L.P.Idaho Power Company PacifiCorp East SFP 7/8 LYPK BRDY
583 Shell Energy North America
(US), L.P.Idaho Power Company PacifiCorp West NF 7/8 LYPK HURR
584 Shell Energy North America
(US), L.P.Idaho Power Company Avista NF 7/8 LYPK LOLO
585 Shell Energy North America
(US), L.P.Idaho Power Company Sierra Pacific Power NF 7/8 LYPK M345
586 Shell Energy North America
(US), L.P.Idaho Power Company Sierra Pacific Power SFP 7/8 LYPK M345
587 Shell Energy North America
(US), L.P.Idaho Power Company PacifiCorp West NF 7/8 LYPK M500
588 Shell Energy North America
(US), L.P.Idaho Power Company NorthWestern/PacifiCorp East NF 7/8 LYPK MLCK
589 Shell Energy North America
(US), L.P.Sierra Pacific Power NorthWestern/PacifiCorp East NF 7/8 M345 BPAT.NWMT
590 Shell Energy North America
(US), L.P.Sierra Pacific Power PacifiCorp East NF 7/8 M345 BRDY
591
Shell Energy North America
(US), L.P.Sierra Pacific Power PacifiCorp West NF 7/8 M345 HURR
592 Shell Energy North America
(US), L.P.Sierra Pacific Power Bonneville Power Administration NF 7/8 M345 LAGRANDE
593 Shell Energy North America
(US), L.P.Sierra Pacific Power Bonneville Power Administration SFP 7/8 M345 LAGRANDE
594 Shell Energy North America
(US), L.P.Sierra Pacific Power Avista NF 7/8 M345 LOLO
TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456.1) (Including transactions referred to as "wheeling")
Line
No.
Payment By (Company of Public
Authority) (Footnote Affiliation)
(a)
Energy Received From (Company of
Public Authority) (Footnote
Affiliation)
(b)
Energy Delivered To (Company of
Public Authority) (Footnote
Affiliation)
(c)
Statistical
Classification
(d)
Ferc Rate
Schedule of
Tariff Number
(e)
Point of Receipt
(Substation or
Other
Designation)
(f)
Point of
Delivery
(Substation or
Other
Designation)
(g)
FERC FORM NO. 1 (ED. 12-90)
Page 328-330
567 Shell Energy North America(US), L.P.PacifiCorp West NorthWestern/PacifiCorp East NF 7/8 HURR BPAT.NWMT568Shell Energy North America(US), L.P.PacifiCorp West Bonneville Power Administration NF 7/8 HURR LAGRANDE569Shell Energy North America(US), L.P.PacifiCorp West Sierra Pacific Power NF 7/8 HURR M345570Shell Energy North America(US), L.P.PacifiCorp East PacifiCorp West NF 7/8 JBSN H500571Shell Energy North America(US), L.P.PacifiCorp East PacifiCorp West NF 7/8 JBSN HURR572Shell Energy North America(US), L.P.PacifiCorp East Bonneville Power Administration NF 7/8 JBSN LAGRANDE573Shell Energy North America(US), L.P.Bonneville Power Administration PacifiCorp East NF 7/8 LAGRANDE BORA574Shell Energy North America(US), L.P.Bonneville Power Administration NorthWestern/PacifiCorp East NF 7/8 LAGRANDE BPAT.NWMT575Shell Energy North America(US), L.P.Bonneville Power Administration PacifiCorp East NF 7/8 LAGRANDE BRDY576Shell Energy North America(US), L.P.Bonneville Power Administration PacifiCorp East NF 7/8 LAGRANDE JBSN577Shell Energy North America(US), L.P.Bonneville Power Administration Sierra Pacific Power NF 7/8 LAGRANDE M345578Shell Energy North America(US), L.P.Idaho Power Company PacifiCorp East NF 7/8 LYPK ANTE579Shell Energy North America(US), L.P.Idaho Power Company PacifiCorp East NF 7/8 LYPK BORA580Shell Energy North America(US), L.P.Idaho Power Company NorthWestern/PacifiCorp East NF 7/8 LYPK BPAT.NWMT581Shell Energy North America(US), L.P.Idaho Power Company PacifiCorp East NF 7/8 LYPK BRDY582Shell Energy North America(US), L.P.Idaho Power Company PacifiCorp East SFP 7/8 LYPK BRDY583Shell Energy North America(US), L.P.Idaho Power Company PacifiCorp West NF 7/8 LYPK HURR584Shell Energy North America(US), L.P.Idaho Power Company Avista NF 7/8 LYPK LOLO585Shell Energy North America(US), L.P.Idaho Power Company Sierra Pacific Power NF 7/8 LYPK M345586Shell Energy North America(US), L.P.Idaho Power Company Sierra Pacific Power SFP 7/8 LYPK M345587Shell Energy North America(US), L.P.Idaho Power Company PacifiCorp West NF 7/8 LYPK M500588Shell Energy North America(US), L.P.Idaho Power Company NorthWestern/PacifiCorp East NF 7/8 LYPK MLCK589Shell Energy North America(US), L.P.Sierra Pacific Power NorthWestern/PacifiCorp East NF 7/8 M345 BPAT.NWMT590Shell Energy North America(US), L.P.Sierra Pacific Power PacifiCorp East NF 7/8 M345 BRDY591Shell Energy North America(US), L.P.Sierra Pacific Power PacifiCorp West NF 7/8 M345 HURR592Shell Energy North America(US), L.P.Sierra Pacific Power Bonneville Power Administration NF 7/8 M345 LAGRANDE593Shell Energy North America(US), L.P.Sierra Pacific Power Bonneville Power Administration SFP 7/8 M345 LAGRANDE594Shell Energy North America(US), L.P.Sierra Pacific Power Avista NF 7/8 M345 LOLOTRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456.1) (Including transactions referred to as "wheeling")LineNo.Payment By (Company of PublicAuthority) (Footnote Affiliation)(a)Energy Received From (Company ofPublic Authority) (FootnoteAffiliation)(b)Energy Delivered To (Company ofPublic Authority) (FootnoteAffiliation)(c)StatisticalClassification(d)Ferc RateSchedule ofTariff Number(e)Point of Receipt(Substation orOtherDesignation)(f)Point ofDelivery(Substation orOtherDesignation)(g)FERC FORM NO. 1 (ED. 12-90)Page 328-330
595 Shell Energy North America
(US), L.P.Sierra Pacific Power Avista SFP 7/8 M345 LOLO
596 Shell Energy North America
(US), L.P.PacifiCorp West Sierra Pacific Power NF 7/8 SMLK M345
597 Shell Energy North America
(US), L.P.Idaho Power Company PacifiCorp East NF 7/8 WALLAWALLA BORA
598 Shell Energy North America
(US), L.P.Idaho Power Company NorthWestern/PacifiCorp East NF 7/8 WALLAWALLA BPAT.NWMT
599 Shell Energy North America
(US), L.P.Idaho Power Company PacifiCorp East NF 7/8 WALLAWALLA BRDY
600 Shell Energy North America
(US), L.P.Idaho Power Company PacifiCorp East NF 7/8 WALLAWALLA JBSN
601 Shell Energy North America
(US), L.P.Idaho Power Company Bonneville Power Administration NF 7/8 WALLAWALLA LAGRANDE
602 Shell Energy North America
(US), L.P.Idaho Power Company Sierra Pacific Power NF 7/8 WALLAWALLA M345
603 Shell Energy North America
(US), L.P.Idaho Power Company Sierra Pacific Power SFP 7/8 WALLAWALLA M345
604 SociVolta, Inc.NF 7/8
605 Starvation Solar I, LLC Bonneville Power Administration Bonneville Power Administration NF 7/8 LAGRANDE LAGRANDE
606 Suntex Solar, LLC Bonneville Power Administration Bonneville Power Administration NF 7/8 LAGRANDE LAGRANDE
607 TEC Energy Inc.PacifiCorp East Sierra Pacific Power NF 7/8 BRDY M345
608 TEC Energy Inc.PacifiCorp East Sierra Pacific Power NF 7/8 JBSN M345
609 TEC Energy Inc.Sierra Pacific Power NorthWestern/PacifiCorp East NF 7/8 M345 AVAT.NWMT
610 TEC Energy Inc.Sierra Pacific Power PacifiCorp East NF 7/8 M345 BRDY
611 TEC Energy Inc.Sierra Pacific Power Bonneville Power Administration NF 7/8 M345 LAGRANDE
612 TEC Energy Inc.Sierra Pacific Power NorthWestern/PacifiCorp East NF 7/8 M345 MLCK
613 Tenaska Power Services PacifiCorp East Sierra Pacific Power NF 7/8 GSHN M345
614 Tenaska Power Services PacifiCorp East Sierra Pacific Power SFP 7/8 GSHN M345
615 Tenaska Power Services PacifiCorp East PacifiCorp West NF 7/8 JBSN POP
616 Tenaska Power Services Bonneville Power Administration PacifiCorp East NF 7/8 LAGRANDE BRDY
617 Tenaska Power Services Avista PacifiCorp East NF 7/8 LOLO BRDY
618 Tenaska Power Services Idaho Power Company PacifiCorp East NF 7/8 MDSK GSHN
619 Tenaska Power Services Idaho Power Company PacifiCorp East SFP 7/8 MDSK GSHN
620 Tenaska Power Services Idaho Power Company Sierra Pacific Power NF 7/8 MDSK M345
621 Tenaska Power Services Idaho Power Company Sierra Pacific Power SFP 7/8 MDSK M345
622 The Energy Authority, Inc.NorthWestern/PacifiCorp East Sierra Pacific Power NF 7/8 AVAT.NWMT M345
623 The Energy Authority, Inc.PacifiCorp East PacifiCorp East NF 7/8 BORA ANTE
624 The Energy Authority, Inc.PacifiCorp East NorthWestern/PacifiCorp East NF 7/8 BORA BPAT.NWMT
625 The Energy Authority, Inc.PacifiCorp East PacifiCorp East NF 7/8 BORA BRDY
626 The Energy Authority, Inc.PacifiCorp East PacifiCorp West NF 7/8 BORA H500
627 The Energy Authority, Inc.PacifiCorp East PacifiCorp West NF 7/8 BORA HURR
628 The Energy Authority, Inc.PacifiCorp East Bonneville Power Administration NF 7/8 BORA LAGRANDE
629 The Energy Authority, Inc.PacifiCorp East Avista NF 7/8 BORA LOLO
630 The Energy Authority, Inc.PacifiCorp East Sierra Pacific Power NF 7/8 BORA M345
631 The Energy Authority, Inc.NorthWestern/PacifiCorp East PacifiCorp East NF 7/8 BPAT.NWMT BORA
632 The Energy Authority, Inc.NorthWestern/PacifiCorp East PacifiCorp East NF 7/8 BPAT.NWMT BRDY
633 The Energy Authority, Inc.NorthWestern/PacifiCorp East Bonneville Power Administration NF 7/8 BPAT.NWMT LAGRANDE
TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456.1) (Including transactions referred to as "wheeling")
Line
No.
Payment By (Company of Public
Authority) (Footnote Affiliation)
(a)
Energy Received From (Company of
Public Authority) (Footnote
Affiliation)
(b)
Energy Delivered To (Company of
Public Authority) (Footnote
Affiliation)
(c)
Statistical
Classification
(d)
Ferc Rate
Schedule of
Tariff Number
(e)
Point of Receipt
(Substation or
Other
Designation)
(f)
Point of
Delivery
(Substation or
Other
Designation)
(g)
FERC FORM NO. 1 (ED. 12-90)
Page 328-330
595 Shell Energy North America(US), L.P.Sierra Pacific Power Avista SFP 7/8 M345 LOLO596Shell Energy North America(US), L.P.PacifiCorp West Sierra Pacific Power NF 7/8 SMLK M345597Shell Energy North America(US), L.P.Idaho Power Company PacifiCorp East NF 7/8 WALLAWALLA BORA598Shell Energy North America(US), L.P.Idaho Power Company NorthWestern/PacifiCorp East NF 7/8 WALLAWALLA BPAT.NWMT599Shell Energy North America(US), L.P.Idaho Power Company PacifiCorp East NF 7/8 WALLAWALLA BRDY600Shell Energy North America(US), L.P.Idaho Power Company PacifiCorp East NF 7/8 WALLAWALLA JBSN601Shell Energy North America(US), L.P.Idaho Power Company Bonneville Power Administration NF 7/8 WALLAWALLA LAGRANDE602Shell Energy North America(US), L.P.Idaho Power Company Sierra Pacific Power NF 7/8 WALLAWALLA M345603Shell Energy North America(US), L.P.Idaho Power Company Sierra Pacific Power SFP 7/8 WALLAWALLA M345604SociVolta, Inc.NF 7/8605Starvation Solar I, LLC Bonneville Power Administration Bonneville Power Administration NF 7/8 LAGRANDE LAGRANDE606Suntex Solar, LLC Bonneville Power Administration Bonneville Power Administration NF 7/8 LAGRANDE LAGRANDE607TEC Energy Inc.PacifiCorp East Sierra Pacific Power NF 7/8 BRDY M345608TEC Energy Inc.PacifiCorp East Sierra Pacific Power NF 7/8 JBSN M345609TEC Energy Inc.Sierra Pacific Power NorthWestern/PacifiCorp East NF 7/8 M345 AVAT.NWMT610TEC Energy Inc.Sierra Pacific Power PacifiCorp East NF 7/8 M345 BRDY611TEC Energy Inc.Sierra Pacific Power Bonneville Power Administration NF 7/8 M345 LAGRANDE612TEC Energy Inc.Sierra Pacific Power NorthWestern/PacifiCorp East NF 7/8 M345 MLCK613Tenaska Power Services PacifiCorp East Sierra Pacific Power NF 7/8 GSHN M345614Tenaska Power Services PacifiCorp East Sierra Pacific Power SFP 7/8 GSHN M345615Tenaska Power Services PacifiCorp East PacifiCorp West NF 7/8 JBSN POP616Tenaska Power Services Bonneville Power Administration PacifiCorp East NF 7/8 LAGRANDE BRDY617Tenaska Power Services Avista PacifiCorp East NF 7/8 LOLO BRDY618Tenaska Power Services Idaho Power Company PacifiCorp East NF 7/8 MDSK GSHN619Tenaska Power Services Idaho Power Company PacifiCorp East SFP 7/8 MDSK GSHN620Tenaska Power Services Idaho Power Company Sierra Pacific Power NF 7/8 MDSK M345621Tenaska Power Services Idaho Power Company Sierra Pacific Power SFP 7/8 MDSK M345622The Energy Authority, Inc.NorthWestern/PacifiCorp East Sierra Pacific Power NF 7/8 AVAT.NWMT M345623The Energy Authority, Inc.PacifiCorp East PacifiCorp East NF 7/8 BORA ANTE624The Energy Authority, Inc.PacifiCorp East NorthWestern/PacifiCorp East NF 7/8 BORA BPAT.NWMT625The Energy Authority, Inc.PacifiCorp East PacifiCorp East NF 7/8 BORA BRDY626The Energy Authority, Inc.PacifiCorp East PacifiCorp West NF 7/8 BORA H500627The Energy Authority, Inc.PacifiCorp East PacifiCorp West NF 7/8 BORA HURR628The Energy Authority, Inc.PacifiCorp East Bonneville Power Administration NF 7/8 BORA LAGRANDE629The Energy Authority, Inc.PacifiCorp East Avista NF 7/8 BORA LOLO630The Energy Authority, Inc.PacifiCorp East Sierra Pacific Power NF 7/8 BORA M345631The Energy Authority, Inc.NorthWestern/PacifiCorp East PacifiCorp East NF 7/8 BPAT.NWMT BORA632The Energy Authority, Inc.NorthWestern/PacifiCorp East PacifiCorp East NF 7/8 BPAT.NWMT BRDY633The Energy Authority, Inc.NorthWestern/PacifiCorp East Bonneville Power Administration NF 7/8 BPAT.NWMT LAGRANDETRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456.1) (Including transactions referred to as "wheeling")LineNo.Payment By (Company of PublicAuthority) (Footnote Affiliation)(a)Energy Received From (Company ofPublic Authority) (FootnoteAffiliation)(b)Energy Delivered To (Company ofPublic Authority) (FootnoteAffiliation)(c)StatisticalClassification(d)Ferc RateSchedule ofTariff Number(e)Point of Receipt(Substation orOtherDesignation)(f)Point ofDelivery(Substation orOtherDesignation)(g)FERC FORM NO. 1 (ED. 12-90)Page 328-330
634 The Energy Authority, Inc.NorthWestern/PacifiCorp East Bonneville Power Administration SFP 7/8 BPAT.NWMT LAGRANDE
635 The Energy Authority, Inc.NorthWestern/PacifiCorp East Avista NF 7/8 BPAT.NWMT LOLO
636 The Energy Authority, Inc.NorthWestern/PacifiCorp East Sierra Pacific Power NF 7/8 BPAT.NWMT M345
637 The Energy Authority, Inc.NorthWestern/PacifiCorp East Sierra Pacific Power SFP 7/8 BPAT.NWMT M345
638 The Energy Authority, Inc.PacifiCorp East NorthWestern/PacifiCorp East NF 7/8 BRDY AVAT.NWMT
639 The Energy Authority, Inc.PacifiCorp East PacifiCorp East NF 7/8 BRDY BORA
640 The Energy Authority, Inc.PacifiCorp East NorthWestern/PacifiCorp East NF 7/8 BRDY BPAT.NWMT
641 The Energy Authority, Inc.PacifiCorp East PacifiCorp West NF 7/8 BRDY HURR
642 The Energy Authority, Inc.PacifiCorp East Bonneville Power Administration NF 7/8 BRDY LAGRANDE
643 The Energy Authority, Inc.PacifiCorp East Avista NF 7/8 BRDY LOLO
644 The Energy Authority, Inc.PacifiCorp East Avista SFP 7/8 BRDY LOLo
645 The Energy Authority, Inc.PacifiCorp East Sierra Pacific Power NF 7/8 BRDY M345
646 The Energy Authority, Inc.PacifiCorp East PacifiCorp West NF 7/8 GSHN HURR
647 The Energy Authority, Inc.PacifiCorp East Bonneville Power Administration NF 7/8 GSHN LAGRANDE
648 The Energy Authority, Inc.PacifiCorp East Avista NF 7/8 GSHN LOLO
649 The Energy Authority, Inc.PacifiCorp West PacifiCorp East NF 7/8 H500 BORA
650 The Energy Authority, Inc.PacifiCorp West PacifiCorp East NF 7/8 HURR BORA
651 The Energy Authority, Inc.PacifiCorp West Avista NF 7/8 HURR LOLO
652 The Energy Authority, Inc.PacifiCorp West Sierra Pacific Power NF 7/8 HURR M345
653 The Energy Authority, Inc.PacifiCorp East PacifiCorp East NF 7/8 JBSN BORA
654 The Energy Authority, Inc.PacifiCorp East NorthWestern/PacifiCorp East NF 7/8 JBSN BPAT.NWMT
655 The Energy Authority, Inc.PacifiCorp East PacifiCorp East NF 7/8 JBSN BRDY
656 The Energy Authority, Inc.PacifiCorp East PacifiCorp East NF 7/8 JBSN GSHN
657 The Energy Authority, Inc.PacifiCorp East PacifiCorp West NF 7/8 JBSN H500
658 The Energy Authority, Inc.PacifiCorp East PacifiCorp West NF 7/8 JBSN HURR
659 The Energy Authority, Inc.PacifiCorp East Bonneville Power Administration NF 7/8 JBSN LAGRANDE
660 The Energy Authority, Inc.PacifiCorp East Avista NF 7/8 JBSN LOLO
661 The Energy Authority, Inc.PacifiCorp East Sierra Pacific Power NF 7/8 JBSN M345
662 The Energy Authority, Inc.PacifiCorp East PacifiCorp West NF 7/8 JBSN POP
663 The Energy Authority, Inc.PacifiCorp East PacifiCorp East NF 7/8 JEFF BORA
664 The Energy Authority, Inc.PacifiCorp East Bonneville Power Administration NF 7/8 JEFF LAGRANDE
665 The Energy Authority, Inc.PacifiCorp East Sierra Pacific Power NF 7/8 JEFF M345
666 The Energy Authority, Inc.Bonneville Power Administration PacifiCorp East NF 7/8 LAGRANDE BORA
667 The Energy Authority, Inc.Bonneville Power Administration PacifiCorp East NF 7/8 LAGRANDE BRDY
668 The Energy Authority, Inc.Bonneville Power Administration Sierra Pacific Power NF 7/8 LAGRANDE M345
669 The Energy Authority, Inc.Avista PacifiCorp East NF 7/8 LOLO BORA
670 The Energy Authority, Inc.Avista PacifiCorp East NF 7/8 LOLO BRDY
671 The Energy Authority, Inc.Avista Sierra Pacific Power NF 7/8 LOLO M345
672 The Energy Authority, Inc.Sierra Pacific Power PacifiCorp East NF 7/8 M345 BORA
673 The Energy Authority, Inc.Sierra Pacific Power NorthWestern/PacifiCorp East NF 7/8 M345 BPAT.NWMT
674 The Energy Authority, Inc.Sierra Pacific Power NorthWestern/PacifiCorp East SFP 7/8 M345 BPAT.NWMT
675 The Energy Authority, Inc.Sierra Pacific Power PacifiCorp East NF 7/8 M345 GSHN
676 The Energy Authority, Inc.Sierra Pacific Power PacifiCorp West NF 7/8 M345 H500
TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456.1) (Including transactions referred to as "wheeling")
Line
No.
Payment By (Company of Public
Authority) (Footnote Affiliation)
(a)
Energy Received From (Company of
Public Authority) (Footnote
Affiliation)
(b)
Energy Delivered To (Company of
Public Authority) (Footnote
Affiliation)
(c)
Statistical
Classification
(d)
Ferc Rate
Schedule of
Tariff Number
(e)
Point of Receipt
(Substation or
Other
Designation)
(f)
Point of
Delivery
(Substation or
Other
Designation)
(g)
FERC FORM NO. 1 (ED. 12-90)
Page 328-330
634 The Energy Authority, Inc.NorthWestern/PacifiCorp East Bonneville Power Administration SFP 7/8 BPAT.NWMT LAGRANDE635The Energy Authority, Inc.NorthWestern/PacifiCorp East Avista NF 7/8 BPAT.NWMT LOLO636The Energy Authority, Inc.NorthWestern/PacifiCorp East Sierra Pacific Power NF 7/8 BPAT.NWMT M345637The Energy Authority, Inc.NorthWestern/PacifiCorp East Sierra Pacific Power SFP 7/8 BPAT.NWMT M345638The Energy Authority, Inc.PacifiCorp East NorthWestern/PacifiCorp East NF 7/8 BRDY AVAT.NWMT639The Energy Authority, Inc.PacifiCorp East PacifiCorp East NF 7/8 BRDY BORA640The Energy Authority, Inc.PacifiCorp East NorthWestern/PacifiCorp East NF 7/8 BRDY BPAT.NWMT641The Energy Authority, Inc.PacifiCorp East PacifiCorp West NF 7/8 BRDY HURR642The Energy Authority, Inc.PacifiCorp East Bonneville Power Administration NF 7/8 BRDY LAGRANDE643The Energy Authority, Inc.PacifiCorp East Avista NF 7/8 BRDY LOLO644The Energy Authority, Inc.PacifiCorp East Avista SFP 7/8 BRDY LOLo645The Energy Authority, Inc.PacifiCorp East Sierra Pacific Power NF 7/8 BRDY M345646The Energy Authority, Inc.PacifiCorp East PacifiCorp West NF 7/8 GSHN HURR647The Energy Authority, Inc.PacifiCorp East Bonneville Power Administration NF 7/8 GSHN LAGRANDE648The Energy Authority, Inc.PacifiCorp East Avista NF 7/8 GSHN LOLO649The Energy Authority, Inc.PacifiCorp West PacifiCorp East NF 7/8 H500 BORA650The Energy Authority, Inc.PacifiCorp West PacifiCorp East NF 7/8 HURR BORA651The Energy Authority, Inc.PacifiCorp West Avista NF 7/8 HURR LOLO652The Energy Authority, Inc.PacifiCorp West Sierra Pacific Power NF 7/8 HURR M345653The Energy Authority, Inc.PacifiCorp East PacifiCorp East NF 7/8 JBSN BORA654The Energy Authority, Inc.PacifiCorp East NorthWestern/PacifiCorp East NF 7/8 JBSN BPAT.NWMT655The Energy Authority, Inc.PacifiCorp East PacifiCorp East NF 7/8 JBSN BRDY656The Energy Authority, Inc.PacifiCorp East PacifiCorp East NF 7/8 JBSN GSHN657The Energy Authority, Inc.PacifiCorp East PacifiCorp West NF 7/8 JBSN H500658The Energy Authority, Inc.PacifiCorp East PacifiCorp West NF 7/8 JBSN HURR659The Energy Authority, Inc.PacifiCorp East Bonneville Power Administration NF 7/8 JBSN LAGRANDE660The Energy Authority, Inc.PacifiCorp East Avista NF 7/8 JBSN LOLO661The Energy Authority, Inc.PacifiCorp East Sierra Pacific Power NF 7/8 JBSN M345662The Energy Authority, Inc.PacifiCorp East PacifiCorp West NF 7/8 JBSN POP663The Energy Authority, Inc.PacifiCorp East PacifiCorp East NF 7/8 JEFF BORA664The Energy Authority, Inc.PacifiCorp East Bonneville Power Administration NF 7/8 JEFF LAGRANDE665The Energy Authority, Inc.PacifiCorp East Sierra Pacific Power NF 7/8 JEFF M345666The Energy Authority, Inc.Bonneville Power Administration PacifiCorp East NF 7/8 LAGRANDE BORA667The Energy Authority, Inc.Bonneville Power Administration PacifiCorp East NF 7/8 LAGRANDE BRDY668The Energy Authority, Inc.Bonneville Power Administration Sierra Pacific Power NF 7/8 LAGRANDE M345669The Energy Authority, Inc.Avista PacifiCorp East NF 7/8 LOLO BORA670The Energy Authority, Inc.Avista PacifiCorp East NF 7/8 LOLO BRDY671The Energy Authority, Inc.Avista Sierra Pacific Power NF 7/8 LOLO M345672The Energy Authority, Inc.Sierra Pacific Power PacifiCorp East NF 7/8 M345 BORA673The Energy Authority, Inc.Sierra Pacific Power NorthWestern/PacifiCorp East NF 7/8 M345 BPAT.NWMT674The Energy Authority, Inc.Sierra Pacific Power NorthWestern/PacifiCorp East SFP 7/8 M345 BPAT.NWMT675The Energy Authority, Inc.Sierra Pacific Power PacifiCorp East NF 7/8 M345 GSHN676The Energy Authority, Inc.Sierra Pacific Power PacifiCorp West NF 7/8 M345 H500TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456.1) (Including transactions referred to as "wheeling")LineNo.Payment By (Company of PublicAuthority) (Footnote Affiliation)(a)Energy Received From (Company ofPublic Authority) (FootnoteAffiliation)(b)Energy Delivered To (Company ofPublic Authority) (FootnoteAffiliation)(c)StatisticalClassification(d)Ferc RateSchedule ofTariff Number(e)Point of Receipt(Substation orOtherDesignation)(f)Point ofDelivery(Substation orOtherDesignation)(g)FERC FORM NO. 1 (ED. 12-90)Page 328-330
677 The Energy Authority, Inc.Sierra Pacific Power PacifiCorp West SFP 7/8 M345 H500
678 The Energy Authority, Inc.Sierra Pacific Power PacifiCorp West NF 7/8 M345 HURR
679 The Energy Authority, Inc.Sierra Pacific Power Bonneville Power Administration NF 7/8 M345 LAGRANDE
680 The Energy Authority, Inc.Sierra Pacific Power Bonneville Power Administration SFP 7/8 M345 LAGRANDE
681 The Energy Authority, Inc.Sierra Pacific Power Avista NF 7/8 M345 LOLO
682 The Energy Authority, Inc.Sierra Pacific Power PacifiCorp West SFP 7/8 M345 M500
683 The Energy Authority, Inc.PacifiCorp West PacifiCorp East NF 7/8 POP BORA
684 The Energy Authority, Inc.PacifiCorp West Sierra Pacific Power NF 7/8 POP M345
685 The Energy Authority, Inc.PacifiCorp West PacifiCorp East NF 7/8 SMLK BORA
686 The Energy Authority, Inc.PacifiCorp West PacifiCorp East NF 7/8 SMLK BRDY
687 The Energy Authority, Inc.PacifiCorp West Sierra Pacific Power NF 7/8 SMLK M345
688 The Energy Authority, Inc.Idaho Power Company PacifiCorp East NF 7/8 WALLAWALLA BORA
689 The Energy Authority, Inc.Idaho Power Company Sierra Pacific Power NF 7/8 WALLAWALLA M345
690 Thunderegg Solar Center, LLC NF 11
691 TransAlta Energy Marketing
(US) Inc.PacifiCorp East Bonneville Power Administration NF 7/8 ANTE LAGRANDE
692 TransAlta Energy Marketing
(US) Inc.Idaho Power Company PacifiCorp East NF 7/8 BGSY JEFF
693 TransAlta Energy Marketing
(US) Inc.Idaho Power Company PacifiCorp East SFP 7/8 BGSY JEFF
694 TransAlta Energy Marketing
(US) Inc.PacifiCorp East PacifiCorp East NF 7/8 BORA ANTE
695 TransAlta Energy Marketing
(US) Inc.PacifiCorp East NorthWestern/PacifiCorp East NF 7/8 BORA BPAT.NWMT
696 TransAlta Energy Marketing
(US) Inc.PacifiCorp East PacifiCorp West NF 7/8 BORA HURR
697 TransAlta Energy Marketing
(US) Inc.PacifiCorp East Bonneville Power Administration NF 7/8 BORA LAGRANDE
698 TransAlta Energy Marketing
(US) Inc.PacifiCorp East Avista NF 7/8 BORA LOLO
699 TransAlta Energy Marketing
(US) Inc.PacifiCorp East Sierra Pacific Power NF 7/8 BORA M345
700 TransAlta Energy Marketing
(US) Inc.NorthWestern/PacifiCorp East PacifiCorp East NF 7/8 BPAT.NWMT BORA
701 TransAlta Energy Marketing
(US) Inc.NorthWestern/PacifiCorp East Bonneville Power Administration NF 7/8 BPAT.NWMT LAGRANDE
702 TransAlta Energy Marketing
(US) Inc.NorthWestern/PacifiCorp East Sierra Pacific Power NF 7/8 BPAT.NWMT M345
703 TransAlta Energy Marketing
(US) Inc.PacifiCorp East PacifiCorp East NF 7/8 BRDY ANTE
704 TransAlta Energy Marketing
(US) Inc.PacifiCorp East NorthWestern/PacifiCorp East NF 7/8 BRDY AVAT.NWMT
705 TransAlta Energy Marketing
(US) Inc.PacifiCorp East PacifiCorp East NF 7/8 BRDY BORA
706 TransAlta Energy Marketing
(US) Inc.PacifiCorp East NorthWestern/PacifiCorp East NF 7/8 BRDY BPAT.NWMT
707 TransAlta Energy Marketing
(US) Inc.PacifiCorp East PacifiCorp West NF 7/8 BRDY HURR
708 TransAlta Energy Marketing
(US) Inc.PacifiCorp East Bonneville Power Administration NF 7/8 BRDY LAGRANDE
709 TransAlta Energy Marketing
(US) Inc.PacifiCorp East Avista NF 7/8 BRDY LOLO
710 TransAlta Energy Marketing
(US) Inc.PacifiCorp East Sierra Pacific Power NF 7/8 BRDY M345
TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456.1) (Including transactions referred to as "wheeling")
Line
No.
Payment By (Company of Public
Authority) (Footnote Affiliation)
(a)
Energy Received From (Company of
Public Authority) (Footnote
Affiliation)
(b)
Energy Delivered To (Company of
Public Authority) (Footnote
Affiliation)
(c)
Statistical
Classification
(d)
Ferc Rate
Schedule of
Tariff Number
(e)
Point of Receipt
(Substation or
Other
Designation)
(f)
Point of
Delivery
(Substation or
Other
Designation)
(g)
FERC FORM NO. 1 (ED. 12-90)
Page 328-330
677 The Energy Authority, Inc.Sierra Pacific Power PacifiCorp West SFP 7/8 M345 H500678The Energy Authority, Inc.Sierra Pacific Power PacifiCorp West NF 7/8 M345 HURR679The Energy Authority, Inc.Sierra Pacific Power Bonneville Power Administration NF 7/8 M345 LAGRANDE680The Energy Authority, Inc.Sierra Pacific Power Bonneville Power Administration SFP 7/8 M345 LAGRANDE681The Energy Authority, Inc.Sierra Pacific Power Avista NF 7/8 M345 LOLO682The Energy Authority, Inc.Sierra Pacific Power PacifiCorp West SFP 7/8 M345 M500683The Energy Authority, Inc.PacifiCorp West PacifiCorp East NF 7/8 POP BORA684The Energy Authority, Inc.PacifiCorp West Sierra Pacific Power NF 7/8 POP M345685The Energy Authority, Inc.PacifiCorp West PacifiCorp East NF 7/8 SMLK BORA686The Energy Authority, Inc.PacifiCorp West PacifiCorp East NF 7/8 SMLK BRDY687The Energy Authority, Inc.PacifiCorp West Sierra Pacific Power NF 7/8 SMLK M345688The Energy Authority, Inc.Idaho Power Company PacifiCorp East NF 7/8 WALLAWALLA BORA689The Energy Authority, Inc.Idaho Power Company Sierra Pacific Power NF 7/8 WALLAWALLA M345690Thunderegg Solar Center, LLC NF 11691TransAlta Energy Marketing(US) Inc.PacifiCorp East Bonneville Power Administration NF 7/8 ANTE LAGRANDE692TransAlta Energy Marketing(US) Inc.Idaho Power Company PacifiCorp East NF 7/8 BGSY JEFF693TransAlta Energy Marketing(US) Inc.Idaho Power Company PacifiCorp East SFP 7/8 BGSY JEFF694TransAlta Energy Marketing(US) Inc.PacifiCorp East PacifiCorp East NF 7/8 BORA ANTE695TransAlta Energy Marketing(US) Inc.PacifiCorp East NorthWestern/PacifiCorp East NF 7/8 BORA BPAT.NWMT696TransAlta Energy Marketing(US) Inc.PacifiCorp East PacifiCorp West NF 7/8 BORA HURR697TransAlta Energy Marketing(US) Inc.PacifiCorp East Bonneville Power Administration NF 7/8 BORA LAGRANDE698TransAlta Energy Marketing(US) Inc.PacifiCorp East Avista NF 7/8 BORA LOLO699TransAlta Energy Marketing(US) Inc.PacifiCorp East Sierra Pacific Power NF 7/8 BORA M345700TransAlta Energy Marketing(US) Inc.NorthWestern/PacifiCorp East PacifiCorp East NF 7/8 BPAT.NWMT BORA701TransAlta Energy Marketing(US) Inc.NorthWestern/PacifiCorp East Bonneville Power Administration NF 7/8 BPAT.NWMT LAGRANDE702TransAlta Energy Marketing(US) Inc.NorthWestern/PacifiCorp East Sierra Pacific Power NF 7/8 BPAT.NWMT M345703TransAlta Energy Marketing(US) Inc.PacifiCorp East PacifiCorp East NF 7/8 BRDY ANTE704TransAlta Energy Marketing(US) Inc.PacifiCorp East NorthWestern/PacifiCorp East NF 7/8 BRDY AVAT.NWMT705TransAlta Energy Marketing(US) Inc.PacifiCorp East PacifiCorp East NF 7/8 BRDY BORA706TransAlta Energy Marketing(US) Inc.PacifiCorp East NorthWestern/PacifiCorp East NF 7/8 BRDY BPAT.NWMT707TransAlta Energy Marketing(US) Inc.PacifiCorp East PacifiCorp West NF 7/8 BRDY HURR708TransAlta Energy Marketing(US) Inc.PacifiCorp East Bonneville Power Administration NF 7/8 BRDY LAGRANDE709TransAlta Energy Marketing(US) Inc.PacifiCorp East Avista NF 7/8 BRDY LOLO710TransAlta Energy Marketing(US) Inc.PacifiCorp East Sierra Pacific Power NF 7/8 BRDY M345TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456.1) (Including transactions referred to as "wheeling")LineNo.Payment By (Company of PublicAuthority) (Footnote Affiliation)(a)Energy Received From (Company ofPublic Authority) (FootnoteAffiliation)(b)Energy Delivered To (Company ofPublic Authority) (FootnoteAffiliation)(c)StatisticalClassification(d)Ferc RateSchedule ofTariff Number(e)Point of Receipt(Substation orOtherDesignation)(f)Point ofDelivery(Substation orOtherDesignation)(g)FERC FORM NO. 1 (ED. 12-90)Page 328-330
711 TransAlta Energy Marketing
(US) Inc.PacifiCorp West PacifiCorp East NF 7/8 HURR BORA
712 TransAlta Energy Marketing
(US) Inc.PacifiCorp East NorthWestern/PacifiCorp East NF 7/8 JBSN AVAT.NWMT
713 TransAlta Energy Marketing
(US) Inc.PacifiCorp East PacifiCorp East NF 7/8 JBSN BORA
714 TransAlta Energy Marketing
(US) Inc.PacifiCorp East NorthWestern/PacifiCorp East NF 7/8 JBSN BPAT.NWMT
715 TransAlta Energy Marketing
(US) Inc.PacifiCorp East PacifiCorp East NF 7/8 JBSN BRDY
716 TransAlta Energy Marketing
(US) Inc.PacifiCorp East PacifiCorp West NF 7/8 JBSN HURR
717 TransAlta Energy Marketing
(US) Inc.PacifiCorp East Bonneville Power Administration NF 7/8 JBSN LAGRANDE
718 TransAlta Energy Marketing
(US) Inc.PacifiCorp East Avista NF 7/8 JBSN LOLO
719
TransAlta Energy Marketing
(US) Inc.PacifiCorp East Sierra Pacific Power NF 7/8 JBSN M345
720 TransAlta Energy Marketing
(US) Inc.PacifiCorp East PacifiCorp West NF 7/8 JBSN POP
721 TransAlta Energy Marketing
(US) Inc.PacifiCorp East PacifiCorp East NF 7/8 JEFF BORA
722 TransAlta Energy Marketing
(US) Inc.PacifiCorp East Bonneville Power Administration NF 7/8 JEFF LAGRANDE
723 TransAlta Energy Marketing
(US) Inc.Bonneville Power Administration PacifiCorp East NF 7/8 LAGRANDE BORA
724 TransAlta Energy Marketing
(US) Inc.Bonneville Power Administration NorthWestern/PacifiCorp East NF 7/8 LAGRANDE BPAT.NWMT
725 TransAlta Energy Marketing
(US) Inc.Bonneville Power Administration PacifiCorp East NF 7/8 LAGRANDE BRDY
726 TransAlta Energy Marketing
(US) Inc.Bonneville Power Administration PacifiCorp West NF 7/8 LAGRANDE HURR
727 TransAlta Energy Marketing
(US) Inc.Bonneville Power Administration PacifiCorp East NF 7/8 LAGRANDE JBSN
728 TransAlta Energy Marketing
(US) Inc.Bonneville Power Administration Avista NF 7/8 LAGRANDE LOLO
729 TransAlta Energy Marketing
(US) Inc.Bonneville Power Administration Sierra Pacific Power NF 7/8 LAGRANDE M345
730 TransAlta Energy Marketing
(US) Inc.Avista PacifiCorp East NF 7/8 LOLO BORA
731 TransAlta Energy Marketing
(US) Inc.Avista NorthWestern/PacifiCorp East NF 7/8 LOLO BPAT.NWMT
732 TransAlta Energy Marketing
(US) Inc.Avista PacifiCorp East NF 7/8 LOLO BRDY
733 TransAlta Energy Marketing
(US) Inc.Avista Sierra Pacific Power NF 7/8 LOLO M345
734 TransAlta Energy Marketing
(US) Inc.Sierra Pacific Power PacifiCorp West NF 7/8 M345 H500
735 TransAlta Energy Marketing
(US) Inc.Sierra Pacific Power PacifiCorp West NF 7/8 M345 HURR
736 TransAlta Energy Marketing
(US) Inc.Sierra Pacific Power Bonneville Power Administration NF 7/8 M345 LAGRANDE
737 TransAlta Energy Marketing
(US) Inc.Sierra Pacific Power Bonneville Power Administration SFP 7/8 M345 LAGRANDE
738 TransAlta Energy Marketing
(US) Inc.Sierra Pacific Power Avista NF 7/8 M345 LOLO
739 TransAlta Energy Marketing
(US) Inc.PacifiCorp West PacifiCorp East NF 7/8 SMLK BORA
TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456.1) (Including transactions referred to as "wheeling")
Line
No.
Payment By (Company of Public
Authority) (Footnote Affiliation)
(a)
Energy Received From (Company of
Public Authority) (Footnote
Affiliation)
(b)
Energy Delivered To (Company of
Public Authority) (Footnote
Affiliation)
(c)
Statistical
Classification
(d)
Ferc Rate
Schedule of
Tariff Number
(e)
Point of Receipt
(Substation or
Other
Designation)
(f)
Point of
Delivery
(Substation or
Other
Designation)
(g)
FERC FORM NO. 1 (ED. 12-90)
Page 328-330
711 TransAlta Energy Marketing(US) Inc.PacifiCorp West PacifiCorp East NF 7/8 HURR BORA712TransAlta Energy Marketing(US) Inc.PacifiCorp East NorthWestern/PacifiCorp East NF 7/8 JBSN AVAT.NWMT713TransAlta Energy Marketing(US) Inc.PacifiCorp East PacifiCorp East NF 7/8 JBSN BORA714TransAlta Energy Marketing(US) Inc.PacifiCorp East NorthWestern/PacifiCorp East NF 7/8 JBSN BPAT.NWMT715TransAlta Energy Marketing(US) Inc.PacifiCorp East PacifiCorp East NF 7/8 JBSN BRDY716TransAlta Energy Marketing(US) Inc.PacifiCorp East PacifiCorp West NF 7/8 JBSN HURR717TransAlta Energy Marketing(US) Inc.PacifiCorp East Bonneville Power Administration NF 7/8 JBSN LAGRANDE718TransAlta Energy Marketing(US) Inc.PacifiCorp East Avista NF 7/8 JBSN LOLO719TransAlta Energy Marketing(US) Inc.PacifiCorp East Sierra Pacific Power NF 7/8 JBSN M345720TransAlta Energy Marketing(US) Inc.PacifiCorp East PacifiCorp West NF 7/8 JBSN POP721TransAlta Energy Marketing(US) Inc.PacifiCorp East PacifiCorp East NF 7/8 JEFF BORA722TransAlta Energy Marketing(US) Inc.PacifiCorp East Bonneville Power Administration NF 7/8 JEFF LAGRANDE723TransAlta Energy Marketing(US) Inc.Bonneville Power Administration PacifiCorp East NF 7/8 LAGRANDE BORA724TransAlta Energy Marketing(US) Inc.Bonneville Power Administration NorthWestern/PacifiCorp East NF 7/8 LAGRANDE BPAT.NWMT725TransAlta Energy Marketing(US) Inc.Bonneville Power Administration PacifiCorp East NF 7/8 LAGRANDE BRDY726TransAlta Energy Marketing(US) Inc.Bonneville Power Administration PacifiCorp West NF 7/8 LAGRANDE HURR727TransAlta Energy Marketing(US) Inc.Bonneville Power Administration PacifiCorp East NF 7/8 LAGRANDE JBSN728TransAlta Energy Marketing(US) Inc.Bonneville Power Administration Avista NF 7/8 LAGRANDE LOLO729TransAlta Energy Marketing(US) Inc.Bonneville Power Administration Sierra Pacific Power NF 7/8 LAGRANDE M345730TransAlta Energy Marketing(US) Inc.Avista PacifiCorp East NF 7/8 LOLO BORA731TransAlta Energy Marketing(US) Inc.Avista NorthWestern/PacifiCorp East NF 7/8 LOLO BPAT.NWMT732TransAlta Energy Marketing(US) Inc.Avista PacifiCorp East NF 7/8 LOLO BRDY733TransAlta Energy Marketing(US) Inc.Avista Sierra Pacific Power NF 7/8 LOLO M345734TransAlta Energy Marketing(US) Inc.Sierra Pacific Power PacifiCorp West NF 7/8 M345 H500735TransAlta Energy Marketing(US) Inc.Sierra Pacific Power PacifiCorp West NF 7/8 M345 HURR736TransAlta Energy Marketing(US) Inc.Sierra Pacific Power Bonneville Power Administration NF 7/8 M345 LAGRANDE737TransAlta Energy Marketing(US) Inc.Sierra Pacific Power Bonneville Power Administration SFP 7/8 M345 LAGRANDE738TransAlta Energy Marketing(US) Inc.Sierra Pacific Power Avista NF 7/8 M345 LOLO739TransAlta Energy Marketing(US) Inc.PacifiCorp West PacifiCorp East NF 7/8 SMLK BORATRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456.1) (Including transactions referred to as "wheeling")LineNo.Payment By (Company of PublicAuthority) (Footnote Affiliation)(a)Energy Received From (Company ofPublic Authority) (FootnoteAffiliation)(b)Energy Delivered To (Company ofPublic Authority) (FootnoteAffiliation)(c)StatisticalClassification(d)Ferc RateSchedule ofTariff Number(e)Point of Receipt(Substation orOtherDesignation)(f)Point ofDelivery(Substation orOtherDesignation)(g)FERC FORM NO. 1 (ED. 12-90)Page 328-330
740 TransAlta Energy Marketing
(US) Inc.PacifiCorp West Sierra Pacific Power NF 7/8 SMLK M345
741 TransAlta Energy Marketing
(US) Inc.Idaho Power Company PacifiCorp East NF 7/8 WALLAWALLA BORA
742 TransAlta Energy Marketing
(US) Inc.Idaho Power Company PacifiCorp East NF 7/8 WALLAWALLA JBSN
743 TransAlta Energy Marketing
(US) Inc.Idaho Power Company Sierra Pacific Power NF 7/8 WALLAWALLA M345
744 Vitol Inc.PacifiCorp East Sierra Pacific Power NF 7/8 BRDY M345
745 Vitol Inc.PacifiCorp East Sierra Pacific Power SFP 7/8 BRDY M345
746 Vitol Inc.PacifiCorp East NorthWestern/PacifiCorp East NF 7/8 JBSN MLCK
747 Vitol Inc.PacifiCorp East Sierra Pacific Power NF 7/8 JEFF M345
748 Vitol Inc.Idaho Power Company Sierra Pacific Power NF 7/8 WALLAWALLA M345
749 West Hines Solar, LLC Bonneville Power Administration Bonneville Power Administration NF 7/8 LAGRANDE LAGRANDE
750 Willow Springs Windfarm, LLC NF 11
35 TOTAL
FERC FORM NO. 1 (ED. 12-90)
Page 328-330
TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456.1) (Including transactions referred to as "wheeling")
Line
No.
