20260331Compliance Filing.pdf

H IQAHO POVER.,
RILEY MALONEY
Regulatory Policy and Strategy Leader RECEIVED
rmaloney(Widahopower.com March 31, 2026
IDAHO PUBLIC
March 31, 2026 UTILITIES COMMISSION
Commission Secretary
Idaho Public Utilities Commission
11331 W. Chinden Boulevard
Building 8, Suite 201-A
Boise, Idaho 83714
Re: Case No. IPC-E-25-15
Application for Its First Annual Update to the Export Credit Rate for Non-
Legacy On-Site Generation Customers from June 1, 2025 through May 31,
2026, In Compliance with Order No. 36048
Commission Secretary:
Pursuant to Order No. 36785 in the above-mentioned case, Idaho Power Company
("Idaho Power" or "Company") hereby submits for electronic filing its Annual Distribution
Energy Resources ("DER") Status Report for 2025 in the above-entitled matter.
While preparing the 2025 DER Status Report, the Company identified that some
financial credit transfers for customers with non-legacy systems were inadvertently
omitted from the 2024 DER Status Report. As a result, the financial credit transfers
reported on pages 13 and 15 of the 2024 DER Status Report are understated relative to
the amounts actually transferred in 2024. The Company has corrected this reporting issue
and the correct number of credits transferred in 2024 is reflected in Figure 4 on page 10
of the 2025 DER Status Report. Of note, all customers with non-legacy systems who
applied for and were eligible to receive credit transfers in 2024 received those transfers
and the discrepancy occurred only in the Company's reporting.
If you have any questions about the attached documents, please do not hesitate
to contact Regulatory Analyst, Mary Alice Taylor at (208) 388-5645 or
mtaylor(a)_idahopower.com.
Sincerely,
Riley Maloney
RM:sg
Enclosure
P.O.Box 70(83707)
1221 W.Idaho St.
Boise,ID 83702

qN6 ID1AH0 POWER.
Distributed Energy Resources
2025 Annual Report
March 2026
© Idaho Power

Idaho Power Company Introduction and Table of Contents
INTRODUCTION
Idaho Power Company ("Idaho Power" or "Company") presents its annual Distributed Energy
Resources ("DER") Status Report to the Idaho Public Utilities Commission ("Commission")
as required by Order Nos. 32846,1 32925,2 34955,3 and 36159.4 The report begins with a brief
overview of the regulatory framework for the Company's on-site generation offering, followed
by an update on current participation levels and growth rates since the Company's last DER
Status Report, which was filed with the Commission in April 2025. Next, the report discusses
system reliability considerations and provides an update regarding meter aggregation activity,
credit transfers, and accumulated excess net energy credits. Finally, it concludes with a
discussion of system upgrades caused by on-site generation customers and provides an update
of the ongoing operations and maintenance ("O&W) costs associated with those upgrades.
In the Matter of the Application of Idaho Power Company forAuthority to Modify its Net Metering Service and to
Increase the Generation Capacity Limit,Case No. IPC-E-12-27, Order No. 32846 at 19(July 3, 2013).
z Id., Order No. 32925 at 7(Nov. 19,2013).
3 In the Matter of Idaho Power Company's Application to Establish Tariff Schedule 68—Interconnections to
Customer Distributed Energy Resources,Case No. IPC-E-20-30, Order No. 34955 at 11(Mar.9, 2021).
41n the Matter of Idaho Power Company's Application for Authority to Implement Changes to the Compensation
Structure Applicable to Customer On-Site Generation Under Schedules 6, 8, and 84 and to Establish an Export
Credit Rate,Case No. IPC-E-23-14,Order No. 36159 at 2 (Apr. 30, 2024).
Distributed Energy Resources 2025 Annual Report Page i

