20250623Compliance Filing.pdf

®IQAHO Re
RECEIVED
GRANT ANDERSON June 23, 2025
Pricing and Tariff Administration Leader IDAHO PUBLIC
ganderson(a)idahopower.com UTILITIES COMMISSION
June 23, 2025
Commission Secretary
Idaho Public Utilities Commission
11331 W. Chinden Boulevard
Building 8, Suite 201-A
Boise, Idaho 83714
Re: Case No. IPC-E-24-42
Idaho Power Company's Application for Approval of a Power Purchase
Agreement with Blacks Creek Energy Center, LLC
Dear Commission Secretary:
Attached for electronic filing is Idaho Power Company's Compliance Filing in the
above-entitled matter. If you have any questions about the attached documents, please
do not hesitate to contact me.
Sincerely,
I? / 4"rL
Grant Anderson
GA:cd
Attachments
1221 W. Idaho St(83702)
P.O.Box 70
Boise, ID 83707

DONOVAN E. WALKER (ISB No. 5921)
Idaho Power Company
1221 West Idaho Street (83702)
P.O. Box 70
Boise, Idaho 83707
Telephone: [phone]
Facsimile: [phone]
dwalker(a-)_idahopower.com
Attorneys for Idaho Power Company
BEFORE THE IDAHO PUBLIC UTILITIES COMMISSION
IN THE MATTER OF IDAHO POWER )
COMPANY'S APPLICATION FOR ) CASE NO. IPC-E-24-42
APPROVAL OF A POWER PURCHASE )
AGREEMENT WITH BLACKS CREEK ) IDAHO POWER COMPANY'S
ENERGY CENTER, LLC. ) COMPLIANCE FILING
Idaho Power Company ("Idaho Power" or "Company"), pursuant to Idaho Public
Utilities Commission ("Commission") Order No. 36572,' hereby respectfully submits the
following compliance filing which contains the structure for calculating Brisbie LLC's
("Brisbie") Renewable Capacity Credit ("RCC") under the Brisbie Special Contract
("Brisbie ESA") related to the Power Purchase Agreement ("PPA") between Idaho Power
and Blacks Creek Energy Center, LLC ("Blacks Creek").
I. INTRODUCTION
In its final order approving the Blacks Creek PPA the Commission directed the
Company to work with Staff on the structure for calculating Brisbie's RCC under the
Order No. 36572, p. 3.
IDAHO POWER COMPANY'S COMPLIANCE FILING - 1

Special Contract and directed the Company to submit a compliance filing with the
proposed RCC and associated updates to Schedule 33 within 60 days of the order.2 As
more fully described herein, in this compliance filing, Idaho Power presents the
Commission with an updated proposed RCC payment structure, which resulted from
discussions with Commission Staff("Staff"). More specifically, following the Commission's
issuance of Order No. 36572, Idaho Power met with Staff to discuss the following Staff
recommendations3 related to the quantification of Brisbie's RCC4:
o The Company update the Effective Load Carrying Capacity ("ELCC") by using the
most recent load and contracted resource data as of the contract execution date
of October 11, 2024 ("Recommendation 2");
o The Company include additional load and resource adjustments to reflect near-
term trends in the Final Study when informing the monthly distribution of the annual
payment ("Recommendation 3");
o The Company create "seasons" based on the 2028 Loss of Load Probability
("LOLP") profiles determined in the Final Study ("Recommendation 4");
o The Company identify high-risk hours based on the 2028 LOLP profiles determined
in the Final Study, with no expansion of risk-hours ("Recommendation 5"); and
o The Company establish the relationship between Performance Ratio and ELCC
based on the Final Study ("Recommendation 6"). Additionally, use increments of
2 Id., page 3.
3 Staff Comments, page 2 (February 27, 2025).
4 Note, Staff's Recommendation 1 ("the parties modify the definition of Market Price Index and how it is
determined to avoid potential impacts of Washington's Climate Commitment Act ("CCA") on Idaho
ratepayers," Staff Comments, page 1 (February 27, 2025))was previously addressed and resolved
through Order No. 36572.
IDAHO POWER COMPANY'S COMPLIANCE FILING -2