Payment By (Company of Public
Authority) (Footnote Affiliation)
(a)
Energy Received From (Company of
Public Authority) (Footnote
Affiliation)
(b)
Energy Delivered To (Company of
Public Authority) (Footnote
Affiliation)
(c)
Statistical
Classification
(d)
Ferc Rate
Schedule of
Tariff Number
(e)
Point of Receipt
(Substation or
Other
Designation)
(f)
Point of
Delivery
(Substation or
Other
Designation)
(g)
TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456.1) (Including transactions referred to as "wheeling")
TRANSFER OF ENERGY TRANSFER OF ENERGY
REVENUE FROM
TRANSMISSION OF
ELECTRICITY FOR
REVENUE FROM
TRANSMISSION OF
ELECTRICITY FOR
REVENUE FROM
TRANSMISSION OF
ELECTRICITY FOR
REVENUE
FROM
TRANSMISSION
OF
FERC FORM NO. 1 (ED. 12-90)
Page 328-330
740 TransAlta Energy Marketing(US) Inc.PacifiCorp West Sierra Pacific Power NF 7/8 SMLK M345741TransAlta Energy Marketing(US) Inc.Idaho Power Company PacifiCorp East NF 7/8 WALLAWALLA BORA742TransAlta Energy Marketing(US) Inc.Idaho Power Company PacifiCorp East NF 7/8 WALLAWALLA JBSN743TransAlta Energy Marketing(US) Inc.Idaho Power Company Sierra Pacific Power NF 7/8 WALLAWALLA M345744Vitol Inc.PacifiCorp East Sierra Pacific Power NF 7/8 BRDY M345745Vitol Inc.PacifiCorp East Sierra Pacific Power SFP 7/8 BRDY M345746Vitol Inc.PacifiCorp East NorthWestern/PacifiCorp East NF 7/8 JBSN MLCK747Vitol Inc.PacifiCorp East Sierra Pacific Power NF 7/8 JEFF M345748Vitol Inc.Idaho Power Company Sierra Pacific Power NF 7/8 WALLAWALLA M345749West Hines Solar, LLC Bonneville Power Administration Bonneville Power Administration NF 7/8 LAGRANDE LAGRANDE750Willow Springs Windfarm, LLC NF 1135TOTALFERC FORM NO. 1 (ED. 12-90)Page 328-330TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456.1) (Including transactions referred to as "wheeling")LineNo.Payment By (Company of PublicAuthority) (Footnote Affiliation)(a)Energy Received From (Company ofPublic Authority) (FootnoteAffiliation)(b)Energy Delivered To (Company ofPublic Authority) (FootnoteAffiliation)(c)StatisticalClassification(d)Ferc RateSchedule ofTariff Number(e)Point of Receipt(Substation orOtherDesignation)(f)Point ofDelivery(Substation orOtherDesignation)(g)
TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456.1) (Including transactions referred to as "wheeling")
TRANSFER OF ENERGY TRANSFER OF ENERGY
REVENUE FROM
TRANSMISSION OF
ELECTRICITY FOR
REVENUE FROM
TRANSMISSION OF
ELECTRICITY FOR
REVENUE FROM
TRANSMISSION OF
ELECTRICITY FOR
REVENUE
FROM
TRANSMISSION
OF
FERC FORM NO. 1 (ED. 12-90)
Page 328-330
TRANSFER OF ENERGY TRANSFER OF ENERGY ELECTRICITY FOR
OTHERS
ELECTRICITY FOR
OTHERS
ELECTRICITY FOR
OTHERS
OF
ELECTRICITY
FOR OTHERS
Line
No.
Billing Demand (MW)
(h)
Megawatt Hours
Received
(i)
Megawatt Hours
Delivered
(j)
Demand Charges ($)
(k)
Energy Charges ($)
(l)
Other Charges ($)
(m)
Total Revenues
($) (k+l+m)
(n)
1 (m)363,434 363,434 1,941,522 138,060 2,079,582
2 40,219 40,219 1,534,652 150,804 1,685,456
3 1,421,596 1,421,596 7,247,051 480,284 7,727,335
4 9,778 9,778 15,831 15,831
5 331,841 331,841 108,394 108,394
6 2,223 2,223 12,602 957 13,559
7 14,350 14,350 55,022 55,022
8 0 0 2,938 2,938
9 272,509 272,509 4,531,221 4,531,221
10 268,210 268,210 3,874,975 3,874,975
11 1,605,221 1,605,221 7,531,202 7,531,202
12 32,337 32,337 3,156,230 3,156,230
13 85,198 85,198 3,124,980 3,124,980
14 450,418 450,418 3,124,980 3,124,980
15 280,605 280,605 6,249,960 6,249,960
16 82,491 82,491 2,218,736 2,218,736
17 0 0 62,500 62,500
18 7,944 7,944 62,500 62,500
19 10 10 36 36
20 0 0 1,309 1,309
21 0 0 1,309 1,309
22 148 148 1,479 1,479
23 1,451 1,451 14,501 14,501
24 101 101 1,009 1,009
25 204 204 2,039 2,039
26 112 112 1,119 1,119
27 192 192 1,919 1,919
28 527 527 5,267 5,267
29 101 101 1,009 1,009
30 6,890 6,890 68,856 68,856
31 725 725 7,245 7,245
32 172 172 878 878
33 25 25 128 128
34 1,288 1,288 6,577 6,577
35 1,070 1,070 5,464 5,464
36 100 100 511 511
37 52 52 493 493
38 150 150 1,422 1,422
39 13 13 123 123
40 56 56 531 531
41 1,409 1,409 13,359 13,359
42 329 329 3,119 3,119
FERC FORM NO. 1 (ED. 12-90)
Page 328-330
TRANSFER OF ENERGY TRANSFER OF ENERGY ELECTRICITY FOROTHERS ELECTRICITY FOROTHERS ELECTRICITY FOROTHERS OFELECTRICITYFOR OTHERSLineNo.Billing Demand (MW)(h)Megawatt HoursReceived(i)Megawatt HoursDelivered(j)Demand Charges ($)(k)Energy Charges ($)(l)Other Charges ($)(m)Total Revenues($) (k+l+m)(n)1 (m)363,434 363,434 1,941,522 138,060 2,079,582240,219 40,219 1,534,652 150,804 1,685,45631,421,596 1,421,596 7,247,051 480,284 7,727,33549,778 9,778 15,831 15,8315331,841 331,841 108,394 108,39462,223 2,223 12,602 957 13,559714,350 14,350 55,022 55,0228002,938 2,9389272,509 272,509 4,531,221 4,531,22110268,210 268,210 3,874,975 3,874,975111,605,221 1,605,221 7,531,202 7,531,2021232,337 32,337 3,156,230 3,156,2301385,198 85,198 3,124,980 3,124,98014450,418 450,418 3,124,980 3,124,98015280,605 280,605 6,249,960 6,249,9601682,491 82,491 2,218,736 2,218,736170062,500 62,500187,944 7,944 62,500 62,500191010363620001,309 1,30921001,309 1,309221481481,479 1,479231,451 1,451 14,501 14,501241011011,009 1,009252042042,039 2,039261121121,119 1,119271921921,919 1,919285275275,267 5,267291011011,009 1,009306,890 6,890 68,856 68,856317257257,245 7,24532172172878878332525128128341,288 1,288 6,577 6,577351,070 1,070 5,464 5,46436100100511511375252493493381501501,422 1,422391313123123405656531531411,409 1,409 13,359 13,359423293293,119 3,119FERC FORM NO. 1 (ED. 12-90)Page 328-330
43 1 1 9 9
44 0 0 4,843 4,843
45 50 50 314 314
46 14 14 88 88
47 106 106 666 666
48 366 366 2,299 2,299
49 5 5 31 31
50 572 572 3,593 3,593
51 6,257 6,257 39,302 39,302
52 1,479 1,479 9,290 9,290
53 3,078 3,078 19,334 19,334
54 1,355 1,355 8,511 8,511
55 1,975 1,975 12,405 12,405
56 2,682 2,682 16,846 16,846
57 32 32 201 201
58 2 2 13 13
59 1,088 1,088 6,834 6,834
60 709 709 4,453 4,453
61 275 275 2,506 2,506
62 164 164 7,373 7,373
63 21 21 944 944
64 1 1 45 45
65 581 581 7,101 7,101
66 581 581 7,101 7,101
67 1,546 1,546 18,896 18,896
68 360 360 4,400 4,400
69 1,170 1,170 8,690 8,690
70 29 29 215 215
71 80 80 594 594
72 602 602 4,471 4,471
73 400 400 3,019 3,019
74 15 15 113 113
75 86 86 649 649
76 58 58 438 438
77 0 0 4,843 4,843
78 300 300 5,098 5,098
79 164 164 2,787 2,787
80 351 351 5,965 5,965
81 600 600 10,196 10,196
82 311 311 5,285 5,285
83 1,127 1,127 19,152 19,152
84 131 131 2,226 2,226
TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456.1) (Including transactions referred to as "wheeling")
TRANSFER OF ENERGY TRANSFER OF ENERGY
REVENUE FROM
TRANSMISSION OF
ELECTRICITY FOR
OTHERS
REVENUE FROM
TRANSMISSION OF
ELECTRICITY FOR
OTHERS
REVENUE FROM
TRANSMISSION OF
ELECTRICITY FOR
OTHERS
REVENUE
FROM
TRANSMISSION
OF
ELECTRICITY
FOR OTHERS
Line
No.
Billing Demand (MW)
(h)
Megawatt Hours
Received
(i)
Megawatt Hours
Delivered
(j)
Demand Charges ($)
(k)
Energy Charges ($)
(l)
Other Charges ($)
(m)
Total Revenues
($) (k+l+m)
(n)
FERC FORM NO. 1 (ED. 12-90)
Page 328-330
43 1 1 9 944004,843 4,843455050314314461414888847106106666666483663662,299 2,29949553131505725723,593 3,593516,257 6,257 39,302 39,302521,479 1,479 9,290 9,290533,078 3,078 19,334 19,334541,355 1,355 8,511 8,511551,975 1,975 12,405 12,405562,682 2,682 16,846 16,84657323220120158221313591,088 1,088 6,834 6,834607097094,453 4,453612752752,506 2,506621641647,373 7,37363212194494464114545655815817,101 7,101665815817,101 7,101671,546 1,546 18,896 18,896683603604,400 4,400691,170 1,170 8,690 8,690702929215215718080594594726026024,471 4,471734004003,019 3,01974151511311375868664964976585843843877004,843 4,843783003005,098 5,098791641642,787 2,787803513515,965 5,9658160060010,196 10,196823113115,285 5,285831,127 1,127 19,152 19,152841311312,226 2,226TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456.1) (Including transactions referred to as "wheeling")TRANSFER OF ENERGY TRANSFER OF ENERGY REVENUE FROMTRANSMISSION OFELECTRICITY FOROTHERS REVENUE FROMTRANSMISSION OFELECTRICITY FOROTHERS REVENUE FROMTRANSMISSION OFELECTRICITY FOROTHERS REVENUEFROMTRANSMISSIONOFELECTRICITYFOR OTHERSLineNo.Billing Demand (MW)(h)Megawatt HoursReceived(i)Megawatt HoursDelivered(j)Demand Charges ($)(k)Energy Charges ($)(l)Other Charges ($)(m)Total Revenues($) (k+l+m)(n)FERC FORM NO. 1 (ED. 12-90)Page 328-330
85 3,280 3,280 55,739 55,739
86 336 336 5,710 5,710
87 64 64 1,088 1,088
88 3,334 3,334 56,656 56,656
89 340 340 5,778 5,778
90 233 233 3,959 3,959
91 120 120 2,039 2,039
92 75 75 1,275 1,275
93 31,730 31,730 539,202 539,202
94 207 207 3,518 3,518
95 1,896 1,896 32,220 32,220
96 900 900 15,294 15,294
97 552 552 9,380 9,380
98 4,931 4,931 83,795 83,795
99 535 535 9,091 9,091
100 486 486 8,259 8,259
101 8,344 8,344 141,793 141,793
102 4,512 4,512 76,674 76,674
103 15,426 15,426 262,141 262,141
104 15 15 255 255
105 1,074 1,074 18,251 18,251
106 274 274 4,656 4,656
107 2,667 2,667 45,322 45,322
108 230 230 3,908 3,908
109 675 675 11,471 11,471
110 1,732 1,732 29,433 29,433
111 200 200 3,399 3,399
112 94 94 1,597 1,597
113 706 706 11,997 11,997
114 37,583 37,583 638,665 638,665
115 127 127 2,158 2,158
116 125 125 2,124 2,124
117 367 367 6,237 6,237
118 336 336 5,710 5,710
119 1,162 1,162 19,746 19,746
120 12,418 12,418 211,025 211,025
121 95 95 1,614 1,614
122 25 25 161 161
123 890 890 5,532 5,532
124 3,434 3,434 21,345 21,345
125 60 60 373 373
126 8,363 8,363 51,981 51,981
TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456.1) (Including transactions referred to as "wheeling")
TRANSFER OF ENERGY TRANSFER OF ENERGY
REVENUE FROM
TRANSMISSION OF
ELECTRICITY FOR
OTHERS
REVENUE FROM
TRANSMISSION OF
ELECTRICITY FOR
OTHERS
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OTHERS
REVENUE
FROM
TRANSMISSION
OF
ELECTRICITY
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Line
No.
Billing Demand (MW)
(h)
Megawatt Hours
Received
(i)
Megawatt Hours
Delivered
(j)
Demand Charges ($)
(k)
Energy Charges ($)
(l)
Other Charges ($)
(m)
Total Revenues
($) (k+l+m)
(n)
FERC FORM NO. 1 (ED. 12-90)
Page 328-330
85 3,280 3,280 55,739 55,739863363365,710 5,7108764641,088 1,088883,334 3,334 56,656 56,656893403405,778 5,778902332333,959 3,959911201202,039 2,0399275751,275 1,2759331,730 31,730 539,202 539,202942072073,518 3,518951,896 1,896 32,220 32,2209690090015,294 15,294975525529,380 9,380984,931 4,931 83,795 83,795995355359,091 9,0911004864868,259 8,2591018,344 8,344 141,793 141,7931024,512 4,512 76,674 76,67410315,426 15,426 262,141 262,14110415152552551051,074 1,074 18,251 18,2511062742744,656 4,6561072,667 2,667 45,322 45,3221082302303,908 3,90810967567511,471 11,4711101,732 1,732 29,433 29,4331112002003,399 3,39911294941,597 1,59711370670611,997 11,99711437,583 37,583 638,665 638,6651151271272,158 2,1581161251252,124 2,1241173673676,237 6,2371183363365,710 5,7101191,162 1,162 19,746 19,74612012,418 12,418 211,025 211,02512195951,614 1,61412225251611611238908905,532 5,5321243,434 3,434 21,345 21,34512560603733731268,363 8,363 51,981 51,981TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456.1) (Including transactions referred to as "wheeling")TRANSFER OF ENERGY TRANSFER OF ENERGY REVENUE FROMTRANSMISSION OFELECTRICITY FOROTHERS REVENUE FROMTRANSMISSION OFELECTRICITY FOROTHERS REVENUE FROMTRANSMISSION OFELECTRICITY FOROTHERS REVENUEFROMTRANSMISSIONOFELECTRICITYFOR OTHERSLineNo.Billing Demand (MW)(h)Megawatt HoursReceived(i)Megawatt HoursDelivered(j)Demand Charges ($)(k)Energy Charges ($)(l)Other Charges ($)(m)Total Revenues($) (k+l+m)(n)FERC FORM NO. 1 (ED. 12-90)Page 328-330
127 36,829 36,829 228,916 228,916
128 75 75 466 466
129 1,995 1,995 12,400 12,400
130 872 872 5,420 5,420
131 9,237 9,237 57,414 57,414
132 717 717 4,457 4,457
133 18,049 18,049 112,186 112,186
134 306 306 1,902 1,902
135 375 375 2,331 2,331
136 277 277 1,722 1,722
137 25 25 155 155
138 969 969 6,023 6,023
139 154 154 957 957
140 323 323 2,008 2,008
141 125 125 777 777
142 200 200 1,243 1,243
143 0 0 101 101
144 84 84 494 494
145 12 12 71 71
146 403 403 2,368 2,368
147 159 159 934 934
148 1,940 1,940 11,401 11,401
149 5,636 5,636 33,123 33,123
150 840 840 4,937 4,937
151 25 25 147 147
152 49 49 288 288
153 208 208 1,222 1,222
154 3,260 3,260 19,159 19,159
155 1,986 1,986 11,672 11,672
156 15 15 88 88
157 91 91 535 535
158 50 50 294 294
159 85 85 500 500
160 7,931 7,931 46,611 46,611
161 3,279 3,279 19,271 19,271
162 207 207 1,217 1,217
163 62 62 364 364
164 4 4 24 24
165 61 61 358 358
166 572 572 3,362 3,362
167 6,803 6,803 39,981 39,981
168 464 464 2,727 2,727
TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456.1) (Including transactions referred to as "wheeling")
TRANSFER OF ENERGY TRANSFER OF ENERGY
REVENUE FROM
TRANSMISSION OF
ELECTRICITY FOR
OTHERS
REVENUE FROM
TRANSMISSION OF
ELECTRICITY FOR
OTHERS
REVENUE FROM
TRANSMISSION OF
ELECTRICITY FOR
OTHERS
REVENUE
FROM
TRANSMISSION
OF
ELECTRICITY
FOR OTHERS
Line
No.
Billing Demand (MW)
(h)
Megawatt Hours
Received
(i)
Megawatt Hours
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(j)
Demand Charges ($)
(k)
Energy Charges ($)
(l)
Other Charges ($)
(m)
Total Revenues
($) (k+l+m)
(n)
FERC FORM NO. 1 (ED. 12-90)
Page 328-330
127 36,829 36,829 228,916 228,91612875754664661291,995 1,995 12,400 12,4001308728725,420 5,4201319,237 9,237 57,414 57,4141327177174,457 4,45713318,049 18,049 112,186 112,1861343063061,902 1,9021353753752,331 2,3311362772771,722 1,72213725251551551389699696,023 6,0231391541549579571403233232,008 2,0081411251257777771422002001,243 1,243143001011011448484494494145121271711464034032,368 2,3681471591599349341481,940 1,940 11,401 11,4011495,636 5,636 33,123 33,1231508408404,937 4,937151252514714715249492882881532082081,222 1,2221543,260 3,260 19,159 19,1591551,986 1,986 11,672 11,672156151588881579191535535158505029429415985855005001607,931 7,931 46,611 46,6111613,279 3,279 19,271 19,2711622072071,217 1,217163626236436416444242416561613583581665725723,362 3,3621676,803 6,803 39,981 39,9811684644642,727 2,727TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456.1) (Including transactions referred to as "wheeling")TRANSFER OF ENERGY TRANSFER OF ENERGY REVENUE FROMTRANSMISSION OFELECTRICITY FOROTHERS REVENUE FROMTRANSMISSION OFELECTRICITY FOROTHERS REVENUE FROMTRANSMISSION OFELECTRICITY FOROTHERS REVENUEFROMTRANSMISSIONOFELECTRICITYFOR OTHERSLineNo.Billing Demand (MW)(h)Megawatt HoursReceived(i)Megawatt HoursDelivered(j)Demand Charges ($)(k)Energy Charges ($)(l)Other Charges ($)(m)Total Revenues($) (k+l+m)(n)FERC FORM NO. 1 (ED. 12-90)Page 328-330
169 608 608 3,573 3,573
170 480 480 2,821 2,821
171 236 236 1,387 1,387
172 22 22 129 129
173 50 50 294 294
174 230 230 1,352 1,352
175 212 212 1,246 1,246
176 653 653 3,838 3,838
177 190 190 1,117 1,117
178 3,497 3,497 20,552 20,552
179 39,927 39,927 234,652 234,652
180 45 45 264 264
181 1,741 1,741 10,232 10,232
182 300 300 1,763 1,763
183 262 262 1,540 1,540
184 367 367 2,157 2,157
185 35 35 206 206
186 124 124 729 729
187 179 179 1,052 1,052
188 92 92 541 541
189 1,141 1,141 6,706 6,706
190 232 232 1,363 1,363
191 282 282 1,657 1,657
192 484 484 2,844 2,844
193 1,965 1,965 11,548 11,548
194 9,532 9,532 56,020 56,020
195 151 151 887 887
196 17 17 100 100
197 165 165 970 970
198 0 0 5,199 5,199
199 0 0 5,199 5,199
200 0 0 5,199 5,199
201 0 0 5,199 5,199
202 0 0 5,199 5,199
203 0 0 5,199 5,199
204 0 0 4,843 4,843
205 0 0 2,662 2,662
206 90 90 2,888 2,888
207 100 100 3,209 3,209
208 403 403 12,931 12,931
209 112 112 3,594 3,594
210 547 547 17,552 17,552
TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456.1) (Including transactions referred to as "wheeling")
TRANSFER OF ENERGY TRANSFER OF ENERGY
REVENUE FROM
TRANSMISSION OF
ELECTRICITY FOR
OTHERS
REVENUE FROM
TRANSMISSION OF
ELECTRICITY FOR
OTHERS
REVENUE FROM
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ELECTRICITY FOR
OTHERS
REVENUE
FROM
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OF
ELECTRICITY
FOR OTHERS
Line
No.
Billing Demand (MW)
(h)
Megawatt Hours
Received
(i)
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(j)
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(k)
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(l)
Other Charges ($)
(m)
Total Revenues
($) (k+l+m)
(n)
FERC FORM NO. 1 (ED. 12-90)
Page 328-330
169 608 608 3,573 3,5731704804802,821 2,8211712362361,387 1,387172222212912917350502942941742302301,352 1,3521752122121,246 1,2461766536533,838 3,8381771901901,117 1,1171783,497 3,497 20,552 20,55217939,927 39,927 234,652 234,65218045452642641811,741 1,741 10,232 10,2321823003001,763 1,7631832622621,540 1,5401843673672,157 2,15718535352062061861241247297291871791791,052 1,05218892925415411891,141 1,141 6,706 6,7061902322321,363 1,3631912822821,657 1,6571924844842,844 2,8441931,965 1,965 11,548 11,5481949,532 9,532 56,020 56,0201951511518878871961717100100197165165970970198005,199 5,199199005,199 5,199200005,199 5,199201005,199 5,199202005,199 5,199203005,199 5,199204004,843 4,843205002,662 2,66220690902,888 2,8882071001003,209 3,20920840340312,931 12,9312091121123,594 3,59421054754717,552 17,552TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456.1) (Including transactions referred to as "wheeling")TRANSFER OF ENERGY TRANSFER OF ENERGY REVENUE FROMTRANSMISSION OFELECTRICITY FOROTHERS REVENUE FROMTRANSMISSION OFELECTRICITY FOROTHERS REVENUE FROMTRANSMISSION OFELECTRICITY FOROTHERS REVENUEFROMTRANSMISSIONOFELECTRICITYFOR OTHERSLineNo.Billing Demand (MW)(h)Megawatt HoursReceived(i)Megawatt HoursDelivered(j)Demand Charges ($)(k)Energy Charges ($)(l)Other Charges ($)(m)Total Revenues($) (k+l+m)(n)FERC FORM NO. 1 (ED. 12-90)Page 328-330
211 3,444 3,444 110,507 110,507
212 823 823 26,408 26,408
213 64 64 2,054 2,054
214 720 720 23,103 23,103
215 1 1 32 32
216 513 513 16,461 16,461
217 25 25 802 802
218 245 245 7,861 7,861
219 19 19 610 610
220 400 400 12,835 12,835
221 1,075 1,075 34,493 34,493
222 16 16 513 513
223 18 18 578 578
224 30 30 963 963
225 28 28 898 898
226 119 119 3,818 3,818
227 144 144 4,621 4,621
228 7 7 225 225
229 7,040 7,040 225,892 225,892
230 850 850 27,274 27,274
231 623 623 19,990 19,990
232 3,295 3,295 105,726 105,726
233 2,024 2,024 64,944 64,944
234 13,172 13,172 422,648 422,648
235 246 246 7,893 7,893
236 7,264 7,264 233,079 233,079
237 16 16 513 513
238 25 25 154 154
239 1 1 6 6
240 15 15 92 92
241 44,843 44,843 276,403 276,403
242 427 427 2,632 2,632
243 4,935 4,935 30,418 30,418
244 1,387 1,387 8,549 8,549
245 306 306 1,886 1,886
246 1 1 6 6
247 520 520 15,426 15,426
248 149 149 4,420 4,420
249 38 38 1,127 1,127
250 18 18 534 534
251 1,910 1,910 56,661 56,661
252 60 60 1,780 1,780
TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456.1) (Including transactions referred to as "wheeling")
TRANSFER OF ENERGY TRANSFER OF ENERGY
REVENUE FROM
TRANSMISSION OF
ELECTRICITY FOR
OTHERS
REVENUE FROM
TRANSMISSION OF
ELECTRICITY FOR
OTHERS
REVENUE FROM
TRANSMISSION OF
ELECTRICITY FOR
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REVENUE
FROM
TRANSMISSION
OF
ELECTRICITY
FOR OTHERS
Line
No.
Billing Demand (MW)
(h)
Megawatt Hours
Received
(i)
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(j)
Demand Charges ($)
(k)
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(l)
Other Charges ($)
(m)
Total Revenues
($) (k+l+m)
(n)
FERC FORM NO. 1 (ED. 12-90)
Page 328-330
211 3,444 3,444 110,507 110,50721282382326,408 26,40821364642,054 2,05421472072023,103 23,10321511323221651351316,461 16,46121725258028022182452457,861 7,861219191961061022040040012,835 12,8352211,075 1,075 34,493 34,49322216165135132231818578578224303096396322528288988982261191193,818 3,8182271441444,621 4,621228772252252297,040 7,040 225,892 225,89223085085027,274 27,27423162362319,990 19,9902323,295 3,295 105,726 105,7262332,024 2,024 64,944 64,94423413,172 13,172 422,648 422,6482352462467,893 7,8932367,264 7,264 233,079 233,0792371616513513238252515415423911662401515929224144,843 44,843 276,403 276,4032424274272,632 2,6322434,935 4,935 30,418 30,4182441,387 1,387 8,549 8,5492453063061,886 1,886246116624752052015,426 15,4262481491494,420 4,42024938381,127 1,12725018185345342511,910 1,910 56,661 56,66125260601,780 1,780TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456.1) (Including transactions referred to as "wheeling")TRANSFER OF ENERGY TRANSFER OF ENERGY REVENUE FROMTRANSMISSION OFELECTRICITY FOROTHERS REVENUE FROMTRANSMISSION OFELECTRICITY FOROTHERS REVENUE FROMTRANSMISSION OFELECTRICITY FOROTHERS REVENUEFROMTRANSMISSIONOFELECTRICITYFOR OTHERSLineNo.Billing Demand (MW)(h)Megawatt HoursReceived(i)Megawatt HoursDelivered(j)Demand Charges ($)(k)Energy Charges ($)(l)Other Charges ($)(m)Total Revenues($) (k+l+m)(n)FERC FORM NO. 1 (ED. 12-90)Page 328-330
253 300 300 8,900 8,900
254 3,217 3,217 95,433 95,433
255 20 20 593 593
256 49 49 1,454 1,454
257 11,541 11,541 342,366 342,366
258 0 0 2,618 2,618
259 757 757 5,013 5,013
260 6 6 40 40
261 472 472 3,126 3,126
262 3,447 3,447 22,826 22,826
263 1,189 1,189 7,873 7,873
264 657 657 4,351 4,351
265 2,398 2,398 15,879 15,879
266 13,177 13,177 87,257 87,257
267 3,437 3,437 22,759 22,759
268 6,283 6,283 41,605 41,605
269 30,700 30,700 203,292 203,292
270 1,978 1,978 13,098 13,098
271 26,421 26,421 174,957 174,957
272 470 470 3,112 3,112
273 9,748 9,748 64,550 64,550
274 14 14 93 93
275 998 998 6,609 6,609
276 3,562 3,562 23,587 23,587
277 921 921 6,099 6,099
278 6,974 6,974 46,181 46,181
279 50,648 50,648 335,385 335,385
280 364 364 2,410 2,410
281 1,241 1,241 8,218 8,218
282 3,467 3,467 22,958 22,958
283 51 51 338 338
284 525 525 3,476 3,476
285 5,440 5,440 36,023 36,023
286 3,177 3,177 21,038 21,038
287 1,200 1,200 7,946 7,946
288 24,114 24,114 159,680 159,680
289 22,211 22,211 147,079 147,079
290 282 282 1,867 1,867
291 200 200 1,324 1,324
292 104 104 689 689
293 350 350 2,318 2,318
294 240 240 1,589 1,589
TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456.1) (Including transactions referred to as "wheeling")
TRANSFER OF ENERGY TRANSFER OF ENERGY
REVENUE FROM
TRANSMISSION OF
ELECTRICITY FOR
OTHERS
REVENUE FROM
TRANSMISSION OF
ELECTRICITY FOR
OTHERS
REVENUE FROM
TRANSMISSION OF
ELECTRICITY FOR
OTHERS
REVENUE
FROM
TRANSMISSION
OF
ELECTRICITY
FOR OTHERS
Line
No.
Billing Demand (MW)
(h)
Megawatt Hours
Received
(i)
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(j)
Demand Charges ($)
(k)
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(l)
Other Charges ($)
(m)
Total Revenues
($) (k+l+m)
(n)
FERC FORM NO. 1 (ED. 12-90)
Page 328-330
253 300 300 8,900 8,9002543,217 3,217 95,433 95,433255202059359325649491,454 1,45425711,541 11,541 342,366 342,366258002,618 2,6182597577575,013 5,0132606640402614724723,126 3,1262623,447 3,447 22,826 22,8262631,189 1,189 7,873 7,8732646576574,351 4,3512652,398 2,398 15,879 15,87926613,177 13,177 87,257 87,2572673,437 3,437 22,759 22,7592686,283 6,283 41,605 41,60526930,700 30,700 203,292 203,2922701,978 1,978 13,098 13,09827126,421 26,421 174,957 174,9572724704703,112 3,1122739,748 9,748 64,550 64,550274141493932759989986,609 6,6092763,562 3,562 23,587 23,5872779219216,099 6,0992786,974 6,974 46,181 46,18127950,648 50,648 335,385 335,3852803643642,410 2,4102811,241 1,241 8,218 8,2182823,467 3,467 22,958 22,95828351513383382845255253,476 3,4762855,440 5,440 36,023 36,0232863,177 3,177 21,038 21,0382871,200 1,200 7,946 7,94628824,114 24,114 159,680 159,68028922,211 22,211 147,079 147,0792902822821,867 1,8672912002001,324 1,3242921041046896892933503502,318 2,3182942402401,589 1,589TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456.1) (Including transactions referred to as "wheeling")TRANSFER OF ENERGY TRANSFER OF ENERGY REVENUE FROMTRANSMISSION OFELECTRICITY FOROTHERS REVENUE FROMTRANSMISSION OFELECTRICITY FOROTHERS REVENUE FROMTRANSMISSION OFELECTRICITY FOROTHERS REVENUEFROMTRANSMISSIONOFELECTRICITYFOR OTHERSLineNo.Billing Demand (MW)(h)Megawatt HoursReceived(i)Megawatt HoursDelivered(j)Demand Charges ($)(k)Energy Charges ($)(l)Other Charges ($)(m)Total Revenues($) (k+l+m)(n)FERC FORM NO. 1 (ED. 12-90)Page 328-330
295 2,041 2,041 13,515 13,515
296 1,353 1,353 8,959 8,959
297 10,173 10,173 67,364 67,364
298 1,868 1,868 12,370 12,370
299 622 622 4,119 4,119
300 2,998 2,998 19,852 19,852
301 1,097 1,097 7,264 7,264
302 143 143 947 947
303 19,911 19,911 131,848 131,848
304 960 960 6,357 6,357
305 474 474 3,139 3,139
306 409 409 2,708 2,708
307 3,048 3,048 20,184 20,184
308 2,923 2,923 19,356 19,356
309 5,030 5,030 33,308 33,308
310 620 620 4,106 4,106
311 65 65 430 430
312 16 16 106 106
313 7,695 7,695 50,955 50,955
314 201 201 1,331 1,331
315 2,241 2,241 14,840 14,840
316 7,859 7,859 52,041 52,041
317 20,172 20,172 133,577 133,577
318 74 74 490 490
319 100 100 744 744
320 3,117 3,117 23,194 23,194
321 4,204 4,204 31,283 31,283
322 67 67 499 499
323 35,100 35,100 261,186 261,186
324 1,545 1,545 11,497 11,497
325 80 80 595 595
326 7,867 7,867 58,540 58,540
327 13,016 13,016 96,855 96,855
328 15,014 15,014 111,722 111,722
329 10,008 10,008 74,472 74,472
330 390 390 2,902 2,902
331 3,660 3,660 27,235 27,235
332 1,221 1,221 9,086 9,086
333 38 38 283 283
334 400 400 2,811 2,811
335 804 804 5,650 5,650
336 5,302 5,302 37,261 37,261
TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456.1) (Including transactions referred to as "wheeling")
TRANSFER OF ENERGY TRANSFER OF ENERGY
REVENUE FROM
TRANSMISSION OF
ELECTRICITY FOR
OTHERS
REVENUE FROM
TRANSMISSION OF
ELECTRICITY FOR
OTHERS
REVENUE FROM
TRANSMISSION OF
ELECTRICITY FOR
OTHERS
REVENUE
FROM
TRANSMISSION
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FOR OTHERS
Line
No.
Billing Demand (MW)
(h)
Megawatt Hours
Received
(i)
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(j)
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(k)
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(l)
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(m)
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($) (k+l+m)
(n)
FERC FORM NO. 1 (ED. 12-90)
Page 328-330
295 2,041 2,041 13,515 13,5152961,353 1,353 8,959 8,95929710,173 10,173 67,364 67,3642981,868 1,868 12,370 12,3702996226224,119 4,1193002,998 2,998 19,852 19,8523011,097 1,097 7,264 7,26430214314394794730319,911 19,911 131,848 131,8483049609606,357 6,3573054744743,139 3,1393064094092,708 2,7083073,048 3,048 20,184 20,1843082,923 2,923 19,356 19,3563095,030 5,030 33,308 33,3083106206204,106 4,106311656543043031216161061063137,695 7,695 50,955 50,9553142012011,331 1,3313152,241 2,241 14,840 14,8403167,859 7,859 52,041 52,04131720,172 20,172 133,577 133,57731874744904903191001007447443203,117 3,117 23,194 23,1943214,204 4,204 31,283 31,283322676749949932335,100 35,100 261,186 261,1863241,545 1,545 11,497 11,49732580805955953267,867 7,867 58,540 58,54032713,016 13,016 96,855 96,85532815,014 15,014 111,722 111,72232910,008 10,008 74,472 74,4723303903902,902 2,9023313,660 3,660 27,235 27,2353321,221 1,221 9,086 9,08633338382832833344004002,811 2,8113358048045,650 5,6503365,302 5,302 37,261 37,261TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456.1) (Including transactions referred to as "wheeling")TRANSFER OF ENERGY TRANSFER OF ENERGY REVENUE FROMTRANSMISSION OFELECTRICITY FOROTHERS REVENUE FROMTRANSMISSION OFELECTRICITY FOROTHERS REVENUE FROMTRANSMISSION OFELECTRICITY FOROTHERS REVENUEFROMTRANSMISSIONOFELECTRICITYFOR OTHERSLineNo.Billing Demand (MW)(h)Megawatt HoursReceived(i)Megawatt HoursDelivered(j)Demand Charges ($)(k)Energy Charges ($)(l)Other Charges ($)(m)Total Revenues($) (k+l+m)(n)FERC FORM NO. 1 (ED. 12-90)Page 328-330
337 2,600 2,600 18,272 18,272
338 175 175 1,230 1,230
339 317 317 2,228 2,228
340 3,870 3,870 27,197 27,197
341 1,149 1,149 8,075 8,075
342 31,610 31,610 222,147 222,147
343 6,231 6,231 43,790 43,790
344 1,440 1,440 10,120 10,120
345 45 45 316 316
346 8,703 8,703 61,162 61,162
347 578 578 4,062 4,062
348 76,422 76,422 537,074 537,074
349 353 353 2,481 2,481
350 30 30 211 211
351 1,599 1,599 11,237 11,237
352 2,123 2,123 14,920 14,920
353 1,948 1,948 13,690 13,690
354 224 224 1,718 1,718
355 62 62 476 476
356 880 880 6,750 6,750
357 506 506 3,881 3,881
358 2 2 15 15
359 77 77 591 591
360 1,173 1,173 8,997 8,997
361 36 36 276 276
362 569 569 4,364 4,364
363 2,048 2,048 15,708 15,708
364 140 140 1,074 1,074
365 40 40 307 307
366 1,680 1,680 12,886 12,886
367 27 27 207 207
368 150 150 1,151 1,151
369 89 89 683 683
370 2,255 2,255 17,296 17,296
371 168 168 1,289 1,289
372 644 644 4,940 4,940
373 225 225 1,726 1,726
374 120 120 920 920
375 100 100 767 767
376 11,135 11,135 85,406 85,406
377 1,467 1,467 11,252 11,252
TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456.1) (Including transactions referred to as "wheeling")
TRANSFER OF ENERGY TRANSFER OF ENERGY
REVENUE FROM
TRANSMISSION OF
ELECTRICITY FOR
OTHERS
REVENUE FROM
TRANSMISSION OF
ELECTRICITY FOR
OTHERS
REVENUE FROM
TRANSMISSION OF
ELECTRICITY FOR
OTHERS
REVENUE
FROM
TRANSMISSION
OF
ELECTRICITY
FOR OTHERS
Line
No.
Billing Demand (MW)
(h)
Megawatt Hours
Received
(i)
Megawatt Hours
Delivered
(j)
Demand Charges ($)
(k)
Energy Charges ($)
(l)
Other Charges ($)
(m)
Total Revenues
($) (k+l+m)
(n)
FERC FORM NO. 1 (ED. 12-90)
Page 328-330
337 2,600 2,600 18,272 18,2723381751751,230 1,2303393173172,228 2,2283403,870 3,870 27,197 27,1973411,149 1,149 8,075 8,07534231,610 31,610 222,147 222,1473436,231 6,231 43,790 43,7903441,440 1,440 10,120 10,12034545453163163468,703 8,703 61,162 61,1623475785784,062 4,06234876,422 76,422 537,074 537,0743493533532,481 2,48135030302112113511,599 1,599 11,237 11,2373522,123 2,123 14,920 14,9203531,948 1,948 13,690 13,6903542242241,718 1,71835562624764763568808806,750 6,7503575065063,881 3,88135822151535977775915913601,173 1,173 8,997 8,99736136362762763625695694,364 4,3643632,048 2,048 15,708 15,7083641401401,074 1,07436540403073073661,680 1,680 12,886 12,88636727272072073681501501,151 1,15136989896836833702,255 2,255 17,296 17,2963711681681,289 1,2893726446444,940 4,9403732252251,726 1,72637412012092092037510010076776737611,135 11,135 85,406 85,4063771,467 1,467 11,252 11,252TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456.1) (Including transactions referred to as "wheeling")TRANSFER OF ENERGY TRANSFER OF ENERGY REVENUE FROMTRANSMISSION OFELECTRICITY FOROTHERS REVENUE FROMTRANSMISSION OFELECTRICITY FOROTHERS REVENUE FROMTRANSMISSION OFELECTRICITY FOROTHERS REVENUEFROMTRANSMISSIONOFELECTRICITYFOR OTHERSLineNo.Billing Demand (MW)(h)Megawatt HoursReceived(i)Megawatt HoursDelivered(j)Demand Charges ($)(k)Energy Charges ($)(l)Other Charges ($)(m)Total Revenues($) (k+l+m)(n)FERC FORM NO. 1 (ED. 12-90)Page 328-330
378 237 237 1,818 1,818
379 210 210 1,611 1,611
380 31 31 73 73
381 19 19 45 45
382 15 15 35 35
383 100 100 235 235
384 55 55 129 129
385 40 40 94 94
386 1,044 1,044 2,455 2,455
387 4,456 4,456 10,478 10,478
388 122 122 287 287
389 121 121 285 285
390 298 298 701 701
391 6,556 6,556 15,415 15,415
392 7,185 7,185 16,894 16,894
393 353 353 830 830
394 26 26 61 61
395 2,764 2,764 6,499 6,499
396 360 360 846 846
397 8,398 8,398 19,747 19,747
398 965 965 2,269 2,269
399 82,434 82,434 193,831 193,831
400 8,627 8,627 20,285 20,285
401 20,491 20,491 48,182 48,182
402 11,983 11,983 28,176 28,176
403 532 532 1,251 1,251
404 1,066 1,066 2,507 2,507
405 2,700 2,700 6,349 6,349
406 182 182 428 428
407 358 358 842 842
408 298 298 701 701
409 40 40 94 94
410 188 188 442 442
411 13,407 13,407 31,525 31,525
412 50 50 118 118
413 965 965 2,269 2,269
414 1,478 1,478 3,475 3,475
415 234 234 550 550
416 3,585 3,585 8,430 8,430
417 430 430 1,011 1,011
418 18,143 18,143 42,661 42,661
TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456.1) (Including transactions referred to as "wheeling")
TRANSFER OF ENERGY TRANSFER OF ENERGY
REVENUE FROM
TRANSMISSION OF
ELECTRICITY FOR
OTHERS
REVENUE FROM
TRANSMISSION OF
ELECTRICITY FOR
OTHERS
REVENUE FROM
TRANSMISSION OF
ELECTRICITY FOR
OTHERS
REVENUE
FROM
TRANSMISSION
OF
ELECTRICITY
FOR OTHERS
Line
No.
Billing Demand (MW)
(h)
Megawatt Hours
Received
(i)
Megawatt Hours
Delivered
(j)
Demand Charges ($)
(k)
Energy Charges ($)
(l)
Other Charges ($)
(m)
Total Revenues
($) (k+l+m)
(n)
FERC FORM NO. 1 (ED. 12-90)
Page 328-330
378 237 237 1,818 1,8183792102101,611 1,6113803131737338119194545382151535353831001002352353845555129129385404094943861,044 1,044 2,455 2,4553874,456 4,456 10,478 10,4783881221222872873891211212852853902982987017013916,556 6,556 15,415 15,4153927,185 7,185 16,894 16,894393353353830830394262661613952,764 2,764 6,499 6,4993963603608468463978,398 8,398 19,747 19,7473989659652,269 2,26939982,434 82,434 193,831 193,8314008,627 8,627 20,285 20,28540120,491 20,491 48,182 48,18240211,983 11,983 28,176 28,1764035325321,251 1,2514041,066 1,066 2,507 2,5074052,700 2,700 6,349 6,3494061821824284284073583588428424082982987017014094040949441018818844244241113,407 13,407 31,525 31,52541250501181184139659652,269 2,2694141,478 1,478 3,475 3,4754152342345505504163,585 3,585 8,430 8,4304174304301,011 1,01141818,143 18,143 42,661 42,661TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456.1) (Including transactions referred to as "wheeling")TRANSFER OF ENERGY TRANSFER OF ENERGY REVENUE FROMTRANSMISSION OFELECTRICITY FOROTHERS REVENUE FROMTRANSMISSION OFELECTRICITY FOROTHERS REVENUE FROMTRANSMISSION OFELECTRICITY FOROTHERS REVENUEFROMTRANSMISSIONOFELECTRICITYFOR OTHERSLineNo.Billing Demand (MW)(h)Megawatt HoursReceived(i)Megawatt HoursDelivered(j)Demand Charges ($)(k)Energy Charges ($)(l)Other Charges ($)(m)Total Revenues($) (k+l+m)(n)FERC FORM NO. 1 (ED. 12-90)Page 328-330
419 39,323 39,323 92,462 92,462
420 6,894 6,894 16,210 16,210
421 219 219 515 515
422 195 195 459 459
423 726 726 1,707 1,707
424 52 52 122 122
425 890 890 2,093 2,093
426 23 23 54 54
427 17 17 40 40
428 11 11 26 26
429 3,132 3,132 7,364 7,364
430 11,570 11,570 27,205 27,205
431 779 779 1,832 1,832
432 1,273 1,273 2,993 2,993
433 6,877 6,877 16,170 16,170
434 2 2 5 5
435 4,637 4,637 10,903 10,903
436 302 302 710 710
437 40 40 94 94
438 13 13 31 31
439 518 518 1,218 1,218
440 2,704 2,704 6,358 6,358
441 7,114 7,114 16,728 16,728
442 405 405 952 952
443 1,007 1,007 2,368 2,368
444 3,097 3,097 7,282 7,282
445 24 24 56 56
446 97,601 97,601 229,494 229,494
447 4,458 4,458 10,482 10,482
448 2,710 2,710 6,372 6,372
449 2,238 2,238 5,262 5,262
450 120 120 282 282
451 25 25 59 59
452 3 3 7 7
453 103 103 242 242
454 994 994 2,337 2,337
455 280 280 658 658
456 18,661 18,661 43,879 43,879
457 4,365 4,365 10,264 10,264
458 85 85 200 200
459 253 253 595 595
TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456.1) (Including transactions referred to as "wheeling")
TRANSFER OF ENERGY TRANSFER OF ENERGY
REVENUE FROM
TRANSMISSION OF
ELECTRICITY FOR
OTHERS
REVENUE FROM
TRANSMISSION OF
ELECTRICITY FOR
OTHERS
REVENUE FROM
TRANSMISSION OF
ELECTRICITY FOR
OTHERS
REVENUE
FROM
TRANSMISSION
OF
ELECTRICITY
FOR OTHERS
Line
No.