Idaho Power Company Introduction and Table of Contents
TABLE OF CONTENTS
Introduction ......................................................................................................................................i
I. Customer Generation in Idaho ........................................................................................... 1
RegulatoryBackground............................................................................................................. 1
Current Participation (Exporting Systems) ............................................................................... 2
LegacySystems ................................................................................................................... 2
Non-Legacy Systems ........................................................................................................... 3
TotalSystems...................................................................................................................... 3
II. System Reliability Considerations....................................................................................... 5
Installation Concentration versus Capacity.............................................................................. 5
Smart Inverter Installation........................................................................................................ 6
III. 2025 Excess Net Credit Transfers ....................................................................................... 7
Meter Aggregation Eligibility- Legacy....................................................................................... 7
Meter Aggregation Eligibility- Non-Legacy............................................................................... 7
Customer Communication........................................................................................................ 8
CreditTransfer Requests .......................................................................................................... 8
Credit Transfer Magnitude—Legacy......................................................................................... 9
Credit Transfer Magnitude—Non-Legacy............................................................................... 10
Accumulated Excess Net Energy Credit Balances................................................................... 11
Accumulated Excess Net Financial Credit Balances................................................................ 11
IV. System Upgrades and 0&M Costs.................................................................................... 12
System Upgrades and 0&M Costs.......................................................................................... 12
V. Conclusion......................................................................................................................... 13
LIST OF TABLES
Table 1. Legacy—Idaho active Exporting Systems as of December 31, 2025 ............................ 2
Table 2. Legacy—Idaho active Exporting Systems nameplate capacity (MW) as of
December31, 2025....................................................................................................... 2
Table 3. Non-Legacy—Idaho active and pending Exporting Systems as of December 31,
2025 .............................................................................................................................. 3
Distributed Energy Resources 2025 Annual Report Page ii

Idaho Power Company Introduction and Table of Contents
Table 4. Non-Legacy—Idaho active and pending Exporting Systems nameplate capacity
(MW) as of December 31, 2025.................................................................................... 3
Table 5. System upgrades and O&M costs............................................................................... 12
LIST OF FIGURES
Figure 1. Cumulative Exporting System counts by customer type, 2016-2025.......................... 4
Figure 2. Cumulative Exporting System capacity by customer type, 2016-2025 ....................... 4
Figure 3. Excess net energy credit transfers by customer class, 2021-2025............................ 10
Figure 4. Excess net financial credit transfers by customer class, 2024 and 2025.................... 10
Figure 5. Accumulated unused excess net energy credit balance, 2016-2025 ........................ 11
Figure 6. Accumulated unused excess net financial credit balance, 2024 and 2025................ 11
Distributed Energy Resources 2025 Annual Report Page iii

Idaho Power Company Customer Generation in Idaho
I. CUSTOMER GENERATION IN IDAHO
Regulatory Background
Idaho Power has long offered its customers the option to interconnect on-site generation, with
its first offering dating back to 1983. While the option has evolved over the years, the core
foundation of allowing customers the ability to offset their own usage has not changed. In 2019
and 2020, the Commission established "legacy" and "non-legacy" status for residential, small
general service, and commercial, industrial, and irrigation on-site generation systems.'Through
its orders, the Commission found that customers with legacy systems will continue to
participate in the offering that was in place at that time—net energy metering (one-for-one
kilowatt-hour ("kWh") credit for excess net energy)—under certain criteria through 20451
and customers with non-legacy systems would be subject to future changes to the program
fundamentals, including the compensation structure applied to excess energy.
On December 29, 2023, the Commission issued Order No. 36048, which authorized new
program parameters for customers with non-legacy systems with an effective date of January
1, 2024.7 In its order, the Commission approved changes to the Company's on-site generation
offering including a real-time net billing structure pursuant to which customers continue to be
able to offset their energy needs with energy generated on-site and to export excess energy to
the grid, for which they receive a financial bill credit based on an avoided cost-based export
credit rate ("ECR") that varies based on the season and time of export.
'In the Matter of the Petition of Idaho Power Company to Study the Costs, Benefits, and Compensation of Net
Excess Energy Supplied by Customer On-Site Generation,Case No. IPC-E-18-15,Order No. 34509 at 10(Dec. 20,
2019);In the Matter of Idaho Power Company's Application for Authority to Modify Schedule 84's Metering
Requirement and to Grandfather Existing Customers with Two Meters, IPC-E-20-26,Order No.34854 at 10
(Dec. 1, 2020).
61n the Matter of the Petition of Idaho Power Company to Study the Costs, Benefits, and Compensation of Net
Excess Energy Supplied by Customer On-Site Generation, Case No. IPC-E-18-15,Order No. 34546 at 9(Feb. 5,
2020);In the Matter of Idaho Power Company's Application for Authority to Modify Schedule 84's Metering
Requirement and to Grandfather Existing Customers with Two Meters,Case No. IPC-E-20-26,Order No. 34854
at 10(Dec. 1, 2020).
'In the Matter of Idaho Power Company's Application for Authority to Implement Changes to the Compensation
Structure Applicable to Customer On-Site Generation Under Schedules 6, 8, and 84 and to Establish an Export
Credit Rate,Case No. IPC-E-23-14 Order No.36048 at 6 and 18(Dec.29,2023).
Distributed Energy Resources 2025 Annual Report Page 1