0.05 of Performance Ratio to create data points ("Recommendation 6a"); and use
a method of the best-fit linear equation with constraints of 100% of the original
ELCC at Performance Ratio of 1.0 ("Recommendation 6b").
Following two meetings (May 19, 2025, and May 28, 2025), Idaho Power and Staff
were able to resolve Staff's concerns either through clarification of Idaho Power's
proposed method or by incorporating improvements suggested by Staff.
II. PROPOSED RENEWABLE CAPACITY CREDIT PAYMENT
Included as Attachment 1 is a detailed description of the methodology for
Company's proposed RCC and the performance mechanism for monthly payments. The
proposed RCC follows the same general methodology approved by the Commission in
Order Nos. 35735,5 35777,E 35958,' and 36270,$ while incorporating certain adjustments
resulting from recent discussions with Staff necessary to ensure the payment for capacity
of the renewable project is commensurate with the benefits provided to the system. The
maximum value Brisbie is eligible to be paid for capacity delivered by the Blacks Creek
project is capped at $8,172,640. The Company addresses each of Staff's
recommendations and the resolution of each issue in the comments that follow.
5 In the Matter of Idaho Power Company's Application for Approval of a Replacement Special Contract
with Micron Technology, Inc., and a Power Purchase Agreement with Black Mesa Energy, LLC, Case No.
IPC-E-22-06, order issued April 12, 2023.
6 In the Matter of Idaho Power Company's Application for Approval of a Special Contract and Tariff
Schedule 33 to Provide Electric Service to Brisbie, LLC's Data Center Facility, Case No. IPC-E-21-42,
May 11, 2023.
Id., order issued October 12, 2023.
8 In the Matter of Idaho Power Company's Application for Approval of a Power Purchase Agreement with
PVS 2, LLC, Case No. IPC-E-24-01, July 26, 2024.
IDAHO POWER COMPANY'S COMPLIANCE FILING - 3

A. Recommendation 2 — Update to ELCC
Staff recommended the Company update the ELCC by using the most recent load
and contracted resource data as of the contract execution date of October 11 , 2024. As
noted by Staff in comments, the Company had inadvertently included a 50 megawatts
storage facility in the quantification of the ELCC that was not yet under contract by the
Company, which is inconsistent with the Commission approved methodology and the
Company's intent. Accordingly, the Company has updated the ELCC to only include
resources that were under contract at the time the Blacks Creek PPA was executed,
which results in an ELCC of 17.50 percent, rather than the 18.44 percent included with
the Company's original filing.
B. Recommendation 3 — Load & Resource ("L&R") Adjustments
Staff recommended the Company include additional L&R adjustments to reflect
near-term trends when informing the monthly distribution of the annual payment. In its
initial filing, the Company had included the expected L&R adjustments known at the time
of that filing. After discussions with Staff, the Company adjusted the 2028 monthly Loss
of Load Expectation ("LOLE")weighted averages to consider most-recently available data
(including an updated load forecast and generation projects that were contracted after
Blacks Creek) which better reflects the expected LOLE distribution of future years. These
modifications are reflected in Table 2 of Attachment 1.
C. Recommendation 4 — Adjustment to Seasons Based on LOLP
Staff recommended the Company create "seasons" based on the 2028 LOLP
profiles. In its initial filing, the Company had relied on the methodology developed in Case
No. IPC-E-22-06 when establishing the RCC of Clean Energy Your Way ("CEYW")
IDAHO POWER COMPANY'S COMPLIANCE FILING -4

