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HomeMy WebLinkAbout20240110Supplemental Compliance Filing.pdf Connie Aschenbrenner Rate Design Senior Manager caschenbrenner@idahopower.com January 10, 2024 Commission Secretary Idaho Public Utilities Commission 11331 W. Chinden Boulevard Building 8, Suite 201-A Boise, Idaho 83714 Re: Supplemental Compliance Filing Case No. IPC-E-23-11 – (Idaho Power Company’s 2023 General Rate Case) Case No. IPC-E-23-14 – (Authority to Implement Changes to the Compensation Structure Applicable to On-Site Generation) Dear Commission Secretary: On Friday, December 29, 2023, Idaho Power Company (“Idaho Power” or “Company”) filed an initial Compliance Filing pursuant to Idaho Public Utilities Commission (“Commission”) Order Nos. 36042 (IPC-E-23-11), 36048 (IPC-E-23-14), and 36036 (IPC- E-23-28) with tariff sheets that would become effective January 1, 2024, in compliance with those orders. At the time, the Company indicated it was still evaluating what additional tariff modifications would be necessary to effectuate Order No. 36048 in Case No. IPC-E-23-14 and intended to follow-up with a second compliance filing to that end. Since then the Company has worked with Commission Staff to identify and incorporate changes necessary to implement the directives mandated by the Commission in Order No. 36048 relative to Schedules 6, 8, 68, and 84. In addition, as a result of its comprehensive review of the other rules and schedules submitted by the Company with the December 29th Compliance Filing, Staff recommended various grammatical and clarifying edits to limit the potential for customer confusion, which the Company agrees are necessary to help ensure customer understandability of the new tariff sheets. Accordingly, in order to incorporate the directives from the relevant Commission orders as well as the clarifying edits identified by Commission Staff in its review, the Company respectfully makes this Second Supplemental Compliance Filing submitting the following Rules and Tariff Schedules, to replace, in their entirety, the corresponding sheets filed with the Company’s initial Compliance Filing dated December 29, 2023. To assist the Commission and the Commission Staff in its review, the Company is submitting “redlines” from the “clean” tariff sheets that were submitted on December 29, RECEIVED 2024 Janury 10, AM 8:57 IDAHO PUBLIC UTILITIES COMMISSION Commission Secretary Idaho Public Utilities Commission January 10, 2024 Page 2 2023. Additionally, the following table summarizes the substantive changes incorporated into the replacement tariff sheets: Rule/Schedule Page Update Rule D 1 Updated header to reflect correct versioning of page number. Rule E 1 Updated header to reflect correct versioning of page number. Schedule 6 6 Added tariff language re: transferability of financial credits pursuant to Order No. 36048. 8 Added section headings to clarify applicability of time periods. 9 Updated Export Credit Rates pursuant to Order No. 36048. Schedule 8 5 Added tariff language re: transferability of financial credits pursuant to Order No. 36048. 7 Added section heading and corrected time periods for the Export Credit Rate. 8 Updated Export Credit Rates pursuant to Order No. 36048. Schedule 20 4 Updated language describing holidays to be consistent with Schedule 19. Schedule 41 3 Added note to clarify Option B is discontinued. Schedule 54 1 & 2 Removed reference to Schedule 4. Schedule 68 11 Added tariff language re: requirement for a deposit in advance of a Feasibility Study pursuant to Order No. 36048. Schedule 84 2 Added tariff language re: applicability of demand-based project eligibility cap pursuant to Order No. 36048. 3 Updated header to reflect correct page number and updated numbering necessary from changes on page number 2. 6 & 7 Added tariff language re: transferability of financial credits pursuant to Order No. 36048. 9 Added section heading to “time periods” and updated Export Credit Rates pursuant to Order No. 36048. The Company is appreciative of Staff’s review in this matter and believes the contained tariff schedules reflect all changes necessary to effectuate the Commission’s orders. If you have any questions about the attached documents, please do not hesitate to contact me. Very truly yours, Connie Aschenbrenner CA:sg Enclosures Idaho Power Company Original Sheet No. D-1 Cancels I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. D-1 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 36042 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho RULE D METERING 1. Meter Installations. The Company will install and maintain the metering equipment required by the Company to measure power and energy supplied to the Customer. Meter installations will be done at the Company's expense except as specified below or otherwise specified in a schedule. Customer provisions for meter installations will be made in conformance with Company specifications, the National Electrical Code, and/or applicable state or municipal requirements. a. Instrument Transformer Metering. When instrument transformer metering is requested by the Customer but not required by the Company at the time of the initial meter installation, the Customer will be required to pay the cost of such metering equipment and its installation in accordance with the charges specified in Schedule 66. When a Customer requests instrument transformer metering not required by the Company at a time other than at the time of the initial meter installation, work order costs will apply. b. Load Profile Metering. The Company will install, at the Customer’s request, the metering equipment necessary to provide load profile information. When Load Profile Metering service is requested by the Customer but not provided by the Company as part of its standard meter installation, the Customer will pay work order costs for the installation of all equipment required to provide such service. The options available under Load Profile Metering service include: Pulse Output Service, which provides limited kWh and kW load information; Load Profile Recording Service, which downloads load characteristics and information on a delayed basis; and Enhanced Metering Information Service, which provides real-time access to load characteristics and information. Customers requesting that the Company provide Load Profile Metering service are responsible for providing, at their own expense, a hard-wired or wireless connection to each metering point, and all such connection equipment will be owned by the Customer unless the configuration of metering equipment necessitates otherwise. The Company shall not be liable to any Customer or any other persons for any loss or damage incurred resulting from the supply or interruption of any Load Profile Metering service. The Company does not warrant or guarantee the accuracy, reliability, validity or usability of the information or data provided by its Load Profile Metering service, and Customers receiving any such Load Profile Metering service voluntarily assume all responsibility and risk in use of such service’s information or data. c. Primary Voltage Metering. The Company will install, at its own expense, a maximum of one primary voltage meter at a single Premises to record usage taken at 12.5 kV or 34.5 kV. In all other circumstances, work order costs will apply. 2. Measurement of Energy. Except as otherwise specifically provided, all energy delivered by the Company will be billed according to measurement by meters located at or near the Point of Delivery. If the Company is unable to obtain a Customer's meter reading(s), the Company may estimate the meter reading(s) for the Billing Period on the basis of the Customer's previous use, season of the year and use by similar Customers of the same class in that service area. Bills rendered based on an estimated monthly read, or when a Billing Period includes more than twenty-four unscaled hourly reads, will be designated as estimated on the bill. The amount of such estimated bill will be subsequently adjusted, when practicable, when the next actual reading is obtained. Idaho Power Company Original Sheet No. D-2 Cancels I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. D-2 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 36042 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho RULE D METERING (Continued) 3. Failure to Register. If the Company's meters fail to register at any time, the service delivered and energy consumed during such period of failure will be determined by the Company on the basis of the best available data. If any appliance or wiring connection, or any other device, is found on the Customer's Premises which prevents the meters from accurately recording the total amount of energy used on the Premises, the Company may at once remove any such wiring connection or appliance, or device, at the Customer's expense, and will estimate the amount of energy so consumed and not registered as accurately as it is able so to do, and the Customer will pay for any such energy within 5 days after being billed, in accordance with such estimate. 4. Meter Tests. The Company will test and inspect its meters from time to time and maintain their accuracy of registration in accordance with generally accepted practices and the rules and regulations established by the Idaho Public Utilities Commission. The Company will, without charge, test the accuracy of registration of a meter upon request of a Customer, provided that the Customer does not request such a test more frequently than once in a 12-month period. If more than one requested test is performed within a 12-month period, the Customer will be required to pay in advance the cost of a special meter test as specified in Schedule 66. The Company will refund the amount paid by the Customer for the test if the results of the test show the average registration error of the meter exceeds ±2 percent. 5. Transformer Losses. When delivery of service is on the primary side of the Customer's transformers, the Company may install its meters on the secondary side of the transformers, and, unless otherwise provided in the schedule, in determining the monthly consumption of power and energy, transformer losses and other losses occurring between the Point of Delivery and the meters will be computed and added to the reading of such meters. 6. Meter Reading. Meters will be read to the last kWh registered, normally at intervals of approximately 30 days for monthly register reads and daily for hourly interval reads. In no case will the meter reading interval exceed 45 days. Idaho Power Company Original Sheet No. E-1 Cancels I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. E-1 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 36042 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho RULE E MASTER METERING STANDARDS 1. Definitions: a. Tenant--Mobile Home Park. A tenant of a mobile home park is a person defined as a resident and not a transient by the Manufactured Home Residency Act, Section 55-2001 et seq., Idaho Code, and in particular by Section 55-2003(16) and 55-2003(19), Idaho Code. b. Tenant--Multi-Unit Residential or Commercial Building. A tenant of a multi-unit residential building is a person who is not a transient and who intends to reside in or be a commercial tenant in one of the building's units for a period of not less than one month. 2. Master-Metering and Individual Metering in Mobile Home Parks: a. Master Metering Prohibited. Master-metering, whether or not in conjunction with sub-metering of electric service by the park operator, is prohibited for any mobile home park connected for service by the Company after July 1, 1980. After that date, tenants (excluding transients) of mobile home parks must be individually metered and billed by the Company. b. Exception for Sub-Metered Parks. Any mobile home park connected for service on or before July 1, 1980, whose spaces for non-transient tenants have been fully sub-metered for electricity by the park owners need not be individually metered by the Company. A mobile home park sub-metered by the park operator must charge each of their tenants the same rate for electric service that a Customer of the Company would be charged if the tenant were directly metered and billed by the Company under Schedule 3 – Master-Metered Mobile Home Park – Residential Service. Testing of sub-meters will be at the park operator's expense. 3. Master-Metering and Individual Metering in Multi-Occupant Residential Buildings. Non- transient tenants of multi-occupant residential buildings connected for electric service after July 1, 1980, will be individually metered and billed by the Company if the dwelling units for such tenants contain an electric space heating, water heating, or air-conditioning (space cooling) unit that is not centrally controlled and for which said tenants individually control electric usage. 4. Master-Metering and Individual Metering in Commercial Buildings and Shopping Centers. Commercial buildings and shopping centers connected for electric service after July 1, 1980, may not be master-metered if the units for non-transient tenants contain an electric space heating, water heating, or air-conditioning (space cooling) unit that is not centrally controlled and for which the unit's tenants individually control electric usage. Any non-transient tenants in otherwise master- metered buildings will be individually metered and billed by the Company if the tenant’s electric load is significantly greater than that of the other tenants in the building or shopping center, or exceeds the individual metering threshold found in the Company's Tariff. Idaho Power Company Original Sheet No. 6-1 Cancels I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. 6-1 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 6 RESIDENTIAL SERVICE ON-SITE GENERATION AVAILABILITY Service under this schedule is available at points on the Company's interconnected system within the State of Idaho where existing facilities of adequate capacity and desired phase and voltage are adjacent to the location where Residential Service, On-Site Generation is desired, and where additional investment by the Company for new transmission, substation or terminal facilities is not necessary to supply the desired service. This service is available to Customers intending to operate Exporting Systems to generate electricity to reduce all or part of the monthly energy usage. Standard rates will be applicable unless a Customer elects time-of-use. Time-of-use is an optional, voluntary service that provides Customers the option to take electric service with seasonal time- of-use energy rates. If a Customer requests to participate in the optional time-of-use service, the Customer will be placed on time-of-use under this schedule effective with their next billing cycle. A Customer may terminate their participation in the time-of-use service at any time. However, the Customer may not subsequently elect time-of-use service under this schedule for one year after the effective date of cancellation. If a Customer requests to be taken off of time-of-use service under this schedule, the Customer will be moved back to the default service under this schedule as of the last meter read date. Effective December 21, 2019, Schedule 6 is closed to new applications for Net Energy Metering. APPLICABILITY Service under this schedule is applicable to Electric Service required for residential service Customers for general domestic uses, including single phase motors of 7½ horsepower rating or less, subject to the following conditions: 1. When a portion of a dwelling is used regularly for business, professional or other gainful purposes, or when service is supplied in whole or in part for business, professional, or other gainful purposes, the Premises will be classified as non-residential and the appropriate General Service Schedule will apply. However, if the wiring is so arranged that the service for residential purposes can be metered separately, this schedule will be applied to such service. 2. Whenever the Customer's equipment does not conform to the Company's specifications for service under this schedule, service will be supplied under the appropriate General Service Schedule. 3. This schedule is not applicable to standby service, service for resale, or shared service. 4. Customer owns and/or operates a Generation Facility fueled by solar, wind, biomass, geothermal, hydropower or represents fuel cell technology, with a total nameplate capacity rating of 25 kilowatts (kW) or less, that is connected in Parallel with the Idaho Power System. The capacity of an Energy Storage Device shall not be used to calculate the capacity limits in this schedule. 5. The Generation Facility is interconnected to the Customer’s individual electric system on the Customer’s side of the Point of Delivery, thus all energy received and delivered by the Company is through the Company’s existing watt-hour retail meter. Idaho Power Company Original Sheet No. 6-2 Cancels I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. 6-2 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 6 RESIDENTIAL SERVICE ON-SITE GENERATION (Continued) APPLICABILITY (Continued) 6. Customer meets all applicable requirements detailed in the Company’s Schedule 68, Interconnections to Customer Distributed Energy Resources. 7. Legacy Status for eligible Exporting Systems will terminate December 2045. 8. The Legacy Status of the Exporting System is transferrable to a subsequent Customer at the premises for which a valid on-site generation service is in effect. Each Customer of a Legacy System taking service under Schedule 6 will be responsible for complying with the terms and conditions of the on-site generation service in effect for that premises. 9. A Legacy System that is offline for over six (6) months or that is moved to a different site shall forfeit Legacy Status of the Exporting System. 10. To remain eligible for Legacy Status, a Customer may increase the capacity of a Legacy System by no more than 10 percent of the originally installed nameplate capacity, or 1 kW, whichever is greater, to allow for the replacement of broken or degraded components. If a Customer expands a Legacy System beyond these limits, the new portion of the DER shall be separately metered and would not qualify for Legacy Status. DEFINITIONS Designated Meter is the retail meter physically connected to the Exporting System. 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 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. Excess Net Energy means the positive difference between the kilowatt-hours (kWh) generated by a Customer and the kWh supplied by the Company over the applicable Billing Period. Exported Energy means the kWh generated by a Customer in excess of the Customer’s on-site consumption that is exported to the Company’s system. 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. An Exporting System is interconnected to the Company’s system under the applicable terms of Schedule 68. Generation Facility means all equipment used to generate electric energy where the resulting energy is delivered to the Company via a single meter at the Point of Delivery or is consumed by the Customer. A Generation Facility is a DER. Idaho Power Company Original Sheet No. 6-3 Cancels I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. 6-3 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 6 RESIDENTIAL SERVICE ON-SITE GENERATION (Continued) DEFINITIONS (Continued) Interconnection Facilities are all facilities reasonably required by Prudent Electrical Practices and the applicable electric and safety codes to interconnect and safely deliver energy from the DER to the Point of Delivery. Legacy Status refers to the ability for a system to receive Net Energy Metering, including net monthly one-for-one kWh credit compensation for Excess Net Energy. Legacy System means any system that meets the applicable criteria as described in Order Nos. 34509 and 34546. Net Billing is the compensation structure applicable to all systems that do not meet the criteria of a Legacy System. Net Billing will be effective with each eligible customer’s first billing cycle after January 1, 2024. Net Energy Metering is the compensation structure applicable to all Legacy Systems. Parallel connection means generating electricity from an on-site generation system that is connected to and receives voltage from Idaho Power’s system. Point of Delivery is the retail metering point where the Company's and the Customer’s electrical facilities are interconnected to allow the Customer to take retail electric service from the Company. Prudent Electrical Practices are those practices, methods and equipment that are commonly used in prudent electrical engineering and operations to operate electric equipment lawfully and with safety, dependability, efficiency and economy. Schedule 68 is the Company’s service schedule which provides for interconnection to DERs or its successor schedule(s) as approved by the Commission. TYPE OF SERVICE The type of service provided under this schedule is single phase, alternating current at approximately 120 or 240 volts and 60 cycles, supplied through one meter at one Point of Delivery. Upon request by the owner of multi-family dwellings, the Company may provide 120/208 volt service for multi- family dwellings when all equipment is U L approved to operate at 120/208 volts. Idaho Power Company Original Sheet No. 6-4 Cancels I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. 6-4 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 6 RESIDENTIAL SERVICE ON-SITE GENERATION (Continued) NET ENERGY METERING - CONDITIONS OF PURCHASE AND SALE The conditions listed below shall apply to all transactions for Net Energy Metering under this schedule. 1. Balances of generation and usage by the Customer: a. If electricity supplied by the Company during the Billing Period exceeds the electricity generated by the Customer and delivered to the Company during the Billing Period, the Customer shall be billed for the net electricity supplied by the Company at the rates contained within this schedule, in accordance with normal metering practices. b. If electricity generated by the Customer and delivered to the Company during the Billing Period exceeds the electricity supplied by the Company during the Billing Period, the Excess Net Energy shall be carried forward as a kWh credit to offset energy usage in a subsequent Billing Period. Excess Net Energy credits are subject to the following provisions: i. Credits can only be used to offset billed kWh consumption. Customers shall be billed for all applicable non-energy charges for the Billing Period according to the applicable standard service schedule. ii. Credits shall carry forward provided the Customer maintains electric service at the same Point of Delivery. iii. Credits are non-transferrable in the event that a Customer relocates and/or discontinues service at the Point of Delivery associated with the Exporting System. Any unused credits will expire at the time the final bill is prepared. c. Compensation for the balance of generation and usage by the Customer is subject to change upon Commission approval. 2. Aggregation of meters for the annual transfer of unused Excess Net Energy credits: a. If a balance of Excess Net Energy credits exists at a Designated Meter the Customer may request to transfer the unused credits to offset energy consumption at eligible meters. A meter is eligible for aggregation if it meets all of the following criteria: Idaho Power Company Original Sheet No. 6-5 Cancels I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. 6-5 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 6 RESIDENTIAL SERVICE ON-SITE GENERATION (Continued) NET ENERGY METERING - CONDITIONS OF PURCHASE AND SALE (Continued) i. The account subject to offset is held by the Customer; and ii. The meter is located on, or contiguous to, the property on which the Designated Meter is located. For the purposes of this tariff, contiguous property includes property that is separated from the Premises of the Designated Meter by public or railroad rights of way; and iii. The meter is served by the same primary feeder as the Designated Meter at the time the Customer files the application for the Exporting System; and iv. The electricity recorded by the meter is for the Customer’s requirements; and v. Credits may only be transferred to meters taking service under Schedule 1, Schedule 6, Schedule 7, or Schedule 8. b. Customers may submit requests to transfer Excess Net Energy credits between December 1 and January 31 of each year. All requests must be received by Idaho Power by midnight, Mountain Standard Time, on January 31. If a Customer does not request to transfer Excess Net Energy credits by the January 31 submission deadline Excess Net Energy credits will carry forward to offset consumption at the Designated Meter until they become eligible the following year. c. Requests to transfer Excess Net Energy credits must be executed by the Company no later than March 31. Transfers will be based on the balance of Excess Net Energy credits available at the time the transfer is made. d. If multiple meters are eligible for aggregation, Excess Net Energy credits must first be applied to the Designated Meter, then to eligible meters on rate schedules in accordance with Section 2a(v) above. e. A meter aggregation fee of $10.00 will be assessed per aggregated meter per annual transfer transaction. NET BILLING – CONDITIONS OF PURCHASE AND SALE The conditions listed below shall apply to all transactions for Net Billing under this schedule. 1. Balances of usage and exports by the Customer. a. The Customer shall be billed for the electricity supplied by the Company at the rates contained within this schedule, in accordance with normal metering practices. Idaho Power Company Original Sheet No. 6-6 Cancels I.P.U.C. No. 30, Tariff No. 101 Sixth Revised Sheet No. 6-6 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 6 RESIDENTIAL SERVICE ON-SITE GENERATION (Continued) NET BILLING – CONDITIONS OF PURCHASE AND SALE (Continued) b. The Customer shall be credited for Exported Energy at the applicable Export Credit Rate contained within this schedule as a credit in dollars to only offset Monthly Charges. Exported Energy credits are subject to the following provisions: i. Credits shall carry forward provided the Customer maintains electric service at the same Point of Delivery. ii. Credits are transferrable in the event that a Customer relocates. If the establishment of service at the new Point of Delivery is not initiated at the time service at the Designated Meter is discontinued, it is the Customer’s responsibility to request the credit transfer when service is established at the new location in Idaho Power’s service area. iii. If a Customer discontinues services at the Point of Delivery associated with the Exporting System and does not intend to establish service at another location in Idaho Power’s service area any unused credits will be paid out following the time the final bill is prepared. 2. Aggregation of meters for the annual transfer of unused credits: a. If a balance of credits exists at a Designated Meter, the Customer may request to transfer the unused credits to eligible meters. A meter is eligible for aggregation if it meets the following criteria: i. The account subject to offset is held by the Customer, and ii. The electricity recorded by the meter is for the Customer’s requirements. b. Customers may submit requests to transfer a stated percentage of available credits between December 1 and January 31 of each year. All requests must be received by Idaho Power by midnight, Mountain Standard Time, on January 31. If a Customer does not request to transfer credits by the January 31 submission deadline credits will carry forward at the Designated Meter until they become eligible for transfer the following year. c. Requests to transfer credits must be executed by the Company no later than March 31. Transfers will be based on the balance of credits available at the time the transfer is made. d. A meter aggregation fee of $10.00 will be assessed per aggregated meter per annual transfer transaction. Idaho Power Company I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 6-7 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 6 RESIDENTIAL SERVICE ON-SITE GENERATION (Continued) NET ENERGY METERING & NET BILLING – GENERAL CONDITIONS 1. The Customer shall never deliver or attempt to deliver energy to the Company’s system when the Company’s system serving the Customer’s DER is de-energized for any reason. 