Billing Demand (MW)
(h)
Megawatt Hours
Received
(i)
Megawatt Hours
Delivered
(j)
Demand Charges ($)
(k)
Energy Charges ($)
(l)
Other Charges ($)
(m)
Total Revenues
($) (k+l+m)
(n)
FERC FORM NO. 1 (ED. 12-90)
Page 328-330
419 39,323 39,323 92,462 92,4624206,894 6,894 16,210 16,2104212192195155154221951954594594237267261,707 1,70742452521221224258908902,093 2,0934262323545442717174040428111126264293,132 3,132 7,364 7,36443011,570 11,570 27,205 27,2054317797791,832 1,8324321,273 1,273 2,993 2,9934336,877 6,877 16,170 16,17043422554354,637 4,637 10,903 10,90343630230271071043740409494438131331314395185181,218 1,2184402,704 2,704 6,358 6,3584417,114 7,114 16,728 16,7284424054059529524431,007 1,007 2,368 2,3684443,097 3,097 7,282 7,2824452424565644697,601 97,601 229,494 229,4944474,458 4,458 10,482 10,4824482,710 2,710 6,372 6,3724492,238 2,238 5,262 5,2624501201202822824512525595945233774531031032422424549949942,337 2,33745528028065865845618,661 18,661 43,879 43,8794574,365 4,365 10,264 10,2644588585200200459253253595595TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456.1) (Including transactions referred to as "wheeling")TRANSFER OF ENERGY TRANSFER OF ENERGY REVENUE FROMTRANSMISSION OFELECTRICITY FOROTHERS REVENUE FROMTRANSMISSION OFELECTRICITY FOROTHERS REVENUE FROMTRANSMISSION OFELECTRICITY FOROTHERS REVENUEFROMTRANSMISSIONOFELECTRICITYFOR OTHERSLineNo.Billing Demand (MW)(h)Megawatt HoursReceived(i)Megawatt HoursDelivered(j)Demand Charges ($)(k)Energy Charges ($)(l)Other Charges ($)(m)Total Revenues($) (k+l+m)(n)FERC FORM NO. 1 (ED. 12-90)Page 328-330
460 159 159 374 374
461 239 239 562 562
462 2,517 2,517 5,918 5,918
463 70 70 165 165
464 241 241 567 567
465 423 423 995 995
466 13 13 31 31
467 38 38 89 89
468 252 252 593 593
469 2,806 2,806 6,598 6,598
470 10,352 10,352 24,341 24,341
471 104 104 245 245
472 92 92 216 216
473 133 133 313 313
474 48 48 113 113
475 5,062 5,062 11,903 11,903
476 90 90 212 212
477 4,846 4,846 11,395 11,395
478 7,255 7,255 17,059 17,059
479 2,483 2,483 5,838 5,838
480 78,273 78,273 184,047 184,047
481 897 897 2,109 2,109
482 7,491 7,491 17,614 17,614
483 3,740 3,740 8,794 8,794
484 892 892 2,097 2,097
485 698 698 1,641 1,641
486 3,378 3,378 7,943 7,943
487 3,152 3,152 7,411 7,411
488 162 162 381 381
489 37 37 87 87
490 654 654 1,538 1,538
491 695 695 1,634 1,634
492 2,965 2,965 6,972 6,972
493 0 0 4,843 4,843
494 99 99 403 403
495 1,320 1,320 5,373 5,373
496 402 402 3,806 3,806
497 816 816 7,725 7,725
498 32 32 303 303
499 150 150 1,420 1,420
500 1,015 1,015 9,609 9,609
501 8,545 8,545 80,895 80,895
TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456.1) (Including transactions referred to as "wheeling")
TRANSFER OF ENERGY TRANSFER OF ENERGY
REVENUE FROM
TRANSMISSION OF
ELECTRICITY FOR
OTHERS
REVENUE FROM
TRANSMISSION OF
ELECTRICITY FOR
OTHERS
REVENUE FROM
TRANSMISSION OF
ELECTRICITY FOR
OTHERS
REVENUE
FROM
TRANSMISSION
OF
ELECTRICITY
FOR OTHERS
Line
No.
Billing Demand (MW)
(h)
Megawatt Hours
Received
(i)
Megawatt Hours
Delivered
(j)
Demand Charges ($)
(k)
Energy Charges ($)
(l)
Other Charges ($)
(m)
Total Revenues
($) (k+l+m)
(n)
FERC FORM NO. 1 (ED. 12-90)
Page 328-330
460 159 159 374 3744612392395625624622,517 2,517 5,918 5,918463707016516546424124156756746542342399599546613133131467383889894682522525935934692,806 2,806 6,598 6,59847010,352 10,352 24,341 24,341471104104245245472929221621647313313331331347448481131134755,062 5,062 11,903 11,90347690902122124774,846 4,846 11,395 11,3954787,255 7,255 17,059 17,0594792,483 2,483 5,838 5,83848078,273 78,273 184,047 184,0474818978972,109 2,1094827,491 7,491 17,614 17,6144833,740 3,740 8,794 8,7944848928922,097 2,0974856986981,641 1,6414863,378 3,378 7,943 7,9434873,152 3,152 7,411 7,411488162162381381489373787874906546541,538 1,5384916956951,634 1,6344922,965 2,965 6,972 6,972493004,843 4,84349499994034034951,320 1,320 5,373 5,3734964024023,806 3,8064978168167,725 7,72549832323033034991501501,420 1,4205001,015 1,015 9,609 9,6095018,545 8,545 80,895 80,895TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456.1) (Including transactions referred to as "wheeling")TRANSFER OF ENERGY TRANSFER OF ENERGY REVENUE FROMTRANSMISSION OFELECTRICITY FOROTHERS REVENUE FROMTRANSMISSION OFELECTRICITY FOROTHERS REVENUE FROMTRANSMISSION OFELECTRICITY FOROTHERS REVENUEFROMTRANSMISSIONOFELECTRICITYFOR OTHERSLineNo.Billing Demand (MW)(h)Megawatt HoursReceived(i)Megawatt HoursDelivered(j)Demand Charges ($)(k)Energy Charges ($)(l)Other Charges ($)(m)Total Revenues($) (k+l+m)(n)FERC FORM NO. 1 (ED. 12-90)Page 328-330
502 1,000 1,000 9,467 9,467
503 4,273 4,273 40,452 40,452
504 3,594 3,594 34,024 34,024
505 1,234 1,234 11,682 11,682
506 53 53 502 502
507 1,875 1,875 17,750 17,750
508 8 8 76 76
509 400 400 3,787 3,787
510 890 890 8,426 8,426
511 5,920 5,920 56,044 56,044
512 14 14 133 133
513 105 105 994 994
514 755 755 7,148 7,148
515 404 404 3,825 3,825
516 119 119 1,127 1,127
517 453 453 4,289 4,289
518 34 34 322 322
519 100 100 947 947
520 925 925 8,757 8,757
521 4,422 4,422 41,863 41,863
522 13,040 13,040 123,449 123,449
523 128 128 1,212 1,212
524 225 225 2,130 2,130
525 105 105 994 994
526 96 96 909 909
527 125 125 1,183 1,183
528 3,144 3,144 29,764 29,764
529 98 98 928 928
530 244 244 2,310 2,310
531 10 10 95 95
532 288 288 2,726 2,726
533 2,979 2,979 28,202 28,202
534 588 588 5,567 5,567
535 11,189 11,189 105,925 105,925
536 11,611 11,611 109,920 109,920
537 7,136 7,136 67,556 67,556
538 25,996 25,996 246,102 246,102
539 379 379 3,588 3,588
540 362 362 3,427 3,427
541 1,681 1,681 15,914 15,914
542 370 370 3,503 3,503
543 558 558 5,283 5,283
TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456.1) (Including transactions referred to as "wheeling")
TRANSFER OF ENERGY TRANSFER OF ENERGY
REVENUE FROM
TRANSMISSION OF
ELECTRICITY FOR
OTHERS
REVENUE FROM
TRANSMISSION OF
ELECTRICITY FOR
OTHERS
REVENUE FROM
TRANSMISSION OF
ELECTRICITY FOR
OTHERS
REVENUE
FROM
TRANSMISSION
OF
ELECTRICITY
FOR OTHERS
Line
No.
Billing Demand (MW)
(h)
Megawatt Hours
Received
(i)
Megawatt Hours
Delivered
(j)
Demand Charges ($)
(k)
Energy Charges ($)
(l)
Other Charges ($)
(m)
Total Revenues
($) (k+l+m)
(n)
FERC FORM NO. 1 (ED. 12-90)
Page 328-330
502 1,000 1,000 9,467 9,4675034,273 4,273 40,452 40,4525043,594 3,594 34,024 34,0245051,234 1,234 11,682 11,68250653535025025071,875 1,875 17,750 17,7505088876765094004003,787 3,7875108908908,426 8,4265115,920 5,920 56,044 56,04451214141331335131051059949945147557557,148 7,1485154044043,825 3,8255161191191,127 1,1275174534534,289 4,28951834343223225191001009479475209259258,757 8,7575214,422 4,422 41,863 41,86352213,040 13,040 123,449 123,4495231281281,212 1,2125242252252,130 2,13052510510599499452696969099095271251251,183 1,1835283,144 3,144 29,764 29,76452998989289285302442442,310 2,310531101095955322882882,726 2,7265332,979 2,979 28,202 28,2025345885885,567 5,56753511,189 11,189 105,925 105,92553611,611 11,611 109,920 109,9205377,136 7,136 67,556 67,55653825,996 25,996 246,102 246,1025393793793,588 3,5885403623623,427 3,4275411,681 1,681 15,914 15,9145423703703,503 3,5035435585585,283 5,283TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456.1) (Including transactions referred to as "wheeling")TRANSFER OF ENERGY TRANSFER OF ENERGY REVENUE FROMTRANSMISSION OFELECTRICITY FOROTHERS REVENUE FROMTRANSMISSION OFELECTRICITY FOROTHERS REVENUE FROMTRANSMISSION OFELECTRICITY FOROTHERS REVENUEFROMTRANSMISSIONOFELECTRICITYFOR OTHERSLineNo.Billing Demand (MW)(h)Megawatt HoursReceived(i)Megawatt HoursDelivered(j)Demand Charges ($)(k)Energy Charges ($)(l)Other Charges ($)(m)Total Revenues($) (k+l+m)(n)FERC FORM NO. 1 (ED. 12-90)Page 328-330
544 5,492 5,492 51,992 51,992
545 0 0 10,473 10,473
546 147 147 3,936 3,936
547 0 0 2,618 2,618
548 289 289 84 84
549 892 892 260 260
550 6,868 6,868 2,005 2,005
551 3,129 3,129 913 913
552 960 960 280 280
553 46 46 13 13
554 100 100 29 29
555 18 18 5 5
556 62 62 18 18
557 4,147 4,147 1,210 1,210
558 6,057 6,057 1,768 1,768
559 937 937 273 273
560 2,755 2,755 804 804
561 41 41 12 12
562 24,467 24,467 7,142 7,142
563 5,084 5,084 1,484 1,484
564 451 451 132 132
565 209 209 61 61
566 232 232 68 68
567 21 21 6 6
568 1,162 1,162 339 339
569 1,769 1,769 516 516
570 17 17 5 5
571 193 193 56 56
572 388 388 113 113
573 77 77 22 22
574 1,414 1,414 413 413
575 31 31 9 9
576 146 146 43 43
577 9,613 9,613 2,806 2,806
578 26 26 8 8
579 162 162 47 47
580 17,953 17,953 5,240 5,240
581 12,824 12,824 3,743 3,743
582 20,048 20,048 5,852 5,852
583 3,255 3,255 950 950
584 263 263 77 77
585 24,184 24,184 7,059 7,059
TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456.1) (Including transactions referred to as "wheeling")
TRANSFER OF ENERGY TRANSFER OF ENERGY
REVENUE FROM
TRANSMISSION OF
ELECTRICITY FOR
OTHERS
REVENUE FROM
TRANSMISSION OF
ELECTRICITY FOR
OTHERS
REVENUE FROM
TRANSMISSION OF
ELECTRICITY FOR
OTHERS
REVENUE
FROM
TRANSMISSION
OF
ELECTRICITY
FOR OTHERS
Line
No.
Billing Demand (MW)
(h)
Megawatt Hours
Received
(i)
Megawatt Hours
Delivered
(j)
Demand Charges ($)
(k)
Energy Charges ($)
(l)
Other Charges ($)
(m)
Total Revenues
($) (k+l+m)
(n)
FERC FORM NO. 1 (ED. 12-90)
Page 328-330
544 5,492 5,492 51,992 51,9925450010,473 10,4735461471473,936 3,936547002,618 2,61854828928984845498928922602605506,868 6,868 2,005 2,0055513,129 3,129 913 913552960960280280553464613135541001002929555181855556626218185574,147 4,147 1,210 1,2105586,057 6,057 1,768 1,7685599379372732735602,755 2,755 804 8045614141121256224,467 24,467 7,142 7,1425635,084 5,084 1,484 1,484564451451132132565209209616156623223268685672121665681,162 1,162 339 3395691,769 1,769 516 5165701717555711931935656572388388113113573777722225741,414 1,414 413 41357531319957614614643435779,613 9,613 2,806 2,806578262688579162162474758017,953 17,953 5,240 5,24058112,824 12,824 3,743 3,74358220,048 20,048 5,852 5,8525833,255 3,255 950 950584263263777758524,184 24,184 7,059 7,059TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456.1) (Including transactions referred to as "wheeling")TRANSFER OF ENERGY TRANSFER OF ENERGY REVENUE FROMTRANSMISSION OFELECTRICITY FOROTHERS REVENUE FROMTRANSMISSION OFELECTRICITY FOROTHERS REVENUE FROMTRANSMISSION OFELECTRICITY FOROTHERS REVENUEFROMTRANSMISSIONOFELECTRICITYFOR OTHERSLineNo.Billing Demand (MW)(h)Megawatt HoursReceived(i)Megawatt HoursDelivered(j)Demand Charges ($)(k)Energy Charges ($)(l)Other Charges ($)(m)Total Revenues($) (k+l+m)(n)FERC FORM NO. 1 (ED. 12-90)Page 328-330
586 216,781 216,781 63,276 63,276
587 260 260 76 76
588 1,003 1,003 293 293
589 23,850 23,850 6,962 6,962
590 840 840 245 245
591 393 393 115 115
592 5,163 5,163 1,507 1,507
593 15,452 15,452 4,510 4,510
594 329 329 96 96
595 800 800 234 234
596 969 969 283 283
597 149 149 43 43
598 66 66 19 19
599 392 392 114 114
600 229 229 67 67
601 301 301 88 88
602 1,120 1,120 327 327
603 147 147 43 43
604 0 0 6 6
605 228 228 5,537 5,537
606 110 110 3,547 3,547
607 149 149 1,459 1,459
608 10 10 98 98
609 7 7 69 69
610 399 399 3,907 3,907
611 5 5 49 49
612 18 18 176 176
613 135 135 681 681
614 48 48 242 242
615 303 303 1,528 1,528
616 100 100 504 504
617 609 609 3,071 3,071
618 69 69 348 348
619 389 389 1,961 1,961
620 33 33 166 166
621 262 262 1,321 1,321
622 179 179 1,192 1,192
623 354 354 2,358 2,358
624 698 698 4,649 4,649
625 25 25 167 167
626 559 559 3,723 3,723
627 1,110 1,110 7,393 7,393
TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456.1) (Including transactions referred to as "wheeling")
TRANSFER OF ENERGY TRANSFER OF ENERGY
REVENUE FROM
TRANSMISSION OF
ELECTRICITY FOR
OTHERS
REVENUE FROM
TRANSMISSION OF
ELECTRICITY FOR
OTHERS
REVENUE FROM
TRANSMISSION OF
ELECTRICITY FOR
OTHERS
REVENUE
FROM
TRANSMISSION
OF
ELECTRICITY
FOR OTHERS
Line
No.
Billing Demand (MW)
(h)
Megawatt Hours
Received
(i)
Megawatt Hours
Delivered
(j)
Demand Charges ($)
(k)
Energy Charges ($)
(l)
Other Charges ($)
(m)
Total Revenues
($) (k+l+m)
(n)
FERC FORM NO. 1 (ED. 12-90)
Page 328-330
586 216,781 216,781 63,276 63,27658726026076765881,003 1,003 293 29358923,850 23,850 6,962 6,9625908408402452455913933931151155925,163 5,163 1,507 1,50759315,452 15,452 4,510 4,5105943293299696595800800234234596969969283283597149149434359866661919599392392114114600229229676760130130188886021,120 1,120 327 327603147147434360400666052282285,537 5,5376061101103,547 3,5476071491491,459 1,459608101098986097769696103993993,907 3,907611554949612181817617661313513568168161448482422426153033031,528 1,5286161001005045046176096093,071 3,07161869693483486193893891,961 1,96162033331661666212622621,321 1,3216221791791,192 1,1926233543542,358 2,3586246986984,649 4,64962525251671676265595593,723 3,7236271,110 1,110 7,393 7,393TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456.1) (Including transactions referred to as "wheeling")TRANSFER OF ENERGY TRANSFER OF ENERGY REVENUE FROMTRANSMISSION OFELECTRICITY FOROTHERS REVENUE FROMTRANSMISSION OFELECTRICITY FOROTHERS REVENUE FROMTRANSMISSION OFELECTRICITY FOROTHERS REVENUEFROMTRANSMISSIONOFELECTRICITYFOR OTHERSLineNo.Billing Demand (MW)(h)Megawatt HoursReceived(i)Megawatt HoursDelivered(j)Demand Charges ($)(k)Energy Charges ($)(l)Other Charges ($)(m)Total Revenues($) (k+l+m)(n)FERC FORM NO. 1 (ED. 12-90)Page 328-330
628 10,661 10,661 71,003 71,003
629 337 337 2,244 2,244
630 1,290 1,290 8,592 8,592
631 846 846 5,634 5,634
632 387 387 2,577 2,577
633 1,311 1,311 8,731 8,731
634 720 720 4,795 4,795
635 55 55 366 366
636 3,886 3,886 25,881 25,881
637 18 18 120 120
638 18 18 120 120
639 1,466 1,466 9,764 9,764
640 2,890 2,890 19,248 19,248
641 250 250 1,665 1,665
642 2,519 2,519 16,777 16,777
643 710 710 4,729 4,729
644 3,044 3,044 20,273 20,273
645 1,687 1,687 11,236 11,236
646 600 600 3,996 3,996
647 175 175 1,166 1,166
648 670 670 4,462 4,462
649 746 746 4,968 4,968
650 30 30 200 200
651 5 5 33 33
652 389 389 2,591 2,591
653 1,144 1,144 7,619 7,619
654 14 14 93 93
655 2 2 13 13
656 105 105 699 699
657 388 388 2,584 2,584
658 239 239 1,592 1,592
659 888 888 5,914 5,914
660 217 217 1,445 1,445
661 4,108 4,108 27,360 27,360
662 374 374 2,491 2,491
663 80 80 533 533
664 25 25 167 167
665 100 100 666 666
666 2,340 2,340 15,585 15,585
667 802 802 5,341 5,341
668 29,649 29,649 197,465 197,465
669 323 323 2,151 2,151
TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456.1) (Including transactions referred to as "wheeling")
TRANSFER OF ENERGY TRANSFER OF ENERGY
REVENUE FROM
TRANSMISSION OF
ELECTRICITY FOR
OTHERS
REVENUE FROM
TRANSMISSION OF
ELECTRICITY FOR
OTHERS
REVENUE FROM
TRANSMISSION OF
ELECTRICITY FOR
OTHERS
REVENUE
FROM
TRANSMISSION
OF
ELECTRICITY
FOR OTHERS
Line
No.
Billing Demand (MW)
(h)
Megawatt Hours
Received
(i)
Megawatt Hours
Delivered
(j)
Demand Charges ($)
(k)
Energy Charges ($)
(l)
Other Charges ($)
(m)
Total Revenues
($) (k+l+m)
(n)
FERC FORM NO. 1 (ED. 12-90)
Page 328-330
628 10,661 10,661 71,003 71,0036293373372,244 2,2446301,290 1,290 8,592 8,5926318468465,634 5,6346323873872,577 2,5776331,311 1,311 8,731 8,7316347207204,795 4,79563555553663666363,886 3,886 25,881 25,881637181812012063818181201206391,466 1,466 9,764 9,7646402,890 2,890 19,248 19,2486412502501,665 1,6656422,519 2,519 16,777 16,7776437107104,729 4,7296443,044 3,044 20,273 20,2736451,687 1,687 11,236 11,2366466006003,996 3,9966471751751,166 1,1666486706704,462 4,4626497467464,968 4,96865030302002006515533336523893892,591 2,5916531,144 1,144 7,619 7,619654141493936552213136561051056996996573883882,584 2,5846582392391,592 1,5926598888885,914 5,9146602172171,445 1,4456614,108 4,108 27,360 27,3606623743742,491 2,491663808053353366425251671676651001006666666662,340 2,340 15,585 15,5856678028025,341 5,34166829,649 29,649 197,465 197,4656693233232,151 2,151TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456.1) (Including transactions referred to as "wheeling")TRANSFER OF ENERGY TRANSFER OF ENERGY REVENUE FROMTRANSMISSION OFELECTRICITY FOROTHERS REVENUE FROMTRANSMISSION OFELECTRICITY FOROTHERS REVENUE FROMTRANSMISSION OFELECTRICITY FOROTHERS REVENUEFROMTRANSMISSIONOFELECTRICITYFOR OTHERSLineNo.Billing Demand (MW)(h)Megawatt HoursReceived(i)Megawatt HoursDelivered(j)Demand Charges ($)(k)Energy Charges ($)(l)Other Charges ($)(m)Total Revenues($) (k+l+m)(n)FERC FORM NO. 1 (ED. 12-90)Page 328-330
670 238 238 1,585 1,585
671 480 480 3,197 3,197
672 216 216 1,439 1,439
673 1,599 1,599 10,649 10,649
674 2,518 2,518 16,770 16,770
675 30 30 200 200
676 3,335 3,335 22,211 22,211
677 384 384 2,557 2,557
678 993 993 6,613 6,613
679 26,108 26,108 173,882 173,882
680 55,926 55,926 372,472 372,472
681 1,021 1,021 6,800 6,800
682 698 698 4,649 4,649
683 42 42 280 280
684 649 649 4,322 4,322
685 50 50 333 333
686 78 78 519 519
687 5,324 5,324 35,458 35,458
688 665 665 4,429 4,429
689 1,998 1,998 13,307 13,307
690 0 0 2,719 2,719
691 216 216 1,901 1,901
692 814 814 7,165 7,165
693 3,418 3,418 30,084 30,084
694 340 340 2,993 2,993
695 823 823 7,244 7,244
696 1,240 1,240 10,914 10,914
697 13,074 13,074 115,072 115,072
698 1,127 1,127 9,919 9,919
699 217 217 1,910 1,910
700 22 22 194 194
701 63 63 555 555
702 57 57 502 502
703 189 189 1,664 1,664
704 34 34 299 299
705 9 9 79 79
706 680 680 5,985 5,985
707 39 39 343 343
708 4,335 4,335 38,155 38,155
709 115 115 1,012 1,012
710 225 225 1,980 1,980
711 39 39 343 343
TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456.1) (Including transactions referred to as "wheeling")
TRANSFER OF ENERGY TRANSFER OF ENERGY
REVENUE FROM
TRANSMISSION OF
ELECTRICITY FOR
OTHERS
REVENUE FROM
TRANSMISSION OF
ELECTRICITY FOR
OTHERS
REVENUE FROM
TRANSMISSION OF
ELECTRICITY FOR
OTHERS
REVENUE
FROM
TRANSMISSION
OF
ELECTRICITY
FOR OTHERS
Line
No.
Billing Demand (MW)
(h)
Megawatt Hours
Received
(i)
Megawatt Hours
Delivered
(j)
Demand Charges ($)
(k)
Energy Charges ($)
(l)
Other Charges ($)
(m)
Total Revenues
($) (k+l+m)
(n)
FERC FORM NO. 1 (ED. 12-90)
Page 328-330
670 238 238 1,585 1,5856714804803,197 3,1976722162161,439 1,4396731,599 1,599 10,649 10,6496742,518 2,518 16,770 16,77067530302002006763,335 3,335 22,211 22,2116773843842,557 2,5576789939936,613 6,61367926,108 26,108 173,882 173,88268055,926 55,926 372,472 372,4726811,021 1,021 6,800 6,8006826986984,649 4,64968342422802806846496494,322 4,322685505033333368678785195196875,324 5,324 35,458 35,4586886656654,429 4,4296891,998 1,998 13,307 13,307690002,719 2,7196912162161,901 1,9016928148147,165 7,1656933,418 3,418 30,084 30,0846943403402,993 2,9936958238237,244 7,2446961,240 1,240 10,914 10,91469713,074 13,074 115,072 115,0726981,127 1,127 9,919 9,9196992172171,910 1,9107002222194194701636355555570257575025027031891891,664 1,66470434342992997059979797066806805,985 5,98570739393433437084,335 4,335 38,155 38,1557091151151,012 1,0127102252251,980 1,9807113939343343TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456.1) (Including transactions referred to as "wheeling")TRANSFER OF ENERGY TRANSFER OF ENERGY REVENUE FROMTRANSMISSION OFELECTRICITY FOROTHERS REVENUE FROMTRANSMISSION OFELECTRICITY FOROTHERS REVENUE FROMTRANSMISSION OFELECTRICITY FOROTHERS REVENUEFROMTRANSMISSIONOFELECTRICITYFOR OTHERSLineNo.Billing Demand (MW)(h)Megawatt HoursReceived(i)Megawatt HoursDelivered(j)Demand Charges ($)(k)Energy Charges ($)(l)Other Charges ($)(m)Total Revenues($) (k+l+m)(n)FERC FORM NO. 1 (ED. 12-90)Page 328-330
712 750 750 6,601 6,601
713 75 75 660 660
714 554 554 4,876 4,876
715 170 170 1,496 1,496
716 5,156 5,156 45,381 45,381
717 14,892 14,892 131,073 131,073
718 1,117 1,117 9,831 9,831
719 104 104 915 915
720 608 608 5,351 5,351
721 171 171 1,505 1,505
722 176 176 1,549 1,549
723 1,815 1,815 15,975 15,975
724 43 43 378 378
725 370 370 3,257 3,257
726 27 27 238 238
727 227 227 1,998 1,998
728 314 314 2,764 2,764
729 2,664 2,664 23,447 23,447
730 86 86 757 757
731 258 258 2,271 2,271
732 3 3 26 26
733 79 79 695 695
734 305 305 2,684 2,684
735 8 8 70 70
736 30,302 30,302 266,706 266,706
737 168 168 1,479 1,479
738 556 556 4,894 4,894
739 527 527 4,638 4,638
740 661 661 5,818 5,818
741 1,749 1,749 15,394 15,394
742 1,080 1,080 9,506 9,506
743 52 52 458 458
744 198 198 885 885
745 44,357 44,357 198,216 198,216
746 13 13 58 58
747 115 115 514 514
748 75 75 335 335
749 240 240 5,601 5,601
750 0 0 4,843 4,843
35 0 7,756,368 7,756,368 10,735,827 49,918,310 0 60,654,137
FERC FORM NO. 1 (ED. 12-90)
Page 328-330
TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456.1) (Including transactions referred to as "wheeling")
TRANSFER OF ENERGY TRANSFER OF ENERGY
REVENUE FROM
TRANSMISSION OF
ELECTRICITY FOR
OTHERS
REVENUE FROM
TRANSMISSION OF
ELECTRICITY FOR
OTHERS
REVENUE FROM
TRANSMISSION OF
ELECTRICITY FOR
OTHERS
REVENUE
FROM
TRANSMISSION
OF
ELECTRICITY
FOR OTHERS
Line
No.
Billing Demand (MW)
(h)
Megawatt Hours
Received
(i)
Megawatt Hours
Delivered
(j)
Demand Charges ($)
(k)
Energy Charges ($)
(l)
Other Charges ($)
(m)
Total Revenues
($) (k+l+m)
(n)
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original
(2) ☐ A Resubmission
Date of Report:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
FOOTNOTE DATA
712 750 750 6,601 6,60171375756606607145545544,876 4,8767151701701,496 1,4967165,156 5,156 45,381 45,38171714,892 14,892 131,073 131,0737181,117 1,117 9,831 9,8317191041049159157206086085,351 5,3517211711711,505 1,5057221761761,549 1,5497231,815 1,815 15,975 15,97572443433783787253703703,257 3,25772627272382387272272271,998 1,9987283143142,764 2,7647292,664 2,664 23,447 23,44773086867577577312582582,271 2,27173233262673379796956957343053052,684 2,68473588707073630,302 30,302 266,706 266,7067371681681,479 1,4797385565564,894 4,8947395275274,638 4,6387406616615,818 5,8187411,749 1,749 15,394 15,3947421,080 1,080 9,506 9,506743525245845874419819888588574544,357 44,357 198,216 198,2167461313585874711511551451474875753353357492402405,601 5,601750004,843 4,8433507,756,368 7,756,368 10,735,827 49,918,310 0 60,654,137FERC FORM NO. 1 (ED. 12-90)Page 328-330TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456.1) (Including transactions referred to as "wheeling")TRANSFER OF ENERGY TRANSFER OF ENERGY REVENUE FROMTRANSMISSION OFELECTRICITY FOROTHERS REVENUE FROMTRANSMISSION OFELECTRICITY FOROTHERS REVENUE FROMTRANSMISSION OFELECTRICITY FOROTHERS REVENUEFROMTRANSMISSIONOFELECTRICITYFOR OTHERSLineNo.Billing Demand (MW)(h)Megawatt HoursReceived(i)Megawatt HoursDelivered(j)Demand Charges ($)(k)Energy Charges ($)(l)Other Charges ($)(m)Total Revenues($) (k+l+m)(n)
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original
(2) ☐ A Resubmission
Date of Report:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
FOOTNOTE DATAFOOTNOTE DATA
(a) Concept: PaymentByCompanyOrPublicAuthority
The network service agreement between Idaho Power and the Bonneville Power Administration for the Oregon Trail Electric Cooperative expires September 30, 2028.
(b) Concept: PaymentByCompanyOrPublicAuthority
The network service agreement between Idaho Power and the Bonneville Power Administration for the USBR expired December 31, 2023.
(c) Concept: PaymentByCompanyOrPublicAuthority
The network service agreement between Idaho Power and the Bonneville Power Administration for the Priority Firm Customers expires September 30, 2028.
(d) Concept: PaymentByCompanyOrPublicAuthority
The contract between Idaho Power and the Milner Irrigation District expired December 31, 2023.
(e) Concept: PaymentByCompanyOrPublicAuthority
The agreement between Idaho Power and the City of Seattle expired December 31, 2023. City of Seattle has re-sold this transmission service request to Shell Energy North America (CORP)
and CORP is responsible for payment.
(f) Concept: PaymentByCompanyOrPublicAuthority
The contract between Idaho Power and PacifiCorp - Imnaha expires on March 31, 2026.
(g) Concept: PaymentByCompanyOrPublicAuthority
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.
(h) Concept: RateScheduleTariffNumber
9, Open Access Transmission Tariff, Schedule 9 Network Integration Transmission Service
(i) Concept: RateScheduleTariffNumber
Legacy, contract prior to the Open Access Transmission Tariff
(j) Concept: RateScheduleTariffNumber
5/6, Open Access Transmission Tariff, Schedule 5/6 Operating Reserves
(k) Concept: RateScheduleTariffNumber
7/8, Open Access Transmission Tariff, Schedule 7/8 Firm/Non-Firm Point-to-Point Transmission Service
(l) Concept: RateScheduleTariffNumber
11, Open Access Transmission Tariff, Schedule 11 Unreserved Use Penalty
(m) Concept: BillingDemand
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.
FERC FORM NO. 1 (ED. 12-90)
Page 328-330
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original
(2) ☐ A Resubmission
Date of Report:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
TRANSMISSION OF ELECTRICITY BY OTHERS (Account 565)
FOOTNOTE DATA(a) Concept: PaymentByCompanyOrPublicAuthorityThe network service agreement between Idaho Power and the Bonneville Power Administration for the Oregon Trail Electric Cooperative expires September 30, 2028.(b) Concept: PaymentByCompanyOrPublicAuthorityThe network service agreement between Idaho Power and the Bonneville Power Administration for the USBR expired December 31, 2023.(c) Concept: PaymentByCompanyOrPublicAuthorityThe network service agreement between Idaho Power and the Bonneville Power Administration for the Priority Firm Customers expires September 30, 2028.(d) Concept: PaymentByCompanyOrPublicAuthorityThe contract between Idaho Power and the Milner Irrigation District expired December 31, 2023.(e) Concept: PaymentByCompanyOrPublicAuthorityThe agreement between Idaho Power and the City of Seattle expired December 31, 2023. City of Seattle has re-sold this transmission service request to Shell Energy North America (CORP)and CORP is responsible for payment.(f) Concept: PaymentByCompanyOrPublicAuthorityThe contract between Idaho Power and PacifiCorp - Imnaha expires on March 31, 2026.(g) Concept: PaymentByCompanyOrPublicAuthorityThe 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.(h) Concept: RateScheduleTariffNumber9, Open Access Transmission Tariff, Schedule 9 Network Integration Transmission Service(i) Concept: RateScheduleTariffNumberLegacy, contract prior to the Open Access Transmission Tariff(j) Concept: RateScheduleTariffNumber5/6, Open Access Transmission Tariff, Schedule 5/6 Operating Reserves(k) Concept: RateScheduleTariffNumber7/8, Open Access Transmission Tariff, Schedule 7/8 Firm/Non-Firm Point-to-Point Transmission Service(l) Concept: RateScheduleTariffNumber11, Open Access Transmission Tariff, Schedule 11 Unreserved Use Penalty(m) Concept: BillingDemandThe billing demand for network service is the customer's demand at the time of Idaho Power Company transmission system peak and varies by month.FERC FORM NO. 1 (ED. 12-90)Page 328-330
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original
(2) ☐ A Resubmission
Date of Report:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
TRANSMISSION OF ELECTRICITY BY OTHERS (Account 565)TRANSMISSION OF ELECTRICITY BY OTHERS (Account 565)
TRANSFER OF ENERGY TRANSFER OF ENERGY
Line
No.
Name of Company or Public Authority (Footnote Affiliations)
(a)
Statistical Classification
(b)
MegaWatt Hours Received
(c)
MegaWatt Hours Delivered
(d)
1 Avista Corp. - WWP Div.
(a)
LFP 328,558 328,558
2 Avista Corp. - WWP Div.NF 714 714
3 Avista Corp. - WWP Div.SFP 4,200 4,200
4 Avista Corp. - WWP Div.
(b)
OS
5 Bonneville Power Administration
(c)
LFP 56,903 56,903
6 Bonneville Power Administration NF 2,860 2,860
7 Bonneville Power Administration
(d)
OS
8 Bonneville Power Administration
(e)
OS
9 Bonneville Power Administration
(f)
OS 15,350 15,350
10 Bonneville Power Administration
(g)
OS 2,208 2,208
11 Bonneville Power Administration
(h)
OS
12 Constellation Energy Generation, LLC
(i)
OS
13 Dynasty Power Inc.
(j)
OS
14 NorthWestern Energy NF 2,735 2,735
15 NorthWestern Energy
(k)
OS
16 NV Energy NF
17 NV Energy
(l)
OS
18 PacifiCorp Inc.
(m)
LFP 25,666 25,666
19 PacifiCorp Inc.NF 10,125 10,125
20 PacifiCorp Inc.
(n)
OS
21 PacifiCorp Inc.
(o)
OS
22 PacifiCorp Inc.
(p)
OS
23 PacifiCorp Inc.
(q)
OS
24 PacifiCorp Inc.
(r)
OS
25 Phillips 66 Trading LLC
(s)
OS
26 Seattle City Light
(t)
OS
27 Sierra Pacific Power Company NF 3,681 3,681
28 Sierra Pacific Power Company
(u)
OS
29 Snohomish County PUD OS
30 Snohomish County PUD
(v)
SFP 7,182 7,182
TOTAL 460,182 460,182
FERC FORM NO. 1 (REV. 02-04)
Page 332
TRANSMISSION OF ELECTRICITY BY OTHERS (Account 565)
EXPENSES FOR TRANSMISSION OF
ELECTRICITY BY OTHERS
EXPENSES FOR TRANSMISSION OF
ELECTRICITY BY OTHERS
EXPENSES FOR TRANSMISSION OF
ELECTRICITY BY OTHERS
EXPENSES FOR TRANSMISSION OF
ELECTRICITY BY OTHERS
Line
No.
Demand Charges ($)
(e)
Energy Charges ($)
(f)
Other Charges ($)
(g)
Total Cost of Transmission ($)
(h)
FERC FORM NO. 1 (REV. 02-04)
Page 332
TRANSMISSION OF ELECTRICITY BY OTHERS (Account 565)TRANSFER OF ENERGY TRANSFER OF ENERGYLineNo.Name of Company or Public Authority (Footnote Affiliations)(a)Statistical Classification(b)MegaWatt Hours Received(c)MegaWatt Hours Delivered(d)1 Avista Corp. - WWP Div.(a)LFP 328,558 328,5582Avista Corp. - WWP Div.NF 714 7143Avista Corp. - WWP Div.SFP 4,200 4,2004Avista Corp. - WWP Div.(b)OS5Bonneville Power Administration (c)LFP 56,903 56,9036Bonneville Power Administration NF 2,860 2,8607Bonneville Power Administration (d)OS8Bonneville Power Administration (e)OS9Bonneville Power Administration (f)OS 15,350 15,35010Bonneville Power Administration (g)OS 2,208 2,20811Bonneville Power Administration (h)OS12Constellation Energy Generation, LLC (i)OS13Dynasty Power Inc.(j)OS14NorthWestern Energy NF 2,735 2,73515NorthWestern Energy (k)OS16NV Energy NF17NV Energy (l)OS18PacifiCorp Inc.(m)LFP 25,666 25,66619PacifiCorp Inc.NF 10,125 10,12520PacifiCorp Inc.(n)OS21PacifiCorp Inc.(o)OS22PacifiCorp Inc.(p)OS23PacifiCorp Inc.(q)OS24PacifiCorp Inc.(r)OS25Phillips 66 Trading LLC (s)OS26Seattle City Light (t)OS27Sierra Pacific Power Company NF 3,681 3,68128Sierra Pacific Power Company (u)OS29Snohomish County PUD OS30Snohomish County PUD (v)SFP 7,182 7,182TOTAL460,182 460,182FERC FORM NO. 1 (REV. 02-04)Page 332
TRANSMISSION OF ELECTRICITY BY OTHERS (Account 565)
EXPENSES FOR TRANSMISSION OF
ELECTRICITY BY OTHERS
EXPENSES FOR TRANSMISSION OF
ELECTRICITY BY OTHERS
EXPENSES FOR TRANSMISSION OF
ELECTRICITY BY OTHERS
EXPENSES FOR TRANSMISSION OF
ELECTRICITY BY OTHERS
Line
No.
Demand Charges ($)
(e)
Energy Charges ($)
(f)
Other Charges ($)
(g)
Total Cost of Transmission ($)
(h)
FERC FORM NO. 1 (REV. 02-04)
Page 332
1 6,596,000 6,596,000
2 5,900 5,900
3 123,660 123,660
4 (43,800)(43,800)
5 1,076,616 1,076,616
6 13,634 13,634
7 189,984 189,984
8 1,493 1,493
9
10
11 5,000 5,000
12 (74,524)(74,524)
13 (63,720)(63,720)
14 15,352 15,352
15 360 360
16 2,192 2,192
17 44 44
18 3,900,076 3,900,076
19 97,083 97,083
20 (1,018,584)(1,018,584)
21 173,637 173,637
22 (14,640)(14,640)
23 (32,888)(32,888)
24 (26)(26)
25 (10,844)(10,844)
26 5,168 5,168
27 19,772 19,772
28 497 497
29 32,960 32,960
30 50,220 50,220
0 10,727,161 323,461 11,050,622
FERC FORM NO. 1 (REV. 02-04)
Page 332
FOOTNOTE DATA
(a) Concept: StatisticalClassificationCode
Financial Transmission Losses
1 6,596,000 6,596,00025,900 5,9003123,660 123,6604(43,800)(43,800)5 1,076,616 1,076,616613,634 13,6347189,984 189,98481,493 1,493910115,000 5,00012(74,524)(74,524)13 (63,720)(63,720)14 15,352 15,35215360360162,192 2,192174444183,900,076 3,900,0761997,083 97,08320(1,018,584)(1,018,584)21 173,637 173,63722(14,640)(14,640)23 (32,888)(32,888)24 (26)(26)25 (10,844)(10,844)26 5,168 5,1682719,772 19,772284974972932,960 32,9603050,220 50,220010,727,161 323,461 11,050,622FERC FORM NO. 1 (REV. 02-04)Page 332
FOOTNOTE DATA
(a) Concept: StatisticalClassificationCode
Financial Transmission Losses
(b) Concept: StatisticalClassificationCode
Resale Transmission
(c) Concept: StatisticalClassificationCode
There are 3 contracts with Expiration Dates of 12/31/2025 and 12/31/2026
(d) Concept: StatisticalClassificationCode
Ancillary services
(e) Concept: StatisticalClassificationCode
Spinning/Supplemental Reserves
(f) Concept: StatisticalClassificationCode
Capacity reassignment, BPAT is provider for Snohomish
(g) Concept: StatisticalClassificationCode
Capacity reassignment, BPAT is provider for Seattle City Light
(h) Concept: StatisticalClassificationCode
Processing Fee for Transmission Service
(i) Concept: StatisticalClassificationCode
Resale Transmission
(j) Concept: StatisticalClassificationCode
Resale Transmission
(k) Concept: StatisticalClassificationCode
Ancillary services
(l) Concept: StatisticalClassificationCode
Ancillary services
(m) Concept: StatisticalClassificationCode
There are 2 Contracts with Expiration Dates of 5/31/2024 and 12/31/2027
(n) Concept: StatisticalClassificationCode
Resale Transmission
(o) Concept: StatisticalClassificationCode
Ancillary services
(p) Concept: StatisticalClassificationCode
2022 Unreserved Use Refund
(q) Concept: StatisticalClassificationCode
2022 Rate True Up - LFP_Refund Rate True-up
(r) Concept: StatisticalClassificationCode
2021 Rate True Up - LFP_Refund Rate True-up
(s) Concept: StatisticalClassificationCode
Resale Transmission
(t) Concept: StatisticalClassificationCode
Capacity reassignment, BPAT is provider
(u) Concept: StatisticalClassificationCode
Ancillary services
(v) Concept: StatisticalClassificationCode
Capacity reassignment, BPAT is provider
FERC FORM NO. 1 (REV. 02-04)
Page 332
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original
(2) ☐ A Resubmission
Date of Report:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
MISCELLANEOUS GENERAL EXPENSES (Account 930.2) (ELECTRIC)
(b) Concept: StatisticalClassificationCodeResale Transmission(c) Concept: StatisticalClassificationCodeThere are 3 contracts with Expiration Dates of 12/31/2025 and 12/31/2026(d) Concept: StatisticalClassificationCodeAncillary services(e) Concept: StatisticalClassificationCodeSpinning/Supplemental Reserves(f) Concept: StatisticalClassificationCodeCapacity reassignment, BPAT is provider for Snohomish(g) Concept: StatisticalClassificationCodeCapacity reassignment, BPAT is provider for Seattle City Light(h) Concept: StatisticalClassificationCodeProcessing Fee for Transmission Service(i) Concept: StatisticalClassificationCodeResale Transmission(j) Concept: StatisticalClassificationCodeResale Transmission(k) Concept: StatisticalClassificationCodeAncillary services(l) Concept: StatisticalClassificationCodeAncillary services(m) Concept: StatisticalClassificationCodeThere are 2 Contracts with Expiration Dates of 5/31/2024 and 12/31/2027(n) Concept: StatisticalClassificationCodeResale Transmission(o) Concept: StatisticalClassificationCodeAncillary services(p) Concept: StatisticalClassificationCode2022 Unreserved Use Refund(q) Concept: StatisticalClassificationCode2022 Rate True Up - LFP_Refund Rate True-up(r) Concept: StatisticalClassificationCode2021 Rate True Up - LFP_Refund Rate True-up(s) Concept: StatisticalClassificationCodeResale Transmission(t) Concept: StatisticalClassificationCodeCapacity reassignment, BPAT is provider(u) Concept: StatisticalClassificationCodeAncillary services(v) Concept: StatisticalClassificationCodeCapacity reassignment, BPAT is providerFERC FORM NO. 1 (REV. 02-04)Page 332
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original
(2) ☐ A Resubmission
Date of Report:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
MISCELLANEOUS GENERAL EXPENSES (Account 930.2) (ELECTRIC)
Line No.Description
(a)
Amount
(b)
1 Industry Association Dues 629,835
2 Nuclear Power Research Expenses
3 Other Experimental and General Research Expenses
4 Pub and Dist Info to Stkhldrs...expn servicing outstanding Securities (a)2,136,851
5 Oth Expn greater than or equal to 5,000 show purpose, recipient, amount. Group if less than $5,000
6 DIRECTOR FEES & EXPENSES 0
7 BOLANO, ODETTE 94,710
8 CARLILE, THOMAS 38,382
9 DAHL, RICHARD J 193,545
10 ELG, ANNETTE G 104,445
11 JIBSON, RONALD W 94,720
12 JOHANSEN, JUDITH A 116,679
13 JOHNSON, DENNIS L 104,445
14 KINNEEVEAUK, JEFF 97,316
15 PETERS, MARK T 94,050
16 JORGENSEN, NATE 64,907
17 MORRIS, SUSAN 66,161
18 NAVARRO, RICHARD J 117,453
19 TRAVEL & LODGING 96,077
20 Corp Memberships & Subscriptions 0
21 ASSOCIATED TAXPAYERS OF I 5,500
22 BANNOCK DEVELOPMENT CORP 5,000
23 BOISE METRO CHAMBER OF COMMERCE 31,954
24 BUSINESS PLUS INC 10,000
25 CEATI INTERNATIONAL INC 82,455
26 CHAMBER OF COMMERCE 20,706
27 CENTER FOR CORPORATE INNOVATION 54,000
28 E SOURCE 25,297
29 ELECTRIC POWER RESEARCH 20,000
30 IDAHO ASSOC OF COMMERCE 13,700
31 NORTH AMERICAN ENERGY STANDARD 8,000
32 OREGON STATE UNIVERSITY 15,000
33 PACIFIC NW UTILITIES 56,900
34 PROCUREMENT IQ 8,925
35 SPGLO (30,000)
36 WEI MEMBERSHIP 31,140
37 Misc. memberships or Subscriptions under $5000 24,069
46 TOTAL 4,432,222
FERC FORM NO. 1 (ED. 12-94)
Page 335
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original
(2) ☐ A Resubmission
Date of Report:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
FOOTNOTE DATA
Line No.Description(a)Amount(b)1 Industry Association Dues 629,8352Nuclear Power Research Expenses3Other Experimental and General Research Expenses4Pub and Dist Info to Stkhldrs...expn servicing outstanding Securities (a)2,136,8515Oth Expn greater than or equal to 5,000 show purpose, recipient, amount. Group if less than $5,0006DIRECTOR FEES & EXPENSES 07BOLANO, ODETTE 94,7108CARLILE, THOMAS 38,3829DAHL, RICHARD J 193,54510ELG, ANNETTE G 104,44511JIBSON, RONALD W 94,72012JOHANSEN, JUDITH A 116,67913JOHNSON, DENNIS L 104,44514KINNEEVEAUK, JEFF 97,31615PETERS, MARK T 94,05016JORGENSEN, NATE 64,90717MORRIS, SUSAN 66,16118NAVARRO, RICHARD J 117,45319TRAVEL & LODGING 96,07720Corp Memberships & Subscriptions 021ASSOCIATED TAXPAYERS OF I 5,50022BANNOCK DEVELOPMENT CORP 5,00023BOISE METRO CHAMBER OF COMMERCE 31,95424BUSINESS PLUS INC 10,00025CEATI INTERNATIONAL INC 82,45526CHAMBER OF COMMERCE 20,70627CENTER FOR CORPORATE INNOVATION 54,00028E SOURCE 25,29729ELECTRIC POWER RESEARCH 20,00030IDAHO ASSOC OF COMMERCE 13,70031NORTH AMERICAN ENERGY STANDARD 8,00032OREGON STATE UNIVERSITY 15,00033PACIFIC NW UTILITIES 56,90034PROCUREMENT IQ 8,92535SPGLO(30,000)36 WEI MEMBERSHIP 31,14037Misc. memberships or Subscriptions under $5000 24,06946TOTAL4,432,222FERC FORM NO. 1 (ED. 12-94)Page 335
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original
(2) ☐ A Resubmission
Date of Report:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
FOOTNOTE DATA
(a) Concept: PublicationAndDistributionExpensesForSecuritiesToStockholders
Pub & Distr info to Stckholders Purpose Amount
BANK OF NEW YORK Misc Expense 3,498.00
BROADRIDGE FINANCIAL SOLUTIONS Misc Expense 113,132.68
BUSINESS WIRE INC Misc Expense 10,890.00
DEUTSCH BANK TRUST CO Broker Fees 60,000.00
D F KING & COMPANY INC Misc Expense 31,203.74
EQ SHAREOWNER SERVICES MGMT Expenses 80,710.19
Fees & Training Related to Stockholder Services Misc Expense 57,497.09
JEROME 20/20 Misc Expense 2,500.00
MARKIT NORTH AMERICA INC Misc Expense 42,570.00
MISC OTHER EXPENSE Misc Expense 1,380.49
MODERN NETWORKS IR, LLC Misc Expense 11,820.60
MOODYS Financial Software 42,999.00
NASDAQ CORP SOLUTIONS Misc Expense 36,848.88
NEW YORK STOCK EXCHANGE Misc Expense 79,014.73
Payroll Related Misc Expense 203,259.87
Q4 INC Misc Expense 25,953.33
RIVEL RESEARCH GROUP INC MGMT Expenses 16,830.00
US BANK OF IDAHO Misc Expense 19,150.00
Stock Based Compensation Misc Expense 1,276,396.82
Travel Expense - Stock Related Misc Expense 21,195.27
2,136,850.69
FERC FORM NO. 1 (ED. 12-94)
Page 335
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original
(2) ☐ A Resubmission
Date of Report:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
Depreciation and Amortization of Electric Plant (Account 403, 404, 405)
(a) Concept: PublicationAndDistributionExpensesForSecuritiesToStockholdersPub & Distr info to Stckholders Purpose AmountBANK OF NEW YORK Misc Expense 3,498.00BROADRIDGE FINANCIAL SOLUTIONS Misc Expense 113,132.68BUSINESS WIRE INC Misc Expense 10,890.00DEUTSCH BANK TRUST CO Broker Fees 60,000.00D F KING & COMPANY INC Misc Expense 31,203.74EQ SHAREOWNER SERVICES MGMT Expenses 80,710.19Fees & Training Related to Stockholder Services Misc Expense 57,497.09JEROME 20/20 Misc Expense 2,500.00MARKIT NORTH AMERICA INC Misc Expense 42,570.00MISC OTHER EXPENSE Misc Expense 1,380.49MODERN NETWORKS IR, LLC Misc Expense 11,820.60MOODYSFinancial Software 42,999.00NASDAQ CORP SOLUTIONS Misc Expense 36,848.88NEW YORK STOCK EXCHANGE Misc Expense 79,014.73Payroll Related Misc Expense 203,259.87Q4 INC Misc Expense 25,953.33RIVEL RESEARCH GROUP INC MGMT Expenses 16,830.00US BANK OF IDAHO Misc Expense 19,150.00Stock Based Compensation Misc Expense 1,276,396.82Travel Expense - Stock Related Misc Expense 21,195.272,136,850.69FERC FORM NO. 1 (ED. 12-94)Page 335
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original
(2) ☐ A Resubmission
Date of Report:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
Depreciation and Amortization of Electric Plant (Account 403, 404, 405)
A. Summary of Depreciation and
Amortization Charges
A. Summary of
Depreciation and
Amortization Charges
A. Summary of
Depreciation and
Amortization Charges
A. Summary of
Depreciation and
Amortization Charges
A. Summary of
Depreciation and
Amortization Charges
A. Summary of
Depreciation and
Amortization Charges
Line
No.
