APPLICATION

APPLICATION - 1
LISA C. LANCE (ISB No. 6241)
MEGAN GOICOECHEA ALLEN (ISB No. 7623)
Idaho Power Company
1221 West Idaho Street (83702)
P.O. Box 70
Boise, Idaho 83707
Telephone: [phone]
Facsimile: [phone]
[e-mail]
[e-mail]

Attorneys for Idaho Power Company

BEFORE THE IDAHO PUBLIC UTILITIES COMMISSION

IN THE MATTER OF IDAHO POWER
COMPANY’S APPLICATION FOR
MODIFICATIONS TO THE COMPANY’S
INTERCONNECTION RULES FOR
CUSTOMER DISTRIBUTED ENERGY
RESOURCES, SCHEDULE 68
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CASE NO. IPC-E-26-27

APPLICATION

Idaho Power Company ("Idaho Power” or "Company"), respectfully applies to the
Idaho Public Utilities Commission (“Commission”) pursuant to Idaho Code §§ 61-503 and
61-507 and Commission Rule of Procedure1 52, for authority to implement modifications
to its Schedule 68, Interconnections to Customer Distributed Energy Resources
(“Schedule 68”). Schedule 68 is the Company’s rules and procedures governing the
interconnection of customer-owned distributed energy resources (“DERs”). As more fully
set forth below, in response to stakeholder feedback and recent state legislation around

1 Hereinafter cited as RP
APPLICATION - 2
portable solar systems, Idaho Power proposes certain modifications to Schedule 68 to
allow for a streamlined registration process for residential and small general service DERs
under a specified nameplate capacity and like-for-like inverter replacements.
In support of this Application, Idaho Power represents as follows:
I. BACKGROUND
1. Schedule 68. Under Idaho Power’s on-site generation service offerings,
retail customers can choose to install their own DERs at their home or business to offset
some or all of their electric needs. As part of Idaho Power’s on-site generation service
offering, Schedule 68 lays out system requirements and interconnection processes for all
customer-owned DERs. Currently, all customers wanting to install DERs must go through
a full application process, which requires customers to pay a $100 application fee2 that
covers some of the costs related to the Company’s work performed during the application
process. This work includes feasibility studies and on-site inspections.
2. Portable Solar Systems. Portable solar systems are generation systems
that plug into an electrical outlet and supply solar generated power directly to a customer’s
home, thereby offsetting a portion of such home’s load. These systems operate in parallel
with the utility’s system and excess generation can also be exported to the grid. Recently,
there has been a growing movement across the United States to allow for electric utility
customers to use these systems in their homes, expanding portable solar systems’ use
beyond their historic off-grid recreational applications. However, the National Electric
Code (“NEC”) does not currently allow for portable solar systems to safely interconnect

2 The Commission initially approved the $100 application fee in Order No. 32846 (IPC-E-12-27) when on-
site generation interconnection rules were in Schedule 72. The Commission approved the $100 application
in Schedule 68 in Order No. 34955 (IPC-E-20-30) when the Company proposed to create Schedule 68.
APPLICATION - 3
to customer homes and the electric utility grid. Although Underwriters Laboratory (“UL”)
standards, such as UL3700, published in December 2025, establish product safety
requirements for plug-in and portable solar systems, the NEC does not currently
recognize or provide installation requirements for these systems. Specifically, UL3700
standards include a new plug type, bi-directional ground fault circuit interrupters and other
installation requirements to ensure these types of products do not create a fire or shock
hazard. Consequently, a gap exists between product certification and code-compliant
installation. Future NEC revisions may address this gap by establishing requirements for
the safe installation and interconnection of plug-in solar technologies.
3. Recent State Legislation. In recent years, in response to lobbying by
organizations with vested interests in portable solar systems, state governments across
the United States have begun taking up and, in some cases, passing legislation allowing
for these systems to be used in customers’ homes without the same level of oversight as
traditional hardwired systems. Figure 1 below, from the Electric Power Research Institute,
shows the movement portable solar legislation has had in each state as of April 2026.
APPLICATION - 4
Figure 1: Portable Solar Legislation Progress in the U.S.

As shown by Figure 1, during the 2026 Idaho Legislative Session, a bill was introduced
in the House of Representatives to codify in state statute customers’ optional use of
portable solar systems, though the bill did not move forward during the 2026 Legislative
Session.
4. Idaho Power’s Concerns. With the recent push by lobbying organizations to
have states pass legislation to allow for the use of portable solar systems, some
manufacturers of these systems and media articles have suggested these systems are
safe, legal, and code compliant. Idaho Power is concerned that these misleading
communications may be creating customer confusion or uncertainty as to the status of
portable solar systems in Idaho. Though portable solar systems are not currently allowed
in permanent residences and businesses in Idaho, are not compliant with NEC code, and
may pose safety risks to customers and Idaho Power’s system, the Company has found
seven of these systems since May of 2026. The Company found these systems through
APPLICATION - 5
its routine monitoring for reverse power flow on non-customer generation and meters.
When the Company identifies this reverse power flow, it sends out field personnel to
physically inspect the meter and look for unauthorized on-site generation systems.
5. Because portable solar systems operate in parallel with Idaho Power’s
system and can export energy to the grid, the Company’s ability to verify their technical
characteristics, assess grid impacts, and track their locations is critical to the Company’s
ability to safely provide electric service and operate the electric system.
II. PROPOSED CHANGES
6. The Company’s goal in proposing these changes to Schedule 68 is to
proactively modify its tariff to ensure customers have a clear understanding of what
requirements there are for systems to interconnect and the types of systems that currently
meet these requirements. Additionally, the Company’s proposal is designed to improve
customer experience, as well as encourage customers to notify the Company when
installing on-site generation systems, regardless of the size and mobility of the system,
so that the safety and operational concerns discussed above may be avoided. Once NEC
requirements can be met, many portable solar systems would be eligible to interconnect
to Idaho Power’s grid using the proposed registration process.
7. Idaho Power’s Proposed Changes to Schedule 68. The Company is
proposing to add an optional, technology-neutral, and streamlined registration process
within Schedule 68 (the “Optional Registration Process”), in addition to the current
application process. Customers who wish to connect DERs in parallel with the Company’s
system will have to go through either the current application process or the proposed
Optional Registration Process. The Optional Registration Process is permitted for
APPLICATION - 6
residential and small general service on-site generation customers whose aggregate
nameplate capacity of system(s) does not exceed 400 watts at the point of
interconnection. Systems eligible for the Optional Registration Process may consist of
exporting or non-exporting inverter-based DERs that do not include an energy storage
device.
8. The 400-watt limit of the Optional Registration Process is designed to
ensure that the Company’s employees and equipment are protected while providing a
simplified option for customers to connect smaller DERs. The 400-watt limit applied to
service voltages in Idaho corresponds to the equivalent amperage output of the standard
800-watt limit for portable solar used in Germany, which has become a global leader in
residential plug-in solar. Idaho Power will continue to monitor developments in DER
technologies, applicable codes and standards, and evolving market conditions and, as
warranted, may recommend future updates to Schedule 68, including revisions to the
registration process eligibility threshold, to ensure the tariff remains aligned with safe,
reliable, and customer-focused interconnection practices.
9. Registration Process Technical Requirements. For a customer’s system to
be eligible for the Optional Registration Process, it must meet all local, state, and federal
electric, building, and fire codes. Additionally, systems must be listed by UL or other
recognized standards, that may include but are not limited to the most recent version of
UL 1741 SB, Institute of Electrical and Electronics Engineers 1547, UL 3700 and UL 3141.
Inverters used for systems interconnecting under the Optional Registration Process must
also have anti-islanding functionality and meet the Smart Inverter standard outlined in
Schedule 68.
APPLICATION - 7
10. When a customer submits a registration form under the Optional
Registration Process, they will list the make and model of the interconnecting system and
self-attest that it meets Schedule 68’s requirements. Idaho Power will then review the
information provided. The customer must confirm and comply with all local, state, and
national electric, building, and fire code requirements and if any discrepancies exist in the
customer’s registration form the Company will notify the customer of the discrepancy.
Idaho Power’s approval of a customer’s system interconnecting under Schedule 68 does
not transfer liability to the Company if the customer’s system is not in compliance with
such requirements.
11. It is recommended, but not required, that systems interconnecting under the
Optional Registration Process have disconnection equipment meeting the current
requirements in Schedule 68. Disconnection equipment allows Idaho Power to disconnect
the on-site generation system without disrupting electrical service to the customer’s
premises. Absent disconnection equipment – and in the event a safety or operational risk
necessitates disconnecting the on-site generation system – Idaho Power will have to
disconnect electrical service to the customer’s premises. This practice will be clearly
communicated with customers for their consideration.
12. Registration Process Customer Experience. Customers who seek to
interconnect their systems under the Optional Registration Process will not be required
to pay an application fee as the Company will not perform an on-site inspection or meter
change. As such, there is not a need for Idaho Power to recover costs associated with
these activities through the application fee.
APPLICATION - 8
13. Under the Optional Registration Process, and pursuant to Rule H, New
Service Attachments and Distribution Line Installations or Alterations, of the Company’s
tariff, customers will remain responsible for the cost of any service wire, transformer, or
distribution feeder upgrades identified as being necessary to safely interconnect their
systems. The Company will confirm the availability of capacity or need for customer-
funded system upgrades through the Optional Registration Process.
14. Customers who interconnect their systems under the Optional Registration
Process will remain on their standard service schedule and their exports will not be eligible
for compensation. If a customer wants to be compensated for their exports, they may
elect to take service under the Company’s on-site generation service schedules and
interconnect their systems in accordance with Schedule 68’s standard application
process.
15. Additional Modifications to Schedule 68. To accommodate the Optional
Registration Process, the Company is proposing several additional modifications to
Schedule 68 so that customers using the existing application process or the Optional
Registration Process will be subject to the same rules and procedures needed for the
Company to maintain safety and reliability. This includes updates to Schedule 68’s
disconnection equipment, system modifications, unauthorized installations and
expansions, and unauthorized inadvertent exports sections.
16. The Company is also proposing to allow customers completing like-for-like
inverter replacements to use the Optional Registration Process as opposed to the existing
application process. A like-for-like inverter replacement is when a customer replaces an
existing inverter with an inverter of the same make, model and capacity, without making
APPLICATION - 9
any additional system modifications. Because like-for-like inverter replacements do not
require a meter change or full inspection by the Company to be safely integrated with
Idaho Power’s system, requiring that customers submit a full application and pay its
associated cost is not necessary. Instead, the Company will verify a like-for-like inverter
change through the Optional Registration Process.
17. Lastly, the Company is proposing to fix a few minor clerical errors it
discovered in preparation of this Application. These changes are non-substantive and
have been incorporated into both the clean and legislative versions of the proposed
Schedule 68, included as Attachment 1 to this Application, alongside the revisions
intended to implement the changes discussed above.
18. Additionally, because the changes necessary to implement the Optional
Registration Process introduce pagination, numbering, and formatting revisions
throughout Schedule 68, redline changes appear on every page of the tariff schedule.
Although the substantive changes proposed by the Company are limited, the resulting
redline document can create the appearance of more extensive changes than those
proposed. Accordingly, the Company has prepared Attachment 2 to this Application to
assist Commission Staff (“Staff”) and stakeholders in efficiently identifying and evaluating
the substantive changes apart from the associated pagination, numbering, and formatting
revisions.
III. STAKEHOLDER INPUT
19. Throughout the past year, Idaho Power has collaborated with stakeholders
to gain an understanding of the rapidly evolving technology discussed herein and to better
assess how Idaho Power could be positioned to accommodate a streamlined registration
APPLICATION - 10
process once the identified concerns have been addressed. Stakeholders Idaho Power
met and corresponded with included a portable solar advocate and lobbying organization,
parties that have historically intervened in Commission cases related to on-site
generation, peer utilities, the Idaho State Fire Marshal, the Idaho State Electrical Code
Board, and Staff.
20. Idaho Power believes the proposed Schedule 68 revisions will provide
clarity and enhance customer experience while continuing to support the Company’s safe
and reliable operation of the electric system. The Company notes that stakeholders were
generally supportive of the changes proposed in this Application and expressed
appreciation for the Company’s commitment to safety, reliability, and customer
experience.
IV. MODIFIED PROCEDURE
21. Idaho Power believes that a technical hearing is not necessary to consider
the issues presented herein and respectfully requests that this Application be processed
under Modified Procedure, i.e., by written submissions rather than by hearing. RP 201,
et. seq. If, however, the Commission determines that a technical hearing is required, the
Company stands ready to prepare and present its testimony in such hearing.
V. COMMUNICATIONS AND SERVICE OF PLEADINGS
22. Communications and service of pleadings with reference to this Application
should be sent to the following:
Lisa C. Lance
Megan Goicoechea Allen
Regulatory Dockets
Idaho Power Company
1221 West Idaho Street (83702)
P.O. Box 70
Tim Tatum
Connie Aschenbrenner
Mary Alice Taylor
Idaho Power Company
1221 West Idaho Street (83702)
P.O. Box 70
APPLICATION - 11
Boise, Idaho 83707
[e-mail]
[e-mail]
[e-mail]
Boise, Idaho 83707
[e-mail]
[e-mail]
[e-mail]
VI.REQUEST FOR RELIEF
23.As described in greater detail above, Idaho Power respectfully requests that
the Commission issue an order: (1) authorizing that this matter be processed by Modified
Procedure, and (2) approving the proposed modifications to Schedule 68 by December
31, 2026.
DATED at Boise, Idaho this 25th day of September 2026.
LISA C. LANCE
Attorney for Idaho Power Company

BEFORE THE

IDAHO PUBLIC UTILITIES COMMISSION

CASE NO. IPC-E-26-27

IDAHO POWER COMPANY

ATTACHMENT 1
PROPOSED SCHEDULE 68
(CLEAN AND LEGISLATIVE)
Idaho Power Company Second Revised Sheet No. 68-1
Cancels
I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. 68-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES

AVAILABILITY

Service under this schedule is available throughout the Company’s service area within the State
of Idaho to all Customer Generators owning or operating DERs, in Parallel with the Company’s system,
and located on the customer’s side of the Interconnection Point. DERs with Total Nameplate Capacity
of 3 MVA or greater are required to sign a Uniform Customer Generator Interconnection Agreement.

APPLICABILITY

Service under this schedule applies to construction, operation, and maintenance of a Customer
Generator System interconnected in Parallel with the Company’s system. In limited circumstances,
certain interconnection requirements included in this schedule may not be applicable when the Company
determines the DER relies on a technology, such as regenerative drives, that does not jeopardize grid
stability or reliability. In making its determination, the Company will evaluate criteria such as the
magnitude and duration of exports.

DEFINITIONS

Company is the Idaho Power Company.

Company-Furnished Facilities are those portions of the Interconnection Facilities funded by the
Customer Generator and provided by the Company.

Customer Generator is a Customer or prospective Customer applying to operate or operating a
DER in Parallel with the Company’s system.

Customer Generator-Furnished Facilities are those portions of the Interconnection Facilities
provided by the Customer Generator.

Customer Generator Application Process are the steps a Customer Generator must complete to
interconnect DERs less than 3 MVA with the Company’s system unless they are eligible for and elect to
use the Customer Generator Registration Process.

Customer Generator Interconnection Process are the steps a Customer Generator must complete
to connect a DER to the Company’s system and includes the Customer Generator Applicaton Process.

Customer Generator Registration Process are the steps a Customer Generator must complete to
interconnect DERs with the Company’s System when the DERs meet the eligibility requirements outlined
in Section 2.

Customer Generator System is an Exporting System, a Non-Exporting System, or a system
eligible for the Customer Generator Registration Process.

Idaho Power Company Second Revised Sheet No. 68-2
Cancels
I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. 68-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

DEFINITIONS (Continued)

Customer Representative is a person or entity identified by the Customer Generator who is
authorized to communicate with the Company on the Customer Generator’s behalf.

Disconnection Equipment is any device or combination of devices by which the Company can
manually and/or automatically interrupt the flow of energy from the Customer Generator to the Company’s
system, including enclosures or other equipment as may be required to ensure that only the Company
will have access to the devices.

Distributed Energy Resource(s) (DER(s)) is a source of electric power that is not directly
connected to the bulk power system. Any combination of Generation Facilities and/or Energy Storage
Devices connected in Parallel is considered a DER.

Energy Storage Device is a device that captures energy produced at a point in time and stores
the energy for use as electricity at a future point in time. An Energy Storage Device is a DER.

Exporting System is a Customer-owned DER under the terms of Schedules 6, 8, or 84, which is
designed to provide for the transfer of electric energy to the Company.

Feasibility Review is the Company’s standard engineering review of a proposed Customer
Generator System and is intended to ensure the Company’s system is equipped to incorporate the
proposed Customer Generator-Furnished Facilities in a manner that conforms with good utility practices
and the National Electric Safety Code.

Feasibility Study is the Company’s more detailed engineering assessment for DERs as
determined by the Feasibility Review. This study is intended to ensure that the Company’s system is
sufficiently equipped to incorporate proposed DERs in a manner that conforms with good utility practices
and the National Electric Safety Code, including protection coordination and system voltage
management.

Generation Facility means equipment used to produce electric energy at a specific physical
location and service point that qualifies for Schedules 6, 8, 84, or Non-Export. A Generation Facility is a
DER.

Inadvertent Export is the unplanned, unscheduled, and uncompensated transfer of electrical
energy from a Customer’s Non-Exporting System to the Company’s system across the Interconnection
Point.

Incomplete Application or Registration Form is an application or registration form missing any
information needed to satisfy the requirements of the Customer Generator Interconnection Process;
including but not limited to, Customer Generator signature, the application fee, and details about the
Generation Facility.

Idaho Power Company First Revised Sheet No. 68-3
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 68-3
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

DEFINITIONS (Continued)

Interconnection Facilities are all facilities which are reasonably required by good utility practices
and the National Electric Safety Code to interconnect and to allow for Parallel operations of the DER with
the Company’s system, including, but not limited to, Special Facilities, Disconnection Equipment, and
Metering Equipment.

Interconnection Point is the point where the Customer Generator’s conductors connect to the
facilities owned by the Company.

Like-for-Like Inverter Replacement is when a Customer Generator replaces an existing inverter
with an inverter of the same make, model, and capacity, without making any additional system
modifications.

Metering Equipment is the Company owned equipment required to measure, record or telemeter
power flows between the Customer Generator and the Company’s system.

Non-Exporting System is a Customer-owned DER that limits or prevents electrical energy from
transferring to the Company’s system.

Parallel connection means operating a DER that is connected to and receives voltage from Idaho
Power’s system.

Protection Equipment is the equipment, hardware, and/or software necessary to ensure the
protection of the Company’s system and could include a circuit-interrupting device, protective relaying,
instrument transformers, and associated wiring.

Relocation is a change in the location of existing Company-owned transmission and/or distribution
lines, poles, or equipment.

Smart Inverter is an inverter that conforms to the latest IEEE 1547 standards and is certified by
the UL 1741 standard, which complies with the latest IEEE 1547 standards.

Special Facilities are additions to or alterations of transmission and/or distribution lines and
transformers, including, but not limited to, Upgrades and Relocation, to safely interconnect the
Customer’s DER to the Company’s system.

System Verification Form is the form that a Customer must provide to the Company prior to the
connection of the Customer Generator System as part of the Customer Generator Application Process
as described in this schedule.

Total Nameplate Capacity is the total of the gross capacity of a DER as designated by the
manufacturer(s) maximum continuous operating rating of the DER in Alternating Current (AC), or as
determined by Idaho Power based on information provided on the application and System Verification
Form or registration form.

Idaho Power Company Second Revised Sheet No. 68-4
Cancels
I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. 68-4
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

DEFINITIONS (Continued)

Upgrades are those improvements to the Company’s existing system, which are reasonably
required by good practices and the National Electric Safety Code to interconnect the Customer Generator
System safely. Such improvements include, but are not limited to, additional or larger conductors,
transformers, poles, and related equipment.

SECTION 1: GENERAL INTERCONNECTION REQUIREMENTS

The following provisions apply to all Customer Generators requesting interconnection to the
Company’s system.

CONSTRUCTION AND OPERATION OF INTERCONNECTION FACILITIES

All Customer Generator-Furnished Interconnection Facilities will be constructed and maintained
in a manner as determined by the Company to be in full compliance with all good utility practices,
including the Company’s Customer Requirements for Electric Service (found at
idahopower.com/requirements), National Electric Safety Code, conforms to the IEEE 1547 standards,
and all other applicable federal, state, and local safety and electrical codes and standards at all times.

The Customer Generator shall:

1. Upon request, submit proof to the Company that all licenses, permits, inspections, and
approvals necessary for the construction and operation of the Customer’s DER and Interconnection
Facilities under this schedule have been obtained from applicable federal, state, or local authorities.

2. Upon request, submit the designs, plans, specifications, settings, and performance data
for the DER and Customer Generator-Furnished Facilities to the Company for review. The Company’s
acceptance shall not be construed as confirming or endorsing the design, or as a warranty of safety,
durability, or reliability of the DER or Customer Generator-Furnished Facilities. The Company will retain
the right to inspect this equipment at its discretion.

3. Demonstrate to the Company’s satisfaction that the Customer’s DER and Customer
Generator-Furnished Facilities have been completed, and that all features and equipment of the
Customer’s DER and Customer Generator-Furnished Facilities are capable of operating safely to
commence deliveries of energy into the Company’s system.

4. Should a Customer move a DER to a new service point, the Customer must initiate and
complete the Customer Generator Interconnection Process.

5. DERs must be listed by UL or other recognized standards, that may include but are not
limited to UL 1741 SB, IEEE 1547-2018, UL 3700 and UL 3141.

6. Provide and maintain adequate Protection Equipment sufficient to prevent damage to the
DER, Customer Generator-Furnished Facilities, and any other Customer Generator-owned facilities in
conformance with all applicable electrical and safety codes and requirements.
Idaho Power Company First Revised Sheet No. 68-5
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 68-5
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

SECTION 1: GENERAL INTERCONNECTION REQUIREMENTS (Continued)

7. Provide and maintain Disconnection Equipment as required by the Company in
accordance with all applicable electrical and safety codes and requirements as described within this
Schedule.

8. Upon request, provide a 24-hour telephone contact(s). This contact will be used by the
Company to arrange for repairs and inspections or in case of an emergency. The Company will make its
best effort to arrange repairs and inspections during normal business hours and to notify the Customer
Generator of such arrangements in advance. The Company will provide a telephone number to the
Customer Generator so that the Customer Generator can obtain information about Company activity
impacting the Customer’s DER.

DISCONNECTION EQUIPMENT

Disconnection Equipment is required for all Customer DERs initially subject to the Customer
Generator Application Process. The Disconnection Equipment shall be installed at an electrical location
to allow complete isolation of Customer’s DER and Interconnection Facilities from the Company’s system.
Disconnection Equipment will be installed at an electrical location on the Customer Generator’s side of
the Company’s retail metering point to allow complete isolation of the Customer’s DER and
Interconnection Facilities from the Customer Generator’s other electrical load and service.

The Disconnection Equipment’s operating device shall be:

1. Readily accessible by the Company at all times.

2. Clearly marked “Generation Disconnect Switch” or similar language, as approved by Idaho
Power, with permanent 3/8 inch or larger letters.

3. Physically installed and visible within 10 feet of the Interconnection Point or permanently-
posted instructions at the Interconnection Point indicating the exact location of the Disconnection
Equipment’s operating device. Instructions with lamination or in plastic sleeves do not satisfy this
requirement.

4. Of a design manually operated and lockable in the open position with a standard Company
padlock.

5. Equipped with a visual disconnect that enables the Company to visually confirm that the
Customer’s and Company’s conductors are physically disconnected. This requires the ability to inspect
the actual conductors visually. Circuit breakers do not satisfy this requirement.

6. Disconnection Equipment meeting the requirements in this section is recommended but
not required for inverter-based systems without Energy Storage Devices where the aggregate Total
Nameplate Capacity of all DERs behind the Customer’s meter does not exceed 400 Volt-Amps AC and
where the Customer takes metered service under Schedules 1, 5, or 7.

Idaho Power Company First Revised Sheet No. 68-6
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 68-6
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

SECTION 1: GENERAL INTERCONNECTION REQUIREMENTS (Continued)

DISCONNECTION EQUIPMENT (Continued)

Operation of Disconnection Equipment. If, in the reasonable opinion of the Company, the
Customer Generator’s operation or maintenance of the DER or Interconnection Facilities is unsafe, not
in compliance with this schedule, or may otherwise adversely affect the Company’s equipment,
personnel, or service to its customers, the Company may physically disconnect the Customer’s DER or
Interconnection Facilities by operation of the disconnection device or by any other means the Company
deems necessary to adequately disconnect the Customer’s DER and Interconnection Facilities from the
Company’s system. At such time as the unsafe condition is remedied or other condition adversely
affecting the Company is resolved to the Company’s satisfaction, the interconnection will be restored.

The Company will disconnect the Customer’s DER and Interconnection Facilities in the event of
any planned or unplanned maintenance or repair of the Company’s system connected to the Customer’s
DER and Interconnection Facilities. In the event of unplanned maintenance or repairs, no prior notice
will be provided. In the event of planned repairs, the Company will attempt to notify the Customer
Generator of the time and duration of the planned outage.

The Company will disconnect the Customer’s DER and Interconnection Facilities in the event that
any terms and conditions of any applicable Company tariff or contract enabling the interconnection of the
Customer’s DER are deemed by the Company to be in default or delinquent.

Customer Generators will be subject to disconnection and reconnection charges if the expenses
are incurred as the result of a DER and/or a Customer’s failure to abide by the provisions of Schedule
68.

Disconnection of the service may be necessary. The disconnection may result in the interruption
of both energy deliveries from the Customer Generator System to the Company as well as the interruption
of energy deliveries from the Company to the Customer Generator. Disconnection provisions specific to
DERs less than 3 MVA are described further in Section 2 of this schedule. Disconnection provisions
specific to DERs 3 MVA or greater are described further in Section 4 of this schedule.

The Company will establish the settings of Protection Equipment to disconnect the Customer’s
DER and Interconnection Facilities for the protection of the Company’s system and personnel consistent
with good utility practices. If the Customer Generator attempts to modify, adjust or otherwise interfere
with the Protection Equipment or its settings as established by the Company, such action may be grounds
for the Company’s refusal to continue interconnection of the Customer’s DER and Interconnection
Facilities to the Company’s system.

Idaho Power Company First Revised Sheet No. 68-7
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 68-7
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

SECTION 1: GENERAL INTERCONNECTION REQUIREMENTS (Continued)

GENERAL REQUIREMENTS OF CUSTOMER GENERATOR SYSTEMS

1. The Company will construct, own, operate and maintain all equipment, Upgrades, and
Relocations on the Company’s electrical side of the Interconnection Point.

2. The Company may clearly mark the Metering Equipment and any other Company
equipment associated with the Customer’s DER and/or Interconnection Facilities designating the
existence of the Customer’s DER as required by good utility practices.

3. The Customer Generator will be required to submit all specific designs, equipment
specifications/settings, and test results of the Customer Generator-Furnished Facilities to the Company
for review upon request by the Company. Upon receipt of the design and equipment specifications, the
Company will review the design and equipment specifications for conformance with applicable electrical
and safety codes and standards.