2. The Company shall not be liable directly or indirectly for permitting or continuing to allow an attachment of an Exporting System to the Company’s system, or for the acts or omissions of the Customer that cause loss or injury, including death, to any third party. 3. The Customer is responsible for all costs associated with the DER and Interconnection Facilities. The Customer is also responsible for all costs associated with any Company additions, modifications, or upgrades to any Company facilities that the Company determines are necessary as a result of the installation of the DER in order to maintain a safe, reliable electrical system. 4. The Company shall not be obligated to accept, and the Company may require the Customer to curtail, interrupt or reduce deliveries of Energy if the Company, consistent with Prudent Electrical Practices, determines that curtailment, interruption, or reduction is necessary because of line construction or maintenance requirements, emergencies, or other critical operating conditions on its system. 5. If the Company is required by the Commission to institute curtailment of deliveries of electricity to its customers, the Company may require the Customer to curtail its consumption of electricity in the same manner and to the same degree as other Customers on the Company’s standard service schedules. 6. The Customer shall grant to the Company all access to all Company equipment and facilities including adequate and continuing access rights to the property of the Customer for the purpose of installation, operation, maintenance, replacement, or any other service required of said equipment, as well as all necessary access for inspection, switching, and any other operational requirements of the Customer’s Interconnections Facilities. 7. The Customer shall notify the Company immediately if an Exporting System is permanently removed or disabled. Permanent removal or disablement for the purposes of this Schedule is any removal or disablement of an Exporting System lasting longer than six (6) months. Customers with permanently removed or disabled systems will be removed from service under this schedule and placed on the appropriate standard service schedule. . Idaho Power Company I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 6-8 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 6 RESIDENTIAL SERVICE ON-SITE GENERATION (Continued) SUMMER AND NON-SUMMER SEASONS The summer season begins on June 1 of each year and ends on September 30 of each year. The non-summer season begins on October 1 of each year and ends on May 31 of each year. TIME PERIODS – TIME-OF-USE MONTHLY CHARGES The time periods for Time-of-Use Monthly Charges are defined as follows. All times are stated in Mountain Time. Summer Season On-Peak: 7:00 p.m. to 11:00 p.m. Monday through Saturday, except holidays Mid-Peak: 3:00 p.m. to 7:00 p.m. Monday through Saturday, except holidays Off-Peak: 11:00 p.m. to 7:00 p.m. Monday through Saturday and all hours on Sunday and holidays Non-summer Season On-Peak: 7:00 a.m. to 9:00 a.m. and 6:00 p.m. to 9:00 p.m. Monday through Saturday, except holidays Off-Peak: 9:00 a.m. to 6:00 p.m. and 9:00 p.m. to 7:00 a.m. Monday through Saturday and all hours on Sundays and holidays TIME PERIODS – EXPORT CREDIT RATE The time periods for the Export Credit Rate are defined as follows. All times are stated in Mountain Time. Summer Season On-Peak: 3:00 p.m. to 11:00 p.m. Monday through Saturday, except holidays Off-Peak: 11:00 p.m. to 3:00 p.m. Monday through Saturday and all hours on Sunday and holidays Non-summer Season Off-peak: All hours Monday through Sunday Holidays are New Year's Day (January 1), Memorial Day (last Monday in May), Independence Day (July 4), Labor Day (first Monday in September), Thanksgiving Day (fourth Thursday in November), and Christmas Day (December 25). If New Year’s Day, Independence Day, or Christmas Day falls on Sunday, the following Monday will be designated a holiday. Idaho Power Company I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 6-9 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 6 RESIDENTIAL SERVICE ON-SITE GENERATION (Continued) MONTHLY CHARGE The Monthly Charge is the sum of the following charges, and may also include charges as set forth in Schedule 54 (Fixed Cost Adjustment), Schedule 55 (Power Cost Adjustment), Schedule 91 (Energy Efficiency Rider), Schedule 95 (Adjustment for Municipal Franchise Fees), Schedule 96 (Blaine County Surcharge to Fund the Undergrounding of Certain Facilities), and Schedule 98 (Residential and Small Farm Energy Credit). The following rate structure and charges are subject to change upon Commission approval: STANDARD RATES (DEFAULT) Summer Non-summer Service Charge, per month $10.00 $10.00 Energy Charge, per kWh First 800 kWh 10.1082¢ 8.8958¢ 801-2000 kWh 12.1546¢ 9.8073¢ All Additional kWh Over 2000 14.4385¢ 10.8615¢ TIME-OF-USE RATES (OPTIONAL) Summer Non-summer Service Charge, per month $10.00 $10.00 Energy Charge, per kWh On-Peak 24.6472¢ 12.7787¢ Mid-Peak 12.3238¢ n/a Off-Peak 6.1618¢ 8.5191¢ EXPORT CREDIT RATE The following rate structure and credits are subject to change upon Commission approval: Summer Non-summer Export Credit Rate, per kWh On-Peak 16.9966¢ 4.8365¢ Off-Peak 5.6533¢ 4.8365¢ PAYMENT The monthly bill rendered for service supplied hereunder is payable upon receipt, and becomes past due 15 days from the date on which rendered. Idaho Power Company Original Sheet No. 8-1 Cancels I.P.U.C. No. 30, Tariff No. 101 Second Revised Sheet No. 8-1 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 8 SMALL GENERAL SERVICE ON-SITE GENERATION AVAILABILITY Service under this schedule is available at points on the Company's interconnected system within the State of Idaho where existing facilities of adequate capacity and desired phase and voltage are adjacent to the location where Small General Service, On-Site Generation is desired, and where additional investment by the Company for new transmission, substation or terminal facilities is not necessary to supply the desired service. This service is available to Customers intending to operate Exporting Systems under this schedule to generate electricity to reduce all or part of their monthly energy usage. Effective December 21, 2019, Schedule 8 is closed to new applications for Net Energy Metering. APPLICABILITY Service under this schedule is applicable to Electric Service supplied to a Customer at one Point of Delivery and measured through one meter. This schedule is applicable to Customers whose metered energy usage is 2,000 kWh, or less, per Billing Period for ten or more Billing Periods during the most recent 12 consecutive Billing Periods. When the Customer’s Billing Period is less than 27 days or greater than 36 days, the energy usage will be prorated to 30 days for purposes of determining eligibility under this schedule. Customers whose metered energy usage exceeds 2,000 kWh per Billing Period on an actual or prorated basis three times during the most recent 12 consecutive Billing Periods are not eligible for service under this schedule and will be automatically transferred to the applicable schedule effective with the next Billing Period. New customers may initially be placed on this schedule based on estimated usage. This schedule is also applicable to non-profit or tax supported ball fields, fairgrounds or rodeo grounds with high demands and intermittent use exceeding 2,000 kWh per month. This schedule is not applicable to standby service, service for resale, shared service, to individual or multiple family dwellings first served through one meter after February 9, 1982, or to agricultural irrigation service after October 31, 2004. Service under this schedule is also subject to the following conditions: 1. Customer owns/and or operates a Generation Facility fueled by solar, wind, biomass, geothermal, hydropower or represents fuel cell technology, with a total nameplate capacity rating of 25 kilowatts (kW) or less, that is connected in Parallel with the Idaho Power System. The capacity of an Energy Storage Device shall not be used to calculate the capacity limits in this schedule. 2. The Generation Facility is interconnected to the Customer’s individual electric system on the Customer’s side of the Point of Delivery, thus all energy received and delivered by the Company is through the Company’s existing watt-hour retail meter. 3. Customer meets all applicable requirements detailed in the Company’s Schedule 68, Interconnections to Customer Distributed Energy Resources. Idaho Power Company Original Sheet No. 8-2 Cancels I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. 8-2 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 8 SMALL GENERAL SERVICE ON-SITE GENERATION (Continued) APPLICABILITY (Continued) 4. Legacy Status for eligible Exporting Systems will terminate December 2045. 5. The Legacy Status of the Exporting System is transferable to a subsequent Customer at the premises for which a valid on-site generation service is in effect. Each Customer of a Legacy System taking service under Schedule 8 will be responsible for complying with the terms and conditions of the on-site generation service in effect for that premises. 6. A Legacy System that is offline for over six (6) months or that is moved to a different site shall forfeit Legacy Status of the Exporting System. 7. To remain eligible for Legacy Status, a Customer may increase the capacity of a Legacy System by no more than 10 percent of the originally installed nameplate capacity, or 1 kW, whichever is greater, to allow for the replacement of broken or degraded components. If a Customer expands a Legacy System beyond these limits, the new portion of the DER shall be separately metered and would not qualify for Legacy Status. DEFINITIONS Designated Meter is the retail meter physically connected to the Exporting System. 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. Excess Net Energy means the positive difference between the kilowatt-hours (kWh) generated by a Customer and the kWh supplied by the Company over the applicable Billing Period. Exported Energy means the kWh generated by a Customer in excess of the Customer’s on-site consumption that is exported to the Company’s system. 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 electricity energy to the Company. An Exporting System is interconnected to the Company’s system under the applicable terms of Schedule 68. Generation Facility means all equipment used to generate electric energy where the resulting energy is either delivered to the Company via a single meter at the Point of Delivery or is consumed by the Customer. A Generation Facility is a DER. Interconnection Facilities are all facilities reasonably required by Prudent Electrical Practices and the applicable electric and safety codes to interconnect and safely deliver energy from the DER to the Point of Delivery. Idaho Power Company Original Sheet No. 8-3 Cancels I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. 8-3 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 8 SMALL GENERAL SERVICE ON-SITE GENERATION (Continued) DEFINITIONS (Continued) Legacy Status refers to the ability for a system to receive Net Energy Metering, including net monthly one-for-one kWh credit compensation for Excess Net Energy. Legacy System means for any system that meets the applicable criteria as described in Order No. 34509 and 34546. Net Billing is the compensation structure applicable to all systems that do not meet the criteria of a Legacy System. Net Billing will be effective with each eligible customer’s first billing cycle after January 1, 2024. Net Energy Metering is the compensation structure applicable to all Legacy Systems. Parallel connection means generating electricity from an on-site generation system that is connected to and receives voltage from Idaho Power’s system. Point of Delivery is the retail metering point where the Company's and the Customer’s electrical facilities are interconnected to allow the Customer to take retail electric service from the Company. Prudent Electrical Practices are those practices, methods, and equipment that are commonly used in prudent electrical engineering and operations to operate electric equipment lawfully and with safety, dependability, efficiency and economy. Schedule 68 is the Company’s service schedule which provides for interconnection to DERs or its successor schedule(s) as approved by the Commission. TYPE OF SERVICE The type of service provided under this schedule is single and/or three-phase alternating current, at approximately 60 cycles and at the standard service voltage available at the Premises to be served. NET ENERGY METERING - CONDITIONS OF PURCHASE AND SALE The conditions listed below shall apply to all transactions for Net Energy Metering under this schedule. 1. Balances of generation and usage by the Customer: a. If electricity supplied by the Company during the Billing Period exceeds the electricity generated by the Customer and delivered to the Company during the Billing Period, the Customer shall be billed for the net electricity supplied by the Company at the rates contained within this schedule, in accordance with normal metering practices. Idaho Power Company Original Sheet No. 8-4 Cancels I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. 8-4 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 8 SMALL GENERAL SERVICE ON-SITE GENERATION (Continued) NET ENERGY METERING - CONDITIONS OF PURCHASE AND SALE (Continued) b. If electricity generated by the Customer and delivered to the Company during the Billing Period exceeds the electricity supplied by the Company during the Billing Period, the Excess Net Energy shall be carried forward as a kWh credit to offset energy usage in a subsequent Billing Period. Excess Net Energy credits are subject to the following provisions: i. Credits can only be used to offset billed kWh consumption. Customers shall be billed for all applicable non-energy charges for the Billing Period according to the applicable standard service schedule. ii. Credits shall carry forward provided the Customer maintains electric service at the same Point of Delivery. iii. Credits are non-transferrable in the event that a Customer relocates and/or discontinues service at the Point of Delivery associated with the Exporting System. Any unused credits will expire at the time the final bill is prepared. c. Compensation for the balance of generation and usage by the Customer is subject to change upon Commission approval. 2. Aggregation of meters for the annual transfer of unused Excess Net Energy credits: a. If a balance of Excess Net Energy credits exists at a Designated Meter, the Customer may request to transfer the unused credits to offset energy consumption at eligible meters. A meter is eligible for aggregation if it meets all of the following criteria: i. The account subject to offset is held by the Customer; and ii. The meter is located on, or contiguous to, the property on which the Designated Meter is located. For the purposes of this tariff, contiguous property includes property that is separated from the Premises of the Designated Meter by public or railroad rights of way; and iii. The meter is served by the same primary feeder as the Designated Meter at the time the Customer files the application for the Exporting System; and iv. The electricity recorded by the meter is for the Customer’s requirements; and v. Credits may only be transferred to meters taking service under Schedule 1, Schedule 6, Schedule 7, or Schedule 8. Idaho Power Company Original Sheet No. 8-5 Cancels I.P.U.C. No. 30, Tariff No. 101 Sixth Revised Sheet No. 8-5 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 8 SMALL GENERAL SERVICE ON-SITE GENERATION (Continued) NET ENERGY METERING - CONDITIONS OF PURCHASE AND SALE (Continued) b. Customers may submit requests to transfer Excess Net Energy credits between December 1 and January 31 of each year. All requests must be received by Idaho Power by midnight, Mountain Standard Time, on January 31. If a Customer does not request to transfer Excess Net Energy credits by the January 31 submission deadline Excess Net Energy credits will Carry forward to offset consumption at the Designated Meter until they become eligible for transfer the following year. c. Requests to transfer Excess Net Energy credits must be executed by the Company no later than March 31. Transfers will be based on the balance of Excess Net Energy credits available at the time the transfer is made. d. If multiple meters are eligible for aggregation, Excess Net Energy credits must first be applied to the Designated Meter, then to eligible meters on rate schedules in accordance with Section 2a(v) above. e. A meter aggregation fee of $10.00 will be assessed per aggregated meter per annual transfer transaction. NET BILLING – CONDITIONS OF PURCHASE AND SALE The conditions listed below shall apply to all transactions for Net Billing under the Schedule. 1. Balances of usage and exports by the Customer. a. The Customer shall be billed for the electricity supplied by the Company at the rates contained within this schedule, in accordance with normal metering practices. b. The Customer shall be credited for Exported Energy at the applicable Export Credit Rate contained within this schedule as a credit in dollars to only offset Monthly Charges. Exported Energy credits are subject to the following provisions: i. Credits shall carry forward provided the Customer maintains electric service at the same Point of Delivery. ii. Credits are transferrable in the event that a Customer relocates. If the establishment of service at the new Point of Delivery is not initiated at the time service at the Designated Meter is discontinued, it is the Customer’s responsibility to request the credit transfer when service is established at the new location in Idaho Power’s service area. iii. If a Customer discontinues service at the Point of Delivery associated with the Exporting System and does not intend to establish service at another location in Idaho Power’s service area any unused credits will be paid out following the time the final bill is prepared. Idaho Power Company I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 8-6 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 8 SMALL GENERAL SERVICE ON-SITE GENERATION (Continued) NET BILLING – CONDITIONS OF PURCHASE AND SALE (Continued) 2. Aggregation of meters for the annual transfer of unused credits: a. If a balance of credits exists at a Designated Meter, the Customer may request to transfer the unused credits to eligible meters. A meter is eligible for aggregation if it meets the following criteria: i. The account subject to offset is held by the Customer, and ii. The electricity recorded by the meter is for the Customer’s requirements. b. Customers may submit requests to transfer a stated percentage of available credits between December 1 and January 31 of each year. All requests must be received by Idaho Power by midnight, Mountain Standard Time, on January 31. If a Customer does not request to transfer credits by the January 31 submission deadline credits will carry forward at the Designated Meter until they become eligible for transfer the following year. c. Requests to transfer credits must be executed by the Company no later than March 31. Transfers will be based on the balance of credits available at the time the transfer is made. d. A meter aggregation fee of $10.00 will be assessed per aggregated meter per annual transfer transaction. NET ENERGY METERING & NET BILLING – GENERAL CONDITONS 1. The Customer shall never deliver or attempt to deliver energy to the Company’s system when the Company’s system serving the Customer’s DER is de-energized for any reason. 2. The Company shall not be liable directly or indirectly for permitting or continuing to allow an attachment of an Exporting System to the Company’s system, or for the acts or omissions of the Customer that cause loss or injury, including death, to any third party. 3. The Customer is responsible for all costs associated with the DER and Interconnection Facilities. The Customer is also responsible for all costs associated with any Company additions, modifications, or upgrades to any Company facilities that the Company determines are necessary as a result of the installation of the DER in order to maintain a safe, reliable electrical system. 4. The Company shall not be obligated to accept, and the Company may require the Customer to curtail, interrupt, or reduce deliveries of energy if the Company, consistent with Prudent Electrical Practices, determines that curtailment, interruption, or reduction is necessary because of line construction or maintenance requirements, emergencies, or other critical operating conditions on its system. 5. If the Company is required by the Commission to institute curtailment of deliveries of electricity to its customers, the Company may require the Customer to curtail its consumption of electricity in the same manner and to the same degree as other Customers on the Company’s standard service schedules. Idaho Power Company I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 8-7 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 8 SMALL GENERAL SERVICE ON-SITE GENERATION NET ENERGY METERING & NET BILLING – GENERAL CONDITONS (Continued) 6. The Customer shall grant to the Company all access to all Company equipment and facilities including adequate and continuing access rights to the property of the Customer for the purpose of installation, operation, maintenance, replacement, or any other service required of said equipment as well as all necessary access for inspection, switching, and any other operational requirements of the Customer’s Interconnections Facilities. 7. The Customer shall notify the Company immediately if an Exporting System is permanently removed or disabled. Permanent removal or disablement for the purposes of this Schedule is any removal or disablement of an Exporting System lasting longer than six (6) months. Customers with permanently removed or disabled systems will be removed from service under this schedule and placed on the appropriate standard service schedule. SUMMER AND NON-SUMMER SEASONS The summer season begins on June 1 of each year and ends on September 30 of each year. The non-summer season begins on October 1 of each year and ends on May 31 of each year. TIME PERIODS – EXPORT CREDIT RATE The time periods for the Export Credit Rate are defined as follows. All times are stated in Mountain Time. Summer Season On-Peak: 3:00 p.m. to 11:00 p.m. Monday through Saturday, except holidays Off-Peak 11:00 p.m. to 3:00 p.m. Monday through Saturday and all hours on Sunday and holidays Non-summer Season Off-Peak: All hours Monday through Sunday Holidays are New Year's Day (January 1), Memorial Day (last Monday in May), Independence Day (July 4), Labor Day (first Monday in September), Thanksgiving Day (fourth Thursday in November), and Christmas Day (December 25). If New Year’s Day, Independence Day, or Christmas Day falls on Sunday, the following Monday will be designated a holiday. MONTHLY CHARGE The Monthly Charge is the sum of the following charges, and may also include charges as set forth in Schedule 54 (Fixed Cost Adjustment), Schedule 55 (Power Cost Adjustment), Schedule 91 (Energy Efficiency Rider), Schedule 95 (Adjustment for Municipal Franchise Fees), Schedule 96 (Blaine County Surcharge to Fund the Undergrounding of Certain Facilities), and Schedule 98 (Residential and Small Farm Energy Credit). Idaho Power Company I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 8-8 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 8 SMALL GENERAL SERVICE ON-SITE GENERATION (Continued) MONTHLY CHARGE (Continued) The following charges are subject to change upon Commission approval: Summer Non-summer Service Charge, per month $25.00 $25.00 Energy Charge, per kWh First 300 kWh 6.7404¢ 6.7404¢ All Additional kWh 7.7027¢ 6.7421¢ EXPORT CREDIT RATE The following rate structure and credits are subject to change upon Commission approval: Summer Non-summer Export Credit Rate, per kWh On-Peak 16.9966¢ 4.8365¢ Off-Peak 5.6533¢ 4.8365¢ PAYMENT The monthly bill rendered for service supplied hereunder is payable upon receipt, and becomes past due 15 days from the date on which rendered. Idaho Power Company Original Sheet No. 20-1 Cancels I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 20-1 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 36042 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho SCHEDULE 20 SPECULATIVE HIGH-DENSITY LOAD AVAILABILITY Service under this schedule is available at points on the Company's interconnected system within the State of Idaho where existing facilities of adequate capacity and desired phase and voltage are available. If additional distribution facilities are required to supply the desired service, those facilities provided for under Rule H will be provided under the terms and conditions of that rule. To the extent that additional facilities not provided for under Rule H, including transmission and/or substation facilities, are required to provide the requested service, special arrangements will be made in a separate agreement between the Customer and the Company. APPLICABILITY Service under this schedule is applicable to electric service supplied to a Customer at one Point of Delivery and measured through one meter delivered at the primary or transmission service level. This schedule is applicable to Customers whose metered energy usage exceeds 2,000 kWh per Billing Period for a minimum of three Billing Periods during the most recent 12 consecutive Billing Periods. Where the Customer’s Billing Period is less than 27 days or greater than 36 days, the metered energy usage will be prorated to 30 days for purposes of determining eligibility under this schedule. Applicable Speculative High-Density Load Large Power Service Rates are mandatory for Customers who register a metered Demand of 1,000 kW or more per Billing Period for three or more Billing Periods during the most recent 12 consecutive Billing Periods. Customers whose metered Demand per Billing Period has not equaled or exceeded 1,000 kW more than twice during the most recent 12 consecutive Billing Periods will take service under applicable Speculative High-Density Load Large General Service rates. At their expense, Customers may request to establish an additional circuit for building systems independent of the commercial operational load, such as lighting, climate control, among others, at a separate Point of Delivery. This additional circuit will be separately metered and billed under the applicable rate schedule. The Customer will be responsible for the costs associated with installing the second meter. The Company may refuse to provide service at more than one Point of Delivery at the same Premises if it is determined by the Company that the additional Point of Delivery cannot be provided without jeopardizing the safety and reliability of the Company's system or service to the Customer or to other Customers. Service provided to a Customer at multiple Points of Delivery at the same Premises will not be interconnected electrically. This schedule is not applicable to service for resale, to shared or irrigation service, to standby or supplemental service, unless the Customer has entered into a Uniform Standby Service Agreement or other standby agreement with the Company, or to multi-family dwellings. Idaho Power Company Original Sheet No. 20-2 Cancels I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 20-2 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 36042 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho SCHEDULE 20 SPECULATIVE HIGH-DENSITY LOAD (Continued) APPLICABILITY (Continued) Service under this schedule is applicable to and may be mandatory for Customers who have the ability to relocate quickly in response to short-term economic signals and meet four or more of the following criteria:  High energy use density;  High load factor;  Load that is portable and distributable;  Highly variable load growth or load reduction as an individual customer and/or in aggregate with similar customers in the Company’s service area;  High sensitivity to volatile commodity or asset prices;  Part of an industry with potential to quickly become a large concentration of power demand;  Lack of credit history or ability to demonstrate financial viability. If the aggregate power requirement of a Customer who receives service at one or more Points of Delivery on the same Premises exceeds 20,000 kW, the Customer is ineligible for service under this schedule and is required to make special contract arrangements with the Company. Contract Option. Customers for which this schedule is applicable may optionally take service under a mutually agreed upon individual special contract between the Customer and the Company provided the Customer contracts for firm electric Demand of 10,000 kW to 20,000 kW and the special contract terms, conditions, and rates are approved by the Idaho Public Utilities Commission without change or condition. 