Functional Classification
(a)
Depreciation Expense
(Account 403)
(b)
Depreciation Expense for
Asset Retirement Costs
(Account 403.1)
(c)
Amortization of Limited
Term Electric Plant
(Account 404)
(d)
Amortization of Other
Electric Plant (Acc 405)
(e)
Total
(f)
1 Intangible Plant 6,193,955 6,193,955
2 Steam Production Plant 49,010,473 49,010,473
3 Nuclear Production Plant
4 Hydraulic Production Plant-Conventional 25,320,109 25,320,109
5 Hydraulic Production Plant-Pumped
Storage
6 Other Production Plant 19,314,018 19,314,018
7 Transmission Plant 25,977,974 25,977,974
8 Distribution Plant 50,525,692 50,525,692
9 Regional Transmission and Market
Operation
10 General Plant 17,996,077 17,996,077
11 Common Plant-Electric
12 TOTAL 188,144,343 6,193,955 194,338,298
FERC FORM NO. 1 (REV. 12-03)
Page 336-337
B. Basis for Amortization Charges
(a)
C. Factors Used in Estimating Depreciation Charges
Line
No.
Account No.
(a)
Depreciable Plant Base
(in Thousands)
(b)
Estimated Avg. Service Life
(c)
Net Salvage
(Percent)
(d)
Applied Depr.
Rates
(Percent)
(e)
Mortality Curve Type
(f)
Average Remaining Life
(g)
12 31020 (b)0.649 %(c)4.342%
13 31100 122.135 %3.423%
14 31210 199.352 %4.265%
15 31220 434.149 %5.585%
16 31230 2.504 %1.614%
17 31400 143.046 %5.525%
18 31500 54.669 %4.231%
19 31600 13.7 %7.524%
20 31610 0.664 %11.273%
21 31640 0.204 %0.363%
22 31650 0.384 %1.087%
23 31660 0.045 13.746%
24 31670 0.424 %1.84%
25 31680 4.495 %7.162%
26 31690 0.014 %3.07%
27 31700 39.92
28 STEAM TOTAL 1,016.354
29 33100 268.903
30 33210 19.461
31 33220 287.355
32 33230 5.472
33 33300 398.767
34 33400 76.191
35 33500 32.386
36 33510 0.161
A. Summary of Depreciation andAmortization Charges A. Summary ofDepreciation andAmortization Charges A. Summary ofDepreciation andAmortization Charges A. Summary ofDepreciation andAmortization Charges A. Summary ofDepreciation andAmortization Charges A. Summary ofDepreciation andAmortization ChargesLineNo.Functional Classification(a)Depreciation Expense(Account 403)(b)Depreciation Expense forAsset Retirement Costs(Account 403.1)(c)Amortization of LimitedTerm Electric Plant(Account 404)(d)Amortization of OtherElectric Plant (Acc 405)(e)Total(f)1 Intangible Plant 6,193,955 6,193,9552Steam Production Plant 49,010,473 49,010,4733Nuclear Production Plant4Hydraulic Production Plant-Conventional 25,320,109 25,320,1095Hydraulic Production Plant-PumpedStorage6Other Production Plant 19,314,018 19,314,0187Transmission Plant 25,977,974 25,977,9748Distribution Plant 50,525,692 50,525,6929Regional Transmission and MarketOperation10General Plant 17,996,077 17,996,07711Common Plant-Electric12TOTAL 188,144,343 6,193,955 194,338,298FERC FORM NO. 1 (REV. 12-03)Page 336-337B. Basis for Amortization Charges(a)C. Factors Used in Estimating Depreciation ChargesLineNo.Account No.(a)Depreciable Plant Base(in Thousands)(b)Estimated Avg. Service Life(c)Net Salvage(Percent)(d)Applied Depr.Rates(Percent)(e)Mortality Curve Type(f)Average Remaining Life(g)12 31020 (b)0.649 %(c)4.342%13 31100 122.135 %3.423%14 31210 199.352 %4.265%15 31220 434.149 %5.585%16 31230 2.504 %1.614%17 31400 143.046 %5.525%18 31500 54.669 %4.231%19 31600 13.7 %7.524%20 31610 0.664 %11.273%21 31640 0.204 %0.363%22 31650 0.384 %1.087%23 31660 0.045 13.746%24 31670 0.424 %1.84%25 31680 4.495 %7.162%26 31690 0.014 %3.07%27 31700 39.9228STEAM TOTAL 1,016.3542933100268.903303321019.4613133220287.35532332305.4723333300398.767
34 33400 76.191
35 33500 32.386
36 33510 0.161
37 33520 0.042
38 33530 0.489
39 33600 19.342
40 HYDRO TOTAL 1,108.569
41 34100 154.937
42 34110 0.003
43 34200 10.438
44 34300 294.719
45 34400 72.37
46 34410 0.079
47 34500 93.82
48 34600 7.762
49 34610 0.013
50
OTHER
PRODUCTION
TOTAL
634.141
51 35020 37.34
52 35022 1.321
53 35200 106.294
54 35300 493.035
55 35400 232.602
56 35500 240.662
57 35510 4.64
58 35600 271.536
59 35900 0.405
60 TRANSMISSION
TOTAL 1,387.835
61 36022 0.874
62 36100 66.084
63 36200 338.795
64 36302 14.06 20 years, 0 months 0%5%
65 36303 105.449 20 years, 0 months 0%5%
66 36305 14.06 20 years, 0 months 0%5%
67 36306 3.562 20 years, 0 months 0%5%
68 36307 3.562 20 years, 0 months 0%5%
69 36400 324.768
70 36410 19.537
71 36500 165.014
72 36600 57.715
73 36700 351.104
74 36800 777.304
75 36900 72.438
76 37000 19.63
77 37010 99.291
78 37120 5.844
79 37320 7.085
80 37400 0
81
DISTRIBUTION
TOTAL 2,446.176
82 39011 35.463
37 33520 0.04238335300.489393360019.34240HYDRO TOTAL 1,108.5694134100154.93742341100.003433420010.4384434300294.719453440072.3746344100.079473450093.8248346007.76249346100.01350OTHERPRODUCTIONTOTAL634.141513502037.3452350221.3215335200106.2945435300493.0355535400232.6025635500240.66257355104.645835600271.53659359000.40560TRANSMISSIONTOTAL1,387.83561360220.874623610066.0846336200338.795643630214.06 20 years, 0 months 0%5%65 36303 105.449 20 years, 0 months 0%5%66 36305 14.06 20 years, 0 months 0%5%67 36306 3.562 20 years, 0 months 0%5%68 36307 3.562 20 years, 0 months 0%5%69 36400 324.768703641019.5377136500165.014723660057.7157336700351.1047436800777.304753690072.438763700019.63773701099.29178371205.84479373207.08580374000
81
DISTRIBUTION
TOTAL 2,446.176
82 39011 35.463
83 39012 142.945
84 39110 13.205
85 39120 26.447
86 39121 2.494
87 39210 0.802
88 39230 4.444
89 39240 36.626
90 39250 2.304
91 39260 66.01
92 39270 10.718
93 39290 10.112
94 39300 7.754
95 39400 15.758
96 39500 16.452
97 39600 31.333
98 39710 3.025
99 39720 24.63
100 39730 27.908
101 39740 20.69
102 39750 5.427
103 39800 10.915
104 GENERAL
TOTAL 515.462
105 TOTAL DEPR
PLANT 7,108.537
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original
(2) ☐ A Resubmission
Date of Report:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
FOOTNOTE DATA
83 39012 142.945843911013.205853912026.44786391212.49487392100.80288392304.444893924036.62690392502.304913926066.01923927010.718933929010.11294393007.754953940015.758963950016.452973960031.33398397103.025993972024.631003973027.9081013974020.69102397505.4271033980010.915104GENERALTOTAL515.462105TOTAL DEPRPLANT 7,108.537
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original
(2) ☐ A Resubmission
Date of Report:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
FOOTNOTE DATA
(a) Concept: BasisAmortizationCharges
Account 404 - Basis used to compute charges:
Balance to be Balance to be Remaining
Amortized 2023 Amortized months of
1/1/2023 Amortization 12/31/2023 Amort 12/31/23
(1) Mid Snake Relicensing 6,127,497 511,096 5,616,401 -
(2) Swan Falls Relicensing 3,734,856 189,908 3,544,948 224
(3) Software 26,481,925 4,641,165 33,372,912 -
(4) Shoshone Bannock ROW 1,444,804 287,899 1,156,905 48
(5) FERC Compliance Costs 21,940,621 446,688 24,296,094 -
(6) Radio Frequency - Spectrum 3,214,888 120,255 3,094,633 309
Total 62,944,591 6,197,011 71,081,893
(1) Middle Snake Relicensing Costs (Amoritzed over a 30 year license period; licenses expire July 31, 2034 and February 28, 2035).
(2) Swan Falls Relicensing Costs (Amortized over a 30 year license period, license expires August 31, 2042).
(3) Computer Software packages (Amortized over a 5 or 10 year period, as applicable).
(4) Shoshone-Bannock Right of Way (Termination date December 31, 2027).
(5) FERC License Compliance Costs (Amortized over the term of the applicable FERC License)
(6) Radio Frequency Spectrum (Amortized using a 3.38% annual rate, effective January 2022)
(b) Concept: DepreciablePlantBase
Plant balances in column (b) are year-end plant sub-account balances.
(c) Concept: UtilityPlantAppliedDepreciationRate
Schedule page 336:
Line: 12 to 26 Column: e
The Applied Depreciation Rates presented in column (e) for Steam Production plant sub-accounts
are calculated using annual depreciation expense compared to average plant balance derived from
the beginning and end of year plant balances.
FERC FORM NO. 1 (REV. 12-03)
Page 336-337
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original
(2) ☐ A Resubmission
Date of Report:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
REGULATORY COMMISSION EXPENSES
(a) Concept: BasisAmortizationChargesAccount 404 - Basis used to compute charges:Balance to be Balance to be RemainingAmortized2023Amortizedmonths of1/1/2023 Amortization 12/31/2023 Amort 12/31/23(1) Mid Snake Relicensing 6,127,497 511,096 5,616,401 -(2) Swan Falls Relicensing 3,734,856 189,908 3,544,948 224(3) Software 26,481,925 4,641,165 33,372,912 -(4) Shoshone Bannock ROW 1,444,804 287,899 1,156,905 48(5) FERC Compliance Costs 21,940,621 446,688 24,296,094 -(6) Radio Frequency - Spectrum 3,214,888 120,255 3,094,633 309Total62,944,591 6,197,011 71,081,893(1) Middle Snake Relicensing Costs (Amoritzed over a 30 year license period; licenses expire July 31, 2034 and February 28, 2035).(2) Swan Falls Relicensing Costs (Amortized over a 30 year license period, license expires August 31, 2042).(3) Computer Software packages (Amortized over a 5 or 10 year period, as applicable).(4) Shoshone-Bannock Right of Way (Termination date December 31, 2027).(5) FERC License Compliance Costs (Amortized over the term of the applicable FERC License)(6) Radio Frequency Spectrum (Amortized using a 3.38% annual rate, effective January 2022)(b) Concept: DepreciablePlantBasePlant balances in column (b) are year-end plant sub-account balances.(c) Concept: UtilityPlantAppliedDepreciationRateSchedule page 336:Line: 12 to 26 Column: eThe Applied Depreciation Rates presented in column (e) for Steam Production plant sub-accountsare calculated using annual depreciation expense compared to average plant balance derived fromthe beginning and end of year plant balances.FERC FORM NO. 1 (REV. 12-03)Page 336-337
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original
(2) ☐ A Resubmission
Date of Report:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
REGULATORY COMMISSION EXPENSES
EXPENSES
INCURRED DURING
YEAR
EXPENSES
INCURRED
DURING
YEAR
CURRENTLY
CHARGED TO
CURRENTLY
CHARGED
TO
Line
No.
Description (Furnish name of
regulatory commission or body the
docket or case number and a
description of the case)
(a)
Assessed by
Regulatory
Commission
(b)
Expenses of Utility
(c)
Total Expenses for
Current Year (b) + (c)
(d)
Deferred in Account
182.3 at Beginning of
Year
(e)
Department
(f)
Account No.
(g)
1 FEDERAL ENERGY REGULATORY
COMMISSION:
2 STATUTORY FEES ASSESSED BY
FERC 5,197,045 5,197,045 ELECTRIC 928
3 GENERAL REGULATORY MATTERS 283,013 283,013 ELECTRIC 928
4 OREGON HYDRO FEES 271,717 271,717 ELECTRIC 928
5 REGULATORY COMMISSION
EXPENSES - IDAHO
6 STATUTORY FEES ASSESSED BY
COMMISSION 21,039 ELECTRIC 928
7 GENERAL REGULATORY MATTERS 5,680 5,680 ELECTRIC 928
8 REGULATORY COMMISSION
EXPENSES - OREGON
9 STATUTORY FEES ASSESSED BY
COMMISSION 95,321 ELECTRIC 928
10 GENERAL REGULATORY MATTERS 292,939 292,939 ELECTRIC 928
46 TOTAL 5,468,762 581,632 6,050,394 116,360
FERC FORM NO. 1 (ED. 12-96)
Page 350-351
REGULATORY COMMISSION EXPENSES
EXPENSES INCURRED DURING
YEAR
EXPENSES INCURRED DURING
YEAR
AMORTIZED DURING
YEAR AMORTIZED DURING YEAR AMORTIZED DURING YEAR
CURRENTLY CHARGED TO
Line Amount Deferred to Account 182.3 Contra Account Amount Deferred in Account 182.3 End of
Year
FERC FORM NO. 1 (ED. 12-96)
Page 350-351
EXPENSESINCURRED DURINGYEAR EXPENSESINCURREDDURINGYEARCURRENTLYCHARGED TO CURRENTLYCHARGEDTOLineNo.Description (Furnish name ofregulatory commission or body thedocket or case number and adescription of the case)(a)Assessed byRegulatoryCommission(b)Expenses of Utility(c)Total Expenses forCurrent Year (b) + (c)(d)Deferred in Account182.3 at Beginning ofYear(e)Department(f)Account No.(g)1 FEDERAL ENERGY REGULATORYCOMMISSION:2 STATUTORY FEES ASSESSED BYFERC 5,197,045 5,197,045 ELECTRIC 9283GENERAL REGULATORY MATTERS 283,013 283,013 ELECTRIC 9284OREGON HYDRO FEES 271,717 271,717 ELECTRIC 9285REGULATORY COMMISSIONEXPENSES - IDAHO6STATUTORY FEES ASSESSED BYCOMMISSION 21,039 ELECTRIC 9287GENERAL REGULATORY MATTERS 5,680 5,680 ELECTRIC 9288REGULATORY COMMISSIONEXPENSES - OREGON9STATUTORY FEES ASSESSED BYCOMMISSION 95,321 ELECTRIC 92810GENERAL REGULATORY MATTERS 292,939 292,939 ELECTRIC 92846TOTAL5,468,762 581,632 6,050,394 116,360FERC FORM NO. 1 (ED. 12-96)Page 350-351
REGULATORY COMMISSION EXPENSES
EXPENSES INCURRED DURING
YEAR
EXPENSES INCURRED DURING
YEAR
AMORTIZED DURING
YEAR AMORTIZED DURING YEAR AMORTIZED DURING YEAR
CURRENTLY CHARGED TO
Line Amount Deferred to Account 182.3 Contra Account Amount Deferred in Account 182.3 End of
Year
FERC FORM NO. 1 (ED. 12-96)
Page 350-351
Line
No.
Amount
(h)
Deferred to Account 182.3
(i)
Contra Account
(j)
Amount
(k)Year
(l)
1
2 5,197,045
3 283,013
4 271,717
5
6 38,120 928203, 419000 42,777 16,382
7 5,680
8
9 127,946 928303, 419000 61,511 161,756
10 292,939
46 6,050,394 166,066 104,288 178,138
FERC FORM NO. 1 (ED. 12-96)
Page 350-351
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original
(2) ☐ A Resubmission
Date of Report:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
RESEARCH, DEVELOPMENT, AND DEMONSTRATION ACTIVITIES
LineNo.Amount(h)Deferred to Account 182.3(i)Contra Account(j)Amount(k)Year(l)12 5,197,0453283,0134271,71756 38,120 928203, 419000 42,777 16,38275,68089 127,946 928303, 419000 61,511 161,75610292,939466,050,394 166,066 104,288 178,138FERC FORM NO. 1 (ED. 12-96)Page 350-351
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original
(2) ☐ A Resubmission
Date of Report:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
RESEARCH, DEVELOPMENT, AND DEMONSTRATION ACTIVITIES
Line
No.
Classification
(a)
Description
(b)
Costs Incurred Internally
Current Year
(c)
Costs Incurred Externally
Current Year
(d)
1 Idaho Power did not incur any research and
development expenditures in 2023.
FERC FORM NO. 1 (ED. 12-87)
Page 352-353
RESEARCH, DEVELOPMENT, AND DEMONSTRATION ACTIVITIES
AMOUNTS CHARGED IN CURRENT
YEAR AMOUNTS CHARGED IN CURRENT YEAR
Line No.
Amounts Charged In Current Year:
Account
(e)
Amounts Charged In Current Year: Amount
(f)
Unamortized Accumulation
(g)
FERC FORM NO. 1 (ED. 12-87)
Page 352-353
LineNo.Classification(a)Description(b)Costs Incurred InternallyCurrent Year(c)Costs Incurred ExternallyCurrent Year(d)1 Idaho Power did not incur any research anddevelopment expenditures in 2023.FERC FORM NO. 1 (ED. 12-87)Page 352-353
RESEARCH, DEVELOPMENT, AND DEMONSTRATION ACTIVITIES
AMOUNTS CHARGED IN CURRENT
YEAR AMOUNTS CHARGED IN CURRENT YEAR
Line No.
Amounts Charged In Current Year:
Account
(e)
Amounts Charged In Current Year: Amount
(f)
Unamortized Accumulation
(g)
FERC FORM NO. 1 (ED. 12-87)
Page 352-353
(e)
1 0 0
FERC FORM NO. 1 (ED. 12-87)
Page 352-353
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original
(2) ☐ A Resubmission
Date of Report:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
DISTRIBUTION OF SALARIES AND WAGES
(e)1 0 0FERC FORM NO. 1 (ED. 12-87)Page 352-353
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original
(2) ☐ A Resubmission
Date of Report:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
DISTRIBUTION OF SALARIES AND WAGES
Line
No.
Classification
(a)
Direct Payroll Distribution
(b)
Allocation of Payroll Charged for
Clearing Accounts
(c)
Total
(d)
1 Electric
2 Operation
3 Production 23,642,184
4 Transmission 7,098,005
5 Regional Market
6 Distribution 21,188,788
7 Customer Accounts 10,415,201
8 Customer Service and Informational 5,786,139
9 Sales
10 Administrative and General 90,224,054
11 TOTAL Operation (Enter Total of lines 3 thru 10)158,354,371
12 Maintenance
13 Production 5,053,295
14 Transmission 4,653,556
15 Regional Market
16 Distribution 9,099,661
17 Administrative and General 1,082,710
18 TOTAL Maintenance (Total of lines 13 thru 17)19,889,222
19 Total Operation and Maintenance
20 Production (Enter Total of lines 3 and 13)28,695,479
21 Transmission (Enter Total of lines 4 and 14)11,751,561
22 Regional Market (Enter Total of Lines 5 and 15)
23 Distribution (Enter Total of lines 6 and 16)30,288,449
24 Customer Accounts (Transcribe from line 7)10,415,201
25 Customer Service and Informational (Transcribe from line 8)5,786,139
26 Sales (Transcribe from line 9)
27 Administrative and General (Enter Total of lines 10 and 17)91,306,764
28 TOTAL Oper. and Maint. (Total of lines 20 thru 27)178,243,593 178,243,593
29 Gas
30 Operation
31 Production - Manufactured Gas
32 Production-Nat. Gas (Including Expl. And Dev.)
33 Other Gas Supply
34 Storage, LNG Terminaling and Processing
35 Transmission
36 Distribution
37 Customer Accounts
38 Customer Service and Informational
39 Sales
40 Administrative and General
41 TOTAL Operation (Enter Total of lines 31 thru 40)
42 Maintenance
43 Production - Manufactured Gas
FERC FORM NO. 1 (ED. 12-88)
Page 354-355
LineNo.Classification(a)Direct Payroll Distribution(b)Allocation of Payroll Charged forClearing Accounts(c)Total(d)1 Electric2Operation3Production 23,642,1844Transmission7,098,0055Regional Market6Distribution 21,188,7887Customer Accounts 10,415,2018Customer Service and Informational 5,786,1399Sales10Administrative and General 90,224,05411TOTAL Operation (Enter Total of lines 3 thru 10)158,354,37112Maintenance13Production5,053,29514Transmission4,653,55615Regional Market16Distribution 9,099,66117Administrative and General 1,082,71018TOTAL Maintenance (Total of lines 13 thru 17)19,889,22219Total Operation and Maintenance20Production (Enter Total of lines 3 and 13)28,695,47921Transmission (Enter Total of lines 4 and 14)11,751,56122Regional Market (Enter Total of Lines 5 and 15)23 Distribution (Enter Total of lines 6 and 16)30,288,44924Customer Accounts (Transcribe from line 7)10,415,20125Customer Service and Informational (Transcribe from line 8)5,786,13926Sales (Transcribe from line 9)27 Administrative and General (Enter Total of lines 10 and 17)91,306,76428TOTAL Oper. and Maint. (Total of lines 20 thru 27)178,243,593 178,243,59329Gas30Operation31Production - Manufactured Gas32Production-Nat. Gas (Including Expl. And Dev.)33 Other Gas Supply34Storage, LNG Terminaling and Processing35Transmission36Distribution37Customer Accounts38Customer Service and Informational39Sales40Administrative and General41TOTAL Operation (Enter Total of lines 31 thru 40)42 Maintenance
43 Production - Manufactured Gas
FERC FORM NO. 1 (ED. 12-88)Page 354-355
44
Production-Natural Gas (Including Exploration and
Development)
45 Other Gas Supply
46 Storage, LNG Terminaling and Processing
47 Transmission
48 Distribution
49 Administrative and General
50 TOTAL Maint. (Enter Total of lines 43 thru 49)
51 Total Operation and Maintenance
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 0
65 TOTAL All Utility Dept. (Total of lines 28, 62, and 64)178,243,593 0 178,243,593
66 Utility Plant
67 Construction (By Utility Departments)
68 Electric Plant
69 Gas Plant
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 Construction Work in Progress 89,584,452 89,584,452
79 Other Clearing Accounts 4,836,262 4,836,262
80 Stores Expense 6,565,397 6,565,397
81 Other Accounts 6,007,047 6,007,047
82 Other Work in Progress 5,637,791 5,637,791
83 Preliminary Survey and Investigation (5,392)(5,392)
84 Indirect Loading (a)67,146,319 67,146,319
85
86
DISTRIBUTION OF SALARIES AND WAGES
Line
No.
Classification
(a)
Direct Payroll Distribution
(b)
Allocation of Payroll Charged for
Clearing Accounts
(c)
Total
(d)
FERC FORM NO. 1 (ED. 12-88)
Page 354-355
44 Production-Natural Gas (Including Exploration andDevelopment)45 Other Gas Supply46Storage, LNG Terminaling and Processing47Transmission48Distribution49Administrative and General50TOTAL Maint. (Enter Total of lines 43 thru 49)51 Total Operation and Maintenance52Production-Manufactured Gas (Enter Total of lines 31 and 43)53 Production-Natural Gas (Including Expl. and Dev.) (Total lines32,54 Other Gas Supply (Enter Total of lines 33 and 45)55 Storage, LNG Terminaling and Processing (Total of lines 31thru56Transmission (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 Departments64Operation and Maintenance 065TOTAL All Utility Dept. (Total of lines 28, 62, and 64)178,243,593 0 178,243,59366Utility Plant67Construction (By Utility Departments)68 Electric Plant69Gas Plant70Other (provide details in footnote):71 TOTAL Construction (Total of lines 68 thru 70)72 Plant Removal (By Utility Departments)73 Electric Plant74Gas Plant75Other (provide details in footnote):76 TOTAL Plant Removal (Total of lines 73 thru 75)77 Other Accounts (Specify, provide details in footnote):78 Construction Work in Progress 89,584,452 89,584,45279Other Clearing Accounts 4,836,262 4,836,26280Stores Expense 6,565,397 6,565,39781Other Accounts 6,007,047 6,007,04782Other Work in Progress 5,637,791 5,637,79183Preliminary Survey and Investigation (5,392)(5,392)84 Indirect Loading (a)67,146,319 67,146,31985
86
DISTRIBUTION OF SALARIES AND WAGESLineNo.Classification(a)Direct Payroll Distribution(b)Allocation of Payroll Charged forClearing Accounts(c)Total(d)FERC FORM NO. 1 (ED. 12-88)Page 354-355
87
88
89
90
91
92
93
94
95 TOTAL Other Accounts 112,625,557 67,146,319 179,771,876
96 TOTAL SALARIES AND WAGES 290,869,150 67,146,319 358,015,469
FERC FORM NO. 1 (ED. 12-88)
Page 354-355
DISTRIBUTION OF SALARIES AND WAGES
Line
No.
Classification
(a)
Direct Payroll Distribution
(b)
Allocation of Payroll Charged for
Clearing Accounts
(c)
Total
(d)
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original
(2) ☐ A Resubmission
Date of Report:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
FOOTNOTE DATA
878889909192939495 TOTAL Other Accounts 112,625,557 67,146,319 179,771,87696TOTAL SALARIES AND WAGES 290,869,150 67,146,319 358,015,469FERC FORM NO. 1 (ED. 12-88)Page 354-355DISTRIBUTION OF SALARIES AND WAGESLineNo.Classification(a)Direct Payroll Distribution(b)Allocation of Payroll Charged forClearing Accounts(c)Total(d)
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original
(2) ☐ A Resubmission
Date of Report:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
FOOTNOTE DATA
(a) Concept: SalariesAndWagesOtherAccounts
Amount reported is total amount of indirect loading. The loading is allocated to departments based on labor charges.
FERC FORM NO. 1 (ED. 12-88)
Page 354-355
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original
(2) ☐ A Resubmission
Date of Report:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
PURCHASES AND SALES OF ANCILLARY SERVICES
Amount Purchased for the Year Amount Purchased for the Year Amount Purchased for the Year
(a) Concept: SalariesAndWagesOtherAccountsAmount reported is total amount of indirect loading. The loading is allocated to departments based on labor charges.FERC FORM NO. 1 (ED. 12-88)Page 354-355
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original
(2) ☐ A Resubmission
Date of Report:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
PURCHASES AND SALES OF ANCILLARY SERVICES
Amount Purchased for the Year Amount Purchased for the Year Amount Purchased for the YearAmount Purchased for the Year Amount Purchased for the Year Amount Purchased for the Year
Usage - Related Billing Determinant Usage - Related Billing Determinant Usage - Related Billing Determinant
Line
No.
Type of Ancillary Service
(a)
Number of Units
(b)
Unit of Measure
(c)
Dollar
(d)
1 Scheduling, System Control and Dispatch 245,762
2 Reactive Supply and Voltage 118,794
3 Regulation and Frequency Response
4 Energy Imbalance
5 Operating Reserve - Spinning 903
6 Operating Reserve - Supplement 590
7 Other
8 Total (Lines 1 thru 7)0 366,049
FERC FORM NO. 1 (New 2-04)
Page 398
PURCHASES AND SALES OF ANCILLARY SERVICES
Amount Sold for the Year Amount Sold for the Year Amount Sold for the Year
Usage - Related Billing Determinant Usage - Related Billing Determinant Usage - Related Billing Determinant
Line
No.
Number of Units
(e)
Unit of Measure
(f)
Dollars
(g)
1FERC FORM NO. 1 (New 2-04)
Amount Purchased for the Year Amount Purchased for the Year Amount Purchased for the YearUsage - Related Billing Determinant Usage - Related Billing Determinant Usage - Related Billing DeterminantLineNo.Type of Ancillary Service(a)Number of Units(b)Unit of Measure(c)Dollar(d)1 Scheduling, System Control and Dispatch 245,7622Reactive Supply and Voltage 118,7943Regulation and Frequency Response4Energy Imbalance5Operating Reserve - Spinning 9036Operating Reserve - Supplement 5907Other8Total (Lines 1 thru 7)0 366,049FERC FORM NO. 1 (New 2-04)Page 398
PURCHASES AND SALES OF ANCILLARY SERVICES
Amount Sold for the Year Amount Sold for the Year Amount Sold for the Year
Usage - Related Billing Determinant Usage - Related Billing Determinant Usage - Related Billing Determinant
Line
No.
Number of Units
(e)
Unit of Measure
(f)
Dollars
(g)
1FERC FORM NO. 1 (New 2-04)1
2
3 3,502,146 KW 343,036
4
5 4,499,423 KW 440,719
6 4,499,423 KW 440,719
7
8 12,500,992 1,224,474
FERC FORM NO. 1 (New 2-04)
Page 398
PURCHASES AND SALES OF ANCILLARY SERVICES
Amount Sold for the Year Amount Sold for the Year Amount Sold for the Year
Usage - Related Billing Determinant Usage - Related Billing Determinant Usage - Related Billing Determinant
Line
No.
Number of Units
(e)
Unit of Measure
(f)
Dollars
(g)
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original
(2) ☐ A Resubmission
Date of Report:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
MONTHLY TRANSMISSION SYSTEM PEAK LOAD
Other
123 3,502,146 KW 343,036454,499,423 KW 440,71964,499,423 KW 440,7197812,500,992 1,224,474FERC FORM NO. 1 (New 2-04)Page 398PURCHASES AND SALES OF ANCILLARY SERVICESAmount Sold for the Year Amount Sold for the Year Amount Sold for the YearUsage - Related Billing Determinant Usage - Related Billing Determinant Usage - Related Billing DeterminantLineNo.Number of Units(e)Unit of Measure(f)Dollars(g)
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original
(2) ☐ A Resubmission
Date of Report:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
MONTHLY TRANSMISSION SYSTEM PEAK LOAD
Other
Line
No.
Month
(a)
Monthly Peak MW -
Total
(b)
Day of Monthly
Peak
(c)
Hour of Monthly
Peak
(d)
Firm Network
Service for Self
(e)
Firm Network
Service for
Others
(f)
Long-Term
Firm Point-
to-point
Reservations
(g)
Other
Long-
Term
Firm
Service
(h)
Short-Term
Firm Point-
to-point
Reservation
(i)
Other
Service
(j)
NAME OF SYSTEM: IDAHO
POWER COMPANY - SYSTEM
LOAD
1 January 3,812 30 20 1,944 270 1,177 0 421 0
2 February 3,868 2 8 2,010 268 1,177 0 413 0
3 March 3,603 7 9 1,660 243 1,177 0 523 0
4 Total for Quarter 1 5,614 781 3,531 0 1,357 0
5 April 3,451 5 9 1,686 234 1,177 0 354 0
6 May 4,112 19 19 2,128 294 1,177 0 513 0
7 June 4,735 30 19 2,854 364 1,177 0 340 0
8 Total for Quarter 2 6,668 892 3,531 0 1,207 0
9 July 5,179 20 17 3,295 400 1,177 0 307 0
10 August 4,972 15 19 2,739 377 1,177 0 679 0
11 September 4,143 11 18 2,362 232 1,177 0 372 0
12 Total for Quarter 3 8,396 1,009 3,531 0 1,358 0
13 October 3,256 28 9 1,291 209 1,177 0 579 0
14 November 3,712 28 8 1,891 282 1,177 0 362 0
15 December 3,610 18 9 1,746 237 1,177 0 450 0
16 Total for Quarter 4 4,928 728 3,531 0 1,391 0
17 Total 25,606 3,410 14,124 0 5,313 0
FERC FORM NO. 1 (NEW. 07-04)
Page 400
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original
(2) ☐ A Resubmission
Date of Report:
2024-04-16
Year/Period of Report
End of: 2023/ Q4
ELECTRIC ENERGY ACCOUNT
Line Item MegaWatt Hours Line Item MegaWatt Hours
LineNo.Month(a)Monthly Peak MW -Total(b)Day of MonthlyPeak(c)Hour of MonthlyPeak(d)Firm NetworkService for Self(e)Firm NetworkService forOthers(f)Long-TermFirm Point-to-pointReservations(g)OtherLong-TermFirmService(h)Short-TermFirm Point-to-pointReservation(i)OtherService(j)NAME OF SYSTEM: IDAHOPOWER COMPANY - SYSTEMLOAD1January 3,812 30 20 1,944 270 1,177 0 421 02February3,868 2 8 2,010 268 1,177 0 413 03March3,603 7 9 1,660 243 1,177 0 523 04Total for Quarter 1 5,614 781 3,531 0 1,357 05April3,451 5 9 1,686 234 1,177 0 354 06May4,112 19 19 2,128 294 1,177 0 513 07June4,735 30 19 2,854 364 1,177 0 340 08Total for Quarter 2 6,668 892 3,531 0 1,207 09July5,179 20 17 3,295 400 1,177 0 307 010August4,972 15 19 2,739 377 1,177 0 679 011September4,143 11 18 2,362 232 1,177 0 372 012Total for Quarter 3 8,396 1,009 3,531 0 1,358 013October3,256 28 9 1,291 209 1,177 0 579 014November3,712 28 8 1,891 282 1,177 0 362 015December3,610 18 9 1,746 237 1,177 0 450 016Total for Quarter 4 4,928 728 3,531 0 1,391 017Total25,606 3,410 14,124 0 5,313 0FERC FORM NO. 1 (NEW. 07-04)Page 400
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original
(2) ☐ A Resubmission
Date of Report:
2024-04-16
Year/Period of Report
End of: 2023/ Q4
ELECTRIC ENERGY ACCOUNT
Line Item MegaWatt Hours Line Item MegaWatt HoursLine
No.
Item
(a)
MegaWatt Hours
(b)
Line
No.
Item
(a)
MegaWatt Hours
(b)
1 SOURCES OF ENERGY 21 DISPOSITION OF ENERGY
2 Generation (Excluding Station Use):22 Sales to Ultimate Consumers (Including
Interdepartmental Sales)15,514,992
3 Steam 2,473,143 23 Requirements Sales for Resale (See instruction 4,
page 311.)
4 Nuclear 24 Non-Requirements Sales for Resale (See
instruction 4, page 311.)2,095,145
5 Hydro-Conventional 6,547,878 25 Energy Furnished Without Charge
6 Hydro-Pumped Storage 26 Energy Used by the Company (Electric Dept Only,
Excluding Station Use)0
7 Other 2,917,244 27 Total Energy Losses 1,207,582
8 Less Energy for Pumping 27.1 Total Energy Stored 17,446
9 Net Generation (Enter Total of lines 3 through 8)11,938,265 28 TOTAL (Enter Total of Lines 22 Through 27.1)
MUST EQUAL LINE 20 UNDER SOURCES 18,835,165
10 Purchases (other than for Energy Storage)7,020,964
10.1 Purchases for Energy Storage 0
11 Power Exchanges:
12 Received 57,686
13 Delivered 186,111
14 Net Exchanges (Line 12 minus line 13)(128,425)
15 Transmission For Other (Wheeling)
16 Received 7,756,368
17 Delivered 7,752,007
18 Net Transmission for Other (Line 16 minus line 17)(a)4,361
19 Transmission By Others Losses 0
20 TOTAL (Enter Total of Lines 9, 10, 10.1, 14, 18 and
19)18,835,165
FERC FORM NO. 1 (ED. 12-90)
Page 401a
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original
(2) ☐ A Resubmission
Date of Report:
2024-04-16
Year/Period of Report
End of: 2023/ Q4
FOOTNOTE DATA
LineNo.Item(a)MegaWatt Hours(b)LineNo.Item(a)MegaWatt Hours(b)1 SOURCES OF ENERGY 21 DISPOSITION OF ENERGY2Generation (Excluding Station Use):22 Sales to Ultimate Consumers (IncludingInterdepartmental Sales)15,514,9923Steam2,473,143 23 Requirements Sales for Resale (See instruction 4,page 311.)4 Nuclear 24 Non-Requirements Sales for Resale (Seeinstruction 4, page 311.)2,095,1455Hydro-Conventional 6,547,878 25 Energy Furnished Without Charge6Hydro-Pumped Storage 26 Energy Used by the Company (Electric Dept Only,Excluding Station Use)07Other2,917,244 27 Total Energy Losses 1,207,5828Less Energy for Pumping 27.1 Total Energy Stored 17,4469Net Generation (Enter Total of lines 3 through 8)11,938,265 28 TOTAL (Enter Total of Lines 22 Through 27.1)MUST EQUAL LINE 20 UNDER SOURCES 18,835,16510Purchases (other than for Energy Storage)7,020,96410.1 Purchases for Energy Storage 011Power Exchanges:12 Received 57,68613Delivered186,11114Net Exchanges (Line 12 minus line 13)(128,425)15 Transmission For Other (Wheeling)16 Received 7,756,36817Delivered7,752,00718Net Transmission for Other (Line 16 minus line 17)(a)4,36119Transmission By Others Losses 020TOTAL (Enter Total of Lines 9, 10, 10.1, 14, 18 and19)18,835,165FERC FORM NO. 1 (ED. 12-90)Page 401a
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original
(2) ☐ A Resubmission
Date of Report:
2024-04-16
Year/Period of Report
End of: 2023/ Q4
FOOTNOTE DATA
(a) Concept: NetTransmissionEnergyForOthersElectricPowerWheeling
Page 329 Column I differs from page 401 by 4,361 MWH, reported for Wheeling 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. 12-90)
Page 401a
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original
(2) ☐ A Resubmission
Date of Report:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
MONTHLY PEAKS AND OUTPUT
Monthly Non-FERC FORM NO. 1 (ED. 12-90)
(a) Concept: NetTransmissionEnergyForOthersElectricPowerWheelingPage 329 Column I differs from page 401 by 4,361 MWH, reported for Wheeling 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. 12-90)Page 401a
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original
(2) ☐ A Resubmission
Date of Report:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
MONTHLY PEAKS AND OUTPUT
Monthly Non-FERC FORM NO. 1 (ED. 12-90)
Line
No.
Month
(a)
Total Monthly Energy
(b)
Monthly Non-
Requirement Sales for
Resale & Associated
Losses
(c)
Monthly Peak - Megawatts
(d)
Monthly Peak - Day of
Month
(e)
Monthly Peak - Hour
(f)
NAME OF SYSTEM: IDAHO POWER
COMPANY - SYSTEM LOAD
29 January 1,713,824 288,755 2,521 30 9
30 February 1,436,429 177,995 2,431 1 9
31 March 1,400,530 94,530 2,221 7 8
32 April 1,273,220 127,060 2,160 30 19
33 May 1,743,874 375,378 2,681 20 19
34 June 1,730,586 244,420 3,195 30 19
35 July 2,012,618 41,628 3,615 20 18
36 August 1,794,383 63,916 3,480 16 17
37 September 1,394,795 96,563 2,704 11 18
38 October 1,316,684 161,315 2,170 30 9
39 November 1,438,338 227,835 2,253 28 8
40 December 1,579,884 195,750 2,196 18 9
41 Total 18,835,165 2,095,145
FERC FORM NO. 1 (ED. 12-90)
Page 401b
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original
(2) ☐ A Resubmission
Date of Report:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
Steam Electric Generating Plant Statistics
LineNo.Month(a)Total Monthly Energy(b)Monthly Non-Requirement Sales forResale & AssociatedLosses(c)Monthly Peak - Megawatts(d)Monthly Peak - Day ofMonth(e)Monthly Peak - Hour(f)NAME OF SYSTEM: IDAHO POWERCOMPANY - SYSTEM LOAD29January 1,713,824 288,755 2,521 30 930February1,436,429 177,995 2,431 1 931March1,400,530 94,530 2,221 7 832April1,273,220 127,060 2,160 30 1933May1,743,874 375,378 2,681 20 1934June1,730,586 244,420 3,195 30 1935July2,012,618 41,628 3,615 20 1836August1,794,383 63,916 3,480 16 1737September1,394,795 96,563 2,704 11 1838October1,316,684 161,315 2,170 30 939November1,438,338 227,835 2,253 28 840December1,579,884 195,750 2,196 18 941Total18,835,165 2,095,145FERC FORM NO. 1 (ED. 12-90)Page 401b
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original
(2) ☐ A Resubmission
Date of Report:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
Steam Electric Generating Plant Statistics
1. Report data for plant in Service only.
2. Large plants are steam plants with installed capacity (name plate rating) of 25,000 Kw or more. Report in this page gas-turbine and internal combustion plants of 10,000 Kw or more, and
nuclear plants.
3. Indicate by a footnote any plant leased or operated as a joint facility.
4. If net peak demand for 60 minutes is not available, give data which is available, specifying period.
5. If any employees attend more than one plant, report on line 11 the approximate average number of employees assignable to each plant.
