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HomeMy WebLinkAbout20210323Final Approved Tariffs.pdf LISA D. NORDSTROM Lead Counsel lnordstrom@idahopower.com March 17, 2021 VIA ELECTRONIC FILING Jan Noriyuki, Secretary Idaho Public Utilities Commission 11331 W. Chinden Blvd., Bldg 8, Suite 201-A (83714) PO Box 83720 Boise, Idaho 83720-0074 Re: Case No. IPC-E-20-30 In the Matter of Idaho Power Company’s Application for Authority to Establish Tariff Schedule 68, Interconnections to Customer Distributed Energy Resources – REPLACEMENT Compliance Filing Dear Ms. Noriyuki: Pursuant to Order No. 34955, Idaho Power Company (“Idaho Power” or “Company”) provides tariff sheets for approval with an effective date of March 23, 2021.  Schedule 6, Residential Service On-Site Generation  Schedule 8, Small General Service On-Site Generation  Schedule 68, Interconnections to Customer Distributed Energy Resources  Schedule 72, Generator Interconnections to PURPA Qualifying Facility Sellers  Schedule 84, Customer Energy Production Net Metering Service On March 9, 2021, the Idaho Public Utilities Commission issued Order No. 34955 approving the Company’s application effective 14 days from the date of the order. On Friday, March 12, 2021, Company filed tariff sheets replacing what was initially filed with the Company's application on June 20, 2020, and supplemental application on August 13, 2020. However, after the Company’s initial compliance filing, Staff contacted the Company to point out a few minor grammatical errors that were inadvertently included on pages 6-2 and 72-2. The Company is submitting the enclosed filing as a replacement to what was filed on March 12, 2021. If you have any questions regarding this filing, please contact Regulatory Analyst Grant Anderson at (208) 388-6498 or ganderson@idahopower.com. Very truly yours, Lisa D. Nordstrom LDN:slb Enclosures RECEIVED 2021 March 17, PM 12:59 IDAHO PUBLIC UTILITIES COMMISSION (CLEAN FORMAT) Idaho Power Company First Revised Sheet No. 6-1 Cancels I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 6-1 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – March 23, 2021 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. 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. 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. 6. Customer meets all applicable requirements detailed in the Company’s Schedule 68, Interconnections to Customer Distributed Energy Resources. DEFINITIONS Designated Meter is the retail meter physically connected to the Exporting System. IDAHO PUBLIC UTILITIES COMMISSION Approved Effective March 23, 2021 March 23, 2021 Per ON 34955 Jan Noriyuki Secretary Idaho Power Company First Revised Sheet No. 6-2 Cancels I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 6-2 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 6 RESIDENTIAL SERVICE ON-SITE GENERATION (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 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. 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. 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 Generation Facility to the Point of Delivery. 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 customer generation 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 PUBLIC UTILITIES COMMISSION Approved Effective March 23, 2021 March 23, 2021 Per ON 34955 Jan Noriyuki Secretary Idaho Power Company First Revised Sheet No. 6-4 Cancels I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 6-4 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 6 RESIDENTIAL SERVICE ON-SITE GENERATION (Continued) CONDITIONS OF PURCHASE AND SALE (Continued) 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 at the end of the Customer’s December Billing Period 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. b. Customers may submit requests to transfer Excess Net Energy credits between January 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 on January 1 of the following year. IDAHO PUBLIC UTILITIES COMMISSION Approved Effective March 23, 2021 March 23, 2021 Per ON 34955 Jan Noriyuki Secretary Idaho Power Company First Revised Sheet No. 6-5 Cancels I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 6-5 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 6 RESIDENTIAL SERVICE ON-SITE GENERATION (Continued) CONDITIONS OF PURCHASE AND SALE (Continued) 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 the same rate schedule as the Designated Meter. Remaining Excess Net Energy credits may then be applied to offset consumption at eligible meters on differing 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. 3. The Customer shall never deliver or attempt to deliver energy to the Company’s system when the Company’s system serving the Customer’s Generation Facility is de-energized for any reason. 4. 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. 5. The Customer is responsible for all costs associated with the Generation Facility 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 Generation Facility in order to maintain a safe, reliable electrical system. 6. 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. 7. 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. 8. 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 PUBLIC UTILITIES COMMISSION Approved Effective March 23, 2021 March 23, 2021 Per ON 34955 Jan Noriyuki Secretary Idaho Power Company Fourth Revised Sheet No. 6-6 Cancels I.P.U.C. No. 29, Tariff No. 101 Third Revised Sheet No. 6-6 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 6 RESIDENTIAL SERVICE ON-SITE GENERATION (Continued) CONDITIONS OF PURCHASE AND SALE (Continued) 9. 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 August 31 of each year. The non- summer season begins on September 1 of each year and ends on May 31 of each year. 