projects to group the twelve calendar months into three different periods. After
discussions with Staff, the Company made an adjustment to apply the seasons of highest
risk methodology from the 2023 Integrated Resource Plan ("IRP") to the 2028 L&R year
to group the twelve months of the calendar year into three different periods given their
LOLP profiles. These modifications are reflected in Table 3 of Attachment 1.
D. Recommendation 5 — Performance Metric, High-Risk Hours
Staff recommended the Company identify high-risk hours based on the 2028 LOLP
profiles, with no expansion of risk-hours. After discussions with Staff, the Company and
Staff aligned on applying the most recently acknowledged IRP hours of highest risk
methodology to the project online year. More specifically, Idaho Power's proposed high-
risk hours for the Blacks Creek project performance metric rely on the same thresholds
from the 2023 IRP but are applied to the 2028 L&R year. The identified summer risk hours
using the 2023 IRP methodology applied to the 2028 L&R year are 5pm through 12am.
In recognition that the hours of highest risk analysis do not capture 100 percent of risk
hours, the 4pm through 5pm hour is included to capture expanded risk hours when solar
generation is available, which is done to reduce the solar generation measurement
variability. The identified winter risk hours using the 2023 IRP methodology applied to the
2028 L&R year are 6am through 3pm and 5pm through 10pm.
E. Recommendations 6, 6a, and 6b — Performance Ratio
Staff recommended: (1) the Company establish the relationship between
Performance Ratio and ELCC, (2) use increments of 0.05 of Performance Ratio to create
data points, and (3) use a method of the best-fit linear equation with constraints of 100%
of the original ELCC at Performance Ratio of 1.0. Through discussions with Staff, the
IDAHO POWER COMPANY'S COMPLIANCE FILING - 5

Company and Staff aligned that Idaho Power would rely on its filed method but include
additional data points. That is, the ELCC will be based on the execution date of the Blacks
Creek PPA and the data points would be created based on the 0.05 increments suggested
by Staff, essentially ensuring the data points will reflect what we knew at the time of
contract execution. For the interpolation method applied to the Performance Ratio and
ELCC relationship, the Company and Staff also aligned on continuing to utilize the initially
filed method of interpolating between the two closest data points.
III. CONCLUSION
Idaho Power is appreciative of Staff's collaboration in working through the issues
identified in Staff's comments. The proposed RCC and performance structure presented
in Attachment 1 represents resolution of Staff's identified concerns. Idaho Power believes
the proposed RCC and related performance mechanism not only meets the
Commission's prior orders, but includes minor adjustments necessary to ensure the
unique impacts of each renewable resource is captured, including those added in the
same year as other CEYW resources. The ability to incentivize performance to meet
today's system capacity needs, while ensuring the resource performs as expected in the
future, provides recognition of Idaho Power's reliance on that resource's capacity
contribution.
To assist Staff in its review, Idaho Power has also provided a draft Schedule 33 as
Attachment 2, which reflects the adjustments more fully described herein and throughout
Attachment 1. Idaho Power respectfully requests the Commission issue an order (1)
approving the proposed RCC, and (2) directing Idaho Power to file conforming tariff
sheets.
IDAHO POWER COMPANY'S COMPLIANCE FILING - 6

Respectfully submitted this 23rd day of June 2025.
DONOVAN WALKER
Attorney for Idaho Power Company
IDAHO POWER COMPANY'S COMPLIANCE FILING - 7

CERTIFICATE OF SERVICE
I HEREBY CERTIFY that on the 23rd day of June 2025, 1 served a true and correct
copy of Idaho Power Company's Compliance Filing upon the following named parties by
the method indicated below, and addressed to the following:
Commission Staff Hand Delivered
Chris Burdin U.S. Mail
Deputy Attorney General Overnight Mail
Idaho Public Utilities Commission FAX
11331 W. Chinden Blvd., Bldg No. 8 FTP Site
Suite 201-A (83714) X Email Chris.Burdin(a)_puc.idaho.gov
PO Box 83720
Boise, ID 83720-0074
Christy Davenport
Legal Administrative Assistant
IDAHO POWER COMPANY'S COMPLIANCE FILING - 8

BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-24-42
IDAHO POWER COMPANY
ATTACHMENT 1