6. If gas is used and purchased on a therm basis report the Btu content or the gas and the quantity of fuel burned converted to Mcf.
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.
9. Items under Cost of Plant are based on USofA 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.
11. For a plant equipped with combinations of fossil fuel steam, nuclear steam, hydro, internal combustion or gas-turbine equipment, report each as a separate plant. However, if a gas-
turbine unit functions in a combined cycle operation with a conventional steam unit, include the gas-turbine with the steam plant.
12. If a nuclear power generating plant, briefly explain by footnote (a) accounting method for cost of power generated including any excess costs attributed to research and development;
(b) types of cost units used for the various components of fuel cost; and (c) any other informative data concerning plant type fuel used, fuel enrichment type and quantity for the report period
and other physical and operating characteristics of plant.
Line
No.
Item
(a)
Plant Name:
Bennett Mountain
Plant Name:
Boardman
Plant Name:
Danskin
Plant Name:
Jim Bridger
Plant Name:
Langley Gulch
Plant
Name:
Valmy
1 Kind of Plant (Internal Comb, Gas
Turb, Nuclear)Gas Turbine Steam Gas Turbine Steam Gas Turbine Steam
2 Type of Constr (Conventional,
Outdoor, Boiler, etc)Conventional Conventional Conventional Semi-Outdoor Boiler Conventional Outdoor
3 Year Originally Constructed 2005
(a)
1980 2001
(b)
1974 2012
(c)
1981
4 Year Last Unit was Installed 2005 1980 2008 1979 2012 1985
5 Total Installed Cap (Max Gen Name
Plate Ratings-MW)172.8 (d)0 270.9 (e)775.29 318.45 (f)144.9
6 Net Peak Demand on Plant - MW (60
minutes)203 0 286 716 338 137
7 Plant Hours Connected to Load 4,424 0 3,758 8,760 5,971 3,778
8 Net Continuous Plant Capability
(Megawatts)204 300 344
9 When Not Limited by Condenser
Water 0 (g)0 0 (h)0 0 (i)0
10 When Limited by Condenser Water 0 0 0 0 0 0
11 Average Number of Employees 4 0 6 0 23 0
12 Net Generation, Exclusive of Plant
Use - kWh 725,648,000 0 566,667,000 2,244,357,000 1,624,868,000 228,786,000
13 Cost of Plant: Land and Land Rights 0 106,610 402,745 509,671 2,287,261 1,106,140
14 Structures and Improvements 1,855,550 0 6,288,751 74,228,852 146,781,147 47,906,560
15 Equipment Costs 80,978,761 0 146,463,846 644,479,167 250,690,859 209,171,680
16 Asset Retirement Costs 0 3,767,793 0 36,460,399 0 (308,456)
17 Total cost (total 13 thru 20)82,834,311 3,874,403 153,155,342 755,678,089 399,759,267 257,875,924
18 Cost per KW of Installed Capacity
(line 17/5) Including 479.37 565.36 974.7 1,255.33 1,779.68
19 Production Expenses: Oper, Supv, &
Engr 9,121 (154,681)8,640 268,861 637,812 514,428
20 Fuel 46,847,614 0 43,897,776 77,983,147 89,143,609 17,516,179
21 Coolants and Water (Nuclear Plants
Only)0 0 0 0 0 0
22 Steam Expenses 0 (2,000)0 6,103,197 0 4,049,014
23 Steam From Other Sources 0 0 0 0 0 0
24 Steam Transferred (Cr)0 0 0 0 0 0
25 Electric Expenses 516,125 0 913,522 0 3,856,325 1,589,402
26 Misc Steam (or Nuclear) Power
Expenses 114,173 5 162,360 6,576,575 442,711 1,552,020
27 Rents 0 0 0 233,996 0 0
28 Allowances 0 0 0 0 0 0
29 Maintenance Supervision and
Engineering 0 (282,132)0 17,707 0 0
30 Maintenance of Structures 25,064 0 37,678 0 81,551 1,142,007
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, andnuclear plants. 3. Indicate by a footnote any plant leased or operated as a joint facility.4. If net peak demand for 60 minutes is not available, give data which is available, specifying period.5. If any employees attend more than one plant, report on line 11 the approximate average number of employees assignable to each plant.6. If gas is used and purchased on a therm basis report the Btu content or the gas and the quantity of fuel burned converted to Mcf.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.9. Items under Cost of Plant are based on USofA accounts. Production expenses do not include Purchased Power, System Control and Load Dispatching, and Other Expenses Classifiedas 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 ofElectric Plant." Indicate plants designed for peak load service. Designate automatically operated plants.11. For a plant equipped with combinations of fossil fuel steam, nuclear steam, hydro, internal combustion or gas-turbine equipment, report each as a separate plant. However, if a gas-turbine unit functions in a combined cycle operation with a conventional steam unit, include the gas-turbine with the steam plant.12. If a nuclear power generating plant, briefly explain by footnote (a) accounting method for cost of power generated including any excess costs attributed to research and development;(b) types of cost units used for the various components of fuel cost; and (c) any other informative data concerning plant type fuel used, fuel enrichment type and quantity for the report periodand other physical and operating characteristics of plant.LineNo.Item(a)Plant Name:Bennett Mountain Plant Name:Boardman Plant Name:Danskin Plant Name:Jim Bridger Plant Name:Langley Gulch PlantName:Valmy1Kind of Plant (Internal Comb, GasTurb, Nuclear)Gas Turbine Steam Gas Turbine Steam Gas Turbine Steam2Type of Constr (Conventional,Outdoor, Boiler, etc)Conventional Conventional Conventional Semi-Outdoor Boiler Conventional Outdoor3Year Originally Constructed 2005 (a)1980 2001 (b)1974 2012 (c)19814Year Last Unit was Installed 2005 1980 2008 1979 2012 19855Total Installed Cap (Max Gen NamePlate Ratings-MW)172.8 (d)0 270.9 (e)775.29 318.45 (f)144.96Net Peak Demand on Plant - MW (60minutes)203 0 286 716 338 1377Plant Hours Connected to Load 4,424 0 3,758 8,760 5,971 3,7788Net Continuous Plant Capability(Megawatts)204 300 3449When Not Limited by CondenserWater 0 (g)0 0 (h)0 0 (i)010When Limited by Condenser Water 0 0 0 0 0 011Average Number of Employees 4 0 6 0 23 012Net Generation, Exclusive of PlantUse - kWh 725,648,000 0 566,667,000 2,244,357,000 1,624,868,000 228,786,00013Cost of Plant: Land and Land Rights 0 106,610 402,745 509,671 2,287,261 1,106,14014Structures and Improvements 1,855,550 0 6,288,751 74,228,852 146,781,147 47,906,56015Equipment Costs 80,978,761 0 146,463,846 644,479,167 250,690,859 209,171,68016Asset Retirement Costs 0 3,767,793 0 36,460,399 0 (308,456)17 Total cost (total 13 thru 20)82,834,311 3,874,403 153,155,342 755,678,089 399,759,267 257,875,92418Cost per KW of Installed Capacity(line 17/5) Including 479.37 565.36 974.7 1,255.33 1,779.6819Production Expenses: Oper, Supv, &Engr 9,121 (154,681)8,640 268,861 637,812 514,42820Fuel46,847,614 0 43,897,776 77,983,147 89,143,609 17,516,17921Coolants and Water (Nuclear PlantsOnly)0 0 0 0 0 022Steam Expenses 0 (2,000)0 6,103,197 0 4,049,01423Steam From Other Sources 0 0 0 0 0 024Steam Transferred (Cr)0 0 0 0 0 025Electric Expenses 516,125 0 913,522 0 3,856,325 1,589,40226Misc Steam (or Nuclear) PowerExpenses 114,173 5 162,360 6,576,575 442,711 1,552,02027Rents000233,996 0 0
28 Allowances 0 0 0 0 0 0
29 Maintenance Supervision and
Engineering 0 (282,132)0 17,707 0 0
30 Maintenance of Structures 25,064 0 37,678 0 81,551 1,142,007
31 Maintenance of Boiler (or reactor)
Plant (86,085)0 10,857 5,527,262 23,709 2,169,915
32 Maintenance of Electric Plant 524,570 0 3,403,525 2,464,174 1,263,542 555,201
33 Maintenance of Misc Steam (or
Nuclear) Plant 0 0 0 8,576,992 0 269,361
34 Total Production Expenses 47,950,582 (438,808)48,434,358 107,751,911 95,449,259 29,357,527
35 Expenses per Net kWh 0.07 0.09 0.05 0.06 0.13
35 Plant Name Bennett Mountain Boardman Boardman Danskin Jim Bridger Jim
Bridger
Langley
Gulch Valmy Valmy
36 Fuel Kind Gas Coal Oil Gas Coal Oil Gas Coal Oil
37 Fuel Unit MCF Tons Barrels MCF Tons Barrels MCF Tons Barrels
38 Quantity (Units) of Fuel
Burned 7,329,649 0 0 5,908,125 1,343,055 6,267 10,996,100 143,943 4,223
39 Avg Heat Cont - Fuel Burned
(btu/indicate if nuclear)1,027 0 0 1,027 9,149 140,000 1,027 10,205 138,778
40 Avg Cost of Fuel/unit, as
Delvd f.o.b. during year 6.39 0 0 7.43 56.87 3.74 8.11 65.85 0
41 Average Cost of Fuel per
Unit Burned 6.39 0 0 7.43 57.31 130.46 8.11 115.57 198.58
42 Average Cost of Fuel
Burned per Million BTU 5.68 0 0 6.59 3.08 22.19 7.17 5.66 34.07
43 Average Cost of Fuel
Burned per kWh Net Gen 0.07 0 0 0.08 0.03 0 0.06 0.08 0
44 Average BTU per kWh Net
Generation 10,374 0 0 10,708 11,166 0 6,950 12,946 0
FERC FORM NO. 1 (REV. 12-03)
Page 402-403
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original
(2) ☐ A Resubmission
Date of Report:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
FOOTNOTE DATA
31 Maintenance of Boiler (or reactor)Plant (86,085)0 10,857 5,527,262 23,709 2,169,91532Maintenance of Electric Plant 524,570 0 3,403,525 2,464,174 1,263,542 555,20133Maintenance of Misc Steam (orNuclear) Plant 0 0 0 8,576,992 0 269,36134Total Production Expenses 47,950,582 (438,808)48,434,358 107,751,911 95,449,259 29,357,52735Expenses per Net kWh 0.07 0.09 0.05 0.06 0.1335Plant Name Bennett Mountain Boardman Boardman Danskin Jim Bridger JimBridger LangleyGulch Valmy Valmy36Fuel Kind Gas Coal Oil Gas Coal Oil Gas Coal Oil37Fuel Unit MCF Tons Barrels MCF Tons Barrels MCF Tons Barrels38Quantity (Units) of FuelBurned 7,329,649 0 0 5,908,125 1,343,055 6,267 10,996,100 143,943 4,22339Avg Heat Cont - Fuel Burned(btu/indicate if nuclear)1,027 0 0 1,027 9,149 140,000 1,027 10,205 138,77840Avg Cost of Fuel/unit, asDelvd f.o.b. during year 6.39 0 0 7.43 56.87 3.74 8.11 65.85 041Average Cost of Fuel perUnit Burned 6.39 0 0 7.43 57.31 130.46 8.11 115.57 198.5842Average Cost of FuelBurned per Million BTU 5.68 0 0 6.59 3.08 22.19 7.17 5.66 34.0743Average Cost of FuelBurned per kWh Net Gen 0.07 0 0 0.08 0.03 0 0.06 0.08 044Average BTU per kWh NetGeneration 10,374 0 0 10,708 11,166 0 6,950 12,946 0FERC FORM NO. 1 (REV. 12-03)Page 402-403
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original
(2) ☐ A Resubmission
Date of Report:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
FOOTNOTE DATA
(a) Concept: YearPlantOriginallyConstructed
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 owning 10%. The unit was placed in commercial operation August 3, 1980 and ceased operations in October 2020.
(b) Concept: YearPlantOriginallyConstructed
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 Power 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.
(c) Concept: YearPlantOriginallyConstructed
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 Power owning 1/2. Unit #1 was placed in commercial operation December 11, 1981, and Unit #2 May 21, 1985. Idaho Power ended its participation in Unit #1 in December 2019.
(d) Concept: InstalledCapacityOfPlant
This footnote applies to line 5 and line 12 through 43. Information reflects Idaho Power Company's share as explained in the note for line 3 page 402 under Boardman.
(e) Concept: InstalledCapacityOfPlant
This footnote applies to line 5 and line 12 through 43. Information reflects Idaho Power Company's share as explained in the note for line 3 page 402 under Jim Bridger.
(f) Concept: InstalledCapacityOfPlant
This footnote applies to line 5 and line 12 through 43. Information reflects Idaho Power Company's share as explained in the note for line 3 page 402 under Valmy.
(g) Concept: NetContinuousPlantCapabilityNotLimitedByCondenserWater
This footnote applies to line 9, 10, and 11. PacifiCorp, as operator of the plant, will report this information.
(h) Concept: NetContinuousPlantCapabilityNotLimitedByCondenserWater
This footnote applies to line 9, 10, and 11. Portland General Electric Company, as operator of the plant, will report this information.
(i) Concept: NetContinuousPlantCapabilityNotLimitedByCondenserWater
This footnote applies to line 9, 10, and 11. Sierra Pacific Power, as operator of the plant, will report this information.
FERC FORM NO. 1 (REV. 12-03)
Page 402-403
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original
(2) ☐ A Resubmission
Date of Report:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
Hydroelectric Generating Plant Statistics
(a) Concept: YearPlantOriginallyConstructedThis 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 NorthwestGenerating Company, with Idaho Power owning 10%. The unit was placed in commercial operation August 3, 1980 and ceased operations in October 2020.(b) Concept: YearPlantOriginallyConstructedThis 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, withIdaho Power 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 #4November 29, 1979.(c) Concept: YearPlantOriginallyConstructedThis 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 andIdaho Power owning 1/2. Unit #1 was placed in commercial operation December 11, 1981, and Unit #2 May 21, 1985. Idaho Power ended its participation in Unit #1 in December 2019.(d) Concept: InstalledCapacityOfPlantThis footnote applies to line 5 and line 12 through 43. Information reflects Idaho Power Company's share as explained in the note for line 3 page 402 under Boardman.(e) Concept: InstalledCapacityOfPlantThis footnote applies to line 5 and line 12 through 43. Information reflects Idaho Power Company's share as explained in the note for line 3 page 402 under Jim Bridger.(f) Concept: InstalledCapacityOfPlantThis footnote applies to line 5 and line 12 through 43. Information reflects Idaho Power Company's share as explained in the note for line 3 page 402 under Valmy.(g) Concept: NetContinuousPlantCapabilityNotLimitedByCondenserWaterThis footnote applies to line 9, 10, and 11. PacifiCorp, as operator of the plant, will report this information.(h) Concept: NetContinuousPlantCapabilityNotLimitedByCondenserWaterThis footnote applies to line 9, 10, and 11. Portland General Electric Company, as operator of the plant, will report this information.(i) Concept: NetContinuousPlantCapabilityNotLimitedByCondenserWaterThis footnote applies to line 9, 10, and 11. Sierra Pacific Power, as operator of the plant, will report this information.FERC FORM NO. 1 (REV. 12-03)Page 402-403
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original
(2) ☐ A Resubmission
Date of Report:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
Hydroelectric Generating Plant Statistics
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 11 the approximate average number of employees assignable to each plant.
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.
Hydroelectric Generating Plant Statistics
Line
No.
Item
(a)
FERC Licensed Project No.
2736
Plant Name:
American Falls
FERC Licensed Project No.
1975
Plant Name:
Bliss
FERC Licensed Project No.
1971
Plant Name:
Brownlee
1 Kind of Plant (Run-of-River or Storage)Run-of-River Run-of-River Storage
2 Plant Construction type (Conventional or Outdoor)Outdoor Outdoor Outdoor
3 Year Originally Constructed 1978 1949 1958
4 Year Last Unit was Installed 1978 1950 1980
5 Total installed cap (Gen name plate Rating in MW)92.34 75.04 675
6 Net Peak Demand on Plant-Megawatts (60 minutes)68 52 649
7 Plant Hours Connect to Load 5,110 8,760 8,674
8 Net Plant Capability (in megawatts)
9 (a) Under Most Favorable Oper Conditions 70 75 714
10 (b) Under the Most Adverse Oper Conditions 1 220
11 Average Number of Employees 4 4 7
12 Net Generation, Exclusive of Plant Use - kWh 262,202,000 295,069,000 2,087,723,000
13 Cost of Plant
14 Land and Land Rights 875,319 768,993 18,542,080
15 Structures and Improvements 12,673,865 1,944,695 51,233,164
16 Reservoirs, Dams, and Waterways 5,224,768 12,215,938 71,583,400
17 Equipment Costs 37,144,210 20,543,211 138,908,639
18 Roads, Railroads, and Bridges 839,276 486,477 2,820,134
19 Asset Retirement Costs
20 Total cost (total 13 thru 20)56,757,438 35,959,314 283,087,417
21 Cost per KW of Installed Capacity (line 20 / 5)614.66 479.2 419.39
22 Production Expenses
23 Operation Supervision and Engineering 230,110 259,479 849,456
24 Water for Power 174,371 196,626 504,772
25 Hydraulic Expenses 303,721 342,528 1,012,975
26 Electric Expenses 117,518 85,340 435,767
27 Misc Hydraulic Power Generation Expenses 289,245 373,295 847,872
28 Rents 16,442 18,541 47,597
29 Maintenance Supervision and Engineering 8,315 9,855 15,609
30 Maintenance of Structures 45,649 45,793 82,092
31 Maintenance of Reservoirs, Dams, and Waterways 16,326 38,506 26,690
32 Maintenance of Electric Plant 84,259 126,716 166,079
33 Maintenance of Misc Hydraulic Plant 249,381 257,881 408,653
34 Total Production Expenses (total 23 thru 33)1,535,337 1,754,560 4,397,562
35 Expenses per net kWh 0.01 0.01 0
FERC FORM NO. 1 (REV. 12-03)
Page 406-407
Hydroelectric Generating Plant Statistics
Line
No.
FERC Licensed Project No.
2055
Plant Name:
C J Strike
FERC Licensed Project No.
2848
Plant Name:
Cascade
FERC Licensed Project No.
1971
Plant Name:
Common Facilities
FERC Licensed Project No.
1971
Plant Name:
Hells Canyon
1 Run-of-River Run-of-River StorageFERC FORM NO. 1 (REV. 12-03)
Page 406-407
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 11 the approximate average number of employees assignable to each plant.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 PurchasedPower, 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.Hydroelectric Generating Plant StatisticsLineNo.Item(a)FERC Licensed Project No.2736Plant Name:American Falls FERC Licensed Project No.1975Plant Name:Bliss FERC Licensed Project No.1971Plant Name:Brownlee1Kind of Plant (Run-of-River or Storage)Run-of-River Run-of-River Storage2Plant Construction type (Conventional or Outdoor)Outdoor Outdoor Outdoor3Year Originally Constructed 1978 1949 19584Year Last Unit was Installed 1978 1950 19805Total installed cap (Gen name plate Rating in MW)92.34 75.04 6756Net Peak Demand on Plant-Megawatts (60 minutes)68 52 6497Plant Hours Connect to Load 5,110 8,760 8,6748Net Plant Capability (in megawatts)9 (a) Under Most Favorable Oper Conditions 70 75 71410(b) Under the Most Adverse Oper Conditions 1 22011Average Number of Employees 4 4 712Net Generation, Exclusive of Plant Use - kWh 262,202,000 295,069,000 2,087,723,00013Cost of Plant14Land and Land Rights 875,319 768,993 18,542,08015Structures and Improvements 12,673,865 1,944,695 51,233,16416Reservoirs, Dams, and Waterways 5,224,768 12,215,938 71,583,40017Equipment Costs 37,144,210 20,543,211 138,908,63918Roads, Railroads, and Bridges 839,276 486,477 2,820,13419Asset Retirement Costs20Total cost (total 13 thru 20)56,757,438 35,959,314 283,087,41721Cost per KW of Installed Capacity (line 20 / 5)614.66 479.2 419.3922Production Expenses23Operation Supervision and Engineering 230,110 259,479 849,45624Water for Power 174,371 196,626 504,77225Hydraulic Expenses 303,721 342,528 1,012,97526Electric Expenses 117,518 85,340 435,76727Misc Hydraulic Power Generation Expenses 289,245 373,295 847,87228Rents16,442 18,541 47,59729Maintenance Supervision and Engineering 8,315 9,855 15,60930Maintenance of Structures 45,649 45,793 82,09231Maintenance of Reservoirs, Dams, and Waterways 16,326 38,506 26,69032Maintenance of Electric Plant 84,259 126,716 166,07933Maintenance of Misc Hydraulic Plant 249,381 257,881 408,65334Total Production Expenses (total 23 thru 33)1,535,337 1,754,560 4,397,56235Expenses per net kWh 0.01 0.01 0FERC FORM NO. 1 (REV. 12-03)Page 406-407
Hydroelectric Generating Plant Statistics
Line
No.
FERC Licensed Project No.
2055
Plant Name:
C J Strike
FERC Licensed Project No.
2848
Plant Name:
Cascade
FERC Licensed Project No.
1971
Plant Name:
Common Facilities
FERC Licensed Project No.
1971
Plant Name:
Hells Canyon
1 Run-of-River Run-of-River StorageFERC FORM NO. 1 (REV. 12-03)
Page 406-407
1 Run-of-River Run-of-River Storage
2 Outdoor Outdoor Outdoor
3 1952 1983 1967
4 1952 1984 1967
5 82.8 12.42 391.5
6 86 12 435
7 8,760 8,719 8,746
8
9 92 13 444
10 84 1 137
11 5 2 4
12 377,063,000 35,535,000 1,789,832,000
13
14 5,744,769 82,142 114,368 2,222,392
15 10,792,749 7,333,768 70,068,470 6,790,045
16 12,664,444 3,145,631 13,556,785 56,025,711
17 15,104,070 13,508,220 3,898,090 58,190,403
18 1,602,868 122,668 142,581 1,357,863
19
20 45,908,900 24,192,429 87,780,294 124,586,414
21 554.46 1,947.86 318.23
22
23 543,059 159,245 414,011
24 279,177 112,303 292,825
25 429,769 222,304 13,128,083 579,650
26 92,435 103,833 247,605
27 440,680 214,563 583,812
28 26,325 10,589 27,612
29 17,080 8,402 68,606
30 136,118 40,580 43,564
31 103,567 7,621 1,771,346
32 264,654 136,228 642,958
33 308,334 183,506 113,609 546,437
34 2,641,198 1,199,174 13,241,692 5,218,426
35 0.01 0.03 0
FERC FORM NO. 1 (REV. 12-03)
Page 406-407
Hydroelectric Generating Plant Statistics
Line
No.
FERC Licensed Project No.
2055
Plant Name:
C J Strike
FERC Licensed Project No.
2848
Plant Name:
Cascade
FERC Licensed Project No.
1971
Plant Name:
Common Facilities
FERC Licensed Project No.
1971
Plant Name:
Hells Canyon
Hydroelectric Generating Plant Statistics
Line
No.
FERC Licensed Project No.
2061
Plant Name:
Lower Salmon
FERC Licensed Project No.
2726
Plant Name:
Malad
FERC Licensed Project No.
2899
Plant Name:
Milner
FERC Licensed Project No.
1971
Plant Name:
Oxbow
1 Run-of-River Run-of-River Run-of-River StorageFERC FORM NO. 1 (REV. 12-03)
Page 406-407
1 Run-of-River Run-of-River Storage2OutdoorOutdoorOutdoor31952198319674195219841967582.8 12.42 391.56861243578,760 8,719 8,746899213444108411371152412377,063,000 35,535,000 1,789,832,00013145,744,769 82,142 114,368 2,222,3921510,792,749 7,333,768 70,068,470 6,790,0451612,664,444 3,145,631 13,556,785 56,025,7111715,104,070 13,508,220 3,898,090 58,190,403181,602,868 122,668 142,581 1,357,863192045,908,900 24,192,429 87,780,294 124,586,41421554.46 1,947.86 318.232223543,059 159,245 414,01124279,177 112,303 292,82525429,769 222,304 13,128,083 579,6502692,435 103,833 247,60527440,680 214,563 583,8122826,325 10,589 27,6122917,080 8,402 68,60630136,118 40,580 43,56431103,567 7,621 1,771,34632264,654 136,228 642,95833308,334 183,506 113,609 546,437342,641,198 1,199,174 13,241,692 5,218,426350.01 0.03 0FERC FORM NO. 1 (REV. 12-03)Page 406-407Hydroelectric Generating Plant StatisticsLineNo.FERC Licensed Project No.2055Plant Name:C J Strike FERC Licensed Project No.2848Plant Name:Cascade FERC Licensed Project No.1971Plant Name:Common Facilities FERC Licensed Project No.1971Plant Name:Hells Canyon
Hydroelectric Generating Plant Statistics
Line
No.
FERC Licensed Project No.
2061
Plant Name:
Lower Salmon
FERC Licensed Project No.
2726
Plant Name:
Malad
FERC Licensed Project No.
2899
Plant Name:
Milner
FERC Licensed Project No.
1971
Plant Name:
Oxbow
1 Run-of-River Run-of-River Run-of-River StorageFERC FORM NO. 1 (REV. 12-03)
Page 406-407
2 Outdoor Outdoor Conventional Outdoor
3 1949 1948 1992 1961
4 1949 1948 1992 1961
5 60 21.77 59.45 190
6 38 23 35 209
7 8,760 8,540 2,076 8,755
8
9 71 31 36 210
10 60 21 1 202
11 4 1 2 6
12 187,857,000 159,012,000 28,958,000 900,050,000
13
14 424,428 205,376 139,356 1,212,841
15 3,605,915 15,869,882 10,711,507 22,452,830
16 8,121,814 7,598,766 17,779,586 35,917,788
17 55,603,329 18,777,532 29,677,158 22,533,329
18 88,693 1,507,442 501,877 3,674,733
19
20 67,844,179 43,958,998 58,809,484 85,791,521
21 1,130.74 2,019.25 989.23 451.53
22
23 370,156 65,162 161,431 723,884
24 226,697 49,378 122,558 392,862
25 369,789 100,885 186,238 781,278
26 179,487 24,774 63,045 264,013
27 303,422 75,535 250,389 679,398
28 21,376 4,656 11,556 37,044
29 7,858 4,643 6,692 15,064
30 89,990 10,668 38,056 60,303
31 19,748 43,079 25,246 59,599
32 100,500 63,510 90,964 213,940
33 163,631 103,669 164,149 312,521
34 1,852,654 545,959 1,120,324 3,539,906
35 0.01 0 0.04 0
FERC FORM NO. 1 (REV. 12-03)
Page 406-407
Hydroelectric Generating Plant Statistics
Line
No.
FERC Licensed Project No.
2061
Plant Name:
Lower Salmon
FERC Licensed Project No.
2726
Plant Name:
Malad
FERC Licensed Project No.
2899
Plant Name:
Milner
FERC Licensed Project No.
1971
Plant Name:
Oxbow
Hydroelectric Generating Plant Statistics
Line
No.
FERC Licensed Project No.
2778
Plant Name:
Shoshone Falls
FERC Licensed Project No.
503
Plant Name:
Swan Falls
FERC Licensed Project No.
18
Plant Name:
Twin Falls
FERC Licensed Project No.
2777
Plant Name:
Upper Salmon
1 Run-of-River Run-of-River Run-of-River Run-of-RiverFERC FORM NO. 1 (REV. 12-03)
Page 406-407
2 Outdoor Outdoor Conventional Outdoor319491948199219614194919481992196156021.77 59.45 190638233520978,760 8,540 2,076 8,75589713136210106021120211412612187,857,000 159,012,000 28,958,000 900,050,0001314424,428 205,376 139,356 1,212,841153,605,915 15,869,882 10,711,507 22,452,830168,121,814 7,598,766 17,779,586 35,917,7881755,603,329 18,777,532 29,677,158 22,533,3291888,693 1,507,442 501,877 3,674,733192067,844,179 43,958,998 58,809,484 85,791,521211,130.74 2,019.25 989.23 451.532223370,156 65,162 161,431 723,88424226,697 49,378 122,558 392,86225369,789 100,885 186,238 781,27826179,487 24,774 63,045 264,01327303,422 75,535 250,389 679,3982821,376 4,656 11,556 37,044297,858 4,643 6,692 15,0643089,990 10,668 38,056 60,3033119,748 43,079 25,246 59,59932100,500 63,510 90,964 213,94033163,631 103,669 164,149 312,521341,852,654 545,959 1,120,324 3,539,906350.01 0 0.04 0FERC FORM NO. 1 (REV. 12-03)Page 406-407Hydroelectric Generating Plant StatisticsLineNo.FERC Licensed Project No.2061Plant Name:Lower Salmon FERC Licensed Project No.2726Plant Name:Malad FERC Licensed Project No.2899Plant Name:Milner FERC Licensed Project No.1971Plant Name:Oxbow
Hydroelectric Generating Plant Statistics
Line
No.
FERC Licensed Project No.
2778
Plant Name:
Shoshone Falls
FERC Licensed Project No.
503
Plant Name:
Swan Falls
FERC Licensed Project No.
18
Plant Name:
Twin Falls
FERC Licensed Project No.
2777
Plant Name:
Upper Salmon
1 Run-of-River Run-of-River Run-of-River Run-of-RiverFERC FORM NO. 1 (REV. 12-03)
Page 406-407
2 Conventional Conventional Conventional Outdoor
3 1907 1910 1935 1937
4 1921 1994 1935 1947
5 14.73 27.17 52.9 34.5
6 15 15 34 34
7 6,368 6,368 6,299 8,759
8
9 16 16 44 37
10 11 14 50 32
11 2 4 3 4
12 42,312,000 113,009,000 37,126,000 169,512,000
13
14 313,328 309,958 255,499 207,636
15 10,572,266 28,364,180 12,004,023 3,794,132
16 14,827,399 15,850,156 9,031,704 19,724,184
17 19,476,797 32,765,484 24,963,648 9,723,108
18 468,609 2,261,020 2,642,015 29,359
19
20 45,658,399 79,550,798 48,896,889 33,478,419
21 3,099.69 2,927.89 924.33 970.39
22
23 130,367 340,493 649,761 323,222
24 98,788 243,326 277,275 244,852
25 155,202 414,645 421,307 421,901
26 81,950 156,245 62,271 211,092
27 165,367 401,172 362,341 364,572
28 9,315 22,944 26,145 23,088
29 4,656 10,533 5,398 10,367
30 48,490 126,787 42,574 98,421
31 27,270 30,146 21,916 56,264
32 59,884 130,361 95,243 173,952
33 85,875 213,873 97,106 164,613
34 867,164 2,090,525 2,061,337 2,092,344
35 0.02 0.02 0.06 0.01
FERC FORM NO. 1 (REV. 12-03)
Page 406-407
Hydroelectric Generating Plant Statistics
Line
No.
FERC Licensed Project No.
2778
Plant Name:
Shoshone Falls
FERC Licensed Project No.
503
Plant Name:
Swan Falls
FERC Licensed Project No.
18
Plant Name:
Twin Falls
FERC Licensed Project No.
2777
Plant Name:
Upper Salmon
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original
(2) ☐ A Resubmission
Date of Report:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
GENERATING PLANT STATISTICS (Small Plants)
Line Name of Plant Year Orig. Const.Installed Capacity Name Net Peak Demand MW (60 Net Generation Excluding Cost of PlantFERC FORM NO. 1 (REV. 12-03)
2 Conventional Conventional Conventional Outdoor3190719101935193741921199419351947514.73 27.17 52.9 34.561515343476,368 6,368 6,299 8,759891616443710111450321124341242,312,000 113,009,000 37,126,000 169,512,0001314313,328 309,958 255,499 207,6361510,572,266 28,364,180 12,004,023 3,794,1321614,827,399 15,850,156 9,031,704 19,724,1841719,476,797 32,765,484 24,963,648 9,723,10818468,609 2,261,020 2,642,015 29,359192045,658,399 79,550,798 48,896,889 33,478,419213,099.69 2,927.89 924.33 970.392223130,367 340,493 649,761 323,2222498,788 243,326 277,275 244,85225155,202 414,645 421,307 421,9012681,950 156,245 62,271 211,09227165,367 401,172 362,341 364,572289,315 22,944 26,145 23,088294,656 10,533 5,398 10,3673048,490 126,787 42,574 98,4213127,270 30,146 21,916 56,2643259,884 130,361 95,243 173,9523385,875 213,873 97,106 164,61334867,164 2,090,525 2,061,337 2,092,344350.02 0.02 0.06 0.01FERC FORM NO. 1 (REV. 12-03)Page 406-407Hydroelectric Generating Plant StatisticsLineNo.FERC Licensed Project No.2778Plant Name:Shoshone Falls FERC Licensed Project No.503Plant Name:Swan Falls FERC Licensed Project No.18Plant Name:Twin Falls FERC Licensed Project No.2777Plant Name:Upper Salmon
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original
(2) ☐ A Resubmission
Date of Report:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
GENERATING PLANT STATISTICS (Small Plants)
Line Name of Plant Year Orig. Const.Installed Capacity Name Net Peak Demand MW (60 Net Generation Excluding Cost of PlantFERC FORM NO. 1 (REV. 12-03)Line
No.
Name of Plant
(a)
Year Orig. Const.
(b)
Installed Capacity Name
Plate Rating (MW)
(c)
Net Peak Demand MW (60
min)
(d)
Net Generation Excluding
Plant Use
(e)
Cost of Plant
(f)
1 Hydro
2 Clear Lakes 1937 2.5 2.3 8,396 4,485,042
3 Thousand Springs 1912 6.8 6.8 54,222 13,518,763
4 Internal Combustion
5
(a)
Salmon Diesel 1967 5 5.5 61 986,873
FERC FORM NO. 1 (REV. 12-03)
Page 410-411
GENERATING PLANT STATISTICS (Small Plants)
Production Expenses Production Expenses
Line
No.
Plant Cost (Incl Asset
Retire. Costs) Per MW
(g)
Operation Exc'l. Fuel
(h)
Fuel Production
Expenses
(i)
Maintenance Production
Expenses
(j)
Kind of Fuel
(k)
Fuel Costs (in cents
(per Million Btu)
(l)
1FERC FORM NO. 1 (REV. 12-03)
Page 410-411
LineNo.Name of Plant(a)Year Orig. Const.(b)Installed Capacity NamePlate Rating (MW)(c)Net Peak Demand MW (60min)(d)Net Generation ExcludingPlant Use(e)Cost of Plant(f)1 Hydro2Clear Lakes 1937 2.5 2.3 8,396 4,485,0423Thousand Springs 1912 6.8 6.8 54,222 13,518,7634Internal Combustion5(a)Salmon Diesel 1967 5 5.5 61 986,873FERC FORM NO. 1 (REV. 12-03)Page 410-411
GENERATING PLANT STATISTICS (Small Plants)
Production Expenses Production Expenses
Line
No.
Plant Cost (Incl Asset
Retire. Costs) Per MW
(g)
Operation Exc'l. Fuel
(h)
Fuel Production
Expenses
(i)
Maintenance Production
Expenses
(j)
Kind of Fuel
(k)
Fuel Costs (in cents
(per Million Btu)
(l)
1FERC FORM NO. 1 (REV. 12-03)
Page 410-411
2 1,794,017 100,981 20,489
3 1,988,053 492,435 237,495
4
5 197,375 Diesel
FERC FORM NO. 1 (REV. 12-03)
Page 410-411
GENERATING PLANT STATISTICS (Small Plants)
Production Expenses Production Expenses
Line
No.
Plant Cost (Incl Asset
Retire. Costs) Per MW
(g)
Operation Exc'l. Fuel
(h)
Fuel Production
Expenses
(i)
Maintenance Production
Expenses
(j)
Kind of Fuel
(k)
Fuel Costs (in cents
(per Million Btu)
(l)
GENERATING PLANT STATISTICS (Small Plants)
Line No.Generation Type
(m)
1
2FERC FORM NO. 1 (REV. 12-03)
Page 410-411
2 1,794,017 100,981 20,48931,988,053 492,435 237,49545197,375 DieselFERC FORM NO. 1 (REV. 12-03)Page 410-411GENERATING PLANT STATISTICS (Small Plants)Production Expenses Production ExpensesLineNo.Plant Cost (Incl AssetRetire. Costs) Per MW(g)Operation Exc'l. Fuel(h)Fuel ProductionExpenses(i)Maintenance ProductionExpenses(j)Kind of Fuel(k)Fuel Costs (in cents(per Million Btu)(l)
GENERATING PLANT STATISTICS (Small Plants)
Line No.Generation Type
(m)
1
2FERC FORM NO. 1 (REV. 12-03)
Page 410-411
3
4
5
FERC FORM NO. 1 (REV. 12-03)
Page 410-411
GENERATING PLANT STATISTICS (Small Plants)
Line No.Generation Type
(m)
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original
(2) ☐ A Resubmission
Date of Report:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
FOOTNOTE DATA
345FERC FORM NO. 1 (REV. 12-03)Page 410-411GENERATING PLANT STATISTICS (Small Plants)Line No.Generation Type(m)
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original
(2) ☐ A Resubmission
Date of Report:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
FOOTNOTE DATA
(a) Concept: PlantName
Salmon units are classified as standby.
FERC FORM NO. 1 (REV. 12-03)
Page 410-411
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original
(2) ☐ A Resubmission
Date of Report:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
ENERGY STORAGE OPERATIONS (Large Plants)
MWHsFERC FORM NO. 1 ((NEW 12-12))
(a) Concept: PlantNameSalmon units are classified as standby.FERC FORM NO. 1 (REV. 12-03)Page 410-411
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original
(2) ☐ A Resubmission
Date of Report:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
ENERGY STORAGE OPERATIONS (Large Plants)
MWHsFERC FORM NO. 1 ((NEW 12-12))
Line
No.
Name of the Energy Storage Project
(a)
Functional
Classification
(b)
Location of the
Project
(c)
MWHs
(d)
MWHs delivered to the
grid to support
Production
(e)
MWHs delivered to the
grid to support
Transmission
(f)
delivered to
the grid to
support
Distribution
(g)
1 Hemingway BESS Distribution Owyhee
County, ID 16,572 14,460
2 Black Mesa BESS Distribution Elmore County,
ID 874 598
35 TOTAL 17,446 0 0 15,058
FERC FORM NO. 1 ((NEW 12-12))
Page 414
ENERGY STORAGE OPERATIONS (Large Plants)
Line
MWHs Lost During
Conversion, Storage and
Discharge of Energy
MWHs Lost During
Conversion, Storage and
Discharge of Energy
MWHs Lost During
Conversion, Storage and
Discharge of Energy MWHs Sold Revenues from Energy
Storage Operations
Power Purchased for
Storage Operations
Fuel Costs
from
associated
fuel accounts
for Storage
Operations
FERC FORM NO. 1 ((NEW 12-12))
Page 414
LineNo.Name of the Energy Storage Project(a)FunctionalClassification(b)Location of theProject(c)MWHs(d)MWHs delivered to thegrid to supportProduction(e)MWHs delivered to thegrid to supportTransmission(f)delivered tothe grid tosupportDistribution(g)1 Hemingway BESS Distribution OwyheeCounty, ID 16,572 14,4602Black Mesa BESS Distribution Elmore County,ID 874 59835TOTAL17,446 0 0 15,058FERC FORM NO. 1 ((NEW 12-12))Page 414
ENERGY STORAGE OPERATIONS (Large Plants)
Line
MWHs Lost During
Conversion, Storage and
Discharge of Energy
MWHs Lost During
Conversion, Storage and
Discharge of Energy
MWHs Lost During
Conversion, Storage and
Discharge of Energy MWHs Sold Revenues from Energy
Storage Operations
Power Purchased for
Storage Operations
Fuel Costs
from
associated
fuel accounts
for Storage
Operations
FERC FORM NO. 1 ((NEW 12-12))
Page 414
Line
No.Discharge of Energy
Production
(h)
Discharge of Energy
Transmission
(i)
Discharge of Energy
Distribution
(j)
MWHs Sold
(k)Storage Operations
(l)
Storage Operations
(555.1) (Dollars)
(m)
Operations
Associated
with Self-
Generated
Power
(Dollars)
(n)
1 2,112
2 276
35 0 0 2,388 0 0 0 0
FERC FORM NO. 1 ((NEW 12-12))
Page 414
ENERGY STORAGE OPERATIONS (Large Plants)
Line
No.
Other Costs Associated with Self-
Generated Power (Dollars)
(o)
Account for Project
Costs
(p)
Production (Dollars)
(q)
Transmission (Dollars)
(r)
Distribution (Dollars)
(s)
1 101363 110,007,941
2 101363 30,764,772FERC FORM NO. 1 ((NEW 12-12))
LineNo.Discharge of EnergyProduction(h)Discharge of EnergyTransmission(i)Discharge of EnergyDistribution(j)MWHs Sold(k)Storage Operations(l)Storage Operations(555.1) (Dollars)(m)OperationsAssociatedwith Self-GeneratedPower(Dollars)(n)1 2,112227635002,388 0 0 0 0FERC FORM NO. 1 ((NEW 12-12))Page 414
ENERGY STORAGE OPERATIONS (Large Plants)
Line
No.
Other Costs Associated with Self-
Generated Power (Dollars)
(o)
Account for Project
Costs
(p)
Production (Dollars)
(q)
Transmission (Dollars)
(r)
Distribution (Dollars)
(s)
1 101363 110,007,941
2 101363 30,764,772FERC FORM NO. 1 ((NEW 12-12))2 101363 30,764,772
35 0 0 0 140,772,713
FERC FORM NO. 1 ((NEW 12-12))
Page 414
ENERGY STORAGE OPERATIONS (Large Plants)
Line
No.