4. Customer Generator-Furnished Facilities will be operated and maintained by the
Customer Generator at the Customer Generator’s sole risk and expense. The Company’s review of any
Customer attestations or subsequent approval to proceed does not transfer liability to the Company for
any damages or injury caused by the DER. The Company shall not be liable directly or indirectly for
permitting or continuing to allow an attachment of a Customer Generator System to the Company’s
system, or for the acts or omissions of a Customer DER that cause loss or injury, including death, to any
third party.

INVERTER REQUIREMENTS

All inverter-based Customer Generator Systems must use a Smart Inverter programmed with the
required settings described in the following section. System Modifications that (1) do not replace or add
inverters, (2) are the result of warranty inverter replacements, or (3) rely on an inverter that is required to
meet the original inverter specifications for the Customer Generator System to properly function, may be
considered exempt from this requirement.

INVERTER SETTINGS

All inverter-based Customer Generator System Smart Inverters will be set for normal operating
performance Category B as defined in IEEE 1547, with the default reactive power control mode set for
the Voltage-reactive power mode and the parameters listed in Table 1. All inverter-based Customer
Generator System Smart Inverters will be set for abnormal voltage and ride through operating
performance Category III as defined in IEEE 1547 using the default settings. The remaining Smart
Inverter settings will be set to the default values specified in IEEE 1547. Inverter setting documentation
will be required for all DERs with a Total Nameplate Capacity of 100 kVA or greater.

Idaho Power Company Second Revised Sheet No. 68-8
Cancels
I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. 68-8
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

SECTION 1: GENERAL INTERCONNECTION REQUIREMENTS (Continued)

Table 1: VOLTAGE-REACTIVE POWER SETTINGS FOR SMART INVERTERS
Voltage-reactive power parameters Default Settings
V1 0.92 per unit of nominal voltage
Q1 44% of nameplate apparent power rating, injecting
V2 0.98 per unit of nominal voltage
Q2 0
V3 1.03 per unit of nominal voltage
Q3 0
V4 1.06 per unit of nominal voltage
Q4 44% of nameplate apparent power rating, absorption
Open-loop response time 5 seconds

ENERGY STORAGE DEVICE

Energy Storage Devices may share an inverter with a Generation Facility (“DC Coupled”), or
Energy Storage Devices may have a stand-alone inverter (“AC Coupled”). Energy Storage Devices that
are not coupled with a Generation Facility taking service under Schedules 6, 8, or 84 may not export
energy onto Idaho Power’s system. The Total Nameplate Capacity is determined as follows:

1. DC Coupled: For Energy Storage Devices that are DC Coupled with a Generation Facility,
the Total Nameplate Capacity of the Customer Generator System is defined by the inverter (kVA). A DC
coupled system can be an Exporting or Non-Exporting system.

2. AC Coupled:

i. AC Coupled with an Exporting System: For an Energy Storage Device coupled
with an Exporting System taking service under Schedules 6, 8, or 84, the Total Nameplate
Capacity is the aggregate Total Nameplate Capacity of all DERs on the Customer’s side of the
Interconnection Point.

ii. AC Coupled with a Non-Exporting System: An Energy Storage Device coupled
with a Non-Exporting System is subject to the provisions of Section 3 of this Schedule. The Total
Nameplate Capacity of the Energy Storage Device shall be considered 0 kVA.

Idaho Power Company Second Revised Sheet No. 68-9
Cancels
I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. 68-9
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

SECTION 1: GENERAL INTERCONNECTION REQUIREMENTS (Continued)

APPLICATION EXPIRATION

Applications from a Customer Generator with existing retail service that are not completed within
one year of the initial Feasibility Review are considered expired. Applications from a Customer Generator
without existing retail service that has not completed the Customer Generator Interconnection Process
requirements by the requested project in-service date identified on the completed application will be
considered expired.

Registration forms from a Customer Generator with existing retail service that are not completed
within one year of receipt are considered expired.

Customer Generators requesting connection or approval of expired applications are required to
resubmit a completed application form and a $100 non-refundable application fee and are subject to the
full application process described in Section 2.

RECERTIFICATION

1. The Company may perform full recertification inspections of Customer Generator Systems
at the Company’s discretion and at no charge to the Customer Generator. The Company will provide the
Customer Generator with written notice at least fourteen (14) calendar days prior to performing a
recertification inspection. Recertification inspections will be performed in the same manner as new
Customer Generator System inspections described in Section 2. Customers may choose to verify the
results of the Company’s inspection through an independent inspection performed by a certified third-
party at the Customer Generator’s expense.

2. If in the reasonable opinion of the Company, the Customer Generator’s operation or
maintenance of the DER or Interconnection Facilities is unsafe, not in compliance with this schedule, or
may otherwise adversely affect the Company’s equipment, personnel, or service to its customers, the
Company reserves the right to inspect any Customer Generator System at any time, and without prior
notice.

SYSTEM MODIFICATIONS

1. Any modifications to Customer Generator Systems that increase the Total Nameplate
Capacity of the system or modify the system in any way (including inverter replacements) that may impact
the safety or reliability of the Company’s electrical system are considered system modifications for the
purposes of this schedule.

2. Customer Generators planning to make system modifications must complete the
Customer Generation Interconnection Process including submitting applicable forms and fees.

Idaho Power Company Second Revised Sheet No. 68-10
Cancels
I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. 68-10
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

SECTION 1: GENERAL INTERCONNECTION REQUIREMENTS (Continued)

SYSTEM MODIFICATIONS (Continued)

3. System modifications without gaining prior Company approval are considered
unauthorized installations subject to the provisions of this schedule as described in Unauthorized
Installations and Expansions.

UNAUTHORIZED INSTALLATIONS AND EXPANSIONS

1. Customer Generator Systems that have been interconnected to the Company’s system
without Company approval are considered unauthorized installations that jeopardize the reliability of
Idaho Power’s system and the safety of its employees. This includes, but is not limited to, newly installed
systems and unapproved expansions or other modifications of approved systems. The process
described herein provides the Company with the ability to offer Customer Generation in an efficient, safe,
and reliable manner.

2. Unauthorized installations are subject to immediate Company inspection and
disconnection without notice. The Company will provide the reason for the disconnection of the
Customer’s DER. The Customer will be called and written, or electronic notification will be sent. The
Customer will have twelve (12) months from the notification date to notify the Company and complete
one of the options listed under 5(a) and 5(b).

3. If proper disconnection equipment is present, the Company will open the disconnect or
notify the Customer to open the disconnect immediately.

4. If proper disconnection equipment is not present, the Customer Generator must
disconnect the DER from operating in Parallel with the Company’s system immediately by turning off the
breaker or by other means necessary.

5. The Customer must complete and notify the Company of one of the below options within
twelve (12) months from the notification date:

a. Option 1: Complete the full Customer Generator Interconnection Process
described in Section 2, and the system will be re-energized.

b. Option 2: Permanently disable the DER from Parallel operations with the
Company system within twelve (12) months from the postmarked notification date. Customers that do
not meet this deadline will be subject to termination of service. Permanent disablement of the DER may
require an inspection or other attestation from the Customer Generator that the system is disabled.

Idaho Power Company Second Revised Sheet No. 68-11
Cancels
I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. 68-11
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

SECTION 1: GENERAL INTERCONNECTION REQUIREMENTS (Continued)

UNAUTHORIZED INSTALLATIONS AND EXPANSIONS (Continued)

6. If it is determined, at the sole discretion of the Company, that an unauthorized Customer
Generation System, expansion, or other system modification results in damage to equipment on the
Company’s system, the Customer will be responsible for all costs associated with replacing the
Company’s damaged equipment and defend, indemnify, and reimburse the Company for liabilities or
damages incurred by the Company for third-party claims arising out of the Customer Generator’s
unauthorized connection.

PERMANENTLY REMOVED OR DISABLED SYSTEMS

The Customer shall notify the Company immediately if a DER is permanently removed or
disabled. Permanent removal or disablement for the purposes of this Schedule is any removal or
disablement of a DER lasting longer than six (6) months. If the Customer wishes to interconnect the DER
after six (6) months, the Customer Generator must reapply and meet the interconnection requirements
in place at the time of application.

SECTION 2: INTERCONNECTION PROCESS REQUIREMENTS FOR DISTRIBUTED ENERGY
RESOURCES LESS THAN 3 MVA

Customer Generators requesting to interconnect a DER less than 3 MVA shall complete the
Application Process prior to interconnection unless they are eligible for and elect to use the Customer
Generator Registration Process.

It is within Idaho Power’s sole discretion to disconnect, or refuse to connect, any Customer
Generator System that does not pass inspection, poses a threat to public safety, or has unanticipated
impacts to Idaho Power’s system. In these situations, a Company representative will send a written
communication to the Customer Generator regarding Idaho Power’s inability to connect/reconnect the
Customer Generator System until the issue(s) is resolved. Idaho Power will continue working with the
Customer to resolve the issue(s) required to connect the Customer’s System. Idaho Power will re-inspect
the System upon receiving notice from the Customer indicating Customer’s Generation System meets all
applicable federal, state, and local requirements and is suitable for connection.

REGISTRATION PROCESS

Customers with DERs that meet one of the following eligibility requirements may use the Customer
Generator Registration Process:
 Inverter based systems without Energy Storage Devices where the aggregate Total
Nameplate Capacity of all DERs behind the Customer’s meter does not exceed 400 VA
AC and where the Customer has active and continues to take metered service under
Schedules 1, 5, or 7.
 Like-For-Like Inverter Replacements.

Idaho Power Company Second Revised Sheet No. 68-12
Cancels
I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. 68-12
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

SECTION 2: INTERCONNECTION PROCESS REQUIREMENTS FOR DISTRIBUTED ENERGY
RESOURCES LESS THAN 3 MVA (Continued)

REGISTRATION PROCESS (Continued)

Customers Generators using the Customer Generator Registration Process are required to submit an
applicable registration form to the Company providing information about the DER and certifying
compliance with Schedule 68. Registration forms are available on the Company’s website or will be
provided to the Customer by email or mail upon request. Incomplete Registration Forms are considered
withdrawn after sixty (60) days from the date the form was received.

The Company will review the registration form within seven (7) business days and inform the
Customer:

i. If additional information is needed in order to review the DER. Additional information may
include but is not limited to single lines diagrams or product specification sheets. A
registration form will be considered incomplete until the information is provided.
ii. If the DER does not meet the requirements of Schedule 68.
iii. If Upgrades are needed in order to approve the project. Upgrades will be subject to Section
2, Part 3 and Part 4 of Schedule 68.
iv. If additional time is needed to review the registration, the Company may request an
additional fifteen (15) business days.
v. If the project is approved to interconnect.

The Customer Generator Registration Process is complete when the Company confirms in writing
that the Customer Generator System is registered with Idaho Power.

If the DER system components, capacity, or configuration changes from the original registration
form, the Customer Generator must resubmit a registration form that will be subject to a new review.

APPLICATION PROCESS

Customers Generators using the Customer Generator Application Process are required to
complete the following:

1. Customer Generators must submit a completed application form and a $100 non-
refundable application fee to the Company. Applications are available on the Company’s website or will
be provided to the Customer upon request. Incomplete Applications are considered withdrawn after sixty
(60) days from the date the application was received.

2. Upon receipt of a completed application and a $100 non-refundable fee, the Company will
either (1) provide the Customer with a written or electronic notification that the application has been
received and all necessary information has been provided, or (2) request the Customer provide forms of
documentation outlined in Section 1.

Idaho Power Company Second Revised Sheet No. 68-13
Cancels
I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. 68-13
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

SECTION 2: INTERCONNECTION PROCESS REQUIREMENTS FOR DISTRIBUTED ENERGY
RESOURCES LESS THAN 3 MVA (Continued)

APPLICATION PROCESS (Continued)

If the DER system components, capacity, or configuration changes from the original application,
the Customer Generator will be subject to a new Feasibility Review.

If the Customer Generator changes its Customer Representative, a new application and a $100
non-refundable application fee is required.

3. The Company will perform within seven (7) business days, unless it is determined that
additional studies are necessary, the Feasibility Review based on Total Nameplate Capacity and other
project information provided in the application. The Feasibility Review determines the capability of the
Company’s electrical system to incorporate the proposed Customer Generator System and determines
if Upgrades are necessary. For a Customer Generator who does not yet have established service, the
Feasibility Review will occur as part of the Company’s evaluation for Upgrades for new customers
conducted in compliance with Rule H – New Service Attachments and Distribution Line Installations or
Alterations.

a. If the results of the Feasibility Review indicate satisfactory system capability, the
Company will provide the Customer with an official “Approval to Proceed”
notification.

b. If the results of the Feasibility Review indicate that Upgrades are necessary to
accommodate the proposed project, the Company will notify the Customer through written or
electronic notification of such Upgrades. Funding, construction, installation, and maintenance of
required Upgrades will be subject to the Company’s standard Rule H regarding New Service
Attachments and Distribution Line Installations or Alterations.

c. If the Company determines that additional time is necessary to determine
satisfactory system capability or that Upgrades are necessary to accommodate the proposed
project, the Company will notify the Customer. The Company will perform within fifteen (15)
business days the additional studies to complete the Feasibility Review.

4. If the results of the Feasibility Review require the need for a Feasibility Study, the
Company will provide the Customer with a Feasibility Study Agreement which requires a deposit of
$1,000 and must be signed and returned within fifteen (15) business days. Upon receipt of the signed
Feasibility Study Agreement and deposit, the Company will perform the Feasibility Study within thirty (30)
business days. If the results of the Feasibility Study indicate that Upgrades or Protection Equipment are
necessary to accommodate the proposed project, the Company will notify the Customer of such
Upgrades or Protection Equipment. At the Company’s discretion, additional studies referenced in Section
4 may be applicable.

a. Installation and funding of the construction, installation, and maintenance of
required Protection Equipment will be subject to the following provisions:
Idaho Power Company Second Revised Sheet No. 68-14
Cancels
I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. 68-14
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

SECTION 2: INTERCONNECTION PROCESS REQUIREMENTS FOR DISTRIBUTED ENERGY
RESOURCES LESS THAN 3 MVA (Continued)

APPLICATION PROCESS (Continued)

i. Protection Equipment Requirements (Rotating Machines): Generation
Facilities up to 500 kVA Total Nameplate Capacity may not require additional Protection
Equipment but will be evaluated on a case-by-case basis. Generation Facilities greater
than 500 kVA Total Nameplate Capacity will require additional Company-Furnished
Protection Equipment.

ii. Protection Equipment Requirements (Other DER): DER up to 3 MVA Total
Nameplate Capacity may not require additional Protection Equipment but will be evaluated
on a case-by-case basis.

iii. When it is determined Company-owned Protection Equipment is required,
the Customer shall pay the actual costs of all required Protection Equipment prior to the
start of Parallel operations. The Customer will also pay a Maintenance Charge specified
in Schedule 66, per month times the investment in the Protection Equipment.

5. Following receipt of “Approval to Proceed,” the Customer is responsible for completing the
installation of the Customer Generator System and fulfilling all applicable federal, state, and local
inspection requirements. Customers must also provide the Company with a completed System
Verification Form detailing the specifications of all installed components of the completed Customer
Generator System. System Verification Forms can be found on the Company’s website or will be
provided upon request. Upon completion, the Company reserves the right to request the Customer to
provide forms of documentation outlined in Section 1, verifying that all federal, state, and local
requirements have been met.

6. Once all required documentation has been submitted and the Company has verified that
all applicable federal, state, local, and Customer Generation Interconnection Process requirements have
been met, the Company will complete, barring conditions beyond the Company’s control, an on-site
inspection within ten (10) business days for DER with Total Nameplate Capacity of 100 kVA or less and
within twenty (20) business days for DER with Total Nameplate Capacity of greater than 100 kVA.
Company on-site inspections will not be performed until the system has passed all applicable federal,
state, and local inspection requirements. The Company on-site inspection may include the following:

a. Verification that actual installed components correspond to the information
provided on the initial application and the System Verification Form.
b. Verification that the disconnect is functional and reconnection time complies with
IEEE 1547.
c. Verification of the proximity and visibility of the disconnect or a sign indicating the
location of the disconnect.
d. Photographic documentation of the installation.
e. Posting of appropriate Company signage.
f. Documentation of the meter number and system configuration.
Idaho Power Company Second Revised Sheet No. 68-15
Cancels
I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. 68-15
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

SECTION 2: INTERCONNECTION PROCESS REQUIREMENTS FOR DISTRIBUTED ENERGY
RESOURCES LESS THAN 3 MVA (Continued)

APPLICATION PROCESS (Continued)

g. Verification of Smart Inverters, including the settings for all inverter-based DERs
100 kVA and greater.
h. Verification of Total Nameplate Capacity.
i. Verification of plant controller for all DERs 500 kVA and greater.

7. A return trip charge of $52.00 will be billed to the Customer each time Company personnel
are dispatched to the job site but are unable to conduct the on-site inspection due to one or more of the
conditions not being met that had been certified as complete by the Customer or Customer’s
Representative, as identified on the System Verification Form.

8. Successful completion of the Company on-site inspection constitutes the conclusion of the
application process. The Company must make a reasonable effort to move an Exporting Customer
Generator to the appropriate rate schedule within five (5) business days. The rate change will be no later
than the Customer’s next Billing Period following their successfully completed inspection. Upon
completion of this process, the Customer will receive confirmation that the application process has been
successfully completed.

SECTION 3: ADDITIONAL INTERCONNECTION REQUIREMENTS OF NON-EXPORTING
SYSTEMS

In addition to the requirements of Section 1, the following section is applicable to all Customer
Generators electing to establish their system as Non-Export.

NON-EXPORT TOTAL NAMEPLATE CAPACITY LIMIT

For customers taking service under Schedules 1, 5, or 7 that own and/or operate a Generation
Facility, service is subject to an aggregate DER Total Nameplate Capacity of 25 kVA or less, that is
operated in Parallel with the Idaho Power System. The capacity of an Energy Storage Device shall not
be used to calculate the 25 kVA capacity limit but will be used to calculate Total Nameplate Capacity for
the Feasibility Review.

NON-EXPORT CONTROL SYSTEM

1. Non-Export Systems must incorporate one of the following three options:

Idaho Power Company First Revised Sheet No. 68-16
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 68-16
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

SECTION 3: ADDITIONAL INTERCONNECTION REQUIREMENTS OF NON-EXPORTING
SYSTEMS (Continued)

NON-EXPORT CONTROL SYSTEM (Continued)

a. Option 1: (“Advanced Functionality”): The use of an internal transfer relay, energy
management system, or other customer facility hardware or software system(s) may be used to
ensure power is never exported across the Interconnection Point. To ensure that Inadvertent
Export of power is limited to acceptable levels, all of the following conditions must be met: (a)
inverter-based DERs must utilize a Smart Inverter; (b) the DER must monitor the total Inadvertent
Export; (c) the DER must disconnect from the Company’s distribution system or halt energy
production within two seconds after the period of continuous Inadvertent Export exceeds 30
seconds; (d) the DER must enter a safe operating mode where Inadvertent Export will not occur
as a result of a failure of the control or Smart Inverter system for more than 30 seconds, which
results in loss of control signal, loss of control power or single component failure or related control
sensing of the control circuitry.

b. Option 2: (“Reverse Power Protection”): To ensure power is never exported, a
reverse power relay protective function must be implemented at the Interconnection Point. The
default setting for this Protection Equipment, when used, shall be 0.1% (export) of the DERs Total
Nameplate Capacity, with a maximum 2.0 second time delay.

c. Option 3: (“Minimum Power Protection”): To ensure at least a minimum amount of
power is imported at all times (and, therefore, that power is not exported), an under-power
protective function may be implemented at the Interconnection Point. The default setting for this
non-export control system, when used, shall be 5% (import) of the DERs Total Nameplate
Capacity, with a maximum two (2) second time delay.

2. Control System Failure: Where applicable, any failure of the Customer’s DER control
system for 30 seconds or more, which includes, but is not limited to; the internal transfer relay, energy
management system, or other Customer facility hardware or software system(s) intended to prevent the
reverse power flow, shall cause the Customer’s DER to enter a safe operating mode whereby the
production of energy from the Non-Export DER is autonomously limited to an amount that shall not cause
Inadvertent Export to occur until such time that the Customer has reestablished real power output control
of the non-export control system.

UNAUTHORIZED INADVERTENT EXPORT

Inadvertent Export exceeding three hours of the DER Total Nameplate Capacity in any 30-day
period will be defined as unauthorized Inadvertent Export, and the following steps will be followed for
Customers with Non-Exporting Systems:

Idaho Power Company First Revised Sheet No. 68-17
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 68-17
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

SECTION 3: ADDITIONAL INTERCONNECTION REQUIREMENTS OF NON-EXPORTING
SYSTEMS (Continued)

UNAUTHORIZED INADVERTENT EXPORT (Continued)

1. The Company will notify the Non-Export Customer Generator that their Customer
Generator System has exceeded the Inadvertent Export limit.

2. After notification of Inadvertent Export, the following will occur:

a. For Schedules 1,5, or 7, Non-Exporting Systems, the Customer Generator must
immediately disconnect the DER until the issue(s) is resolved and rectify Inadvertent Export within
30 days after receipt of the notification by Idaho Power that the Non-Exporting System has
exceeded the Inadvertent Export limit. If the Customer Generator has not rectified Inadvertent
Export after 30 days, at the Customer’s election, one of the following actions will occur:

i. The DER must be permanently disconnected from the Company’s system.
A Customer Generator must complete the Customer Generator Interconnection Process
before the Non-Exporting System can interconnect to the Company’s system; or,

ii. The Customer may apply to take service as an Exporting System subject
to the full requirement for exporting systems outlined in this Schedule and Schedules 6,
or 8, as applicable.

b. For Schedules other than Schedules 1, 5, or 7:

i. Upon receipt of the notification by Idaho Power that the Customer
Generator’s Non-Exporting System has exceeded the Inadvertent Export limit, the
Customer Generator System disconnect will be placed in the open position until the issue
that caused the export is remedied. A Company inspection will be required before the
Non-Exporting System can interconnect to the Company’s system.

3. If it is determined, at the sole discretion of the Company, that unauthorized Inadvertent
Export results in damage to equipment on the Company’s system, the Customer Generator will be
responsible for all costs associated with replacing the Company’s damaged equipment and defend,
indemnify, and reimburse the Company for liabilities or damages incurred by the Company for third-party
claims arising out of the Customer Generator’s unauthorized Inadvertent Export.

Idaho Power Company Second Revised Sheet No. 68-18
Cancels
I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. 68-18
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

SECTION 4: ADDITIONAL INTERCONNECTION REQUIREMENTS OF DISTRIBUTED ENERGY
RESOURCES 3 MVA OR GREATER

The following section is applicable to all Customers requesting interconnection of DERs with Total
Nameplate Capacity of 3 MVA or greater.

CUSTOMER GENERATOR INTERCONNECTION PROCESS

1. Customer Generator shall pay the actual costs of all required interconnection studies. Any
difference between the deposit (if required) and the actual cost of the study shall be paid by or refunded
to Customer Generator, as appropriate. If, during the course of preparing a study, the Company incurs
costs in excess of the deposit amount, the Company may require that the deposit amount be replenished
in an amount equal to the estimated costs for completion of the study. If a deposit amount sufficient to
pay for completion of the study is not maintained, the Company may suspend work on the study.

2. Unless modified by the provisions of this schedule, the FERC-approved Large Generator
Interconnection Procedures and Small Generator Interconnection Procedures posted on the Company’s
website will apply to the Customer Generator Interconnection Process.

3. Application. The Customer Generator will submit a completed interconnection application
in the form posted on the Company’s website. The application form includes a general description of the
DER and its location. The application includes payment of an application fee to be applied against costs
the Company incurs to perform the Feasibility Study described below. The amount of the application fee
is $1,000.

4. Study Agreements. Subsequent to the Customer Generator submitting an Application,
the Customer Generator will be offered a series of study agreements. The individual study agreements
establish the time to perform the study, and the deposit the Customer Generator is to provide prior to
commencement of the study. The studies consist of:

a. The Feasibility Study: The Feasibility Study is intended to ensure that the
Company’s system is sufficiently equipped to incorporate proposed DER in a manner that
conforms with good utility practices and the National Electric Safety Code. The Feasibility Study
Agreement states that no deposit is required because the application fee covers the deposit.

b. The System Impact Study: For higher complexity projects, the System Impact
Study provides a detailed assessment of the distribution and/or transmission system adequacy to
accommodate the DER through the evaluation of equipment capabilities and electrical
performance requirements. This step may not be necessary for some projects depending on the
size and location of the project. The System Impact Study Agreement includes a deposit of
$2,000 for a distribution system impact study or a $10,000 deposit for a transmission system
impact study.

Idaho Power Company First Revised Sheet No. 68-19
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 68-19
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

SECTION 4: ADDITIONAL INTERCONNECTION REQUIREMENTS OF DISTRIBUTED ENERGY
RESOURCES 3 MVA OR GREATER (Continued)

CUSTOMER GENERATOR INTERCONNECTION PROCESS (Continued)

c. The Facility Study: The Facility Study includes the engineering to determine the
design specifications of the project. The Facility Study Agreement includes a deposit of 5% of
the total project costs that were determined in the System Impact Study Report (“SISR”) or the
Feasibility Study Report if a SISR is not required, capped at $30,000.

At the end of each stage of the three-step study process, the Company will provide the Customer
Generator with an increasingly more refined and detailed report that, among other things, will present a
list of required Interconnection Facilities and a non-binding, good faith estimate of Customer Generator’s
cost responsibility for the Interconnection Facilities. If long-lead-time equipment items need to be ordered
to meet Customer Generator’s construction schedule, the Company will request advance funding by the
Customer Generator to cover these equipment costs.

5. Customer Generator Interconnection Agreement. The Customer Generator
Interconnection Agreement (“CGIA”), will be offered to the Customer Generator following completion of
the Study Phase. The CGIA will utilize the Uniform Customer Generator Interconnection Agreement
template included in this schedule.

INTERCONNECTION FACILITIES REQUIREMENTS

DER 3 MVA or greater Total Nameplate Capacity will require additional Company-Furnished
Protection, Metering, and communications Equipment. This equipment will be further defined in the CGIA
Attachment 1.

COST OF INTERCONNECTION FACILITIES

The Customer Generator will pay all costs of interconnecting a DER to the Company’s system.
Costs of interconnection include the costs of furnishing and constructing required Upgrades, which will
be determined pursuant to Rule H. To the extent that additional facilities not provided for under Rule H,
including transmission and/or substation facilities, are required to interconnect the requested Generation
Facility, special arrangements will be made in a separate agreement between the Customer Generator
and the Company.