Idaho Power Company Customer Generation in Idaho
Current Participation (Exporting Systems)
As of December 31, 2025, Idaho Power had 19,760 total active and pending On-Site Generation
Exporting Systems ("Exporting Systems")'with a cumulative nameplate capacity of
202.07 megawatts ("MW") in its Idaho service area. All new systems that interconnected in
2025 were solar photovoltaic ("PV").
Legacy Systems
Table 1 provides the total number of active Exporting Systems with legacy status in the
Company's Idaho jurisdiction by resource type and customer class.
Table 1. Legacy—Idaho active Exporting Systems as of December 31,2025
Customer Segment Solar PV Wind Hydro/Other Total
Schedule 6
Residential 5,016 21 7 5,044
Schedule 8
Small General 38 — 2 40
Schedule 84
Commercial&Industrial 163 — 1 164
Irrigation 207 — — 207
Total 5,424 21 10 5,455
Table 2 provides the total nameplate capacity of active Exporting Systems with legacy status in
the Company's Idaho jurisdiction by resource type and customer class.
Table 2. Legacy—Idaho active Exporting Systems nameplate capacity(MW)as of December 31,2025
Customer Segment Solar PV Wind Hydro/Other Total
Schedule 6
Residential 39.74 0.10 0.09 39.93
Schedule 8
Small General 0.27 — 0.05 0.31
Schedule 84
Commercial&Industrial 5.58 — 0.03 5.61
Irrigation 19.50 — — 19.50
Total 65.10 0.10 0.16 65.35
Note:Totals may not sum due to rounding.
$Exporting Systems take service under the terms of Schedule 6, Residential Service On-Site Generation
("Schedule 6"),Schedule 8,Small General On-Site Generation ("Schedule 8"),and Schedule 84, Large General,
Large Power,and Irrigation On-Site Generation ("Schedule 84") and are designed to transfer excess energy to
the Company.
Distributed Energy Resources 2025 Annual Report Page 2

Idaho Power Company Customer Generation in Idaho
Non-Legacy Systems
Table 3 provides the total number of active and pending Exporting Systems with non-legacy
status in the Company's Idaho jurisdiction by resource type and customer class.
Table 3. Non-Legacy—Idaho active and pending Exporting Systems as of December 31,2025
Customer Segment Solar PV Wind Hydro/Other Total
Schedule 6
Residential 14,038 1 2 14,041
Schedule 8
Small General 35 — — 35
Schedule 84
Commercial&Industrial 132 — — 132
Irrigation 97 — — 97
Total 14,302 1 2 14,305
Table 4 provides the total nameplate capacity of active and pending Exporting Systems with
non-legacy status in the Company's Idaho jurisdiction by resource type and customer class.
Table 4. Non-Legacy—Idaho active and pending Exporting Systems nameplate capacity(MW)as of
December 31,2025
Customer Segment Solar PV Wind Hydro/Other Total
Schedule 6
Residential 113.35 0.002 0.02 113.37
Schedule 8
Small General 0.31 — — 0.31
Schedule 84
Commercial&Industrial 7.98 — — 7.98
Irrigation 15.07 — — 15.07
Total 136.70 0.002 0.02 136.72
Note:Totals may not sum due to rounding.
Total Systems
Figures 1 and 2 detail the cumulative customer Exporting System counts and
nameplate capacity, respectively, by customer class in the Company's Idaho jurisdiction
regardless of legacy status, from 2016 through the end of calendar year 2025
(including pending applications).
Distributed Energy Resources 2025 Annual Report Page 3