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), and Schedule 98 (Residential and Small Farm Energy Credit). The following rate structure and charges are subject to change upon Commission approval: Summer Non-summer Service Charge, per month $5.00 $5.00 Energy Charge, per kWh First 800 kWh 8.5005¢ 7.8984¢ 801-2000 kWh 10.2214¢ 8.7077¢ All Additional kWh Over 2000 12.1424¢ 9.6437¢ 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 PUBLIC UTILITIES COMMISSION Approved Effective March 23, 2021 March 23, 2021 Per ON 34955 Jan Noriyuki Secretary Idaho Power Company Second Revised Sheet No. 8-1 Cancels I.P.U.C. No. 29, Tariff No. 101 First Revised Sheet No. 8-1 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – March 23, 2021 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. APPLICABILITY Effective until a final order is issued that addresses metering configuration for Schedule 84 customers, and any appeal period has passed or the order has been upheld on appeal, existing Schedule 8 customers who no longer meet the energy usage requirement of Schedule 8 that ‘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[,]’ can elect Schedule 8. 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. 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 PUBLIC UTILITIES COMMISSION Approved Effective March 23, 2021 March 23, 2021 Per ON 34955 Jan Noriyuki Secretary Idaho Power Company First Revised Sheet No. 8-2 Cancels I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 8-2 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 8 SMALL GENERAL SERVICE ON-SITE GENERATION (Continued) 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. 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 Generation Facility to the Point of Delivery. 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 customer generation 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. IDAHO PUBLIC UTILITIES COMMISSION Approved Effective March 23, 2021 March 23, 2021 Per ON 34955 Jan Noriyuki Secretary Idaho Power Company First Revised Sheet No. 8-3 Cancels I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 8-3 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 8 SMALL GENERAL SERVICE ON-SITE GENERATION (Continued) CONDITIONS OF PURCHASE AND SALE The conditions listed below shall apply to all transactions 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 at the end of the Customer’s December Billing Period 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 IDAHO PUBLIC UTILITIES COMMISSION Approved Effective March 23, 2021 March 23, 2021 Per ON 34955 Jan Noriyuki Secretary Idaho Power Company First Revised Sheet No. 8-4 Cancels I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 8-4 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 8 SMALL GENERAL SERVICE ON-SITE GENERATION (Continued) CONDITIONS OF PURCHASE AND SALE (Continued) 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 January 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 on January 1 of 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 the same rate schedule as the Designated Meter. Remaining Excess Net Energy credits may then be applied to offset consumption at eligible meters on differing 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. 3. The Customer shall never deliver or attempt to deliver energy to the Company’s system when the Company’s system serving the Customer’s Generation Facility is de-energized for any reason. 4. 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. 5. The Customer is responsible for all costs associated with the Generation Facility 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 Generation Facility in order to maintain a safe, reliable electrical system. 6. 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. IDAHO PUBLIC UTILITIES COMMISSION Approved Effective March 23, 2021 March 23, 2021 Per ON 34955 Jan Noriyuki Secretary Idaho Power Company Fourth Revised Sheet No. 8-5 Cancels I.P.U.C. No. 29, Tariff No. 101 Third Revised Sheet No. 8-5 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 8 SMALL GENERAL SERVICE ON-SITE GENERATION (Continued) CONDITIONS OF PURCHASE AND SALE (Continued) 7. 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. 8. 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. 9. 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 August 31 of each year. The non- summer season begins on September 1 of each year and ends on May 31 of each year. 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), and Schedule 98 (Residential and Small Farm Energy Credit). The following charges are subject to change upon Commission approval: Summer Non-summer Service Charge, per month $5.00 $5.00 Energy Charge, per kWh First 300 kWh 9.6908¢ 9.6908¢ All Additional kWh 11.5418¢ 10.1676¢ 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 PUBLIC UTILITIES COMMISSION Approved Effective March 23, 2021 March 23, 2021 Per ON 34955 Jan Noriyuki Secretary Idaho Power Company I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 68-1 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – March 23, 2021 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. Non- Exporting Systems 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. 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 PUBLIC UTILITIES COMMISSION Approved Effective March 23, 2021 March 23, 2021 Per ON 34955 Jan Noriyuki Secretary Idaho Power Company I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 68-2 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – March 23, 2021 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 PUBLIC UTILITIES COMMISSION Approved Effective March 23, 2021 March 23, 2021 Per ON 34955 Jan Noriyuki Secretary Idaho Power Company I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 68-3 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – March 23, 2021 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 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 PUBLIC UTILITIES COMMISSION Approved Effective March 23, 2021 March 23, 2021 Per ON 34955 Jan Noriyuki Secretary Idaho Power Company I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 68-4 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – March 23, 2021 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, 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 PUBLIC UTILITIES COMMISSION Approved Effective March 23, 2021 March 23, 2021 Per ON 34955 Jan Noriyuki Secretary Idaho Power Company I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 68-5 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – March 23, 2021 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” 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. 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. 