Each request for interconnection will go through the Customer Generator Interconnection
Process. Throughout the Customer Generator Interconnection Process, the Company will periodically
bill the Customer Generator for engineering costs incurred or obligated. Failure to pay an invoice within
the time specified in the invoice will result in the suspension of work on the interconnection. Customer
Generator can end the Customer Generator Interconnection Process at any time. If Customer
Generator decides to end the Customer Generator Interconnection Process prior to completion, the
Company will either refund any monies held for security that have not been spent or obligated, or issue
an invoice to Customer Generator for costs incurred prior to cancellation.
Idaho Power Company First Revised Sheet No. 68-20
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 68-20
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

SECTION 4: ADDITIONAL INTERCONNECTION REQUIREMENTS OF DISTRIBUTED ENERGY
RESOURCES 3 MVA OR GREATER (Continued)

SYSTEM PROTECTION, DER METERING, AND DER COMMUNICATION MAINTENANCE CHARGE

The Customer shall pay the actual costs of System Protection, DER metering, and DER
communication equipment, as identified in the study process, prior to the start of Parallel operations. The
Customer will pay a Maintenance Charge as specified in Schedule 66 per month times the investment in
the System Protection, DER metering, and DER communication equipment. The Customer Generator
will also be responsible for any applicable monthly charges as outlined in Attachment 1 of the CGIA.

IDAHO POWER COMPANY
UNIFORM CUSTOMER GENERATOR
INTERCONNECTION AGREEMENT

This Uniform Customer Generator Interconnection Agreement (“Agreement”) is entered to be
effective as of the ____ day of __________, 20___ (“Effective Date”), between
____________________________, (“Customer Generator”) and Idaho Power Company (the
“Company”). Customer Generator and the Company may also be referred to individually as a “Party” or
collectively as the “Parties.” Unless explicitly noted otherwise, the term “days” refers to calendar days.

RECITALS

A. Customer Generator owns or operates a Customer Generator System that qualifies for
service under Idaho Power’s Commission-approved Schedule 68 which is subject to change from time
to time pursuant to Commission order.

B. The Customer Generator System to be interconnected and operate in Parallel with the
Company’s system pursuant to this Agreement is more particularly described in Attachment 1.

AGREEMENT

For and in consideration of the mutual covenants and provisions set forth in this Agreement, and
other good and valuable consideration, the receipt of which is hereby acknowledged, the Parties
intending to be legally bound agree as follows:

1. Recitals. The Parties acknowledge and agree as to the accuracy of the Recitals set forth
above, and such Recitals are incorporated herein by this reference.

2. Defined Terms. Capitalized terms not defined in this Agreement shall have the meaning
given to them in Schedule 68.

Idaho Power Company First Revised Sheet No. 68-21
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 68-21
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

SECTION 4: ADDITIONAL INTERCONNECTION REQUIREMENTS OF DISTRIBUTED ENERGY
RESOURCES 3 MVA OR GREATER (Continued)

IDAHO POWER COMPANY
UNIFORM CUSTOMER GENERATOR
INTERCONNECTION AGREEMENT
(Continued)

AGREEMENT (Continued)

3. Schedule 68. Schedule 68 is incorporated into this Agreement by this reference and this
Agreement shall be interpreted in conjunction with Schedule 68; in the event of a conflict between
Schedule 68 and this Agreement, Schedule 68 shall prevail. This Agreement and Schedule 68 provide
terms and conditions under which the Customer Generator System will interconnect and operate in
Parallel with the Company’s transmission/distribution system.

4. Entire Agreement. This Agreement, in conjunction with Schedule 68, constitutes the full
and entire understanding and agreement between the Parties regarding the subjects set forth herein and
supersede all prior agreements and understandings related thereto. Nothing in this Agreement is
intended to affect any other agreement between the Company and Customer Generator regarding
subjects outside the terms of this Agreement and Schedule 68.

5. Attachments. The following Attachments 1 – 6 are attached hereto and incorporated by
this reference:

Attachment 1 – Description and Costs of the Customer Generator System, Interconnection
Facilities, and Metering Equipment.

Attachment 2–One-line Diagram Depicting the Customer Generator System,
Interconnection Facilities, Metering Equipment and Upgrades.

Attachment 3 – Milestones for Interconnecting the Customer Generator System.

Attachment 4 – Additional Operating Requirements for the Company’s Transmission
System Needed to Support the Customer Generator System.

Attachment 5 – Reactive Power.

Attachment 6 – Description of Upgrades required to integrate the Customer Generator
System and Best Estimate of Upgrade Costs.

6. Effective Date, Term, Termination and Disconnection.

6.1 Term of Agreement. Unless earlier terminated pursuant to the terms hereof, this
Agreement shall remain in effect from the Effective Date for as long as Customer Generator
System is eligible for service under Schedule 68.
Idaho Power Company First Revised Sheet No. 68-22
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 68-22
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

SECTION 4: ADDITIONAL INTERCONNECTION REQUIREMENTS OF DISTRIBUTED ENERGY
RESOURCES 3 MVA OR GREATER (Continued)

IDAHO POWER COMPANY
UNIFORM CUSTOMER GENERATOR
INTERCONNECTION AGREEMENT
(Continued)

AGREEMENT (Continued)

6.2 Termination for Cause. If either Party materially breaches this Agreement and the
material breach is not cured within 10 days after the non-breaching Party gives the breaching
Party written notice thereof, the non-breaching Party may elect to terminate this Agreement by
giving the breaching Party notice of the termination; provided, however, that if the nature of the
breach is such that it could not reasonably be cured within the 10 day period, then the non-
breaching Party may terminate this Agreement immediately upon providing written notice to the
breaching Party. If the Company terminates this Agreement for breach by the Customer
Generator and it is later determined that Customer Generator did not breach the Agreement, or
the breach was excusable, the rights and obligations of the Parties will be the same as if the
termination has been issued for the convenience of the Company pursuant to Section 6.3 below.

6.3 Termination for Convenience. The Company may terminate or suspend this
Agreement at any time without cause and without penalty, on 10 days’ written notice to the
Customer Generator. The Customer Generator may terminate or suspend this Agreement at any
time without cause and without penalty by discontinuing Parallel operation of Customer’s
Generator System, or discontinuing taking electric service from the Company, and providing the
Company with 10 days’ written notice of the same.

6.4. Effect of Termination. Upon termination or expiration of this Agreement pursuant
to this Section 6, Idaho Power will disconnect the Customer Generator System from the
Company’s transmission/distribution system. Upon termination or expiration of this Agreement,
all obligations of the Parties (other than those obligations that expressly or by nature survive
termination) shall terminate.

7. Land Rights. Customer Generator hereby grants to Idaho Power for the term of this
Agreement all necessary rights-of-way and easements to install, operate, maintain, replace, and remove
Idaho Power’s Metering Equipment, Interconnection Equipment, Disconnection Equipment, Protection
Equipment and other Special Facilities necessary or useful to this Agreement, including adequate and
continuing access rights on the property of Customer Generator. Customer Generator warrants that it
has procured sufficient easements and rights-of-way from third parties so as to provide Idaho Power with
the access described above. All documents granting such easements or rights-of-way shall be subject
to Idaho Power’s approval and in recordable form.

Idaho Power Company First Revised Sheet No. 68-23
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 68-23
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

SECTION 4: ADDITIONAL INTERCONNECTION REQUIREMENTS OF DISTRIBUTED
ENERGY RESOURCES 3 MVA OR GREATER (Continued)

IDAHO POWER COMPANY
UNIFORM CUSTOMER GENERATOR
INTERCONNECTION AGREEMENT
(Continued)

AGREEMENT (Continued)

8. Assignment.

8.1 This Agreement may be assigned by either Party upon twenty-one (21) calendar
days prior written notice and opportunity to object by the other Party; provided that:

8.2 Either Party may assign this Agreement without the consent of the other Party to
any affiliate of the assigning Party with an equal or greater credit rating and with the legal authority
and operational ability to satisfy the obligations of the assigning Party under this Agreement.

8.3 The Customer Generator has the right to contingently assign this Agreement,
without the consent of the Company, for collateral security purposes to aid in providing financing
for the Generation Facility, provided that the Customer Generator will promptly notify the
Company of any such contingent assignment.

8.4 Any attempted assignment that violates this Section 6 is void and ineffective.
Assignment shall not relieve a Party of its obligations, nor shall the non-assigning Party’s
obligations be enlarged, in whole or in part, by reason thereof. An assignee is responsible for
meeting the same financial, credit, and insurance obligations as the Customer Generator. Where
required, consent to assignment will not be unreasonably withheld, conditioned or delayed.

9. Indemnity. To the fullest extent permitted by law, Customer Generator shall indemnify,
defend, reimburse, and hold harmless the Company and its successors and their respective directors,
officers, members, employees, representatives, and agents (collectively, the “Indemnitees”), from, for,
and against any and all third-party allegations, claims, liens, liabilities, losses, demands, damages,
expenses, suits, actions, proceedings, judgments, and costs of any kind whatsoever, including, without
limitation, settlement costs, court costs, and attorneys’ and expert witness fees and expenses
(collectively, “Damages”), whether actual or merely alleged, and whether directly incurred or incurred by
a third party, arising out of, or relating to a) the negligent acts, omissions, or willful misconduct of
Customer Generator, b) a violation of federal or state law, regulation, statute, or ordinance, or c)
Customer Generator’s material breach of this Agreement. If the Company seeks indemnification from
the Customer Generator, the Company shall: (i) notify Customer Generator of the assertion of any claim;
(ii) provide reasonable assistance (at Customer Generator’s expense) in connection with the defense;
and (iii) be entitled to pre-approve any settlement.

Idaho Power Company First Revised Sheet No. 68-24
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 68-24
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

SECTION 4: ADDITIONAL INTERCONNECTION REQUIREMENTS OF DISTRIBUTED ENERGY
RESOURCES 3 MVA OR GREATER (Continued)

IDAHO POWER COMPANY
UNIFORM CUSTOMER GENERATOR
INTERCONNECTION AGREEMENT
(Continued)

AGREEMENT (Continued)

9.1 The Parties shall at all times indemnify, defend, and hold the other Party harmless
from, any and all damages, losses, claims, including claims and actions relating to injury to or
death of any person or damage to property, demand, suits, recoveries, costs and expenses, court
costs, attorney fees, and all other obligations by or to third parties, arising out of or resulting from
the other Party’s action or failure to meet its obligations under this Agreement on behalf of the
indemnifying Party, except in cases of gross negligence or intentional wrongdoing by the
indemnified Party.

9.2 If an indemnified person is entitled to indemnification under this article as a result
of a claim by a third party, and the indemnifying Party fails, after notice and reasonable opportunity
to proceed under this article, to assume the defense of such claim, such indemnified person may
at the expense of the indemnifying Party contest, settle or consent to the entry of any judgment
with respect to, or pay in full, such claim. Failure to defend is a Material Breach.

9.3 If an indemnifying party is obligated to indemnify and hold any indemnified person
harmless under this article, the amount owing to the indemnified person shall be the amount of
such indemnified person’s actual loss, net of any insurance or other recovery.

10. Force Majeure Event. Neither Party shall be liable for any breach, default, or delay in
the performance of the obligations under this Agreement if and to the extent such default or delay is
caused by fire, flood, earthquake, elements of nature or acts of God, riots, civil disorder, rebellions or
revolutions, strikes, lockouts or other industrial disturbances, unanticipated changes in governmental
laws and regulations, or any other cause beyond the reasonable control of such Party (a “Force Majeure
Event”); provided the non-performing Party is without fault in causing such breach, default, or delay, and
such breach, default or delay could not have been prevented by reasonable precautions and cannot
reasonably be circumvented by the non-performing Party through the use of alternate sources, work-
around plans, or other means. The Party claiming a Force Majeure Event must give the other Party
immediate written notice, no later than five (5) calendar days of the Party’s discovery of the Force Majeure
Event, and the time for resumption of performance (if applicable) by that Party. The suspension of
performance shall be of no greater scope and of no longer duration than is required by the Force Majeure
Event.

Idaho Power Company First Revised Sheet No. 68-25
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 68-25
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

SECTION 4: ADDITIONAL INTERCONNECTION REQUIREMENTS OF DISTRIBUTED ENERGY
RESOURCES 3 MVA OR GREATER (Continued)

IDAHO POWER COMPANY
UNIFORM CUSTOMER GENERATOR
INTERCONNECTION AGREEMENT
(Continued)

AGREEMENT (Continued)

11. Insurance. During the term of this Agreement, Customer Generator shall secure and
continuously carry the following insurance coverage Comprehensive General Liability Insurance for both
bodily injury and property damage with limits equal to $1,000,000, each occurrence, combined single
limit. The deductible for such insurance shall be consistent with current Insurance Industry Utility
practices for similar property. Such insurance coverage shall be placed with an insurance company with
an A.M. Best Company rating of A- or better and shall include:

11.1 An endorsement naming Idaho Power as an additional insured and loss payee as
applicable; and

11.2 A provision stating that such policy shall not be canceled, or the limits of liability
reduced without sixty (60) days’ prior written notice to Idaho Power.

11.1 Customer Generator to Provide Certificate of Insurance. As required in
Paragraph 11 herein and annually thereafter, Customer Generator shall furnish the Company a
certificate of insurance, together with the endorsements required therein, evidencing the coverage
as set forth above.

11.2 Customer Generator to Notify Idaho Power of Loss of Coverage. If the insurance
coverage required by Paragraph 11.1 shall lapse for any reason, Customer Generator will
immediately notify Idaho Power in writing. The notice will advise Idaho Power of the specific
reason for the lapse and the steps Customer Generator is taking to reinstate the coverage.
Failure to provide this notice and to expeditiously reinstate or replace the coverage will constitute
grounds for a temporary disconnection under Section 9.2 and will be a Material Breach.

12. Miscellaneous.

12.1 Governing Law. This Agreement shall be interpreted, applied and enforced in
accordance with the laws of the State of Idaho without regard to its conflicts of law principles.

Idaho Power Company First Revised Sheet No. 68-26
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 68-26
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

SECTION 4: ADDITIONAL INTERCONNECTION REQUIREMENTS OF DISTRIBUTED ENERGY
RESOURCES 3 MVA OR GREATER (Continued)

IDAHO POWER COMPANY
UNIFORM CUSTOMER GENERATOR
INTERCONNECTION AGREEMENT
(Continued)

AGREEMENT (Continued)

12.2 Net Salvage Value. If removal of the Interconnection Facilities is required, within
sixty (60) days after the termination or expiration of this Agreement, Idaho Power will provide
Customer Generator an estimate of the remaining value of the Company-Furnished
Interconnection Facilities required under Schedule 68 and/or described in this Agreement, less
the cost of removal and transfer to Idaho Power’s warehouse (“Net Salvage Value”). If Customer
Generator elects not to purchase the Interconnection Facilities from the Company, Idaho Power
will reimburse the Customer Generator the Net Salvage Value as estimated by Idaho Power.
Customer Generator shall invoice Idaho Power for the same and Customer Generator shall have
the right to offset the invoice amount with amounts due to Idaho Power from Customer Generator.

13. Notices. Any changes to the below contacts must be made via written notice pursuant to
Section 13.1.

13.1 Written Notice. Where required herein, written notice shall be deemed to have
been duly served when (i) delivered in person, or (ii) sent by mail or courier, return receipt
requested, at the address for each Party as follows:

If to the Customer Generator:
Customer Generator:
Attention:
Address:
City: State: Zip:

If to the Company:
Company:
Attention:
Address:
City: State: Zip:

Idaho Power Company First Revised Sheet No. 68-27
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 68-27
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

SECTION 4: ADDITIONAL INTERCONNECTION REQUIREMENTS OF DISTRIBUTED ENERGY
RESOURCES 3 MVA OR GREATER (Continued)

IDAHO POWER COMPANY
UNIFORM CUSTOMER GENERATOR
INTERCONNECTION AGREEMENT
(Continued)

AGREEMENT (Continued)

13.2 Designated Operating Representative. The Parties may also designate an
operating representative to communicate regarding administration of this Agreement, as well as
operations and maintenance of such Party’s facilities; provided that, any “written notice” required
by this Agreement must be made as set forth in the above Section 13.1.

Customer Generator’s Operating Representative:
Customer Generator:
Attention:
Address:
City: State: Zip:
Phone: Email:

Company’s Operating Representative:
Company:
Attention:
Address:
City: State: Zip:
Phone: Email:

IN WITNESS WHEREOF, the Parties hereto enter this Uniform Customer Generator Agreement
to be effective as of the Effective Date.

Idaho Power Company
Print:
Sign:
Title:
Date:

Customer Generator
Print:
Sign:
Title:
Date:

Idaho Power Company First Revised Sheet No. 68-28
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 68-28
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

SECTION 4: ADDITIONAL INTERCONNECTION REQUIREMENTS OF DISTRIBUTED ENERGY
RESOURCES 3 MVA OR GREATER (Continued)

IDAHO POWER COMPANY
UNIFORM CUSTOMER GENERATOR
INTERCONNECTION AGREEMENT
(Continued)
Attachment 1

Description and Costs of the Customer Generator System, Interconnection Facilities and Metering
Equipment

In this attachment, the Customer Generator System and Interconnection Facilities, including
Special Facilities and upgrades, are itemized and identified as being owned by the Customer Generator
or the Company. As provided in Schedule 68, Cost of Interconnection Facilities, the Company will provide
a best estimate itemized cost of its Interconnection Facilities, including Special Facilities, upgrades and
Metering Equipment.

Attachment 2

One-line Diagram Depicting the Customer Generator System, Interconnection Facilities, Metering
Equipment and Upgrades

Attachment 3

Milestones

In-Service Date: ___________________

Critical milestones and responsibility as agreed to by the Parties:

Milestone/Date Responsible Party

(1) _______________________________________ ______________________
(2) _______________________________________ ______________________
(3) _______________________________________ ______________________
(4) _______________________________________ ______________________
(5) _______________________________________ ______________________
(6) _______________________________________ ______________________
(7) _______________________________________ ______________________
(8) _______________________________________ ______________________
(9) _______________________________________ ______________________
(10) _______________________________________ ______________________
Idaho Power Company

I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 68-29
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

SECTION 4: ADDITIONAL INTERCONNECTION REQUIREMENTS OF DISTRIBUTED ENERGY
RESOURCES 3 MVA OR GREATER (Continued)

IDAHO POWER COMPANY
UNIFORM CUSTOMER GENERATOR
INTERCONNECTION AGREEMENT
(Continued)

Attachment 3 (Continued)

Agreed to by:

For the Company __________________________ Date______________

For the Customer Generator________________________ Date______________

Attachment 4

Additional Operating Requirements for the Company’s Transmission System and Affected
Systems Needed to Support the Customer Generator’s Needs

The Company shall also provide requirements that must be met by the Customer Generator prior
to initiating Parallel operation with the Company’s Transmission System.

Attachment 5

Reactive Power Requirements

Idaho Power will determine the reactive power required to be supplied by the Company to the
Customer Generator, based upon information provided by the Customer Generator. The Company will
specify the equipment required on the Company’s system to meet the Facility’s reactive power
requirements. These specifications will include but not be limited to equipment specifications, equipment
location, Company-provided equipment, Customer Generator provided equipment, and all costs
associated with the equipment, design and installation of the Company-provided equipment. The
equipment specifications and requirements will become an integral part of this Agreement. The
Company-owned equipment will be maintained by the Company, with total cost of purchase, installation,
operation, and maintenance, including administrative cost to be reimbursed to the Company by the
Customer Generator. Payment of these costs will be in accordance with Schedule 68 and the total
reactive power cost will be included in the calculation of the monthly facilities charge.

Attachment 6

Company’s Description of Upgrades Required to Integrate the Generation Facility and Best
Estimate of Upgrade Costs

As provided in Schedule 68, this Attachment describes Upgrades, including best work upgrades,
and provides an itemized best estimate of the cost of the Upgrades.
Idaho Power Company First Second Revised Sheet No. 68-1
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original First Revised Sheet No. 68-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36802 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2026 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES

AVAILABILITY

Service under this schedule is available throughout the Company’s service area within the State
of Idaho to all Customer Generators owning or operating DERs, in Parallel with the Company’s system,
and located on the customer’s side of the Interconnection Point that qualify for Schedule 6, Schedule 8,
Schedule 84, or Non-Export as defined in this schedule. DERs with Total Nameplate Capacity of 3 MVA
or greater are required to sign a Uniform Customer Generator Interconnection Agreement.

APPLICABILITY

Service under this schedule applies to construction, operation, and maintenance of a Customer
Generator System interconnected in Parallel with the Company’s system. In limited circumstances,
certain interconnection requirements included in this schedule may not be applicable when the Company
determines the DER relies on a technology, such as regenerative drives, that does not jeopardize grid
stability or reliability. In making its determination, the Company will evaluate criteria such as the
magnitude and duration of exports.

DEFINITIONS

Company is the Idaho Power Company.

Company-Furnished Facilities are those portions of the Interconnection Facilities funded by the
Customer Generator and provided by the Company.

Customer Generator is a Customer or prospective Customer applying to operate or operating a
DER in Parallel with the Company’s system.

Customer Generator-Furnished Facilities are those portions of the Interconnection Facilities
provided by the Customer Generator.

Customer Generator Application Process are the steps a Customer Generator must complete to
interconnect DERs less than 3 MVA with the Company’s system unless they are eligible for and elect to
use the Customer Generator Registration Process.

Customer Generator Interconnection Process are the steps a Customer Generator must complete
to connect a DER to the Company’s system and includes the Customer Generator Applicaton Process.is
the Company’s DER interconnection application, engineering review, construction, and inspection
process for Customer Generator Systems. The Customer Generator Interconnection Process intends to
ensure a safe and reliable generation interconnection in compliance with all applicable regulatory
requirements, good utility practices, and national safety standards.

Customer Generator Registration Process are the steps a Customer Generator must complete to
interconnect DERs with the Company’s System when the DERs meet the eligibility requirements outlined
in Section 2.

Idaho Power Company First Second Revised Sheet No. 68-1
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original First Revised Sheet No. 68-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36802 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2026 1221 West Idaho Street, Boise, Idaho
Customer Generator System is an Exporting System, or a Non-Exporting System, or a system
eligible for the Customer Generator Registration Process.

Customer Representative is a person or entity identified by the Customer Generator who is
authorized to communicate with the Company on the Customer Generator’s behalf.

Disconnection Equipment is any device or combination of devices by which the Company can manually
and/or automatically interrupt the flow of energy from the Customer Generator to the Company’s system,
including enclosures or other equipment as may be required to ensure that only the Company will have
access to the devices.

Idaho Power Company First Second Revised Sheet No. 68-2
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original First Revised Sheet No. 68-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36802 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2026 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

DEFINITIONS (Continued)

Customer Representative is a person or entity identified by the Customer Generator who is
authorized to communicate with the Company on the Customer Generator’s behalf.

Disconnection Equipment is any device or combination of devices by which the Company can
manually and/or automatically interrupt the flow of energy from the Customer Generator to the Company’s
system, including enclosures or other equipment as may be required to ensure that only the Company
will have access to the devices.

Distributed Energy Resource(s) (DER(s)) is a source of electric power that is not directly
connected to the bulk power system. Any combination of Generation Facilities and/or Energy Storage
Devices connected in Parallel is considered a DER.

Energy Storage Device is a device that captures energy produced at a point in time and stores
the energy for use as electricity at a future point in time. An Energy Storage Device is a DER.

Exporting System is a Customer-owned DER under the terms of Schedules 6, 8, or 84, which is
designed to provide for the transfer of electric energy to the Company.

Feasibility Review is the Company’s standard engineering review of a proposed Customer
Generator System and is intended to ensure the Company’s system is equipped to incorporate the
proposed Customer Generator-Furnished Facilities in a manner that conforms with good utility practices
and the National Electric Safety Code.

Feasibility Study is the Company’s more detailed engineering assessment for DERs as
determined by the Feasibility Review. This study is intended to ensure that the Company’s system is
sufficiently equipped to incorporate proposed DERs in a manner that conforms with good utility practices
and the National Electric Safety Code, including protection coordination and system voltage
management.

Generation Facility means equipment used to produce electric energy at a specific physical
location and service point that qualifies for Schedules 6, 8, 84, or Non-Export. A Generation Facility is a
DER.

Inadvertent Export is the unplanned, unscheduled, and uncompensated transfer of electrical
energy from a Customer’s Non-Exporting System to the Company’s system across the Interconnection
Point.

Incomplete Application or Registration Form is an application or registration form missing any
information needed to satisfy the requirements of the Customer Generator Interconnection Process;
including but not limited to, Customer Generator signature, the application fee, and details about the
Generation Facility.

Idaho Power Company First Second Revised Sheet No. 68-2
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original First Revised Sheet No. 68-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36802 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2026 1221 West Idaho Street, Boise, Idaho
Interconnection Facilities are all facilities which are reasonably required by good utility practices
and the National Electric Safety Code to interconnect and to allow for Parallel operations of the DER with
the Company’s system, including, but not limited to, Special Facilities, Disconnection Equipment, and
Metering Equipment.

Interconnection Point is the point where the Customer Generator’s conductors connect to the
facilities owned by the Company.

Metering Equipment is the Company owned equipment required to measure, record or telemeter
power flows between the Customer Generator and the Company’s system.

Idaho Power Company Original First Revised Sheet No. 68-3
Cancels
I.P.U.C. No. 30, Tariff No. 101 First Revised Original Sheet No. 68-3
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36067 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

DEFINITIONS (Continued)

Interconnection Facilities are all facilities which are reasonably required by good utility practices
and the National Electric Safety Code to interconnect and to allow for Parallel operations of the DER with
the Company’s system, including, but not limited to, Special Facilities, Disconnection Equipment, and
Metering Equipment.

Interconnection Point is the point where the Customer Generator’s conductors connect to the
facilities owned by the Company.

Like-for-Like Inverter Replacement is when a Customer Generator replaces an existing inverter
with an inverter of the same make, model, and capacity, without making any additional system
modifications.

Metering Equipment is the Company owned equipment required to measure, record or telemeter
power flows between the Customer Generator and the Company’s system.

Non-Exporting System is a Customer-owned DER that limits or prevents electrical energy from
transferring to the Company’s system.

Parallel connection means operating a DER that is connected to and receives voltage from Idaho
Power’s system.

Protection Equipment is the equipment, hardware, and/or software necessary to ensure the
protection of the Company’s system and could include a circuit-interrupting device, protective relaying,
instrument transformers, and associated wiring.

Relocation is a change in the location of existing Company-owned transmission and/or distribution
lines, poles, or equipment.

Smart Inverter is an inverter that conforms to the latest IEEE 1547 standards and is certified by
the UL 1741 standard, which complies with the latest IEEE 1547 standards.

Special Facilities are additions to or alterations of transmission and/or distribution lines and
transformers, including, but not limited to, Upgrades and Relocation, to safely interconnect the
Customer’s DER to the Company’s system.

System Verification Form is the form that a Customer must provide to the Company prior to the
connection of the Customer Generator System as part of the Customer Generator Application Process
as described in this schedule.

Total Nameplate Capacity is the total of the gross capacity of a DER as designated by the
manufacturer(s) maximum continuous operating rating of the DER in Alternating Current (AC), or as
determined by Idaho Power based on information provided on the application and System Verification
Form or registration form.

Idaho Power Company Original First Revised Sheet No. 68-3
Cancels
I.P.U.C. No. 30, Tariff No. 101 First Revised Original Sheet No. 68-3
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36067 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho
Upgrades are those improvements to the Company’s existing system, which are reasonably
required by good practices and the National Electric Safety Code to interconnect the Customer Generator
System safely. Such improvements include, but are not limited to, additional or larger conductors,
transformers, poles, and related equipment.