Idaho Power Company Customer Generation in Idaho
Figure 1. Cumulative Exporting System counts by customer type,2016-2025
20,000
18,000
16,000
14,000
41
c 12,000
U
E 10,000
8,000
H
6,000
4,000
2,000
2016 2017 2018 2019 2020 2021 2022 2023 2024 2025
■Residential ■Commercial&Industrial ■ Irrigation
Figure 2. Cumulative Exporting System capacity by customer type,2016-2025
225
200
175 .
3 150 -
125
100
a
U 75
50
25 ■
2016 2017 2018 2019 2020 2021 2022 2023 2024 2025
■Residential ■Commercial&Industrial ■Irrigation
Distributed Energy Resources 2025 Annual Report Page 4

Idaho Power Company System Reliability Considerations
II. SYSTEM RELIABILITY CONSIDERATIONS
There are 706 electrical distribution circuits in the Company's service area. Considering all
customer-owned on-site generation installations across all jurisdictions, all rate classes, and all
resources, as of December 31, 2025, there were 19,797 active, customer-owned on-site
generation systems. These systems total approximately 195.7 MW on 555 distribution circuits.
Installation Concentration versus Capacity
The circuits containing the greatest number of customer-owned on-site generation systems are
in Ada and Elmore County, with the densest concentrations in southeast and south Boise and
north Mountain Home. The largest number of customer-owned on-site generation systems
connected to a single distribution circuit is 260, with a total rated capacity of 1,807 kilowatts
("W'). This circuit primarily serves residential customers in Boise.
The distribution circuit in Idaho with the greatest customer-owned on-site generation capacity
primarily serves irrigation and rural customers in the Magic Valley and has a total of 31 solar PV
systems with a total rated capacity of 2,923 kW (average system size 94 kW). This circuit has a
summer peak load of approximately 7,060 kW. The distribution circuit in Idaho with the
second-highest customer-owned on-site generation capacity also serves irrigation and rural
customers in the Magic Valley and has a total of 21 solar PV systems with a total rated capacity
of 2,760 kW (average system size is 131 kW). This circuit has a summer peak load of
approximately 11,000 kW.
There are 20 circuits with total customer-owned on-site generation capacity greater than
1,000 kW. Those 20 circuits hosted a total of 32.3 MW of generation. Twelve of these circuits
are in the Magic Valley (one serves industrial and residential customers, and all others largely
serve irrigation and residential loads). Of the remaining, five are in Ada County, two in Canyon
County, and one in Elmore County, all of which primarily serve residential and small business
customers.
For 2025, the total number of new customer-owned on-site generation systems installed
decreased for the third year in a row. However, the amount of capacity added in 2025
increased by over 20% compared to 2024, largely due to business and agriculture customers
being able to install systems up to their peak load beginning in 2024 rather than being limited
to 100 kW. Although customers began applying for these larger projects in 2024, most did not
come online until 2025. As a result, there are now three circuits with an average system size
equal to 300 kW or larger, and 17 circuits with average system sizes equal to 100 kW or larger.
All but one of these 17 circuits is in the Magic Valley.
The customer-owned on-site generation connected capacity on the Company's distribution
system as a percentage of the total system peak load in 2025 was 5.4%. The Company has
Distributed Energy Resources 2025 Annual Report Page 5