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. Interconnection Facilities are all facilities which are reasonably required by good practices and the National Electric Safety Code to interconnect the Customer with the capability to remotely interrupt the load at the Point of Delivery. Such improvements include, but are not limited to, reclosers, load control devices, and related equipment. 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 with the capability to remotely interrupt the load at the Point of Delivery. Such improvements include, but are not limited to, additional or larger conductors, transformers, poles, and related equipment. Idaho Power Company Original Sheet No. 20-3 Cancels I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 20-3 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 36042 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho SCHEDULE 20 SPECULATIVE HIGH-DENSITY LOAD (Continued) INTERCONNECTION PROCESS Once a request for new Schedule 20 service is received, Idaho Power will perform a study or studies to determine what Protection Equipment, Interconnection Facilities, and/or Upgrades are necessary to interconnect the Customer’s load to Idaho Power’s system. The customer 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 the Customer, 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. Idaho Power Company Original Sheet No. 20-4 Cancels I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 20-4 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 36042 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho SCHEDULE 20 SPECULATIVE HIGH-DENSITY LOAD (Continued) TYPE OF SERVICE The Type of Service provided under this schedule is three-phase at approximately 60 cycles and at the standard service voltage available at the Premises to be served. BASIC LOAD CAPACITY The Basic Load Capacity is the average of the two greatest monthly Billing Demands established during the 12-month period which includes and ends with the current Billing Period, but not less than 1,000 kW for Large Power Service. BILLING DEMAND The Billing Demand is the average kW supplied during the 15-consecutive-minute period of maximum use during the Billing Period, adjusted for Power Factor, but not less than 1,000 kW for Large Power Service. TIME PERIODS The time periods are defined as follows. All times are stated in Mountain Time. Summer Season On-Peak: 7:00 p.m. to 11:00 p.m. Monday through Saturday, except holidays Mid-Peak: 3:00 p.m. to 7:00 p.m. and 11:00 p.m. to 12:00 a.m. Monday through Saturday, except holidays Off-Peak: 12:00 a.m. to 3:00 p.m. Monday through Saturday and all hours on Sunday and holidays Non-summer Season On-Peak: 6:00 a.m. to 9:00 a.m. and 5:00 p.m. to 8:00 p.m. Monday through Saturday, except holidays Mid-Peak: 9:00 a.m. to 12:00 p.m., 4:00 p.m. to 5:00 p.m., and 8:00 p.m. to 10:00 p.m. Monday through Saturday, except holidays Off-Peak: 12:00 a.m. to 6:00 a.m., 12:00 p.m. to 4:00 p.m., and 10:00 p.m. to 12:00 a.m. Monday through Saturday and all hours on Sunday and holidays The holidays observed by the Company are New Year’s Day (January 1), Memorial Day (last Monday in May), Independence Day (July 4), Labor Day (first Monday in September, Thanksgiving Day (fourth Thursday in November), and Christmas Day (December 25). If New Year’s Day, Independence Day, or Christmas Day falls on Sunday, the following Monday will be considered a holiday. Idaho Power Company Original Sheet No. 20-5 Cancels I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 20-5 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 36042 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho SCHEDULE 20 SPECULATIVE HIGH-DENSITY LOAD (Continued) SUMMER AND NON-SUMMER SEASONS The summer season begins on June 1 of each year and ends on September 30 of each year. The non-summer season begins on October 1 of each year and ends on May 31 of each year. FACILITIES BEYOND THE POINT OF DELIVERY Pursuant to Rule B, customers taking Primary or Transmission Service are responsible for providing the transformation of power to the voltage at which it is to be used by the Customer. INTERRUPTION EVENTS At its discretion, Idaho Power may call Interruption Events to remotely disconnect electric service to Customer load under the following parameters:  June 15 through September 15  1:00 p.m. to 11:00 p.m. Monday through Friday, excluding Holidays  Maximum ten (10) hours per interruption event  Up to 225 hours annually Customer will be notified of upcoming Interruption Event not less than two (2) hours prior to event start via phone call, or at the Company’s discretion via an alternative mutually-agreed upon method. POWER FACTOR ADJUSTMENT Where the Customer’s Power Factor is less than 90 percent, as determined by measurement under actual load conditions, the Company may adjust the kW measured to determine the Billing Demand by multiplying the measured kW by 90 percent and dividing by the actual Power Factor. SPECIAL CONDITIONS The provisions of Interruption do not apply for any time period that the Company requests a load reduction during a system emergency or any other time that a Customer’s service is interrupted by events outside the control of the Company. TEMPORARY SUSPENSION When a Customer has properly invoked Rule G, Temporary Suspension of Demand, the Basic Load Capacity and the Billing Demand Shall be prorated based on the period of such suspension in accordance with Rule G. Idaho Power Company Original Sheet No. 20-6 Cancels I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. 20-6 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 36042 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho SCHEDULE 20 SPECULATIVE HIGH-DENSITY LOAD (Continued) MONTHLY CHARGE The Monthly Charge is the sum of the following charges, and may also include charges as set forth in Schedule 91 (Energy Efficiency Rider), and Schedule 95 (Adjustment for Municipal Franchise Fees). Large General Service Rates PRIMARY SERVICE Summer Non-summer Service Charge, per month $340.00 $340.00 Basic Charge, per kW of $1.73 $1.73 Basic Load Capacity Demand Charge, per kW of $8.39 $7.98 Billing Demand Energy Charge, per kWh On-Peak 8.8770¢ 6.4611¢ Mid-Peak 11.5970¢ 8.2028¢ Off-Peak 6.5765¢ 6.9063¢ TRANSMISSION SERVICE Summer Non-summer Service Charge, per month $340.00 $340.00 Basic Charge, per kW of Basic Load Capacity $1.03 $1.03 Demand Charge, per kW of Billing Demand $7.45 $6.59 Energy Charge, per kWh On-Peak 8.8034¢ 6.3629¢ Mid-Peak 11.5234¢ 8.1044¢ Off-Peak 6.4969¢ 6.8077¢ Idaho Power Company Original Sheet No. 20-7 Cancels I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. 20-7 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 36042 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho SCHEDULE 20 SPECULATIVE HIGH-DENSITY LOAD (Continued) MONTHLY CHARGE (Continued) Large Power Service Rates PRIMARY SERVICE Summer Non-summer Service Charge, per month $415.00 $415.00 Basic Charge, per kW of $2.09 $2.09 Basic Load Capacity Demand Charge, per kW of $9.97 $8.64 Billing Demand Energy Charge, per kWh On-Peak 8.6996¢ 6.2790¢ Mid-Peak 11.4196¢ 8.0200¢ Off-Peak 6.4004¢ 6.7229¢ TRANSMISSION SERVICE Summer Non-summer Service Charge, per month $415.00 $415.00 Basic Charge, per kW of Basic Load Capacity $1.76 $1.76 Demand Charge, per kW of Billing Demand $10.11 $8.77 Energy Charge, per kWh On-Peak 8.6829¢ 6.2503¢ Mid-Peak 11.4029¢ 7.9912¢ Off-Peak 6.3808¢ 6.6940¢ PAYMENT The monthly bill for service supplied hereunder is payable upon receipt, and becomes past due 15 days from the date on which rendered. Idaho Power Company Original Sheet No. 20-8 Cancels I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 20-8 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 36042 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho SCHEDULE 20 SPECULATIVE HIGH-DENSITY LOAD (Continued) INTERRUPTION COMPENSATION Fixed Capacity Reduction Rate: Large General Service Rates $0.0333 per kilowatt of reduction per event hour Large Power Service Rates $0.0382 per kilowatt of reduction per event hour DEFINITIONS Actual kW Reduction. The kilowatt (kW) reduction during an Interruption Event, which is the difference between a Participant’s hourly average kW measured at the Facility Site’s meter and the corresponding hour of the Adjusted Baseline kW. Adjusted Baseline kW. The Original Baseline kW plus or minus the “Day of” Load Adjustment amount. “Day of” Load Adjustment. The difference between the Original Baseline kW and the actual metered kW during the hour prior to the Participant receiving notification of an event. Scalar values will be calculated by dividing the Original Baseline kW for each Interruption Event hour by the Baseline kW of the hour preceding the event notification time. The scalars are multiplied by the actual event day kW for the hour preceding the event notification time to create the Adjusted Baseline kW from which load reduction is measured. The Adjusted Baseline kW for each hour will be capped at 120% of the maximum kW amount for any hour from the Highest Energy Use Days or the hours during the event day prior to event notification. Facility Site(s). All of a Participant’s facility or equipment that is metered from a single service location that a Participant has taken service under Schedule 20. Highest Energy Usage Days. The three days out of the immediate past 10 non-event Business Days that have the highest sum total kW as measured across the Interruption Event daily parameters. Interruption Compensation. The Actual kW Reduction for each hour multiplied by the Fixed Capacity Reduction Rate. Participants are paid based on the average event kilowatt reduction. Load Control Device. Refers to any technology, device, or system utilized under Schedule 20 to enable the Company to initiate the Interruption Event. Interruption Event. Refers to an event where the Company requests or calls for interruption of specific loads with the use of one or more Load Control Devices. Original Baseline kW. The arithmetic mean (average) kW of the Highest Energy Usage Days during the Interruption Event daily parameters, calculated for each Facility Site for each hour. Idaho Power Company Original Sheet No. 41-1 Cancels I.P.U.C. No. 30, Tariff No. 101 Third Revised Sheet No. 41-1 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 36042 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho SCHEDULE 41 STREET LIGHTING SERVICE AVAILABILITY Service under this schedule is available throughout the Company's service area within the State of Idaho where street lighting wires and fixtures can be installed on Customer-provided street lighting facilities or installed on the Company's existing distribution facilities. APPLICABILITY Service under this schedule is applicable to service requested or installed by Customers for the lighting of public streets, public alleys, public grounds, and thoroughfares. Street lighting fixtures will be energized each night from dusk until dawn. SERVICE LOCATION AND PERIOD Street lighting facility locations, type of unit and fixture sizes, as changed from time to time by written request of the Customer and agreed to by the Company, shall be provided for Customers receiving service under Option A of this schedule. The in-service date for each street lighting facility shall also be maintained. The minimum service period for any Company-owned street lighting facility is 10 years. The Company, upon written notification from the Customer, will remove a Company-owned street lighting facility: 1. At no cost to the Customer, if such facility has been in service for no less than the minimum service period. The Company will not grant a request from the Customer for reinstallation of street lighting service at the same location for a minimum period of two years from the date of removal. 2. Upon payment to the Company of the removal cost, if such facility has been in service for less than the minimum service period. SERVICE OPTIONS "A" - Idaho Power-Owned, Idaho Power-Maintained System. The facilities required for supplying service, including fixture, lamp, control relay, mast arm for mounting on an existing utility pole, and energy for the operation thereof, are supplied, installed, owned and maintained by the Company. All necessary repairs and maintenance work, including group fixture replacement, will be performed by the Company during the regularly scheduled working hours of the Company on the Company’s schedule. Individual fixtures will be replaced on burnout as soon as reasonably possible after notification by the Customer and subject to the Company's operating schedules and requirements. The Company has light-emitting diode (“LED”) fixture options. For each initial LED lighting fixture installation, the Customer is required to state, in writing, a fixture preference. A maintenance-related replacement of a current LED fixture will be made with a similar type of fixture as the one being replaced unless written notification has been received from the Customer requesting a change in fixture types. Idaho Power Company Original Sheet No. 41-2 Cancels I.P.U.C. No. 30, Tariff No. 101 Tenth Revised Sheet No. 41-2 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 36042 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho SCHEDULE 41 STREET LIGHTING SERVICE (Continued) SERVICE OPTIONS (Continued) "A" - Idaho Power-Owned, Idaho Power-Maintained System (Continued) Company-owned lighting systems installed on or after June 1, 2004 shall not be constructed, operated, or modified in such a way as to allow for the potential or actual variation in energy usage, such as through, but not limited to, the use of wired outlets or useable plug-ins. Company-owned systems installed prior to June 1, 2004 that are constructed, operated, or modified in such a way as to allow for the potential or actual variation in energy usage may have the estimated annual variations in energy usage charged the Non-Metered Service – Variable Energy Charge until the potential for variations in energy usage has been eliminated. Repair, modification or alteration of these facilities is not permitted. Dark Sky Lighting for LED Fixtures In the event a Customer requests the Company perform an alteration of existing LED fixtures to become dark sky lighting compliant by adding a lens shield to the existing fixture, the following charges will apply: 1. The designed cost estimate which includes labor, time, and mileage costs for the alteration of the existing street lighting fixtures. 2. $27.50 per fixture altered for dark sky lighting. The total charges identified in 1 and 2 above must be paid prior to the beginning of the fixture alteration and are non-refundable. The fixture alteration to become dark sky lighting compliant will be performed by the Company during the regularly scheduled working hours of the Company and on the Company’s schedule. LED Shield In the event a Customer requests the Company install a shield on an LED fixture, the Customer will be responsible for the material cost of the equipment, as well as the design cost estimate which includes labor, time, and mileage costs for the alteration of the existing LED fixture. Idaho Power Company Original Sheet No. 41-3 Cancels I.P.U.C. No. 30, Tariff No. 101 Fifteenth Revised Sheet No. 41-3 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 36042 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho SCHEDULE 41 STREET LIGHTING SERVICE (Continued) SERVICE OPTIONS (Continued) "A" - Idaho Power-Owned, Idaho Power-Maintained System (Continued) Monthly Charges The monthly charges are as follows, and may also include charges as set forth in Schedule 55 (Power Cost Adjustment), Schedule 91 (Energy Efficiency Rider), and Schedule 95 (Adjustment for Municipal Franchise Fees). Charges, per fixture (41A) _________________________LED Fixture____________________________ Watt (Maximum) Lumen (Minimum) Base Rate 40 3,600 $11.48 85 7,200 $13.38 140 10,800 $15.34 200 18,000 $19.06 Non-Metered Service – Variable Energy Energy Charge, per kWh 9.377¢ Pole Charges For Company-owned poles installed after October 5,1964 required to be used for street lighting only: Charge Wood pole, per pole $1.81 Steel pole, per pole $7.18 Facilities Charges Customers assessed a monthly facilities charge prior to June 1, 2004 will continue to be assessed a monthly facilities charge in accordance with the charges specified in Schedule 66. Payment The monthly bill rendered for service supplied hereunder is payable upon receipt and becomes past due 15 days from the date on which rendered. "B" – Customer-Owned, Idaho Power-Maintained System – Discontinued Idaho Power Company Original Sheet No. 41-4 Cancels I.P.U.C. No. 30, Tariff No. 101 Fifteenth Revised Sheet No. 41-4 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 36042 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho SCHEDULE 41 STREET LIGHTING SERVICE (Continued) SERVICE OPTIONS (Continued) "C" - Customer-Owned, Customer-Maintained System The Customer's lighting system, including posts or standards, fixtures, initial installation of fixtures and underground cables with suitable terminals for connection to the Company's distribution system, is installed, owned, and maintained by the Customer. The Customer is responsible for notifying the Company of any changes or additions to the lighting equipment or loads being served under Option C – Non-Metered Service. Failure to notify the Company of such changes or additions will result in the termination of non-metered service under Option C and the requirement that service be provided under Option C - Metered Service. All new Customer-owned lighting systems installed outside of Subdivisions on or after January 1, 2012 are required to be metered in order to record actual energy usage. Customer-owned systems installed prior to June 1, 2004 that are constructed, operated, or modified in such a way as to allow for the potential or actual variation in energy usage may have the estimated annual variations in energy usage charged the Non-Metered Service - Energy Charge until the street lighting system is converted to Metered Service, or until the potential for variations in energy usage has been eliminated, whichever is sooner. Monthly Charges The monthly charges are as follows, and may also include charges as set forth in Schedule 55 (Power Cost Adjustment), Schedule 91 (Energy Efficiency Rider), and Schedule 95 (Adjustment for Municipal Franchise Fees). For non-metered service, the average monthly kWh of energy usage shall be estimated by the Company based on the total wattage of the Customer’s lighting system and 4,059 hours of operation. Non-Metered Service (41C) Energy Charge, per kWh 6.339¢ Metered Service (41CM) Service Charge, per meter $5.59 Energy Charge, per kWh 6.339¢ Idaho Power Company Original Sheet No. 54-1 Cancels I.P.U.C. No. 30, Tariff No. 101 Fifth Revised Sheet No. 54-1 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 36042 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho SCHEDULE 54 FIXED COST ADJUSTMENT APPLICABILITY This schedule is applicable to the electric energy delivered to all Idaho retail Customers receiving service under Schedules 1, 3, 5, or 6 (Residential Service) or under Schedules 7 and 8 (Small General Service). Customers added to Idaho Power’s system starting January 1, 2022 will be considered new customers, all other customers are considered existing customers. FIXED COST PER CUSTOMER RATE The Fixed Cost per Customer rate (FCC) is determined by dividing the Company’s fixed cost components for Residential and Small General Service Customers by the average number of Residential and Small General Service customers, respectively. The Fixed Cost per Customer Distribution rate (FCC-Dist) is determined by dividing the Company’s distribution and customer fixed cost components for Residential and Small General Service Customers by the average number of Residential and Small General Service Customers, respectively. Residential FCC FCC-Dist Schedules 1 and 3 $739.20 $287.96 Schedule 5 $739.20 $287.96 Schedule 6 $654.72 $304.20 Small General Service FCC FCC-Dist Schedule 7 $174.96 $24.02 Schedule 8 $221.61 $63.33 FIXED COST PER ENERGY RATE The Fixed Cost per Energy rate (FCE) is determined by dividing the Company’s fixed cost components for Residential and Small General Service customers by the weather-normalized energy load for Residential and Small General Service customers, respectively. The Fixed Cost per Energy Distribution rate (FCE-Dist) is determined by dividing the Company’s distribution and customer fixed cost components for Residential and Small General Service customers by the weather-normalized energy load for Residential and Small General Service customers, respectively. Idaho Power Company Original Sheet No. 54-2 Cancels I.P.U.C. No. 30, Tariff No. 101 Sixteenth Revised Sheet No. 54-2 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 36042 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho SCHEDULE 54 FIXED COST ADJUSTMENT (Continued) FIXED COST PER ENERGY RATE (Continued) Residential FCE FCE-Dist Schedules 1 and 3 6.7098¢ per kWh 2.6138¢ per kWh Schedule 5 – Summer On-Peak 17.5878¢ per kWh 8.3169¢ per kWh Schedule 5 – Mid-Peak 8.7941¢ per kWh 4.1586¢ per kWh Schedule 5 – Summer Off-Peak 4.3970¢ per kWh 2.0792¢ per kWh Schedule 5 – Non-Summer On-Peak 8.5198¢ per kWh 2.9266¢ per kWh Schedule 5 – Non-Summer Off-Peak 5.6798¢ per kWh 1.9511¢ per kWh Schedule 6 7.0780¢ per kWh 3.2886¢ per kWh Small General Service FCE FCE-Dist Schedule 7 3.8463¢ per kWh 0.5282¢ per kWh Schedule 8 5.2308¢ per kWh 1.4949¢ per kWh ALLOWED FIXED COST RECOVERY AMOUNT The Allowed Fixed Cost Recovery amount is computed by summing 1) the product of the average number of existing Residential and Small General Service customers multiplied by the appropriate Residential and Small General Service FCC rate and 2) the product of the average number of new Residential and Small General Service customers multiplied by the appropriate Residential and Small General Service FCC-Dist rate. ACTUAL FIXED COSTS RECOVERED AMOUNT The Actual Fixed Costs Recovered amount is computed by summing 1) the product of the actual energy load for existing Residential and Small General Service customers multiplied by the appropriate Residential and Small General Service FCE rate and 2) the product of the actual energy load for new Residential and Small General Service customers multiplied by the appropriate Residential and Small General Service FCE-Dist rate. FIXED COST ADJUSTMENT The Fixed Cost Adjustment (FCA) is the difference between the Allowed Fixed Cost Recovery Amount and the Actual Fixed Costs Recovered Amount divided by the estimated weather-normalized energy load for the following year for Residential and Small General Service Customers. The monthly Fixed Cost Adjustment for Residential Service (Schedules 1, 3, 5, and 6) is 0.4402 cents per kWh. The monthly Fixed Cost Adjustment for Small General Service (Schedules 7 and 8) is 0.5541 cents per kWh. EXPIRATION The Fixed Cost Adjustment included on this schedule will expire May 31, 2024. Idaho Power Company Original 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. 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 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, 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 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 Interconnection 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 System is an Exporting System or a Non-Exporting System. 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 Original 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. 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) 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. 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 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 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. 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 Original 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. 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 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, 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. 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. 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 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. 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. 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 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 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 Sheet No. 68-7 Cancels I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. 68-7 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) 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. 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 Original 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. 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) 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 that are not completed within one year of the initial Feasibility Review are considered expired. Customers requesting connection or approval of expired applications are required to resubmit a completed application form and $100 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. Idaho Power Company Original 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. 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) SYSTEM MODIFICATIONS (Continued) 2. Customer Generators planning to make system modifications must submit an application, $100 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. 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 schedule within this time period will be subject to termination of service. Idaho Power Company Original 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. 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) 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 The following section is applicable to all DERs with Total Nameplate Capacity less than 3 MVA. APPLICATION PROCESS Customers requesting to interconnect a DER less than 3 MVA are required to complete the following application process prior to interconnection: 1. Customers must submit a completed application form and a $100 application fee to the Company. Applications are available on the Company’s website or will be provided to the Customer upon request. 2. Upon receipt of a completed application and $100 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. 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. 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. Idaho Power Company Original 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. 