Case No. IPC-E-24-42 - Proposed Brisbie, LLC Renewable
Capacity Credit Payment Structure for Blacks Creek
The Blacks Creek Power Purchase Agreement ("PPA") was executed on October
11, 2024, and the capacity contribution calculated at the time of contract execution was
17.50%. The annual payment is determined by multiplying the average capacity
contribution by the avoided cost of capacity. The avoided cost of capacity is the levelized
fixed cost associated with the least-cost dispatchable resource from the Company's most
recently acknowledged Integrated Resource Plan ("IRP") at the time of PPA execution. In
the case of Blacks Creek, the 2023 IRP was the most recently acknowledged IRP at the
time of PPA execution. For the 2023 IRP the identified resource was a simple-cycle
combustion turbine ("SCCT") with a levelized capacity cost of$145.94 per kW per year.
Determine Annual Payment
The annual payment is calculated by multiplying the capacity contribution by the
nameplate of the selected project by the avoided cost of capacity:
Annual Payment = Capacity Contribution* Project Nameplate *Avoided Cost of Capacity
Applying the annual payment calculation to the Blacks Creek project, the resulting
value is determined to be $8,172,640 per year:
Annual Payment = 17.50% * 320,000 kW * $145.94
y � � � � kW • yr $8,172,640/yr
Determine Months of Capacity Need
The annual payment will be calculated at the time of contract execution and
distributed proportionally over the months that capacity is expected to be needed. To
determine the months of capacity need, the Loss of Load Expectation ("LOLE") per month

of the different historical years would be used to calculate an average LOLE for each
month. If a significant resource stack change is expected in the near future, an adjusted
case would be used to guide the monthly weighted average calculations. Because the
Blacks Creek Energy Center project is contracted to come online in December 2027, a
2028 Load & Resource ("L&R") year was used to determine the months of capacity need.
The average monthly LOLE values for the 2028 L&R year are listed in Table 1 .
Table 1. 2028 L&R Average Monthly LOLE
Month Average LOLE
January 0.001856
February 0.000176
March 0.000006
April 0.000000
May 0.000000
June 0.013046
July 0.025399
August 0.003066
September 0.000297
October 0.000301
November 0.037979
December 0.017552
In review of the projected near-term load and resource buildout, Idaho Power
adjusted the 2028 monthly LOLE weighted averages to better reflect the expected LOLE
distribution of future years and to consider most-recently available data (including an
updated load forecast and generation projects that were contracted after Blacks Creek).
Using the results from the adjusted 2028 L&R year analysis, the monthly LOLE weighted
averages are listed in Table 2.

Table 2. 2028 Monthly LOLE Weighted Average
Month Weighted Average
January 3.33%
February 0.19%
March 0.02%
April -
May -
June 19.95%
July 50.32%
August 8.04%
September 0.30%
October 3.65%
November 12.13%
December 2.06%
The Company applied the seasons of highest risk methodology from the 2023 IRP
to the 2028 L&R year in order to group the twelve months of the calendar year into three
different periods given their Loss of Load Probability ("LOLP") profiles, as described in
the list below:
• Summer: June, July, August, and September
• Winter: January, February, October, November, and December
• Off-Season: March
Note that April and May remain at 0% LOLP. A weighted average per period is
calculated by adding the percentages of each month within the corresponding period
together, as shown in Table 3.

Table 3. 2028 LOLE Weighted Average per Period
Summer Winter Off-Season
June 19.95% January 3.33% March 0.02%
July 50.32% February 0.19%
August 8.04% October 3.65%
September 0.30% November 12.13%
December 2.06%
Summer Total --79% Winter Total -21% Off-Season Total _0%
For the winter and off-season periods, the total is spread out relatively equally over
the months; this means the approximate 21% for the winter total would be divided by the
5 months for a resulting 4.2% in each month, and because the off-season total rounds to
an approximate 0%, the month of March will receive no payment.
For the summer period, the hours of need typically span from the last 2 weeks of
June through the first 2 weeks of September (totaling 12 weeks), meaning there are 2
weeks in June, 4 weeks in July, 4 weeks in August, and 2 weeks in September that should
be considered in the monthly payment distribution. Because the summer total is set to
equal the approximate 79%, the high LOLP hours weekly weighting can be used to
distribute the summer period risk:
• June - 79% * 2 weeks = 13.17%
12 weeks
• July - 79% * 4 weeks 1 = 26.33%
(12 weeks
• August - 79% * (12 4 weeks weeks) = 26.33%
• September - 79% * (12 weeks)
= 13.17%
The final weights by month are shown in Table 4.