Idaho Power Company System Reliability Considerations
managed the impacts on these circuits, when necessary, by requiring customer-funded
distribution upgrades pursuant to Rule H and, in very rare instances, requiring customer-funded
substation upgrades.
Smart Inverter Installation
All new systems applying to interconnect are required to install smart inverters9 with
Idaho Power's required settings to support the distribution system's ongoing stability and
reliability. Idaho Power requires inverters to comply with the IEEE 1547-2018 certification10
which meet all smart inverter requirements as defined by the Institute of Electrical and
Electronics Engineers ("IEEE"). The IEEE Standard 1547 establishes the technical standard for
interconnection and interoperability of distributed energy resources, and Idaho Power is an
active participant in the revision process of this standard which is expected to have a published
update in 2026.
9 Order No. 34955 issued in Case No. IPC-E-20-30 approved Schedule 68,effective March 23,2021.Schedule 68
requires smart inverter functionality to be enabled for all new applications for customer generation.
10 Underwriters Laboratories Standard for Safety 1741—Inverters,Converters,Controllers and Interconnection
System Equipment for Use with Distributed Energy Resources,Supplement B.
Distributed Energy Resources 2025 Annual Report Page 6

Idaho Power Company 2025 Excess Net Credit Transfers
III. 2025 EXCESS NET CREDIT TRANSFERS
Meter Aggregation Eligibility- Legacy
Schedules 6, 8, and 84 provide customers with legacy Exporting Systems the ability to submit
requests to transfer excess net energy credits annually. These applications must be received by
January 31 of each year and the Company applies the following criteria for legacy systems to all
requests received:
i. The account subject to offset is held by the customer; and
ii. The meter is located on, or contiguous to, the property on which the Designated Meter
(the meter physically connected to the Exporting System) is located. For the purposes of
the tariff, contiguous property includes property that is separated from the premises of
the Designated Meter by public or railroad rights of way; and
iii. The meter is served by the same primary feeder as the Designated Meter at the time
the customer files the application for the Exporting System; and
iv. The electricity recorded by the meter is for the customer's requirements; and
v. For customers taking service under Schedule 6 or Schedule 8, credits may only be
transferred to meters taking service under Schedule 1, Schedule 6, Schedule 7,
or Schedule 8. For Schedule 84 customers taking service under Schedule 9, Schedule 19,
or Schedule 24, credits may only be transferred to meters taking service under
Schedule 9, Schedule 19, or Schedule 24.11
Meter Aggregation Eligibility- Non-Legacy
Schedules 6, 8, and 84 also provide customers with non-legacy Exporting Systems the ability to
submit requests to transfer excess net financial credits annually. These applications must be
received by January 31 of each year and the Company applies the following criteria to all
requests received for non-legacy systems from Schedule 6, Schedule 8, and Schedule 84:
i. The account subject to offset is held by the customer; and
ii. The electricity recorded by the meter is for the customers' requirements.
11 Schedule 84 is an "adder" in Idaho Power's billing system.Schedules 9, 19,and 24 customers take service under
those primary schedules and those with on-site generation have Schedule 84 added to their primary service
schedule.
Distributed Energy Resources 2025 Annual Report Page 7