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 2: INTERCONNECTION PROCESS REQUIREMENTS FOR DISTRIBUTED ENERGY RESOURCES LESS THAN 3 MVA (Continued) APPLICATION PROCESS (Continued) 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 perform the Feasibility Study within 15 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. The Feasibilty Study Agreement includes a deposit of $1,000. a. Installation and funding of the construction, installation, and maintenance of required Protection Equipment will be subject to the following provisions: 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 of 0.59 percent per month times the investment in the Protection Equipment. Idaho Power Company Original 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. 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 2: INTERCONNECTION PROCESS REQUIREMENTS FOR DISTRIBUTED ENERGY RESOURCES LESS THAN 3 MVA (Continued) APPLICATION PROCESS (Continued) 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. 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 installer on the System Verification Form. Idaho Power Company Original 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. 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 2: INTERCONNECTION PROCESS REQUIREMENTS FOR DISTRIBUTED ENERGY RESOURCES LESS THAN 3 MVA (Continued) APPLICATION PROCESS (Continued) 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. Under no circumstances will the rate change occur more than fifteen (15) business days from the date of the 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 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. NON-EXPORT CONTROL SYSTEM 1. Non-Export Systems must incorporate one of the following three options: Idaho Power Company Original 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. 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 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: 1. The Company will notify the Non-Export Customer Generator that their Customer Generator System has exceeded the Inadvertent Export limit. Idaho Power Company Original 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. 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 3: ADDITIONAL INTERCONNECTION REQUIREMENTS OF NON-EXPORTING SYSTEMS (Continued) UNAUTHORIZED INADVERTENT EXPORT (Continued) 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 Sheet No. 68-16 Cancels I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. 68-16 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 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 Sheet No. 68-17 Cancels I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. 68-17 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) 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 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. 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) 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 of 0.59 percent 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 Sheet No. 68-19 Cancels I.P.U.C. No. 30, Tariff No. 101 First Revised 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) 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 Sheet No. 68-20 Cancels I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. 68-20 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) 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 Original Sheet No. 68-21 Cancels I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. 68-21 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) 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 Sheet No. 68-22 Cancels I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. 68-22 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) 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 Sheet No. 68-23 Cancels I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. 68-23 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) 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 Sheet No. 68-24 Cancels I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. 68-24 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) 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 Sheet No. 68-25 Cancels I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. 68-25 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) 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 Sheet No. 68-26 Cancels I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. 68-26 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) 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 Idaho Power Company Original Sheet No. 68-27 Cancels I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. 68-27 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) 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 Sheet No. 68-28 Cancels I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. 68-28 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) IDAHO POWER COMPANY UNIFORM CUSTOMER GENERATOR INTERCONNECTION AGREEMENT (Continued) 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 Original Sheet No. 84-1 Cancels I.P.U.C. No. 30, Tariff No. 101 Sixth Revised Sheet No. 84-1 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 84 LARGE GENERAL, LARGE POWER, AND IRRIGATION ON-SITE GENERATION SERVICE AVAILABILITY Service under this schedule is available throughout the Company’s service area within the State of Idaho for Customers intending to operate Exporting Systems to generate electricity to reduce all or part of their monthly energy usage. Effective June 1, 2018, Schedule 84 is closed to service for Idaho residential and Idaho small general service customers. Effective December 2, 2020, Schedule 84 is closed to new applications with a two-meter interconnection and for Net Energy Metering. APPLICABILITY Service under this schedule is applicable to any Customer that: 1. Does not take service under, Schedule 5, Schedule 6, or Schedule 8; and 2. Owns and/or operates a Generation Facility fueled by solar, wind, biomass, geothermal, or hydropower, or represents fuel cell technology; and 3. Maintains its retail electric service account as active and in good standing; and 4. Meets all requirements applicable to Exporting Systems detailed in the Company’s Schedule 68, Interconnections to Customer Distributed Energy Resources; and 5. Takes retail electric service under: a. Schedule 1 or Schedule 7; and Owns and/or operates a Generation Facility with a total nameplate capacity rating of 25 kilowatts (kW) or smaller that is interconnected to the Customer’s individual electric system on the Customer’s side of the Point of Delivery, thus all energy received and delivered by the Company is through a single meter. The capacity of an Energy Storage Device shall not be used to calculate the capacity limits in this schedule. b. Schedule 9, Schedule 19, or Schedule 24; and i. Two Meter Interconnection (Closed to new applicants effective December 2, 2020): Owns and/or operates a Generation Facility with a total nameplate capacity rating of 100 kW or smaller that is interconnected at a Generation Interconnection Point that, at the Company’s discretion, is located either adjacent to or on the Customer’s side of the Point of Delivery and is metered through a meter that is separate from the retail load metering at the Customer’s Point of Delivery. A separate meter from the existing retail load metering at the Customer’s Point of Delivery is not required if the Customer meets the criteria below. The capacity of an Energy Storage Device shall not be used to calculate the capacity limits in this schedule. Idaho Power Company Original Sheet No. 84-2 Cancels I.P.U.C. No. 30, Tariff No. 101 Fifth Revised Sheet No. 84-2 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 84 LARGE GENERAL, LARGE POWER, AND IRRIGATION ON-SITE GENERATION SERVICE (Continued) APPLICABILITY (Continued) ii. Single-Meter Interconnection (applicable to new applicants effective December 2, 2020): Owns and/or operates a Generation Facility interconnected to the Customer’s individual electric system on the Customer’s side of the Point of Delivery, thus all energy received and delivered by the Company is through a single meter. The Generation Facility must have a total nameplate rating equal to or less than the greater of: (a) the greatest monthly Billing Demand established during the most recent 12-month period at the time of applying for interconnection, which includes and ends with the most recent Billing Period, or (b) 100 kW. The capacity of an Energy Storage Device shall not be used to calculate the capacity limits in this schedule. 6. For a Customer applying to interconnect a Generation Facility (1) with a total nameplate capacity rating that exceeds actual billing demand data from the most recent 12 months, or (2) Billing Demand is not available, must provide evidence that the proposed Generation Facility meets the applicability of this schedule in accordance with the following: i. If previous billing data is available for the premises and the Customer’s electrical needs are similar to the previous customer, the Company, at its discretion, may rely on available historical Billing Demand at the premises not to exceed the previous 12 months. ii. If the Customer has another account in the Company’s service area with similar electrical needs, the Company, at its discretion, may rely on available historical Billing Demand from that account not to exceed the previous 12 months. iii. The Customer can have a third-party professional engineer provide analysis and documentation detailing the electrical load requirements for the Customer which support an increase in demand expected to occur within the next 12 months. iv. For a Customer taking retail service under Schedule 24 which only services motor load, the Customer may submit documentation of the horsepower (“HP”) of the motor/pump to the Company and a conversion factor of 1 HP to 0.8kW will be used to define the demand for the Point of Delivery. 7. Legacy Status for eligible Exporting Systems will terminate on December 1, 2045. 8. The Legacy Status of the Exporting System is transferable to a subsequent Customer at the premises for which a valid on-site generation service is in effect. Each Customer of a Legacy System taking service under Schedule 84 will be responsible for complying with the terms and conditions of the on-site generation service in effect for that premises. 9. A Legacy System that is offline for over six (6) months or that is moved to a different site shall forfeit Legacy Status of the Exporting System. Idaho Power Company Original Sheet No. 84-3 Cancels I.P.U.C. No. 30, Tariff No. 101 Fourth Revised Sheet No. 84-3 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 84 LARGE GENERAL, LARGE POWER, AND IRRIGATION ON-SITE GENERATION SERVICE (Continued) APPLICABILITY (Continued) 10. To remain eligible for Legacy Status, a Customer may increase the capacity of a Legacy System by no more than 10 percent of the originally installed nameplate capacity, or 1 kW, whichever is greater, to allow for the replacement of broken or degraded components. If a Customer expands a Legacy System beyond these limits, the new portion of the DER would not qualify for Legacy Status. 11. A Customer that modifies a two-meter Generation Facility to a single-meter forfeits the Legacy Status of the Generation Facility. DEFINITIONS Billing Demand is the average kW supplied during the 15-consecutive-minute period of maximum use during the Billing Period, adjusted for Power Factor. Designated Meter is the retail meter physically connected to the Exporting System. 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. Excess Net Energy means the positive difference between the kilowatt-hours (kWh) generated by a Customer and the kWh supplied by the Company over the applicable Billing Period. Exported Energy means all kWh generated by a Customer in excess of the Customer’s on-site consumption that is exported to the Company’s system. 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. An Exporting System is interconnected to the Company’s system under the applicable terms of Schedule 68. Generation Facility means all equipment used to generate electric energy where the resulting energy is either delivered to the Company via a single meter at the Point of Delivery or Generation Interconnection Point, or is consumed by the Customer. Generation Interconnection Point is the point where the conductors installed to allow receipt of the Customer’s generation connect to the Company’s facilities adjacent to the Customer’s Point of Delivery. Interconnection Facilities are all facilities reasonably required by Prudent Electrical Practices and the applicable electric and safety codes to interconnect and safely deliver energy from the DER to the Point of Delivery or Generation Interconnection Point. Idaho Power Company Original Sheet No. 84-4 Cancels I.P.U.C. No. 30, Tariff No. 101 Fourth Revised Sheet No. 84-4 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 84 LARGE GENERAL, LARGE POWER, AND IRRIGATION ON-SITE GENERATION SERVICE (Continued) DEFINITIONS (Continued) Legacy Status refers to the ability for a system to receive Net Energy Metering, including net monthly one-for-one kWh credit compensation for Excess Net Energy. Legacy Systems means any system that meets the applicable criteria as described in Order Nos. 34509, 34546, 34854 and 34892. Net Billing is the compensation structure applicable to all systems that do not meet the criteria of a Legacy System. Net Billing will be effective with each eligible customer’s first billing cycle after January 1, 2024. Net Energy Metering is the compensation structure applicable to all Legacy Systems. Parallel connection means generating electricity from an on-site generation system that is connected to and receives voltage from Idaho Power’s system. Point of Delivery is the retail metering point where the Company's and the Customer’s electrical facilities are interconnected to allow the Customer to take retail electric service from the Company. Prudent Electrical Practices are those practices, methods and equipment that are commonly used in prudent electrical engineering and operations to operate electric equipment lawfully and with safety, dependability, efficiency and economy. Schedule 68 is the Company’s service schedule which provides for interconnection to DERs or its successor schedule(s) as approved by the Commission. MONTHLY BILLING The Customer shall be billed in accordance with the Customer’s applicable standard service schedule, including appropriate monthly charges, and the Export Credit Rate under this schedule. NET ENERGY METERING - CONDITIONS OF PURCHASE AND SALE The conditions listed below shall apply to all transactions for Net Energy Metering under this schedule. 1. Balances of generation and usage by the Customer: a. If electricity supplied by the Company during the Billing Period exceeds the electricity generated by the Customer and delivered to the Company during the Billing Period, the Customer shall be billed for the net electricity supplied by the Company at the Customer’s standard schedule retail rate, in accordance with normal metering practices. Idaho Power Company Original Sheet No. 84-5 Cancels I.P.U.C. No. 30, Tariff No. 101 Second Revised Sheet No. 84-5 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 84 LARGE GENERAL, LARGE POWER, AND IRRIGATION ON-SITE GENERATION SERVICE (Continued) NET ENERGY METERING - CONDITIONS OF PURCHASE AND SALE (Continued) b. If electricity generated by the Customer and delivered to the Company during the Billing Period exceeds the electricity supplied by the Company during the Billing Period, the Excess Net Energy shall be carried forward as a kWh credit to offset energy usage in a subsequent Billing Period. Excess Net Energy credits are subject to the following provisions: i. Credits can only be used to offset billed kWh consumption. Customers shall be billed for all applicable non-energy charges for the Billing Period according to the applicable standard service schedule. ii. Credits shall carry forward provided the Customer maintains electric service at the same Point of Delivery. iii. Credits are non-transferrable in the event that a Customer relocates and/or discontinues service at the Point of Delivery associated with the Exporting System. Any unused credits will expire at the time the final bill is prepared. 2. Aggregation of meters for the annual transfer of unused Excess Net Energy credits: a. If a balance of Excess Net Energy credits exists at a Designated Meter, the Customer may request to transfer the unused credits to offset energy consumption at eligible meters. A meter is eligible for aggregation if it meets all of the following criteria: i. The account subject to offset is held by the Customer; and ii. The meter is located on, or contiguous to, the property on which the Designated Meter is located. For the purposes of this tariff, contiguous property includes property that is separated from the Premises of the Designated Meter by public or railroad rights of way; and iii. The meter is served by the same primary feeder as the Designated Meter at the time the Customer files the application for the Exporting System; and iv. The electricity recorded by the meter is for the Customer’s requirements; and v. For Customers taking service under Schedule 1 or Schedule 7, credits may only be transferred to meters taking service under Schedule 1 or Schedule 7. For Customers taking service under Schedule 9, Schedule 19, or Schedule 24, credits may only be transferred to meters taking service under Schedule 9, Schedule 19, or Schedule 24. Idaho Power Company Original Sheet No. 84-6 Cancels I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. 84-6 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 84 LARGE GENERAL, LARGE POWER, AND IRRIGATION ON-SITE GENERATION SERVICE (Continued) NET ENERGY METERING - CONDITIONS OF PURCHASE AND SALE (Continued) b. Customers may submit requests to transfer Excess Net Energy credits between December 1 and January 31 of each year. All requests must be received by Idaho Power by midnight, Mountain Standard Time, on January 31. If a Customer does not request to transfer Excess Net Energy credits by the January 31 submission deadline Excess Net Energy credits will carry forward to offset consumption at the Designated Meter until they become eligible the following year. c. Requests to transfer Excess Net Energy credits must be executed by the Company no later than March 31. Transfers will be based on the balance of Excess Net Energy credits available at the time the transfer is made. d. If multiple meters are eligible for aggregation, Excess Net Energy credits must first be applied to the Designated Meter, then to eligible meters on rate schedules in accordance with Section 2a(v) above. e. A meter aggregation fee of $10.00 will be assessed per aggregated meter per annual transfer transaction. NET BILLING – CONDITIONS OF PURCHASE AND SALE The conditions listed below shall apply to transactions for Net Billing under this schedule. 1. Balances of usage and exports by the Customer. a. The Customer shall be billed for the electricity supplied by the Company at the rates contained within the Customer’s applicable standard service schedule, in accordance with normal metering practices. b. The Customer shall be credited for Exported Energy at the applicable Export Credit Rate contained within this schedule as a credit in dollars to only offset Monthly Charges. Exported Energy credits are subject to the following provisions: i. Credits shall carry forward provided the Customer maintains electric service at the same Point of Delivery. ii. Credits are transferrable in the event that a Customer relocates. If the establishment of service at the new Point of Delivery is not initiated at the time service at the Designated Meter is discontinued, it is the Customer’s responsibility to request the credit transfer when service is established at the new location in Idaho Power’s service area. Idaho Power Company I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 84-7 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 84 LARGE GENERAL, LARGE POWER, AND IRRIGATION ON-SITE GENERATION SERVICE (Continued) NET BILLING – CONDITIONS OF PURCHASE AND SALE (Continued) iii. If a Customer discontinues service at the Point of Delivery associated with the Exporting System and does not intend to establish service at another location in Idaho Power’s service area any unused credits will be paid out following the time the final bill is prepared. 2. Aggregation of meters for the annual transfer of unused credits: a. If a balance of credits exists at a Designated Meter, the Customer may request to transfer the unused credits to eligible meters. A meter is eligible for aggregation if it meets the following criteria: i. The account subject to offset is held by the Customer; and ii. The electricity recorded by the meter is for the Customer’s requirements. b. Customers may submit requests to transfer a stated percentage of available credits between December 1 and January 31 of each year. All requests must be received by Idaho Power by midnight, Mountain Standard Time, on January 31. If a Customer does not request to transfer credits by the January 31 submission deadline credits will carry forward at the Designated Meter until they become eligible for transfer the following year. c. Requests to transfer credits must be executed by the Company no later than March 31. Transfers will be based on the balance of credits available at the time the transfer is made. d. A meter aggregation fee of $10.00 will be assessed per aggregated meter per annual transfer transaction. NET ENERGY METERING & NET BILLING – GENERAL CONDITIONS 1. The Customer shall never deliver or attempt to deliver energy to the Company’s system when the Company’s system serving the Customer’s DER is de-energized for any reason. 2. The Company shall not be liable directly or indirectly for permitting or continuing to allow an attachment of a Exporting System to the Company’s system, or for the acts or omissions of the Customer that cause loss or injury, including death, to any third party. 3. The Customer is responsible for all costs associated with the DER and Interconnection Facilities. The Customer is also responsible for all costs associated with any Company additions, modifications, or upgrades to any Company facilities that the Company determines are necessary as a result of the installation of the DER in order to maintain a safe, reliable electrical system. Idaho Power Company I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 84-8 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 84 LARGE GENERAL, LARGE POWER, AND IRRIGATION ON-SITE GENERATION SERVICE (Continued) NET ENERGY METERING & NET BILLING – GENERAL CONDITIONS (Continued) 4. The Company shall not be obligated to accept, and the Company may require the Customer to curtail, interrupt or reduce deliveries of energy if the Company, consistent with Prudent Electrical Practices, determines that curtailment, interruption or reduction is necessary because of line construction or maintenance requirements, emergencies, or other critical operating conditions on its system. 5. If the Company is required by the Commission to institute curtailment of deliveries of electricity to its customers, the Company may require the Customer to curtail its consumption of electricity in the same manner and to the same degree as other Customers on the Company’s standard service schedules. 6. The Customer shall grant to the Company all access to all Company equipment and facilities including adequate and continuing access rights to the property of the Customer for the purpose of installation, operation, maintenance, replacement or any other service required of said equipment, as well as all necessary access for inspection, switching and any other operational requirements of the Customer’s Interconnection Facilities. 7. The Customer shall notify the Company immediately if an Exporting System is permanently removed or disabled. Permanent removal or disablement for the purposes of this schedule is any removal or disablement of an Exporting System lasting longer than six (6) months. Customers with permanently removed systems will be removed from service under this schedule and placed on the appropriate standard service schedule. Idaho Power Company I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 84-9 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 84 LARGE GENERAL, LARGE POWER, AND IRRIGATION ON-SITE GENERATION SERVICE (Continued) SUMMER AND NON-SUMMER SEASONS The summer season begins on June 1 of each year and ends on September 30 of each year. The non-summer season begins on October 1 of each year and ends on May 31 of each year. TIME PERIODS – EXPORT CREDIT RATE The time periods for the Export Credit Rate are defined as follows. All times are stated in Mountain Time. Summer Season On-Peak: 3:00 p.m. to 11:00 p.m. Monday through Saturday, except holidays Off-Peak: 11:00 p.m. to 3:00 p.m. Monday through Saturday and all hours on Sunday and holidays Non-summer Season Off-Peak: All hours Monday through Sunday Holidays are New Year's Day (January 1), Memorial Day (last Monday in May), Independence Day (July 4), Labor Day (first Monday in September), Thanksgiving Day (fourth Thursday in November), and Christmas Day (December 25). If New Year’s Day, Independence Day, or Christmas Day falls on Saturday, the preceding Friday will be designated a holiday. If New Year’s Day, Independence Day, or Christmas Day falls on Sunday, the following Monday will be designated a holiday. EXPORT CREDIT RATE The following rate structure and credits are subject to change upon Commission approval: Summer Non-summer Export Credit Rate, per kWh On-Peak: 16.9966¢ 4.8365¢ Off-Peak: 5.6533¢ 4.8365¢ Idaho Power Company Original Sheet No. D-1 Cancels I.P.U.C. No. 30, Tariff No. 101 OriginalFirst Revised Sheet No. D-1 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 36042 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho RULE D METERING 1. Meter Installations. The Company will install and maintain the metering equipment required by the Company to measure power and energy supplied to the Customer. Meter installations will be done at the Company's expense except as specified below or otherwise specified in a schedule. Customer provisions for meter installations will be made in conformance with Company specifications, the National Electrical Code, and/or applicable state or municipal requirements. a. Instrument Transformer Metering. When instrument transformer metering is requested by the Customer but not required by the Company at the time of the initial meter installation, the Customer will be required to pay the cost of such metering equipment and its installation in accordance with the charges specified in Schedule 66. When a Customer requests instrument transformer metering not required by the Company at a time other than at the time of the initial meter installation, work order costs will apply. b. Load Profile Metering. The Company will install, at the Customer’s request, the metering equipment necessary to provide load profile information. When Load Profile Metering service is requested by the Customer but not provided by the Company as part of its standard meter installation, the Customer will pay work order costs for the installation of all equipment required to provide such service. The options available under Load Profile Metering service include: Pulse Output Service, which provides limited kWh and kW load information; Load Profile Recording Service, which downloads load characteristics and information on a delayed basis; and Enhanced Metering Information Service, which provides real-time access to load characteristics and information. Customers requesting that the Company provide Load Profile Metering service are responsible for providing, at their own expense, a hard-wired or wireless connection to each metering point, and all such connection equipment will be owned by the Customer unless the configuration of metering equipment necessitates otherwise. The Company shall not be liable to any Customer or any other persons for any loss or damage incurred resulting from the supply or interruption of any Load Profile Metering service. The Company does not warrant or guarantee the accuracy, reliability, validity or usability of the information or data provided by its Load Profile Metering service, and Customers receiving any such Load Profile Metering service voluntarily assume all responsibility and risk in use of such service’s information or data. c. Primary Voltage Metering. The Company will install, at its own expense, a maximum of one primary voltage meter at a single Premises to record usage taken at 12.5 kV or 34.5 kV. In all other circumstances, work order costs will apply. 