Table 4. 2028 Seasonal Monthly LOLE Weighted Average
Month Weighted Average
January 4.20%
February 4.20%
March -
April May -
June 13.17%
July 26.33%
August 26.33%
September 13.17%
October 4.20%
November 4.20%
December 4.20%
The monthly payment is calculated by taking the previously calculated annual
payment of $8,172,640 per year and multiplying it by the weighted average for each
month, as shown in Table 5.

Table 5. 2028 Seasonal Monthly Payment
Month Weighted Average Monthly Payment
January 4.20% $343,251
February 4.20% $343,251
March - -
April -May - -
June 13.17% $1,076,064
July 26.33% $2,152,129
August 26.33% $2,152,129
September 13.17% $1,076,064
October 4.20% $343,251
November 4.20% $343,251
December 4.20% $343,251
Total 100.00% $8,172,640
Performance Metric
The Performance Ratio ("PR") is a metric widely used to track performance of
photovoltaic ("PV") systems in the industry.1,2,3 The PR metric can be used to ensure a
project is being well maintained and is performing as expected. PR can be defined as the
ratio of measured output to the expected output for a given reporting period based on the
system nameplate rating. Traditionally, PR is mathematically expressed as
kW haC
kWoc,sTC
PR kW hsun
M2
1 kW
m2
where
IEC 61724-1: 2017 Photovoltaic System Performance
2 Performance of Photovoltaic Systems Recorded by oSPARC, NREL 2020
3 PV System Performance Assessment, Sunspec Alliance, San Jose State University, 2014

kWhAc = Energy Generated by the Plant
kWDc,STc = Rated Direct Current Power of the Plant at Standard Test Conditions
kWhsun = Plane of Array ("POA") Irradiance
The PR metric is most often used by power plant operators to track plant
performance. Idaho Power modifies the previously shown equation to consider the
contracted nameplate of the plant on the Alternating Current ("AC") side and not on the
Direct Current ("DC") side. The contract with Idaho Power is on the AC side and it has the
potential to be the limiting factor during operation. The modification results in the following
PR equation:
kW hac
PR = kWNP,Ac * kW hsun
One of the interconnection requirements is for the project to provide Idaho Power
with weather data via Supervisory Control and Data Acquisition ("SCADA"). One of the
variables required is the Plane of Array ("PDX) irradiance (kWhsun)• The energy injected
into the system is also measured via SCADA, making the PR calculation relatively
straight-forward.
Performance Ratio Target
The PR metric is directly impacted by the energy output which is proportional to
irradiance and inversely proportional to module temperature. The PR equation accounts
for irradiation; changes in irradiation will have little effect on the PR. However, changes
in temperature are not accounted for in the PR calculation and the PR will decrease as
temperature increases. To account for the impact of temperature on the PR calculation,

Idaho Power proposes to set a different PR target for the summer months than the non-
summer months. The Company proposes to use the PR targets described in Table 7 and
graphically displayed in Figure 1.
Table 7. PR Targets by Period
Period Target
January through May PR > 1.0
June through September PR > 0.95
October through December PR > 1.0
Performance Metric Threshold by Month
1
v
0
„ 0.9
r
0
1-- 0.8
m
oc
0
U
C
C
C 7
O
N
a 0.6
0.5 -
2 4 6 8 10 12
Month of the Year
Figure 1. PR Targets by Month
Hours of Need
Capacity is primarily avoided during certain hours of the calendar year. The hours
where capacity is most needed are the hours which have high LOLP values. To provide
compensation for capacity when it is needed, the PR metric will be calculated based on
the 2023 IRP hours of highest risk methodology applied to the 2028 L&R year, which are
provided in Table 8.