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 Generation Facility are deemed by the Company to be in default or delinquent. IDAHO PUBLIC UTILITIES COMMISSION Approved Effective March 23, 2021 March 23, 2021 Per ON 34955 Jan Noriyuki Secretary Idaho Power Company I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 68-6 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 68 INTERCONNECTIONS TO CUSTOMER DISTRIBUTED ENERGY RESOURCES (Continued) SECTION 1: GENERAL INTERCONNECTION REQUIREMENTS (Continued) DISCONNECTION EQUIPMENT (Continued) 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 Customer Generator Systems less than 3 MVA are described further in Section 2 of this tariff. Disconnection provisions specific to Non-Exporting Systems greater than 3 MVA are described further in Section 4 of this tariff. 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, 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. INVERTER REQUIREMENTS All inverter-based Customer Generator Systems must use a Smart Inverter programmed with the required settings described in the following section. IDAHO PUBLIC UTILITIES COMMISSION Approved Effective March 23, 2021 March 23, 2021 Per ON 34955 Jan Noriyuki Secretary Idaho Power Company I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 68-7 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 68 INTERCONNECTIONS TO CUSTOMER DISTRIBUTED ENERGY RESOURCES (Continued) SECTION 1: GENERAL INTERCONNECTION REQUIREMENTS (Continued) 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. Table 1: VOLTAGE-REACTIVE POWER SETTINGS FOR SMART INVERTERS Voltage-reactive power parameters Default Settings V1 0.92 per unit of nominal voltage Q1 44% of nameplate apparent power rating, injecting V2 0.98 per unit of nominal voltage Q2 0 V3 1.03 per unit of nominal voltage Q3 0 V4 1.06 per unit of nominal voltage Q4 44% of nameplate apparent power rating, absorption Open-loop response time 5 seconds ENERGY STORAGE DEVICE Energy Storage Devices may share an inverter with a Generation Facility (“DC Coupled”), or Energy Storage Devices may have a stand-alone inverter (“AC Coupled”). Energy Storage Devices that are not coupled with a Generation Facility taking service under Schedules 6, 8, or 84 may not export energy onto Idaho Power’s system. The Total Nameplate Capacity is determined as follows: 1. DC Coupled: For Energy Storage Devices that are DC Coupled with a Generation Facility, the Total Nameplate Capacity of the Customer Generator System is defined by the inverter (kVA). A DC coupled system can be an Exporting or Non-Exporting system. 2. AC Coupled: i. AC Coupled with an Exporting System: For an Energy Storage Device coupled with an Exporting System taking service under Schedules 6, 8, or 84, the Total Nameplate Capacity is the aggregate Total Nameplate Capacity of all DERs on the Customer’s side of the Interconnection Point. ii. AC Coupled with a Non-Exporting System: An Energy Storage Device coupled with a Non-Exporting System is subject to the provisions of Section 3 of this Schedule. The Total Nameplate Capacity of the Energy Storage Device shall be considered 0 kVA. IDAHO PUBLIC UTILITIES COMMISSION Approved Effective March 23, 2021 March 23, 2021 Per ON 34955 Jan Noriyuki Secretary Idaho Power Company I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 68-8 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 68 INTERCONNECTIONS TO CUSTOMER DISTRIBUTED ENERGY RESOURCES (Continued) SECTION 1: GENERAL INTERCONNECTION REQUIREMENTS (Continued) 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 tariff. 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. IDAHO PUBLIC UTILITIES COMMISSION Approved Effective March 23, 2021 March 23, 2021 Per ON 34955 Jan Noriyuki Secretary Idaho Power Company I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 68-9 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – March 23, 2021 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 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. 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. IDAHO PUBLIC UTILITIES COMMISSION Approved Effective March 23, 2021 March 23, 2021 Per ON 34955 Jan Noriyuki Secretary Idaho Power Company I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 68-10 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – March 23, 2021 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 The following section is applicable to all Customer Generators 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 provide the Customer with a written or electronic notification that the application has been received and all necessary information has been provided. 3. The Company will perform within seven (7) business days, unless it is determined that additional studies are necessary, the Feasibility Review based on 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. 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. IDAHO PUBLIC UTILITIES COMMISSION Approved Effective March 23, 2021 March 23, 2021 Per ON 34955 Jan Noriyuki Secretary Idaho Power Company I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 68-11 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – March 23, 2021 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) 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. 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. 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. IDAHO PUBLIC UTILITIES COMMISSION Approved Effective March 23, 2021 March 23, 2021 Per ON 34955 Jan Noriyuki Secretary Idaho Power Company I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 68-12 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – March 23, 2021 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) 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. h. Verification of Total Nameplate Capacity. 7. A return trip charge of $61.00 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. 