Idaho Power Company 2025 Excess Net Credit Transfers
Customer Communication
In November 2025, prior to the credit transfer window opening on December 1, Schedule 6,
Schedule 8, and Schedule 84 customers with excess net energy or net financial credits were
sent a postcard reminding them of the meter aggregation process, a list of important things to
note about the transfer process, the deadline for them to apply, and a phone number to
contact. The postcard also contained a web address which contains the requirements and an
online form. This postcard was sent to a total of 5,557 customers with both legacy and non-
legacy systems.
In December 2025 and January 2026, the Company provided a bill message on Schedule 6,
Schedule 8, and Schedule 84 customers' bills to inform them of when the transfer window
closed and to provide a link to a webpage where customers could find more information. Lastly,
in January 2026 the Company also sent an email reminder to 97 customers who submitted
transfer requests during the 2024-2025 transfer window but had not yet submitted a request in
the 2025-2026 transfer window. This email reminded these customers of the meter aggregation
process and deadline and provided a link for them to submit a transfer request.
Credit Transfer Requests
As of the application deadline,January 31, 2026, the Company received 301 applications for
transfer. Of the credit transfer requests, 198 applications were from customers with legacy
systems and 103 were from customers with non-legacy systems. The applications were
reviewed against the applicable aggregation criteria. The Company determined that 277 of the
requests were eligible for transfer based on the aggregation criteria. Of the eligible transfer
requests, 191 were from customers with legacy systems and 86 were from customers with non-
legacy systems.
The total amount of energy credits transferred was 9,340,974 kilowatt-hours ("kWh")
generated from Exporting Systems taking service under Irrigation (85%), Large General (9%),
Residential (6%), and Small General (1%) rate schedules. The 9,340,974 kWh were transferred
to customers taking service under Irrigation (79%), Large General (14%), Residential (6%),
and Small General (less than 1%) rate schedules. 12
The total amount of financial credits transferred was $73,143 from Exporting Systems taking
service under Irrigation (31%), Large General (16%), Residential (50%), and Small General (3%).
The $73,143 was transferred to customers taking service under Irrigation (33%), Large General
(13%), Residential (51%), and Small General (4%) rate schedules. 13
12 Totals may not sum due to rounding.
13 Totals may not sum due to rounding.
Distributed Energy Resources 2025 Annual Report Page 8

Idaho Power Company 2025 Excess Net Credit Transfers
The Company received 24 applications that were ineligible for transfer based on the following:
Legacy
• Three applications had no excess credits at the time of transfer
• Two applications requested a transfer to a meter that was not on contiguous property
and not on the same feeder
• Two applications were not on the same feeder
Non-Legacy
• 15 applications had no excess credits
• Two applications requested to transfer credits to an account that was not held by the
customer
The Company notified ineligible customers during its review period via email prior to the
deadline to submit requests. This allowed those customers additional time to resubmit requests
should there be an alternative, qualifying option. Any customers' requests that were deemed
ineligible after the deadline to submit request were notified via email.
Credit Transfer Magnitude—Legacy
Figure 3 shows the total excess net energy credit transfers for the last five years (2021 through
2025) by customer class.
Distributed Energy Resources 2025 Annual Report Page 9

Idaho Power Company 2025 Excess Net Credit Transfers
Figure 3. Excess net energy credit transfers by customer class,2021-2025
25,000,000
20,000,000 19,167,726
15,000,000 13,626,674 14,693,176
L
3
Y
10,000,000 9,340,974
5,000,000 4,627,989
2021 2022 2023 2024 2025
■ Residential Commercial ■ Irrigation
Credit Transfer Magnitude—Non-Legacy
This was the second-year customers with non-legacy systems could request to transfer excess
net financial credits. Figure 4 shows the total excess net financial credit transfers for 2024 and
2025, by customer class.
Figure 4. Excess net financial credit transfers by customer class,2024 and 2025
$80,000 $73,143
$70,000
$60,000 $56,790
$50,000
$40,000
$30,000
$20,000
$10,000
2024 2025
■Residential Commercial ■ Irrigation
Distributed Energy Resources 2025 Annual Report Page 10