Table 8. 2028 L&R Year High LOLP Hours
Period Identified High LOLP Hours for 2028 L&R Year
Summer4 4:00 pm - 12:00 am
Winter 6:00 am - 3:00 pm & 5:00 pm - 10:00 pm
For clarification, the hours presented in Table 8 are Hour Beginning ("HB") for the
first interval and Hour Ending for the second interval ("HE"). Using the summer period
as an example, 4:00 pm HB represents the hour spanning from 4:00 pm to 5:00 pm
while 12:00 am HE represents the hour spanning from 11:00 pm to 12:00 am; this
means the identified summer period high LOLP hours begin at 4:00 pm and conclude at
12:00 am.
Reduction on Payment
To receive the full monthly payment, the project will have to meet the PR threshold
in the corresponding high LOLP hours (as set forth in Table 8). If the PR is not met, a
reduction in payment will be applied to the project. The reduction will be calculated based
on the impact to capacity as measured by the ELCC. The impact on capacity will be
determined by reducing the output of the project and calculating its ELCC. For the Blacks
Creek Energy Center project, the relationship between output and ELCC reduction was
calculated over the range of 0.5 PR to 1.0 PR, as shown in Figure 2.
4 Identified Summer risk hours using the 2023 IRP methodology applied to the 2028 L&R year are 5:00
pm - 12:00 am. In acknowledgement that the hours of highest risk analysis does not capture 100% of risk
hours and due to the limited solar PV generation possible in the 5:00 pm to 12:00 am window in certain
months of the Summer period, the 4:00 pm - 5:00 pm hour is included to capture risk hours when solar
generation is available and reduce the solar generation measurement variability. For LOLP hours outside
of solar PV generation hours, the expectation of solar PV generation based on irradiance at the site is
zero.

Performance Ratio versus ELCC
100% •
•
•
U 90% •
w •
c •
Eb
80% •
.L
O •
4--
0 70% •
v
t •
M
+-
u 60%
v
a
50%
0.50 0.55 0.60 0.65 0.70 0.75 0.80 0.85 0.90 0.95 1.00
Pv Output
Figure 2. Relationship Between PR & ELCC
The results shown in Figure 2 will be used to determine the monthly payment
reduction if the project did not meet the monthly PR target. If any month where capacity
payments are applied do not meet the corresponding target PR, a reduction as presented
in Figure 2 would be applied (the reduction is calculated by interpolating between the
monthly PR value and the target PR value for that month). As an example of how the PR
versus ELCC approach would be implemented, data for a similar project near the Blacks
Creek Energy Center site was collected for the 2023 L&R; the PRs were then calculated
for the corresponding high LOLP hours of each month with the results shown in Table 9
(bolded values represent calculated PR values that did not meet the targets identified in
Table 7).

Table 9. Monthly Performance Ratio & Payment Example
Month Performance Ratio Payment Reduction Monthly Payment
January 1.42 0.00% $343,251
February 1.11 0.00% $343,251
March - - -
April - - -
May -
June 0.83 7.70% $993,207
July 1.01 0.00% $2,152,129
August 0.97 0.00% $2,152,129
September 1.08 0.00% $1,076,064
October 0.95 3.32% $331,855
November 1.04 0.00% $343,251
December 1.15 0.00% $343,251
Total $8,078,387

BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-24-42
IDAHO POWER COMPANY
ATTACHMENT 2

Idaho Power Company Third Revised Sheet No. 33-4
Cancels
I.P.U.C. No. 30, Tariff No. 101 Second Revised Sheet No. 33-4
SCHEDULE 33
IDAHO POWER COMPANY
ELECTRIC SERVICE RATE
FOR
BRISBIE, LLC.
(Continued)
Renewable Resource Agreements
Calculation of the Monthly Unadjusted Renewable Capacity Credit for each Project is quantified in the
tables below. The Monthly Adjusted Renewable Capacity Credit will be provided to Brisbie, LLC
monthly, starting the month of the Project's Renewable Capacity Credit Eligibility Date (as defined in
Table 3) or the month following the respective Project's commercial operation date, whichever is later,
and will remain in effect for the duration of the term of the Renewable Resource PPA or the period of
time during which the Idaho Power-owned Renewable Resource will provide Project Output to Brisbie,
LLC as applicable. The Monthly Adjusted Renewable Capacity Credit will be provided in accordance
with Second Revised Exhibit 3.1 of Brisbie, LLC's Special Contract, dated December 22, 2021, as
amended.
TABLE 1: RENEWABLE CAPACITY CREDIT
a b c d e f
Project Most Recently Project Capacity Renewable Renewable Renewable Annual
Acknowledged Nameplate Contribution Capacity Capacity Capacity Renewable
IRP (kW AC) Factor Contribution Credit Rate Credit Capacity
(a * b) ($/kW-yr) Adjustment Credit`
c*d*e
Pleasant 2019 200,000 0.3121 62,420 $121.19 1.0 $7,564,680
Valley
Solar
LLC
Pleasant 2021 125,000 0.3154 39,425 $131.60 1.0 $5,188,330
Valley
Solar 2
LLC
Blacks 2023 320,000 0.1750 56,000 $145.94 1.0 $8,172,640
Creek
Energy
Center,
LLC
*Table 2 denotes the Monthly Unadjusted Renewable Capacity Credit.
'Table 3 denotes each project's date of eligibility for the Annual Renewable Capacity Credit.
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective — 1221 West Idaho Street, Boise, Idaho