Other Costs Associated with Self-
Generated Power (Dollars)
(o)
Account for Project
Costs
(p)
Production (Dollars)
(q)
Transmission (Dollars)
(r)
Distribution (Dollars)
(s)
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original
(2) ☐ A Resubmission
Date of Report:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
TRANSMISSION LINE STATISTICS
LENGTH
(Pole miles) -
LENGTH
(Pole miles) -
FERC FORM NO. 1 (ED. 12-87)
2 101363 30,764,77235000140,772,713FERC FORM NO. 1 ((NEW 12-12))Page 414ENERGY STORAGE OPERATIONS (Large Plants)LineNo.Other Costs Associated with Self-Generated Power (Dollars)(o)Account for ProjectCosts(p)Production (Dollars)(q)Transmission (Dollars)(r)Distribution (Dollars)(s)
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original
(2) ☐ A Resubmission
Date of Report:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
TRANSMISSION LINE STATISTICS
LENGTH
(Pole miles) -
LENGTH
(Pole miles) -
FERC FORM NO. 1 (ED. 12-87)
DESIGNATION DESIGNATION
VOLTAGE (KV) -
(Indicate where other
than 60 cycle, 3
phase)
VOLTAGE (KV) -
(Indicate where other
than 60 cycle, 3
phase)
(Pole miles) -
(In the case
of
underground
lines report
circuit miles)
(Pole miles) -
(In the case
of
underground
lines report
circuit miles)
Line
No.From To Operating Designated
Type of
Supporting
Structure
On Structure
of Line
Designated
On
Structures of
Another Line
Number
of
Circuits
(a)(b)(c)(d)(e)(f)(g)(h)
1 Borah
(a)
Midpoint 345 500 S Tower 62.35 0 1
2 Boardman
(b)
Slatt 500 500 S Tower 1.79 0 1
3 Summer lake
(c)
Hemingway 500 500 S Tower 0.08 0 1
4 Hemingway
(d)
Midpoint 500 500 S Tower 0.15 0 1
5 Summer Lake
(e)
Hemingway 500 500 S Tower 53.07 0 1
6 Hemingway
(f)
Midpoint 500 500 S Tower 47.76 0 1
7 Jim Bridger
(g)
Goshen 345 345 S Tower 66.15 0 1
8 State Line Midpoint 345 345 S Tower 76.05 0 2
9 Rogerson Midpoint 345 345 S Tower 1.08 0 1
10 Kinport
(h)
Borah 345 345 S Tower 19.81 0 1
11 Jim Bridger
(i)
Populus 345 345 S Tower 60.93 0 1
12 Populus
(j)
Kinport 345 345 S Tower 7.42 0 1
13 Jim Bridger
(k)
Populus 345 345 S Tower 61.1 0 1
14 Populus
(l)
Borah 345 345 S Tower 9.05 0 1
15 Goshen
(m)
Kinport 345 345 S Tower 7.49 0 1
16 Midpoint
(n)
Borah #1 345 345 H Wood 51.07 0 1
17 Midpoint
(o)
Borah #2 345 345 H Wood 49.98 0 2
18 Adelaide Tap
(p)
Adelaide 345 345 H Wood 1.72 0 2
19 Quartz LaGrande 230 230 H Wood 45.97 0 1
20 Midpoint Hunt 230 230 S Tower 0.7 0 2
21 Brady Antelope 230 230 H Wood 56.38 0 1
22 Brady Treasureton 230 230 H Wood 0.08 0 1
23 Brady #1 & #2 Kinport 230 230 S Tower 17.94 0 2
24 Brownlee Ontario 230 230 S Tower 72.67 0 1
25 Mora Bowmont 138 230 S P Wood 9.99 0 1
26 Mora Bowmont 138 230 H Wood 8.71 0 1
27 Caldwell Locust 230 230 SP Steel 18.5 0 1
28 Boise Bench Caldwell 230 230 S Tower 7.69 0 1
29 Boise Bench Caldwell 230 230 H Wood 33.49 0 1
30 Boise Bench Cloverdale 230 230 S Tower 16.08 0 2
31 Boardman
(q)
Dalreed Sub 230 230 H Wood 1.67 0 1
32 Brownlee Oxbow 230 230 SP Steel 10.96 0 2
FERC FORM NO. 1 (ED. 12-87)
Page 422-423
DESIGNATION DESIGNATION VOLTAGE (KV) -(Indicate where otherthan 60 cycle, 3phase)VOLTAGE (KV) -(Indicate where otherthan 60 cycle, 3phase)(Pole miles) -(In the caseofundergroundlines reportcircuit miles)(Pole miles) -(In the caseofundergroundlines reportcircuit miles)LineNo.From To Operating Designated Type ofSupportingStructure On Structureof LineDesignated OnStructures ofAnother Line NumberofCircuits(a)(b)(c)(d)(e)(f)(g)(h)1 Borah (a)Midpoint 345 500 S Tower 62.35 0 12Boardman(b)Slatt 500 500 S Tower 1.79 0 13Summer lake (c)Hemingway 500 500 S Tower 0.08 0 14Hemingway(d)Midpoint 500 500 S Tower 0.15 0 15Summer Lake (e)Hemingway 500 500 S Tower 53.07 0 16Hemingway(f)Midpoint 500 500 S Tower 47.76 0 17Jim Bridger (g)Goshen 345 345 S Tower 66.15 0 18State Line Midpoint 345 345 S Tower 76.05 0 29RogersonMidpoint345345S Tower 1.08 0 110Kinport(h)Borah 345 345 S Tower 19.81 0 111Jim Bridger (i)Populus 345 345 S Tower 60.93 0 112Populus(j)Kinport 345 345 S Tower 7.42 0 113Jim Bridger (k)Populus 345 345 S Tower 61.1 0 114Populus(l)Borah 345 345 S Tower 9.05 0 115Goshen(m)Kinport 345 345 S Tower 7.49 0 116Midpoint(n)Borah #1 345 345 H Wood 51.07 0 117Midpoint(o)Borah #2 345 345 H Wood 49.98 0 218Adelaide Tap (p)Adelaide 345 345 H Wood 1.72 0 219QuartzLaGrande230230H Wood 45.97 0 120MidpointHunt230230S Tower 0.7 0 221BradyAntelope230230H Wood 56.38 0 122BradyTreasureton230230H Wood 0.08 0 123Brady #1 & #2 Kinport 230 230 S Tower 17.94 0 224BrownleeOntario230230S Tower 72.67 0 125MoraBowmont138230S P Wood 9.99 0 126MoraBowmont138230H Wood 8.71 0 127CaldwellLocust230230SP Steel 18.5 0 128Boise Bench Caldwell 230 230 S Tower 7.69 0 129Boise Bench Caldwell 230 230 H Wood 33.49 0 130Boise Bench Cloverdale 230 230 S Tower 16.08 0 231Boardman(q)Dalreed Sub 230 230 H Wood 1.67 0 132BrownleeOxbow230230SP Steel 10.96 0 2FERC FORM NO. 1 (ED. 12-87)Page 422-423
33 Caldwell Ontario 230 230 H Wood 30.06 0 1
34 Caldwell Ontario 230 230 S Tower 3.14 0 1
35 Bennett Mtn PP Rattlesnake TS 230 230 SP Steel 4.39 0 1
36 Borah Hunt 230 230 H Steel 68.12 0 1
37 Danskin Hubbard 230 230 H Steel 36.25 0 1
38 Danskin Hubbard 230 230 SP Steel 1.84 0 1
39 Danskin Hubbard 230 230 SP Steel 1.3 0 2
40 Danskin Bennett Mtn 230 230 SP Steel 5.39 0 1
41 Hemingway Bowmont 230 230 SP Steel 12.94 0 1
42 Langley Gulch Galloway Rd 138 230 SP Steel 14.19 0 1
43 Galloway Rd Willis Tap 138 230 SP Steel 2.09 0 1
44 Walla Walla
(r)
Hurricane 230 230 H Wood 31.66 0 1
45 Cloverdale Hubbard 230 230 SP Steel 6.86 0 2
46 Bowmont Hubbard 0 230 0 0 0
47 Boise Bench Midpoint #1 230 230 S Tower 0.71 0 1
48 Boise Bench Midpoint #1 230 230 H Wood 109.65 0 1
49 Brownlee Quartz Jct 230 230 S Tower 1.51 0 1
50 Brownlee Quartz Jct 230 230 H Wood 41.3 0 1
51 Brownlee Boise Bench #1 & #2 230 230 S Tower 99.78 0 2
52 Oxbow Brownlee 230 230 S Tower 10.32 0 2
53 Boise Bench Midpoint #2 230 230 S Tower 3.49 0 1
54 Boise Bench Midpoint #2 230 230 H Wood 102.13 0 1
55 Oxbow Pallette Jct 230 230 S Tower 19.98 0 2
56 Pallette Jct Imnaha 230 230 H Wood 24.43 0 2
57 Hells Canyon Palette Jct 230 230 S Tower 9.05 0 2
58 Brownlee Boise Bench 230 230 S Tower 102.1 0 2
59 Boise Bench Midpoint #3 230 230 H Wood 106.29 0 1
60 Palette Jct Enterprise 230 230 H Wood 29.6 0 1
61 Borah Brady #2 230 230 S Tower 0.42 0 1
62 Borah Brady #2 230 230 H Wood 3.52 0 1
63 Borah Brady #1 230 230 H Wood 3.84 0 1
64 Goshen
(s)
State Line 161 161 H Wood 40.89 0 1
65 Don Goshen 161 161 S Tower 2.37 0 2
66 Don Goshen 161 161 H Wood 16.49 0 2
67 Don Goshen 138 161 H Wood 29.66 0 2
68 Antelope
(t)
Goshen 161 161 H Wood 5.68 0 1
69 Goshen
(u)
State Line 161 161 H Wood 10.9 0 1
70 Goshen
(v)
State Line 161 161 H Wood 7.84 0 1
71 American Falls PP Adelaide 138 138 H Wood 14.09 0 2
TRANSMISSION LINE STATISTICS
DESIGNATION DESIGNATION
VOLTAGE (KV) -
(Indicate where other
than 60 cycle, 3
phase)
VOLTAGE (KV) -
(Indicate where other
than 60 cycle, 3
phase)
LENGTH
(Pole miles) -
(In the case
of
underground
lines report
circuit miles)
LENGTH
(Pole miles) -
(In the case
of
underground
lines report
circuit miles)
Line
No.From To Operating Designated
Type of
Supporting
Structure
On Structure
of Line
Designated
On
Structures of
Another Line
Number
of
Circuits
(a)(b)(c)(d)(e)(f)(g)(h)
FERC FORM NO. 1 (ED. 12-87)
Page 422-423
33 Caldwell Ontario 230 230 H Wood 30.06 0 134CaldwellOntario230230S Tower 3.14 0 135Bennett Mtn PP Rattlesnake TS 230 230 SP Steel 4.39 0 136BorahHunt230230H Steel 68.12 0 137DanskinHubbard230230H Steel 36.25 0 138DanskinHubbard230230SP Steel 1.84 0 139DanskinHubbard230230SP Steel 1.3 0 240DanskinBennett Mtn 230 230 SP Steel 5.39 0 141HemingwayBowmont230230SP Steel 12.94 0 142Langley Gulch Galloway Rd 138 230 SP Steel 14.19 0 143Galloway Rd Willis Tap 138 230 SP Steel 2.09 0 144Walla Walla (r)Hurricane 230 230 H Wood 31.66 0 145CloverdaleHubbard230230SP Steel 6.86 0 246BowmontHubbard023000047Boise Bench Midpoint #1 230 230 S Tower 0.71 0 148Boise Bench Midpoint #1 230 230 H Wood 109.65 0 149BrownleeQuartz Jct 230 230 S Tower 1.51 0 150BrownleeQuartz Jct 230 230 H Wood 41.3 0 151BrownleeBoise Bench #1 & #2 230 230 S Tower 99.78 0 252OxbowBrownlee230230S Tower 10.32 0 253Boise Bench Midpoint #2 230 230 S Tower 3.49 0 154Boise Bench Midpoint #2 230 230 H Wood 102.13 0 155OxbowPallette Jct 230 230 S Tower 19.98 0 256Pallette Jct Imnaha 230 230 H Wood 24.43 0 257Hells Canyon Palette Jct 230 230 S Tower 9.05 0 258BrownleeBoise Bench 230 230 S Tower 102.1 0 259Boise Bench Midpoint #3 230 230 H Wood 106.29 0 160Palette Jct Enterprise 230 230 H Wood 29.6 0 161BorahBrady #2 230 230 S Tower 0.42 0 162BorahBrady #2 230 230 H Wood 3.52 0 163BorahBrady #1 230 230 H Wood 3.84 0 164Goshen(s)State Line 161 161 H Wood 40.89 0 165DonGoshen161161S Tower 2.37 0 266DonGoshen161161H Wood 16.49 0 267DonGoshen138161H Wood 29.66 0 268Antelope(t)Goshen 161 161 H Wood 5.68 0 169Goshen(u)State Line 161 161 H Wood 10.9 0 170Goshen(v)State Line 161 161 H Wood 7.84 0 171American Falls PP Adelaide 138 138 H Wood 14.09 0 2TRANSMISSION LINE STATISTICSDESIGNATIONDESIGNATIONVOLTAGE (KV) -(Indicate where otherthan 60 cycle, 3phase)VOLTAGE (KV) -(Indicate where otherthan 60 cycle, 3phase)LENGTH(Pole miles) -(In the caseofundergroundlines reportcircuit miles)LENGTH(Pole miles) -(In the caseofundergroundlines reportcircuit miles)LineNo.From To Operating Designated Type ofSupportingStructure On Structureof LineDesignated OnStructures ofAnother Line NumberofCircuits(a)(b)(c)(d)(e)(f)(g)(h)FERC FORM NO. 1 (ED. 12-87)Page 422-423
72 American Falls PP Adelaide 138 138 S P Wood 0.12 0 2
73 Minidoka Loop Adelaide 138 138 S Tower 1.13 0 2
74 Nampa Caldwell 138 138 S P Wood 9.6 0 2
75 Skyway Tap 138 138 S P Steel 0.89 0 2
76 Upper Salmon Mountain Home Jct 138 138 H Wood 54.36 0 1
77 Upper Salmon Cliff 138 138 H Wood 30.81 0 1
78 Eastgate Russet 138 138 S P Wood 2.06 0 1
79 Brady Fremont 138 138 S Tower 1.01 0 2
80 Brady Fremont 138 138 H Wood 24.36 0 2
81 Brady Fremont 138 138 S P Wood 24.33 0 2
82 King Lower Malad 138 138 H Wood 84.92 0 2
83 Orchard Tap 138 138 S P Steel 3.81 0 1
84 Emmett Jct Payette 138 138 H Wood 66.41 0 2
85 Mountain Home AFB Tap 138 138 H Wood 6.2 0 1
86 Ontario Quartz 138 138 H Wood 73.23 0 1
87 King American Falls PP 138 138 S Tower 0.91 0 2
88 King American Falls PP 138 138 H Wood 142.15 0 1
89 King American Falls PP 138 138 S P Wood 3.71 0 1
90 King American Falls PP 138 138 S P Steel 0.5 0 1
91 Duffin Clawson 138 138 H Wood 6.19 0 1
92 American Falls Brady Tie 138 138 H Wood 0.33 0 1
93 Upper Salmon A-B King 138 138 H Wood 5.66 0 1
94 Upper Salmon B Wells 138 138 H Wood 125.47 0 1
95 King Wood River 138 138 H Wood 73.59 0 1
96 Toponis Pocket 138 138 S P Wood 9.8 0 1
97 Boise Bench Grove 138 138 S P Wood 10.5 0 2
98 Quartz John Day 138 138 H Wood 67.37 0 1
99 Sinker Creek Tap 138 138 H Wood 2.83 0 1
100 Mora Cloverdale 138 138 H Wood 2.51 0 1
101 Mora Cloverdale 138 138 S P Wood 22.25 0 1
102 Mora Cloverdale 138 138 S P Steel 0.96 0 2
103 Stoddard Jct Stoddard Sub 138 138 S P Steel 3.8 0 1
104 Fossil Gulch Tap 138 138 H Wood 1.81 0 1
105 Wood River Midpoint 138 138 H Wood 53.08 0 2
106 Wood River Midpoint 138 138 S P Wood 16.69 0 2
107 Oxbow McCall 138 138 H Wood 37.04 0 1
108 Oxbow McCall 138 138 S P Wood 2.32 0 1
109 Lowell Jct Nampa 138 138 S P Wood 7.53 0 2
110 Hunt Milner 138 138 S P Wood 19.41 0 1
111 Strike Bruneau Bridge 138 138 H Wood 13.49 0 1
112 American Falls Kramer Sub 138 138 S P Wood 18.46 0 2
TRANSMISSION LINE STATISTICS
DESIGNATION DESIGNATION
VOLTAGE (KV) -
(Indicate where other
than 60 cycle, 3
phase)
VOLTAGE (KV) -
(Indicate where other
than 60 cycle, 3
phase)
LENGTH
(Pole miles) -
(In the case
of
underground
lines report
circuit miles)
LENGTH
(Pole miles) -
(In the case
of
underground
lines report
circuit miles)
Line
No.From To Operating Designated
Type of
Supporting
Structure
On Structure
of Line
Designated
On
Structures of
Another Line
Number
of
Circuits
(a)(b)(c)(d)(e)(f)(g)(h)
FERC FORM NO. 1 (ED. 12-87)
Page 422-423
72 American Falls PP Adelaide 138 138 S P Wood 0.12 0 273Minidoka Loop Adelaide 138 138 S Tower 1.13 0 274NampaCaldwell138138S P Wood 9.6 0 275Skyway Tap 138 138 S P Steel 0.89 0 276Upper Salmon Mountain Home Jct 138 138 H Wood 54.36 0 177Upper Salmon Cliff 138 138 H Wood 30.81 0 178EastgateRusset138138S P Wood 2.06 0 179BradyFremont138138S Tower 1.01 0 280BradyFremont138138H Wood 24.36 0 281BradyFremont138138S P Wood 24.33 0 282KingLower Malad 138 138 H Wood 84.92 0 283Orchard Tap 138 138 S P Steel 3.81 0 184Emmett Jct Payette 138 138 H Wood 66.41 0 285Mountain Home AFB Tap 138 138 H Wood 6.2 0 186OntarioQuartz138138H Wood 73.23 0 187KingAmerican Falls PP 138 138 S Tower 0.91 0 288KingAmerican Falls PP 138 138 H Wood 142.15 0 189KingAmerican Falls PP 138 138 S P Wood 3.71 0 190KingAmerican Falls PP 138 138 S P Steel 0.5 0 191DuffinClawson138138H Wood 6.19 0 192American Falls Brady Tie 138 138 H Wood 0.33 0 193Upper Salmon A-B King 138 138 H Wood 5.66 0 194Upper Salmon B Wells 138 138 H Wood 125.47 0 195KingWood River 138 138 H Wood 73.59 0 196ToponisPocket138138S P Wood 9.8 0 197Boise Bench Grove 138 138 S P Wood 10.5 0 298QuartzJohn Day 138 138 H Wood 67.37 0 199Sinker Creek Tap 138 138 H Wood 2.83 0 1100MoraCloverdale138138H Wood 2.51 0 1101MoraCloverdale138138S P Wood 22.25 0 1102MoraCloverdale138138S P Steel 0.96 0 2103Stoddard Jct Stoddard Sub 138 138 S P Steel 3.8 0 1104Fossil Gulch Tap 138 138 H Wood 1.81 0 1105Wood River Midpoint 138 138 H Wood 53.08 0 2106Wood River Midpoint 138 138 S P Wood 16.69 0 2107OxbowMcCall138138H Wood 37.04 0 1108OxbowMcCall138138S P Wood 2.32 0 1109Lowell Jct Nampa 138 138 S P Wood 7.53 0 2110HuntMilner138138S P Wood 19.41 0 1111StrikeBruneau Bridge 138 138 H Wood 13.49 0 1112American Falls Kramer Sub 138 138 S P Wood 18.46 0 2TRANSMISSION LINE STATISTICSDESIGNATIONDESIGNATIONVOLTAGE (KV) -(Indicate where otherthan 60 cycle, 3phase)VOLTAGE (KV) -(Indicate where otherthan 60 cycle, 3phase)LENGTH(Pole miles) -(In the caseofundergroundlines reportcircuit miles)LENGTH(Pole miles) -(In the caseofundergroundlines reportcircuit miles)LineNo.From To Operating Designated Type ofSupportingStructure On Structureof LineDesignated OnStructures ofAnother Line NumberofCircuits(a)(b)(c)(d)(e)(f)(g)(h)FERC FORM NO. 1 (ED. 12-87)
Page 422-423
113 Pingree Haven 138 138 S P Wood 11.72 0 1
114 Midpoint Twin Falls 138 138 S P Wood 25.19 0 2
115 Shoshone Tap 138 138 H Wood 7.09 0 2
116 Twin Falls Russett 138 138 S P Wood 1.71 0 1
117 Blackfoot Aiken 46 138 S P Wood 6.22 0 2
118 Peterson Tendoy 69 138 H Wood 57.04 0 1
119 Eastgate Tap Eastgate 138 138 S P Wood 6.39 0 1
120 Kimberly Tap Kimberly 138 138 S P Steel 1.84 0 2
121 Boise Bench Mora 138 138 H Wood 13.11 0 2
122 Bowmont-Caldwell Simplot Sub 138 138 S P Wood 0.51 0 1
123 Gary Lane Eagle 138 138 S P Wood 6.64 0 1
124 Locust Grove Blackcat Sub 138 138 S P Steel 9.25 2.98 1
125 Boise Bench Butler 138 138 S P Wood 0.14 4.02 1
126 Eagle Star 138 138 S P Wood 6.77 0 1
127 Star Lansing 138 138 S P Steel 5.5 0 1
128 Beacon Light Tap Beacon Light 138 138 S P Steel 4.32 0 1
129 Karcher Sub Zilog Tap 138 138 S P Steel 3.12 0 1
130 Zilog Can Ada 138 138 S P Steel 1.5 0 1
131 Blackcat Can Ada 138 138 H Wood 3.42 0 1
132 Cloverdale Wye 138 138 S P Steel 0.42 4.02 1
133 Victory Jct Victory 138 138 S P Steel 1.87 0 1
134 Butler Wye 138 138 S P Steel 2.94 0 1
135 Horseflat Starkey 138 138 H Wood 33.97 0 1
136 Starkey Mccall 138 138 S P Steel 2.23 0 2
137 Starkey Mccall 138 138 H Wood 3.8 0 1
138 Starkey Mccall 138 138 S P Steel 1.5 0 1
139 Starkey Mccall 138 138 S P Wood 17.61 0 1
140 Chestnut Happy Valley 138 138 S P Steel 2.78 0 1
141 Garnet Ward 0 138 0 0 0
142 McCall Lake Fork 138 138 S P Wood 8.89 0 1
143 McCall Lake Fork 138 138 S Steel 2.9 0 1
144 Boulder Tap 138 138 S P Steel 1.98 0 1
145 Caldwell Willis 138 138 S P Steel 1.3 0 1
146 Caldwell Willis 138 138 S P Steel 3.63 0 1
147 Caldwell Willis 138 138 S P Wood 0.87 0 1
148 Willis Lansing 138 138 Verious 3.23 0 2
149 Valivue Tap 138 138 S P Steel 0.79 0 2
150 Bowmont Happy Valley 138 138 S P Steel 8.65 0 1
151 Antelope
(w)
Scoville 138 138 H Wood 0.12 0 1
152 American Falls
(x)
Wheelon 138 138 H Wood 1.05 0 1
TRANSMISSION LINE STATISTICS
DESIGNATION DESIGNATION
VOLTAGE (KV) -
(Indicate where other
than 60 cycle, 3
phase)
VOLTAGE (KV) -
(Indicate where other
than 60 cycle, 3
phase)
LENGTH
(Pole miles) -
(In the case
of
underground
lines report
circuit miles)
LENGTH
(Pole miles) -
(In the case
of
underground
lines report
circuit miles)
Line
No.From To Operating Designated
Type of
Supporting
Structure
On Structure
of Line
Designated
On
Structures of
Another Line
Number
of
Circuits
(a)(b)(c)(d)(e)(f)(g)(h)
FERC FORM NO. 1 (ED. 12-87)
Page 422-423
113 Pingree Haven 138 138 S P Wood 11.72 0 1114MidpointTwin Falls 138 138 S P Wood 25.19 0 2115Shoshone Tap 138 138 H Wood 7.09 0 2116Twin Falls Russett 138 138 S P Wood 1.71 0 1117BlackfootAiken46138S P Wood 6.22 0 2118PetersonTendoy69138H Wood 57.04 0 1119Eastgate Tap Eastgate 138 138 S P Wood 6.39 0 1120Kimberly Tap Kimberly 138 138 S P Steel 1.84 0 2121Boise Bench Mora 138 138 H Wood 13.11 0 2122Bowmont-Caldwell Simplot Sub 138 138 S P Wood 0.51 0 1123Gary Lane Eagle 138 138 S P Wood 6.64 0 1124Locust Grove Blackcat Sub 138 138 S P Steel 9.25 2.98 1125Boise Bench Butler 138 138 S P Wood 0.14 4.02 1126EagleStar138138S P Wood 6.77 0 1127StarLansing138138S P Steel 5.5 0 1128Beacon Light Tap Beacon Light 138 138 S P Steel 4.32 0 1129Karcher Sub Zilog Tap 138 138 S P Steel 3.12 0 1130ZilogCan Ada 138 138 S P Steel 1.5 0 1131BlackcatCan Ada 138 138 H Wood 3.42 0 1132CloverdaleWye138138S P Steel 0.42 4.02 1133Victory Jct Victory 138 138 S P Steel 1.87 0 1134ButlerWye138138S P Steel 2.94 0 1135HorseflatStarkey138138H Wood 33.97 0 1136StarkeyMccall138138S P Steel 2.23 0 2137StarkeyMccall138138H Wood 3.8 0 1138StarkeyMccall138138S P Steel 1.5 0 1139StarkeyMccall138138S P Wood 17.61 0 1140ChestnutHappy Valley 138 138 S P Steel 2.78 0 1141GarnetWard0138000142McCallLake Fork 138 138 S P Wood 8.89 0 1143McCallLake Fork 138 138 S Steel 2.9 0 1144Boulder Tap 138 138 S P Steel 1.98 0 1145CaldwellWillis138138S P Steel 1.3 0 1146CaldwellWillis138138S P Steel 3.63 0 1147CaldwellWillis138138S P Wood 0.87 0 1148WillisLansing138138Verious3.23 0 2149Valivue Tap 138 138 S P Steel 0.79 0 2150BowmontHappy Valley 138 138 S P Steel 8.65 0 1151Antelope(w)Scoville 138 138 H Wood 0.12 0 1152American Falls (x)Wheelon 138 138 H Wood 1.05 0 1TRANSMISSION LINE STATISTICSDESIGNATIONDESIGNATIONVOLTAGE (KV) -(Indicate where otherthan 60 cycle, 3phase)VOLTAGE (KV) -(Indicate where otherthan 60 cycle, 3phase)LENGTH(Pole miles) -(In the caseofundergroundlines reportcircuit miles)LENGTH(Pole miles) -(In the caseofundergroundlines reportcircuit miles)LineNo.From To Operating Designated Type ofSupportingStructure On Structureof LineDesignated OnStructures ofAnother Line NumberofCircuits(a)(b)(c)(d)(e)(f)(g)(h)FERC FORM NO. 1 (ED. 12-87)Page 422-423
153 Kinport Don #1 138 138 S Tower 1.27 0 2
154 Donn HOKU 138 138 S P Steel 2.69 0 1
155 HOKU Alamed 138 138 S P Steel 0.22 0 2
156 HOKU Alamed 138 138 S P Steel 0.23 0 2
157 HOKU Alamed 138 138 S P Steel 2.85 0 1
158 Eldridge tap 138 138 S P Steel 0.85 0 1
159 Mora Columbia 138 138 S P Steel 0 3.92 2
160 Rockland Jct Rockland Wind Farm 138 138 S P Steel 5.18 0 1
161 King Justice 138 138 S P Wood 0.07 0 1
162 NorthView Tap 138 138 S P Wood 6.17 0 1
163 Twin Falls PP Tap 138 138 H Wood 0.99 0 1
164 American Falls PP Amercian Falls Trans ST 138 138 S P Steel 0.37 0 1
165 Lower Salmon King Tie 138 138 H Wood 0.05 0 1
166 C J Strike Strike Jct 138 138 S Tower 4.3 0 2
167 Strike Jct Mountain Home Jct 138 138 H Wood 23.42 0 1
168 Strike Jct Bowmont 0 138 H Wood 0.05 0 1
169 Strike Jct Bowmont 138 138 S Tower 0.36 0 1
170 Strike Jct Bowmont 138 138 H Wood 67.89 0 1
171 Lucky Peak Lucky Peak Jct 138 138 H Wood 4.48 0 2
172 Bliss King 138 138 H Wood 10.51 0 1
173 Milner Deadend Milner PP 138 138 S P Wood 1.3 0 1
174 Swan Falls Tap 138 138 H Wood 0.95 0 1
175 Hines BPA (Harney)115 115 H Wood 3.35 0 1
176 69 Kv Lines 69 69 H Wood 205.81 0 1
177 69 Kv Lines 69 69 S P Wood 821.13 0 1
178 46 Kv Lines 46 46 S P Wood 374.77 0 1
179 NA
36 TOTAL 4,735.02 14.94 225
FERC FORM NO. 1 (ED. 12-87)
Page 422-423
TRANSMISSION LINE STATISTICS
DESIGNATION DESIGNATION
VOLTAGE (KV) -
(Indicate where other
than 60 cycle, 3
phase)
VOLTAGE (KV) -
(Indicate where other
than 60 cycle, 3
phase)
LENGTH
(Pole miles) -
(In the case
of
underground
lines report
circuit miles)
LENGTH
(Pole miles) -
(In the case
of
underground
lines report
circuit miles)
Line
No.From To Operating Designated
Type of
Supporting
Structure
On Structure
of Line
Designated
On
Structures of
Another Line
Number
of
Circuits
(a)(b)(c)(d)(e)(f)(g)(h)
TRANSMISSION LINE STATISTICS
COST OF LINE
(Include in column (j)
Land, Land rights,
and clearing right-of-
way)
COST OF LINE
(Include in column (j)
Land, Land rights,
and clearing right-of-
way)
COST OF LINE
(Include in column (j)
Land, Land rights,
and clearing right-of-
way)
EXPENSES, EXCEPT
DEPRECIATION AND
TAXES
EXPENSES,
EXCEPT
DEPRECIATION
AND TAXES
EXPENSES,
EXCEPT
DEPRECIATION
AND TAXES
EXPENSES,
EXCEPT
DEPRECIATION
AND TAXES
Line
No.
Size of Conductor and
Material Land Construction Costs Total Costs Operation Expenses Maintenance
Expenses Rents Total ExpensesFERC FORM NO. 1 (ED. 12-87)
153 Kinport Don #1 138 138 S Tower 1.27 0 2154DonnHOKU138138S P Steel 2.69 0 1155HOKUAlamed138138S P Steel 0.22 0 2156HOKUAlamed138138S P Steel 0.23 0 2157HOKUAlamed138138S P Steel 2.85 0 1158Eldridge tap 138 138 S P Steel 0.85 0 1159MoraColumbia138138S P Steel 0 3.92 2160Rockland Jct Rockland Wind Farm 138 138 S P Steel 5.18 0 1161KingJustice138138S P Wood 0.07 0 1162NorthView Tap 138 138 S P Wood 6.17 0 1163Twin Falls PP Tap 138 138 H Wood 0.99 0 1164American Falls PP Amercian Falls Trans ST 138 138 S P Steel 0.37 0 1165Lower Salmon King Tie 138 138 H Wood 0.05 0 1166C J Strike Strike Jct 138 138 S Tower 4.3 0 2167Strike Jct Mountain Home Jct 138 138 H Wood 23.42 0 1168Strike Jct Bowmont 0 138 H Wood 0.05 0 1169Strike Jct Bowmont 138 138 S Tower 0.36 0 1170Strike Jct Bowmont 138 138 H Wood 67.89 0 1171Lucky Peak Lucky Peak Jct 138 138 H Wood 4.48 0 2172BlissKing138138H Wood 10.51 0 1173Milner Deadend Milner PP 138 138 S P Wood 1.3 0 1174Swan Falls Tap 138 138 H Wood 0.95 0 1175HinesBPA (Harney)115 115 H Wood 3.35 0 117669 Kv Lines 69 69 H Wood 205.81 0 117769 Kv Lines 69 69 S P Wood 821.13 0 117846 Kv Lines 46 46 S P Wood 374.77 0 1179NA36TOTAL4,735.02 14.94 225FERC FORM NO. 1 (ED. 12-87)Page 422-423TRANSMISSION LINE STATISTICSDESIGNATIONDESIGNATIONVOLTAGE (KV) -(Indicate where otherthan 60 cycle, 3phase)VOLTAGE (KV) -(Indicate where otherthan 60 cycle, 3phase)LENGTH(Pole miles) -(In the caseofundergroundlines reportcircuit miles)LENGTH(Pole miles) -(In the caseofundergroundlines reportcircuit miles)LineNo.From To Operating Designated Type ofSupportingStructure On Structureof LineDesignated OnStructures ofAnother Line NumberofCircuits(a)(b)(c)(d)(e)(f)(g)(h)
TRANSMISSION LINE STATISTICS
COST OF LINE
(Include in column (j)
Land, Land rights,
and clearing right-of-
way)
COST OF LINE
(Include in column (j)
Land, Land rights,
and clearing right-of-
way)
COST OF LINE
(Include in column (j)
Land, Land rights,
and clearing right-of-
way)
EXPENSES, EXCEPT
DEPRECIATION AND
TAXES
EXPENSES,
EXCEPT
DEPRECIATION
AND TAXES
EXPENSES,
EXCEPT
DEPRECIATION
AND TAXES
EXPENSES,
EXCEPT
DEPRECIATION
AND TAXES
Line
No.
Size of Conductor and
Material Land Construction Costs Total Costs Operation Expenses Maintenance
Expenses Rents Total ExpensesFERC FORM NO. 1 (ED. 12-87)
No.Material Land Construction Costs Total Costs Operation Expenses Expenses Rents Total Expenses
(i)(j)(k)(l)(m)(n)(o)(p)
1 1272 ACSR 256,381 16,047,911 16,304,292 0 0 0 0
2 2X1780 ACSR 0 446,708 446,708 0 0 0 0
3 1272 ACSR 0 0 0 0 0 0 0
4 1272 ACSR 0 0 0 0 0 0 0
5 3x1272 ACSR 0 18,859,844 18,859,844 0 0 0 0
6 3x1272 ACSR 0 17,142,784 17,142,784 0 0 0 0
7 1272 ACSR 566,396 5,333,016 5,899,412 0 0 0 0
8 795 ACSR 572,296 12,999,035 13,571,331 0 0 0 0
9 795 ACSR 0 0 0 0 0 0 0
10 1272 ACSR 344,220 4,400,939 4,745,159 0 0 0 0
11 1272 ACSR 0 9,602,400 9,602,400 0 0 0 0
12 1272 ACSR 0 0 0 0 0 0 0
13 1272 ACSR 0 9,261,033 9,261,033 0 0 0 0
14 1272 ACSR 0 0 0 0 0 0 0
15 2x1272 ACSR 0 585,982 585,982 0 0 0 0
16 715.5 ACSR 283,143 20,126,894 20,410,037 0 0 0 0
17 715.5 ACSR 64,851 15,156,214 15,221,065 0 0 0 0
18 715.5 ACSR 51,448 227,554 279,002 0 0 0 0
19 795 ACSR 62,218 7,305,569 7,367,787 0 0 0 0
20 715.5 ACSR 9,145 1,001,298 1,010,443 0 0 0 0
21 1272 ACSR 163,320 4,696,608 4,859,928 0 0 0 0
22 795 ACSR 0 6,186 6,186 0 0 0 0
23 715.5 ACSR 18,829 1,218,904 1,237,733 0 0 0 0
24 2X954 ACSR 1,676,838 20,730,375 22,407,213 0 0 0 0
25 715.5 ACSR 413,793 2,609,062 3,022,855 0 0 0 0
26 715.5 ACSR 0 0 0 0 0 0 0
27 1590 ACSR 2,378,436 8,775,086 11,153,522 0 0 0 0
28 1272 ACSR 1,748,202 12,569,900 14,318,102 0 0 0 0
29 715.5 ACSR 0 0 0 0 0 0 0
30 1272 ACSR 3,062,812 7,408,200 10,471,012 0 0 0 0
31 795 AAC 0 89,089 89,089 0 0 0 0
32 954 ACSR 34,174 16,026,470 16,060,644 0 0 0 0
33 2X954 ACSR 236,152 9,539,874 9,776,026 0 0 0 0
34 1272 ACSR 0 0 0 0 0 0 0
35 1272 ACSR 81,701 1,666,354 1,748,055 0 0 0 0
36 1590 ACSR 624,917 22,468,413 23,093,330 0 0 0 0
37 1590 ACSR 24,639 15,210,560 15,235,199 0 0 0 0
38 1590 ACSR 0 0 0 0 0 0 0
39 1590 ACSR 0 0 0 0 0 0 0
40 1590 ACSR 0 3,528,033 3,528,033 0 0 0 0
41 1590 ACSR 1,854,996 9,277,980 11,132,976 0 0 0 0
42 1590 ACSR 948,166 9,066,804 10,014,970 0 0 0 0
FERC FORM NO. 1 (ED. 12-87)
Page 422-423
No.Material Land Construction Costs Total Costs Operation Expenses Expenses Rents Total Expenses(i)(j)(k)(l)(m)(n)(o)(p)1 1272 ACSR 256,381 16,047,911 16,304,292 0 0 0 022X1780 ACSR 0 446,708 446,708 0 0 0 031272 ACSR 0 0 0 0 0 0 041272 ACSR 0 0 0 0 0 0 053x1272 ACSR 0 18,859,844 18,859,844 0 0 0 063x1272 ACSR 0 17,142,784 17,142,784 0 0 0 071272 ACSR 566,396 5,333,016 5,899,412 0 0 0 08795 ACSR 572,296 12,999,035 13,571,331 0 0 0 09795 ACSR 0 0 0 0 0 0 0101272 ACSR 344,220 4,400,939 4,745,159 0 0 0 0111272 ACSR 0 9,602,400 9,602,400 0 0 0 0121272 ACSR 0 0 0 0 0 0 0131272 ACSR 0 9,261,033 9,261,033 0 0 0 0141272 ACSR 0 0 0 0 0 0 0152x1272 ACSR 0 585,982 585,982 0 0 0 016715.5 ACSR 283,143 20,126,894 20,410,037 0 0 0 017715.5 ACSR 64,851 15,156,214 15,221,065 0 0 0 018715.5 ACSR 51,448 227,554 279,002 0 0 0 019795 ACSR 62,218 7,305,569 7,367,787 0 0 0 020715.5 ACSR 9,145 1,001,298 1,010,443 0 0 0 0211272 ACSR 163,320 4,696,608 4,859,928 0 0 0 022795 ACSR 0 6,186 6,186 0 0 0 023715.5 ACSR 18,829 1,218,904 1,237,733 0 0 0 0242X954 ACSR 1,676,838 20,730,375 22,407,213 0 0 0 025715.5 ACSR 413,793 2,609,062 3,022,855 0 0 0 026715.5 ACSR 0 0 0 0 0 0 0271590 ACSR 2,378,436 8,775,086 11,153,522 0 0 0 0281272 ACSR 1,748,202 12,569,900 14,318,102 0 0 0 029715.5 ACSR 0 0 0 0 0 0 0301272 ACSR 3,062,812 7,408,200 10,471,012 0 0 0 031795 AAC 0 89,089 89,089 0 0 0 032954 ACSR 34,174 16,026,470 16,060,644 0 0 0 0332X954 ACSR 236,152 9,539,874 9,776,026 0 0 0 0341272 ACSR 0 0 0 0 0 0 0351272 ACSR 81,701 1,666,354 1,748,055 0 0 0 0361590 ACSR 624,917 22,468,413 23,093,330 0 0 0 0371590 ACSR 24,639 15,210,560 15,235,199 0 0 0 0381590 ACSR 0 0 0 0 0 0 0391590 ACSR 0 0 0 0 0 0 0401590 ACSR 0 3,528,033 3,528,033 0 0 0 0411590 ACSR 1,854,996 9,277,980 11,132,976 0 0 0 0421590 ACSR 948,166 9,066,804 10,014,970 0 0 0 0FERC FORM NO. 1 (ED. 12-87)Page 422-423
43 1272 ACSR 0 0 0 0 0 0 0
44 1272 ACSR 0 6,912,708 6,912,708 0 0 0 0
45 1272 ACSR 287,582 8,909,499 9,197,081 0 0 0 0
46 940,966 0 940,966 0 0 0 0
47 715.5 ACSR 385,287 14,979,564 15,364,851 0 0 0 0
48 715.5 ACSR 0 0 0 0 0 0 0
49 795 ACSR 53,068 4,982,426 5,035,494 0 0 0 0
50 795 ACSR 0 0 0 0 0 0 0
51 VARIOUS 289,923 9,953,870 10,243,793 0 0 0 0
52 1272 ACSR 14,810 1,570,855 1,585,665 0 0 0 0
53 715.5 ACSR 227,814 19,136,607 19,364,421 0 0 0 0
54 VARIOUS 0 0 0 0 0 0 0
55 1272 ACSR 87,468 4,058,883 4,146,351 0 0 0 0
56 1272 ACSR 171,082 4,392,542 4,563,624 0 0 0 0
57 1272 ACSR 44,687 1,567,365 1,612,052 0 0 0 0
58 954 ACSR 184,805 6,656,986 6,841,791 0 0 0 0
59 715.5 ACSR 247,846 8,496,627 8,744,473 0 0 0 0
60 1272 ACSR 84,014 2,449,084 2,533,098 0 0 0 0
61 1272 ACSR 3,068 864,609 867,677 0 0 0 0
62 715.5 ACSR 0 0 0 0 0 0 0
63 1272 ACSR 7,248 514,141 521,389 0 0 0 0
64 250 COPPER 375,576 3,295,299 3,670,875 0 0 0 0
65 715.5 ACSR 88,204 3,554,218 3,642,422 0 0 0 0
66 397.5 ACSR 0 0 0 0 0 0 0
67 397.5 ACSR 0 0 0 0 0 0 0
68 397.5 ACSR 0 824,418 824,418 0 0 0 0
69 250 COPPER 116,873 1,251,619 1,368,492 0 0 0 0
70 250 COPPER 76,969 632,833 709,802 0 0 0 0
71 250 COPPER 26,507 420,519 447,026 0 0 0 0
72 250 COPPER 0 0 0 0 0 0 0
73 715.5 ACSR 21,327 286,219 307,546 0 0 0 0
74 795 AAC 1,798,312 6,013,135 7,811,447 0 0 0 0
75 1272 ACSR 0 0 0 0 0 0 0
76 795 ACSR 78,078 5,074,158 5,152,236 0 0 0 0
77 795 ACSR 43,568 3,467,397 3,510,965 0 0 0 0
78 795 AAC 270,823 561,561 832,384 0 0 0 0
79 VARIOUS 564,932 5,358,793 5,923,725 0 0 0 0
80 VARIOUS 0 0 0 0 0 0 0
81 VARIOUS 0 0 0 0 0 0 0
82 VARIOUS 276,966 6,600,133 6,877,099 0 0 0 0
83 795 ACSR 0 0 0 0 0 0 0
84 VARIOUS 61,872 4,751,462 4,813,334 0 0 0 0
TRANSMISSION LINE STATISTICS
COST OF LINE
(Include in column (j)
Land, Land rights,
and clearing right-of-
way)
COST OF LINE
(Include in column (j)
Land, Land rights,
and clearing right-of-
way)
COST OF LINE
(Include in column (j)
Land, Land rights,
and clearing right-of-
way)
EXPENSES, EXCEPT
DEPRECIATION AND
TAXES
EXPENSES,
EXCEPT
DEPRECIATION
AND TAXES
EXPENSES,
EXCEPT
DEPRECIATION
AND TAXES
EXPENSES,
EXCEPT
DEPRECIATION
AND TAXES
Line
No.
Size of Conductor and
Material Land Construction Costs Total Costs Operation Expenses Maintenance
Expenses Rents Total Expenses
(i)(j)(k)(l)(m)(n)(o)(p)
FERC FORM NO. 1 (ED. 12-87)
Page 422-423
43 1272 ACSR 0 0 0 0 0 0 0441272 ACSR 0 6,912,708 6,912,708 0 0 0 0451272 ACSR 287,582 8,909,499 9,197,081 0 0 0 046940,966 0 940,966 0 0 0 047715.5 ACSR 385,287 14,979,564 15,364,851 0 0 0 048715.5 ACSR 0 0 0 0 0 0 049795 ACSR 53,068 4,982,426 5,035,494 0 0 0 050795 ACSR 0 0 0 0 0 0 051VARIOUS289,923 9,953,870 10,243,793 0 0 0 0521272 ACSR 14,810 1,570,855 1,585,665 0 0 0 053715.5 ACSR 227,814 19,136,607 19,364,421 0 0 0 054VARIOUS0000000551272 ACSR 87,468 4,058,883 4,146,351 0 0 0 0561272 ACSR 171,082 4,392,542 4,563,624 0 0 0 0571272 ACSR 44,687 1,567,365 1,612,052 0 0 0 058954 ACSR 184,805 6,656,986 6,841,791 0 0 0 059715.5 ACSR 247,846 8,496,627 8,744,473 0 0 0 0601272 ACSR 84,014 2,449,084 2,533,098 0 0 0 0611272 ACSR 3,068 864,609 867,677 0 0 0 062715.5 ACSR 0 0 0 0 0 0 0631272 ACSR 7,248 514,141 521,389 0 0 0 064250 COPPER 375,576 3,295,299 3,670,875 0 0 0 065715.5 ACSR 88,204 3,554,218 3,642,422 0 0 0 066397.5 ACSR 0 0 0 0 0 0 067397.5 ACSR 0 0 0 0 0 0 068397.5 ACSR 0 824,418 824,418 0 0 0 069250 COPPER 116,873 1,251,619 1,368,492 0 0 0 070250 COPPER 76,969 632,833 709,802 0 0 0 071250 COPPER 26,507 420,519 447,026 0 0 0 072250 COPPER 0 0 0 0 0 0 073715.5 ACSR 21,327 286,219 307,546 0 0 0 074795 AAC 1,798,312 6,013,135 7,811,447 0 0 0 0751272 ACSR 0 0 0 0 0 0 076795 ACSR 78,078 5,074,158 5,152,236 0 0 0 077795 ACSR 43,568 3,467,397 3,510,965 0 0 0 078795 AAC 270,823 561,561 832,384 0 0 0 079VARIOUS564,932 5,358,793 5,923,725 0 0 0 080VARIOUS000000081VARIOUS000000082VARIOUS276,966 6,600,133 6,877,099 0 0 0 083795 ACSR 0 0 0 0 0 0 084VARIOUS61,872 4,751,462 4,813,334 0 0 0 0TRANSMISSION LINE STATISTICSCOST OF LINE(Include in column (j)Land, Land rights,and clearing right-of-way)COST OF LINE(Include in column (j)Land, Land rights,and clearing right-of-way)COST OF LINE(Include in column (j)Land, Land rights,and clearing right-of-way)EXPENSES, EXCEPTDEPRECIATION ANDTAXES EXPENSES,EXCEPTDEPRECIATIONAND TAXES EXPENSES,EXCEPTDEPRECIATIONAND TAXES EXPENSES,EXCEPTDEPRECIATIONAND TAXESLineNo.Size of Conductor andMaterial Land Construction Costs Total Costs Operation Expenses MaintenanceExpenses Rents Total Expenses(i)(j)(k)(l)(m)(n)(o)(p)FERC FORM NO. 1 (ED. 12-87)
Page 422-423
85 397.5 ACSR 5,086 250,764 255,850 0 0 0 0
86 VARIOUS 127,899 9,057,787 9,185,686 0 0 0 0
87 715.5 ACSR 216,919 18,706,390 18,923,309 0 0 0 0
88 715.5 ACSR 0 0 0 0 0 0 0
89 715.5 ACSR 0 0 0 0 0 0 0
90 715.5 ACSR 0 0 0 0 0 0 0
91 4\0 4,191 562,786 566,977 0 0 0 0
92 954 ACSR 0 154,612 154,612 0
93 250 COPPER 2,741 1,093,852 1,096,593 0 0 0 0
94 VARIOUS 28,490 5,648,890 5,677,380 0 0 0 0
95 VARIOUS 186,198 26,094,732 26,280,930 0 0 0 0
96 397.5 ACSR 0 0 0 0 0 0 0
97 VARIOUS 225,602 1,643,680 1,869,282 0 0 0 0
98 397.5 ACSR 96,582 3,811,750 3,908,332 0 0 0 0
99 VARIOUS 11,083 307,693 318,776 0 0 0 0
100 715.5 ACSR 3,123,381 10,255,013 13,378,394 0 0 0 0
101 VARIOUS 0 0 0 0 0 0 0
102 795AAC 0 0 0 0 0 0 0
103 1272 ACSR 0 0 0 0 0 0 0
104 250 COPPER 450 190,553 191,003 0 0 0 0
105 397.5 ACSR 349,712 8,489,125 8,838,837 0 0 0 0
106 397.5 ACSR 0 0 0 0 0 0 0
107 397.5 ACSR 141,534 2,848,943 2,990,477 0 0 0 0
108 397.5 ACSR 0 0 0 0 0 0 0
109 715.5 ACSR 211,131 1,960,097 2,171,228 0 0 0 0
110 715.5 ACSR 3,324 1,673,746 1,677,070 0 0 0 0
111 397.5 ACSR 14,927 758,749 773,676 0 0 0 0
112 715.5 ACSR 13,734 1,333,743 1,347,477 0 0 0 0
113 397.5 ACSR 18,223 1,343,412 1,361,635 0 0 0 0
114 VARIOUS 107,132 7,663,056 7,770,188 0 0 0 0
115 397.5 ACSR 0 0 0 0 0 0 0
116 715.5 ACSR 16,790 217,557 234,347 0 0 0 0
117 715.5 ACSR 13,616 580,168 593,784 0 0 0 0
118 397.5 ACSR 395,696 3,617,011 4,012,707 0 0 0 0
119 715.5 ACSR 343,955 2,195,624 2,539,579 0 0 0 0
120 795 ACSR 0 0 0 0 0 0 0
121 715.5 ACSR 14,697 756,210 770,907 0 0 0 0
122 795 AAC 0 52,366 52,366 0 0 0 0
123 795 AAC 308,141 2,254,517 2,562,658 0 0 0 0
124 1272 ACSR 935,810 3,855,331 4,791,141 0 0 0 0
125 1272 ACSR 34,687 838,605 873,292 0 0 0 0
126 715.5 ACSR 630,977 8,553,831 9,184,808 0 0 0 0
TRANSMISSION LINE STATISTICS
COST OF LINE
(Include in column (j)
Land, Land rights,
and clearing right-of-
way)
COST OF LINE
(Include in column (j)
Land, Land rights,
and clearing right-of-
way)
COST OF LINE
(Include in column (j)
Land, Land rights,
and clearing right-of-
way)
EXPENSES, EXCEPT
DEPRECIATION AND
TAXES
EXPENSES,
EXCEPT
DEPRECIATION
AND TAXES
EXPENSES,
EXCEPT
DEPRECIATION
AND TAXES
EXPENSES,
EXCEPT
DEPRECIATION
AND TAXES
Line
No.