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 written notice from the Customer indicating Customer’s Generation System meets all applicable federal, state, and local requirements and is suitable for connection. IDAHO PUBLIC UTILITIES COMMISSION Approved Effective March 23, 2021 March 23, 2021 Per ON 34955 Jan Noriyuki Secretary Idaho Power Company I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 68-13 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 68 INTERCONNECTIONS TO CUSTOMER DISTRIBUTED ENERGY RESOURCES (Continued) 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. NON-EXPORT CONTROL SYSTEM 1. Non-Export Systems must incorporate one of the following three options: a. Option 1: (“Advanced Functionality”): The use of an internal transfer relay, Energy Management System, or other customer facility hardware or software system(s) may be used to ensure power is never exported across the Interconnection Point. To ensure that Inadvertent Export of power is limited to acceptable levels, all of the following conditions must be met: (a) inverter-based DERs must utilize a Smart Inverter; (b) the DER must monitor the total Inadvertent Export; (c) the DER must disconnect from the Company’s distribution system or halt energy production within two seconds after the period of continuous Inadvertent Export exceeds 30 seconds; (d) the DER must enter a safe operating mode where Inadvertent Export will not occur as a result of a failure of the control or Smart Inverter system for more than 30 seconds, which results in loss of control signal, loss of control power or single component failure or related control sensing of the control circuitry. b. Option 2: (“Reverse Power Protection”): To ensure power is never exported, a reverse power relay protective function must be implemented at the Interconnection Point. The default setting for this Protection Equipment, when used, shall be 0.1% (export) of the DERs Total Nameplate Capacity, with a maximum 2.0 second time delay. 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. IDAHO PUBLIC UTILITIES COMMISSION Approved Effective March 23, 2021 March 23, 2021 Per ON 34955 Jan Noriyuki Secretary Idaho Power Company I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 68-14 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – March 23, 2021 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 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. 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 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 PUBLIC UTILITIES COMMISSION Approved Effective March 23, 2021 March 23, 2021 Per ON 34955 Jan Noriyuki Secretary Idaho Power Company I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 68-15 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 68 INTERCONNECTIONS TO CUSTOMER DISTRIBUTED ENERGY RESOURCES (Continued) SECTION 4: ADDITIONAL INTERCONNECTION REQUIREMENTS OF NON-EXPORTING SYSTEMS 3 MVA OR GREATER In addition to Section 1 and 3, the following section is applicable to all Customers requesting interconnection of Non-Exporting Systems 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 festimated 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 PUBLIC UTILITIES COMMISSION Approved Effective March 23, 2021 March 23, 2021 Per ON 34955 Jan Noriyuki Secretary Idaho Power Company I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 68-16 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 68 INTERCONNECTIONS TO CUSTOMER DISTRIBUTED ENERGY RESOURCES (Continued) SECTION 4: ADDITIONAL INTERCONNECTION REQUIREMENTS OF NON-EXPORTING SYSTEMS 3 MVA OR GREATER (Continued) CUSTOMER GENERATOR INTERCONNECTION PROCESS (Continued) c. The Facility Study: The Facility Study includes the engineering to determine the design specifications of the project. The Facility Study Agreement includes a deposit of 5% of the total project costs that were determined in the System Impact Study Report (“SISR”) or the Feasibility Study Report if a SISR is not required, capped at $30,000. At the end of each stage of the three-step study process, the Company will provide the Customer Generator with an increasingly more refined and detailed report that, among other things, will present a list of required Interconnection Facilities and a non-binding, good faith estimate of Customer Generator’s cost responsibility for the Interconnection Facilities. If long-lead-time equipment items need to be ordered to meet Customer Generator’s construction schedule, the Company will request advance funding by the Customer Generator to cover these equipment costs. 5. Customer Generator Interconnection Agreement. The Customer Generator Interconnection Agreement (“CGIA”), will be offered to the Customer Generator following completion of the Study Phase. The CGIA will utilize the Uniform Customer Generator Interconnection Agreement template included in this schedule. INTERCONNECTION FACILITIES REQUIREMENTS DER greater than 3 MVA Total Nameplate Capacity will require additional Company-Furnished Protection, Metering, and communications Equipment. This equipment will be further defined in the CGIA Attachment 1. IDAHO PUBLIC UTILITIES COMMISSION Approved Effective March 23, 2021 March 23, 2021 Per ON 34955 Jan Noriyuki Secretary Idaho Power Company I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 68-17 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 68 INTERCONNECTIONS TO CUSTOMER DISTRIBUTED ENERGY RESOURCES (Continued) SECTION 4: ADDITIONAL INTERCONNECTION REQUIREMENTS OF NON-EXPORTING SYSTEMS 3 MVA OR GREATER (Continued) COST OF INTERCONNECTION FACILITIES The Customer Generator will pay all costs of interconnecting a Generation Facility 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. 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 PUBLIC UTILITIES COMMISSION Approved Effective March 23, 2021 March 23, 2021 Per ON 34955 Jan Noriyuki Secretary Idaho Power Company I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 68-18 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 68 INTERCONNECTIONS TO CUSTOMER DISTRIBUTED ENERGY RESOURCES (Continued) SECTION 4: ADDITIONAL INTERCONNECTION REQUIREMENTS OF NON-EXPORTING SYSTEMS 3 MVA OR GREATER (Continued) 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. 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. IDAHO PUBLIC UTILITIES COMMISSION Approved Effective March 23, 2021 March 23, 2021 Per ON 34955 Jan Noriyuki Secretary Idaho Power Company I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 68-19 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 68 INTERCONNECTIONS TO CUSTOMER DISTRIBUTED ENERGY RESOURCES (Continued) SECTION 4: ADDITIONAL INTERCONNECTION REQUIREMENTS OF NON-EXPORTING SYSTEMS 3 MVA OR GREATER (Continued) IDAHO POWER COMPANY UNIFORM CUSTOMER GENERATOR INTERCONNECTION AGREEMENT (Continued) AGREEMENT (Continued) 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. 