Idaho Power Company First Revised Sheet No. 33-5
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 33-5
SCHEDULE 33
IDAHO POWER COMPANY
ELECTRIC SERVICE RATE
FOR
BRISBIE, LLC.
(Continued)
Renewable Resource Agreements
(Continued)
TABLE 2: MONTHLY UNADJUSTED RENEWABLE CAPACITY CREDIT BY MONTH
Project Jan Feb Mar June July Aug Sept Oct Nov Dec
Pleasant $416,057 $416,057 -- $1,380,554 $2,761,108 $1,380,554 $189,117 $189,117 $416,057 $416,057
Valley Solar
LLC'
Pleasant $324,271 $324,271 $17,294 $959,841 $1,919,682 $959,841 $17,294 $17,294 $324,271 $324,271
Valley Solar 2
LLC2
Blacks Creek $343,251 $343,251 -- $1,076,064 $2,152,129 $2,152,129 $1,076,064 $343,251 $343,251 $343,251
Energy
enter, LLC3
TABLE 3: ELIGIBILITY DATE FOR RENEWABLE CAPACITY CREDIT
Project PPA Execution Date Capacity Deficiency Year Renewable Capacity Credit Eligibility Date
leasant 10/27/2022 2023 6/1/2023
Valley Solar
LC
leasant 12/5/2023 2023 6/1/2023
alley Solar 2
LC
lacks Creek 10/11/2024 2026 6/1/2026
nergy Center
LC
Amounts to be adjusted by the Performance Ratio Adjustment Factor,which is calculated pursuant to the methodology
detailed in Case No. IPC-E-21-42,Attachment 1 to Idaho Power Company's Compliance Filing dated August 9, 2023, as
approved in Order No. 35777 (May 11, 2023),to determine the Monthly Adjusted Renewable Capacity Credit.
2 Amounts to be adjusted by the Performance Ratio Adjustment Factor,which is calculated pursuant to the methodology
detailed in Case No. IPC-E-24-01,Attachment 2 to Idaho Power Company's Compliance Filing dated June 18, 2024, as
approved in Order No. 36270(July 26, 2024), to determine the Monthly Adjusted Renewable Capacity Credit.
3 Amounts to be adjusted by the Performance Ratio Adjustment Factor,which is calculated pursuant to the methodology
detailed in Case No. IPC-E-24-42,Attachment 1 to Idaho Power Company's Compliance Filing dated June 23, 2025, as
approved in Order No.XXXXX(Month XX, 20XX), to determine the Monthly Adjusted Renewable Capacity Credit.
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective — 1221 West Idaho Street, Boise, Idaho