Size of Conductor and
Material Land Construction Costs Total Costs Operation Expenses Maintenance
Expenses Rents Total Expenses
(i)(j)(k)(l)(m)(n)(o)(p)
FERC FORM NO. 1 (ED. 12-87)
Page 422-423
85 397.5 ACSR 5,086 250,764 255,850 0 0 0 086VARIOUS127,899 9,057,787 9,185,686 0 0 0 087715.5 ACSR 216,919 18,706,390 18,923,309 0 0 0 088715.5 ACSR 0 0 0 0 0 0 089715.5 ACSR 0 0 0 0 0 0 090715.5 ACSR 0 0 0 0 0 0 0914\0 4,191 562,786 566,977 0 0 0 092954 ACSR 0 154,612 154,612 093250 COPPER 2,741 1,093,852 1,096,593 0 0 0 094VARIOUS28,490 5,648,890 5,677,380 0 0 0 095VARIOUS186,198 26,094,732 26,280,930 0 0 0 096397.5 ACSR 0 0 0 0 0 0 097VARIOUS225,602 1,643,680 1,869,282 0 0 0 098397.5 ACSR 96,582 3,811,750 3,908,332 0 0 0 099VARIOUS11,083 307,693 318,776 0 0 0 0100715.5 ACSR 3,123,381 10,255,013 13,378,394 0 0 0 0101VARIOUS0000000102795AAC00000001031272 ACSR 0 0 0 0 0 0 0104250 COPPER 450 190,553 191,003 0 0 0 0105397.5 ACSR 349,712 8,489,125 8,838,837 0 0 0 0106397.5 ACSR 0 0 0 0 0 0 0107397.5 ACSR 141,534 2,848,943 2,990,477 0 0 0 0108397.5 ACSR 0 0 0 0 0 0 0109715.5 ACSR 211,131 1,960,097 2,171,228 0 0 0 0110715.5 ACSR 3,324 1,673,746 1,677,070 0 0 0 0111397.5 ACSR 14,927 758,749 773,676 0 0 0 0112715.5 ACSR 13,734 1,333,743 1,347,477 0 0 0 0113397.5 ACSR 18,223 1,343,412 1,361,635 0 0 0 0114VARIOUS107,132 7,663,056 7,770,188 0 0 0 0115397.5 ACSR 0 0 0 0 0 0 0116715.5 ACSR 16,790 217,557 234,347 0 0 0 0117715.5 ACSR 13,616 580,168 593,784 0 0 0 0118397.5 ACSR 395,696 3,617,011 4,012,707 0 0 0 0119715.5 ACSR 343,955 2,195,624 2,539,579 0 0 0 0120795 ACSR 0 0 0 0 0 0 0121715.5 ACSR 14,697 756,210 770,907 0 0 0 0122795 AAC 0 52,366 52,366 0 0 0 0123795 AAC 308,141 2,254,517 2,562,658 0 0 0 01241272 ACSR 935,810 3,855,331 4,791,141 0 0 0 01251272 ACSR 34,687 838,605 873,292 0 0 0 0126715.5 ACSR 630,977 8,553,831 9,184,808 0 0 0 0TRANSMISSION LINE STATISTICSCOST OF LINE(Include in column (j)Land, Land rights,and clearing right-of-way)COST OF LINE(Include in column (j)Land, Land rights,and clearing right-of-way)COST OF LINE(Include in column (j)Land, Land rights,and clearing right-of-way)EXPENSES, EXCEPTDEPRECIATION ANDTAXES EXPENSES,EXCEPTDEPRECIATIONAND TAXES EXPENSES,EXCEPTDEPRECIATIONAND TAXES EXPENSES,EXCEPTDEPRECIATIONAND TAXESLineNo.Size of Conductor andMaterial Land Construction Costs Total Costs Operation Expenses MaintenanceExpenses Rents Total Expenses(i)(j)(k)(l)(m)(n)(o)(p)FERC FORM NO. 1 (ED. 12-87)Page 422-423
127 795 AAC 0 0 0 0 0 0 0
128 795 AAC 0 0 0 0 0 0 0
129 795 AAC 541,877 3,301,157 3,843,034 0 0 0 0
130 795 AAC 0 0 0 0 0 0 0
131 397.5 ACSR 0 0 0 0 0 0 0
132 1272 ACSR 140,412 2,602,119 2,742,531 0 0 0 0
133 1272 ACSR 0 0 0 0 0 0 0
134 795 ACSR 134,471 1,405,436 1,539,907 0 0 0 0
135 715.5 ACSR 2,473,833 19,071,763 21,545,596 0 0 0 0
136 715.5 ACSR 0 0 0 0 0 0 0
137 715.5 ACSR 0 0 0 0 0 0 0
138 715.5 ACSR 0 0 0 0 0 0 0
139 715.5 ACSR 0 0 0 0 0 0 0
140 1272 ACSR 78,579 2,221,530 2,300,109 0 0 0 0
141 40,580 0 40,580 0 0 0 0
142 715.5 ACSR 331,539 4,883,142 5,214,681 0 0 0 0
143 715.5 ACSR 0 0 0 0 0 0 0
144 715.5 ACSR 0 0 0 0 0 0 0
145 1272 ACSR 846,523 5,865,688 6,712,211 0 0 0 0
146 795 ACSR 0 0 0 0 0 0 0
147 795 ACSR 0 0 0 0 0 0 0
148 795 ACSR 0 0 0 0 0 0 0
149 795 ACSR 0 351,497 351,497 0 0 0 0
150 1272 ACSR 691,728 6,045,286 6,737,014 0 0 0 0
151 397.5 ACSR 0 94,004 94,004 0 0 0 0
152 250 COPPER 0 105,684 105,684 0 0 0 0
153 715.5 ACSR 1,174 267,313 268,487 0 0 0 0
154 1272 ACSR 327,334 2,143,350 2,470,684 0 0 0 0
155 1272 ACSR 0 0 0 0 0 0 0
156 795 ACSR 0 0 0 0 0 0 0
157 795 ACSR 0 0 0 0 0 0 0
158 795 ACSR 0 0 0 0 0 0 0
159 795 ACSR 0 533,011 533,011 0 0 0 0
160 795 ACSR 0 (16,973)(16,973)0 0 0 0
161 1590 ACSR 0 60,659 60,659 0 0 0 0
162 715.5 ACSR 105,933 4,125,054 4,230,987 0 0 0 0
163 250 COPPER 58 112,396 112,454 0 0 0 0
164 715.5 ACSR 0 176,784 176,784 0 0 0 0
165 397.5 ACSR 0 74,560 74,560 0 0 0 0
166 715.5 ACSR 1,074 705,716 706,790 0 0 0 0
167 397.5 ACSR 6,332 2,612,677 2,619,009 0 0 0 0
168 715.5 ACSR 86,651 5,275,527 5,362,178 0 0 0 0
TRANSMISSION LINE STATISTICS
COST OF LINE
(Include in column (j)
Land, Land rights,
and clearing right-of-
way)
COST OF LINE
(Include in column (j)
Land, Land rights,
and clearing right-of-
way)
COST OF LINE
(Include in column (j)
Land, Land rights,
and clearing right-of-
way)
EXPENSES, EXCEPT
DEPRECIATION AND
TAXES
EXPENSES,
EXCEPT
DEPRECIATION
AND TAXES
EXPENSES,
EXCEPT
DEPRECIATION
AND TAXES
EXPENSES,
EXCEPT
DEPRECIATION
AND TAXES
Line
No.
Size of Conductor and
Material Land Construction Costs Total Costs Operation Expenses Maintenance
Expenses Rents Total Expenses
(i)(j)(k)(l)(m)(n)(o)(p)
FERC FORM NO. 1 (ED. 12-87)
Page 422-423
127 795 AAC 0 0 0 0 0 0 0128795 AAC 0 0 0 0 0 0 0129795 AAC 541,877 3,301,157 3,843,034 0 0 0 0130795 AAC 0 0 0 0 0 0 0131397.5 ACSR 0 0 0 0 0 0 01321272 ACSR 140,412 2,602,119 2,742,531 0 0 0 01331272 ACSR 0 0 0 0 0 0 0134795 ACSR 134,471 1,405,436 1,539,907 0 0 0 0135715.5 ACSR 2,473,833 19,071,763 21,545,596 0 0 0 0136715.5 ACSR 0 0 0 0 0 0 0137715.5 ACSR 0 0 0 0 0 0 0138715.5 ACSR 0 0 0 0 0 0 0139715.5 ACSR 0 0 0 0 0 0 01401272 ACSR 78,579 2,221,530 2,300,109 0 0 0 014140,580 0 40,580 0 0 0 0142715.5 ACSR 331,539 4,883,142 5,214,681 0 0 0 0143715.5 ACSR 0 0 0 0 0 0 0144715.5 ACSR 0 0 0 0 0 0 01451272 ACSR 846,523 5,865,688 6,712,211 0 0 0 0146795 ACSR 0 0 0 0 0 0 0147795 ACSR 0 0 0 0 0 0 0148795 ACSR 0 0 0 0 0 0 0149795 ACSR 0 351,497 351,497 0 0 0 01501272 ACSR 691,728 6,045,286 6,737,014 0 0 0 0151397.5 ACSR 0 94,004 94,004 0 0 0 0152250 COPPER 0 105,684 105,684 0 0 0 0153715.5 ACSR 1,174 267,313 268,487 0 0 0 01541272 ACSR 327,334 2,143,350 2,470,684 0 0 0 01551272 ACSR 0 0 0 0 0 0 0156795 ACSR 0 0 0 0 0 0 0157795 ACSR 0 0 0 0 0 0 0158795 ACSR 0 0 0 0 0 0 0159795 ACSR 0 533,011 533,011 0 0 0 0160795 ACSR 0 (16,973)(16,973)0 0 0 01611590 ACSR 0 60,659 60,659 0 0 0 0162715.5 ACSR 105,933 4,125,054 4,230,987 0 0 0 0163250 COPPER 58 112,396 112,454 0 0 0 0164715.5 ACSR 0 176,784 176,784 0 0 0 0165397.5 ACSR 0 74,560 74,560 0 0 0 0166715.5 ACSR 1,074 705,716 706,790 0 0 0 0167397.5 ACSR 6,332 2,612,677 2,619,009 0 0 0 0168715.5 ACSR 86,651 5,275,527 5,362,178 0 0 0 0TRANSMISSION LINE STATISTICSCOST OF LINE(Include in column (j)Land, Land rights,and clearing right-of-way)COST OF LINE(Include in column (j)Land, Land rights,and clearing right-of-way)COST OF LINE(Include in column (j)Land, Land rights,and clearing right-of-way)EXPENSES, EXCEPTDEPRECIATION ANDTAXES EXPENSES,EXCEPTDEPRECIATIONAND TAXES EXPENSES,EXCEPTDEPRECIATIONAND TAXES EXPENSES,EXCEPTDEPRECIATIONAND TAXESLineNo.Size of Conductor andMaterial Land Construction Costs Total Costs Operation Expenses MaintenanceExpenses Rents Total Expenses(i)(j)(k)(l)(m)(n)(o)(p)FERC FORM NO. 1 (ED. 12-87)Page 422-423
169 715.5 ACSR 0 0 0 0 0 0 0
170 715.5 ACSR 0 0 0 0 0 0 0
171 715.5 ACSR 7 295,569 295,576 0 0 0 0
172 715.5 ACSR 5,620 1,744,668 1,750,288 0 0 0 0
173 715.5 ACSR 14,968 186,543 201,511 0 0 0 0
174 397.5 ACSR 17,207 262,545 279,752 0 0 0 0
175 397.5 ACSR 1,978 116,178 118,156 0 0 0 0
176 VARIOUS 2,463,460 107,834,596 110,298,056 0 0 0 0
177 VARIOUS 0 0 0 0 0 0 0
178 VARIOUS 841,348 29,694,385 30,535,733 0 0 0 0
179 8,094,714 1,542,724 5,051,708 14,689,146
36 39,042,142 749,845,066 788,887,208 8,094,714 1,542,724 5,051,708 14,689,146
FERC FORM NO. 1 (ED. 12-87)
Page 422-423
TRANSMISSION LINE STATISTICS
COST OF LINE
(Include in column (j)
Land, Land rights,
and clearing right-of-
way)
COST OF LINE
(Include in column (j)
Land, Land rights,
and clearing right-of-
way)
COST OF LINE
(Include in column (j)
Land, Land rights,
and clearing right-of-
way)
EXPENSES, EXCEPT
DEPRECIATION AND
TAXES
EXPENSES,
EXCEPT
DEPRECIATION
AND TAXES
EXPENSES,
EXCEPT
DEPRECIATION
AND TAXES
EXPENSES,
EXCEPT
DEPRECIATION
AND TAXES
Line
No.
Size of Conductor and
Material Land Construction Costs Total Costs Operation Expenses Maintenance
Expenses Rents Total Expenses
(i)(j)(k)(l)(m)(n)(o)(p)
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original
(2) ☐ A Resubmission
Date of Report:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
FOOTNOTE DATA
(a) Concept: TransmissionLineEndPoint
169 715.5 ACSR 0 0 0 0 0 0 0170715.5 ACSR 0 0 0 0 0 0 0171715.5 ACSR 7 295,569 295,576 0 0 0 0172715.5 ACSR 5,620 1,744,668 1,750,288 0 0 0 0173715.5 ACSR 14,968 186,543 201,511 0 0 0 0174397.5 ACSR 17,207 262,545 279,752 0 0 0 0175397.5 ACSR 1,978 116,178 118,156 0 0 0 0176VARIOUS2,463,460 107,834,596 110,298,056 0 0 0 0177VARIOUS0000000178VARIOUS841,348 29,694,385 30,535,733 0 0 0 01798,094,714 1,542,724 5,051,708 14,689,1463639,042,142 749,845,066 788,887,208 8,094,714 1,542,724 5,051,708 14,689,146FERC FORM NO. 1 (ED. 12-87)Page 422-423TRANSMISSION LINE STATISTICSCOST OF LINE(Include in column (j)Land, Land rights,and clearing right-of-way)COST OF LINE(Include in column (j)Land, Land rights,and clearing right-of-way)COST OF LINE(Include in column (j)Land, Land rights,and clearing right-of-way)EXPENSES, EXCEPTDEPRECIATION ANDTAXES EXPENSES,EXCEPTDEPRECIATIONAND TAXES EXPENSES,EXCEPTDEPRECIATIONAND TAXES EXPENSES,EXCEPTDEPRECIATIONAND TAXESLineNo.Size of Conductor andMaterial Land Construction Costs Total Costs Operation Expenses MaintenanceExpenses Rents Total Expenses(i)(j)(k)(l)(m)(n)(o)(p)
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original
(2) ☐ A Resubmission
Date of Report:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
FOOTNOTE DATA
(a) Concept: TransmissionLineEndPoint(a) Concept: TransmissionLineEndPoint
Borah Midpoint - This line is jointly owned with PacifiCorp and Idaho Power owns 73.2% of this 85.4 mile line.
(b) Concept: TransmissionLineEndPoint
Boardman Slatt - This line is jointly owned with Portland General Electric and Idaho Power owns 10% of this 17.8 mile line.
(c) Concept: TransmissionLineEndPoint
Summer Lake - Hemingway - This line is jointly owned with PacifiCorp and Idaho Power owns 22.0% of this 241.3 mile line.
(d) Concept: TransmissionLineEndPoint
Hemingway Midpoint - This line is jointly owned with PacifiCorp and Idaho Power owns 37.0% of this 129.3 mile line.
(e) Concept: TransmissionLineEndPoint
Summer Lake Hemingway - This line is jointly owned with PacifiCorp and Idaho Power owns 22.0% of this 241.3 mile line.
(f) Concept: TransmissionLineEndPoint
Hemingway Midpoint - This line is jointly owned with PacifiCorp and Idaho Power owns 37.0% of this 129.3 mile line.
(g) Concept: TransmissionLineEndPoint
Jim Bridger Goshen - This line is jointly owned with PacifiCorp and Idaho Power owns 29.2% of this 226.6 mile line.
(h) Concept: TransmissionLineEndPoint
Kinport Borah - This line is jointly owned with PacifiCorp and Idaho Power owns 73.2% of this 27.1 mile line.
(i) Concept: TransmissionLineEndPoint
Jim Bridger Populus - This line is jointly owned with PacifiCorp and Idaho Power owns 29.2% of this approximately 193 mile line.
(j) Concept: TransmissionLineEndPoint
Populus Kinport This line is jointly owned with PacifiCorp and Idaho Power owns 29.2% of this 41.2 mile line.
(k) Concept: TransmissionLineEndPoint
Jim Bridger Populus - This line is jointly owned with PacifiCorp and Idaho Power owns 29.2% of this approximately 193 mile line.
(l) Concept: TransmissionLineEndPoint
Populus Borah - This line is jointly owned with PacifiCorp and Idaho Power owns 29.2% of this 47.3 mile line.
(m) Concept: TransmissionLineEndPoint
Goshen - Kinport - This line is jointly owned with PacifiCorp and Idaho Power owns 18.3% of this 40.9 mile line.
(n) Concept: TransmissionLineEndPoint
Midpoint Borah #1 - This line is jointly owned with PacifiCorp and Idaho Power owns 64.4% of this 79.5 mile line.
(o) Concept: TransmissionLineEndPoint
Midpoint Borah #2 - This line is jointly owned with PacifiCorp and Idaho Power owns 64.4% of this 77.9 mile line.
(p) Concept: TransmissionLineEndPoint
Adelaide Tap Adelaide - This line is jointly owned with PacifiCorp and Idaho Power owns 64.4% of this 0.9 mile line.
(q) Concept: TransmissionLineEndPoint
Boardman Dalreed Sub - This line is jointly owned with Portland General Electric and Idaho Power owns 10% of this 16.7 mile line.
(r) Concept: TransmissionLineEndPoint
Walla Walla - Hurricane - This line is jointly owned with PacifiCorp and Idaho Power owns 40.8% of this 77.6 mile line.
(s) Concept: TransmissionLineEndPoint
Goshen Stateline - This line is jointly owned with PacifiCorp. Idaho Power owns 37.8% of the Goshen Jefferson 28.9 mile segment, 37.8% of the Jefferson Big Grassy 20.8 mile segment and
100% of the Big Grassy Stateline 40.9 mile segment.
(t) Concept: TransmissionLineEndPoint
Antelope - Goshen - This line is jointly owned with PacifiCorp and Idaho Power owns 21.9% of this 25.8 mile line.
(u) Concept: TransmissionLineEndPoint
Goshen Stateline - This line is jointly owned with PacifiCorp. Idaho Power owns 37.8% of the Goshen Jefferson 28.9 mile segment, 37.8% of the Jefferson Big Grassy 20.8 mile segment and
100% of the Big Grassy Stateline 40.9 mile segment.
(v) Concept: TransmissionLineEndPoint
Goshen Stateline - This line is jointly owned with PacifiCorp. Idaho Power owns 37.8% of the Goshen Jefferson 28.9 mile segment, 37.8% of the Jefferson Big Grassy 20.8 mile segment and
100% of the Big Grassy Stateline 40.9 mile segment.
(w) Concept: TransmissionLineEndPoint
Antelope - Scoville - This line is jointly owned with PacifiCorp and Idaho Power owns 11.5% of this 1 mile line.
(x) Concept: TransmissionLineEndPoint
American Falls Wheelon - 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 422-423
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original
(2) ☐ A Resubmission
Date of Report:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
TRANSMISSION LINES ADDED DURING YEAR
LINE DESIGNATION LINE DESIGNATION SUPPORTING
STRUCTURE
SUPPORTING
STRUCTURE
CIRCUITS
PER
FERC FORM NO. 1 (REV. 12-03)
Page 424-425
(a) Concept: TransmissionLineEndPointBorah Midpoint - This line is jointly owned with PacifiCorp and Idaho Power owns 73.2% of this 85.4 mile line.(b) Concept: TransmissionLineEndPointBoardman Slatt - This line is jointly owned with Portland General Electric and Idaho Power owns 10% of this 17.8 mile line.(c) Concept: TransmissionLineEndPointSummer Lake - Hemingway - This line is jointly owned with PacifiCorp and Idaho Power owns 22.0% of this 241.3 mile line.(d) Concept: TransmissionLineEndPointHemingway Midpoint - This line is jointly owned with PacifiCorp and Idaho Power owns 37.0% of this 129.3 mile line.(e) Concept: TransmissionLineEndPointSummer Lake Hemingway - This line is jointly owned with PacifiCorp and Idaho Power owns 22.0% of this 241.3 mile line.(f) Concept: TransmissionLineEndPointHemingway Midpoint - This line is jointly owned with PacifiCorp and Idaho Power owns 37.0% of this 129.3 mile line.(g) Concept: TransmissionLineEndPointJim Bridger Goshen - This line is jointly owned with PacifiCorp and Idaho Power owns 29.2% of this 226.6 mile line.(h) Concept: TransmissionLineEndPointKinport Borah - This line is jointly owned with PacifiCorp and Idaho Power owns 73.2% of this 27.1 mile line.(i) Concept: TransmissionLineEndPointJim Bridger Populus - This line is jointly owned with PacifiCorp and Idaho Power owns 29.2% of this approximately 193 mile line.(j) Concept: TransmissionLineEndPointPopulus Kinport This line is jointly owned with PacifiCorp and Idaho Power owns 29.2% of this 41.2 mile line.(k) Concept: TransmissionLineEndPointJim Bridger Populus - This line is jointly owned with PacifiCorp and Idaho Power owns 29.2% of this approximately 193 mile line.(l) Concept: TransmissionLineEndPointPopulus Borah - This line is jointly owned with PacifiCorp and Idaho Power owns 29.2% of this 47.3 mile line.(m) Concept: TransmissionLineEndPointGoshen - Kinport - This line is jointly owned with PacifiCorp and Idaho Power owns 18.3% of this 40.9 mile line.(n) Concept: TransmissionLineEndPointMidpoint Borah #1 - This line is jointly owned with PacifiCorp and Idaho Power owns 64.4% of this 79.5 mile line.(o) Concept: TransmissionLineEndPointMidpoint Borah #2 - This line is jointly owned with PacifiCorp and Idaho Power owns 64.4% of this 77.9 mile line.(p) Concept: TransmissionLineEndPointAdelaide Tap Adelaide - This line is jointly owned with PacifiCorp and Idaho Power owns 64.4% of this 0.9 mile line.(q) Concept: TransmissionLineEndPointBoardman Dalreed Sub - This line is jointly owned with Portland General Electric and Idaho Power owns 10% of this 16.7 mile line.(r) Concept: TransmissionLineEndPointWalla Walla - Hurricane - This line is jointly owned with PacifiCorp and Idaho Power owns 40.8% of this 77.6 mile line.(s) Concept: TransmissionLineEndPointGoshen Stateline - This line is jointly owned with PacifiCorp. Idaho Power owns 37.8% of the Goshen Jefferson 28.9 mile segment, 37.8% of the Jefferson Big Grassy 20.8 mile segment and100% of the Big Grassy Stateline 40.9 mile segment.(t) Concept: TransmissionLineEndPointAntelope - Goshen - This line is jointly owned with PacifiCorp and Idaho Power owns 21.9% of this 25.8 mile line.(u) Concept: TransmissionLineEndPointGoshen Stateline - This line is jointly owned with PacifiCorp. Idaho Power owns 37.8% of the Goshen Jefferson 28.9 mile segment, 37.8% of the Jefferson Big Grassy 20.8 mile segment and100% of the Big Grassy Stateline 40.9 mile segment.(v) Concept: TransmissionLineEndPointGoshen Stateline - This line is jointly owned with PacifiCorp. Idaho Power owns 37.8% of the Goshen Jefferson 28.9 mile segment, 37.8% of the Jefferson Big Grassy 20.8 mile segment and100% of the Big Grassy Stateline 40.9 mile segment.(w) Concept: TransmissionLineEndPointAntelope - Scoville - This line is jointly owned with PacifiCorp and Idaho Power owns 11.5% of this 1 mile line.(x) Concept: TransmissionLineEndPointAmerican Falls Wheelon - 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 422-423
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original
(2) ☐ A Resubmission
Date of Report:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
TRANSMISSION LINES ADDED DURING YEAR
LINE DESIGNATION LINE DESIGNATION SUPPORTING
STRUCTURE
SUPPORTING
STRUCTURE
CIRCUITS
PER
FERC FORM NO. 1 (REV. 12-03)
Page 424-425LINE DESIGNATION LINE DESIGNATION STRUCTURE STRUCTURE PER
STRUCTURE
Line
No.From To Line Length in Miles Type Average Number per
Miles Present
(a)(b)(c)(d)(e)(f)
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
FERC FORM NO. 1 (REV. 12-03)
Page 424-425
LINE DESIGNATION LINE DESIGNATION STRUCTURE STRUCTURE PERSTRUCTURELineNo.From To Line Length in Miles Type Average Number perMiles Present(a)(b)(c)(d)(e)(f)1234567891011121314151617181920212223242526272829303132333435363738394041FERC FORM NO. 1 (REV. 12-03)
Page 424-425
42
43
44 TOTAL (a)
FERC FORM NO. 1 (REV. 12-03)
Page 424-425
TRANSMISSION LINES ADDED DURING YEAR
LINE DESIGNATION LINE DESIGNATION SUPPORTING
STRUCTURE
SUPPORTING
STRUCTURE
CIRCUITS
PER
STRUCTURE
Line
No.From To Line Length in Miles Type Average Number per
Miles Present
(a)(b)(c)(d)(e)(f)
TRANSMISSION LINES ADDED DURING YEAR
CIRCUITS PER
STRUCTURE CONDUCTORS CONDUCTORS CONDUCTORS LINE COST
Line
No.Ultimate Size Specification Configuration and Spacing Voltage KV (Operating)Land and Land Rights
(g)(h)(i)(j)(k)(l)
1FERC FORM NO. 1 (REV. 12-03)
Page 424-425
424344 TOTAL (a)FERC FORM NO. 1 (REV. 12-03)Page 424-425TRANSMISSION LINES ADDED DURING YEARLINE DESIGNATION LINE DESIGNATION SUPPORTINGSTRUCTURE SUPPORTINGSTRUCTURE CIRCUITSPERSTRUCTURELineNo.From To Line Length in Miles Type Average Number perMiles Present(a)(b)(c)(d)(e)(f)
TRANSMISSION LINES ADDED DURING YEAR
CIRCUITS PER
STRUCTURE CONDUCTORS CONDUCTORS CONDUCTORS LINE COST
Line
No.Ultimate Size Specification Configuration and Spacing Voltage KV (Operating)Land and Land Rights
(g)(h)(i)(j)(k)(l)
1FERC FORM NO. 1 (REV. 12-03)
Page 424-425
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
FERC FORM NO. 1 (REV. 12-03)
Page 424-425
TRANSMISSION LINES ADDED DURING YEAR
CIRCUITS PER
STRUCTURE CONDUCTORS CONDUCTORS CONDUCTORS LINE COST
Line
No.Ultimate Size Specification Configuration and Spacing Voltage KV (Operating)Land and Land Rights
(g)(h)(i)(j)(k)(l)
TRANSMISSION LINES ADDED DURING YEAR
LINE COST LINE COST LINE COST LINE COST
Line
No.Poles, Towers and Fixtures Conductors and Devices Asset Retire. Costs Total Construction
(m)(n)(o)(p)(q)
1
FERC FORM NO. 1 (REV. 12-03)
1234567891011121314151617181920212223242526272829303132333435363738394041424344FERC FORM NO. 1 (REV. 12-03)
Page 424-425
TRANSMISSION LINES ADDED DURING YEARCIRCUITS PERSTRUCTURE CONDUCTORS CONDUCTORS CONDUCTORS LINE COSTLineNo.Ultimate Size Specification Configuration and Spacing Voltage KV (Operating)Land and Land Rights(g)(h)(i)(j)(k)(l)
TRANSMISSION LINES ADDED DURING YEAR
LINE COST LINE COST LINE COST LINE COST
Line
No.Poles, Towers and Fixtures Conductors and Devices Asset Retire. Costs Total Construction
(m)(n)(o)(p)(q)
1
FERC FORM NO. 1 (REV. 12-03)2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
FERC FORM NO. 1 (REV. 12-03)
Page 424-425
TRANSMISSION LINES ADDED DURING YEAR
LINE COST LINE COST LINE COST LINE COST
Line
No.Poles, Towers and Fixtures Conductors and Devices Asset Retire. Costs Total Construction
(m)(n)(o)(p)(q)
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original
(2) ☐ A Resubmission
Date of Report:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
FOOTNOTE DATA
(a) Concept: LengthOfTransmissionLineAdded
234567891011121314151617181920212223242526272829303132333435363738394041424344FERC FORM NO. 1 (REV. 12-03)Page 424-425TRANSMISSION LINES ADDED DURING YEARLINE COST LINE COST LINE COST LINE COSTLineNo.Poles, Towers and Fixtures Conductors and Devices Asset Retire. Costs Total Construction(m)(n)(o)(p)(q)
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original
(2) ☐ A Resubmission
Date of Report:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
FOOTNOTE DATA
(a) Concept: LengthOfTransmissionLineAdded(a) Concept: LengthOfTransmissionLineAdded
No Transmission line additions for 2023.
FERC FORM NO. 1 (REV. 12-03)
Page 424-425
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original
(2) ☐ A Resubmission
Date of Report:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
SUBSTATIONS
Character of Substation Character of Substation VOLTAGE (In MVa)VOLTAGE (In
MVa)
VOLTAGE
(In MVa)
FERC FORM NO. 1 (ED. 12-96)
Page 426-427
(a) Concept: LengthOfTransmissionLineAddedNo Transmission line additions for 2023.FERC FORM NO. 1 (REV. 12-03)Page 424-425
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original
(2) ☐ A Resubmission
Date of Report:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
SUBSTATIONS
Character of Substation Character of Substation VOLTAGE (In MVa)VOLTAGE (In
MVa)
VOLTAGE
(In MVa)
FERC FORM NO. 1 (ED. 12-96)
Page 426-427 MVa)(In MVa)
Line
No.
Name and Location of Substation
(a)
Transmission or Distribution
(b)
Attended or Unattended
(b-1)
Primary Voltage (In
MVa)
(c)
Secondary
Voltage (In
MVa)
(d)
Tertiary
Voltage
(In MVa)
(e)
Capacity
of
Substation
(In
Service)
(In MVa)
(f)
1
(a)
Adelaide Transmission Unattended (u)345 (v)138 (w)13.8 (x)500
2 Aiken Distribution Unattended 46 13 27
3 Alameda Distribution Unattended 138 13 30
4 Alameda Distribution Unattended 138 13.09 30
5 American Falls PP Transmission Attended 138 13.8 120
6 American Falls Transmission Unattended 138 46 12.47 47
7
(b)
Antelope Transmission Unattended 230 161 13.8 224
8
(c)
Antelope Transmission Unattended 161 138 12.47 103
9
(d)
Antelope Transmission Unattended 161 138 13.8 92
10 Artesian Distribution Unattended 46 13 14
11 Bannock Creek Distribution Unattended 46 13 14
12 Beacon Light Distribution Unattended 138 13.09 45
13 Bennett Mountain Power Plant Transmission Attended 230 18 225
14 Bennett Mountain Power Plant Distribution Attended 18 4.16 5
15 Bethel Court Distribution Unattended 138 13 28
16
(e)
Big Grassy Transmission Unattended 161
17 Black Cat Distribution Unattended 138 13.09 90
18 Black Mesa Distribution Unattended 138 13 11
19 Blackfoot Distribution Unattended 46 13 56
20 Blackfoot Transmission Unattended 161 46 12.47 93
21 Blackfoot Distribution Unattended 161 138 12.98 135
22 Bliss Transmission Attended 138 13.8 86
23 Blue Gulch Distribution Unattended 138 35 48
24 Boise Bench Transmission Unattended 230 138 13.2 448
25 Boise Bench Distribution Unattended 138 35 30
26 Boise Bench Transmission Unattended 138 69 12.98 125
27 Boise Bench Transmission Unattended 230 138 13.8 448
28 Boise Bench Distribution Unattended 138 36.2 45
29 Boise Distribution Unattended 138 13 117
30
(f)
Borah Transmission Unattended 345 230 13.8 750
31 Border Distribution Unattended 138 12.47 11
32 Border Distribution Unattended 35 12.47 5
33 Boulder Distribution Unattended 138 35 30
34 Bowmont Distribution Unattended 138 35 30
35 Bowmont Transmission Unattended 138 69 12.98 46
36 Bowmont Transmission Unattended 138 69 12.47 47
37 Bowmont Transmission Unattended 230 138 13.8 600
FERC FORM NO. 1 (ED. 12-96)
Page 426-427
MVa)(In MVa)LineNo.Name and Location of Substation(a)Transmission or Distribution(b)Attended or Unattended(b-1)Primary Voltage (InMVa)(c)SecondaryVoltage (InMVa)(d)TertiaryVoltage(In MVa)(e)CapacityofSubstation(InService)(In MVa)(f)1 (a)Adelaide Transmission Unattended (u)345 (v)138 (w)13.8 (x)5002AikenDistributionUnattended4613273AlamedaDistributionUnattended13813304AlamedaDistributionUnattended13813.09 305American Falls PP Transmission Attended 138 13.8 1206American Falls Transmission Unattended 138 46 12.47 477(b)Antelope Transmission Unattended 230 161 13.8 2248(c)Antelope Transmission Unattended 161 138 12.47 1039(d)Antelope Transmission Unattended 161 138 13.8 9210ArtesianDistributionUnattended46131411Bannock Creek Distribution Unattended 46 13 1412Beacon Light Distribution Unattended 138 13.09 4513Bennett Mountain Power Plant Transmission Attended 230 18 22514Bennett Mountain Power Plant Distribution Attended 18 4.16 515Bethel Court Distribution Unattended 138 13 2816(e)Big Grassy Transmission Unattended 16117Black Cat Distribution Unattended 138 13.09 9018Black Mesa Distribution Unattended 138 13 1119BlackfootDistributionUnattended46135620BlackfootTransmissionUnattended1614612.47 9321BlackfootDistributionUnattended16113812.98 13522BlissTransmissionAttended13813.8 8623Blue Gulch Distribution Unattended 138 35 4824Boise Bench Transmission Unattended 230 138 13.2 44825Boise Bench Distribution Unattended 138 35 3026Boise Bench Transmission Unattended 138 69 12.98 12527Boise Bench Transmission Unattended 230 138 13.8 44828Boise Bench Distribution Unattended 138 36.2 4529BoiseDistributionUnattended1381311730(f)Borah Transmission Unattended 345 230 13.8 75031BorderDistributionUnattended13812.47 1132BorderDistributionUnattended3512.47 533BoulderDistributionUnattended138353034BowmontDistributionUnattended138353035BowmontTransmissionUnattended1386912.98 4636BowmontTransmissionUnattended1386912.47 4737BowmontTransmissionUnattended23013813.8 600FERC FORM NO. 1 (ED. 12-96)Page 426-427
38 Brady Transmission Unattended 230 138 13.8 312
39 Brady Transmission Unattended 138 46 12.47
40 Brady Distribution Unattended 46 13
41 Brady Distribution Unattended 46 7.2
42 Brownlee Transmission Attended 230 13.8 856
43 Bruneau Bridge Distribution Unattended 138 35 30
44 Bruneau Bridge Distribution Unattended 138 36.2 45
45 Buckhorn Distribution Unattended 69 35 37
46 Buhl Distribution Unattended 46 13.2
47 Burley Rural Distribution Unattended 69 13 20
48 Burley Rural Distribution Unattended 69 13.09 30
49 Butler Distribution Unattended 138 13.09 90
50 Caldwell Distribution Unattended 138 13 28
51 Caldwell Transmission Unattended 230 138 225
52 Caldwell Distribution Unattended 138 13.09 45
53 Caldwell Transmission Unattended 138 69 12.47 140
54 Caldwell Transmission Unattended 230 138 12.47 200
55 Camas Distribution Unattended 35 12.47 5
56 Camas Distribution Unattended 35 14.4 10
57 Can-Ada Distribution Unattended 138 13.09 45
58 Canyon Creek Distribution Unattended 138 36.2 45
59 Canyon Creek Transmission Unattended 138 69 12.98 20
60 Cartwright Distribution Unattended 138 13 11
61 Cascade Power Plant Transmission Attended 69 4.6 16
62 Cascade Distribution Unattended 69 13.09 21
63 Cascade Distribution Unattended 25 12.5 5
64 Chestnut Distribution Unattended 138 13 45
65 Chestnut Distribution Unattended 138 13.09 45
66 Cinder Distribution Unattended 46 13 11
67 Clear Lake Transmission Attended 46 2.4 5
68 Cliff Transmission Unattended 138 46 12.5 21
69 Cliff Transmission Unattended 138 46 12.95 10
70 Cloverdale Distribution Unattended 138 13 90
71 Cloverdale Distribution Unattended 138 13.09 45
72 Cloverdale Transmission Unattended 230 138 13.8 300
73 Columbia Distribution Unattended 138 13.09 45
74 Council Distribution Unattended 69 13 14
75 Crane Creek Distribution Unattended 69 13 11
76 Crater Distribution Unattended 46 13 11
77 Dale Distribution Unattended 46 4.6
78 Dale Distribution Unattended 46 13
79 Dale Distribution Unattended 69 13
SUBSTATIONS
Character of Substation Character of Substation VOLTAGE (In MVa)VOLTAGE (In
MVa)
VOLTAGE
(In MVa)
Line
No.
Name and Location of Substation
(a)
Transmission or Distribution
(b)
Attended or Unattended
(b-1)
Primary Voltage (In
MVa)
(c)
Secondary
Voltage (In
MVa)
(d)
Tertiary
Voltage
(In MVa)
(e)
Capacity
of
Substation
(In
Service)
(In MVa)
(f)
FERC FORM NO. 1 (ED. 12-96)
Page 426-427
38 Brady Transmission Unattended 230 138 13.8 31239BradyTransmissionUnattended1384612.4740BradyDistributionUnattended461341BradyDistributionUnattended467.242BrownleeTransmissionAttended23013.8 85643Bruneau Bridge Distribution Unattended 138 35 3044Bruneau Bridge Distribution Unattended 138 36.2 4545BuckhornDistributionUnattended69353746BuhlDistributionUnattended4613.247Burley Rural Distribution Unattended 69 13 2048Burley Rural Distribution Unattended 69 13.09 3049ButlerDistributionUnattended13813.09 9050CaldwellDistributionUnattended138132851CaldwellTransmissionUnattended23013822552CaldwellDistributionUnattended13813.09 4553CaldwellTransmissionUnattended1386912.47 14054CaldwellTransmissionUnattended23013812.47 20055CamasDistributionUnattended3512.47 556CamasDistributionUnattended3514.4 1057Can-Ada Distribution Unattended 138 13.09 4558Canyon Creek Distribution Unattended 138 36.2 4559Canyon Creek Transmission Unattended 138 69 12.98 2060CartwrightDistributionUnattended138131161Cascade Power Plant Transmission Attended 69 4.6 1662CascadeDistributionUnattended6913.09 2163CascadeDistributionUnattended2512.5 564ChestnutDistributionUnattended138134565ChestnutDistributionUnattended13813.09 4566CinderDistributionUnattended46131167Clear Lake Transmission Attended 46 2.4 568CliffTransmissionUnattended1384612.5 2169CliffTransmissionUnattended1384612.95 1070CloverdaleDistributionUnattended138139071CloverdaleDistributionUnattended13813.09 4572CloverdaleTransmissionUnattended23013813.8 30073ColumbiaDistributionUnattended13813.09 4574CouncilDistributionUnattended69131475Crane Creek Distribution Unattended 69 13 1176CraterDistributionUnattended46131177DaleDistributionUnattended464.678DaleDistributionUnattended461379DaleDistributionUnattended6913SUBSTATIONSCharacter of Substation Character of Substation VOLTAGE (In MVa)VOLTAGE (InMVa)VOLTAGE(In MVa)LineNo.Name and Location of Substation(a)Transmission or Distribution(b)Attended or Unattended(b-1)Primary Voltage (InMVa)(c)SecondaryVoltage (InMVa)(d)TertiaryVoltage(In MVa)(e)CapacityofSubstation(InService)(In MVa)(f)FERC FORM NO. 1 (ED. 12-96)
Page 426-427
80 Dale Distribution Unattended 138 36.2 90
81 Dale Transmission Unattended 138 46 12.47 47
82 Danskin Transmission Attended 230 18 233
83 Danskin Transmission Attended 230 138 13.8 300
84 Danskin Distribution Attended 18 4.16 6
85 Danskin Transmission Attended 138 12 160
86 Danskin Distribution Attended 35 13.8 5
87 Deen Distribution Unattended 46 13 11
88 Dietrich Distribution Unattended 46 13.09 14
89 Don Distribution Unattended 138 7.6
90 Don Distribution Unattended 138 13.2 180
91 Don Distribution Unattended 138 13 44
92 DRAM Distribution Unattended 138 13.09 168
93 DRAM Transmission Unattended 230 138 13.8 212
94 DRAM Distribution Unattended 138 12.47 28
95 DRAM Distribution Unattended 138 13 28
96 Duffin Distribution Unattended 138 35 60
97 Eagle Distribution Unattended 138 13.09 67
98 Eastgate Distribution Unattended 138 13.09 75
99 Eckert Distribution Unattended 138 36.2 30
100 Eden Distribution Unattended 138 36.2 45
101 Eden Transmission Unattended 138 46 12.98 20
102 Eldredge Distribution Unattended 138 13.09 45
103 Elkhorn Distribution Unattended 138 12.47 11
104 Elkhorn Distribution Unattended 138 13 11
105 Elmore Distribution Unattended 138 35 28
106 Elmore Transmission Unattended 138 69 12.5 25
107 Elmore Transmission Unattended 138 69 12.98 20
108 Emmett Distribution Unattended 138 13.09 45
109 Emmett Transmission Unattended 138 69 12.47 47
110 Emmett-Boise Cascade #1 Distribution Unattended 69 13.09 14
111 Falls Distribution Unattended 46 13 28
112 Filer Distribution Unattended 46 13 14
113 Flat Top Distribution Unattended 46 13 11
114 Flat Top Distribution Unattended 46 13.09 14
115 Flying H Distribution Unattended 69 2.4 20
116 Fort Hall Distribution Unattended 46 13 14
117 Fossil Gulch Distribution Unattended 138 35 28
118 Fremont Transmission Unattended 138 46 12.5 67
119 Fruitland Distribution Unattended 69 13 20
120 Gary Distribution Unattended 138 13.09 37
SUBSTATIONS
Character of Substation Character of Substation VOLTAGE (In MVa)VOLTAGE (In
MVa)
VOLTAGE
(In MVa)
Line
No.
Name and Location of Substation
(a)
Transmission or Distribution
(b)
Attended or Unattended
(b-1)
Primary Voltage (In
MVa)
(c)
Secondary
Voltage (In
MVa)
(d)
Tertiary
Voltage
(In MVa)
(e)
Capacity
of
Substation
(In
Service)
(In MVa)
(f)
FERC FORM NO. 1 (ED. 12-96)
Page 426-427
80 Dale Distribution Unattended 138 36.2 9081DaleTransmissionUnattended1384612.47 4782DanskinTransmissionAttended2301823383DanskinTransmissionAttended23013813.8 30084DanskinDistributionAttended184.16 685DanskinTransmissionAttended1381216086DanskinDistributionAttended3513.8 587DeenDistributionUnattended46131188DietrichDistributionUnattended4613.09 1489DonDistributionUnattended1387.690DonDistributionUnattended13813.2 18091DonDistributionUnattended138134492DRAMDistributionUnattended13813.09 16893DRAMTransmissionUnattended23013813.8 21294DRAMDistributionUnattended13812.47 2895DRAMDistributionUnattended138132896DuffinDistributionUnattended138356097EagleDistributionUnattended13813.09 6798EastgateDistributionUnattended13813.09 7599EckertDistributionUnattended13836.2 30100EdenDistributionUnattended13836.2 45101EdenTransmissionUnattended1384612.98 20102EldredgeDistributionUnattended13813.09 45103ElkhornDistributionUnattended13812.47 11104ElkhornDistributionUnattended1381311105ElmoreDistributionUnattended1383528106ElmoreTransmissionUnattended1386912.5 25107ElmoreTransmissionUnattended1386912.98 20108EmmettDistributionUnattended13813.09 45109EmmettTransmissionUnattended1386912.47 47110Emmett-Boise Cascade #1 Distribution Unattended 69 13.09 14111FallsDistributionUnattended461328112FilerDistributionUnattended461314113Flat Top Distribution Unattended 46 13 11114Flat Top Distribution Unattended 46 13.09 14115Flying H Distribution Unattended 69 2.4 20116Fort Hall Distribution Unattended 46 13 14117Fossil Gulch Distribution Unattended 138 35 28118FremontTransmissionUnattended1384612.5 67119FruitlandDistributionUnattended691320120GaryDistributionUnattended13813.09 37SUBSTATIONSCharacter of Substation Character of Substation VOLTAGE (In MVa)VOLTAGE (InMVa)VOLTAGE(In MVa)LineNo.Name and Location of Substation(a)Transmission or Distribution(b)Attended or Unattended(b-1)Primary Voltage (InMVa)(c)SecondaryVoltage (InMVa)(d)TertiaryVoltage(In MVa)(e)CapacityofSubstation(InService)(In MVa)(f)FERC FORM NO. 1 (ED. 12-96)Page 426-427
121 Gary Distribution Unattended 138 13 28
122 Gem Distribution Unattended 69 13
123 Gem Distribution Unattended 69 13.09 28
124 Glenns Ferry Distribution Unattended 138 13 11
125 Gooding Rural Distribution Unattended 46 13 20
126 Golden Valley Distribution Unattended 69 13 14
127
(g)
Goshen Transmission Unattended 345 161 13.8 1608
128 Gowen Substation Distribution Unattended 138 35 45
129 Gowen Substation Distribution Unattended 138 36.2 45
130 Grindstone Distribution Unattended 35 2.4 14
131 Grove Distribution Unattended 138 13.09 90
132 Grove Distribution Unattended 138 13 45
133 Hagerman Distribution Unattended 46 13 14
134 Hagerman Distribution Unattended 69 13 6
135 Hailey Distribution Unattended 138 13 37
136 Happy Valley Distribution Unattended 138 13.09 30
137 Haven Distribution Unattended 138 35 20
138 Haven Transmission Unattended 138 46 47
139 Hawk Distribution Unattended 138 35 30
140
(h)
Hemingway Transmission Unattended 500 230 34.5 1000
141 Hewlett Packard Distribution Unattended 138 13 37
142 Hidden Springs Distribution Unattended 138 13 11
143 Highland Distribution Unattended 138 13 30
144 Hill Distribution Unattended 138 13 73
145 Hillsdale Distribution Unattended 138 13.09 45
146 Homedale Distribution Unattended 69 13 34
147 Horse Flat Transmission Unattended 230 138 13.8 100
148 Horseshoe Bend Distribution Unattended 35 13.09 7
149 Horseshoe Bend Distribution Unattended 69 36.2 22
150 Horseshoe Bend Distribution Unattended 69 25 7
151 Huston Distribution Unattended 69 13 14
152 Hulen Distribution Unattended 46 13 14
153 Hunt Transmission Unattended 230 138 13.8 336
154 Hydra Distribution Unattended 138 36.2 90
155 Island Distribution Unattended 69 13 20
156
(i)
Jefferson Transmission Unattended 161
157 Jerome Distribution Unattended 138 13 37
158 Jerome Distribution Unattended 138 13.09 37
159 Julion Clawson Distribution Unattended 138 35 56
160 Joplin Distribution Unattended 138 13 28
161 Joplin Distribution Unattended 138 36.2 45
SUBSTATIONS
Character of Substation Character of Substation VOLTAGE (In MVa)VOLTAGE (In
MVa)
VOLTAGE
(In MVa)
Line
No.