Idaho Power Company First Second Revised Sheet No. 68-4
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original First Revised Sheet No. 68-4
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36802 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2026 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

DEFINITIONS (Continued)

Upgrades are those improvements to the Company’s existing system, which are reasonably
required by good practices and the National Electric Safety Code to interconnect the Customer Generator
System safely. Such improvements include, but are not limited to, additional or larger conductors,
transformers, poles, and related equipment.

SECTION 1: GENERAL INTERCONNECTION REQUIREMENTS

The following provisions apply to all Customer Generators requesting interconnection to the
Company’s system.

CONSTRUCTION AND OPERATION OF INTERCONNECTION FACILITIES

All Customer Generator-Furnished Interconnection Facilities will be constructed and maintained
in a manner as determined by the Company to be in full compliance with all good utility practices,
including the Company’s Customer Requirements for Electric Service (found at
idahopower.com/requirements), National Electric Safety Code, conforms to the IEEE 1547 standards,
and all other applicable federal, state, and local safety and electrical codes and standards at all times.

The Customer Generator shall:

1. Upon request, submit proof to the Company that all licenses, permits, inspections, and
approvals necessary for the construction and operation of the Customer’s DER and Interconnection
Facilities under this schedule have been obtained from applicable federal, state, or local authorities.

2. Upon request, submit the designs, plans, specifications, settings, and performance data
for the DER and Customer Generator-Furnished Facilities to the Company for review. The Company’s
acceptance shall not be construed as confirming or endorsing the design, or as a warranty of safety,
durability, or reliability of the DER or Customer Generator-Furnished Facilities. The Company will retain
the right to inspect this equipment at its discretion.

3. Demonstrate to the Company’s satisfaction that the Customer’s DER and Customer
Generator-Furnished Facilities have been completed, and that all features and equipment of the
Customer’s DER and Customer Generator-Furnished Facilities are capable of operating safely to
commence deliveries of energy into the Company’s system.

4. Should a Customer move a DER to a new service point, the Customer must initiate and
complete the Customer Generator Interconnection Process.

5. DERs must be listed by UL or other recognized standards, that may include but are not
limited to UL 1741 SB, IEEE 1547-2018, UL 3700 and UL 3141.

46. Provide and maintain adequate Protection Equipment sufficient to prevent damage to the
DER, Customer Generator-Furnished Facilities, and any other Customer Generator-owned facilities in
conformance with all applicable electrical and safety codes and requirements.
Idaho Power Company First Second Revised Sheet No. 68-4
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original First Revised Sheet No. 68-4
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36802 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2026 1221 West Idaho Street, Boise, Idaho

5. Provide and maintain Disconnection Equipment in accordance with all applicable electrical
and safety codes and requirements as described within this Schedule.

6. Upon request, provide a 24-hour telephone contact(s). This contact will be used by the
Company to arrange for repairs and inspections or in case of an emergency. The Company will make its
best effort to arrange repairs and inspections during normal business hours and to notify the Customer
Generator of such arrangements in advance. The Company will provide a telephone number to the
Customer Generator so that the Customer Generator can obtain information about Company activity
impacting the Customer’s DER.

Idaho Power Company Original First Revised Sheet No. 68-5
Cancels
I.P.U.C. No. 30, Tariff No. 101 First RevisedOriginal Sheet No. 68-5
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36067 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

SECTION 1: GENERAL INTERCONNECTION REQUIREMENTS (Continued)

7. Provide and maintain Disconnection Equipment as required by the Company in
accordance with all applicable electrical and safety codes and requirements as described within this
Schedule.

68. Upon request, provide a 24-hour telephone contact(s). This contact will be used by the
Company to arrange for repairs and inspections or in case of an emergency. The Company will make its
best effort to arrange repairs and inspections during normal business hours and to notify the Customer
Generator of such arrangements in advance. The Company will provide a telephone number to the
Customer Generator so that the Customer Generator can obtain information about Company activity
impacting the Customer’s DER.

DISCONNECTION EQUIPMENT

Disconnection Equipment is required for all Customer DERs initially subject to the Customer
Generator Application Process. The Disconnection Equipment shall be installed at an electrical location
to allow complete isolation of Customer’s DER and Interconnection Facilities from the Company’s system.
Disconnection Equipment will be installed at an electrical location on the Customer Generator’s side of
the Company’s retail metering point to allow complete isolation of the Customer’s DER and
Interconnection Facilities from the Customer Generator’s other electrical load and service.

The Disconnection Equipment’s operating device shall be:

1. Readily accessible by the Company at all times.

2. Clearly marked “Generation Disconnect Switch” or similar language, as approved by Idaho
Power, with permanent 3/8 inch or larger letters.

3. Physically installed and visible within 10 feet of the Interconnection Point or permanently-
posted instructions at the Interconnection Point indicating the exact location of the Disconnection
Equipment’s operating device. Instructions with lamination or in plastic sleeves do not satisfy this
requirement.

4. Of a design manually operated and lockable in the open position with a standard Company
padlock.

5. Equipped with a visual disconnect that enables the Company to visually confirm that the
Customer’s and Company’s conductors are physically disconnected. This requires the ability to inspect
the actual conductors visually. Circuit breakers do not satisfy this requirement.

6. Disconnection Equipment meeting the requirements in this section is recommended but
not required for inverter-based systems without Energy Storage Devices where the aggregate Total
Nameplate Capacity of all DERs behind the Customer’s meter does not exceed 400 Volt-Amps AC and
where the Customer takes metered service under Schedules 1, 5, or 7.

Idaho Power Company Original First Revised Sheet No. 68-5
Cancels
I.P.U.C. No. 30, Tariff No. 101 First RevisedOriginal Sheet No. 68-5
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36067 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho
Operation of Disconnection Equipment. If, in the reasonable opinion of the Company, the
Customer Generator’s operation or maintenance of the DER or Interconnection Facilities is unsafe, not
in compliance with this schedule, or may otherwise adversely affect the Company’s equipment,
personnel, or service to its customers, the Company may physically disconnect the Customer’s DER or
Interconnection Facilities by operation of the disconnection device or by any other means the Company
deems necessary to adequately disconnect the Customer’s DER and Interconnection Facilities from the
Company’s system. At such time as the unsafe condition is remedied or other condition adversely
affecting the Company is resolved to the Company’s satisfaction, the interconnection will be restored.

The Company will disconnect the Customer’s DER and Interconnection Facilities in the event of
any planned or unplanned maintenance or repair of the Company’s system connected to the Customer’s
DER and Interconnection Facilities. In the event of unplanned maintenance or repairs, no prior notice
will be provided. In the event of planned repairs, the Company will attempt to notify the Customer
Generator of the time and duration of the planned outage.

Idaho Power Company Original First Revised Sheet No. 68-6
Cancels
I.P.U.C. No. 30, Tariff No. 101 First RevisedOriginal Sheet No. 68-6
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36067 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

SECTION 1: GENERAL INTERCONNECTION REQUIREMENTS (Continued)

DISCONNECTION EQUIPMENT (Continued)

Operation of Disconnection Equipment. If, in the reasonable opinion of the Company, the
Customer Generator’s operation or maintenance of the DER or Interconnection Facilities is unsafe, not
in compliance with this schedule, or may otherwise adversely affect the Company’s equipment,
personnel, or service to its customers, the Company may physically disconnect the Customer’s DER or
Interconnection Facilities by operation of the disconnection device or by any other means the Company
deems necessary to adequately disconnect the Customer’s DER and Interconnection Facilities from the
Company’s system. At such time as the unsafe condition is remedied or other condition adversely
affecting the Company is resolved to the Company’s satisfaction, the interconnection will be restored.

The Company will disconnect the Customer’s DER and Interconnection Facilities in the event of
any planned or unplanned maintenance or repair of the Company’s system connected to the Customer’s
DER and Interconnection Facilities. In the event of unplanned maintenance or repairs, no prior notice
will be provided. In the event of planned repairs, the Company will attempt to notify the Customer
Generator of the time and duration of the planned outage.

The Company will disconnect the Customer’s DER and Interconnection Facilities in the event that
any terms and conditions of any applicable Company tariff or contract enabling the interconnection of the
Customer’s DER are deemed by the Company to be in default or delinquent.

Customer Generators will be subject to disconnection and reconnection charges if the expenses
are incurred as the result of a DER and/or a Customer’s failure to abide by the provisions of Schedule
68.

Disconnection of the service may be necessary. The disconnection may result in the interruption
of both energy deliveries from the Customer Generator System to the Company as well as the interruption
of energy deliveries from the Company to the Customer Generator. Disconnection provisions specific to
DERs less than 3 MVA are described further in Section 2 of this schedule. Disconnection provisions
specific to DERs 3 MVA or greater are described further in Section 4 of this schedule.

The Company will establish the settings of Protection Equipment to disconnect the Customer’s
DER and Interconnection Facilities for the protection of the Company’s system and personnel consistent
with good utility practices. If the Customer Generator attempts to modify, adjust or otherwise interfere
with the Protection Equipment or its settings as established by the Company, such action may be grounds
for the Company’s refusal to continue interconnection of the Customer’s DER and Interconnection
Facilities to the Company’s system.

GENERAL REQUIREMENTS OF CUSTOMER GENERATOR SYSTEMS
Idaho Power Company Original First Revised Sheet No. 68-6
Cancels
I.P.U.C. No. 30, Tariff No. 101 First RevisedOriginal Sheet No. 68-6
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36067 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

1. The Company will construct, own, operate and maintain all equipment, Upgrades, and
Relocations on the Company’s electrical side of the Interconnection Point.

2. The Company will clearly mark the Metering Equipment and any other Company
equipment associated with the Customer’s DER and/or Interconnection Facilities designating the
existence of the Customer’s DER as required by good utility practices.

3. The Customer Generator will be required to submit all specific designs, equipment
specifications/settings, and test results of the Customer Generator-Furnished Facilities to the Company
for review upon request by the Company. Upon receipt of the design and equipment specifications, the
Company will review the design and equipment specifications for conformance with applicable electrical
and safety codes and standards.

4. Customer Generator-Furnished Facilities will be operated and maintained by the
Customer Generator at the Customer Generator’s sole risk and expense.

Idaho Power Company Original First Revised Sheet No. 68-7
Cancels
I.P.U.C. No. 30, Tariff No. 101 First RevisedOriginal Sheet No. 68-7
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36067 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

SECTION 1: GENERAL INTERCONNECTION REQUIREMENTS (Continued)

GENERAL REQUIREMENTS OF CUSTOMER GENERATOR SYSTEMS

1. The Company will construct, own, operate and maintain all equipment, Upgrades, and
Relocations on the Company’s electrical side of the Interconnection Point.

2. The Company willmay clearly mark the Metering Equipment and any other Company
equipment associated with the Customer’s DER and/or Interconnection Facilities designating the
existence of the Customer’s DER as required by good utility practices.

3. The Customer Generator will be required to submit all specific designs, equipment
specifications/settings, and test results of the Customer Generator-Furnished Facilities to the Company
for review upon request by the Company. Upon receipt of the design and equipment specifications, the
Company will review the design and equipment specifications for conformance with applicable electrical
and safety codes and standards.

4. Customer Generator-Furnished Facilities will be operated and maintained by the
Customer Generator at the Customer Generator’s sole risk and expense. The Company’s review of any
Customer attestations or subsequent approval to proceed does not transfer liability to the Company for
any damages or injury caused by the DER. The Company shall not be liable directly or indirectly for
permitting or continuing to allow an attachment of a Customer Generator System to the Company’s
system, or for the acts or omissions of a Customer DER that cause loss or injury, including death, to any
third party.

INVERTER REQUIREMENTS

All inverter-based Customer Generator Systems must use a Smart Inverter programmed with the
required settings described in the following section. System Modifications that (1) do not replace or add
inverters, (2) are the result of warranty inverter replacements, or (3) rely on an inverter that is required to
meet the original inverter specifications for the Customer Generator System to properly function, may be
considered exempt from this requirement.

INVERTER SETTINGS

All inverter-based Customer Generator System Smart Inverters will be set for normal operating
performance Category B as defined in IEEE 1547, with the default reactive power control mode set for
the Voltage-reactive power mode and the parameters listed in Table 1. All inverter-based Customer
Generator System Smart Inverters will be set for abnormal voltage and ride through operating
performance Category III as defined in IEEE 1547 using the default settings. The remaining Smart
Inverter settings will be set to the default values specified in IEEE 1547. Inverter setting documentation
will be required for all DERs with a Total Nameplate Capacity of 100 kVA or greater.

Idaho Power Company Original First Revised Sheet No. 68-7
Cancels
I.P.U.C. No. 30, Tariff No. 101 First RevisedOriginal Sheet No. 68-7
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36067 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho
Table 1: VOLTAGE-REACTIVE POWER SETTINGS FOR SMART INVERTERS
Voltage-reactive power parameters Default Settings
V1 0.92 per unit of nominal voltage
Q1 44% of nameplate apparent power rating, injecting
V2 0.98 per unit of nominal voltage
Q2 0
V3 1.03 per unit of nominal voltage
Q3 0
V4 1.06 per unit of nominal voltage
Q4 44% of nameplate apparent power rating, absorption
Open-loop response time 5 seconds

ENERGY STORAGE DEVICE

Energy Storage Devices may share an inverter with a Generation Facility (“DC Coupled”), or
Energy Storage Devices may have a stand-alone inverter (“AC Coupled”). Energy Storage Devices that
are not coupled with a Generation Facility taking service under Schedules 6, 8, or 84 may not export
energy onto Idaho Power’s system. The Total Nameplate Capacity is determined as follows:

1. DC Coupled: For Energy Storage Devices that are DC Coupled with a Generation Facility,
the Total Nameplate Capacity of the Customer Generator System is defined by the inverter (kVA). A DC
coupled system can be an Exporting or Non-Exporting system.
Idaho Power Company First Second Revised Sheet No. 68-8
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original First Revised Sheet No. 68-8
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36802 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2026 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

SECTION 1: GENERAL INTERCONNECTION REQUIREMENTS (Continued)

Table 1: VOLTAGE-REACTIVE POWER SETTINGS FOR SMART INVERTERS
Voltage-reactive power parameters Default Settings
V1 0.92 per unit of nominal voltage
Q1 44% of nameplate apparent power rating, injecting
V2 0.98 per unit of nominal voltage
Q2 0
V3 1.03 per unit of nominal voltage
Q3 0
V4 1.06 per unit of nominal voltage
Q4 44% of nameplate apparent power rating, absorption
Open-loop response time 5 seconds

ENERGY STORAGE DEVICE

Energy Storage Devices may share an inverter with a Generation Facility (“DC Coupled”), or
Energy Storage Devices may have a stand-alone inverter (“AC Coupled”). Energy Storage Devices that
are not coupled with a Generation Facility taking service under Schedules 6, 8, or 84 may not export
energy onto Idaho Power’s system. The Total Nameplate Capacity is determined as follows:

1. DC Coupled: For Energy Storage Devices that are DC Coupled with a Generation Facility,
the Total Nameplate Capacity of the Customer Generator System is defined by the inverter (kVA). A DC
coupled system can be an Exporting or Non-Exporting system.

ENERGY STORAGE DEVICE (Continued)

2. AC Coupled:

i. AC Coupled with an Exporting System: For an Energy Storage Device coupled
with an Exporting System taking service under Schedules 6, 8, or 84, the Total Nameplate
Capacity is the aggregate Total Nameplate Capacity of all DERs on the Customer’s side of the
Interconnection Point.

ii. AC Coupled with a Non-Exporting System: An Energy Storage Device coupled
with a Non-Exporting System is subject to the provisions of Section 3 of this Schedule. The Total
Nameplate Capacity of the Energy Storage Device shall be considered 0 kVA.

Idaho Power Company First Second Revised Sheet No. 68-8
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original First Revised Sheet No. 68-8
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36802 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2026 1221 West Idaho Street, Boise, Idaho
APPLICATION EXPIRATION

Applications from a Customer Generator with existing retail service that are not completed within
one year of the initial Feasibility Review are considered expired. Applications from a Customer Generator
without existing retail service that has not completed the Customer Generator Interconnection Process
requirements by the requested project in-service date identitifed on the completed application will be
considered expired.

Customer Generators requesting connection or approval of expired applications are required to
resubmit a completed application form and a $100 non-refundable application fee and are subject to the
full application process described in Section 2.

RECERTIFICATION

1. The Company may perform full recertification inspections of Customer Generator Systems
at the Company’s discretion and at no charge to the Customer Generator. The Company will provide the
Customer Generator with written notice at least fourteen (14) calendar days prior to performing a
recertification inspection. Recertification inspections will be performed in the same manner as new
Customer Generator System inspections described in Section 2. Customers may choose to verify the
results of the Company’s inspection through an independent inspection performed by a certified third-
party at the Customer Generator’s expense.

2. If in the reasonable opinion of the Company, the Customer Generator’s operation or
maintenance of the DER or Interconnection Facilities is unsafe, not in compliance with this schedule, or
may otherwise adversely affect the Company’s equipment, personnel, or service to its customers, the
Company reserves the right to inspect any Customer Generator System at any time, and without prior
notice.

Idaho Power Company First Second Revised Sheet No. 68-9
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original First Revised Sheet No. 68-9
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36802 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2026 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

SECTION 1: GENERAL INTERCONNECTION REQUIREMENTS (Continued)

APPLICATION EXPIRATION

Applications from a Customer Generator with existing retail service that are not completed within
one year of the initial Feasibility Review are considered expired. Applications from a Customer Generator
without existing retail service that has not completed the Customer Generator Interconnection Process
requirements by the requested project in-service date identitifedidentified on the completed application
will be considered expired.

Registration forms from a Customer Generator with existing retail service that are not completed
within one year of receipt are considered expired.

Customer Generators requesting connection or approval of expired applications are required to
resubmit a completed application form and a $100 non-refundable application fee and are subject to the
full application process described in Section 2.

RECERTIFICATION

1. The Company may perform full recertification inspections of Customer Generator Systems
at the Company’s discretion and at no charge to the Customer Generator. The Company will provide the
Customer Generator with written notice at least fourteen (14) calendar days prior to performing a
recertification inspection. Recertification inspections will be performed in the same manner as new
Customer Generator System inspections described in Section 2. Customers may choose to verify the
results of the Company’s inspection through an independent inspection performed by a certified third-
party at the Customer Generator’s expense.

2. If in the reasonable opinion of the Company, the Customer Generator’s operation or
maintenance of the DER or Interconnection Facilities is unsafe, not in compliance with this schedule, or
may otherwise adversely affect the Company’s equipment, personnel, or service to its customers, the
Company reserves the right to inspect any Customer Generator System at any time, and without prior
notice.

SYSTEM MODIFICATIONS

1. Any modifications to Customer Generator Systems that increase the Total Nameplate
Capacity of the system or modify the system in any way (including inverter replacements) that may impact
the safety or reliability of the Company’s electrical system are considered system modifications for the
purposes of this schedule.

2. Customer Generators planning to make system modifications must complete the
Customer Generation Interconnection Process including submitting applicable forms and feessubmit an
application, a $100 non-refundable fee, and complete the application process according to the
procedures required for new interconnection.

Idaho Power Company First Second Revised Sheet No. 68-9
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original First Revised Sheet No. 68-9
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36802 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2026 1221 West Idaho Street, Boise, Idaho

3. System modifications without gaining prior Company approval are considered
unauthorized installations subject to the provisions of this schedule as described in Unauthorized
Installations and Expansions.

UNAUTHORIZED INSTALLATIONS AND EXPANSIONS

1. Customer Generator Systems that have been interconnected to the Company’s system
without Company approval are considered unauthorized installations that jeopardize the reliability of
Idaho Power’s system and the safety of its employees. This includes, but is not limited to, newly installed
systems and unapproved expansions or other modifications of approved systems. The process
described herein provides the Company with the ability to offer Customer Generation in an efficient, safe,
and reliable manner.

2. Unauthorized installations are subject to immediate Company inspection and
disconnection without notice. The Company will provide the reason for the disconnection of the
Customer’s DER. The Customer will be called and written, or electronic notification will be sent. The
Customer will have twelve (12) months from the notification date to notify the Company and complete
one of the options listed under 5(a) and 5(b).

3. If proper disconnection equipment is present, the Company will open the disconnect or
notify the Customer to open the disconnect immediately.

4. If proper disconnection equipment is not present, the Customer Generator must
disconnect the DER from operating in Parallel with the Company’s system immediately by turning off the
breaker or by other means necessary.

5. The Customer must complete and notify the Company of one of the below options within
twelve (12) months from the notification date:

a. Option 1: Complete the full Customer Generator Interconnection Process
described in Section 2, and the system will be re-energized.
Idaho Power Company First Second Revised Sheet No. 68-10
Cancels
I.P.U.C. No. 30, Tariff No. 101Original First Revised Sheet No. 68-10
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36802 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2026 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

SECTION 1: GENERAL INTERCONNECTION REQUIREMENTS (Continued)

SYSTEM MODIFICATIONS (Continued)

3. System modifications without gaining prior Company approval are considered
unauthorized installations subject to the provisions of this schedule as described in Unauthorized
Installations and Expansions.

UNAUTHORIZED INSTALLATIONS AND EXPANSIONS

1. Customer Generator Systems that have been interconnected to the Company’s system
without Company approval are considered unauthorized installations that jeopardize the reliability of
Idaho Power’s system and the safety of its employees. This includes, but is not limited to, newly installed
systems and unapproved expansions or other modifications of approved systems. The process
described herein provides the Company with the ability to offer Customer Generation in an efficient, safe,
and reliable manner.

2. Unauthorized installations are subject to immediate Company inspection and
disconnection without notice. The Company will provide the reason for the disconnection of the
Customer’s DER. The Customer will be called and written, or electronic notification will be sent. The
Customer will have twelve (12) months from the notification date to notify the Company and complete
one of the options listed under 5(a) and 5(b).

3. If proper disconnection equipment is present, the Company will open the disconnect or
notify the Customer to open the disconnect immediately.

4. If proper disconnection equipment is not present, the Customer Generator must
disconnect the DER from operating in Parallel with the Company’s system immediately by turning off the
breaker or by other means necessary.

5. The Customer must complete and notify the Company of one of the below options within
twelve (12) months from the notification date:

a. Option 1: Complete the full Customer Generator Interconnection Process
described in Section 2, and the system will be re-energized.

UNAUTHORIZED INSTALLATIONS AND EXPANSIONS (Continued)

b. Option 2: Permanently disable the DER from Parallel operations with the
Company system. Permanent disablement of the DER requires an inspection to be scheduled
with the Company within twelve (12) months from the postmarked notification date. Customers
that do not meet this deadlineschedule within this time period will be subject to termination of
service. Permanent disablement of the DER may require an inspection or other attestation from
the Customer Generator that the system is disabled.

Idaho Power Company First Second Revised Sheet No. 68-10
Cancels
I.P.U.C. No. 30, Tariff No. 101Original First Revised Sheet No. 68-10
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36802 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2026 1221 West Idaho Street, Boise, Idaho

6. If it is determined, at the sole discretion of the Company, that an unauthorized Customer
Generation System, expansion, or other system modification results in damage to equipment on the
Company’s system, the Customer will be responsible for all costs associated with replacing the
Company’s damaged equipment and defend, indemnify, and reimburse the Company for liabilities or
damages incurred by the Company for third-party claims arising out of the Customer Generator’s
unauthorized connection.

PERMANENTLY REMOVED OR DISABLED SYSTEMS

The Customer shall notify the Company immediately if a DER is permanently removed or
disabled. Permanent removal or disablement for the purposes of this Schedule is any removal or
disablement of a DER lasting longer than six (6) months. If the Customer wishes to interconnect the DER
after six (6) months, the Customer Generator must reapply and meet the interconnection requirements
in place at the time of application.

SECTION 2: INTERCONNECTION PROCESS REQUIREMENTS FOR DISTRIBUTED ENERGY
RESOURCES LESS THAN 3 MVA

The following section is applicable to all DERs with Total Nameplate Capacity less than 3 MVA.

APPLICATION PROCESS

Customer Generators requesting to interconnect a DER less than 3 MVA are required to complete
the following application process prior to interconnection:

1. Customer Generators must submit a completed application form and a $100 non-
refundable application fee to the Company. Applications are available on the Company’s website or will
be provided to the Customer upon request. Incomplete Applications are considered withdrawn after sixty
(60) days from the date the application was received.

2. Upon receipt of a completed application and a $100 non-refundable fee, the Company will
either (1) provide the Customer with a written or electronic notification that the application has been
received and all necessary information has been provided, or (2) request the Customer provide forms of
documentation outlined in Section 1.

Idaho Power Company First Second Revised Sheet No. 68-11
Cancels
I.P.U.C. No. 30, Tariff No. 101Original First Revised Sheet No. 68-11
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2026 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

SECTION 1: GENERAL INTERCONNECTION REQUIREMENTS (Continued)

UNAUTHORIZED INSTALLATIONS AND EXPANSIONS (Continued)

6. If it is determined, at the sole discretion of the Company, that an unauthorized Customer
Generation System, expansion, or other system modification results in damage to equipment on the
Company’s system, the Customer will be responsible for all costs associated with replacing the
Company’s damaged equipment and defend, indemnify, and reimburse the Company for liabilities or
damages incurred by the Company for third-party claims arising out of the Customer Generator’s
unauthorized connection.

PERMANENTLY REMOVED OR DISABLED SYSTEMS

The Customer shall notify the Company immediately if a DER is permanently removed or
disabled. Permanent removal or disablement for the purposes of this Schedule is any removal or
disablement of a DER lasting longer than six (6) months. If the Customer wishes to interconnect the DER
after six (6) months, the Customer Generator must reapply and meet the interconnection requirements
in place at the time of application.

SECTION 2: INTERCONNECTION PROCESS REQUIREMENTS FOR DISTRIBUTED ENERGY
RESOURCES LESS THAN 3 MVA

Customer Generators requesting to interconnect a DER less than 3 MVA shall complete the
Application Process prior to interconnection unless they are eligible for and elect to use the Customer
Generator Registration Process. The following section is applicable to all DERs with Total Nameplate
Capacity less than 3 MVA.

It is within Idaho Power’s sole discretion to disconnect, or refuse to connect, any Customer
Generator System that does not pass inspection, poses a threat to public safety, or has unanticipated
impacts to Idaho Power’s system. In these situations, a Company representative will send a written
communication to the Customer Generator regarding Idaho Power’s inability to connect/reconnect the
Customer Generator System until the issue(s) is resolved. Idaho Power will continue working with the
Customer to resolve the issue(s) required to connect the Customer’s System. Idaho Power will re-inspect
the System upon receiving notice from the Customer indicating Customer’s Generation System meets all
applicable federal, state, and local requirements and is suitable for connection.

REGISTRATION PROCESS

Customers with DERs that meet one of the following eligibility requirements may use the Customer
Generator Registration Process:
 Inverter based systems without Energy Storage Devices where the aggregate Total
Nameplate Capacity of all DERs behind the Customer’s meter does not exceed 400 VA
AC and where the Customer has active and continues to take metered service under
Schedules 1, 5, or 7.
 Like-For-Like Inverter Replacements.

APPLICATION PROCESS (Continued)
Idaho Power Company First Second Revised Sheet No. 68-11
Cancels
I.P.U.C. No. 30, Tariff No. 101Original First Revised Sheet No. 68-11
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2026 1221 West Idaho Street, Boise, Idaho

If the DER system components, capacity, or configuration changes from the original application,
the Customer Generator will be subject to a new Feasibility Review.