2. Measurement of Energy. Except as otherwise specifically provided, all energy delivered by the Company will be billed according to measurement by meters located at or near the Point of Delivery. If the Company is unable to obtain a Customer's meter reading(s), the Company may estimate the meter reading(s) for the Billing Period on the basis of the Customer's previous use, season of the year and use by similar Customers of the same class in that service area. Bills rendered based on an estimated monthly read, or when a Billing Period includes more than twenty-four unscaled hourly reads, will be designated as estimated on the bill. The amount of such estimated bill will be subsequently adjusted, when practicable, when the next actual reading is obtained. Idaho Power Company Original Sheet No. D-2 Cancels I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. D-2 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 36042 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho RULE D METERING (Continued) 3. Failure to Register. If the Company's meters fail to register at any time, the service delivered and energy consumed during such period of failure will be determined by the Company on the basis of the best available data. If any appliance or wiring connection, or any other device, is found on the Customer's Premises which prevents the meters from accurately recording the total amount of energy used on the Premises, the Company may at once remove any such wiring connection or appliance, or device, at the Customer's expense, and will estimate the amount of energy so consumed and not registered as accurately as it is able so to do, and the Customer will pay for any such energy within 5 days after being billed, in accordance with such estimate. 4. Meter Tests. The Company will test and inspect its meters from time to time and maintain their accuracy of registration in accordance with generally accepted practices and the rules and regulations established by the Idaho Public Utilities Commission. The Company will, without charge, test the accuracy of registration of a meter upon request of a Customer, provided that the Customer does not request such a test more frequently than once in a 12-month period. If more than one requested test is performed within a 12-month period, the Customer will be required to pay in advance the cost of a special meter test as specified in Schedule 66. The Company will refund the amount paid by the Customer for the test if the results of the test show the average registration error of the meter exceeds ±2 percent. 5. Transformer Losses. When delivery of service is on the primary side of the Customer's transformers, the Company may install its meters on the secondary side of the transformers, and, unless otherwise provided in the schedule, in determining the monthly consumption of power and energy, transformer losses and other losses occurring between the Point of Delivery and the meters will be computed and added to the reading of such meters. 6. Meter Reading. Meters will be read to the last kWh registered, normally at intervals of approximately 30 days for monthly register reads and daily for hourly interval reads. In no case will the meter reading interval exceed 45 days. Idaho Power Company Original Sheet No. E-1 Cancels I.P.U.C. No. 30, Tariff No. 101 Original First Revised Sheet No. E-1 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 36042 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho RULE E MASTER METERING STANDARDS 1. Definitions: a. Tenant--Mobile Home Park. A tenant of a mobile home park is a person defined as a resident and not a transient by the Manufactured Home Residency Act, Section 55-2001 et seq., Idaho Code, and in particular by Section 55-2003(16) and 55-2003(19), Idaho Code. b. Tenant--Multi-Unit Residential or Commercial Building. A tenant of a multi-unit residential building is a person who is not a transient and who intends to reside in or be a commercial tenant in one of the building's units for a period of not less than one month. 2. Master-Metering and Individual Metering in Mobile Home Parks: a. Master Metering Prohibited. Master-metering, whether or not in conjunction with sub-metering of electric service by the park operator, is prohibited for any mobile home park connected for service by the Company after July 1, 1980. After that date, tenants (excluding transients) of mobile home parks must be individually metered and billed by the Company. b. Exception for Sub-Metered Parks. Any mobile home park connected for service on or before July 1, 1980, whose spaces for non-transient tenants have been fully sub-metered for electricity by the park owners need not be individually metered by the Company. A mobile home park sub-metered by the park operator must charge each of their tenants the same rate for electric service that a Customer of the Company would be charged if the tenant were directly metered and billed by the Company under Schedule 3 – Master-Metered Mobile Home Park – Residential Service. Testing of sub-meters will be at the park operator's expense. 3. Master-Metering and Individual Metering in Multi-Occupant Residential Buildings. Non- transient tenants of multi-occupant residential buildings connected for electric service after July 1, 1980, will be individually metered and billed by the Company if the dwelling units for such tenants contain an electric space heating, water heating, or air-conditioning (space cooling) unit that is not centrally controlled and for which said tenants individually control electric usage. 4. Master-Metering and Individual Metering in Commercial Buildings and Shopping Centers. Commercial buildings and shopping centers connected for electric service after July 1, 1980, may not be master-metered if the units for non-transient tenants contain an electric space heating, water heating, or air-conditioning (space cooling) unit that is not centrally controlled and for which the unit's tenants individually control electric usage. Any non-transient tenants in otherwise master- metered buildings will be individually metered and billed by the Company if the tenant’s electric load is significantly greater than that of the other tenants in the building or shopping center, or exceeds the individual metering threshold found in the Company's Tariff. Idaho Power Company Original Sheet No. 6-1 Cancels I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. 6-1 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 6 RESIDENTIAL SERVICE ON-SITE GENERATION AVAILABILITY Service under this schedule is available at points on the Company's interconnected system within the State of Idaho where existing facilities of adequate capacity and desired phase and voltage are adjacent to the location where Residential Service, On-Site Generation is desired, and where additional investment by the Company for new transmission, substation or terminal facilities is not necessary to supply the desired service. This service is available to Customers intending to operate Exporting Systems to generate electricity to reduce all or part of the monthly energy usage. Standard rates will be applicable unless a Customer elects time-of-use. Time-of-use is an optional, voluntary service that provides Customers the option to take electric service with seasonal time- of-use energy rates. If a Customer requests to participate in the optional time-of-use service, the Customer will be placed on time-of-use under this schedule effective with their next billing cycle. A Customer may terminate their participation in the time-of-use service at any time. However, the Customer may not subsequently elect time-of-use service under this schedule for one year after the effective date of cancellation. If a Customer requests to be taken off of time-of-use service under this schedule, the Customer will be moved back to the default service under this schedule as of the last meter read date. Effective December 21, 2019, Schedule 6 is closed to new applications for Net Energy Metering. APPLICABILITY Service under this schedule is applicable to Electric Service required for residential service Customers for general domestic uses, including single phase motors of 7½ horsepower rating or less, subject to the following conditions: 1. When a portion of a dwelling is used regularly for business, professional or other gainful purposes, or when service is supplied in whole or in part for business, professional, or other gainful purposes, the Premises will be classified as non-residential and the appropriate General Service Schedule will apply. However, if the wiring is so arranged that the service for residential purposes can be metered separately, this schedule will be applied to such service. 2. Whenever the Customer's equipment does not conform to the Company's specifications for service under this schedule, service will be supplied under the appropriate General Service Schedule. 3. This schedule is not applicable to standby service, service for resale, or shared service. 4. Customer owns and/or operates a Generation Facility fueled by solar, wind, biomass, geothermal, hydropower or represents fuel cell technology, with a total nameplate capacity rating of 25 kilowatts (kW) or less, that is connected in Parallel with the Idaho Power System. The capacity of an Energy Storage Device shall not be used to calculate the capacity limits in this schedule. 5. The Generation Facility is interconnected to the Customer’s individual electric system on the Customer’s side of the Point of Delivery, thus all energy received and delivered by the Company is through the Company’s existing watt-hour retail meter. Idaho Power Company Original Sheet No. 6-2 Cancels I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. 6-2 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 6 RESIDENTIAL SERVICE ON-SITE GENERATION (Continued) APPLICABILITY (Continued) 6. Customer meets all applicable requirements detailed in the Company’s Schedule 68, Interconnections to Customer Distributed Energy Resources. 7. Legacy Status for eligible Exporting Systems will terminate December 2045. 8. The Legacy Status of the Exporting System is transferrable to a subsequent Customer at the premises for which a valid on-site generation service is in effect. Each Customer of a Legacy System taking service under Schedule 6 will be responsible for complying with the terms and conditions of the on-site generation service in effect for that premises. 9. A Legacy System that is offline for over six (6) months or that is moved to a different site shall forfeit Legacy Status of the Exporting System. 10. To remain eligible for Legacy Status, a Customer may increase the capacity of a Legacy System by no more than 10 percent of the originally installed nameplate capacity, or 1 kW, whichever is greater, to allow for the replacement of broken or degraded components. If a Customer expands a Legacy System beyond these limits, the new portion of the DER shall be separately metered and would not qualify for Legacy Status. DEFINITIONS Designated Meter is the retail meter physically connected to the Exporting System. 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 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. Excess Net Energy means the positive difference between the kilowatt-hours (kWh) generated by a Customer and the kWh supplied by the Company over the applicable Billing Period. Exported Energy means the kWh generated by a Customer in excess of the Customer’s on-site consumption that is exported to the Company’s system. 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. An Exporting System is interconnected to the Company’s system under the applicable terms of Schedule 68. Generation Facility means all equipment used to generate electric energy where the resulting energy is delivered to the Company via a single meter at the Point of Delivery or is consumed by the Customer. A Generation Facility is a DER. Idaho Power Company Original Sheet No. 6-3 Cancels I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. 6-3 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 6 RESIDENTIAL SERVICE ON-SITE GENERATION (Continued) DEFINITIONS (Continued) Interconnection Facilities are all facilities reasonably required by Prudent Electrical Practices and the applicable electric and safety codes to interconnect and safely deliver energy from the DER to the Point of Delivery. Legacy Status refers to the ability for a system to receive Net Energy Metering, including net monthly one-for-one kWh credit compensation for Excess Net Energy. Legacy System means any system that meets the applicable criteria as described in Order Nos. 34509 and 34546. Net Billing is the compensation structure applicable to all systems that do not meet the criteria of a Legacy System. Net Billing will be effective with each eligible customer’s first billing cycle after January 1, 2024. Net Energy Metering is the compensation structure applicable to all Legacy Systems. Parallel connection means generating electricity from an on-site generation system that is connected to and receives voltage from Idaho Power’s system. Point of Delivery is the retail metering point where the Company's and the Customer’s electrical facilities are interconnected to allow the Customer to take retail electric service from the Company. Prudent Electrical Practices are those practices, methods and equipment that are commonly used in prudent electrical engineering and operations to operate electric equipment lawfully and with safety, dependability, efficiency and economy. Schedule 68 is the Company’s service schedule which provides for interconnection to DERs or its successor schedule(s) as approved by the Commission. TYPE OF SERVICE The type of service provided under this schedule is single phase, alternating current at approximately 120 or 240 volts and 60 cycles, supplied through one meter at one Point of Delivery. Upon request by the owner of multi-family dwellings, the Company may provide 120/208 volt service for multi- family dwellings when all equipment is U L approved to operate at 120/208 volts. Idaho Power Company Original Sheet No. 6-4 Cancels I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. 6-4 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 6 RESIDENTIAL SERVICE ON-SITE GENERATION (Continued) NET ENERGY METERING - CONDITIONS OF PURCHASE AND SALE The conditions listed below shall apply to all transactions for Net Energy Metering under this schedule. 1. Balances of generation and usage by the Customer: a. If electricity supplied by the Company during the Billing Period exceeds the electricity generated by the Customer and delivered to the Company during the Billing Period, the Customer shall be billed for the net electricity supplied by the Company at the rates contained within this schedule, in accordance with normal metering practices. b. If electricity generated by the Customer and delivered to the Company during the Billing Period exceeds the electricity supplied by the Company during the Billing Period, the Excess Net Energy shall be carried forward as a kWh credit to offset energy usage in a subsequent Billing Period. Excess Net Energy credits are subject to the following provisions: i. Credits can only be used to offset billed kWh consumption. Customers shall be billed for all applicable non-energy charges for the Billing Period according to the applicable standard service schedule. ii. Credits shall carry forward provided the Customer maintains electric service at the same Point of Delivery. iii. Credits are non-transferrable in the event that a Customer relocates and/or discontinues service at the Point of Delivery associated with the Exporting System. Any unused credits will expire at the time the final bill is prepared. c. Compensation for the balance of generation and usage by the Customer is subject to change upon Commission approval. 2. Aggregation of meters for the annual transfer of unused Excess Net Energy credits: a. If a balance of Excess Net Energy credits exists at a Designated Meter the Customer may request to transfer the unused credits to offset energy consumption at eligible meters. A meter is eligible for aggregation if it meets all of the following criteria: Idaho Power Company Original Sheet No. 6-5 Cancels I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. 6-5 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 6 RESIDENTIAL SERVICE ON-SITE GENERATION (Continued) NET ENERGY METERING - CONDITIONS OF PURCHASE AND SALE (Continued) i. The account subject to offset is held by the Customer; and ii. The meter is located on, or contiguous to, the property on which the Designated Meter is located. For the purposes of this tariff, contiguous property includes property that is separated from the Premises of the Designated Meter by public or railroad rights of way; and iii. The meter is served by the same primary feeder as the Designated Meter at the time the Customer files the application for the Exporting System; and iv. The electricity recorded by the meter is for the Customer’s requirements; and v. Credits may only be transferred to meters taking service under Schedule 1, Schedule 6, Schedule 7, or Schedule 8. b. Customers may submit requests to transfer Excess Net Energy credits between December 1 and January 31 of each year. All requests must be received by Idaho Power by midnight, Mountain Standard Time, on January 31. If a Customer does not request to transfer Excess Net Energy credits by the January 31 submission deadline Excess Net Energy credits will carry forward to offset consumption at the Designated Meter until they become eligible the following year. c. Requests to transfer Excess Net Energy credits must be executed by the Company no later than March 31. Transfers will be based on the balance of Excess Net Energy credits available at the time the transfer is made. d. If multiple meters are eligible for aggregation, Excess Net Energy credits must first be applied to the Designated Meter, then to eligible meters on rate schedules in accordance with Section 2a(v) above. e. A meter aggregation fee of $10.00 will be assessed per aggregated meter per annual transfer transaction. NET BILLING – CONDITIONS OF PURCHASE AND SALE The conditions listed below shall apply to all transactions for Net Billing under this schedule. 1. Balances of usage and exports by the Customer. a. The Customer shall be billed for the electricity supplied by the Company at the rates contained within this schedule, in accordance with normal metering practices. Idaho Power Company Original Sheet No. 6-6 Cancels I.P.U.C. No. 30, Tariff No. 101 Sixth Revised Sheet No. 6-6 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 6 RESIDENTIAL SERVICE ON-SITE GENERATION (Continued) NET BILLING – CONDITIONS OF PURCHASE AND SALE (Continued) b. The Customer shall be credited for Exported Energy at the applicable Export Credit Rate contained within this schedule as a credit in dollars to only offset Monthly Charges. Exported Energy credits are subject to the following provisions: i. Credits shall carry forward provided the Customer maintains electric service at the same Point of Delivery. ii. Credits are non-transferrable in the event that a Customer relocates. If the establishment of service at the new Point of Delivery is not initiated at the time service at the Designated Meter is discontinued, it is the Customer’s responsibility to request the credit transfer when service is established at the new location in Idaho Power’s service area. ii.iii. If a Customer and/or discontinues services at the Point of Delivery associated with the Exporting System and does not intend to establish service at another location in Idaho Power’s service area. Aany unused credits will be paid out following expire at the time the final bill is prepared. 2. Aggregation of meters for the annual transfer of unused credits: a. If a balance of credits exists at a Designated Meter, the Customer may request to transfer the unused credits to eligible meters. A meter is eligible for aggregation if it meets the following criteria: i. The account subject to offset is held by the Customer, and ii. The electricity recorded by the meter is for the Customer’s requirements. b. Customers may submit requests to transfer a stated percentage of available credits between December 1 and January 31 of each year. All requests must be received by Idaho Power by midnight, Mountain Standard Time, on January 31. If a Customer does not request to transfer credits by the January 31 submission deadline credits will carry forward at the Designated Meter until they become eligible for transfer the following year. c. Requests to transfer credits must be executed by the Company no later than March 31. Transfers will be based on the balance of credits available at the time the transfer is made. d. A meter aggregation fee of $10.00 will be assessed per aggregated meter per annual transfer transaction. NET ENERGY METERING & NET BILLING – GENERAL CONDITIONS Idaho Power Company Original Sheet No. 6-6 Cancels I.P.U.C. No. 30, Tariff No. 101 Sixth Revised Sheet No. 6-6 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 1. The Customer shall never deliver or attempt to deliver energy to the Company’s system when the Company’s system serving the Customer’s DER is de-energized for any reason. 2. The Company shall not be liable directly or indirectly for permitting or continuing to allow an attachment of an Exporting System to the Company’s system, or for the acts or omissions of the Customer that cause loss or injury, including death, to any third party. Idaho Power Company I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 6-7 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 6 RESIDENTIAL SERVICE ON-SITE GENERATION (Continued) NET ENERGY METERING & NET BILLING – GENERAL CONDITIONS 1. The Customer shall never deliver or attempt to deliver energy to the Company’s system when the Company’s system serving the Customer’s DER is de-energized for any reason. 2. The Company shall not be liable directly or indirectly for permitting or continuing to allow an attachment of an Exporting System to the Company’s system, or for the acts or omissions of the Customer that cause loss or injury, including death, to any third party. 3. The Customer is responsible for all costs associated with the DER and Interconnection Facilities. The Customer is also responsible for all costs associated with any Company additions, modifications, or upgrades to any Company facilities that the Company determines are necessary as a result of the installation of the DER in order to maintain a safe, reliable electrical system. 4. The Company shall not be obligated to accept, and the Company may require the Customer to curtail, interrupt or reduce deliveries of Energy if the Company, consistent with Prudent Electrical Practices, determines that curtailment, interruption, or reduction is necessary because of line construction or maintenance requirements, emergencies, or other critical operating conditions on its system. 5. If the Company is required by the Commission to institute curtailment of deliveries of electricity to its customers, the Company may require the Customer to curtail its consumption of electricity in the same manner and to the same degree as other Customers on the Company’s standard service schedules. 6. The Customer shall grant to the Company all access to all Company equipment and facilities including adequate and continuing access rights to the property of the Customer for the purpose of installation, operation, maintenance, replacement, or any other service required of said equipment, as well as all necessary access for inspection, switching, and any other operational requirements of the Customer’s Interconnections Facilities. 7. The Customer shall notify the Company immediately if an Exporting System is permanently removed or disabled. Permanent removal or disablement for the purposes of this Schedule is any removal or disablement of an Exporting System lasting longer than six (6) months. Customers with permanently removed or disabled systems will be removed from service under this schedule and placed on the appropriate standard service schedule. SUMMER AND NON-SUMMER SEASONS The summer season begins on June 1 of each year and ends on September 30 of each year. The non-summer season begins on October 1 of each year and ends on May 31 of each year. Idaho Power Company I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 6-8 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 6 RESIDENTIAL SERVICE ON-SITE GENERATION (Continued) SUMMER AND NON-SUMMER SEASONS The summer season begins on June 1 of each year and ends on September 30 of each year. The non-summer season begins on October 1 of each year and ends on May 31 of each year. TIME PERIODS – TIME-OF-USE MONTHLY CHARGES The time periods for Time-of-Use Monthly Charges are defined as follows. All times are stated in Mountain Time. Summer Season On-Peak: 7:00 p.m. to 11:00 p.m. Monday through Saturday, except holidays Mid-Peak: 3:00 p.m. to 7:00 p.m. Monday through Saturday, except holidays Off-Peak: 11:00 p.m. to 7:00 p.m. Monday through Saturday and all hours on Sunday and holidays Non-summer Season On-Peak: 7:00 a.m. to 9:00 a.m. and 6:00 p.m. to 9:00 p.m. Monday through Saturday, except holidays Off-Peak: 9:00 a.m. to 6:00 p.m. and 9:00 p.m. to 7:00 a.m. Monday through Saturday and all hours on Sundays and holidays TIME PERIODS – EXPORT CREDIT RATE The time periods for the Export Credit Rate are defined as follows. All times are stated in Mountain Time. Summer Season On-Peak: 3:00 p.m. to 11:00 p.m. Monday through Saturday, except holidays Off-Peak: 11:00 p.m. to 3:00 p.m. Monday through Saturday and all hours on Sunday and holidays Non-summer Season Off-peak: All hours Monday through Sunday Holidays are New Year's Day (January 1), Memorial Day (last Monday in May), Independence Day (July 4), Labor Day (first Monday in September), Thanksgiving Day (fourth Thursday in November), and Christmas Day (December 25). If New Year’s Day, Independence Day, or Christmas Day falls on Sunday, the following Monday will be designated a holiday. Idaho Power Company I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 6-9 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 6 RESIDENTIAL SERVICE ON-SITE GENERATION (Continued) MONTHLY CHARGE The Monthly Charge is the sum of the following charges, and may also include charges as set forth in Schedule 54 (Fixed Cost Adjustment), Schedule 55 (Power Cost Adjustment), Schedule 91 (Energy Efficiency Rider), Schedule 95 (Adjustment for Municipal Franchise Fees), Schedule 96 (Blaine County Surcharge to Fund the Undergrounding of Certain Facilities), and Schedule 98 (Residential and Small Farm Energy Credit). The following rate structure and charges are subject to change upon Commission approval: STANDARD RATES (DEFAULT) Summer Non-summer Service Charge, per month $10.00 $10.00 Energy Charge, per kWh First 800 kWh 10.1082¢ 8.8958¢ 801-2000 kWh 12.1546¢ 9.8073¢ All Additional kWh Over 2000 14.4385¢ 10.8615¢ TIME-OF-USE RATES (OPTIONAL) Summer Non-summer Service Charge, per month $10.00 $10.00 Energy Charge, per kWh On-Peak 24.6472¢ 12.7787¢ Mid-Peak 12.3238¢ n/a Off-Peak 6.1618¢ 8.5191¢ EXPORT CREDIT RATE The following rate structure and credits are subject to change upon Commission approval: Summer Non-summer Export Credit Rate, per kWh On-Peak TBD16.9966¢ TBD4.8365¢ Off-Peak TBD5.6533 ¢ TBD4.8365¢ PAYMENT The monthly bill rendered for service supplied hereunder is payable upon receipt, and becomes past due 15 days from the date on which rendered. Idaho Power Company Original Sheet No. 8-1 Cancels I.P.U.C. No. 30, Tariff No. 101 Second Revised Sheet No. 8-1 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 8 SMALL GENERAL SERVICE ON-SITE GENERATION AVAILABILITY Service under this schedule is available at points on the Company's interconnected system within the State of Idaho where existing facilities of adequate capacity and desired phase and voltage are adjacent to the location where Small General Service, On-Site Generation is desired, and where additional investment by the Company for new transmission, substation or terminal facilities is not necessary to supply the desired service. This service is available to Customers intending to operate Exporting Systems under this schedule to generate electricity to reduce all or part of their monthly energy usage. Effective December 21, 2019, Schedule 8 is closed to new applications for Net Energy Metering. APPLICABILITY Service under this schedule is applicable to Electric Service supplied to a Customer at one Point of Delivery and measured through one meter. This schedule is applicable to Customers whose metered energy usage is 2,000 kWh, or less, per Billing Period for ten or more Billing Periods during the most recent 12 consecutive Billing Periods. When the Customer’s Billing Period is less than 27 days or greater than 36 days, the energy usage will be prorated to 30 days for purposes of determining eligibility under this schedule. Customers whose metered energy usage exceeds 2,000 kWh per Billing Period on an actual or prorated basis three times during the most recent 12 consecutive Billing Periods are not eligible for service under this schedule and will be automatically transferred to the applicable schedule effective with the next Billing Period. New customers may initially be placed on this schedule based on estimated usage. This schedule is also applicable to non-profit or tax supported ball fields, fairgrounds or rodeo grounds with high demands and intermittent use exceeding 2,000 kWh per month. This schedule is not applicable to standby service, service for resale, shared service, to individual or multiple family dwellings first served through one meter after February 9, 1982, or to agricultural irrigation service after October 31, 2004. Service under this schedule is also subject to the following conditions: 1. Customer owns/and or operates a Generation Facility fueled by solar, wind, biomass, geothermal, hydropower or represents fuel cell technology, with a total nameplate capacity rating of 25 kilowatts (kW) or less, that is connected in Parallel with the Idaho Power System. The capacity of an Energy Storage Device shall not be used to calculate the capacity limits in this schedule. 