Idaho Power Company 2025 Excess Net Credit Transfers
Accumulated Excess Net Energy Credit Balances
Figure 5 shows the accumulated excess net energy credit balance for 2016 through 2025.14
Figure S. Accumulated unused excess net energy credit balance,2016-20251-1
40
35
3... 34.3
30 28.9 30.9
c25
0
.�20 17.1
s15 11.3
310 7.6
0 r M ■
2016 2017 2018 2019 2020 2021 2022 2023 2024 2025
Accumulated Excess Net Financial Credit Balances
In 2024, customers with non-legacy systems began earning financial credits. The balance of
accumulated excess net financial credits was $447,037 and $702,961, at the end of 2024 and
2025, respectively.
Figure 6. Accumulated unused excess net financial credit balance,2024 and 2025
$800,000
$702,961
$700,000
$600,000
$500,000 $447,037
$400,000
$300,000
$200,000
$100,000
2024 2025
14 In Order No. 32846,the Commission stated, "we find it fair,just,and reasonable for the kWh credit to
indefinitely carry forward to offset future bills as long as the customer remains on the net metering service at
the same generation site.Allowing the credits to carry forward indefinitely ensures that customers will be able
to use their credits when they need them and thus receive the benefits of their systems."
1s The accumulated excess net energy credit balance represents all unused credits as of December 31. It does not
reflect the potential reduction due to future offset at the premise generated or transferred to another meter for
offset.
Distributed Energy Resources 2025 Annual Report Page 11

Idaho Power Company Conclusion
IV. SYSTEM UPGRADES AND O&M COSTS
System Upgrades and O&M Costs
In 2025, 70 on-site generation projects out of approximately 1,192 new system applicants were
notified that transformer or feeder upgrades would be necessary as a result of the Feasibility
Review. Of those 70 projects, 57 included an energy storage device. As of December 31, 2025,
12 of the 70 projects chose to proceed with funding the necessary upgrades. Table 5 provides
information for each of the 12 projects, including the size of the project, whether an energy
storage device (and type) was included, the upgrade that was required, the total cost of that
upgrade, and the estimated annual 0&M.
Table 5. System upgrades and O&M costs
Energy
Feasibility Storage
Customer Review* (AC, DC,or Cost of Estimated
Project Class (kW AC) None) Scope of Required Upgrade Upgrade Annual O&M
1 Residential 24.46 AC 15 kilovolt-amperes("kVa") $3,475 $0.35
(single phase)to 25 Wa(single
phase)
2 Irrigation 200 None 75 Wa(three phase)to $24,990 $2.50
300 Wa(three phase)
3 Residential 24.8 AC 25 Wa(single phase)to $8,360 $0.84
50 Wa(single phase)
4 Residential 23.5 AC 25 Wa(single phase)to $4,321 $0.43
50 Wa(single phase)
5 Residential 30.88 AC 25 Wa(three phase)to $10,679 $1.07
50 Wa(three phase)
6 Residential 6.96 None 25 Wa(single phase)to $9,857 $0.99
50 Wa(single phase)
7 Residential 21.5 AC 15 Wa(single phase)to $3,545 $0.35
25 Wa(single phase)
8 Residential 18.12 AC 15 Wa(single phase)to $3,438 $0.34
25 Wa(single phase)
9** Irrigation 170 None Feeder—regulator controls of $5,867 $0.59
all three phases upgraded from
CL-5E to CL-7
10** Irrigation 200 None Feeder—regulator controls of $5,867 $0.59
all three phases upgraded from
CL-5E to CL-7
11** Irrigation 100 None Feeder—regulator controls of $5,866 $0.59
all three phases upgraded from
CL-5E to CL-7
12 Irrigation 120 None Feeder—upgraded the $10,000 $1.00
substation voltage regulator
controller
Distributed Energy Resources 2025 Annual Report Page 12

Idaho Power Company Conclusion
*The Feasibility Review is based on Total Nameplate Capacity.For systems with AC coupled energy storage,the Total
Nameplate Capacity is the sum of the Generation Facility and the Energy Storage Device. For systems with DC coupled storage,
the Total Nameplate Capacity is equal to the capacity of the Generation Facility.See Schedule 68 for additional detail.
**Projects shared a single feeder upgrade with total cost of$17,600.
V. CONCLUSION
The continued expansion of on-site generation on Idaho Power's system highlights the
evolution of the Company's electrical grid, along with the importance of evaluating service
provisions and pricing to ensure safe, reliable, and fair-priced electricity. Idaho Power will
continue to monitor customer generation and keep the Commission informed of its impact on
system reliability.
Distributed Energy Resources 2025 Annual Report Page 13