If the Customer Generator changes its Customer Representative, a new application and a $100
non-refundable application fee is required.

3. The Company will perform within seven (7) business days, unless it is determined that
additional studies are necessary, the Feasibility Review based on Total Nameplate Capacity and other
project information provided in the application. The Feasibility Review determines the capability of the
Company’s electrical system to incorporate the proposed Customer Generator System and determines
if Upgrades are necessary. For a Customer Generator who does not yet have established service, the
Feasibility Review will occur as part of the Company’s evaluation for Upgrades for new customers
conducted in compliance with Rule H – New Service Attachments and Distribution Line Installations or
Alterations.

a. If the results of the Feasibility Review indicate satisfactory system capability, the
Company will provide the Customer with an official “Approval to Proceed” notification.

b. If the results of the Feasibility Review indicate that Upgrades are necessary to
accommodate the proposed project, the Company will notify the Customer through written or
electronic notification of such Upgrades. Funding, construction, installation, and maintenance of
required Upgrades will be subject to the Company’s standard Rule H regarding New Service
Attachments and Distribution Line Installations or Alterations.

c. If the Company determines that additional time is necessary to determine
satisfactory system capability or that Upgrades are necessary to accommodate the proposed
project, the Company will notify the Customer. The Company will perform within fifteen (15)
business days the additional studies to complete the Feasibility Review.

4. If the results of the Feasibility Review require the need for a Feasibility Study, the
Company will provide the Customer with a Feasiblity Study Agreement which requires a deposit of $1,000
and must be signed and returned within fifteen (15) business days. Upon receipt of the signed Feasibility
Study Agreement and deposit, the Company will perform the Feasiblity Study within thirty (30) business
days. If the results of the Feasibility Study indicate that Upgrades or Protection Equipment are necessary
to accommodate the proposed project, the Company will notify the Customer of such Upgrades or
Protection Equipment. At the Company’s discretion, additional studies referenced in Section 4 may be
applicable.

a. Installation and funding of the construction, installation, and maintenance
of required Protection Equipment will be subject to the following provisions:

Idaho Power Company First Second Revised Sheet No. 68-12
Cancels
I.P.U.C. No. 30, Tariff No. 101OriginalFirst Revised Sheet No. 68-12
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36802 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2026 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

SECTION 2: INTERCONNECTION PROCESS REQUIREMENTS FOR DISTRIBUTED ENERGY
RESOURCES LESS THAN 3 MVA (Continued)

REGISTRATION PROCESS (Continued)

Customers Generators using the Customer Generator Registration Process are required to submit an
applicable registration form to the Company providing information about the DER and certifying
compliance with Schedule 68. Registration forms are available on the Company’s website or will be
provided to the Customer by email or mail upon request. Incomplete Registration Forms are considered
withdrawn after sixty (60) days from the date the form was received.

The Company will review the registration form within seven (7) business days and inform the
Customer:

i. If additional information is needed in order to review the DER. Additional information may
include but is not limited to single lines diagrams or product specification sheets. A
registration form will be considered incomplete until the information is provided.
ii. If the DER does not meet the requirements of Schedule 68.
iii. If Upgrades are needed in order to approve the project. Upgrades will be subject to Section
2, Part 3 and Part 4 of Schedule 68.
iv. If additional time is needed to review the registration, the Company may request an
additional fifteen (15) business days.
v. If the project is approved to interconnect.

The Customer Generator Registration Process is complete when the Company confirms in writing
that the Customer Generator System is registered with Idaho Power.

If the DER system components, capacity, or configuration changes from the original registration
form, the Customer Generator must resubmit a registration form that will be subject to a new review.

APPLICATION PROCESS

Customer Generators requesting to interconnect a DER less than 3 MVA are required to complete
the following application process prior to interconnection:Customers Generators using the Customer
Generator Application Process are required to complete the following:

1. Customer Generators must submit a completed application form and a $100 non-
refundable application fee to the Company. Applications are available on the Company’s website or will
be provided to the Customer upon request. Incomplete Applications are considered withdrawn after sixty
(60) days from the date the application was received.

2. Upon receipt of a completed application and a $100 non-refundable fee, the Company will
either (1) provide the Customer with a written or electronic notification that the application has been
received and all necessary information has been provided, or (2) request the Customer provide forms of
documentation outlined in Section 1.
APPLICATION PROCESS (Continued)
Idaho Power Company First Second Revised Sheet No. 68-12
Cancels
I.P.U.C. No. 30, Tariff No. 101OriginalFirst Revised Sheet No. 68-12
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36802 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2026 1221 West Idaho Street, Boise, Idaho

i. Protection Equipment Requirements (Rotating Machines): Generation
Facilities up to 500 kVA Total Nameplate Capacity may not require additional Protection
Equipment but will be evaluated on a case-by-case basis. Generation Facilities greater
than 500 kVA Total Nameplate Capacity will require additional Company-Furnished
Protection Equipment.

ii. Protection Equipment Requirements (Other DER): DER up to 3 MVA Total
Nameplate Capacity may not require additional Protection Equipment but will be evaluated
on a case-by-case basis.

iii. When it is determined Company-owned Protection Equipment is required,
the Customer shall pay the actual costs of all required Protection Equipment prior to the
start of Parallel operations. The Customer will also pay a Maintenance Charge specified
in Schedule 66, per month times the investment in the Protection Equipment.

5. Following receipt of “Approval to Proceed,” the Customer is responsible for completing the
installation of the Customer Generator System and fulfilling all applicable federal, state, and local
inspection requirements. Customers must also provide the Company with a completed System
Verification Form detailing the specifications of all installed components of the completed Customer
Generator System. System Verification Forms can be found on the Company’s website or will be
provided upon request. Upon completion, the Company reserves the right to request the Customer to
provide forms of documentation outlined in Section 1, verifying that all federal, state, and local
requirements have been met.

6. Once all required documentation has been submitted and the Company has verified that
all applicable federal, state, local, and Customer Generation Interconnection Process requirements have
been met, the Company will complete, barring conditions beyond the Company’s control, an on-site
inspection within ten (10) business days for DER with Total Nameplate Capacity of 100 kVA or less and
within twenty (20) business days for DER with Total Nameplate Capacity of greater than 100 kVA.
Company on-site inspections will not be performed until the system has passed all applicable federal,
state, and local inspection requirements. The Company on-site inspection may include the following:

a. Verification that actual installed components correspond to the information
provided on the initial application and the System Verification Form.
b. Verification that the disconnect is functional and reconnection time complies with
IEEE 1547.
c. Verification of the proximity and visibility of the disconnect or a sign indicating the
location of the disconnect.
d. Photographic documentation of the installation.
e. Posting of appropriate Company signage.
f. Documentation of the meter number and system configuration.
Idaho Power Company First Second Revised Sheet No. 68-13
Cancels
I.P.U.C. No. 30, Tariff No. 101Original First Revised Sheet No. 68-13
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36802 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2026 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

SECTION 2: INTERCONNECTION PROCESS REQUIREMENTS FOR DISTRIBUTED ENERGY
RESOURCES LESS THAN 3 MVA (Continued)

APPLICATION PROCESS (Continued)

If the DER system components, capacity, or configuration changes from the original application,
the Customer Generator will be subject to a new Feasibility Review.

If the Customer Generator changes its Customer Representative, a new application and a $100
non-refundable application fee is required.

3. The Company will perform within seven (7) business days, unless it is determined that
additional studies are necessary, the Feasibility Review based on Total Nameplate Capacity and other
project information provided in the application. The Feasibility Review determines the capability of the
Company’s electrical system to incorporate the proposed Customer Generator System and determines
if Upgrades are necessary. For a Customer Generator who does not yet have established service, the
Feasibility Review will occur as part of the Company’s evaluation for Upgrades for new customers
conducted in compliance with Rule H – New Service Attachments and Distribution Line Installations or
Alterations.

a. a. If the results of the Feasibility Review indicate satisfactory system
capability, the Company will provide the Customer with an official “Approval to
Proceed” notification.

b. If the results of the Feasibility Review indicate that Upgrades are necessary to
accommodate the proposed project, the Company will notify the Customer through written or
electronic notification of such Upgrades. Funding, construction, installation, and maintenance of
required Upgrades will be subject to the Company’s standard Rule H regarding New Service
Attachments and Distribution Line Installations or Alterations.

c. If the Company determines that additional time is necessary to determine
satisfactory system capability or that Upgrades are necessary to accommodate the proposed
project, the Company will notify the Customer. The Company will perform within fifteen (15)
business days the additional studies to complete the Feasibility Review.

4. If the results of the Feasibility Review require the need for a Feasibility Study, the
Company will provide the Customer with a FeasiblityFeasibility Study Agreement which requires a deposit
of $1,000 and must be signed and returned within fifteen (15) business days. Upon receipt of the signed
Feasibility Study Agreement and deposit, the Company will perform the FeasiblityFeasibility Study within
thirty (30) business days. If the results of the Feasibility Study indicate that Upgrades or Protection
Equipment are necessary to accommodate the proposed project, the Company will notify the Customer
of such Upgrades or Protection Equipment. At the Company’s discretion, additional studies referenced
in Section 4 may be applicable.

a. Installation and funding of the construction, installation, and maintenance of
required Protection Equipment will be subject to the following provisions:
Idaho Power Company First Second Revised Sheet No. 68-14
Cancels
I.P.U.C. No. 30, Tariff No. 101Original First Revised Sheet No. 68-14
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36802 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2026 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

SECTION 2: INTERCONNECTION PROCESS REQUIREMENTS FOR DISTRIBUTED ENERGY
RESOURCES LESS THAN 3 MVA (Continued)

APPLICATION PROCESS (Continued)

i. Protection Equipment Requirements (Rotating Machines): Generation
Facilities up to 500 kVA Total Nameplate Capacity may not require additional Protection
Equipment but will be evaluated on a case-by-case basis. Generation Facilities greater
than 500 kVA Total Nameplate Capacity will require additional Company-Furnished
Protection Equipment.

ii. Protection Equipment Requirements (Other DER): DER up to 3 MVA Total
Nameplate Capacity may not require additional Protection Equipment but will be evaluated
on a case-by-case basis.

iii. When it is determined Company-owned Protection Equipment is required,
the Customer shall pay the actual costs of all required Protection Equipment prior to the
start of Parallel operations. The Customer will also pay a Maintenance Charge specified
in Schedule 66, per month times the investment in the Protection Equipment.

5. Following receipt of “Approval to Proceed,” the Customer is responsible for completing the
installation of the Customer Generator System and fulfilling all applicable federal, state, and local
inspection requirements. Customers must also provide the Company with a completed System
Verification Form detailing the specifications of all installed components of the completed Customer
Generator System. System Verification Forms can be found on the Company’s website or will be
provided upon request. Upon completion, the Company reserves the right to request the Customer to
provide forms of documentation outlined in Section 1, verifying that all federal, state, and local
requirements have been met.

6. Once all required documentation has been submitted and the Company has verified that
all applicable federal, state, local, and Customer Generation Interconnection Process requirements have
been met, the Company will complete, barring conditions beyond the Company’s control, an on-site
inspection within ten (10) business days for DER with Total Nameplate Capacity of 100 kVA or less and
within twenty (20) business days for DER with Total Nameplate Capacity of greater than 100 kVA.
Company on-site inspections will not be performed until the system has passed all applicable federal,
state, and local inspection requirements. The Company on-site inspection may include the following:

a. Verification that actual installed components correspond to the information
provided on the initial application and the System Verification Form.
b. Verification that the disconnect is functional and reconnection time complies with
IEEE 1547.
c. Verification of the proximity and visibility of the disconnect or a sign indicating the
location of the disconnect.
d. Photographic documentation of the installation.
e. Posting of appropriate Company signage.
f. Documentation of the meter number and system configuration.
Idaho Power Company First Second Revised Sheet No. 68-14
Cancels
I.P.U.C. No. 30, Tariff No. 101Original First Revised Sheet No. 68-14
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36802 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2026 1221 West Idaho Street, Boise, Idaho
g. Verification of Smart Inverters, including the settings for all inverter-based DERs
100 kVA and greater.
h. Verification of Total Nameplate Capacity.
i. Verification of plant controller for all DERs 500 kVA and greater.

7. A return trip charge of $52.00 will be billed to the Customer each time Company
personnel are dispatched to the job site but are unable to conduct the on-site inspection due to
one or more of the conditions not being met that had been certified as complete by the Customer
or Customer’s Representative, as identified on the System Verification Form.

8. Successful completion of the Company on-site inspection constitutes the
conclusion of the application process. The Company must make a reasonable effort to move an
Exporting Customer Generator to the appropriate rate schedule within five (5) business days. The
rate change will be no later than the Customer’s next Billing Period following their successfully
completed inspection. Upon completion of this process, the Customer will receive confirmation
that the application process has been successfully completed.
SECTION 3: ADDITIONAL INTERCONNECTION REQUIREMENTS OF NON-
EXPORTING SYSTEMS

In addition to the requirements of Section 1, the following section is applicable to all
Customer Generators electing to establish their system as Non-Export.

NON-EXPORT TOTAL NAMEPLATE CAPACITY LIMIT

For customers taking service under Schedule 1 or Schedule 7 that own and/or operate a
Generation Facility, service is subject to an aggregate DER Total Nameplate Capacity of 25 kVA
or less, that is operated in Parallel with the Idaho Power System.The capacity of an Energy
Storage Device shall not be used to calculate the 25 kVA capacity limit but will be used to calculate
Total Nameplate Capacity for the Feasbility Review.
SECTION 3: ADDITIONAL INTERCONNECTION REQUIREMENTS OF NON-
EXPORTING SYSTEMS (Continued)

NON-EXPORT CONTROL SYSTEM

1. Non-Export Systems must incorporate one of the following three options:

a. Option 1: (“Advanced Functionality”): The use of an internal transfer relay, energy
management system, or other customer facility hardware or software system(s) may be used to
ensure power is never exported across the Interconnection Point. To ensure that Inadvertent
Export of power is limited to acceptable levels, all of the following conditions must be met: (a)
inverter-based DERs must utilize a Smart Inverter; (b) the DER must monitor the total Inadvertent
Export; (c) the DER must disconnect from the Company’s distribution system or halt energy
production within two seconds after the period of continuous Inadvertent Export exceeds 30
seconds; (d) the DER must enter a safe operating mode where Inadvertent Export will not occur
as a result of a failure of the control or Smart Inverter system for more than 30 seconds, which
results in loss of control signal, loss of control power or single component failure or related control
sensing of the control circuitry.

b. Option 2: (“Reverse Power Protection”): To ensure power is never exported, a
reverse power relay protective function must be implemented at the Interconnection Point. The
default setting for this Protection Equipment, when used, shall be 0.1% (export) of the DERs Total
Nameplate Capacity, with a maximum 2.0 second time delay.

Idaho Power Company First Second Revised Sheet No. 68-14
Cancels
I.P.U.C. No. 30, Tariff No. 101Original First Revised Sheet No. 68-14
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36802 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2026 1221 West Idaho Street, Boise, Idaho
c. Option 3: (“Minimum Power Protection”): To ensure at least a minimum amount of
power is imported at all times (and, therefore, that power is not exported), an under-power
protective function may be implemented at the Interconnection Point. The default setting for this
non-export control system, when used, shall be 5% (import) of the DERs Total Nameplate
Capacity, with a maximum two (2) second time delay.

2. Control System Failure: Where applicable, any failure of the Customer’s DER
control system for 30 seconds or more, which includes, but is not limited to; the internal transfer
relay, energy management system, or other Customer facility hardware or software system(s)
intended to prevent the reverse power flow, shall cause the Customer’s DER to enter a safe
operating mode whereby the production of energy from the Non-Export DER is autonomously
limited to an amount that shall not cause Inadvertent Export to occur until such time that the
Customer has reestablished real power output control of the non-export control system.

UNAUTHORIZED INADVERTENT EXPORT

Inadvertent Export exceeding three hours of the DER Total Nameplate Capacity in any
30-day period will be defined as unauthorized Inadvertent Export, and the following steps will be
followed for Customers with Non-Exporting Systems:

Idaho Power Company First Second Revised Sheet No. 68-15
Cancels
I.P.U.C. No. 30, Tariff No. 101Original First Revised Sheet No. 68-15
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36802 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2026 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

SECTION 2: INTERCONNECTION PROCESS REQUIREMENTS FOR DISTRIBUTED ENERGY
RESOURCES LESS THAN 3 MVA (Continued)

APPLICATION PROCESS (Continued)

SECTION 3: ADDITIONAL INTERCONNECTION REQUIREMENTS OF NON-EXPORTING
SYSTEMS (Continued)
g. Verification of Smart Inverters, including the settings for all inverter-based DERs
100 kVA and greater.
h. Verification of Total Nameplate Capacity.
i. Verification of plant controller for all DERs 500 kVA and greater.

7. A return trip charge of $52.00 will be billed to the Customer each time Company personnel
are dispatched to the job site but are unable to conduct the on-site inspection due to one or more of the
conditions not being met that had been certified as complete by the Customer or Customer’s
Representative, as identified on the System Verification Form.

8. Successful completion of the Company on-site inspection constitutes the conclusion of the
application process. The Company must make a reasonable effort to move an Exporting Customer
Generator to the appropriate rate schedule within five (5) business days. The rate change will be no later
than the Customer’s next Billing Period following their successfully completed inspection. Upon
completion of this process, the Customer will receive confirmation that the application process has been
successfully completed.

SECTION 3: ADDITIONAL INTERCONNECTION REQUIREMENTS OF NON-EXPORTING
SYSTEMS

In addition to the requirements of Section 1, the following section is applicable to all Customer
Generators electing to establish their system as Non-Export.

NON-EXPORT TOTAL NAMEPLATE CAPACITY LIMIT

For customers taking service under Schedules 1, 5, or Schedule 7 that own and/or operate a
Generation Facility, service is subject to an aggregate DER Total Nameplate Capacity of 25 kVA or less,
that is operated in Parallel with the Idaho Power System. The capacity of an Energy Storage Device shall
not be used to calculate the 25 kVA capacity limit but will be used to calculate Total Nameplate Capacity
for the FeasbilityFeasibility Review.
SECTION 3: ADDITIONAL INTERCONNECTION REQUIREMENTS OF NON-EXPORTING
SYSTEMS (Continued)

NON-EXPORT CONTROL SYSTEM

1. Non-Export Systems must incorporate one of the following three options:

Idaho Power Company First Second Revised Sheet No. 68-15
Cancels
I.P.U.C. No. 30, Tariff No. 101Original First Revised Sheet No. 68-15
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36802 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2026 1221 West Idaho Street, Boise, Idaho

UNAUTHORIZED INADVERTENT EXPORT (Continued)

1. The Company will notify the Non-Export Customer Generator that their Customer
Generator System has exceeded the Inadvertent Export limit.

2. After notification of Inadvertent Export, the following will occur:

a. For Schedule 1, Residential and Schedule 7, Small General Non-Exporting
Systems, the Customer Generator must rectify Inadvertent Export within 30 days after receipt of
the notification by Idaho Power that the Non-Exporting System has exceeded the Inadvertent
Export limit. If the Customer Generator has not rectified Inadvertent Export after 30 days, at the
Customer’s election, one of the following actions will occur:

i. The Customer Generator System disconnect will be placed in the open (off)
position until the issue that caused the export is remedied. A Company inspection will be
required before the Non-Exporting System can interconnect to the Company’s system; or,

ii. If the Customer does not elect to open the disconnect, the Customer
Generator will be placed on Schedule 6 or Schedule 8, as appropriate, and subject to
applicable provisions of Section 2. If the Customer elects to be placed on Schedule 6 or
Schedule 8, the Customer will be given the option to submit an additional application and
be moved back to Schedule 1 or Schedule 7, as appropriate, after 180 days.

b. For Schedules other than Schedule 1 or Schedule 7:

i. Upon receipt of the notification by Idaho Power that the Customer
Generator’s Non-Exporting System has exceeded the Inadvertent Export limit, the
Customer Generator System disconnect will be placed in the open position until the issue
that caused the export is remedied. A Company inspection will be required before the
Non-Exporting System can interconnect to the Company’s system.

3. If it is determined, at the sole discretion of the Company, that unauthorized Inadvertent
Export results in damage to equipment on the Company’s system, the Customer Generator will be
responsible for all costs associated with replacing the Company’s damaged equipment and defend,
indemnify, and reimburse the Company for liabilities or damages incurred by the Company for third-party
claims arising out of the Customer Generator’s unauthorized Inadvertent Export.

Idaho Power Company Original First Revised Sheet No. 68-16
Cancels
I.P.U.C. No. 30, Tariff No. 101First RevisedOriginal Sheet No. 68-16
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36067 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

SECTION 3: ADDITIONAL INTERCONNECTION REQUIREMENTS OF NON-EXPORTING
SYSTEMS (Continued)

NON-EXPORT CONTROL SYSTEM (Continued)

a. Option 1: (“Advanced Functionality”): The use of an internal transfer relay, energy
management system, or other customer facility hardware or software system(s) may be used to
ensure power is never exported across the Interconnection Point. To ensure that Inadvertent
Export of power is limited to acceptable levels, all of the following conditions must be met: (a)
inverter-based DERs must utilize a Smart Inverter; (b) the DER must monitor the total Inadvertent
Export; (c) the DER must disconnect from the Company’s distribution system or halt energy
production within two seconds after the period of continuous Inadvertent Export exceeds 30
seconds; (d) the DER must enter a safe operating mode where Inadvertent Export will not occur
as a result of a failure of the control or Smart Inverter system for more than 30 seconds, which
results in loss of control signal, loss of control power or single component failure or related control
sensing of the control circuitry.

b. Option 2: (“Reverse Power Protection”): To ensure power is never exported, a
reverse power relay protective function must be implemented at the Interconnection Point. The
default setting for this Protection Equipment, when used, shall be 0.1% (export) of the DERs Total
Nameplate Capacity, with a maximum 2.0 second time delay.

c. Option 3: (“Minimum Power Protection”): To ensure at least a minimum amount of
power is imported at all times (and, therefore, that power is not exported), an under-power
protective function may be implemented at the Interconnection Point. The default setting for this
non-export control system, when used, shall be 5% (import) of the DERs Total Nameplate
Capacity, with a maximum two (2) second time delay.

2. Control System Failure: Where applicable, any failure of the Customer’s DER control
system for 30 seconds or more, which includes, but is not limited to; the internal transfer relay, energy
management system, or other Customer facility hardware or software system(s) intended to prevent the
reverse power flow, shall cause the Customer’s DER to enter a safe operating mode whereby the
production of energy from the Non-Export DER is autonomously limited to an amount that shall not cause
Inadvertent Export to occur until such time that the Customer has reestablished real power output control
of the non-export control system.

UNAUTHORIZED INADVERTENT EXPORT

Inadvertent Export exceeding three hours of the DER Total Nameplate Capacity in any 30-day
period will be defined as unauthorized Inadvertent Export, and the following steps will be followed for
Customers with Non-Exporting Systems:

SECTION 4: ADDITIONAL INTERCONNECTION REQUIREMENTS OF DISTRIBUTED ENERGY
RESOURCES 3 MVA OR GREATER

Idaho Power Company Original First Revised Sheet No. 68-16
Cancels
I.P.U.C. No. 30, Tariff No. 101First RevisedOriginal Sheet No. 68-16
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36067 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho
The following section is applicable to all Customers requesting interconnection of DERs with Total
Nameplate Capacity of 3 MVA or greater.

CUSTOMER GENERATOR INTERCONNECTION PROCESS

1. Customer Generator shall pay the actual costs of all required interconnection studies. Any
difference between the deposit (if required) and the actual cost of the study shall be paid by or refunded
to Customer Generator, as appropriate. If, during the course of preparing a study, the Company incurs
costs in excess of the deposit amount, the Company may require that the deposit amount be replenished
in an amount equal to the estimated costs for completion of the study. If a deposit amount sufficient to
pay for completion of the study is not maintained, the Company may suspend work on the study.

2. Unless modified by the provisions of this schedule, the FERC-approved Large Generator
Interconnection Procedures and Small Generator Interconnection Procedures posted on the Company’s
website will apply to the Customer Generator Interconnection Process.

3. Application. The Customer Generator will submit a completed interconnection application
in the form posted on the Company’s website. The application form includes a general description of the
DER and its location. The application includes payment of an application fee to be applied against costs
the Company incurs to perform the Feasibility Study described below. The amount of the application fee
is $1,000.

4. Study Agreements. Subsequent to the Customer Generator submitting an Application,
the Customer Generator will be offered a series of study agreements. The individual study agreements
establish the time to perform the study, and the deposit the Customer Generator is to provide prior to
commencement of the study. The studies consist of:

a. The Feasibility Study: The Feasibility Study is intended to ensure that the
Company’s system is sufficiently equipped to incorporate proposed DER in a manner that
conforms with good utility practices and the National Electric Safety Code. The Feasibility Study
Agreement states that no deposit is required because the application fee covers the deposit.

b. The System Impact Study: For higher complexity projects, the System Impact
Study provides a detailed assessment of the distribution and/or transmission system adequacy to
accommodate the DER through the evaluation of equipment capabilities and electrical
performance requirements. This step may not be necessary for some projects depending on the
size and location of the project. The System Impact Study Agreement includes a deposit of
$2,000 for a distribution system impact study or a $10,000 deposit for a transmission system
impact study.

Idaho Power Company Original First Revised Sheet No. 68-17
Cancels
I.P.U.C. No. 30, Tariff No. 101First RevisedOriginal Sheet No. 68-17
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36067 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

SECTION 3: ADDITIONAL INTERCONNECTION REQUIREMENTS OF NON-EXPORTING
SYSTEMS (Continued)

UNAUTHORIZED INADVERTENT EXPORT (Continued)

1. The Company will notify the Non-Export Customer Generator that their Customer
Generator System has exceeded the Inadvertent Export limit.

2. After notification of Inadvertent Export, the following will occur:

a. For Schedules 1,5, or Residential and Schedule 7, Small General Non-Exporting
Systems, the Customer Generator must immediately disconnect the DER until the issue(s) is
resolved and rectify Inadvertent Export within 30 days after receipt of the notification by Idaho
Power that the Non-Exporting System has exceeded the Inadvertent Export limit. If the Customer
Generator has not rectified Inadvertent Export after 30 days, at the Customer’s election, one of
the following actions will occur:

i. The Customer Generator SystemDER must be permanently disconnected
from the Company’s system. disconnect will be placed in the open (off) position until the
issue that caused the export is remedied. A Company inspection will be required A
Customer Generator must complete the Customer Generator Interconnection Process
before the Non-Exporting System can interconnect to the Company’s system; or,

ii. The Customer may apply to take service as an Exporting System subject
to the full requirement for exporting systems outlined in this Schedule and Schedules 6,
or 8, as applicable. If the Customer does not elect to open the disconnect, the Customer
Generator will be placed on Schedule 6 or Schedule 8, as appropriate, and subject to
applicable provisions of Section 2. If the Customer elects to be placed on Schedule 6 or
Schedule 8, the Customer will be given the option to submit an additional application and
be moved back to Schedule 1 or Schedule 7, as appropriate, after 180 days.

b. For Schedules other than Schedules 1, 5, or Schedule 7:

i. Upon receipt of the notification by Idaho Power that the Customer
Generator’s Non-Exporting System has exceeded the Inadvertent Export limit, the
Customer Generator System disconnect will be placed in the open position until the issue
that caused the export is remedied. A Company inspection will be required before the
Non-Exporting System can interconnect to the Company’s system.