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. IDAHO PUBLIC UTILITIES COMMISSION Approved Effective March 23, 2021 March 23, 2021 Per ON 34955 Jan Noriyuki Secretary Idaho Power Company I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 68-20 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 68 INTERCONNECTIONS TO CUSTOMER DISTRIBUTED ENERGY RESOURCES (Continued) SECTION 4: ADDITIONAL INTERCONNECTION REQUIREMENTS OF NON-EXPORTING SYSTEMS 3 MVA OR GREATER (Continued) IDAHO POWER COMPANY UNIFORM CUSTOMER GENERATOR INTERCONNECTION AGREEMENT (Continued) AGREEMENT (Continued) 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. 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. IDAHO PUBLIC UTILITIES COMMISSION Approved Effective March 23, 2021 March 23, 2021 Per ON 34955 Jan Noriyuki Secretary Idaho Power Company I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 68-21 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 68 INTERCONNECTIONS TO CUSTOMER DISTRIBUTED ENERGY RESOURCES (Continued) SECTION 4: ADDITIONAL INTERCONNECTION REQUIREMENTS OF NON-EXPORTING SYSTEMS 3 MVA OR GREATER (Continued) IDAHO POWER COMPANY UNIFORM CUSTOMER GENERATOR INTERCONNECTION AGREEMENT (Continued) AGREEMENT (Continued) 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. 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. IDAHO PUBLIC UTILITIES COMMISSION Approved Effective March 23, 2021 March 23, 2021 Per ON 34955 Jan Noriyuki Secretary Idaho Power Company I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 68-22 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 68 INTERCONNECTIONS TO CUSTOMER DISTRIBUTED ENERGY RESOURCES (Continued) SECTION 4: ADDITIONAL INTERCONNECTION REQUIREMENTS OF NON-EXPORTING SYSTEMS 3 MVA OR GREATER (Continued) IDAHO POWER COMPANY UNIFORM CUSTOMER GENERATOR INTERCONNECTION AGREEMENT (Continued) AGREEMENT (Continued) 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. 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: IDAHO PUBLIC UTILITIES COMMISSION Approved Effective March 23, 2021 March 23, 2021 Per ON 34955 Jan Noriyuki Secretary Idaho Power Company I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 68-23 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 68 INTERCONNECTIONS TO CUSTOMER DISTRIBUTED ENERGY RESOURCES (Continued) SECTION 4: ADDITIONAL INTERCONNECTION REQUIREMENTS OF NON-EXPORTING SYSTEMS 3 MVA OR GREATER (Continued) IDAHO POWER COMPANY UNIFORM CUSTOMER GENERATOR INTERCONNECTION AGREEMENT (Continued) AGREEMENT (Continued) 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. 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. IDAHO PUBLIC UTILITIES COMMISSION Approved Effective March 23, 2021 March 23, 2021 Per ON 34955 Jan Noriyuki Secretary Idaho Power Company I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 68-24 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 68 INTERCONNECTIONS TO CUSTOMER DISTRIBUTED ENERGY RESOURCES (Continued) SECTION 4: ADDITIONAL INTERCONNECTION REQUIREMENTS OF NON-EXPORTING SYSTEMS 3 MVA OR GREATER (Continued) IDAHO POWER COMPANY UNIFORM CUSTOMER GENERATOR INTERCONNECTION AGREEMENT (Continued) AGREEMENT (Continued) 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 PUBLIC UTILITIES COMMISSION Approved Effective March 23, 2021 March 23, 2021 Per ON 34955 Jan Noriyuki Secretary Idaho Power Company I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 68-25 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 68 INTERCONNECTIONS TO CUSTOMER DISTRIBUTED ENERGY RESOURCES (Continued) SECTION 4: ADDITIONAL INTERCONNECTION REQUIREMENTS OF NON-EXPORTING SYSTEMS 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 PUBLIC UTILITIES COMMISSION Approved Effective March 23, 2021 March 23, 2021 Per ON 34955 Jan Noriyuki Secretary Idaho Power Company I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 68-26 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 68 INTERCONNECTIONS TO CUSTOMER DISTRIBUTED ENERGY RESOURCES (Continued) SECTION 4: ADDITIONAL INTERCONNECTION REQUIREMENTS OF NON-EXPORTING SYSTEMS 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 PUBLIC UTILITIES COMMISSION Approved Effective March 23, 2021 March 23, 2021 Per ON 34955 Jan Noriyuki Secretary Idaho Power Company I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 68-27 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 68 INTERCONNECTIONS TO CUSTOMER DISTRIBUTED ENERGY RESOURCES (Continued) SECTION 4: ADDITIONAL INTERCONNECTION REQUIREMENTS OF NON-EXPORTING SYSTEMS 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 PUBLIC UTILITIES COMMISSION Approved Effective March 23, 2021 March 23, 2021 Per ON 34955 Jan Noriyuki Secretary Idaho Power Company I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 68-28 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 68 INTERCONNECTIONS TO CUSTOMER DISTRIBUTED ENERGY RESOURCES (Continued) SECTION 4: ADDITIONAL INTERCONNECTION REQUIREMENTS OF NON-EXPORTING SYSTEMS 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 PUBLIC UTILITIES COMMISSION Approved Effective March 23, 2021 March 23, 2021 Per ON 34955 Jan Noriyuki Secretary Idaho Power Company Fourth Revised Sheet No. 72-1 Cancels I.P.U.C. No. 29, Tariff No. 101 Third Revised Sheet No. 72-1 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 72 GENERATOR INTERCONNECTIONS TO PURPA QUALIFYING FACILITY SELLERS AVAILABILITY Service under this schedule is available throughout the Company's service area within the State of Idaho to Sellers owning or operating Qualifying Facilities that sign a Uniform Interconnection Agreement. The interconnection procedures and requirements for customer-owned generation facilities, including those that qualify for Schedule 6, Schedule 8, Schedule 84 or non-export customer generation are governed by Schedule 68. APPLICABILITY Service under this schedule applies to the construction, operation, maintenance, Upgrade, Relocation, or removal of transmission and/or distribution lines and equipment necessary to safely interconnect a Seller's Generation Facility to the Company's system. DEFINITIONS Additional Applicant is a person or entity whose request for electrical connection requires the Company to utilize existing Interconnection Facilities which are subject to a Vested Interest. Company is the Idaho Power Company. Connected Load is the combined input rating of the Customer's motors and other energy consuming devices. Construction Cost is the cost, as determined by the Company, of Upgrades, Relocation or construction of Company furnished Interconnection Facilities. 