Name and Location of Substation
(a)
Transmission or Distribution
(b)
Attended or Unattended
(b-1)
Primary Voltage (In
MVa)
(c)
Secondary
Voltage (In
MVa)
(d)
Tertiary
Voltage
(In MVa)
(e)
Capacity
of
Substation
(In
Service)
(In MVa)
(f)
FERC FORM NO. 1 (ED. 12-96)
Page 426-427
121 Gary Distribution Unattended 138 13 28122GemDistributionUnattended6913123GemDistributionUnattended6913.09 28124Glenns Ferry Distribution Unattended 138 13 11125Gooding Rural Distribution Unattended 46 13 20126Golden Valley Distribution Unattended 69 13 14127(g)Goshen Transmission Unattended 345 161 13.8 1608128Gowen Substation Distribution Unattended 138 35 45129Gowen Substation Distribution Unattended 138 36.2 45130GrindstoneDistributionUnattended352.4 14131GroveDistributionUnattended13813.09 90132GroveDistributionUnattended1381345133HagermanDistributionUnattended461314134HagermanDistributionUnattended69136135HaileyDistributionUnattended1381337136Happy Valley Distribution Unattended 138 13.09 30137HavenDistributionUnattended1383520138HavenTransmissionUnattended1384647139HawkDistributionUnattended1383530140(h)Hemingway Transmission Unattended 500 230 34.5 1000141Hewlett Packard Distribution Unattended 138 13 37142Hidden Springs Distribution Unattended 138 13 11143HighlandDistributionUnattended1381330144HillDistributionUnattended1381373145HillsdaleDistributionUnattended13813.09 45146HomedaleDistributionUnattended691334147Horse Flat Transmission Unattended 230 138 13.8 100148Horseshoe Bend Distribution Unattended 35 13.09 7149Horseshoe Bend Distribution Unattended 69 36.2 22150Horseshoe Bend Distribution Unattended 69 25 7151HustonDistributionUnattended691314152HulenDistributionUnattended461314153HuntTransmissionUnattended23013813.8 336154HydraDistributionUnattended13836.2 90155IslandDistributionUnattended691320156(i)Jefferson Transmission Unattended 161157JeromeDistributionUnattended138 13 37158JeromeDistributionUnattended13813.09 37159Julion Clawson Distribution Unattended 138 35 56160JoplinDistributionUnattended1381328161JoplinDistributionUnattended13836.2 45SUBSTATIONSCharacter of Substation Character of Substation VOLTAGE (In MVa)VOLTAGE (InMVa)VOLTAGE(In MVa)LineNo.Name and Location of Substation(a)Transmission or Distribution(b)Attended or Unattended(b-1)Primary Voltage (InMVa)(c)SecondaryVoltage (InMVa)(d)TertiaryVoltage(In MVa)(e)CapacityofSubstation(InService)(In MVa)(f)FERC FORM NO. 1 (ED. 12-96)
Page 426-427
162 Justice Transmission Unattended 230 138 13.8 300
163 Karcher Distribution Unattended 138 13 20
164 Kenyon Distribution Unattended 69 13.09 28
165 Ketchum Distribution Unattended 138 13 75
166 Kimberly Distribution Unattended 138 13.09 45
167 Kinport Transmission Unattended 161 46 13.2
168 Kinport Transmission Unattended 230 138 12.47 300
169 Kinport Transmission Unattended 230 138 13.8 300
170
(j)
Kinport Transmission Unattended 345 230 13.8 1000
171 Kramer Distribution Unattended 138 35 20
172 Kramer Distribution Unattended 138 36.2 30
173 Kuna Distribution Unattended 138 13.09 45
174 Lake Distribution Unattended 69 13 14
175 Lake Fork Distribution Unattended 138 36.2 30
176 Lake Fork Transmission Unattended 138 69 12.5 20
177 Lamb Distribution Unattended 138 13 30
178 Langley Gulch Transmission Attended 230 138 13.8 636
179 Langley Gulch Transmission Attended 230 410
180 Langley Gulch Transmission Attended 230 150
181 Langley Gulch Distribution Attended 18 4.16 20
182 Lansing Distribution Unattended 138 13.09 45
183 Lincoln Distribution Unattended 138 13.09 14
184 Linden Distribution Unattended 138 13 58
185 Locust Distribution Unattended 138 36.2 134
186 Locust Transmission Unattended 230 138 13.8 600
187 Lower Malad Transmission Attended 138 7.2 16
188 Lower Salmon Transmission Attended 138 13.8 70
189 Map Rock Distribution Unattended 69 13.09 14
190 McCall Distribution Unattended 138 13.09 22
191 McCall Distribution Unattended 138 36.2 30
192 Melba Distribution Unattended 69 13 11
193 Meridian Distribution Unattended 138 13 60
194 Micron Distribution Unattended 138 13.09 40
195 Micron Distribution Unattended 138 13 40
196 Midpoint Transmission Unattended 230 138 13.8 300
197 Midpoint Transmission Unattended 345 230 13.8 1400
198
(k)
Midpoint Transmission Unattended 500 345 1500
199 Midrose Distribution Unattended 138 13.09 45
200 Milner Transmission Unattended 138 69 12.47 125
201 Milner Distribution Unattended 69 46 6.9 8
202 Milner Distribution Unattended 138 35 50
SUBSTATIONS
Character of Substation Character of Substation VOLTAGE (In MVa)VOLTAGE (In
MVa)
VOLTAGE
(In MVa)
Line
No.
Name and Location of Substation
(a)
Transmission or Distribution
(b)
Attended or Unattended
(b-1)
Primary Voltage (In
MVa)
(c)
Secondary
Voltage (In
MVa)
(d)
Tertiary
Voltage
(In MVa)
(e)
Capacity
of
Substation
(In
Service)
(In MVa)
(f)
FERC FORM NO. 1 (ED. 12-96)
Page 426-427
162 Justice Transmission Unattended 230 138 13.8 300163KarcherDistributionUnattended1381320164KenyonDistributionUnattended6913.09 28165KetchumDistributionUnattended1381375166KimberlyDistributionUnattended13813.09 45167KinportTransmissionUnattended1614613.2168KinportTransmissionUnattended23013812.47 300169KinportTransmissionUnattended23013813.8 300170(j)Kinport Transmission Unattended 345 230 13.8 1000171KramerDistributionUnattended1383520172KramerDistributionUnattended13836.2 30173KunaDistributionUnattended13813.09 45174LakeDistributionUnattended691314175Lake Fork Distribution Unattended 138 36.2 30176Lake Fork Transmission Unattended 138 69 12.5 20177LambDistributionUnattended1381330178Langley Gulch Transmission Attended 230 138 13.8 636179Langley Gulch Transmission Attended 230 410180Langley Gulch Transmission Attended 230 150181Langley Gulch Distribution Attended 18 4.16 20182LansingDistributionUnattended13813.09 45183LincolnDistributionUnattended13813.09 14184LindenDistributionUnattended1381358185LocustDistributionUnattended13836.2 134186LocustTransmissionUnattended23013813.8 600187Lower Malad Transmission Attended 138 7.2 16188Lower Salmon Transmission Attended 138 13.8 70189Map Rock Distribution Unattended 69 13.09 14190McCallDistributionUnattended13813.09 22191McCallDistributionUnattended13836.2 30192MelbaDistributionUnattended691311193MeridianDistributionUnattended1381360194MicronDistributionUnattended13813.09 40195MicronDistributionUnattended1381340196MidpointTransmissionUnattended23013813.8 300197MidpointTransmissionUnattended34523013.8 1400198(k)Midpoint Transmission Unattended 500 345 1500199MidroseDistributionUnattended13813.09 45200MilnerTransmissionUnattended1386912.47 125201MilnerDistributionUnattended69466.9 8202MilnerDistributionUnattended1383550SUBSTATIONSCharacter of Substation Character of Substation VOLTAGE (In MVa)VOLTAGE (InMVa)VOLTAGE(In MVa)LineNo.Name and Location of Substation(a)Transmission or Distribution(b)Attended or Unattended(b-1)Primary Voltage (InMVa)(c)SecondaryVoltage (InMVa)(d)TertiaryVoltage(In MVa)(e)CapacityofSubstation(InService)(In MVa)(f)FERC FORM NO. 1 (ED. 12-96)Page 426-427
203 Milner PP Transmission Attended 138 13.8 60
204 Moonstone Distribution Unattended 138 35 20
205 Mora Distribution Unattended 138 36.2 90
206 Moreland Distribution Unattended 46 36.2 28
207 Mountain Home Distribution Unattended 69 13 28
208 Mountain Home Air Force Base Distribution Unattended 69 13
209 Mountain Home Air Force Base Distribution Unattended 138 13 34
210 Nampa Transmission Unattended 230 138 13.8 300
211 Nampa Distribution Unattended 138 13 87
212 New Meadows Distribution Unattended 138 36.2 22
213 New Plymouth Distribution Unattended 69 13.09 14
214 Northview Distribution Unattended 138 13.09 45
215 Notch Butte Distribution Unattended 138 13.09 14
216 Orchard Distribution Unattended 138 36.2 45
217 Parma Distribution Unattended 69 13 14
218 Parma Distribution Unattended 69 35 22
219 Parma Distribution Unattended 69 36.2 14
220 Paul Distribution Unattended 138 35 30
221 Paul Distribution Unattended 138 36.2 45
222 Payette Distribution Unattended 138 13.09 45
223 Pingree Transmission Unattended 138 46 12.5 67
224 Pingree Distribution Unattended 138 35 34
225 Pleasant Valley Distribution Unattended 138 35 30
226 Pleasant Valley Distribution Unattended 138 36.2 45
227 Pocatello Distribution Unattended 46 13 60
228 Pocket Distribution Unattended 138 36.2 45
229 Poleline Distribution Unattended 138 13.09 30
230
(l)
Populus Transmission Unattended 345
231 Portneuf Distribution Unattended 138 35 30
232 Portneuf Distribution Unattended 46 35
233 Rockford Distribution Unattended 46 13 25
234 Russett Distribution Unattended 138 13 30
235 Sailor Creek Distribution Unattended 138 2.4 21
236 Sailor Creek Distribution Unattended 138 35 28
237 Salmon Distribution Unattended 69 13.09 22
238 Salmon Distribution Unattended 69 36.2 22
239 Shoshone Distribution Unattended 46 13.09 14
240 Shoshone Transmission Unattended 138 46 12.47 47
241 Shoshone Falls Transmission Attended 46 4.16 4
242 Shoshone Falls Transmission Attended 46 6.6 14
243 Silver Distribution Unattended 138 35 20
SUBSTATIONS
Character of Substation Character of Substation VOLTAGE (In MVa)VOLTAGE (In
MVa)
VOLTAGE
(In MVa)
Line
No.
Name and Location of Substation
(a)
Transmission or Distribution
(b)
Attended or Unattended
(b-1)
Primary Voltage (In
MVa)
(c)
Secondary
Voltage (In
MVa)
(d)
Tertiary
Voltage
(In MVa)
(e)
Capacity
of
Substation
(In
Service)
(In MVa)
(f)
FERC FORM NO. 1 (ED. 12-96)
Page 426-427
203 Milner PP Transmission Attended 138 13.8 60204MoonstoneDistributionUnattended1383520205MoraDistributionUnattended13836.2 90206MorelandDistributionUnattended4636.2 28207Mountain Home Distribution Unattended 69 13 28208Mountain Home Air Force Base Distribution Unattended 69 13209Mountain Home Air Force Base Distribution Unattended 138 13 34210NampaTransmissionUnattended23013813.8 300211NampaDistributionUnattended1381387212New Meadows Distribution Unattended 138 36.2 22213New Plymouth Distribution Unattended 69 13.09 14214NorthviewDistributionUnattended13813.09 45215Notch Butte Distribution Unattended 138 13.09 14216OrchardDistributionUnattended13836.2 45217ParmaDistributionUnattended691314218ParmaDistributionUnattended693522219ParmaDistributionUnattended6936.2 14220PaulDistributionUnattended1383530221PaulDistributionUnattended13836.2 45222PayetteDistributionUnattended13813.09 45223PingreeTransmissionUnattended1384612.5 67224PingreeDistributionUnattended1383534225Pleasant Valley Distribution Unattended 138 35 30226Pleasant Valley Distribution Unattended 138 36.2 45227PocatelloDistributionUnattended461360228PocketDistributionUnattended13836.2 45229PolelineDistributionUnattended13813.09 30230(l)Populus Transmission Unattended 345231PortneufDistributionUnattended138 35 30232PortneufDistributionUnattended4635233RockfordDistributionUnattended461325234RussettDistributionUnattended1381330235Sailor Creek Distribution Unattended 138 2.4 21236Sailor Creek Distribution Unattended 138 35 28237SalmonDistributionUnattended6913.09 22238SalmonDistributionUnattended6936.2 22239ShoshoneDistributionUnattended4613.09 14240ShoshoneTransmissionUnattended1384612.47 47241Shoshone Falls Transmission Attended 46 4.16 4242Shoshone Falls Transmission Attended 46 6.6 14243SilverDistributionUnattended1383520SUBSTATIONSCharacter of Substation Character of Substation VOLTAGE (In MVa)VOLTAGE (InMVa)VOLTAGE(In MVa)LineNo.Name and Location of Substation(a)Transmission or Distribution(b)Attended or Unattended(b-1)Primary Voltage (InMVa)(c)SecondaryVoltage (InMVa)(d)TertiaryVoltage(In MVa)(e)CapacityofSubstation(InService)(In MVa)(f)FERC FORM NO. 1 (ED. 12-96)Page 426-427
244 Simplot Distribution Unattended 138 13 53
245 Sinker Creek Distribution Unattended 138 35 20
246 Siphon Distribution Unattended 138 36.2 75
247 Skyway Distribution Unattended 138 13.09 45
248 South Park Distribution Unattended 46 13 14
249 Spring Valley Distribution Unattended 138 12.47 11
250 Star Distribution Unattended 138 13.09 30
251 Star Distribution Unattended 138 13 28
252 Starkey Transmission Unattended 138 69 12.47 30
253 State Distribution Unattended 69 13 58
254 Sterling Distribution Unattended 46 13 11
255 Stoddard Distribution Unattended 138 13.09 45
256 Strike Power Plant Transmission Attended 138 13.8 104
257 Sugar Distribution Unattended 138 35 28
258 Swan Falls Transmission Attended 138 6.9 34
259 Taber Distribution Unattended 46 13 6
260 Tamarack Distribution Unattended 138 2.4 11
261 Ten Mile Distribution Unattended 138 13.09 90
262 Terry Distribution Unattended 138 13.09 20
263 Terry Distribution Unattended 138 13 50
264 Thousand Springs Transmission Attended 46 7.2 8
265
(m)
Three Mile Knoll Transmission Unattended 345
266 Toponis Distribution Unattended 138 33 30
267 Twin Falls Distribution Unattended 138 13.09 82
268 Twin Falls Transmission Unattended 138 46 12.98 50
269 Twin Falls PP Transmission Attended 138 7.2 13
270 Twin Falls PP Transmission Attended 138 13.2 72
271 Tyhee Distribution Unattended 46 13 14
272 Upper Malad Transmission Attended 45 7.2 8
273 Upper Salmon Transmission Attended 138 7.2 42
274 Ustick Distribution Unattended 138 13 77
275 Vallivue Distribution Unattended 138 13.09 30
276 Victory Distribution Unattended 138 13 45
277 Victory Distribution Unattended 138 13.09 30
278 Ware Distribution Unattended 69 13 20
279 Weiser Distribution Unattended 69 13 28
280 Weiser Transmission Unattended 138 69 12.47 42
281 Wilder Distribution Unattended 69 13 14
282 Willis Distribution Unattended 138 13.09 30
283 Willow Creek Distribution Unattended 138 13 11
284 Wye Distribution Unattended 138 13 60
SUBSTATIONS
Character of Substation Character of Substation VOLTAGE (In MVa)VOLTAGE (In
MVa)
VOLTAGE
(In MVa)
Line
No.
Name and Location of Substation
(a)
Transmission or Distribution
(b)
Attended or Unattended
(b-1)
Primary Voltage (In
MVa)
(c)
Secondary
Voltage (In
MVa)
(d)
Tertiary
Voltage
(In MVa)
(e)
Capacity
of
Substation
(In
Service)
(In MVa)
(f)
FERC FORM NO. 1 (ED. 12-96)
Page 426-427
244 Simplot Distribution Unattended 138 13 53245Sinker Creek Distribution Unattended 138 35 20246SiphonDistributionUnattended13836.2 75247SkywayDistributionUnattended13813.09 45248South Park Distribution Unattended 46 13 14249Spring Valley Distribution Unattended 138 12.47 11250StarDistributionUnattended13813.09 30251StarDistributionUnattended1381328252StarkeyTransmissionUnattended1386912.47 30253StateDistributionUnattended691358254SterlingDistributionUnattended461311255StoddardDistributionUnattended13813.09 45256Strike Power Plant Transmission Attended 138 13.8 104257SugarDistributionUnattended1383528258Swan Falls Transmission Attended 138 6.9 34259TaberDistributionUnattended46136260TamarackDistributionUnattended1382.4 11261Ten Mile Distribution Unattended 138 13.09 90262TerryDistributionUnattended13813.09 20263TerryDistributionUnattended1381350264Thousand Springs Transmission Attended 46 7.2 8265(m)Three Mile Knoll Transmission Unattended 345266ToponisDistributionUnattended138 33 30267Twin Falls Distribution Unattended 138 13.09 82268Twin Falls Transmission Unattended 138 46 12.98 50269Twin Falls PP Transmission Attended 138 7.2 13270Twin Falls PP Transmission Attended 138 13.2 72271TyheeDistributionUnattended461314272Upper Malad Transmission Attended 45 7.2 8273Upper Salmon Transmission Attended 138 7.2 42274UstickDistributionUnattended1381377275VallivueDistributionUnattended13813.09 30276VictoryDistributionUnattended1381345277VictoryDistributionUnattended13813.09 30278WareDistributionUnattended691320279WeiserDistributionUnattended691328280WeiserTransmissionUnattended1386912.47 42281WilderDistributionUnattended691314282WillisDistributionUnattended13813.09 30283Willow Creek Distribution Unattended 138 13 11284WyeDistributionUnattended1381360SUBSTATIONSCharacter of Substation Character of Substation VOLTAGE (In MVa)VOLTAGE (InMVa)VOLTAGE(In MVa)LineNo.Name and Location of Substation(a)Transmission or Distribution(b)Attended or Unattended(b-1)Primary Voltage (InMVa)(c)SecondaryVoltage (InMVa)(d)TertiaryVoltage(In MVa)(e)CapacityofSubstation(InService)(In MVa)(f)FERC FORM NO. 1 (ED. 12-96)Page 426-427
285 Wye Distribution Unattended 138 13.09 37
286 Zilog Distribution Unattended 138 13.09 45
287 The above are all State of Idaho
288 Montana:
289
(n)
Mill Creek Transmission Unattended 230
290 Peterson Transmission Unattended 230 69 13.2 86
291 Nevada:
292
(o)
Valmy Transmission Attended 345 18 315
293 Wells Transmission Unattended 138 69 13 25
294 Oregon:
295 Adrian Distribution Unattended 69 13 11
296
(p)
Burns Transmission Unattended 500
297 Cairo Distribution Unattended 69 13 20
298 Hells Canyon Transmission Attended 230 13.8 560
299 Hells Canyon Distribution Attended 69 0.5 1
300 Hines Transmission Unattended 138 115 12.47 80
301 Holly Distribution Unattended 69 13.09 14
302
(q)
Hurricane Transmission Unattended 230
303 Jacobson Gulch Distribution Unattended 69 2.4 11
304 Malheur Butte Distribution Unattended 69 34.5 11
305 Nyssa Distribution Unattended 69 13 28
306 Ontario Distribution Unattended 138 13 67
307 Ontario Transmission Unattended 138 69 12.47 47
308 Ontario Transmission Unattended 230 138 13.8 400
309 Ontario Transmission Unattended 138 69 12.98 93
310 Ontario Transmission Unattended 138 69 13.09
311 Ontario Transmission Unattended 138 69 12.5
312 Ore-Ida Distribution Unattended 69 13 28
313 Oxbow Transmission Attended 138 69 13 13
314 Oxbow Transmission Attended 230 13.8 274
315 Oxbow Transmission Attended 230 138 13.8 100
316 Quartz Transmission Unattended 138 69 12.5 25
317 Quartz Transmission Unattended 230 138 12.98 167
318 Quartz Transmission Unattended 138 69 12.98 20
319
(r)
Summer Lake Transmission Unattended 500
320 Vale Distribution Unattended 69 13 14
321 Washington:
322
(s)
Walla Walla Transmission Unattended 230
323 Wyoming:
SUBSTATIONS
Character of Substation Character of Substation VOLTAGE (In MVa)VOLTAGE (In
MVa)
VOLTAGE
(In MVa)
Line
No.
Name and Location of Substation
(a)
Transmission or Distribution
(b)
Attended or Unattended
(b-1)
Primary Voltage (In
MVa)
(c)
Secondary
Voltage (In
MVa)
(d)
Tertiary
Voltage
(In MVa)
(e)
Capacity
of
Substation
(In
Service)
(In MVa)
(f)
FERC FORM NO. 1 (ED. 12-96)
Page 426-427
285 Wye Distribution Unattended 138 13.09 37286ZilogDistributionUnattended13813.09 45287The above are all State of Idaho288Montana:289 (n)Mill Creek Transmission Unattended 230290PetersonTransmissionUnattended230 69 13.2 86291Nevada:292 (o)Valmy Transmission Attended 345 18 315293WellsTransmissionUnattended138691325294Oregon:295 Adrian Distribution Unattended 69 13 11296(p)Burns Transmission Unattended 500297CairoDistributionUnattended69 13 20298Hells Canyon Transmission Attended 230 13.8 560299Hells Canyon Distribution Attended 69 0.5 1300HinesTransmissionUnattended13811512.47 80301HollyDistributionUnattended6913.09 14302(q)Hurricane Transmission Unattended 230303Jacobson Gulch Distribution Unattended 69 2.4 11304Malheur Butte Distribution Unattended 69 34.5 11305NyssaDistributionUnattended691328306OntarioDistributionUnattended1381367307OntarioTransmissionUnattended1386912.47 47308OntarioTransmissionUnattended23013813.8 400309OntarioTransmissionUnattended1386912.98 93310OntarioTransmissionUnattended1386913.09311OntarioTransmissionUnattended1386912.5312Ore-Ida Distribution Unattended 69 13 28313OxbowTransmissionAttended138691313314OxbowTransmissionAttended23013.8 274315OxbowTransmissionAttended23013813.8 100316QuartzTransmissionUnattended1386912.5 25317QuartzTransmissionUnattended23013812.98 167318QuartzTransmissionUnattended1386912.98 20319(r)Summer Lake Transmission Unattended 500320ValeDistributionUnattended69 13 14321Washington:322 (s)Walla Walla Transmission Unattended 230323Wyoming:SUBSTATIONSCharacter of Substation Character of Substation VOLTAGE (In MVa)VOLTAGE (InMVa)VOLTAGE(In MVa)LineNo.Name and Location of Substation(a)Transmission or Distribution(b)Attended or Unattended(b-1)Primary Voltage (InMVa)(c)SecondaryVoltage (InMVa)(d)TertiaryVoltage(In MVa)(e)CapacityofSubstation(InService)(In MVa)(f)FERC FORM NO. 1 (ED. 12-96)Page 426-427
324
(t)
Jim Bridger Transmission Attended 345 22 34.5 2244
325 Transformers-under 10,000
326 KVA 55 Distribution Unattended 192
327 Distribution Substations 23,013 4,053.46 19.88 7,386
328 Distribution Substations Attended 158 26.78 0 37
329 Distribution Substations Unattended 22,855 4,026.68 19.88 7,349
330 Transmission Substations 19,893 7,483.26 881.88 22,602
331 Transmission Substations Attended 4,944 905.26 88.9 6,998
332 Transmission Substations
Unattended 14,949 6,578 792.98 15,604
333 Total 29,988
FERC FORM NO. 1 (ED. 12-96)
Page 426-427
SUBSTATIONS
Character of Substation Character of Substation VOLTAGE (In MVa)VOLTAGE (In
MVa)
VOLTAGE
(In MVa)
Line
No.
Name and Location of Substation
(a)
Transmission or Distribution
(b)
Attended or Unattended
(b-1)
Primary Voltage (In
MVa)
(c)
Secondary
Voltage (In
MVa)
(d)
Tertiary
Voltage
(In MVa)
(e)
Capacity
of
Substation
(In
Service)
(In MVa)
(f)
SUBSTATIONS
Conversion Apparatus and Special Equipment Conversion Apparatus and
Special Equipment
Conversion Apparatus and
Special Equipment
Line
No.
Number of Transformers In
Service
(g)
Number of Spare
Transformers
(h)
Type of Equipment
(i)
Number of Units
(j)
Total Capacity (In MVa)
(k)
1 2
324 (t)Jim Bridger Transmission Attended 345 22 34.5 2244325Transformers-under 10,000326KVA 55 Distribution Unattended 192327Distribution Substations 23,013 4,053.46 19.88 7,386328Distribution Substations Attended 158 26.78 0 37329Distribution Substations Unattended 22,855 4,026.68 19.88 7,349330Transmission Substations 19,893 7,483.26 881.88 22,602331Transmission Substations Attended 4,944 905.26 88.9 6,998332Transmission SubstationsUnattended 14,949 6,578 792.98 15,604333Total29,988FERC FORM NO. 1 (ED. 12-96)Page 426-427SUBSTATIONSCharacter of Substation Character of Substation VOLTAGE (In MVa)VOLTAGE (InMVa)VOLTAGE(In MVa)LineNo.Name and Location of Substation(a)Transmission or Distribution(b)Attended or Unattended(b-1)Primary Voltage (InMVa)(c)SecondaryVoltage (InMVa)(d)TertiaryVoltage(In MVa)(e)CapacityofSubstation(InService)(In MVa)(f)
SUBSTATIONS
Conversion Apparatus and Special Equipment Conversion Apparatus and
Special Equipment
Conversion Apparatus and
Special Equipment
Line
No.
Number of Transformers In
Service
(g)
Number of Spare
Transformers
(h)
Type of Equipment
(i)
Number of Units
(j)
Total Capacity (In MVa)
(k)
1 2
2 2
3 1
4 1
5 1
6 1
7 1
8 1
9 1
10 1
11 1
12 1
13 1
14 1
15 1
16
17 2
18 1
19 2
20 3 1
21 1
22 3
23 2
24 2
25 1
26 3
27 2
28 1
29 3
30 3 1
31 1
32 3
33 1
34 1
35 1
36 1
37 2
38 3
39 1
40 5
41 2
42 5 1
43 1
44 1
45 1
SUBSTATIONS
Conversion Apparatus and Special Equipment Conversion Apparatus and
Special Equipment
Conversion Apparatus and
Special Equipment
Line
No.
Number of Transformers In
Service
(g)
Number of Spare
Transformers
(h)
Type of Equipment
(i)
Number of Units
(j)
Total Capacity (In MVa)
(k)
2 23141516171819110111112113114115116172181192203 121122323224225126327228129330313113233313413513613723833914054124251431441
45 1
SUBSTATIONSConversion Apparatus and Special Equipment Conversion Apparatus andSpecial Equipment Conversion Apparatus andSpecial EquipmentLineNo.Number of Transformers InService(g)Number of SpareTransformers(h)Type of Equipment(i)Number of Units(j)Total Capacity (In MVa)(k)
46 1
47 1
48 1
49 2
50 1
51 1
52 1
53 3
54 1
55 3 1
56 3 1
57 1
58 1
59 1
60 1
61 1
62 2
63 1
64 1
65 1
66 1
67 1
68 2 1
69 1
70 2
71 1
72 1
73 1
74 1
75 1
76 1
77 1
78 7
79 1
80 2
81 1
82 1
83 1
84 1
85 2
86 1
87 1
88 1
89 1
SUBSTATIONS
Conversion Apparatus and Special Equipment Conversion Apparatus and
Special Equipment
Conversion Apparatus and
Special Equipment
Line
No.
Number of Transformers In
Service
(g)
Number of Spare
Transformers
(h)
Type of Equipment
(i)
Number of Units
(j)
Total Capacity (In MVa)
(k)
46 1471481492501511521533541553156315715815916016116226316416516616716821691702711721731741751761771787791802811821831841852861871881
89 1
SUBSTATIONSConversion Apparatus and Special Equipment Conversion Apparatus andSpecial Equipment Conversion Apparatus andSpecial EquipmentLineNo.Number of Transformers InService(g)Number of SpareTransformers(h)Type of Equipment(i)Number of Units(j)Total Capacity (In MVa)(k)
90 6 1
91 1
92 6
93 2
94 1
95 1
96 2
97 2
98 2
99 1
100 1
101 1
102 1
103 1
104 1
105 1
106 1
107 1
108 1
109 1
110 1
111 2
112 1
113 1
114 1
115 2
116 1 1
117 1
118 3 1
119 1
120 1
121 1
122 1
123 2
124 1
125 2
126 1 1
127 5
128 1
129 1
130 2
131 2
132 1
133 1
SUBSTATIONS
Conversion Apparatus and Special Equipment Conversion Apparatus and
Special Equipment
Conversion Apparatus and
Special Equipment
Line
No.
Number of Transformers In
Service
(g)
Number of Spare
Transformers
(h)
Type of Equipment
(i)
Number of Units
(j)
Total Capacity (In MVa)
(k)
90 6 1911926932941951962972982991100110111021103110411051106110711081109111011112112111311141115211611117111831119112011211122112321241125212611127512811291130213121321
133 1
SUBSTATIONSConversion Apparatus and Special Equipment Conversion Apparatus andSpecial Equipment Conversion Apparatus andSpecial EquipmentLineNo.Number of Transformers InService(g)Number of SpareTransformers(h)Type of Equipment(i)Number of Units(j)Total Capacity (In MVa)(k)
134 1
135 1
136 1
137 1
138 1
139 1
140 3 1
141 1
142 1
143 1
144 2
145 1
146 2
147 1
148 1
149 1
150 1
151 1
152 1
153 3
154 2
155 1
156
157 1
158 1
159 2
160 1
161 1
162 1
163 1
164 2
165 2
166 1
167 7
168 1
169 1
170 3 1
171 1
172 1
173 1
174 1
175 1
176 1
177 1
SUBSTATIONS
Conversion Apparatus and Special Equipment Conversion Apparatus and
Special Equipment
Conversion Apparatus and
Special Equipment
Line
No.
Number of Transformers In
Service
(g)
Number of Spare
Transformers
(h)
Type of Equipment
(i)
Number of Units
(j)
Total Capacity (In MVa)
(k)
134 1135113611371138113911403 1141114211431144214511462147114811491150115111521153315421551156157115811592160116111621163116421652166116771681169117031171117211731174117511761
177 1
SUBSTATIONSConversion Apparatus and Special Equipment Conversion Apparatus andSpecial Equipment Conversion Apparatus andSpecial EquipmentLineNo.Number of Transformers InService(g)Number of SpareTransformers(h)Type of Equipment(i)Number of Units(j)Total Capacity (In MVa)(k)
178 2
179 2
180 1
181 1
182 1
183 1
184 2
185 3
186 2
187 1
188 4
189 1
190 1
191 1
192 1
193 2
194 2
195 2
196 1 1
197 2 1
198 3
199 1
200 3 1
201 3 1
202 2
203 1
204 1
205 2
206 2
207 1
208 1
209 1
210 1
211 3
212 1
213 1
214 1
215 1
216 1
217 1
218 1
219 1
220 1
221 1
SUBSTATIONS
Conversion Apparatus and Special Equipment Conversion Apparatus and
Special Equipment
Conversion Apparatus and
Special Equipment
Line
No.
Number of Transformers In
Service
(g)
Number of Spare
Transformers
(h)
Type of Equipment
(i)
Number of Units
(j)
Total Capacity (In MVa)
(k)
178 21792180 118111821183118421853186218711884189119011911192119321942195219611197211983199120031201312022203120412052206220712081209121012113212121312141215121612171218121912201
221 1
SUBSTATIONSConversion Apparatus and Special Equipment Conversion Apparatus andSpecial Equipment Conversion Apparatus andSpecial EquipmentLineNo.Number of Transformers InService(g)Number of SpareTransformers(h)Type of Equipment(i)Number of Units(j)Total Capacity (In MVa)(k)
222 1
223 3
224 2
225 1
226 1
227 2
228 1
229 1
230
231 1
232 1
233 2
234 1
235 2
236 1
237 1
238 1
239 1
240 1
241 1
242 1
243 1
244 2
245 1
246 2
247 1
248 1
249 1
250 1
251 1
252 1
253 2
254 2
255 1
256 3
257 2
258 1
259 1
260 1
261 2
262 1
263 2
264 1
265
SUBSTATIONS
Conversion Apparatus and Special Equipment Conversion Apparatus and
Special Equipment
Conversion Apparatus and
Special Equipment
Line
No.
Number of Transformers In
Service
(g)
Number of Spare
Transformers
(h)
Type of Equipment
(i)
Number of Units
(j)
Total Capacity (In MVa)
(k)
FERC FORM NO. 1 (ED. 12-96)
222 122332242225122612272228122912302311232 123322341235223612371238123912401241124212431244224512462247124812491250125112521253225422551256325722581259126012612262126322641
265
SUBSTATIONSConversion Apparatus and Special Equipment Conversion Apparatus andSpecial Equipment Conversion Apparatus andSpecial EquipmentLineNo.Number of Transformers InService(g)Number of SpareTransformers(h)Type of Equipment(i)Number of Units(j)Total Capacity (In MVa)(k)
FERC FORM NO. 1 (ED. 12-96)266 1
267 2
268 2
269 1
270 1
271 1
272 1
273 4
274 2
275 1
276 1
277 1
278 1 1
279 2
280 1
281 1
282 1
283 1
284 2
285 1
286 1
287
288
289
290 2
291
292 1
293 3 1
294
295 1
296
297 1
298 3
299 1
300 1 1
301 1
302
303 1
304 3 1
305 2
306 2 1
307 1
308 2
309 2
SUBSTATIONS
Conversion Apparatus and Special Equipment Conversion Apparatus and
Special Equipment
Conversion Apparatus and
Special Equipment
Line
No.
Number of Transformers In
Service
(g)
Number of Spare
Transformers
(h)
Type of Equipment
(i)
Number of Units
(j)
Total Capacity (In MVa)
(k)
FERC FORM NO. 1 (ED. 12-96)
266 1267226822691270127112721273427422751276127712781 1279228012811282128312842285128612872882892902291292129331294295129629712983299130011301130230313043130523062130713082
309 2
SUBSTATIONSConversion Apparatus and Special Equipment Conversion Apparatus andSpecial Equipment Conversion Apparatus andSpecial EquipmentLineNo.Number of Transformers InService(g)Number of SpareTransformers(h)Type of Equipment(i)Number of Units(j)Total Capacity (In MVa)(k)
FERC FORM NO. 1 (ED. 12-96)310 1
311 1
312 1
313 3 1
314 2
315 1
316 1
317 3 1
318 1
319
320 1
321
322
323
324 4
325
326
327 280 30 0 0
328 5 0 0 0
329 275 30 0 0
330 156 25 0 0
331 54 3 0 0
332 102 22 0 0
333
FERC FORM NO. 1 (ED. 12-96)
Page 426-427
SUBSTATIONS
Conversion Apparatus and Special Equipment Conversion Apparatus and
Special Equipment
Conversion Apparatus and
Special Equipment
Line
No.
Number of Transformers In
Service
(g)
Number of Spare
Transformers
(h)
Type of Equipment
(i)
Number of Units
(j)
Total Capacity (In MVa)
(k)
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original
(2) ☐ A Resubmission
Date of Report:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
FOOTNOTE DATA
(a) Concept: SubstationNameAndLocation
310 131113121313313142315131613173131813193201321322323324432532632728030 0 0328500032927530003301562500331543003321022200333FERC FORM NO. 1 (ED. 12-96)Page 426-427SUBSTATIONSConversion Apparatus and Special Equipment Conversion Apparatus andSpecial Equipment Conversion Apparatus andSpecial EquipmentLineNo.Number of Transformers InService(g)Number of SpareTransformers(h)Type of Equipment(i)Number of Units(j)Total Capacity (In MVa)(k)
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original
(2) ☐ A Resubmission
Date of Report:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
FOOTNOTE DATA
(a) Concept: SubstationNameAndLocation
PacifiCorp has an ownership interest in certain high-voltage transmission related and interconnection equipment located at Idaho Power's Adelaide station. Ownership interest varies by
terminal. 100% of the capacity is reported.
(b) Concept: SubstationNameAndLocation
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 is reported.
(c) Concept: SubstationNameAndLocation
Jointly owned with PacifiCorp, Idaho Power has 66.7% share of ownership. 100% of the capacity is reported.
(d) Concept: SubstationNameAndLocation
Jointly owned with PacifiCorp, Idaho Power has 66.7% share of ownership. 100% of the capacity is reported.
(e) Concept: SubstationNameAndLocation
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.
(f) Concept: SubstationNameAndLocation
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.
(g) Concept: SubstationNameAndLocation
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 is reported.
(h) Concept: SubstationNameAndLocation
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.
(i) Concept: SubstationNameAndLocation
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.
(j) Concept: SubstationNameAndLocation
PacifiCorp has an ownership interest in certain high-voltage transmission related and interconnection equipment located at Idaho Power's Kinport station. Ownership interest varies by
terminal. 100% of the capacity is reported.
(k) Concept: SubstationNameAndLocation
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.
(l) Concept: SubstationNameAndLocation
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.
(m) Concept: SubstationNameAndLocation
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.
(n) Concept: SubstationNameAndLocation
Idaho Power has 32% ownership in certain transmission related equipment located at Northwestern Energy's Mill Creek Station.
(o) Concept: SubstationNameAndLocation
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.
(p) Concept: SubstationNameAndLocation
Idaho Power has a 22% ownership interest in certain high-voltage transmission related and interconnection equipment located at PacifiCorp's Burns station.
(q) Concept: SubstationNameAndLocation
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.
(r) Concept: SubstationNameAndLocation
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.
(s) Concept: SubstationNameAndLocation
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.
(t) Concept: SubstationNameAndLocation
Jointly owned with PacifiCorp. Idaho Power has a 33.3% share of ownership. 100% of the capacity is reported.
(u) Concept: PrimaryVoltageLevel
For all of column c: Primary voltages reported in KV unless otherwise noted.
(v) Concept: SecondaryVoltageLevel
For all of column d: Secondary voltages reported in KV unless otherwise noted.
(w) Concept: TertiaryVoltageLevel
For all of column e: Tertiary voltages reported in KV unless otherwise noted.
(x) Concept: SubstationInServiceCapacity
For all of column f: Top rating capacity reported unless otherwise noted.
FERC FORM NO. 1 (ED. 12-96)
Page 426-427
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original
(2) ☐ A Resubmission
Date of Report:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
TRANSACTIONS WITH ASSOCIATED (AFFILIATED) COMPANIES
Line
No.
Description of the Good or Service
(a)
Name of Associated/Affiliated Company
(b)
Account(s) Charged
or Credited
(c)
Amount Charged or Credited
(d)
FERC FORM NO. 1 ((NEW))
Page 429
PacifiCorp has an ownership interest in certain high-voltage transmission related and interconnection equipment located at Idaho Power's Adelaide station. Ownership interest varies byterminal. 100% of the capacity is reported.(b) Concept: SubstationNameAndLocationIdaho Power has an ownership interest in certain high-voltage transmission related and interconnection equipment located at PacifiCorp's Antelope station. Ownership interest varies byterminal. 100% of the capacity is reported.(c) Concept: SubstationNameAndLocationJointly owned with PacifiCorp, Idaho Power has 66.7% share of ownership. 100% of the capacity is reported.(d) Concept: SubstationNameAndLocationJointly owned with PacifiCorp, Idaho Power has 66.7% share of ownership. 100% of the capacity is reported.(e) Concept: SubstationNameAndLocationIdaho Power has an ownership interest in certain high-voltage transmission related and interconnection equipment located at PacifiCorp's Big Grassy station. Ownership interest varies byterminal.(f) Concept: SubstationNameAndLocationPacifiCorp has an ownership interest in certain high-voltage transmission related and interconnection equipment located at Idaho Power's Borah station. Ownership interest varies byterminal. 100% of the capacity is reported.(g) Concept: SubstationNameAndLocationIdaho Power has an ownership interest in certain high-voltage transmission related and interconnection equipment located at PacifiCorp's Goshen station. Ownership interest varies byterminal. 100% of the capacity is reported.(h) Concept: SubstationNameAndLocationPacifiCorp has an ownership interest in certain high-voltage transmission related and interconnection equipment located at Idaho Power's Hemingway station. Ownership interest varies byterminal. 100% of the capacity is reported.(i) Concept: SubstationNameAndLocationIdaho Power has an ownership interest in certain high-voltage transmission related and interconnection equipment located at PacifiCorp's Jefferson station. Ownership interest varies byterminal.(j) Concept: SubstationNameAndLocationPacifiCorp has an ownership interest in certain high-voltage transmission related and interconnection equipment located at Idaho Power's Kinport station. Ownership interest varies byterminal. 100% of the capacity is reported.(k) Concept: SubstationNameAndLocationPacifiCorp has an ownership interest in certain high-voltage transmission related and interconnection equipment located at Idaho Power's Midpoint station. Ownership interest varies byterminal. 100% of the capacity is reported.(l) Concept: SubstationNameAndLocationIdaho Power has an ownership interest in certain high-voltage transmission related and interconnection equipment located at PacifiCorp's Populus station. Ownership interest varies byterminal.(m) Concept: SubstationNameAndLocationIdaho Power has an ownership interest in certain high-voltage transmission related and interconnection equipment located at PacifiCorp's Three Mile Knoll station. Ownership interest variesby terminal.(n) Concept: SubstationNameAndLocationIdaho Power has 32% ownership in certain transmission related equipment located at Northwestern Energy's Mill Creek Station.(o) Concept: SubstationNameAndLocationJointly owned with Sierra Pacific Power Company, d/b/a NV Energy. Idaho Power has a 50% share of ownership. 100% of the capacity reported.(p) Concept: SubstationNameAndLocationIdaho Power has a 22% ownership interest in certain high-voltage transmission related and interconnection equipment located at PacifiCorp's Burns station.(q) Concept: SubstationNameAndLocationIdaho Power has an ownership interest in certain high-voltage transmission related and interconnection equipment located at PacifiCorp's Hurricane station. Ownership interest varies byterminal.(r) Concept: SubstationNameAndLocationIdaho Power has an ownership interest in certain high-voltage transmission related and interconnection equipment located at PacifiCorp's Summer Lake station. Ownership interest varies byterminal.(s) Concept: SubstationNameAndLocationIdaho Power has an ownership interest in certain high-voltage transmission related and interconnection equipment located at PacifiCorp's Walla Walla station. Ownership interest varies byterminal.(t) Concept: SubstationNameAndLocationJointly owned with PacifiCorp. Idaho Power has a 33.3% share of ownership. 100% of the capacity is reported.(u) Concept: PrimaryVoltageLevelFor all of column c: Primary voltages reported in KV unless otherwise noted.(v) Concept: SecondaryVoltageLevelFor all of column d: Secondary voltages reported in KV unless otherwise noted.(w) Concept: TertiaryVoltageLevelFor all of column e: Tertiary voltages reported in KV unless otherwise noted.(x) Concept: SubstationInServiceCapacityFor all of column f: Top rating capacity reported unless otherwise noted.FERC FORM NO. 1 (ED. 12-96)
Page 426-427
Name of Respondent:
Idaho Power Company
This report is:
(1) ☑ An Original
(2) ☐ A Resubmission
Date of Report:
04/16/2024
Year/Period of Report
End of: 2023/ Q4
TRANSACTIONS WITH ASSOCIATED (AFFILIATED) COMPANIES
Line
No.
Description of the Good or Service
(a)
Name of Associated/Affiliated Company
(b)
Account(s) Charged
or Credited
(c)
Amount Charged or Credited
(d)
FERC FORM NO. 1 ((NEW))
Page 429
(c)
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 Affiliated
21 Managerial Expenses 417420 IDACORP, INC.417420 568,431
22 Managerial Expenses 922000 IDACORP, INC.922000 32,742
42
FERC FORM NO. 1 ((NEW))
Page 429