2. The Generation Facility is interconnected to the Customer’s individual electric system on the Customer’s side of the Point of Delivery, thus all energy received and delivered by the Company is through the Company’s existing watt-hour retail meter. 3. Customer meets all applicable requirements detailed in the Company’s Schedule 68, Interconnections to Customer Distributed Energy Resources. Idaho Power Company Original Sheet No. 8-2 Cancels I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. 8-2 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 8 SMALL GENERAL SERVICE ON-SITE GENERATION (Continued) APPLICABILITY (Continued) 4. Legacy Status for eligible Exporting Systems will terminate December 2045. 5. The Legacy Status of the Exporting System is transferable to a subsequent Customer at the premises for which a valid on-site generation service is in effect. Each Customer of a Legacy System taking service under Schedule 8 will be responsible for complying with the terms and conditions of the on-site generation service in effect for that premises. 6. A Legacy System that is offline for over six (6) months or that is moved to a different site shall forfeit Legacy Status of the Exporting System. 7. To remain eligible for Legacy Status, a Customer may increase the capacity of a Legacy System by no more than 10 percent of the originally installed nameplate capacity, or 1 kW, whichever is greater, to allow for the replacement of broken or degraded components. If a Customer expands a Legacy System beyond these limits, the new portion of the DER shall be separately metered and would not qualify for Legacy Status. DEFINITIONS Designated Meter is the retail meter physically connected to the Exporting System. 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. Excess Net Energy means the positive difference between the kilowatt-hours (kWh) generated by a Customer and the kWh supplied by the Company over the applicable Billing Period. Exported Energy means the kWh generated by a Customer in excess of the Customer’s on-site consumption that is exported to the Company’s system. 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 electricity energy to the Company. An Exporting System is interconnected to the Company’s system under the applicable terms of Schedule 68. Generation Facility means all equipment used to generate electric energy where the resulting energy is either delivered to the Company via a single meter at the Point of Delivery or is consumed by the Customer. A Generation Facility is a DER. Interconnection Facilities are all facilities reasonably required by Prudent Electrical Practices and the applicable electric and safety codes to interconnect and safely deliver energy from the DER to the Point of Delivery. Idaho Power Company Original Sheet No. 8-3 Cancels I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. 8-3 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 8 SMALL GENERAL SERVICE ON-SITE GENERATION (Continued) DEFINITIONS (Continued) Legacy Status refers to the ability for a system to receive Net Energy Metering, including net monthly one-for-one kWh credit compensation for Excess Net Energy. Legacy System means for any system that meets the applicable criteria as described in Order No. 34509 and 34546. Net Billing is the compensation structure applicable to all systems that do not meet the criteria of a Legacy System. Net Billing will be effective with each eligible customer’s first billing cycle after January 1, 2024. Net Energy Metering is the compensation structure applicable to all Legacy Systems. Parallel connection means generating electricity from an on-site generation system that is connected to and receives voltage from Idaho Power’s system. Point of Delivery is the retail metering point where the Company's and the Customer’s electrical facilities are interconnected to allow the Customer to take retail electric service from the Company. Prudent Electrical Practices are those practices, methods, and equipment that are commonly used in prudent electrical engineering and operations to operate electric equipment lawfully and with safety, dependability, efficiency and economy. Schedule 68 is the Company’s service schedule which provides for interconnection to DERs or its successor schedule(s) as approved by the Commission. TYPE OF SERVICE The type of service provided under this schedule is single and/or three-phase alternating current, at approximately 60 cycles and at the standard service voltage available at the Premises to be served. NET ENERGY METERING - CONDITIONS OF PURCHASE AND SALE The conditions listed below shall apply to all transactions for Net Energy Metering under this schedule. 1. Balances of generation and usage by the Customer: a. If electricity supplied by the Company during the Billing Period exceeds the electricity generated by the Customer and delivered to the Company during the Billing Period, the Customer shall be billed for the net electricity supplied by the Company at the rates contained within this schedule, in accordance with normal metering practices. Idaho Power Company Original Sheet No. 8-4 Cancels I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. 8-4 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 8 SMALL GENERAL SERVICE ON-SITE GENERATION (Continued) NET ENERGY METERING - CONDITIONS OF PURCHASE AND SALE (Continued) b. If electricity generated by the Customer and delivered to the Company during the Billing Period exceeds the electricity supplied by the Company during the Billing Period, the Excess Net Energy shall be carried forward as a kWh credit to offset energy usage in a subsequent Billing Period. Excess Net Energy credits are subject to the following provisions: i. Credits can only be used to offset billed kWh consumption. Customers shall be billed for all applicable non-energy charges for the Billing Period according to the applicable standard service schedule. ii. Credits shall carry forward provided the Customer maintains electric service at the same Point of Delivery. iii. Credits are non-transferrable in the event that a Customer relocates and/or discontinues service at the Point of Delivery associated with the Exporting System. Any unused credits will expire at the time the final bill is prepared. c. Compensation for the balance of generation and usage by the Customer is subject to change upon Commission approval. 2. Aggregation of meters for the annual transfer of unused Excess Net Energy credits: a. If a balance of Excess Net Energy credits exists at a Designated Meter, the Customer may request to transfer the unused credits to offset energy consumption at eligible meters. A meter is eligible for aggregation if it meets all of the following criteria: i. The account subject to offset is held by the Customer; and ii. The meter is located on, or contiguous to, the property on which the Designated Meter is located. For the purposes of this tariff, contiguous property includes property that is separated from the Premises of the Designated Meter by public or railroad rights of way; and iii. The meter is served by the same primary feeder as the Designated Meter at the time the Customer files the application for the Exporting System; and iv. The electricity recorded by the meter is for the Customer’s requirements; and v. Credits may only be transferred to meters taking service under Schedule 1, Schedule 6, Schedule 7, or Schedule 8. Idaho Power Company Original Sheet No. 8-5 Cancels I.P.U.C. No. 30, Tariff No. 101 Sixth Revised Sheet No. 8-5 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 8 SMALL GENERAL SERVICE ON-SITE GENERATION (Continued) NET ENERGY METERING - CONDITIONS OF PURCHASE AND SALE (Continued) b. Customers may submit requests to transfer Excess Net Energy credits between December 1 and January 31 of each year. All requests must be received by Idaho Power by midnight, Mountain Standard Time, on January 31. If a Customer does not request to transfer Excess Net Energy credits by the January 31 submission deadline Excess Net Energy credits will Carry forward to offset consumption at the Designated Meter until they become eligible for transfer the following year. c. Requests to transfer Excess Net Energy credits must be executed by the Company no later than March 31. Transfers will be based on the balance of Excess Net Energy credits available at the time the transfer is made. d. If multiple meters are eligible for aggregation, Excess Net Energy credits must first be applied to the Designated Meter, then to eligible meters on rate schedules in accordance with Section 2a(v) above. e. A meter aggregation fee of $10.00 will be assessed per aggregated meter per annual transfer transaction. NET BILLING – CONDITIONS OF PURCHASE AND SALE The conditions listed below shall apply to all transactions for Net Billing under the Schedule. 1. Balances of usage and exports by the Customer. a. The Customer shall be billed for the electricity supplied by the Company at the rates contained within this schedule, in accordance with normal metering practices. b. The Customer shall be credited for Exported Energy at the applicable Export Credit Rate contained within this schedule as a credit in dollars to only offset Monthly Charges. Exported Energy credits are subject to the following provisions: i. Credits shall carry forward provided the Customer maintains electric service at the same Point of Delivery. i. ii. Credits are non-transferrable in the event that a Customer relocates. If the establishment of service at the new Point of Delivery is not initiated at the time service at the Designated Meter is discontinued, it is the Customer’s responsibility to request the credit transfer when service is established at the new location in Idaho Power’s service area. ii.iii. If a Customerand/or discontinues service at the Point of Delivery associated with the Exporting System and does not intend to establish service at another location in Idaho Power’s service area. A any unused credits will be paid out following expire at the time the final bill is prepared. Idaho Power Company Original Sheet No. 8-5 Cancels I.P.U.C. No. 30, Tariff No. 101 Sixth Revised Sheet No. 8-5 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 2. Aggregation of meters for the annual transfer of unused credits: a. If a balance of credits exists at a Designated Meter, the Customer may request to transfer the unused credits to eligible meters. A meter is eligible for aggregation if it meets the following criteria: i.The account subject to offset is held by the Customer, and ii. The electricity recorded by the meter is for the Customer’s requirements. Idaho Power Company I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 8-6 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 8 SMALL GENERAL SERVICE ON-SITE GENERATION (Continued) NET BILLING – CONDITIONS OF PURCHASE AND SALE (Continued) 2. Aggregation of meters for the annual transfer of unused credits: a. If a balance of credits exists at a Designated Meter, the Customer may request to transfer the unused credits to eligible meters. A meter is eligible for aggregation if it meets the following criteria: i. The account subject to offset is held by the Customer, and ii. The electricity recorded by the meter is for the Customer’s requirements. a.b. Customers may submit requests to transfer a stated percentage of available credits between December 1 and January 31 of each year. All requests must be received by Idaho Power by midnight, Mountain Standard Time, on January 31. If a Customer does not request to transfer credits by the January 31 submission deadline credits will carry forward at the Designated Meter until they become eligible for transfer the following year. b.c. Requests to transfer credits must be executed by the Company no later than March 31. Transfers will be based on the balance of credits available at the time the transfer is made. c.d. A meter aggregation fee of $10.00 will be assessed per aggregated meter per annual transfer transaction. NET ENERGY METERING & NET BILLING – GENERAL CONDITONS 1. The Customer shall never deliver or attempt to deliver energy to the Company’s system when the Company’s system serving the Customer’s DER is de-energized for any reason. 2. The Company shall not be liable directly or indirectly for permitting or continuing to allow an attachment of an Exporting System to the Company’s system, or for the acts or omissions of the Customer that cause loss or injury, including death, to any third party. 3. The Customer is responsible for all costs associated with the DER and Interconnection Facilities. The Customer is also responsible for all costs associated with any Company additions, modifications, or upgrades to any Company facilities that the Company determines are necessary as a result of the installation of the DER in order to maintain a safe, reliable electrical system. 4. The Company shall not be obligated to accept, and the Company may require the Customer to curtail, interrupt, or reduce deliveries of energy if the Company, consistent with Prudent Electrical Practices, determines that curtailment, interruption, or reduction is necessary because of line construction or maintenance requirements, emergencies, or other critical operating conditions on its system. 5. If the Company is required by the Commission to institute curtailment of deliveries of electricity to its customers, the Company may require the Customer to curtail its consumption of electricity in the same manner and to the same degree as other Customers on the Company’s standard service schedules. Idaho Power Company I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 8-6 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 6. The Customer shall grant to the Company all access to all Company equipment and facilities including adequate and continuing access rights to the property of the Customer for the purpose of installation, operation, maintenance, replacement, or any other service required of said equipment as well as all necessary access for inspection, switching, and any other operational requirements of the Customer’s Interconnections Facilities. . Idaho Power Company I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 8-7 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 8 SMALL GENERAL SERVICE ON-SITE GENERATION NET ENERGY METERING & NET BILLING – GENERAL CONDITONS (Continued) 6. The Customer shall grant to the Company all access to all Company equipment and facilities including adequate and continuing access rights to the property of the Customer for the purpose of installation, operation, maintenance, replacement, or any other service required of said equipment as well as all necessary access for inspection, switching, and any other operational requirements of the Customer’s Interconnections Facilities. 7. The Customer shall notify the Company immediately if an Exporting System is permanently removed or disabled. Permanent removal or disablement for the purposes of this Schedule is any removal or disablement of an Exporting System lasting longer than six (6) months. Customers with permanently removed or disabled systems will be removed from service under this schedule and placed on the appropriate standard service schedule. SUMMER AND NON-SUMMER SEASONS The summer season begins on June 1 of each year and ends on September 30 of each year. The non-summer season begins on October 1 of each year and ends on May 31 of each year. TIME PERIODS – EXPORT CREDIT RATE The time periods for the Export Credit Rate are defined as follows. All times are stated in Mountain Time. Summer Season On-Peak: 73:00 p.m. to 11:00 p.m. Monday through Saturday, except holidays Mid-Peak 3:00 p.m. to 7:00 p.m. Monday through Saturday, except holidays Off-Peak 11:00 p.m. to 3:00 p.m. Monday through Saturday and all hours on Sunday and holidays Non-summer Season Off-Peak: All hours Monday through Sunday Holidays are New Year's Day (January 1), Memorial Day (last Monday in May), Independence Day (July 4), Labor Day (first Monday in September), Thanksgiving Day (fourth Thursday in November), and Christmas Day (December 25). If New Year’s Day, Independence Day, or Christmas Day falls on Sunday, the following Monday will be designated a holiday. MONTHLY CHARGE The Monthly Charge is the sum of the following charges, and may also include charges as set forth in Schedule 54 (Fixed Cost Adjustment), Schedule 55 (Power Cost Adjustment), Schedule 91 (Energy Efficiency Rider), Schedule 95 (Adjustment for Municipal Franchise Fees), Schedule 96 (Blaine County Surcharge to Fund the Undergrounding of Certain Facilities), and Schedule 98 (Residential and Small Farm Energy Credit). Idaho Power Company I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 8-8 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 8 SMALL GENERAL SERVICE ON-SITE GENERATION (Continued) MONTHLY CHARGE (Continued) The following charges are subject to change upon Commission approval: Summer Non-summer Service Charge, per month $25.00 $25.00 Energy Charge, per kWh First 300 kWh 6.7404¢ 6.7404¢ All Additional kWh 7.7027¢ 6.7421¢ EXPORT CREDIT RATE The following rate structure and credits are subject to change upon Commission approval: Summer Non-summer Export Credit Rate, per kWh On-Peak TBD16.9966¢ TBD4.8365¢ Off-Peak TBD5.6533 ¢ TBD4.8365¢ PAYMENT The monthly bill rendered for service supplied hereunder is payable upon receipt, and becomes past due 15 days from the date on which rendered. Idaho Power Company Original Sheet No. 20-1 Cancels I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 20-1 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 36042 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho SCHEDULE 20 SPECULATIVE HIGH-DENSITY LOAD AVAILABILITY Service under this schedule is available at points on the Company's interconnected system within the State of Idaho where existing facilities of adequate capacity and desired phase and voltage are available. If additional distribution facilities are required to supply the desired service, those facilities provided for under Rule H will be provided under the terms and conditions of that rule. To the extent that additional facilities not provided for under Rule H, including transmission and/or substation facilities, are required to provide the requested service, special arrangements will be made in a separate agreement between the Customer and the Company. APPLICABILITY Service under this schedule is applicable to electric service supplied to a Customer at one Point of Delivery and measured through one meter delivered at the primary or transmission service level. This schedule is applicable to Customers whose metered energy usage exceeds 2,000 kWh per Billing Period for a minimum of three Billing Periods during the most recent 12 consecutive Billing Periods. Where the Customer’s Billing Period is less than 27 days or greater than 36 days, the metered energy usage will be prorated to 30 days for purposes of determining eligibility under this schedule. Applicable Speculative High-Density Load Large Power Service Rates are mandatory for Customers who register a metered Demand of 1,000 kW or more per Billing Period for three or more Billing Periods during the most recent 12 consecutive Billing Periods. Customers whose metered Demand per Billing Period has not equaled or exceeded 1,000 kW more than twice during the most recent 12 consecutive Billing Periods will take service under applicable Speculative High-Density Load Large General Service rates. At their expense, Customers may request to establish an additional circuit for building systems independent of the commercial operational load, such as lighting, climate control, among others, at a separate Point of Delivery. This additional circuit will be separately metered and billed under the applicable rate schedule. The Customer will be responsible for the costs associated with installing the second meter. The Company may refuse to provide service at more than one Point of Delivery at the same Premises if it is determined by the Company that the additional Point of Delivery cannot be provided without jeopardizing the safety and reliability of the Company's system or service to the Customer or to other Customers. Service provided to a Customer at multiple Points of Delivery at the same Premises will not be interconnected electrically. This schedule is not applicable to service for resale, to shared or irrigation service, to standby or supplemental service, unless the Customer has entered into a Uniform Standby Service Agreement or other standby agreement with the Company, or to multi-family dwellings. Idaho Power Company Original Sheet No. 20-2 Cancels I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 20-2 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 36042 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho SCHEDULE 20 SPECULATIVE HIGH-DENSITY LOAD (Continued) APPLICABILITY (Continued) Service under this schedule is applicable to and may be mandatory for Customers who have the ability to relocate quickly in response to short-term economic signals and meet four or more of the following criteria:  High energy use density;  High load factor;  Load that is portable and distributable;  Highly variable load growth or load reduction as an individual customer and/or in aggregate with similar customers in the Company’s service area;  High sensitivity to volatile commodity or asset prices;  Part of an industry with potential to quickly become a large concentration of power demand;  Lack of credit history or ability to demonstrate financial viability. If the aggregate power requirement of a Customer who receives service at one or more Points of Delivery on the same Premises exceeds 20,000 kW, the Customer is ineligible for service under this schedule and is required to make special contract arrangements with the Company. Contract Option. Customers for which this schedule is applicable may optionally take service under a mutually agreed upon individual special contract between the Customer and the Company provided the Customer contracts for firm electric Demand of 10,000 kW to 20,000 kW and the special contract terms, conditions, and rates are approved by the Idaho Public Utilities Commission without change or condition. 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. Interconnection Facilities are all facilities which are reasonably required by good practices and the National Electric Safety Code to interconnect the Customer with the capability to remotely interrupt the load at the Point of Delivery. Such improvements include, but are not limited to, reclosers, load control devices, and related equipment. 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 with the capability to remotely interrupt the load at the Point of Delivery. Such improvements include, but are not limited to, additional or larger conductors, transformers, poles, and related equipment. Idaho Power Company Original Sheet No. 20-3 Cancels I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 20-3 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 36042 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho SCHEDULE 20 SPECULATIVE HIGH-DENSITY LOAD (Continued) INTERCONNECTION PROCESS Once a request for new Schedule 20 service is received, Idaho Power will perform a study or studies to determine what Protection Equipment, Interconnection Facilities, and/or Upgrades are necessary to interconnect the Customer’s load to Idaho Power’s system. The customer 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 the Customer, 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. Idaho Power Company Original Sheet No. 20-4 Cancels I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 20-4 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 36042 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho SCHEDULE 20 SPECULATIVE HIGH-DENSITY LOAD (Continued) TYPE OF SERVICE The Type of Service provided under this schedule is three-phase at approximately 60 cycles and at the standard service voltage available at the Premises to be served. BASIC LOAD CAPACITY The Basic Load Capacity is the average of the two greatest monthly Billing Demands established during the 12-month period which includes and ends with the current Billing Period, but not less than 1,000 kW for Large Power Service. BILLING DEMAND The Billing Demand is the average kW supplied during the 15-consecutive-minute period of maximum use during the Billing Period, adjusted for Power Factor, but not less than 1,000 kW for Large Power Service. TIME PERIODS The time periods are defined as follows. All times are stated in Mountain Time. Summer Season On-Peak: 7:00 p.m. to 11:00 p.m. Monday through Saturday, except holidays Mid-Peak: 3:00 p.m. to 7:00 p.m. and 11:00 p.m. to 12:00 a.m. Monday through Saturday, except holidays Off-Peak: 12:00 a.m. to 3:00 p.m. Monday through Saturday and all hours on Sunday and holidays Non-summer Season On-Peak: 6:00 a.m. to 9:00 a.m. and 5:00 p.m. to 8:00 p.m. Monday through Saturday, except holidays Mid-Peak: 9:00 a.m. to 12:00 p.m., 4:00 p.m. to 5:00 p.m., and 8:00 p.m. to 10:00 p.m. Monday through Saturday, except holidays Off-Peak: 12:00 a.m. to 6:00 a.m., 12:00 p.m. to 4:00 p.m., and 10:00 p.m. to 12:00 a.m. Monday through Saturday and all hours on Sunday and holidays The holidays observed by the Company are New Year’s Day (January 1), Memorial Day (last Monday in May), Independence Day (July 4), Labor Day (first Monday in September, Thanksgiving Day (fourth Thursday in November), and Christmas Day (December 25). When If New Year’s Day, Independence Day, or Christmas Day falls on a Sunday, the following Monday immediately following that Sunday will be considered a holiday. Idaho Power Company Original Sheet No. 20-5 Cancels I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 20-5 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 36042 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho SCHEDULE 20 SPECULATIVE HIGH-DENSITY LOAD (Continued) SUMMER AND NON-SUMMER SEASONS The summer season begins on June 1 of each year and ends on September 30 of each year. The non-summer season begins on October 1 of each year and ends on May 31 of each year. FACILITIES BEYOND THE POINT OF DELIVERY Pursuant to Rule B, customers taking Primary or Transmission Service are responsible for providing the transformation of power to the voltage at which it is to be used by the Customer. INTERRUPTION EVENTS At its discretion, Idaho Power may call Interruption Events to remotely disconnect electric service to Customer load under the following parameters:  June 15 through September 15  1:00 p.m. to 11:00 p.m. Monday through Friday, excluding Holidays  Maximum ten (10) hours per interruption event  Up to 225 hours annually Customer will be notified of upcoming Interruption Event not less than two (2) hours prior to event start via phone call, or at the Company’s discretion via an alternative mutually-agreed upon method. POWER FACTOR ADJUSTMENT Where the Customer’s Power Factor is less than 90 percent, as determined by measurement under actual load conditions, the Company may adjust the kW measured to determine the Billing Demand by multiplying the measured kW by 90 percent and dividing by the actual Power Factor. SPECIAL CONDITIONS The provisions of Interruption do not apply for any time period that the Company requests a load reduction during a system emergency or any other time that a Customer’s service is interrupted by events outside the control of the Company. TEMPORARY SUSPENSION When a Customer has properly invoked Rule G, Temporary Suspension of Demand, the Basic Load Capacity and the Billing Demand Shall be prorated based on the period of such suspension in accordance with Rule G. Idaho Power Company Original Sheet No. 20-6 Cancels I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. 