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 Seller to the Company's system, including enclosures or other equipment as may be required to ensure that only the Company will have access to certain of the devices. First Energy Date is the date when the Seller begins delivering energy to the Company's system. Generation Facility means equipment used to produce electric energy at a specific physical location which meets the requirements to be a Qualifying Facility. Generator Interconnection Process is the Company’s Generation Facility interconnection application, engineering review and construction process. The intent of the Generator Interconnection Process is to ensure a safe and reliable generation interconnection in compliance with all applicable regulatory requirements, good utility practices and national safety standards. Interconnection Facilities are all facilities which are reasonably required by good utility practices and the National Electric Safety Code to interconnect and to allow the delivery of energy from the Seller's Generation Facility to the Company's system, including, but not limited to, Special Facilities, Disconnection Equipment and Metering Equipment. IDAHO PUBLIC UTILITIES COMMISSION Approved Effective March 23, 2021 March 23, 2021 Per ON 34955 Jan Noriyuki Secretary Idaho Power Company Fourth Revised Sheet No. 72-2 Cancels I.P.U.C. No. 29, Tariff No. 101 Third Revised Sheet No. 72-2 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 72 GENERATOR INTERCONNECTIONS TO PURPA QUALIFYING FACILITY SELLERS (Continued) DEFINITIONS (Continued) Interconnection Point is the point where the Seller’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 Seller's Generation Facility and the Company's system. OATT is the Company’s Federal Energy Regulatory Commission (FERC) approved Open Access Transmission Tariff. Protection Equipment is the circuit-interrupting device, protective relaying, and associated instrument transformers. PURPA means the Public Utility Regulatory Policies Act of 1978. Qualifying Facility is a cogeneration facility or a small power production facility which meets the PURPA criteria for qualification set forth in Subpart B of Part 292, Subchapter K, Chapter I, Title 18, of the Code of Federal Regulations. Relocation is a change in the location of existing Company-owned transmission and/or distribution lines, poles or equipment. Seller is a non-utility generator who has contracted or will contract with the Company to interconnect a Generation Facility to the Company’s system to sell electric energy to the Company. Seller-Furnished Facilities are those portions of the Interconnection Facilities provided by the Seller. 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 Seller's Generation Facility to the Company's system. Transfer Cost is the cost, as determined by the Company, for acceptance by the Company of Seller-Furnished Facilities. Upgrades are those improvements to the Company's existing system which are reasonably required by good practices and the National Electric Safety Code to safely interconnect the Seller’s Generation Facility. Such improvements include, but are not limited to, additional or larger conductors, transformers, poles, and related equipment. Vested Interest is the claim for refund that a Seller or Additional Applicant holds in a specific portion of Company-owned Interconnection Facilities. The Vested Interest expires 5 years from the date the Company completes construction of its portion of the Interconnection Facilities unless fully refunded earlier. IDAHO PUBLIC UTILITIES COMMISSION Approved Effective March 23, 2021 March 23, 2021 Per ON 34955 Jan Noriyuki Secretary Idaho Power Company Fourth Revised Sheet No. 72-3 Cancels I.P.U.C. No. 29, Tariff No. 101 Third Revised Sheet No. 72-3 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 72 GENERATOR INTERCONNECTIONS TO PURPA QUALIFYING FACILITY SELLERS (Continued) SECTION 1: GENERAL INTERCONNECTION REQUIREMENTS The following provisions apply to all Sellers requesting interconnection to the Company’s system. CONSTRUCTION AND OPERATION OF INTERCONNECTION FACILITIES All Seller-Furnished Interconnection Facilities will be constructed and maintained in a manner to be in full compliance with all good utility practices, National Electric Safety Code, and all other applicable federal, state, and local safety and electrical codes and standards at all times. The Seller shall: 1. Submit proof to the Company that all licenses, permits, inspections, and approvals necessary for the construction and operation of the Seller's Generation and Interconnection Facilities under this schedule have been obtained from applicable federal, state, or local authorities. 2. Submit the designs, plans, specifications, and performance data for the Generation Facility and Seller-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 Generation Facility or Seller-Furnished Facilities. The Company will retain the right to inspect this equipment at its discretion. 3. Demonstrate to the Company's satisfaction that the Seller's Generation Facility and Seller- Furnished Facilities have been completed, and that all features and equipment of the Seller’s Generation Facility and Seller-Furnished Facilities are capable of operating safely to commence deliveries of Energy into the Company's system. 4. Provide and maintain adequate protective equipment sufficient to prevent damage to the Generation Facility, Seller-Furnished Facilities and any other Seller-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. 