3. If it is determined, at the sole discretion of the Company, that unauthorized Inadvertent
Export results in damage to equipment on the Company’s system, the Customer Generator will be
responsible for all costs associated with replacing the Company’s damaged equipment and defend,
indemnify, and reimburse the Company for liabilities or damages incurred by the Company for third-party
claims arising out of the Customer Generator’s unauthorized Inadvertent Export.

Idaho Power Company Original First Revised Sheet No. 68-17
Cancels
I.P.U.C. No. 30, Tariff No. 101First RevisedOriginal Sheet No. 68-17
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36067 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho
SECTION 4: ADDITIONAL INTERCONNECTION REQUIREMENTS OF DISTRIBUTED ENERGY
RESOURCES 3 MVA OR GREATER (Continued)

c. The Facility Study: The Facility Study includes the engineering to determine the
design specifications of the project. The Facility Study Agreement includes a deposit of 5% of
the total project costs that were determined in the System Impact Study Report (“SISR”) or the
Feasibility Study Report if a SISR is not required, capped at $30,000.

At the end of each stage of the three-step study process, the Company will provide the Customer
Generator with an increasingly more refined and detailed report that, among other things, will present a
list of required Interconnection Facilities and a non-binding, good faith estimate of Customer Generator’s
cost responsibility for the Interconnection Facilities. If long-lead-time equipment items need to be ordered
to meet Customer Generator’s construction schedule, the Company will request advance funding by the
Customer Generator to cover these equipment costs.

5. Customer Generator Interconnection Agreement. The Customer Generator
Interconnection Agreement (“CGIA”), will be offered to the Customer Generator following completion of
the Study Phase. The CGIA will utilize the Uniform Customer Generator Interconnection Agreement
template included in this schedule.

INTERCONNECTION FACILITIES REQUIREMENTS

DER 3 MVA or greater Total Nameplate Capacity will require additional Company-Furnished
Protection, Metering, and communications Equipment. This equipment will be further defined in the CGIA
Attachment 1.

COST OF INTERCONNECTION FACILITIES

The Customer Generator will pay all costs of interconnecting a DER to the Company’s system.
Costs of interconnection include the costs of furnishing and constructing required Upgrades, which will
be determined pursuant to Rule H. To the extent that additional facilities not provided for under Rule H,
including transmission and/or substation facilities, are required to interconnect the requested Generation
Facility, special arrangements will be made in a separate agreement between the Customer Generator
and the Company.

Each request for interconnection will go through the Customer Generator Interconnection
Process. Throughout the Customer Generator Interconnection Process, the Company will periodically
bill the Customer Generator for engineering costs incurred or obligated. Failure to pay an invoice within
the time specified in the invoice will result in the suspension of work on the interconnection. Customer
Generator can end the Customer Generator Interconnection Process at any time. If Customer Generator
decides to end the Customer Generator Interconnection Process prior to completion, the Company will
either refund any monies held for security that have not been spent or obligated, or issue an invoice to
Customer Generator for costs incurred prior to cancellation.

Idaho Power Company First Second Revised Sheet No. 68-18
Cancels
I.P.U.C. No. 30, Tariff No. 101Original First Revised Sheet No. 68-18
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36802 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2026 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

SECTION 4: ADDITIONAL INTERCONNECTION REQUIREMENTS OF DISTRIBUTED ENERGY
RESOURCES 3 MVA OR GREATER

The following section is applicable to all Customers requesting interconnection of DERs with Total
Nameplate Capacity of 3 MVA or greater.

CUSTOMER GENERATOR INTERCONNECTION PROCESS

1. Customer Generator shall pay the actual costs of all required interconnection studies. Any
difference between the deposit (if required) and the actual cost of the study shall be paid by or refunded
to Customer Generator, as appropriate. If, during the course of preparing a study, the Company incurs
costs in excess of the deposit amount, the Company may require that the deposit amount be replenished
in an amount equal to the estimated costs for completion of the study. If a deposit amount sufficient to
pay for completion of the study is not maintained, the Company may suspend work on the study.

2. Unless modified by the provisions of this schedule, the FERC-approved Large Generator
Interconnection Procedures and Small Generator Interconnection Procedures posted on the Company’s
website will apply to the Customer Generator Interconnection Process.

3. Application. The Customer Generator will submit a completed interconnection application
in the form posted on the Company’s website. The application form includes a general description of the
DER and its location. The application includes payment of an application fee to be applied against costs
the Company incurs to perform the Feasibility Study described below. The amount of the application fee
is $1,000.

4. Study Agreements. Subsequent to the Customer Generator submitting an Application,
the Customer Generator will be offered a series of study agreements. The individual study agreements
establish the time to perform the study, and the deposit the Customer Generator is to provide prior to
commencement of the study. The studies consist of:

a. The Feasibility Study: The Feasibility Study is intended to ensure that the
Company’s system is sufficiently equipped to incorporate proposed DER in a manner that
conforms with good utility practices and the National Electric Safety Code. The Feasibility Study
Agreement states that no deposit is required because the application fee covers the deposit.

b. The System Impact Study: For higher complexity projects, the System Impact
Study provides a detailed assessment of the distribution and/or transmission system adequacy to
accommodate the DER through the evaluation of equipment capabilities and electrical
performance requirements. This step may not be necessary for some projects depending on the
size and location of the project. The System Impact Study Agreement includes a deposit of
$2,000 for a distribution system impact study or a $10,000 deposit for a transmission system
impact study.

SECTION 4: ADDITIONAL INTERCONNECTION REQUIREMENTS OF DISTRIBUTED ENERGY
RESOURCES 3 MVA OR GREATER (Continued)
Idaho Power Company First Second Revised Sheet No. 68-18
Cancels
I.P.U.C. No. 30, Tariff No. 101Original First Revised Sheet No. 68-18
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36802 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2026 1221 West Idaho Street, Boise, Idaho

SYSTEM PROTECTION, DER METERING, AND DER COMMUNICATION MAINTENANCE CHARGE

The Customer shall pay the actual costs of System Protection, DER metering, and DER
communication equipment, as identified in the study process, prior to the start of Parallel operations. The
Customer will pay a Maintenance Charge as specified in Schedule 66 per month times the investment in
the System Protection, DER metering, and DER communication equipment. The Customer Generator
will also be responsible for any applicable monthly charges as outlined in Attachment 1 of the CGIA.

IDAHO POWER COMPANY
UNIFORM CUSTOMER GENERATOR
INTERCONNECTION AGREEMENT

This Uniform Customer Generator Interconnection Agreement (“Agreement”) is entered to be
effective as of the ____ day of __________, 20___ (“Effective Date”), between
____________________________, (“Customer Generator”) and Idaho Power Company (the
“Company”). Customer Generator and the Company may also be referred to individually as a “Party” or
collectively as the “Parties.” Unless explicitly noted otherwise, the term “days” refers to calendar days.

RECITALS

A. Customer Generator owns or operates a Customer Generator System that qualifies for
service under Idaho Power’s Commission-approved Schedule 68 which is subject to change from time
to time pursuant to Commission order.

B. The Customer Generator System to be interconnected and operate in Parallel with the
Company’s system pursuant to this Agreement is more particularly described in Attachment 1.

AGREEMENT

For and in consideration of the mutual covenants and provisions set forth in this Agreement, and
other good and valuable consideration, the receipt of which is hereby acknowledged, the Parties
intending to be legally bound agree as follows:

1. Recitals. The Parties acknowledge and agree as to the accuracy of the Recitals set forth
above, and such Recitals are incorporated herein by this reference.

2. Defined Terms. Capitalized terms not defined in this Agreement shall have the meaning
given to them in Schedule 68.

Idaho Power Company Original First Revised Sheet No. 68-19
Cancels
I.P.U.C. No. 30, Tariff No. 101First RevisedOriginal Sheet No. 68-19
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No.36042 & 36048 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

SECTION 4: ADDITIONAL INTERCONNECTION REQUIREMENTS OF DISTRIBUTED ENERGY
RESOURCES 3 MVA OR GREATER (Continued)

CUSTOMER GENERATOR INTERCONNECTION PROCESS (Continued)

c. The Facility Study: The Facility Study includes the engineering to determine the
design specifications of the project. The Facility Study Agreement includes a deposit of 5% of
the total project costs that were determined in the System Impact Study Report (“SISR”) or the
Feasibility Study Report if a SISR is not required, capped at $30,000.

At the end of each stage of the three-step study process, the Company will provide the Customer
Generator with an increasingly more refined and detailed report that, among other things, will present a
list of required Interconnection Facilities and a non-binding, good faith estimate of Customer Generator’s
cost responsibility for the Interconnection Facilities. If long-lead-time equipment items need to be ordered
to meet Customer Generator’s construction schedule, the Company will request advance funding by the
Customer Generator to cover these equipment costs.

5. Customer Generator Interconnection Agreement. The Customer Generator
Interconnection Agreement (“CGIA”), will be offered to the Customer Generator following completion of
the Study Phase. The CGIA will utilize the Uniform Customer Generator Interconnection Agreement
template included in this schedule.

INTERCONNECTION FACILITIES REQUIREMENTS

DER 3 MVA or greater Total Nameplate Capacity will require additional Company-Furnished
Protection, Metering, and communications Equipment. This equipment will be further defined in the CGIA
Attachment 1.

COST OF INTERCONNECTION FACILITIES

The Customer Generator will pay all costs of interconnecting a DER to the Company’s system.
Costs of interconnection include the costs of furnishing and constructing required Upgrades, which will
be determined pursuant to Rule H. To the extent that additional facilities not provided for under Rule H,
including transmission and/or substation facilities, are required to interconnect the requested Generation
Facility, special arrangements will be made in a separate agreement between the Customer Generator
and the Company.

Each request for interconnection will go through the Customer Generator Interconnection
Process. Throughout the Customer Generator Interconnection Process, the Company will periodically
bill the Customer Generator for engineering costs incurred or obligated. Failure to pay an invoice within
the time specified in the invoice will result in the suspension of work on the interconnection. Customer
Generator can end the Customer Generator Interconnection Process at any time. If Customer Generator
decides to end the Customer Generator Interconnection Process prior to completion, the Company will
either refund any monies held for security that have not been spent or obligated, or issue an invoice to
Customer Generator for costs incurred prior to cancellation.
Idaho Power Company Original First Revised Sheet No. 68-19
Cancels
I.P.U.C. No. 30, Tariff No. 101First RevisedOriginal Sheet No. 68-19
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No.36042 & 36048 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SECTION 4: ADDITIONAL INTERCONNECTION REQUIREMENTS OF DISTRIBUTED ENERGY
RESOURCES 3 MVA OR GREATER (Continued)

IDAHO POWER COMPANY
UNIFORM CUSTOMER GENERATOR
INTERCONNECTION AGREEMENT
(Continued)
AGREEMENT (Continued)

3. Schedule 68. Schedule 68 is incorporated into this Agreement by this reference and this
Agreement shall be interpreted in conjunction with Schedule 68; in the event of a conflict between
Schedule 68 and this Agreement, Schedule 68 shall prevail. This Agreement and Schedule 68 provide
terms and conditions under which the Customer Generator System will interconnect and operate in
Parallel with the Company’s transmission/distribution system.

4. Entire Agreement. This Agreement, in conjunction with Schedule 68, constitutes the
full and entire understanding and agreement between the Parties regarding the subjects set forth herein
and supersede all prior agreements and understandings related thereto. Nothing in this Agreement is
intended to affect any other agreement between the Company and Customer Generator regarding
subjects outside the terms of this Agreement and Schedule 68.

5. Attachments. The following Attachments 1 – 6 are attached hereto and incorporated by this
reference:

Attachment 1 – Description and Costs of the Customer Generator System, Interconnection Facilities,
and Metering Equipment.

Attachment 2 – One-line Diagram Depicting the Customer Generator System, Interconnection Facilities,
Metering Equipment and Upgrades.

Attachment 3 – Milestones for Interconnecting the Customer Generator System.

Attachment 4 – Additional Operating Requirements for the Company’s Transmission System Needed to
Support the Customer Generator System.

Attachment 5 – Reactive Power.

Attachment 6 – Description of Upgrades required to integrate the Customer Generator System and
Best Estimate of Upgrade Costs.

6. Effective Date, Term, Termination and Disconnection.

6.1 Term of Agreement. Unless earlier terminated pursuant to the terms hereof, this Agreement
shall remain in effect from the Effective Date for as long as Customer Generator System is eligible for
service under Schedule 68.

Idaho Power Company Original First Revised Sheet No. 68-20
Cancels
I.P.U.C. No. 30, Tariff No. 101First RevisedOriginal Sheet No. 68-20
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36067 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

SECTION 4: ADDITIONAL INTERCONNECTION REQUIREMENTS OF DISTRIBUTED ENERGY
RESOURCES 3 MVA OR GREATER (Continued)

SYSTEM PROTECTION, DER METERING, AND DER COMMUNICATION MAINTENANCE CHARGE

The Customer shall pay the actual costs of System Protection, DER metering, and DER
communication equipment, as identified in the study process, prior to the start of Parallel operations. The
Customer will pay a Maintenance Charge as specified in Schedule 66 per month times the investment in
the System Protection, DER metering, and DER communication equipment. The Customer Generator
will also be responsible for any applicable monthly charges as outlined in Attachment 1 of the CGIA.

IDAHO POWER COMPANY
UNIFORM CUSTOMER GENERATOR
INTERCONNECTION AGREEMENT

This Uniform Customer Generator Interconnection Agreement (“Agreement”) is entered to be
effective as of the ____ day of __________, 20___ (“Effective Date”), between
____________________________, (“Customer Generator”) and Idaho Power Company (the
“Company”). Customer Generator and the Company may also be referred to individually as a “Party” or
collectively as the “Parties.” Unless explicitly noted otherwise, the term “days” refers to calendar days.

RECITALS

A. Customer Generator owns or operates a Customer Generator System that qualifies for
service under Idaho Power’s Commission-approved Schedule 68 which is subject to change from time
to time pursuant to Commission order.

B. The Customer Generator System to be interconnected and operate in Parallel with the
Company’s system pursuant to this Agreement is more particularly described in Attachment 1.

AGREEMENT

For and in consideration of the mutual covenants and provisions set forth in this Agreement, and
other good and valuable consideration, the receipt of which is hereby acknowledged, the Parties
intending to be legally bound agree as follows:

1. Recitals. The Parties acknowledge and agree as to the accuracy of the Recitals set forth
above, and such Recitals are incorporated herein by this reference.

2. Defined Terms. Capitalized terms not defined in this Agreement shall have the meaning
given to them in Schedule 68.
SECTION 4: ADDITIONAL INTERCONNECTION REQUIREMENTS OF DISTRIBUTED ENERGY
RESOURCES 3 MVA OR GREATER (Continued)

IDAHO POWER COMPANY
Idaho Power Company Original First Revised Sheet No. 68-20
Cancels
I.P.U.C. No. 30, Tariff No. 101First RevisedOriginal Sheet No. 68-20
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36067 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho
UNIFORM CUSTOMER GENERATOR
INTERCONNECTION AGREEMENT
(Continued)

AGREEMENT (Continued)

6.2 Termination for Cause. If either Party materially breaches this Agreement and the
material breach is not cured within 10 days after the non-breaching Party gives the breaching
Party written notice thereof, the non-breaching Party may elect to terminate this Agreement by
giving the breaching Party notice of the termination; provided, however, that if the nature of the
breach is such that it could not reasonably be cured within the 10 day period, then the non-
breaching Party may terminate this Agreement immediately upon providing written notice to the
breaching Party. If the Company terminates this Agreement for breach by the Customer
Generator and it is later determined that Customer Generator did not breach the Agreement, or
the breach was excusable, the rights and obligations of the Parties will be the same as if the
termination has been issued for the convenience of the Company pursuant to Section 6.3 below.

6.3 Termination for Convenience. The Company may terminate or suspend this
Agreement at any time without cause and without penalty, on 10 days’ written notice to the
Customer Generator. The Customer Generator may terminate or suspend this Agreement at any
time without cause and without penalty by discontinuing Parallel operation of Customer’s
Generator System, or discontinuing taking electric service from the Company, and providing the
Company with 10 days’ written notice of the same.

6.4. Effect of Termination. Upon termination or expiration of this Agreement pursuant
to this Section 6, Idaho Power will disconnect the Customer Generator System from the
Company’s transmission/distribution system. Upon termination or expiration of this Agreement,
all obligations of the Parties (other than those obligations that expressly or by nature survive
termination) shall terminate.

7. Land Rights. Customer Generator hereby grants to Idaho Power for the term of this
Agreement all necessary rights-of-way and easements to install, operate, maintain, replace, and remove
Idaho Power’s Metering Equipment, Interconnection Equipment, Disconnection Equipment, Protection
Equipment and other Special Facilities necessary or useful to this Agreement, including adequate and
continuing access rights on the property of Customer Generator. Customer Generator warrants that it
has procured sufficient easements and rights-of-way from third parties so as to provide Idaho Power with
the access described above. All documents granting such easements or rights-of-way shall be subject
to Idaho Power’s approval and in recordable form.

Idaho Power Company Original First Revised Sheet No. 68-21
Cancels
I.P.U.C. No. 30, Tariff No. 101First RevisedOriginal Sheet No. 68-21
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36067 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

SECTION 4: ADDITIONAL INTERCONNECTION REQUIREMENTS OF DISTRIBUTED ENERGY
RESOURCES 3 MVA OR GREATER (Continued)

IDAHO POWER COMPANY
UNIFORM CUSTOMER GENERATOR
INTERCONNECTION AGREEMENT
(Continued)

AGREEMENT (Continued)

3. Schedule 68. Schedule 68 is incorporated into this Agreement by this reference and this
Agreement shall be interpreted in conjunction with Schedule 68; in the event of a conflict between
Schedule 68 and this Agreement, Schedule 68 shall prevail. This Agreement and Schedule 68 provide
terms and conditions under which the Customer Generator System will interconnect and operate in
Parallel with the Company’s transmission/distribution system.

4. Entire Agreement. This Agreement, in conjunction with Schedule 68, constitutes the full
and entire understanding and agreement between the Parties regarding the subjects set forth herein and
supersede all prior agreements and understandings related thereto. Nothing in this Agreement is
intended to affect any other agreement between the Company and Customer Generator regarding
subjects outside the terms of this Agreement and Schedule 68.

5. Attachments. The following Attachments 1 – 6 are attached hereto and incorporated by
this reference:

Attachment 1 – Description and Costs of the Customer Generator System, Interconnection
Facilities, and Metering Equipment.

Attachment 2 – One-line Diagram Depicting the Customer Generator System,
Interconnection Facilities, Metering Equipment and Upgrades.

Attachment 3 – Milestones for Interconnecting the Customer Generator System.

Attachment 4 – Additional Operating Requirements for the Company’s Transmission
System Needed to Support the Customer Generator System.

Attachment 5 – Reactive Power.

Attachment 6 – Description of Upgrades required to integrate the Customer Generator
System and Best Estimate of Upgrade Costs.

6. Effective Date, Term, Termination and Disconnection.

6.1 Term of Agreement. Unless earlier terminated pursuant to the terms hereof, this
Agreement shall remain in effect from the Effective Date for as long as Customer Generator
System is eligible for service under Schedule 68.
Idaho Power Company Original First Revised Sheet No. 68-21
Cancels
I.P.U.C. No. 30, Tariff No. 101First RevisedOriginal Sheet No. 68-21
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36067 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho
SECTION 4: ADDITIONAL INTERCONNECTION REQUIREMENTS OF DISTRIBUTED
ENERGY RESOURCES 3 MVA OR GREATER (Continued)

IDAHO POWER COMPANY
UNIFORM CUSTOMER GENERATOR
INTERCONNECTION AGREEMENT
(Continued)

AGREEMENT (Continued)

8. Assignment.

8.1 This Agreement may be assigned by either Party upon twenty-one (21) calendar
days prior written notice and opportunity to object by the other Party; provided that:

8.2 Either Party may assign this Agreement without the consent of the other Party to
any affiliate of the assigning Party with an equal or greater credit rating and with the legal authority
and operational ability to satisfy the obligations of the assigning Party under this Agreement.

8.3 The Customer Generator has the right to contingently assign this Agreement,
without the consent of the Company, for collateral security purposes to aid in providing financing
for the Generation Facility, provided that the Customer Generator will promptly notify the
Company of any such contingent assignment.

8.4 Any attempted assignment that violates this Section 6 is void and ineffective.
Assignment shall not relieve a Party of its obligations, nor shall the non-assigning Party’s
obligations be enlarged, in whole or in part, by reason thereof. An assignee is responsible for
meeting the same financial, credit, and insurance obligations as the Customer Generator. Where
required, consent to assignment will not be unreasonably withheld, conditioned or delayed.

9. Indemnity. To the fullest extent permitted by law, Customer Generator shall indemnify,
defend, reimburse, and hold harmless the Company and its successors and their respective directors,
officers, members, employees, representatives, and agents (collectively, the “Indemnitees”), from, for,
and against any and all third-party allegations, claims, liens, liabilities, losses, demands, damages,
expenses, suits, actions, proceedings, judgments, and costs of any kind whatsoever, including, without
limitation, settlement costs, court costs, and attorneys’ and expert witness fees and expenses
(collectively, “Damages”), whether actual or merely alleged, and whether directly incurred or incurred by
a third party, arising out of, or relating to a) the negligent acts, omissions, or willful misconduct of
Customer Generator, b) a violation of federal or state law, regulation, statute, or ordinance, or c)
Customer Generator’s material breach of this Agreement. If the Company seeks indemnification from
the Customer Generator, the Company shall: (i) notify Customer Generator of the assertion of any claim;
(ii) provide reasonable assistance (at Customer Generator’s expense) in connection with the defense;
and (iii) be entitled to pre-approve any settlement.

Idaho Power Company Original First Revised Sheet No. 68-22
Cancels
I.P.U.C. No. 30, Tariff No. 101First RevisedOriginal Sheet No. 68-22
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36067 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

SECTION 4: ADDITIONAL INTERCONNECTION REQUIREMENTS OF DISTRIBUTED ENERGY
RESOURCES 3 MVA OR GREATER (Continued)

IDAHO POWER COMPANY
UNIFORM CUSTOMER GENERATOR
INTERCONNECTION AGREEMENT
(Continued)

AGREEMENT (Continued)

6.2 Termination for Cause. If either Party materially breaches this Agreement and the
material breach is not cured within 10 days after the non-breaching Party gives the breaching
Party written notice thereof, the non-breaching Party may elect to terminate this Agreement by
giving the breaching Party notice of the termination; provided, however, that if the nature of the
breach is such that it could not reasonably be cured within the 10 day period, then the non-
breaching Party may terminate this Agreement immediately upon providing written notice to the
breaching Party. If the Company terminates this Agreement for breach by the Customer
Generator and it is later determined that Customer Generator did not breach the Agreement, or
the breach was excusable, the rights and obligations of the Parties will be the same as if the
termination has been issued for the convenience of the Company pursuant to Section 6.3 below.

6.3 Termination for Convenience. The Company may terminate or suspend this
Agreement at any time without cause and without penalty, on 10 days’ written notice to the
Customer Generator. The Customer Generator may terminate or suspend this Agreement at any
time without cause and without penalty by discontinuing Parallel operation of Customer’s
Generator System, or discontinuing taking electric service from the Company, and providing the
Company with 10 days’ written notice of the same.

6.4. Effect of Termination. Upon termination or expiration of this Agreement pursuant
to this Section 6, Idaho Power will disconnect the Customer Generator System from the
Company’s transmission/distribution system. Upon termination or expiration of this Agreement,
all obligations of the Parties (other than those obligations that expressly or by nature survive
termination) shall terminate.

7. Land Rights. Customer Generator hereby grants to Idaho Power for the term of this
Agreement all necessary rights-of-way and easements to install, operate, maintain, replace, and remove
Idaho Power’s Metering Equipment, Interconnection Equipment, Disconnection Equipment, Protection
Equipment and other Special Facilities necessary or useful to this Agreement, including adequate and
continuing access rights on the property of Customer Generator. Customer Generator warrants that it
has procured sufficient easements and rights-of-way from third parties so as to provide Idaho Power with
the access described above. All documents granting such easements or rights-of-way shall be subject
to Idaho Power’s approval and in recordable form.
SECTION 4: ADDITIONAL INTERCONNECTION REQUIREMENTS OF DISTRIBUTED ENERGY
RESOURCES 3 MVA OR GREATER (Continued)

IDAHO POWER COMPANY
Idaho Power Company Original First Revised Sheet No. 68-22
Cancels
I.P.U.C. No. 30, Tariff No. 101First RevisedOriginal Sheet No. 68-22
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36067 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho
UNIFORM CUSTOMER GENERATOR
INTERCONNECTION AGREEMENT
(Continued)

AGREEMENT (Continued)

9.1 The Parties shall at all times indemnify, defend, and hold the other Party harmless
from, any and all damages, losses, claims, including claims and actions relating to injury to or
death of any person or damage to property, demand, suits, recoveries, costs and expenses, court
costs, attorney fees, and all other obligations by or to third parties, arising out of or resulting from
the other Party’s action or failure to meet its obligations under this Agreement on behalf of the
indemnifying Party, except in cases of gross negligence or intentional wrongdoing by the
indemnified Party.

9.2 If an indemnified person is entitled to indemnification under this article as a result
of a claim by a third party, and the indemnifying Party fails, after notice and reasonable opportunity
to proceed under this article, to assume the defense of such claim, such indemnified person may
at the expense of the indemnifying Party contest, settle or consent to the entry of any judgment
with respect to, or pay in full, such claim. Failure to defend is a Material Breach.

9.3 If an indemnifying party is obligated to indemnify and hold any indemnified person
harmless under this article, the amount owing to the indemnified person shall be the amount of
such indemnified person’s actual loss, net of any insurance or other recovery.

10. Force Majeure Event. Neither Party shall be liable for any breach, default, or delay in
the performance of the obligations under this Agreement if and to the extent such default or delay is
caused by fire, flood, earthquake, elements of nature or acts of God, riots, civil disorder, rebellions or
revolutions, strikes, lockouts or other industrial disturbances, unanticipated changes in governmental
laws and regulations, or any other cause beyond the reasonable control of such Party (a “Force Majeure
Event”); provided the non-performing Party is without fault in causing such breach, default, or delay, and
such breach, default or delay could not have been prevented by reasonable precautions and cannot
reasonably be circumvented by the non-performing Party through the use of alternate sources, work-
around plans, or other means. The Party claiming a Force Majeure Event must give the other Party
immediate written notice, no later than five (5) calendar days of the Party’s discovery of the Force Majeure
Event, and the time for resumption of performance (if applicable) by that Party. The suspension of
performance shall be of no greater scope and of no longer duration than is required by the Force Majeure
Event.