20-6 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 36042 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho SCHEDULE 20 SPECULATIVE HIGH-DENSITY LOAD (Continued) MONTHLY CHARGE The Monthly Charge is the sum of the following charges, and may also include charges as set forth in Schedule 91 (Energy Efficiency Rider), and Schedule 95 (Adjustment for Municipal Franchise Fees). Large General Service Rates PRIMARY SERVICE Summer Non-summer Service Charge, per month $340.00 $340.00 Basic Charge, per kW of $1.73 $1.73 Basic Load Capacity Demand Charge, per kW of $8.39 $7.98 Billing Demand Energy Charge, per kWh On-Peak 8.8770¢ 6.4611¢ Mid-Peak 11.5970¢ 8.2028¢ Off-Peak 6.5765¢ 6.9063¢ TRANSMISSION SERVICE Summer Non-summer Service Charge, per month $340.00 $340.00 Basic Charge, per kW of Basic Load Capacity $1.03 $1.03 Demand Charge, per kW of Billing Demand $7.45 $6.59 Energy Charge, per kWh On-Peak 8.8034¢ 6.3629¢ Mid-Peak 11.5234¢ 8.1044¢ Off-Peak 6.4969¢ 6.8077¢ Idaho Power Company Original Sheet No. 20-7 Cancels I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. 20-7 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 36042 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho SCHEDULE 20 SPECULATIVE HIGH-DENSITY LOAD (Continued) MONTHLY CHARGE (Continued) Large Power Service Rates PRIMARY SERVICE Summer Non-summer Service Charge, per month $415.00 $415.00 Basic Charge, per kW of $2.09 $2.09 Basic Load Capacity Demand Charge, per kW of $9.97 $8.64 Billing Demand Energy Charge, per kWh On-Peak 8.6996¢ 6.2790¢ Mid-Peak 11.4196¢ 8.0200¢ Off-Peak 6.4004¢ 6.7229¢ TRANSMISSION SERVICE Summer Non-summer Service Charge, per month $415.00 $415.00 Basic Charge, per kW of Basic Load Capacity $1.76 $1.76 Demand Charge, per kW of Billing Demand $10.11 $8.77 Energy Charge, per kWh On-Peak 8.6829¢ 6.2503¢ Mid-Peak 11.4029¢ 7.9912¢ Off-Peak 6.3808¢ 6.6940¢ PAYMENT The monthly bill for service supplied hereunder is payable upon receipt, and becomes past due 15 days from the date on which rendered. Idaho Power Company Original Sheet No. 20-8 Cancels I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 20-8 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 36042 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho SCHEDULE 20 SPECULATIVE HIGH-DENSITY LOAD (Continued) INTERRUPTION COMPENSATION Fixed Capacity Reduction Rate: Large General Service Rates $0.0333 per kilowatt of reduction per event hour Large Power Service Rates $0.0382 per kilowatt of reduction per event hour DEFINITIONS Actual kW Reduction. The kilowatt (kW) reduction during an Interruption Event, which is the difference between a Participant’s hourly average kW measured at the Facility Site’s meter and the corresponding hour of the Adjusted Baseline kW. Adjusted Baseline kW. The Original Baseline kW plus or minus the “Day of” Load Adjustment amount. “Day of” Load Adjustment. The difference between the Original Baseline kW and the actual metered kW during the hour prior to the Participant receiving notification of an event. Scalar values will be calculated by dividing the Original Baseline kW for each Interruption Event hour by the Baseline kW of the hour preceding the event notification time. The scalars are multiplied by the actual event day kW for the hour preceding the event notification time to create the Adjusted Baseline kW from which load reduction is measured. The Adjusted Baseline kW for each hour will be capped at 120% of the maximum kW amount for any hour from the Highest Energy Use Days or the hours during the event day prior to event notification. Facility Site(s). All of a Participant’s facility or equipment that is metered from a single service location that a Participant has taken service under Schedule 20. Highest Energy Usage Days. The three days out of the immediate past 10 non-event Business Days that have the highest sum total kW as measured across the Interruption Event daily parameters. Interruption Compensation. The Actual kW Reduction for each hour multiplied by the Fixed Capacity Reduction Rate. Participants are paid based on the average event kilowatt reduction. Load Control Device. Refers to any technology, device, or system utilized under Schedule 20 to enable the Company to initiate the Interruption Event. Interruption Event. Refers to an event where the Company requests or calls for interruption of specific loads with the use of one or more Load Control Devices. Original Baseline kW. The arithmetic mean (average) kW of the Highest Energy Usage Days during the Interruption Event daily parameters, calculated for each Facility Site for each hour. Idaho Power Company Original Sheet No. 41-1 Cancels I.P.U.C. No. 30, Tariff No. 101 Third Revised Sheet No. 41-1 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 36042 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho SCHEDULE 41 STREET LIGHTING SERVICE AVAILABILITY Service under this schedule is available throughout the Company's service area within the State of Idaho where street lighting wires and fixtures can be installed on Customer-provided street lighting facilities or installed on the Company's existing distribution facilities. APPLICABILITY Service under this schedule is applicable to service requested or installed by Customers for the lighting of public streets, public alleys, public grounds, and thoroughfares. Street lighting fixtures will be energized each night from dusk until dawn. SERVICE LOCATION AND PERIOD Street lighting facility locations, type of unit and fixture sizes, as changed from time to time by written request of the Customer and agreed to by the Company, shall be provided for Customers receiving service under Option A of this schedule. The in-service date for each street lighting facility shall also be maintained. The minimum service period for any Company-owned street lighting facility is 10 years. The Company, upon written notification from the Customer, will remove a Company-owned street lighting facility: 1. At no cost to the Customer, if such facility has been in service for no less than the minimum service period. The Company will not grant a request from the Customer for reinstallation of street lighting service at the same location for a minimum period of two years from the date of removal. 2. Upon payment to the Company of the removal cost, if such facility has been in service for less than the minimum service period. SERVICE OPTIONS "A" - Idaho Power-Owned, Idaho Power-Maintained System. The facilities required for supplying service, including fixture, lamp, control relay, mast arm for mounting on an existing utility pole, and energy for the operation thereof, are supplied, installed, owned and maintained by the Company. All necessary repairs and maintenance work, including group fixture replacement, will be performed by the Company during the regularly scheduled working hours of the Company on the Company’s schedule. Individual fixtures will be replaced on burnout as soon as reasonably possible after notification by the Customer and subject to the Company's operating schedules and requirements. The Company has light-emitting diode (“LED”) fixture options. For each initial LED lighting fixture installation, the Customer is required to state, in writing, a fixture preference. A maintenance-related replacement of a current LED fixture will be made with a similar type of fixture as the one being replaced unless written notification has been received from the Customer requesting a change in fixture types. Idaho Power Company Original Sheet No. 41-2 Cancels I.P.U.C. No. 30, Tariff No. 101 Tenth Revised Sheet No. 41-2 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 36042 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho SCHEDULE 41 STREET LIGHTING SERVICE (Continued) SERVICE OPTIONS (Continued) "A" - Idaho Power-Owned, Idaho Power-Maintained System (Continued) Company-owned lighting systems installed on or after June 1, 2004 shall not be constructed, operated, or modified in such a way as to allow for the potential or actual variation in energy usage, such as through, but not limited to, the use of wired outlets or useable plug-ins. Company-owned systems installed prior to June 1, 2004 that are constructed, operated, or modified in such a way as to allow for the potential or actual variation in energy usage may have the estimated annual variations in energy usage charged the Non-Metered Service – Variable Energy Charge until the potential for variations in energy usage has been eliminated. Repair, modification or alteration of these facilities is not permitted. Dark Sky Lighting for LED Fixtures In the event a Customer requests the Company perform an alteration of existing LED fixtures to become dark sky lighting compliant by adding a lens shield to the existing fixture, the following charges will apply: 1. The designed cost estimate which includes labor, time, and mileage costs for the alteration of the existing street lighting fixtures. 2. $27.50 per fixture altered for dark sky lighting. The total charges identified in 1 and 2 above must be paid prior to the beginning of the fixture alteration and are non-refundable. The fixture alteration to become dark sky lighting compliant will be performed by the Company during the regularly scheduled working hours of the Company and on the Company’s schedule. LED Shield In the event a Customer requests the Company install a shield on an LED fixture, the Customer will be responsible for the material cost of the equipment, as well as the design cost estimate which includes labor, time, and mileage costs for the alteration of the existing LED fixture. Idaho Power Company Original Sheet No. 41-3 Cancels I.P.U.C. No. 30, Tariff No. 101 Fifteenth Revised Sheet No. 41-3 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 36042 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho SCHEDULE 41 STREET LIGHTING SERVICE (Continued) SERVICE OPTIONS (Continued) "A" - Idaho Power-Owned, Idaho Power-Maintained System (Continued) Monthly Charges The monthly charges are as follows, and may also include charges as set forth in Schedule 55 (Power Cost Adjustment), Schedule 91 (Energy Efficiency Rider), and Schedule 95 (Adjustment for Municipal Franchise Fees). Charges, per fixture (41A) _________________________LED Fixture____________________________ Watt (Maximum) Lumen (Minimum) Base Rate 40 3,600 $11.48 85 7,200 $13.38 140 10,800 $15.34 200 18,000 $19.06 Non-Metered Service – Variable Energy Energy Charge, per kWh 9.377¢ Pole Charges For Company-owned poles installed after October 5,1964 required to be used for street lighting only: Charge Wood pole, per pole $1.81 Steel pole, per pole $7.18 Facilities Charges Customers assessed a monthly facilities charge prior to June 1, 2004 will continue to be assessed a monthly facilities charge in accordance with the charges specified in Schedule 66. Payment The monthly bill rendered for service supplied hereunder is payable upon receipt and becomes past due 15 days from the date on which rendered. "B" – Customer-Owned, Idaho Power-Maintained System – Discontinued Idaho Power Company Original Sheet No. 41-4 Cancels I.P.U.C. No. 30, Tariff No. 101 Fifteenth Revised Sheet No. 41-4 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 36042 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho SCHEDULE 41 STREET LIGHTING SERVICE (Continued) SERVICE OPTIONS (Continued) "C" - Customer-Owned, Customer-Maintained System The Customer's lighting system, including posts or standards, fixtures, initial installation of fixtures and underground cables with suitable terminals for connection to the Company's distribution system, is installed, owned, and maintained by the Customer. The Customer is responsible for notifying the Company of any changes or additions to the lighting equipment or loads being served under Option C – Non-Metered Service. Failure to notify the Company of such changes or additions will result in the termination of non-metered service under Option C and the requirement that service be provided under Option C - Metered Service. All new Customer-owned lighting systems installed outside of Subdivisions on or after January 1, 2012 are required to be metered in order to record actual energy usage. Customer-owned systems installed prior to June 1, 2004 that are constructed, operated, or modified in such a way as to allow for the potential or actual variation in energy usage may have the estimated annual variations in energy usage charged the Non-Metered Service - Energy Charge until the street lighting system is converted to Metered Service, or until the potential for variations in energy usage has been eliminated, whichever is sooner. Monthly Charges The monthly charges are as follows, and may also include charges as set forth in Schedule 55 (Power Cost Adjustment), Schedule 91 (Energy Efficiency Rider), and Schedule 95 (Adjustment for Municipal Franchise Fees). For non-metered service, the average monthly kWh of energy usage shall be estimated by the Company based on the total wattage of the Customer’s lighting system and 4,059 hours of operation. Non-Metered Service (41C) Energy Charge, per kWh 6.339¢ Metered Service (41CM) Service Charge, per meter $5.59 Energy Charge, per kWh 6.339¢ Idaho Power Company Original Sheet No. 54-1 Cancels I.P.U.C. No. 30, Tariff No. 101 Fifth Revised Sheet No. 54-1 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 36042 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho SCHEDULE 54 FIXED COST ADJUSTMENT APPLICABILITY This schedule is applicable to the electric energy delivered to all Idaho retail Customers receiving service under Schedules 1, 3, 4, 5, or 6 (Residential Service) or under Schedules 7 and 8 (Small General Service). Customers added to Idaho Power’s system starting January 1, 2022 will be considered new customers, all other customers are considered existing customers. FIXED COST PER CUSTOMER RATE The Fixed Cost per Customer rate (FCC) is determined by dividing the Company’s fixed cost components for Residential and Small General Service Customers by the average number of Residential and Small General Service customers, respectively. The Fixed Cost per Customer Distribution rate (FCC-Dist) is determined by dividing the Company’s distribution and customer fixed cost components for Residential and Small General Service Customers by the average number of Residential and Small General Service Customers, respectively. Residential FCC FCC-Dist Schedules 1 and 3 $739.20 $287.96 Schedule 5 $739.20 $287.96 Schedule 6 $654.72 $304.20 Small General Service FCC FCC-Dist Schedule 7 $174.96 $24.02 Schedule 8 $221.61 $63.33 FIXED COST PER ENERGY RATE The Fixed Cost per Energy rate (FCE) is determined by dividing the Company’s fixed cost components for Residential and Small General Service customers by the weather-normalized energy load for Residential and Small General Service customers, respectively. The Fixed Cost per Energy Distribution rate (FCE-Dist) is determined by dividing the Company’s distribution and customer fixed cost components for Residential and Small General Service customers by the weather-normalized energy load for Residential and Small General Service customers, respectively. Idaho Power Company Original Sheet No. 54-2 Cancels I.P.U.C. No. 30, Tariff No. 101 Sixteenth Revised Sheet No. 54-2 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 36042 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – January 1, 2024 1221 West Idaho Street, Boise, Idaho SCHEDULE 54 FIXED COST ADJUSTMENT (Continued) FIXED COST PER ENERGY RATE (Continued) Residential FCE FCE-Dist Schedules 1 and 3 6.7098¢ per kWh 2.6138¢ per kWh Schedule 5 – Summer On-Peak 17.5878¢ per kWh 8.3169¢ per kWh Schedule 5 – Mid-Peak 8.7941¢ per kWh 4.1586¢ per kWh Schedule 5 – Summer Off-Peak 4.3970¢ per kWh 2.0792¢ per kWh Schedule 5 – Non-Summer On-Peak 8.5198¢ per kWh 2.9266¢ per kWh Schedule 5 – Non-Summer Off-Peak 5.6798¢ per kWh 1.9511¢ per kWh Schedule 6 7.0780¢ per kWh 3.2886¢ per kWh Small General Service FCE FCE-Dist Schedule 7 3.8463¢ per kWh 0.5282¢ per kWh Schedule 8 5.2308¢ per kWh 1.4949¢ per kWh ALLOWED FIXED COST RECOVERY AMOUNT The Allowed Fixed Cost Recovery amount is computed by summing 1) the product of the average number of existing Residential and Small General Service customers multiplied by the appropriate Residential and Small General Service FCC rate and 2) the product of the average number of new Residential and Small General Service customers multiplied by the appropriate Residential and Small General Service FCC-Dist rate. ACTUAL FIXED COSTS RECOVERED AMOUNT The Actual Fixed Costs Recovered amount is computed by summing 1) the product of the actual energy load for existing Residential and Small General Service customers multiplied by the appropriate Residential and Small General Service FCE rate and 2) the product of the actual energy load for new Residential and Small General Service customers multiplied by the appropriate Residential and Small General Service FCE-Dist rate. FIXED COST ADJUSTMENT The Fixed Cost Adjustment (FCA) is the difference between the Allowed Fixed Cost Recovery Amount and the Actual Fixed Costs Recovered Amount divided by the estimated weather-normalized energy load for the following year for Residential and Small General Service Customers. The monthly Fixed Cost Adjustment for Residential Service (Schedules 1, 3, 4, 5, and 6) is 0.4402 cents per kWh. The monthly Fixed Cost Adjustment for Small General Service (Schedules 7 and 8) is 0.5541 cents per kWh. EXPIRATION The Fixed Cost Adjustment included on this schedule will expire May 31, 2024. Idaho Power Company Original 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. 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 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, 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 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 Interconnection 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 System is an Exporting System or a Non-Exporting System. 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 Original 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. 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) 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. 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 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 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. 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 Original 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. 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 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, 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. 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. 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 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. 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. 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 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 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 Sheet No. 68-7 Cancels I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. 68-7 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) 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. 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 Original 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. 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) 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 that are not completed within one year of the initial Feasibility Review are considered expired. Customers requesting connection or approval of expired applications are required to resubmit a completed application form and $100 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. Idaho Power Company Original 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. 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) SYSTEM MODIFICATIONS (Continued) 2. Customer Generators planning to make system modifications must submit an application, $100 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. 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 schedule within this time period will be subject to termination of service. Idaho Power Company Original 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. 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) 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 The following section is applicable to all DERs with Total Nameplate Capacity less than 3 MVA. APPLICATION PROCESS Customers requesting to interconnect a DER less than 3 MVA are required to complete the following application process prior to interconnection: 1. Customers must submit a completed application form and a $100 application fee to the Company. Applications are available on the Company’s website or will be provided to the Customer upon request. 2. Upon receipt of a completed application and $100 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. 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. 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. Idaho Power Company Original 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. 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 2: INTERCONNECTION PROCESS REQUIREMENTS FOR DISTRIBUTED ENERGY RESOURCES LESS THAN 3 MVA (Continued) APPLICATION PROCESS (Continued) 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 perform the Feasibility Study within 15 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. The Feasibilty Study Agreement includes a deposit of $1,000. a. Installation and funding of the construction, installation, and maintenance of required Protection Equipment will be subject to the following provisions: 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 of 0.59 percent per month times the investment in the Protection Equipment. Idaho Power Company Original 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. 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 2: INTERCONNECTION PROCESS REQUIREMENTS FOR DISTRIBUTED ENERGY RESOURCES LESS THAN 3 MVA (Continued) APPLICATION PROCESS (Continued) 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. 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 installer on the System Verification Form. Idaho Power Company Original 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. 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 2: INTERCONNECTION PROCESS REQUIREMENTS FOR DISTRIBUTED ENERGY RESOURCES LESS THAN 3 MVA (Continued) APPLICATION PROCESS (Continued) 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. Under no circumstances will the rate change occur more than fifteen (15) business days from the date of the 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 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. NON-EXPORT CONTROL SYSTEM 1.Non-Export Systems must incorporate one of the following three options: Idaho Power Company Original 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. 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 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: 1.The Company will notify the Non-Export Customer Generator that their Customer Generator System has exceeded the Inadvertent Export limit. Idaho Power Company Original 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. 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 3: ADDITIONAL INTERCONNECTION REQUIREMENTS OF NON-EXPORTING SYSTEMS (Continued) UNAUTHORIZED INADVERTENT EXPORT (Continued) 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 Sheet No. 68-16 Cancels I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. 68-16 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 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 Sheet No. 68-17 Cancels I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. 68-17 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) 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 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. 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) 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 of 0.59 percent 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 Sheet No. 68-19 Cancels I.P.U.C. No. 30, Tariff No. 101 First Revised 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) 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 Sheet No. 68-20 Cancels I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. 68-20 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) 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 Original Sheet No. 68-21 Cancels I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. 68-21 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) 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 Sheet No. 68-22 Cancels I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. 68-22 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) 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 Sheet No. 68-23 Cancels I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. 68-23 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) 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 Sheet No. 68-24 Cancels I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. 68-24 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) 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 Sheet No. 68-25 Cancels I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. 68-25 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) 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 Sheet No. 68-26 Cancels I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. 68-26 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) 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 Idaho Power Company Original Sheet No. 68-27 Cancels I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. 68-27 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) 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 Sheet No. 68-28 Cancels I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. 