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 Seller of such arrangements in advance. The Company will provide a telephone number to the Seller so that the Seller can obtain information about Company activity impacting the Seller’s facility. IDAHO PUBLIC UTILITIES COMMISSION Approved Effective March 23, 2021 March 23, 2021 Per ON 34955 Jan Noriyuki Secretary Idaho Power Company Fourth Revised Sheet No. 72-4 Cancels I.P.U.C. No. 29, Tariff No. 101 Third Revised Sheet No. 72-4 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 72 GENERATOR INTERCONNECTIONS TO PURPA QUALIFYING FACILITY SELLERS (Continued) SECTION 1: GENERAL INTERCONNECTION REQUIREMENTS (Continued) DISCONNECTION EQUIPMENT Disconnection Equipment is required for all Seller Generation Facilities. The Disconnection Equipment shall be installed at an electrical location to allow complete isolation of Seller’s Generation and Interconnection Facilities from the Company’s system. The Disconnection Equipment’s operating device shall be: 1. Readily accessible by the Company at all times. 2. Clearly marked “Generation Disconnect Switch” with permanent 3/8 inch or larger letters. 3. Physically installed at a location within 10 feet of the Interconnection Point or exact, permanent instructions posted at the Interconnection Point indicating the precise location of the Disconnection Equipment’s operating device. 4. Of a design manually operated and lockable in the open position with a standard Company padlock. Operation of Disconnection Equipment. If, in the reasonable opinion of the Company, the Seller's operation or maintenance of the Generation Facility or Interconnection Facilities is unsafe or may otherwise adversely affect the Company's equipment, personnel, or service to its customers, the Company may physically disconnect the Seller’s Generation Facility or Interconnection Facilities by operation of the disconnection device or by any other means the Company deems necessary to adequately disconnect the Seller’s Generation 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 Seller’s Generation and Interconnection Facilities in the event of any planned or unplanned maintenance or repair of the Company’s system connected to the Seller’s Generation 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 Seller of the time and duration of the planned outage. The Company will disconnect the Seller’s Generation Facility and Interconnection Facilities in the event that any terms and conditions of any applicable Company tariff or contract enabling the interconnection of the Seller’s Generation Facility is deemed by the Company to be in default or delinquent. All expenses of disconnection and reconnection incurred by the Company will be billed to the Seller. IDAHO PUBLIC UTILITIES COMMISSION Approved Effective March 23, 2021 March 23, 2021 Per ON 34955 Jan Noriyuki Secretary Idaho Power Company Fourth Revised Sheet No. 72-5 Cancels I.P.U.C. No. 29, Tariff No. 101 Third Revised Sheet No. 72-5 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 72 GENERATOR INTERCONNECTIONS TO PURPA QUALIFYING FACILITY SELLERS (Continued) SECTION 1: GENERAL INTERCONNECTION REQUIREMENTS (Continued) DISCONNECTION EQUIPMENT (Continued) The Company will establish the settings of Protection Equipment to disconnect the Seller’s Generation Facility and Interconnection Facilities for the protection of the Company’s system and personnel consistent with good utility practices. If the Seller 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 Seller’s Generation and Interconnection Facilities to the Company’s system. GENERAL REQUIREMENTS OF INTERCONNECTED PROJECTS 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 Seller’s Generation Facility and/or Interconnection Facilities designating the existence of the Seller’s Generation Facility as required by good utility practices. 3. The Seller will be required to submit all specific designs, equipment specifications, and test results of the Seller-Furnished Facilities to the Company for review. 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. OPERATIONS AND MAINTENANCE OBLIGATIONS AND EXPENSES The Company will operate and maintain Company furnished Interconnection Facilities, as well as any Seller-Furnished Facilities transferred to the Company. SECTION 2: INTERCONNECTION OF GENERATION FACILITIES The following section is applicable to all Sellers requesting interconnection of non-utility generation. SPECIFIC PROJECT REQUIREMENTS 1. Generation Facilities Less than 1 MW Nameplate Rating The following requirements are for Generation Facilities with nameplate ratings of less than 1 MW. IDAHO PUBLIC UTILITIES COMMISSION Approved Effective March 23, 2021 March 23, 2021 Per ON 34955 Jan Noriyuki Secretary Idaho Power Company Fourth Revised Sheet No. 72-6 Cancels I.P.U.C. No. 29, Tariff No. 101 Third Revised Sheet No. 72-6 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 72 GENERATOR INTERCONNECTIONS TO PURPA QUALIFYING FACILITY SELLERS (Continued) SECTION 2: INTERCONNECTION OF GENERATION FACILITIES (Continued) SPECIFIC PROJECT REQUIREMENTS (Continued) a. The Company shall procure, install, own and maintain Metering Equipment to record energy deliveries to the Company. This metering will be separate from any other metering of the Seller’s load and may be located on either side of the Interconnection Point. All acquisition, installation, maintenance, inspection and testing costs related to Meter Equipment installed to measure the Seller’s energy deliveries to the Company shall be borne by the Seller. b. The Seller is responsible for all costs incurred by the Company for the review, evaluation and testing of Seller supplied designs and equipment regardless as to the outcome of the review or test results. c. The Seller, upon completion of installation and prior to interconnection of the Generation Facility to the Company’s system, will provide the Company with certification from a professional engineer licensed in the State of Idaho stating that the Seller’s Generation Facility and Interconnection Facilities are in compliance with IEEE Standard 1547 and all applicable electrical and safety codes to enable safe and reliable operation. d. The Seller will obtain and provide to the Company an annual certification and testing by a professional engineer licensed in the State of Idaho, certifying the ongoing compliance with IEEE Standard 1547 and all applicable electrical and safety codes and that the Seller-Furnished Facilities successfully meet applicable testing requirements and standards. In the event the Company does not receive and accept the annual certification within thirty (30) days of the annual anniversary date of the agreement, the project will be disconnected from the Company’s system until such time as the certification is completed and accepted by the Company. e. In addition to the requirements specified in sections a through d, Generation Facilities that are greater than 100 kW and less than 1 MW total nameplate rating require the following: i. If the Company owns the transformer interconnecting the Seller’s Generation Facility, then the Seller may own and maintain a secondary voltage disconnection device that can be operated by both the Seller and the Company. ii. If the Seller owns the transformer interconnecting the Seller’s Generation Facility, then the Company will own, operate and maintain a primary voltage disconnection device at the Seller’s expense. iii. The Company will construct, own, operate and maintain all protective relays and any associated equipment required to operate the protective relays. 