Idaho Power Company Original First Revised Sheet No. 68-23
Cancels
I.P.U.C. No. 30, Tariff No. 101First RevisedOriginal Sheet No. 68-23
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36067 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

SECTION 4: ADDITIONAL INTERCONNECTION REQUIREMENTS OF DISTRIBUTED
ENERGY RESOURCES 3 MVA OR GREATER (Continued)

IDAHO POWER COMPANY
UNIFORM CUSTOMER GENERATOR
INTERCONNECTION AGREEMENT
(Continued)

AGREEMENT (Continued)

8. Assignment.

8.1 This Agreement may be assigned by either Party upon twenty-one (21) calendar
days prior written notice and opportunity to object by the other Party; provided that:

8.2 Either Party may assign this Agreement without the consent of the other Party to
any affiliate of the assigning Party with an equal or greater credit rating and with the legal authority
and operational ability to satisfy the obligations of the assigning Party under this Agreement.

8.3 The Customer Generator has the right to contingently assign this Agreement,
without the consent of the Company, for collateral security purposes to aid in providing financing
for the Generation Facility, provided that the Customer Generator will promptly notify the
Company of any such contingent assignment.

8.4 Any attempted assignment that violates this Section 6 is void and ineffective.
Assignment shall not relieve a Party of its obligations, nor shall the non-assigning Party’s
obligations be enlarged, in whole or in part, by reason thereof. An assignee is responsible for
meeting the same financial, credit, and insurance obligations as the Customer Generator. Where
required, consent to assignment will not be unreasonably withheld, conditioned or delayed.

9. Indemnity. To the fullest extent permitted by law, Customer Generator shall indemnify,
defend, reimburse, and hold harmless the Company and its successors and their respective directors,
officers, members, employees, representatives, and agents (collectively, the “Indemnitees”), from, for,
and against any and all third-party allegations, claims, liens, liabilities, losses, demands, damages,
expenses, suits, actions, proceedings, judgments, and costs of any kind whatsoever, including, without
limitation, settlement costs, court costs, and attorneys’ and expert witness fees and expenses
(collectively, “Damages”), whether actual or merely alleged, and whether directly incurred or incurred by
a third party, arising out of, or relating to a) the negligent acts, omissions, or willful misconduct of
Customer Generator, b) a violation of federal or state law, regulation, statute, or ordinance, or c)
Customer Generator’s material breach of this Agreement. If the Company seeks indemnification from
the Customer Generator, the Company shall: (i) notify Customer Generator of the assertion of any claim;
(ii) provide reasonable assistance (at Customer Generator’s expense) in connection with the defense;
and (iii) be entitled to pre-approve any settlement.
SECTION 4: ADDITIONAL INTERCONNECTION REQUIREMENTS OF DISTRIBUTED ENERGY
RESOURCES 3 MVA OR GREATER (Continued)
Idaho Power Company Original First Revised Sheet No. 68-23
Cancels
I.P.U.C. No. 30, Tariff No. 101First RevisedOriginal Sheet No. 68-23
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36067 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

IDAHO POWER COMPANY
UNIFORM CUSTOMER GENERATOR
INTERCONNECTION AGREEMENT
(Continued)

AGREEMENT (Continued)

11. Insurance. During the term of this Agreement, Customer Generator shall secure and
continuously carry the following insurance coverage Comprehensive General Liability Insurance for both
bodily injury and property damage with limits equal to $1,000,000, each occurrence, combined single
limit. The deductible for such insurance shall be consistent with current Insurance Industry Utility
practices for similar property. Such insurance coverage shall be placed with an insurance company with
an A.M. Best Company rating of A- or better and shall include:

11.1 An endorsement naming Idaho Power as an additional insured and loss payee as
applicable; and

11.2 A provision stating that such policy shall not be canceled, or the limits of liability
reduced without sixty (60) days’ prior written notice to Idaho Power.

11.1 Customer Generator to Provide Certificate of Insurance. As required in
Paragraph 11 herein and annually thereafter, Customer Generator shall furnish the Company a
certificate of insurance, together with the endorsements required therein, evidencing the coverage
as set forth above.

11.2 Customer Generator to Notify Idaho Power of Loss of Coverage. If the insurance
coverage required by Paragraph 11.1 shall lapse for any reason, Customer Generator will
immediately notify Idaho Power in writing. The notice will advise Idaho Power of the specific
reason for the lapse and the steps Customer Generator is taking to reinstate the coverage.
Failure to provide this notice and to expeditiously reinstate or replace the coverage will constitute
grounds for a temporary disconnection under Section 9.2 and will be a Material Breach.

12. Miscellaneous.

12.1 Governing Law. This Agreement shall be interpreted, applied and enforced in
accordance with the laws of the State of Idaho without regard to its conflicts of law principles.

Idaho Power Company Original First Revised Sheet No. 68-24
Cancels
I.P.U.C. No. 30, Tariff No. 101First RevisedOriginal Sheet No. 68-24
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36067 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

SECTION 4: ADDITIONAL INTERCONNECTION REQUIREMENTS OF DISTRIBUTED ENERGY
RESOURCES 3 MVA OR GREATER (Continued)

IDAHO POWER COMPANY
UNIFORM CUSTOMER GENERATOR
INTERCONNECTION AGREEMENT
(Continued)

AGREEMENT (Continued)

9.1 The Parties shall at all times indemnify, defend, and hold the other Party harmless
from, any and all damages, losses, claims, including claims and actions relating to injury to or
death of any person or damage to property, demand, suits, recoveries, costs and expenses, court
costs, attorney fees, and all other obligations by or to third parties, arising out of or resulting from
the other Party’s action or failure to meet its obligations under this Agreement on behalf of the
indemnifying Party, except in cases of gross negligence or intentional wrongdoing by the
indemnified Party.

9.2 If an indemnified person is entitled to indemnification under this article as a result
of a claim by a third party, and the indemnifying Party fails, after notice and reasonable opportunity
to proceed under this article, to assume the defense of such claim, such indemnified person may
at the expense of the indemnifying Party contest, settle or consent to the entry of any judgment
with respect to, or pay in full, such claim. Failure to defend is a Material Breach.

9.3 If an indemnifying party is obligated to indemnify and hold any indemnified person
harmless under this article, the amount owing to the indemnified person shall be the amount of
such indemnified person’s actual loss, net of any insurance or other recovery.

10. Force Majeure Event. Neither Party shall be liable for any breach, default, or delay in
the performance of the obligations under this Agreement if and to the extent such default or delay is
caused by fire, flood, earthquake, elements of nature or acts of God, riots, civil disorder, rebellions or
revolutions, strikes, lockouts or other industrial disturbances, unanticipated changes in governmental
laws and regulations, or any other cause beyond the reasonable control of such Party (a “Force Majeure
Event”); provided the non-performing Party is without fault in causing such breach, default, or delay, and
such breach, default or delay could not have been prevented by reasonable precautions and cannot
reasonably be circumvented by the non-performing Party through the use of alternate sources, work-
around plans, or other means. The Party claiming a Force Majeure Event must give the other Party
immediate written notice, no later than five (5) calendar days of the Party’s discovery of the Force Majeure
Event, and the time for resumption of performance (if applicable) by that Party. The suspension of
performance shall be of no greater scope and of no longer duration than is required by the Force Majeure
Event.

Idaho Power Company Original First Revised Sheet No. 68-24
Cancels
I.P.U.C. No. 30, Tariff No. 101First RevisedOriginal Sheet No. 68-24
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36067 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho
SECTION 4: ADDITIONAL INTERCONNECTION REQUIREMENTS OF DISTRIBUTED ENERGY
RESOURCES 3 MVA OR GREATER (Continued)

IDAHO POWER COMPANY
UNIFORM CUSTOMER GENERATOR
INTERCONNECTION AGREEMENT
(Continued)

AGREEMENT (Continued)

12.2 Net Salvage Value. If removal of the Interconnection Facilities is required, within
sixty (60) days after the termination or expiration of this Agreement, Idaho Power will provide
Customer Generator an estimate of the remaining value of the Company-Furnished
Interconnection Facilities required under Schedule 68 and/or described in this Agreement, less
the cost of removal and transfer to Idaho Power’s warehouse (“Net Salvage Value”). If Customer
Generator elects not to purchase the Interconnection Facilities from the Company, Idaho Power
will reimburse the Customer Generator the Net Salvage Value as estimated by Idaho Power.
Customer Generator shall invoice Idaho Power for the same and Customer Generator shall have
the right to offset the invoice amount with amounts due to Idaho Power from Customer Generator.

13. Notices. Any changes to the below contacts must be made via written notice pursuant to
Section 13.1.

13.1 Written Notice. Where required herein, written notice shall be deemed to have
been duly served when (i) delivered in person, or (ii) sent by mail or courier, return receipt
requested, at the address for each Party as follows:

If to the Customer Generator:
Customer Generator:
Attention:
Address:
City: State: Zip:

If to the Company:
Company:
Attention:
Address:
City: State: Zip:

Idaho Power Company Original First Revised Sheet No. 68-25
Cancels
I.P.U.C. No. 30, Tariff No. 101First RevisedOriginal Sheet No. 68-25
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36067 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

SECTION 4: ADDITIONAL INTERCONNECTION REQUIREMENTS OF DISTRIBUTED ENERGY
RESOURCES 3 MVA OR GREATER (Continued)

IDAHO POWER COMPANY
UNIFORM CUSTOMER GENERATOR
INTERCONNECTION AGREEMENT
(Continued)

AGREEMENT (Continued)

11. Insurance. During the term of this Agreement, Customer Generator shall secure and
continuously carry the following insurance coverage Comprehensive General Liability Insurance for both
bodily injury and property damage with limits equal to $1,000,000, each occurrence, combined single
limit. The deductible for such insurance shall be consistent with current Insurance Industry Utility
practices for similar property. Such insurance coverage shall be placed with an insurance company with
an A.M. Best Company rating of A- or better and shall include:

11.1 An endorsement naming Idaho Power as an additional insured and loss payee as
applicable; and

11.2 A provision stating that such policy shall not be canceled, or the limits of liability
reduced without sixty (60) days’ prior written notice to Idaho Power.

11.1 Customer Generator to Provide Certificate of Insurance. As required in
Paragraph 11 herein and annually thereafter, Customer Generator shall furnish the Company a
certificate of insurance, together with the endorsements required therein, evidencing the coverage
as set forth above.

11.2 Customer Generator to Notify Idaho Power of Loss of Coverage. If the insurance
coverage required by Paragraph 11.1 shall lapse for any reason, Customer Generator will
immediately notify Idaho Power in writing. The notice will advise Idaho Power of the specific
reason for the lapse and the steps Customer Generator is taking to reinstate the coverage.
Failure to provide this notice and to expeditiously reinstate or replace the coverage will constitute
grounds for a temporary disconnection under Section 9.2 and will be a Material Breach.

12. Miscellaneous.

12.1 Governing Law. This Agreement shall be interpreted, applied and enforced in
accordance with the laws of the State of Idaho without regard to its conflicts of law principles.

SECTION 4: ADDITIONAL INTERCONNECTION REQUIREMENTS OF DISTRIBUTED ENERGY
RESOURCES 3 MVA OR GREATER (Continued)

IDAHO POWER COMPANY
UNIFORM CUSTOMER GENERATOR
Idaho Power Company Original First Revised Sheet No. 68-25
Cancels
I.P.U.C. No. 30, Tariff No. 101First RevisedOriginal Sheet No. 68-25
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36067 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho
INTERCONNECTION AGREEMENT
(Continued)

AGREEMENT (Continued)

13.2 Designated Operating Representative. The Parties may also designate an
operating representative to communicate regarding administration of this Agreement, as well as
operations and maintenance of such Party’s facilities; provided that, any “written notice” required
by this Agreement must be made as set forth in the above Section 13.1.

Customer Generator’s Operating Representative:
Customer Generator:
Attention:
Address:
City: State: Zip:
Phone: Email:

Company’s Operating Representative:
Company:
Attention:
Address:
City: State: Zip:
Phone: Email:

IN WITNESS WHEREOF, the Parties hereto enter this Uniform Customer Generator Agreement
to be effective as of the Effective Date.

Idaho Power Company
Print:
Sign:
Title:
Date:

Customer Generator
Print:
Sign:
Title:
Date:
Idaho Power Company Original First Revised Sheet No. 68-26
Cancels
I.P.U.C. No. 30, Tariff No. 101First RevisedOriginal Sheet No. 68-26
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36067 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

SECTION 4: ADDITIONAL INTERCONNECTION REQUIREMENTS OF DISTRIBUTED ENERGY
RESOURCES 3 MVA OR GREATER (Continued)

IDAHO POWER COMPANY
UNIFORM CUSTOMER GENERATOR
INTERCONNECTION AGREEMENT
(Continued)

AGREEMENT (Continued)

12.2 Net Salvage Value. If removal of the Interconnection Facilities is required, within
sixty (60) days after the termination or expiration of this Agreement, Idaho Power will provide
Customer Generator an estimate of the remaining value of the Company-Furnished
Interconnection Facilities required under Schedule 68 and/or described in this Agreement, less
the cost of removal and transfer to Idaho Power’s warehouse (“Net Salvage Value”). If Customer
Generator elects not to purchase the Interconnection Facilities from the Company, Idaho Power
will reimburse the Customer Generator the Net Salvage Value as estimated by Idaho Power.
Customer Generator shall invoice Idaho Power for the same and Customer Generator shall have
the right to offset the invoice amount with amounts due to Idaho Power from Customer Generator.

13. Notices. Any changes to the below contacts must be made via written notice pursuant to
Section 13.1.

13.1 Written Notice. Where required herein, written notice shall be deemed to have
been duly served when (i) delivered in person, or (ii) sent by mail or courier, return receipt
requested, at the address for each Party as follows:

If to the Customer Generator:
Customer Generator:
Attention:
Address:
City: State: Zip:

If to the Company:
Company:
Attention:
Address:
City: State: Zip:

SECTION 4: ADDITIONAL INTERCONNECTION REQUIREMENTS OF DISTRIBUTED ENERGY
RESOURCES 3 MVA OR GREATER (Continued)

IDAHO POWER COMPANY
Idaho Power Company Original First Revised Sheet No. 68-26
Cancels
I.P.U.C. No. 30, Tariff No. 101First RevisedOriginal Sheet No. 68-26
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36067 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho
UNIFORM CUSTOMER GENERATOR
INTERCONNECTION AGREEMENT
(Continued)

Attachment 1

Description and Costs of the Customer Generator System, Interconnection Facilities and Metering
Equipment

In this attachment, the Customer Generator System and Interconnection Facilities, including
Special Facilities and upgrades, are itemized and identified as being owned by the Customer Generator
or the Company. As provided in Schedule 68, Cost of Interconnection Facilities, the Company will provide
a best estimate itemized cost of its Interconnection Facilities, including Special Facilities, upgrades and
Metering Equipment.

Attachment 2

One-line Diagram Depicting the Customer Generator System, Interconnection Facilities, Metering
Equipment and Upgrades

Idaho Power Company Original First Revised Sheet No. 68-27
Cancels
I.P.U.C. No. 30, Tariff No. 101First RevisedOriginal Sheet No. 68-27
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36067 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

SECTION 4: ADDITIONAL INTERCONNECTION REQUIREMENTS OF DISTRIBUTED ENERGY
RESOURCES 3 MVA OR GREATER (Continued)

IDAHO POWER COMPANY
UNIFORM CUSTOMER GENERATOR
INTERCONNECTION AGREEMENT
(Continued)

AGREEMENT (Continued)

13.2 Designated Operating Representative. The Parties may also designate an
operating representative to communicate regarding administration of this Agreement, as well as
operations and maintenance of such Party’s facilities; provided that, any “written notice” required
by this Agreement must be made as set forth in the above Section 13.1.

Customer Generator’s Operating Representative:
Customer Generator:
Attention:
Address:
City: State: Zip:
Phone: Email:

Company’s Operating Representative:
Company:
Attention:
Address:
City: State: Zip:
Phone: Email:

IN WITNESS WHEREOF, the Parties hereto enter this Uniform Customer Generator Agreement
to be effective as of the Effective Date.

Idaho Power Company
Print:
Sign:
Title:
Date:

Customer Generator
Print:
Sign:
Title:
Date:
Idaho Power Company Original First Revised Sheet No. 68-27
Cancels
I.P.U.C. No. 30, Tariff No. 101First RevisedOriginal Sheet No. 68-27
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36067 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho
SECTION 4: ADDITIONAL INTERCONNECTION REQUIREMENTS OF DISTRIBUTED ENERGY
RESOURCES 3 MVA OR GREATER (Continued)

IDAHO POWER COMPANY
UNIFORM CUSTOMER GENERATOR
INTERCONNECTION AGREEMENT
(Continued)

Attachment 3

Milestones

In-Service Date: ___________________

Critical milestones and responsibility as agreed to by the Parties:

Milestone/Date Responsible Party

(1) _______________________________________ ______________________
(2) _______________________________________ ______________________
(3) _______________________________________ ______________________
(4) _______________________________________ ______________________
(5) _______________________________________ ______________________
(6) _______________________________________ ______________________
(7) _______________________________________ ______________________
(8) _______________________________________ ______________________
(9) _______________________________________ ______________________
(10) _______________________________________ ______________________

Agreed to by:

For the Company __________________________ Date______________

For the Customer Generator________________________ Date______________

Idaho Power Company Original First Revised Sheet No. 68-28
Cancels
I.P.U.C. No. 30, Tariff No. 101First RevisedOriginal Sheet No. 68-28
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36067 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

SECTION 4: ADDITIONAL INTERCONNECTION REQUIREMENTS OF DISTRIBUTED ENERGY
RESOURCES 3 MVA OR GREATER (Continued)

IDAHO POWER COMPANY
UNIFORM CUSTOMER GENERATOR
INTERCONNECTION AGREEMENT
(Continued)
Attachment 1

Description and Costs of the Customer Generator System, Interconnection Facilities and Metering
Equipment

In this attachment, the Customer Generator System and Interconnection Facilities, including
Special Facilities and upgrades, are itemized and identified as being owned by the Customer Generator
or the Company. As provided in Schedule 68, Cost of Interconnection Facilities, the Company will provide
a best estimate itemized cost of its Interconnection Facilities, including Special Facilities, upgrades and
Metering Equipment.

Attachment 2

One-line Diagram Depicting the Customer Generator System, Interconnection Facilities, Metering
Equipment and Upgrades

Attachment 3

Milestones

In-Service Date: ___________________

Critical milestones and responsibility as agreed to by the Parties:

Milestone/Date Responsible Party

(1) _______________________________________ ______________________
(2) _______________________________________ ______________________
(3) _______________________________________ ______________________
(4) _______________________________________ ______________________
(5) _______________________________________ ______________________
(6) _______________________________________ ______________________
(7) _______________________________________ ______________________
(8) _______________________________________ ______________________
(9) _______________________________________ ______________________
(10) _______________________________________ ______________________
Attachment 4

Idaho Power Company Original First Revised Sheet No. 68-28
Cancels
I.P.U.C. No. 30, Tariff No. 101First RevisedOriginal Sheet No. 68-28
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36067 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho
Additional Operating Requirements for the Company’s Transmission System and Affected
Systems Needed to Support the Customer Generator’s Needs

The Company shall also provide requirements that must be met by the Customer Generator prior
to initiating Parallel operation with the Company’s Transmission System.

Attachment 5

Reactive Power Requirements

Idaho Power will determine the reactive power required to be supplied by the Company to the
Customer Generator, based upon information provided by the Customer Generator. The Company will
specify the equipment required on the Company’s system to meet the Facility’s reactive power
requirements. These specifications will include but not be limited to equipment specifications, equipment
location, Company-provided equipment, Customer Generator provided equipment, and all costs
associated with the equipment, design and installation of the Company-provided equipment. The
equipment specifications and requirements will become an integral part of this Agreement. The
Company-owned equipment will be maintained by the Company, with total cost of purchase, installation,
operation, and maintenance, including administrative cost to be reimbursed to the Company by the
Customer Generator. Payment of these costs will be in accordance with Schedule 68 and the total
reactive power cost will be included in the calculation of the monthly facilities charge.

Attachment 6

Company’s Description of Upgrades Required to Integrate the Generation Facility and Best
Estimate of Upgrade Costs

As provided in Schedule 68, this Attachment describes Upgrades, including best work upgrades,
and provides an itemized best estimate of the cost of the Upgrades.
Idaho Power Company

I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 68-29
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

SECTION 4: ADDITIONAL INTERCONNECTION REQUIREMENTS OF DISTRIBUTED ENERGY
RESOURCES 3 MVA OR GREATER (Continued)

IDAHO POWER COMPANY
UNIFORM CUSTOMER GENERATOR
INTERCONNECTION AGREEMENT
(Continued)

Attachment 3 (Continued)

Agreed to by:

For the Company __________________________ Date______________

For the Customer Generator________________________ Date______________

Attachment 4

Additional Operating Requirements for the Company’s Transmission System and Affected
Systems Needed to Support the Customer Generator’s Needs

The Company shall also provide requirements that must be met by the Customer Generator prior
to initiating Parallel operation with the Company’s Transmission System.

Attachment 5

Reactive Power Requirements

Idaho Power will determine the reactive power required to be supplied by the Company to the
Customer Generator, based upon information provided by the Customer Generator. The Company will
specify the equipment required on the Company’s system to meet the Facility’s reactive power
requirements. These specifications will include but not be limited to equipment specifications, equipment
location, Company-provided equipment, Customer Generator provided equipment, and all costs
associated with the equipment, design and installation of the Company-provided equipment. The
equipment specifications and requirements will become an integral part of this Agreement. The
Company-owned equipment will be maintained by the Company, with total cost of purchase, installation,
operation, and maintenance, including administrative cost to be reimbursed to the Company by the
Customer Generator. Payment of these costs will be in accordance with Schedule 68 and the total
reactive power cost will be included in the calculation of the monthly facilities charge.

Attachment 6

Company’s Description of Upgrades Required to Integrate the Generation Facility and Best
Estimate of Upgrade Costs

As provided in Schedule 68, this Attachment describes Upgrades, including best work upgrades,
and provides an itemized best estimate of the cost of the Upgrades.

BEFORE THE

IDAHO PUBLIC UTILITIES COMMISSION

CASE NO. IPC-E-26-27

IDAHO POWER COMPANY

ATTACHMENT 2
PROPOSED CHANGES TO
SCHEDULE 68
Idaho Power Company First Revised Sheet No. 68-1
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 68-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2026 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES

AVAILABILITY

Service under this schedule is available throughout the Company’s service area within the State
of Idaho to all Customer Generators owning or operating DERs, in Parallel with the Company’s system
and located on the customer’s side of the Interconnection Point, that qualify for Schedule 6, Schedule 8,
Schedule 84, or Non-Export as defined in this schedule. DERs with Total Nameplate Capacity of 3 MVA
or greater are required to sign a Uniform Customer Generator Interconnection Agreement.

APPLICABILITY

Service under this schedule applies to construction, operation, and maintenance of a Customer
Generator System interconnected in Parallel with the Company’s system. In limited circumstances,
certain interconnection requirements included in this schedule may not be applicable when the Company
determines the DER relies on a technology, such as regenerative drives, that does not jeopardize grid
stability or reliability. In making its determination, the Company will evaluate criteria such as the
magnitude and duration of exports.

DEFINITIONS

Company is the Idaho Power Company.

Company-Furnished Facilities are those portions of the Interconnection Facilities funded by the
Customer Generator and provided by the Company.

Customer Generator is a Customer or prospective Customer applying to operate or operating a
DER in Parallel with the Company’s system.

Customer Generator-Furnished Facilities are those portions of the Interconnection Facilities
provided by the Customer Generator.

Customer Generator Application Process are the steps a Customer Generator must complete to
interconnect DERs less than 3 MVA with the Company’s system unless they are eligible for and elect to
use the Customer Generator Registration Process.

Customer Generator Interconnection Process are the steps a Customer Generator must complete
to connect a DER to the Company’s system and includes the Customer Generator Application Process
or Customer Generator Registration Process.is the Company’s DER interconnection application,
engineering review, construction, and inspection process for Customer Generator Systems. The
Customer Generator Interconnection Process intends to ensure a safe and reliable generation
interconnection in compliance with all applicable regulatory requirements, good utility practices, and
national safety standards.

Commented [IPC1]: Broadens the availability to include
DERs that qualify for the proposed registration process
Commented [IPC2]: Standalone definition for the
application process to separate it from the registration process
Commented [IPC3]: Change to include both the application
and registration processes as part of the interconnection
process
Idaho Power Company First Revised Sheet No. 68-1
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 68-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2026 1221 West Idaho Street, Boise, Idaho
Customer Generator Registration Process are the steps a Customer Generator must complete to
interconnect DERs with the Company’s System when the DERs meet the eligibility requirements outlined
in Section 2.

Customer Generator System is an Exporting System, or a Non-Exporting System, or a system
eligible for the Customer Generator Registration Process.

Customer Representative is a person or entity identified by the Customer Generator who is
authorized to communicate with the Company on the Customer Generator’s behalf.

Disconnection Equipment is any device or combination of devices by which the Company can
manually and/or automatically interrupt the flow of energy from the Customer Generator to the Company’s
system, including enclosures or other equipment as may be required to ensure that only the Company
will have access to the devices.

Commented [IPC4]: Standalone definition for the
registration process to separate it from the application process
Commented [IPC5]: Change to also include systems that
interconnect under the registration process
Idaho Power Company First Revised Sheet No. 68-2
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 68-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2026 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

DEFINITIONS (Continued)

Distributed Energy Resource(s) (DER(s)) is a source of electric power that is not directly
connected to the bulk power system. Any combination of Generation Facilities and/or Energy Storage
Devices connected in Parallel is considered a DER.

Energy Storage Device is a device that captures energy produced at a point in time and stores
the energy for use as electricity at a future point in time. An Energy Storage Device is a DER.

Exporting System is a Customer-owned DER under the terms of Schedules 6, 8, or 84, which is
designed to provide for the transfer of electric energy to the Company.

Feasibility Review is the Company’s standard engineering review of a proposed Customer
Generator System and is intended to ensure the Company’s system is equipped to incorporate the
proposed Customer Generator-Furnished Facilities in a manner that conforms with good utility practices
and the National Electric Safety Code.

Feasibility Study is the Company’s more detailed engineering assessment for DERs as
determined by the Feasibility Review. This study is intended to ensure that the Company’s system is
sufficiently equipped to incorporate proposed DERs in a manner that conforms with good utility practices
and the National Electric Safety Code, including protection coordination and system voltage
management.

Generation Facility means equipment used to produce electric energy at a specific physical
location and service point that qualifies for Schedules 6, 8, 84, or Non-Export. A Generation Facility is a
DER.

Inadvertent Export is the unplanned, unscheduled, and uncompensated transfer of electrical
energy from a Customer’s Non-Exporting System to the Company’s system across the Interconnection
Point.

Incomplete Application or Registration Form is an application or registration form missing any
information needed to satisfy the requirements of the Customer Generator Interconnection Process;
including but not limited to, Customer Generator signature, the application fee, and details about the
Generation Facility.

Interconnection Facilities are all facilities which are reasonably required by good utility practices
and the National Electric Safety Code to interconnect and to allow for Parallel operations of the DER with
the Company’s system, including, but not limited to, Special Facilities, Disconnection Equipment, and
Metering Equipment.

Interconnection Point is the point where the Customer Generator’s conductors connect to the
facilities owned by the Company.