68-28 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) IDAHO POWER COMPANY UNIFORM CUSTOMER GENERATOR INTERCONNECTION AGREEMENT (Continued) 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 Original Sheet No. 84-1 Cancels I.P.U.C. No. 30, Tariff No. 101 Sixth Revised Sheet No. 84-1 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 84 LARGE GENERAL, LARGE POWER, AND IRRIGATION ON-SITE GENERATION SERVICE AVAILABILITY Service under this schedule is available throughout the Company’s service area within the State of Idaho for Customers intending to operate Exporting Systems to generate electricity to reduce all or part of their monthly energy usage. Effective June 1, 2018, Schedule 84 is closed to service for Idaho residential and Idaho small general service customers. Effective December 2, 2020, Schedule 84 is closed to new applications with a two-meter interconnection and for Net Energy Metering. APPLICABILITY Service under this schedule is applicable to any Customer that: 1. Does not take service under, Schedule 5, Schedule 6, or Schedule 8; and 2. Owns and/or operates a Generation Facility fueled by solar, wind, biomass, geothermal, or hydropower, or represents fuel cell technology; and 3. Maintains its retail electric service account as active and in good standing; and 4. Meets all requirements applicable to Exporting Systems detailed in the Company’s Schedule 68, Interconnections to Customer Distributed Energy Resources; and 5. Takes retail electric service under: a. Schedule 1 or Schedule 7; and Owns and/or operates a Generation Facility with a total nameplate capacity rating of 25 kilowatts (kW) or smaller that is interconnected to the Customer’s individual electric system on the Customer’s side of the Point of Delivery, thus all energy received and delivered by the Company is through a single meter. The capacity of an Energy Storage Device shall not be used to calculate the capacity limits in this schedule. b. Schedule 9, Schedule 19, or Schedule 24; and i. Two Meter Interconnection (Closed to new applicants effective December 2, 2020): Owns and/or operates a Generation Facility with a total nameplate capacity rating of 100 kW or smaller that is interconnected at a Generation Interconnection Point that, at the Company’s discretion, is located either adjacent to or on the Customer’s side of the Point of Delivery and is metered through a meter that is separate from the retail load metering at the Customer’s Point of Delivery. A separate meter from the existing retail load metering at the Customer’s Point of Delivery is not required if the Customer meets the criteria below. The capacity of an Energy Storage Device shall not be used to calculate the capacity limits in this schedule. Idaho Power Company Original Sheet No. 84-2 Cancels I.P.U.C. No. 30, Tariff No. 101 Fifth Revised Sheet No. 84-2 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 84 LARGE GENERAL, LARGE POWER, AND IRRIGATION ON-SITE GENERATION SERVICE (Continued) APPLICABILITY (Continued) ii. Single-Meter Interconnection (applicable to new applicants effective December 2, 2020): Owns and/or operates a Generation Facility interconnected to the Customer’s individual electric system on the Customer’s side of the Point of Delivery, thus all energy received and delivered by the Company is through a single meter. The Generation Facility must have a total nameplate rating equal to or less than the greater of: (a) the greatest monthly Billing Demand established during the most recent 12-month period at the time of applying for interconnection, which includes and ends with the current most recent Billing Period, or (b) 100 kW. The capacity of an Energy Storage Device shall not be used to calculate the capacity limits in this schedule. 6. For a Customer applying to interconnect a Generation Facility (1) with a total nameplate capacity rating that exceeds actual billing demand data from the most recent 12 months, or (2) Billing Demand is not available, must provide evidence that the proposed Generation Facility meets the applicability of this schedule in accordance with the following: i. If previous billing data is available for the premises and the Customer’s electrical needs are similar to the previous customer, the Company, at its discretion, may rely on available historical Billing Demand at the premises not to exceed the previous 12 months. ii. If the Customer has another account in the Company’s service area with similar electrical needs, the Company, at its discretion, may rely on available historical Billing Demand from that account not to exceed the previous 12 months. iii. The Customer can have a third-party professional engineer provide analysis and documentation detailing the electrical load requirements for the Customer which support an increase in demand expected to occur within the next 12 months. iv. For a Customer taking retail service under Schedule 24 which only services motor load, the Customer may submit documentation of the horsepower (“HP”) of the motor/pump to the Company and a conversion factor of 1 HP to 0.8kW will be used to define the demand for the Point of Delivery. 6.7. Legacy Status for eligible Exporting Systems will terminate on December 1, 2045. 78. The Legacy Status of the Exporting System is transferable to a subsequent Customer at the premises for which a valid on-site generation service is in effect. Each Customer of a Legacy System taking service under Schedule 84 will be responsible for complying with the terms and conditions of the on-site generation service in effect for that premises. 89. A Legacy System that is offline for over six (6) months or that is moved to a different site shall forfeit Legacy Status of the Exporting System. Idaho Power Company Original Sheet No. 84-43 Cancels I.P.U.C. No. 30, Tariff No. 101 Fourth Revised Sheet No. 84-34 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 84 LARGE GENERAL, LARGE POWER, AND IRRIGATION ON-SITE GENERATION SERVICE (Continued) APPLICABILITY (Continued) 910. To remain eligible for Legacy Status, a Customer may increase the capacity of a Legacy System by no more than 10 percent of the originally installed nameplate capacity, or 1 kW, whichever is greater, to allow for the replacement of broken or degraded components. If a Customer expands a Legacy System beyond these limits, the new portion of the DER would not qualify for Legacy Status. 1011. A Customer that modifies a two-meter Generation Facility to a single-meter forfeits the Legacy Status of the Generation Facility. DEFINITIONS Billing Demand is the average kW supplied during the 15-consecutive-minute period of maximum use during the Billing Period, adjusted for Power Factor. Designated Meter is the retail meter physically connected to the Exporting System. 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. Excess Net Energy means the positive difference between the kilowatt-hours (kWh) generated by a Customer and the kWh supplied by the Company over the applicable Billing Period. Exported Energy means all kWh generated by a Customer in excess of the Customer’s on-site consumption that is exported to the Company’s system. 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. An Exporting System is interconnected to the Company’s system under the applicable terms of Schedule 68. Generation Facility means all equipment used to generate electric energy where the resulting energy is either delivered to the Company via a single meter at the Point of Delivery or Generation Interconnection Point, or is consumed by the Customer. Generation Interconnection Point is the point where the conductors installed to allow receipt of the Customer’s generation connect to the Company’s facilities adjacent to the Customer’s Point of Delivery. Interconnection Facilities are all facilities reasonably required by Prudent Electrical Practices and the applicable electric and safety codes to interconnect and safely deliver energy from the DER to the Point of Delivery or Generation Interconnection Point. Idaho Power Company Original Sheet No. 84-43 Cancels I.P.U.C. No. 30, Tariff No. 101 Fourth Revised Sheet No. 84-34 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 Legacy Status refers to the ability for a system to receive Net Energy Metering, including net monthly one-for-one kWh credit compensation for Excess Net Energy. Legacy Systems means any system that meets the applicable criteria as described in Order Nos. 34509, 34546, 34854 and 34892. Net Billing is the compensation structure applicable to all systems that do not meet the criteria of a Legacy System. Net Billing will be effective with each eligible customer’s first billing cycle after January 1, 2024. Net Energy Metering is the compensation structure applicable to all Legacy Systems. Idaho Power Company Original Sheet No. 84-4 Cancels I.P.U.C. No. 30, Tariff No. 101 Fourth Revised Sheet No. 84-4 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 84 LARGE GENERAL, LARGE POWER, AND IRRIGATION ON-SITE GENERATION SERVICE (Continued) DEFINITIONS (Continued) Legacy Status refers to the ability for a system to receive Net Energy Metering, including net monthly one-for-one kWh credit compensation for Excess Net Energy. Legacy Systems means any system that meets the applicable criteria as described in Order Nos. 34509, 34546, 34854 and 34892. Net Billing is the compensation structure applicable to all systems that do not meet the criteria of a Legacy System. Net Billing will be effective with each eligible customer’s first billing cycle after January 1, 2024. Net Energy Metering is the compensation structure applicable to all Legacy Systems. Parallel connection means generating electricity from an on-site generation system that is connected to and receives voltage from Idaho Power’s system. Point of Delivery is the retail metering point where the Company's and the Customer’s electrical facilities are interconnected to allow the Customer to take retail electric service from the Company. Prudent Electrical Practices are those practices, methods and equipment that are commonly used in prudent electrical engineering and operations to operate electric equipment lawfully and with safety, dependability, efficiency and economy. Schedule 68 is the Company’s service schedule which provides for interconnection to DERs or its successor schedule(s) as approved by the Commission. MONTHLY BILLING The Customer shall be billed in accordance with the Customer’s applicable standard service schedule, including appropriate monthly charges, and the Export Credit Rate under this schedule. NET ENERGY METERING - CONDITIONS OF PURCHASE AND SALE The conditions listed below shall apply to all transactions for Net Energy Metering under this schedule. 1. Balances of generation and usage by the Customer: a. If electricity supplied by the Company during the Billing Period exceeds the electricity generated by the Customer and delivered to the Company during the Billing Period, the Customer shall be billed for the net electricity supplied by the Company at the Customer’s standard schedule retail rate, in accordance with normal metering practices. Idaho Power Company Original Sheet No. 84-4 Cancels I.P.U.C. No. 30, Tariff No. 101 Fourth Revised Sheet No. 84-4 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 b. If electricity generated by the Customer and delivered to the Company during the Billing Period exceeds the electricity supplied by the Company during the Billing Period, the Excess Net Energy shall be carried forward as a kWh credit to offset energy usage in a subsequent Billing Period. Excess Net Energy credits are subject to the following provisions: i. Credits can only be used to offset billed kWh consumption. Customers shall be billed for all applicable non-energy charges for the Billing Period according to the applicable standard service schedule. ii. Credits shall carry forward provided the Customer maintains electric service at the same Point of Delivery. iii. Credits are non-transferrable in the event that a Customer relocates and/or discontinues service at the Point of Delivery associated with the Exporting System. Any unused credits will expire at the time the final bill is prepared. Idaho Power Company Original Sheet No. 84-5 Cancels I.P.U.C. No. 30, Tariff No. 101 Second Revised Sheet No. 84-5 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 84 LARGE GENERAL, LARGE POWER, AND IRRIGATION ON-SITE GENERATION SERVICE (Continued) NET ENERGY METERING - CONDITIONS OF PURCHASE AND SALE (Continued) b. If electricity generated by the Customer and delivered to the Company during the Billing Period exceeds the electricity supplied by the Company during the Billing Period, the Excess Net Energy shall be carried forward as a kWh credit to offset energy usage in a subsequent Billing Period. Excess Net Energy credits are subject to the following provisions: i. Credits can only be used to offset billed kWh consumption. Customers shall be billed for all applicable non-energy charges for the Billing Period according to the applicable standard service schedule. ii. Credits shall carry forward provided the Customer maintains electric service at the same Point of Delivery. iii. Credits are non-transferrable in the event that a Customer relocates and/or discontinues service at the Point of Delivery associated with the Exporting System. Any unused credits will expire at the time the final bill is prepared. 2. Aggregation of meters for the annual transfer of unused Excess Net Energy credits: a. If a balance of Excess Net Energy credits exists at a Designated Meter, the Customer may request to transfer the unused credits to offset energy consumption at eligible meters. A meter is eligible for aggregation if it meets all of the following criteria: i. The account subject to offset is held by the Customer; and ii. The meter is located on, or contiguous to, the property on which the Designated Meter is located. For the purposes of this tariff, contiguous property includes property that is separated from the Premises of the Designated Meter by public or railroad rights of way; and iii. The meter is served by the same primary feeder as the Designated Meter at the time the Customer files the application for the Exporting System; and iv. The electricity recorded by the meter is for the Customer’s requirements; and v. For Customers taking service under Schedule 1 or Schedule 7, credits may only be transferred to meters taking service under Schedule 1 or Schedule 7. For Customers taking service under Schedule 9, Schedule 19, or Schedule 24, credits may only be transferred to meters taking service under Schedule 9, Schedule 19, or Schedule 24. b. Customers may submit requests to transfer Excess Net Energy credits between December 1 and January 31 of each year. All requests must be received by Idaho Power by Idaho Power Company Original Sheet No. 84-5 Cancels I.P.U.C. No. 30, Tariff No. 101 Second Revised Sheet No. 84-5 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 midnight, Mountain Standard Time, on January 31. If a Customer does not request to transfer Excess Net Energy credits by the January 31 submission deadline Excess Net Energy credits will carry forward to offset consumption at the Designated Meter until they become eligible the following year. c. Requests to transfer Excess Net Energy credits must be executed by the Company no later than March 31. Transfers will be based on the balance of Excess Net Energy credits available at the time the transfer is made. d. If multiple meters are eligible for aggregation, Excess Net Energy credits must first be applied to the Designated Meter, then to eligible meters on rate schedules in accordance with Section 2a(v) above. e. A meter aggregation fee of $10.00 will be assessed per aggregated meter per annual transfer transaction. Idaho Power Company Original Sheet No. 84-6 Cancels I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. 84-6 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 84 LARGE GENERAL, LARGE POWER, AND IRRIGATION ON-SITE GENERATION SERVICE (Continued) NET ENERGY METERING - CONDITIONS OF PURCHASE AND SALE (Continued) b. Customers may submit requests to transfer Excess Net Energy credits between December 1 and January 31 of each year. All requests must be received by Idaho Power by midnight, Mountain Standard Time, on January 31. If a Customer does not request to transfer Excess Net Energy credits by the January 31 submission deadline Excess Net Energy credits will carry forward to offset consumption at the Designated Meter until they become eligible the following year. c. Requests to transfer Excess Net Energy credits must be executed by the Company no later than March 31. Transfers will be based on the balance of Excess Net Energy credits available at the time the transfer is made. d. If multiple meters are eligible for aggregation, Excess Net Energy credits must first be applied to the Designated Meter, then to eligible meters on rate schedules in accordance with Section 2a(v) above. e. A meter aggregation fee of $10.00 will be assessed per aggregated meter per annual transfer transaction. NET BILLING – CONDITIONS OF PURCHASE AND SALE The conditions listed below shall apply to transactions for Net Billing under this schedule. 1. Balances of usage and exports by the Customer. a. The Customer shall be billed for the electricity supplied by the Company at the rates contained within the Customer’s applicable standard service schedule, in accordance with normal metering practices. b. The Customer shall be credited for Exported Energy at the applicable Export Credit Rate contained within this schedule as a credit in dollars to only offset Monthly Charges. Exported Energy credits are subject to the following provisions: i. Credits shall carry forward provided the Customer maintains electric service at the same Point of Delivery. ii. Credits are non-transferrable in the event that a Customer relocates. If the establishment of service at the new Point of Delivery is not initiated at the time service at the Designated Meter is discontinued, it is the Customer’s responsibility to request the credit transfer when service is established at the new location in Idaho Power’s service area. 2. Aggregation of meters for the annual transfer of unused credits: Idaho Power Company Original Sheet No. 84-6 Cancels I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. 84-6 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 a. If a balance of credits exists at a Designated Meter, the Customer may request to transfer the unused credits to eligible meters. A meter is eligible for aggregation if it meets the following criteria: i. The account subject to offset is held by the Customer; and ii. The electricity recorded by the meter is for the Customer’s requirements. b. Customers may submit requests to transfer a stated percentage of available credits between December 1 and January 31 of each year. All requests must be received by Idaho Power by midnight, Mountain Standard Time, on January 31. If a Customer does not request to transfer credits by the January 31 submission deadline credits will carry forward at the Designated Meter until they become eligible for transfer the following year. c. Requests to transfer credits must be executed by the Company no later than March 31. Transfers will be based on the balance of credits available at the time the transfer is made. d. A meter aggregation fee of $10.00 will be assessed per aggregated meter per annual transfer transaction. Idaho Power Company I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 84-7 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 84 LARGE GENERAL, LARGE POWER, AND IRRIGATION ON-SITE GENERATION SERVICE (Continued) NET BILLING – CONDITIONS OF PURCHASE AND SALE (Continued) iii. If a Customer and/or discontinues service at the Point of Delivery associated with the Exporting System and does not intend to establish service at another location in Idaho Power’s service area .Aany unused credits will be paid out following expire at the time the final bill is prepared. 2. Aggregation of meters for the annual transfer of unused credits: a. If a balance of credits exists at a Designated Meter, the Customer may request to transfer the unused credits to eligible meters. A meter is eligible for aggregation if it meets the following criteria: i. The account subject to offset is held by the Customer; and ii. The electricity recorded by the meter is for the Customer’s requirements. b. Customers may submit requests to transfer a stated percentage of available credits between December 1 and January 31 of each year. All requests must be received by Idaho Power by midnight, Mountain Standard Time, on January 31. If a Customer does not request to transfer credits by the January 31 submission deadline credits will carry forward at the Designated Meter until they become eligible for transfer the following year. c. Requests to transfer credits must be executed by the Company no later than March 31. Transfers will be based on the balance of credits available at the time the transfer is made. d. A meter aggregation fee of $10.00 will be assessed per aggregated meter per annual transfer transaction. NET ENERGY METERING & NET BILLING – GENERAL CONDITIONS 1. The Customer shall never deliver or attempt to deliver energy to the Company’s system when the Company’s system serving the Customer’s DER is de-energized for any reason. 2. The Company shall not be liable directly or indirectly for permitting or continuing to allow an attachment of a Exporting System to the Company’s system, or for the acts or omissions of the Customer that cause loss or injury, including death, to any third party. 3. The Customer is responsible for all costs associated with the DER and Interconnection Facilities. The Customer is also responsible for all costs associated with any Company additions, modifications, or upgrades to any Company facilities that the Company determines are necessary as a result of the installation of the DER in order to maintain a safe, reliable electrical system. 4. The Company shall not be obligated to accept, and the Company may require the Customer to curtail, interrupt or reduce deliveries of energy if the Company, consistent with Prudent Idaho Power Company I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 84-7 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 Electrical Practices, determines that curtailment, interruption or reduction is necessary because of line construction or maintenance requirements, emergencies, or other critical operating conditions on its system. 5. If the Company is required by the Commission to institute curtailment of deliveries of electricity to its customers, the Company may require the Customer to curtail its consumption of electricity in the same manner and to the same degree as other Customers on the Company’s standard service schedules. 6. The Customer shall grant to the Company all access to all Company equipment and facilities including adequate and continuing access rights to the property of the Customer for the purpose of installation, operation, maintenance, replacement or any other service required of said equipment, as well as all necessary access for inspection, switching and any other operational requirements of the Customer’s Interconnection Facilities. 7. The Customer shall notify the Company immediately if an Exporting System is permanently removed or disabled. Permanent removal or disablement for the purposes of this schedule is any removal or disablement of an Exporting System lasting longer than six (6) months. Customers with permanently removed systems will be removed from service under this schedule and placed on the appropriate standard service schedule. Idaho Power Company I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 84-8 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 84 LARGE GENERAL, LARGE POWER, AND IRRIGATION ON-SITE GENERATION SERVICE (Continued) NET ENERGY METERING & NET BILLING – GENERAL CONDITIONS (Continued) 4. The Company shall not be obligated to accept, and the Company may require the Customer to curtail, interrupt or reduce deliveries of energy if the Company, consistent with Prudent Electrical Practices, determines that curtailment, interruption or reduction is necessary because of line construction or maintenance requirements, emergencies, or other critical operating conditions on its system. 5. If the Company is required by the Commission to institute curtailment of deliveries of electricity to its customers, the Company may require the Customer to curtail its consumption of electricity in the same manner and to the same degree as other Customers on the Company’s standard service schedules. 6. The Customer shall grant to the Company all access to all Company equipment and facilities including adequate and continuing access rights to the property of the Customer for the purpose of installation, operation, maintenance, replacement or any other service required of said equipment, as well as all necessary access for inspection, switching and any other operational requirements of the Customer’s Interconnection Facilities. 7. The Customer shall notify the Company immediately if an Exporting System is permanently removed or disabled. Permanent removal or disablement for the purposes of this schedule is any removal or disablement of an Exporting System lasting longer than six (6) months. Customers with permanently removed systems will be removed from service under this schedule and placed on the appropriate standard service schedule. SUMMER AND NON-SUMMER SEASONS The summer season begins on June 1 of each year and ends on September 30 of each year. The non-summer season begins on October 1 of each year and ends on May 31 of each year. TIME PERIODS The time periods for the Export Credit Rate are defined as follows. All times are stated in Mountain Time. Summer Season On-Peak: 3:00 p.m. to 11:00 p.m. Monday through Saturday, except holidays Off-Peak: 11:00 p.m. to 3:00 p.m. Monday through Saturday and all hours on Sunday and holidays Non-summer Season Off-Peak: All hours Monday through Sunday Holidays are New Year's Day (January 1), Memorial Day (last Monday in May), Independence Day (July 4), Labor Day (first Monday in September), Thanksgiving Day (fourth Thursday in November), Idaho Power Company I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 84-8 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 and Christmas Day (December 25). If New Year’s Day, Independence Day, or Christmas Day falls on Saturday, the preceding Friday will be designated a holiday. If New Year’s Day, Independence Day, or Christmas Day falls on Sunday, the following Monday will be designated a holiday. Idaho Power Company I.P.U.C. No. 30, Tariff No. 101 Original Sheet No. 84-89 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 84 LARGE GENERAL, LARGE POWER, AND IRRIGATION ON-SITE GENERATION SERVICE (Continued) TIME PERIODSSUMMER AND NON-SUMMER SEASONS The summer season begins on June 1 of each year and ends on September 30 of each year. The non-summer season begins on October 1 of each year and ends on May 31 of each year. TIME PERIODS – EXPORT CREDIT RATE The time periods for the Export Credit Rate are defined as follows. All times are stated in Mountain Time. Summer Season On-Peak: 3:00 p.m. to 11:00 p.m. Monday through Saturday, except holidays Off-Peak: 11:00 p.m. to 3:00 p.m. Monday through Saturday and all hours on Sunday and holidays Non-summer Season Off-Peak: All hours Monday through Sunday Holidays are New Year's Day (January 1), Memorial Day (last Monday in May), Independence Day (July 4), Labor Day (first Monday in September), Thanksgiving Day (fourth Thursday in November), and Christmas Day (December 25). If New Year’s Day, Independence Day, or Christmas Day falls on Saturday, the preceding Friday will be designated a holiday. If New Year’s Day, Independence Day, or Christmas Day falls on Sunday, the following Monday will be designated a holiday. EXPORT CREDIT RATE The following rate structure and credits are subject to change upon Commission approval: Summer Non-summer Export Credit Rate, per kWh On-Peak: TBD16.9966¢ TBD 4.8365¢ Off-Peak: TBD5.6533¢ TBD 4.8365¢