Idaho Power Company SeGGRd Third Revised Sheet No. 33-4
Cancels
I.P.U.C. No. 30, Tariff No. 101 €arst-Second Revised Sheet No. 33-4
SCHEDULE 33
IDAHO POWER COMPANY
ELECTRIC SERVICE RATE
FOR
BRISBIE, LLC.
(Continued)
Renewable Resource Agreements
Calculation of the Monthly Unadjusted Renewable Capacity Credit for each Project is quantified in the
tables below. The Monthly Adjusted Renewable Capacity Credit will be provided to Brisbie, LLC
monthly, starting the month of the Project's Renewable Capacity Credit Eligibility Date (as defined in
Table 3) or the month following the respective Project's commercial operation date, whichever is later,
and will remain in effect for the duration of the term of the Renewable Resource PPA or the period of
time during which the Idaho Power-owned Renewable Resource will provide Project Output to Brisbie,
LLC as applicable. The Monthly Adjusted Renewable Capacity Credit will be provided in accordance
with Second Revised Exhibit 3.1 of Brisbie, LLC's Special Contract, dated December 22, 2021, as
amended.
TABLE 1: RENEWABLE CAPACITY CREDIT
a b c d e f
Project Most Recently Project Capacity Renewable Renewable Renewable Annual
Acknowledged Nameplate Contribution Capacity Capacity Capacity Renewable
IRP (kW AC) Factor Contribution Credit Rate Credit Capacity
(a * b) ($/kW-yr) Adjustment Credit`
c*d*e
Pleasant 2019 200,000 0.3121 62,420 $121.19 1.0 $7,564,680
Valley
Solar
LLC
Pleasant 2021 125,000 0.3154 39,425 $131.60 1.0 $5,188,330
Valley
Solar 2
LLC
Blacks 2023 320,000 0.1750 56,000 $145.94 1_0 $8,172,640
Creek
Energy
Center,
LLC
*Table 2 denotes the Monthly Unadjusted Renewable Capacity Credit.
'Table 3 denotes each project's date of eligibility for the Annual Renewable Capacity Credit.
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36383 R 36^'Q Timothy E. Tatum, Vice President, Regulatory Affairs
Effective— Neye„ ber 8, 2024 1221 West Idaho Street, Boise, Idaho

Idaho Power Company First Revised Sheet No. 33-5
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 33-5
SCHEDULE 33
IDAHO POWER COMPANY
ELECTRIC SERVICE RATE
FOR
BRISBIE, LLC.
(Continued)
Renewable Resource Agreements
(Continued)
TABLE 2: MONTHLY UNADJUSTED RENEWABLE CAPACITY CREDIT BY MONTH
Project Jan Feb Mar June July Aug Sept Oct Nov Dec
Pleasant $416,057 $416,057 -- $1,380,554 $2,761,108 $1,380,554 $189,117 $189,117 $416,057 $416,057
Valley Solar
LLC'
Pleasant $324,271 $324,271 $17,294 $959,841 $1,919,682 $959,841 $17,294 $17,294 $324,271 $324,271
Valley Solar 2
LLC2
Blacks Creek $343,251 $343,251 - $1,076,064 $2,152,129 $2,152,129 $1,076,064 $343,251 $343,251 $343,251
EnerqV
enter, LLC3
TABLE 3: ELIGIBILITY DATE FOR RENEWABLE CAPACITY CREDIT
Project PPA Execution Date Capacity Deficiency Year Renewable Capacity Credit Eligibility Date
leasant 10/27/2022 2023 6/1/2023
Valley Solar
LC
leasant 12/5/2023 2023 6/1/2023
alley Solar 2
LC
lacks Creek 1 10/11/2024 2026 6/1/2026
nergy Center
LC
Amounts to be adjusted by the Performance Ratio Adjustment Factor,which is calculated pursuant to the methodology
detailed in Case No. IPC-E-21-42,Attachment 1 to Idaho Power Company's Compliance Filing dated August 9, 2023, as
approved in Order No. 35777 (May 11, 2023),to determine the Monthly Adjusted Renewable Capacity Credit.
2 Amounts to be adjusted by the Performance Ratio Adjustment Factor,which is calculated pursuant to the methodology
detailed in Case No. IPC-E-24-01,Attachment 2 to Idaho Power Company's Compliance Filing dated June 18, 2024, as
approved in Order No. 36270(July 26, 2024), to determine the Monthly Adjusted Renewable Capacity Credit.
3 Amounts to be adjusted by the Performance Ratio Adjustment Factor,which is calculated pursuant to the methodology
detailed in Case No. IPC-E-24-42, Attachment 1 to Idaho Power Company's Compliance Filing dated June 23, 2025, as
approved in Order No.XXXXX(Month XX, 20XX), to determine the Monthly Adjusted Renewable Capacity Credit.
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36270 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective july 26 20241221 West Idaho Street, Boise, Idaho