Commented [IPC6]: Adds Registration Form as part of this
definition
Idaho Power Company First Revised Sheet No. 68-2
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 68-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2026 1221 West Idaho Street, Boise, Idaho
Like-for-Like Inverter Replacement is when a Customer Generator replaces an existing inverter
with an inverter of the same make, model, and capacity, without making any additional system
modifications.

Metering Equipment is the Company owned equipment required to measure, record or telemeter
power flows between the Customer Generator and the Company’s system.

Commented [IPC7]: Added to specify what a like-for-like
inverter replacement encompasses
Idaho Power Company Original Sheet No. 68-3
Cancels
I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. 68-3
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36042 & 36048 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

DEFINITIONS (Continued)

Non-Exporting System is a Customer-owned DER that limits or prevents electrical energy from
transferring to the Company’s system.

Parallel connection means operating a DER that is connected to and receives voltage from Idaho
Power’s system.

Protection Equipment is the equipment, hardware, and/or software necessary to ensure the
protection of the Company’s system and could include a circuit-interrupting device, protective relaying,
instrument transformers, and associated wiring.

Relocation is a change in the location of existing Company-owned transmission and/or distribution
lines, poles, or equipment.

Smart Inverter is an inverter that conforms to the latest IEEE 1547 standards and is certified by
the UL 1741 standard, which complies with the latest IEEE 1547 standards.

Special Facilities are additions to or alterations of transmission and/or distribution lines and
transformers, including, but not limited to, Upgrades and Relocation, to safely interconnect the
Customer’s DER to the Company’s system.

System Verification Form is the form that a Customer must provide to the Company prior to the
connection of the Customer Generator System as part of the Customer Generator Application Process
as described in this schedule.

Total Nameplate Capacity is the total of the gross capacity of a DER as designated by the
manufacturer(s) maximum continuous operating rating of the DER in Alternating Current (AC), or as
determined by Idaho Power based on information provided on the application and System Verification
Form or registration form.

Upgrades are those improvements to the Company’s existing system, which are reasonably
required by good practices and the National Electric Safety Code to interconnect the Customer Generator
System safely. Such improvements include, but are not limited to, additional or larger conductors,
transformers, poles, and related equipment.

Commented [IPC8]: Added to specify this is only part of the
application process
Commented [IPC9]: Added to accommodate the
registration process
Idaho Power Company First Revised Sheet No. 68-4
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 68-4
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2026 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

SECTION 1: GENERAL INTERCONNECTION REQUIREMENTS

The following provisions apply to all Customer Generators requesting interconnection to the
Company’s system.

CONSTRUCTION AND OPERATION OF INTERCONNECTION FACILITIES

All Customer Generator-Furnished Interconnection Facilities will be constructed and maintained
in a manner as determined by the Company to be in full compliance with all good utility practices,
including the Company’s Customer Requirements for Electric Service (found at
idahopower.com/requirements), National Electric Safety Code, conforms to the IEEE 1547 standards,
and all other applicable federal, state, and local safety and electrical codes and standards at all times.

The Customer Generator shall:

1. Upon request, submit proof to the Company that all licenses, permits, inspections, and
approvals necessary for the construction and operation of the Customer’s DER and Interconnection
Facilities under this schedule have been obtained from applicable federal, state, or local authorities.

2. Upon request, submit the designs, plans, specifications, settings, and performance data
for the DER and Customer Generator-Furnished Facilities to the Company for review. The Company’s
acceptance shall not be construed as confirming or endorsing the design, or as a warranty of safety,
durability, or reliability of the DER or Customer Generator-Furnished Facilities. The Company will retain
the right to inspect this equipment at its discretion.

3. Demonstrate to the Company’s satisfaction that the Customer’s DER and Customer
Generator-Furnished Facilities have been completed, and that all features and equipment of the
Customer’s DER and Customer Generator-Furnished Facilities are capable of operating safely to
commence deliveries of energy into the Company’s system.

4. Should a Customer move a DER to a new service point, the Customer must initiate and
complete the Customer Generator Interconnection Process.

5. DERs must be listed by UL or other recognized standards, that may include but are not
limited to UL 1741 SB, IEEE 1547-2018, UL 3700 and UL 3141.

46. Provide and maintain adequate Protection Equipment sufficient to prevent damage to the
DER, Customer Generator-Furnished Facilities, and any other Customer Generator-owned facilities in
conformance with all applicable electrical and safety codes and requirements.

57. Provide and maintain Disconnection Equipment as required by the Company in
accordance with all applicable electrical and safety codes and requirements as described within this
Schedule.

68. Upon request, provide a 24-hour telephone contact(s). This contact will be used by the
Company to arrange for repairs and inspections or in case of an emergency. The Company will make its
Commented [IPC10]: The Company expects that portable
systems will be moved to new service points more frequently,
this specifies that Customers will need to complete the
registration process each time that happens
Commented [IPC11]: Added to make clear what standards
the Company will require all DERs to meet
Commented [IPC12]: Specifies as required by the
Company as systems eligible for the registration process will
not be required to have disconnection equipment
Idaho Power Company Original Sheet No. 68-5
Cancels
I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. 68-5
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36042 & 36048 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

SECTION 1: GENERAL INTERCONNECTION REQUIREMENTS (Continued)

DISCONNECTION EQUIPMENT

Disconnection Equipment is required for all Customer DERs initially subject to the Customer
Generator Application Process. The Disconnection Equipment shall be installed at an electrical location
to allow complete isolation of Customer’s DER and Interconnection Facilities from the Company’s system.
Disconnection Equipment will be installed at an electrical location on the Customer Generator’s side of
the Company’s retail metering point to allow complete isolation of the Customer’s DER and
Interconnection Facilities from the Customer Generator’s other electrical load and service.

The Disconnection Equipment’s operating device shall be:

1. Readily accessible by the Company at all times.

2. Clearly marked “Generation Disconnect Switch” or similar language, as approved by Idaho
Power, with permanent 3/8 inch or larger letters.

3. Physically installed and visible within 10 feet of the Interconnection Point or permanently-
posted instructions at the Interconnection Point indicating the exact location of the Disconnection
Equipment’s operating device. Instructions with lamination or in plastic sleeves do not satisfy this
requirement.

4. Of a design manually operated and lockable in the open position with a standard Company
padlock.

5. Equipped with a visual disconnect that enables the Company to visually confirm that the
Customer’s and Company’s conductors are physically disconnected. This requires the ability to inspect
the actual conductors visually. Circuit breakers do not satisfy this requirement.

6. Disconnection Equipment meeting the requirements in this section is recommended but
not required for inverter-based systems without Energy Storage Devices where the aggregate Total
Nameplate Capacity of all DERs behind the Customer’s meter does not exceed 400 VA AC and where
the Customer takes metered service under Schedules 1, 5, or 7.

Operation of Disconnection Equipment. If, in the reasonable opinion of the Company, the
Customer Generator’s operation or maintenance of the DER or Interconnection Facilities is unsafe, not
in compliance with this schedule, or may otherwise adversely affect the Company’s equipment,
personnel, or service to its customers, the Company may physically disconnect the Customer’s DER or
Interconnection Facilities by operation of the disconnection device or by any other means the Company
deems necessary to adequately disconnect the Customer’s DER and Interconnection Facilities from the
Company’s system. At such time as the unsafe condition is remedied or other condition adversely
affecting the Company is resolved to the Company’s satisfaction, the interconnection will be restored.

The Company will disconnect the Customer’s DER and Interconnection Facilities in the event of
any planned or unplanned maintenance or repair of the Company’s system connected to the Customer’s
Commented [IPC13]: Specifies DERs that are required to
have disconnection equipment as DERs eligible for the
registration process are not required to
Commented [IPC14]: Defines which DERs are not required
to have disconnection equipment
Idaho Power Company Original Sheet No. 68-6
Cancels
I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. 68-6
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36042 & 36048 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

SECTION 1: GENERAL INTERCONNECTION REQUIREMENTS (Continued)

DISCONNECTION EQUIPMENT (Continued)

The Company will disconnect the Customer’s DER and Interconnection Facilities in the event that
any terms and conditions of any applicable Company tariff or contract enabling the interconnection of the
Customer’s DER are deemed by the Company to be in default or delinquent.

Customer Generators will be subject to disconnection and reconnection charges if the expenses
are incurred as the result of a DER and/or a Customer’s failure to abide by the provisions of Schedule
68.

Disconnection of the service may be necessary. The disconnection may result in the interruption
of both energy deliveries from the Customer Generator System to the Company as well as the interruption
of energy deliveries from the Company to the Customer Generator. Disconnection provisions specific to
DERs less than 3 MVA are described further in Section 2 of this schedule. Disconnection provisions
specific to DERs 3 MVA or greater are described further in Section 4 of this schedule.

The Company will establish the settings of Protection Equipment to disconnect the Customer’s
DER and Interconnection Facilities for the protection of the Company’s system and personnel consistent
with good utility practices. If the Customer Generator attempts to modify, adjust or otherwise interfere
with the Protection Equipment or its settings as established by the Company, such action may be grounds
for the Company’s refusal to continue interconnection of the Customer’s DER and Interconnection
Facilities to the Company’s system.

GENERAL REQUIREMENTS OF CUSTOMER GENERATOR SYSTEMS

1. The Company will construct, own, operate and maintain all equipment, Upgrades, and
Relocations on the Company’s electrical side of the Interconnection Point.

2. The Company will may clearly mark the Metering Equipment and any other Company
equipment associated with the Customer’s DER and/or Interconnection Facilities designating the
existence of the Customer’s DER as required by good utility practices.

3. The Customer Generator will be required to submit all specific designs, equipment
specifications/settings, and test results of the Customer Generator-Furnished Facilities to the Company
for review upon request by the Company. Upon receipt of the design and equipment specifications, the
Company will review the design and equipment specifications for conformance with applicable electrical
and safety codes and standards.

4. Customer Generator-Furnished Facilities will be operated and maintained by the
Customer Generator at the Customer Generator’s sole risk and expense. The Company’s review of any
Customer attestations or subsequent approval to proceed does not transfer liability to the Company for
any damages or injury caused by the DER. The Company shall not be liable directly or indirectly for
permitting or continuing to allow an attachment of a Customer Generator System to the Company’s
Commented [IPC15]: The Company will not go out and
mark systems that come through the registration process
Idaho Power Company First Revised Sheet No. 68-8
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 68-8
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2026 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

SECTION 1: GENERAL INTERCONNECTION REQUIREMENTS (Continued)

ENERGY STORAGE DEVICE (Continued)

2. AC Coupled:

i. AC Coupled with an Exporting System: For an Energy Storage Device coupled
with an Exporting System taking service under Schedules 6, 8, or 84, the Total Nameplate
Capacity is the aggregate Total Nameplate Capacity of all DERs on the Customer’s side of the
Interconnection Point.

ii. AC Coupled with a Non-Exporting System: An Energy Storage Device coupled
with a Non-Exporting System is subject to the provisions of Section 3 of this Schedule. The Total
Nameplate Capacity of the Energy Storage Device shall be considered 0 kVA.

APPLICATION EXPIRATION

Applications from a Customer Generator with existing retail service that are not completed within
one year of the initial Feasibility Review are considered expired. Applications from a Customer Generator
without existing retail service that has not completed the Customer Generator Interconnection Process
requirements by the requested project in-service date identitifedidentified on the completed application
will be considered expired.

Registration forms from a Customer Generator with existing retail service that are not completed
within one year of receipt are considered expired.

Customer Generators requesting connection or approval of expired applications are required to
resubmit a completed application form and a $100 non-refundable application fee and are subject to the
full application process described in Section 2.

RECERTIFICATION

1. The Company may perform full recertification inspections of Customer Generator Systems
at the Company’s discretion and at no charge to the Customer Generator. The Company will provide the
Customer Generator with written notice at least fourteen (14) calendar days prior to performing a
recertification inspection. Recertification inspections will be performed in the same manner as new
Customer Generator System inspections described in Section 2. Customers may choose to verify the
results of the Company’s inspection through an independent inspection performed by a certified third-
party at the Customer Generator’s expense.

2. If in the reasonable opinion of the Company, the Customer Generator’s operation or
maintenance of the DER or Interconnection Facilities is unsafe, not in compliance with this schedule, or
may otherwise adversely affect the Company’s equipment, personnel, or service to its customers, the
Company reserves the right to inspect any Customer Generator System at any time, and without prior
notice.
Commented [IPC17]: Defines when registration forms
expire
Idaho Power Company First Revised Sheet No. 68-9
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 68-9
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2026 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

SECTION 1: GENERAL INTERCONNECTION REQUIREMENTS (Continued)

SYSTEM MODIFICATIONS

1. Any modifications to Customer Generator Systems that increase the Total Nameplate
Capacity of the system or modify the system in any way (including inverter replacements) that may impact
the safety or reliability of the Company’s electrical system are considered system modifications for the
purposes of this schedule.

2. Customer Generators planning to make system modifications must complete the
Customer Generation Interconnection Process including submitting applicable forms and fees. submit an
application, a $100 non-refundable fee, and complete the application process according to the
procedures required for new interconnection.

3. System modifications without gaining prior Company approval are considered
unauthorized installations subject to the provisions of this schedule as described in Unauthorized
Installations and Expansions.

UNAUTHORIZED INSTALLATIONS AND EXPANSIONS

1. Customer Generator Systems that have been interconnected to the Company’s system
without Company approval are considered unauthorized installations that jeopardize the reliability of
Idaho Power’s system and the safety of its employees. This includes, but is not limited to, newly installed
systems and unapproved expansions or other modifications of approved systems. The process
described herein provides the Company with the ability to offer Customer Generation in an efficient, safe,
and reliable manner.

2. Unauthorized installations are subject to immediate Company inspection and
disconnection without notice. The Company will provide the reason for the disconnection of the
Customer’s DER. The Customer will be called and written, or electronic notification will be sent. The
Customer will have twelve (12) months from the notification date to notify the Company and complete
one of the options listed under 5(a) and 5(b).

3. If proper disconnection equipment is present, the Company will open the disconnect or
notify the Customer to open the disconnect immediately.

4. If proper disconnection equipment is not present, the Customer Generator must
disconnect the DER from operating in Parallel with the Company’s system immediately by turning off the
breaker or by other means necessary.

5. The Customer must complete and notify the Company of one of the below options within
twelve (12) months from the notification date:

a. Option 1: Complete the full Customer Generator Interconnection Process
described in Section 2, and the system will be re-energized.
Commented [IPC18]: Broadens to include both the
application and registration processes
Idaho Power Company First Revised Sheet No. 68-10
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 68-10
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2026 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

SECTION 1: GENERAL INTERCONNECTION REQUIREMENTS (Continued)

UNAUTHORIZED INSTALLATIONS AND EXPANSIONS (Continued)

b. Option 2: Permanently disable the DER from Parallel operations with the
Company system. Permanent disablement of the DER requires an inspection to be scheduled
with the Company within twelve (12) months from the postmarked notification date. Customers
that do not meet this deadline schedule within this time period will be subject to termination of
service. Permanent disablement of the DER may require an inspection or other attestation from
the Customer Generator that the system is disabled.

6. If it is determined, at the sole discretion of the Company, that an unauthorized Customer
Generation System, expansion, or other system modification results in damage to equipment on the
Company’s system, the Customer will be responsible for all costs associated with replacing the
Company’s damaged equipment and defend, indemnify, and reimburse the Company for liabilities or
damages incurred by the Company for third-party claims arising out of the Customer Generator’s
unauthorized connection.

PERMANENTLY REMOVED OR DISABLED SYSTEMS

The Customer shall notify the Company immediately if a DER is permanently removed or
disabled. Permanent removal or disablement for the purposes of this Schedule is any removal or
disablement of a DER lasting longer than six (6) months. If the Customer wishes to interconnect the DER
after six (6) months, the Customer Generator must reapply and meet the interconnection requirements
in place at the time of application.

SECTION 2: INTERCONNECTION PROCESS REQUIREMENTS FOR DISTRIBUTED ENERGY
RESOURCES LESS THAN 3 MVA

Customer Generators requesting to interconnect a DER less than 3 MVA shall complete the
Application Process prior to interconnection unless they are eligible for and elect to use the Customer
Generator Registration Process. The following section is applicable to all DERs with Total Nameplate
Capacity less than 3 MVA.

It is within Idaho Power’s sole discretion to disconnect, or refuse to connect, any Customer
Generator System that does not pass inspection, poses a threat to public safety, or has unanticipated
impacts to Idaho Power’s system. In these situations, a Company representative will send a written
communication to the Customer Generator regarding Idaho Power’s inability to connect/reconnect the
Customer Generator System until the issue(s) is resolved. Idaho Power will continue working with the
Customer to resolve the issue(s) required to connect the Customer’s System. Idaho Power will re-inspect
the System upon receiving notice from the Customer indicating Customer’s Generation System meets all
applicable federal, state, and local requirements and is suitable for connection.

REGISTRATION PROCESS
Commented [IPC19]: The Company will not inspect DERs
that come through the registration process for permanent
disablement
Commented [IPC20]: Expanded to explain which
interconnection process a customer must complete
Commented [IPC21]: Moved from the application process
section as it applies to both the application and registration
processes
Commented [IPC22]: Eligibility requirements and process
for the registration option
Idaho Power Company First Revised Sheet No. 68-10
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 68-10
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2026 1221 West Idaho Street, Boise, Idaho

Customers with DERs that meet one of the following eligibility requirements may use the Customer
Generator Registration Process:
 Inverter based systems without Energy Storage Devices where the aggregate Total
Nameplate Capacity of all DERs behind the Customer’s meter does not exceed 400 Volt-
Amps (VA) AC and where the Customer has active and continues to take metered service
under Schedules 1, 5, or 7.
 Like-For-Like Inverter Replacements

Customers Generators using the Customer Generator Registration Process are required to submit an
applicable registration form to the Company providing information about the DER and certifying
compliance with Schedule 68. Registration forms are available on the Company’s website or will be
provided to the Customer by email or mail upon request. Incomplete Registration Forms are considered
withdrawn after sixty (60) days from the date the form was received.

The Company will review the registration form within seven (7) business days and inform the
Customer:
i. If additional information is needed in order to review the DER. Additional information may
include but is not limited to single lines diagrams or product specification sheets. A
registration form will be considered incomplete until the information is provided.
ii. If the DER does not meet the requirements of Schedule 68.
iii. If Upgrades are needed in order to approve the project. Upgrades will be subject to Section
2, Part 3 and Part 4 of Schedule 68.
iv. If additional time is needed to review the registration, the Company may request an
additional fifteen (15) business days.
v. If the project is approved to interconnect.

The Customer Generator Registration Process is complete when the Company confirms in writing
that the Customer Generator System is registered with Idaho Power.

If the DER system components, capacity, or configuration changes from the original registration
form, the Customer Generator must resubmit a registration form that will be subject to a new review.

APPLICATION PROCESS

Customer Generators requesting to interconnect a DER less than 3 MVA are required to complete the
following application process prior to interconnection: Customers Generators using the Customer
Generator Application Process are required to complete the following:

1. Customer Generators must submit a completed application form and a $100 non-
refundable application fee to the Company. Applications are available on the Company’s website or will
be provided to the Customer upon request. Incomplete Applications are considered withdrawn after sixty
(60) days from the date the application was received.

2. Upon receipt of a completed application and a $100 non-refundable fee, the Company will
either (1) provide the Customer with a written or electronic notification that the application has been
received and all necessary information has been provided, or (2) request the Customer provide forms of
documentation outlined in Section 1.

Commented [IPC23]: Specifies the application process
Idaho Power Company First Revised Sheet No. 68-11
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 68-11
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2026 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

SECTION 2: INTERCONNECTION PROCESS REQUIREMENTS FOR DISTRIBUTED ENERGY
RESOURCES LESS THAN 3 MVA (Continued)

APPLICATION PROCESS (Continued)

If the DER system components, capacity, or configuration changes from the original application,
the Customer Generator will be subject to a new Feasibility Review.

If the Customer Generator changes its Customer Representative, a new application and a $100
non-refundable application fee is required.

3. The Company will perform within seven (7) business days, unless it is determined that
additional studies are necessary, the Feasibility Review based on Total Nameplate Capacity and other
project information provided in the application. The Feasibility Review determines the capability of the
Company’s electrical system to incorporate the proposed Customer Generator System and determines
if Upgrades are necessary. For a Customer Generator who does not yet have established service, the
Feasibility Review will occur as part of the Company’s evaluation for Upgrades for new customers
conducted in compliance with Rule H – New Service Attachments and Distribution Line Installations or
Alterations.

a. If the results of the Feasibility Review indicate satisfactory system capability, the
Company will provide the Customer with an official “Approval to Proceed” notification.

b. If the results of the Feasibility Review indicate that Upgrades are necessary to
accommodate the proposed project, the Company will notify the Customer through written or
electronic notification of such Upgrades. Funding, construction, installation, and maintenance of
required Upgrades will be subject to the Company’s standard Rule H regarding New Service
Attachments and Distribution Line Installations or Alterations.

c. If the Company determines that additional time is necessary to determine
satisfactory system capability or that Upgrades are necessary to accommodate the proposed
project, the Company will notify the Customer. The Company will perform within fifteen (15)
business days the additional studies to complete the Feasibility Review.

4. If the results of the Feasibility Review require the need for a Feasibility Study, the
Company will provide the Customer with a FeasiblityFeasibility Study Agreement which requires a deposit
of $1,000 and must be signed and returned within fifteen (15) business days. Upon receipt of the signed
Feasibility Study Agreement and deposit, the Company will perform the FeasiblityFeasibility Study within
thirty (30) business days. If the results of the Feasibility Study indicate that Upgrades or Protection
Equipment are necessary to accommodate the proposed project, the Company will notify the Customer
of such Upgrades or Protection Equipment. At the Company’s discretion, additional studies referenced
in Section 4 may be applicable.

a. Installation and funding of the construction, installation, and maintenance
of required Protection Equipment will be subject to the following provisions:

Idaho Power Company First Revised Sheet No. 68-13
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 68-13
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2026 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

SECTION 2: INTERCONNECTION PROCESS REQUIREMENTS FOR DISTRIBUTED ENERGY
RESOURCES LESS THAN 3 MVA (Continued)

APPLICATION PROCESS (Continued)

g. Verification of Smart Inverters, including the settings for all inverter-based DERs
100 kVA and greater.
h. Verification of Total Nameplate Capacity.
i. Verification of plant controller for all DERs 500 kVA and greater.

7. A return trip charge of $52.00 will be billed to the Customer each time Company personnel
are dispatched to the job site but are unable to conduct the on-site inspection due to one or more of the
conditions not being met that had been certified as complete by the Customer or Customer’s
Representative, as identified on the System Verification Form.

8. Successful completion of the Company on-site inspection constitutes the conclusion of the
application process. The Company must make a reasonable effort to move an Exporting Customer
Generator to the appropriate rate schedule within five (5) business days. The rate change will be no later
than the Customer’s next Billing Period following their successfully completed inspection. Upon
completion of this process, the Customer will receive confirmation that the application process has been
successfully completed.

9. It is within Idaho Power’s sole discretion to disconnect, or refuse to connect, any Customer
Generator System that does not pass inspection, poses a threat to public safety, or has unanticipated
impacts to Idaho Power’s system. In these situations, a Company representative will send a written
communication to the Customer Generator regarding Idaho Power’s inability to connect/reconnect the
Customer Generator System until the issue(s) is resolved. Idaho Power will continue working with the
Customer to resolve the issue(s) required to connect the Customer’s System. Idaho Power will re-inspect
the System upon receiving notice from the Customer indicating Customer’s Generation System meets all
applicable federal, state, and local requirements and is suitable for connection.

SECTION 3: ADDITIONAL INTERCONNECTION REQUIREMENTS OF NON-EXPORTING
SYSTEMS

In addition to the requirements of Section 1, the following section is applicable to all Customer
Generators electing to establish their system as Non-Export.

NON-EXPORT TOTAL NAMEPLATE CAPACITY LIMIT

For customers taking service under Schedules 1, 5, or Schedule 7 that own and/or operate a
Generation Facility, service is subject to an aggregate DER Total Nameplate Capacity of 25 kVA or less,
that is operated in Parallel with the Idaho Power System. The capacity of an Energy Storage Device shall
not be used to calculate the 25 kVA capacity limit but will be used to calculate Total Nameplate Capacity
for the FeasbilityFeasibility Review.

Commented [IPC24]: Expanded to include Schedule 5
Idaho Power Company First Revised Sheet No. 68-15
Cancels
I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 68-15
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2026 1221 West Idaho Street, Boise, Idaho

SCHEDULE 68
INTERCONNECTIONS TO CUSTOMER
DISTRIBUTED ENERGY RESOURCES
(Continued)

SECTION 3: ADDITIONAL INTERCONNECTION REQUIREMENTS OF NON-EXPORTING
SYSTEMS (Continued)

UNAUTHORIZED INADVERTENT EXPORT (Continued)

1. The Company will notify the Non-Export Customer Generator that their Customer
Generator System has exceeded the Inadvertent Export limit.

2. After notification of Inadvertent Export, the following will occur:

a. For Schedules 1, 5, or Residential and Schedule 7, Small General Non-Exporting
Systems, the Customer Generator must immediately disconnect the DER until the issue(s) is
resolved and rectify Inadvertent Export within 30 days after receipt of the notification by Idaho
Power that the Non-Exporting System has exceeded the Inadvertent Export limit. If the Customer
Generator has not rectified Inadvertent Export after 30 days, at the Customer’s election, one of
the following actions will occur:

i. The Customer Generator SystemDER must be permanently disconnected
from the Company’s system. disconnect will be placed in the open (off) position until the
issue that caused the export is remedied. A Company inspection will be requiredA
Customer Generator must complete the Customer Generator Interconnection Process
before the Non-Exporting System can interconnect to the Company’s system; or,

ii. The Customer may apply to take service as an Exporting System
subject to the full requirement for exporting systems outlined in this Schedule and
Schedules 6 or 8, as applicable. If the Customer does not elect to open the
disconnect, the Customer Generator will be placed on Schedule 6 or Schedule 8,
as appropriate, and subject to applicable provisions of Section 2. If the Customer
elects to be placed on Schedule 6 or Schedule 8, the Customer will be given the
option to submit an additional application and be moved back to Schedule 1 or
Schedule 7, as appropriate, after 180 days.

b. For Schedules other than Schedules 1, 5, or Schedule 7:

i. Upon receipt of the notification by Idaho Power that the Customer
Generator’s Non-Exporting System has exceeded the Inadvertent Export limit, the
Customer Generator System disconnect will be placed in the open position until the issue
that caused the export is remedied. A Company inspection will be required before the
Non-Exporting System can interconnect to the Company’s system.

3. If it is determined, at the sole discretion of the Company, that unauthorized Inadvertent
Export results in damage to equipment on the Company’s system, the Customer Generator will be
responsible for all costs associated with replacing the Company’s damaged equipment and defend,
indemnify, and reimburse the Company for liabilities or damages incurred by the Company for third-party
claims arising out of the Customer Generator’s unauthorized Inadvertent Export.
Commented [IPC25]: Expanded to include Schedule 5 and
updated to accommodate systems that come through the
registration process
Commented [IPC26]: Expanded to include Schedule 5