2. Generation Facilities Greater Than 1 MW Nameplate Rating The Company will own, maintain and operate all Interconnection Facilities and Disconnection Equipment at the Seller’s expense. IDAHO PUBLIC UTILITIES COMMISSION Approved Effective March 23, 2021 March 23, 2021 Per ON 34955 Jan Noriyuki Secretary Idaho Power Company Fourth Revised Sheet No. 72-7 Cancels I.P.U.C. No. 29, Tariff No. 101 Third Revised Sheet No. 72-7 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 72 GENERATOR INTERCONNECTIONS TO PURPA QUALIFYING FACILITY SELLERS (Continued) SECTION 2: INTERCONNECTION OF GENERATION FACILITIES (Continued) GENERATOR INTERCONNECTION PROCESS 1. Seller 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 Seller, 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 Generator Interconnection Process. 3. The deposit amounts for Generation Facilities up to 30 MW are specified in this schedule. Deposit amounts for Generation Facilities 30 MW and larger are covered by the FERC-approved Large Generator Interconnection Procedures posted on the Company’s website. 4. Application. The Seller will submit a completed interconnection application in the form posted on the Company’s website. The application form includes a general description of the Generation Facility 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 for a Generation Facility up to 30 MW. 5. Study Agreements. If the Seller desires to proceed beyond the Application stage, the Seller will be offered a series of study agreements. The individual study agreements establish the time to perform the study and the deposit the Seller is to provide prior to commencement of the study. The deposit amount may be waived if a Seller meets the Company’s credit worthiness standards for unsecured credit specified in Attachment L to the Company’s OATT. The studies consist of: a. The Feasibility Study: The Feasibility Study includes a general review of project impact, e.g. exceeding equipment capabilities and violation of electrical performance requirements. The Feasibility Study Agreement states that no deposit is required, since the deposit is covered by the application fee. b. The System Impact Study: The System Impact Study provides a detailed assessment of the distribution and/or transmission system adequacy to accommodate the Generation Facility 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 PUBLIC UTILITIES COMMISSION Approved Effective March 23, 2021 March 23, 2021 Per ON 34955 Jan Noriyuki Secretary Idaho Power Company Fourth Revised Sheet No. 72-8 Cancels I.P.U.C. No. 29, Tariff No. 101 Third Revised Sheet No. 72-8 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 72 GENERATOR INTERCONNECTIONS TO PURPA QUALIFYING FACILITY SELLERS (Continued) SECTION 2: INTERCONNECTION OF GENERATION FACILITIES (Continued) GENERATOR INTERCONNECTION PROCESS (Continued) c. The Facility Study: The Facility Study includes the engineering to determine the design specifications of the project. The Facility Study Agreement includes a deposit of 5% of the total project costs that were determined in the System Impact Study Report (“SISR”) or the Feasibility Study Report if a SISR is not required, capped at $30,000. At the end of each stage of the three-step study process, the Company will provide the Seller 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 Seller’s cost responsibility for the Interconnection Facilities. If long-lead time equipment items need to be ordered to meet Seller’s construction schedule, the Company will request advance funding by the Seller to cover these equipment costs. 6. Generator Interconnection Agreement. The Generator Interconnection Agreement (“GIA”), will be offered to Seller following completion of the Facility Study. The GIA will utilize the Uniform Interconnection Agreement template included in this schedule. COST OF INTERCONNECTION FACILITIES All Interconnection Facilities provided under this schedule will be valued at the Company's Construction Cost and/or the Transfer Cost for vesting purposes, as well as for operation and maintenance payment obligations. PAYMENT FOR INTERCONNECTION FACILITIES Unless specifically agreed otherwise by written agreement between the Seller and the Company, the Seller will pay all costs of interconnecting a Generation Facility to the Company's system. Costs of interconnection include the costs of furnishing and constructing required Interconnection Facilities, including Upgrades. Each request for interconnection will go through the Generator Interconnection Process. Throughout the Generator Interconnection Process, the Company will periodically bill the Seller for costs incurred or obligated. Failure to pay an invoice within the time specified in the invoice will result in suspension of work on the interconnection and if the suspension of work extends beyond thirty (30) calendar days, the Generation Facility will be removed from the interconnection queue. Seller can end the Generator Interconnection Process at any time. If Seller decides to end the 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 Seller for costs incurred prior to cancellation. IDAHO PUBLIC UTILITIES COMMISSION Approved Effective March 23, 2021 March 23, 2021 Per ON 34955 Jan Noriyuki Secretary Idaho Power Company Fourth Revised Sheet No. 72-9 Cancels I.P.U.C. No. 29, Tariff No. 101 Third Revised Sheet No. 72-9 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 72 GENERATOR INTERCONNECTIONS TO PURPA QUALIFYING FACILITY SELLERS (Continued) SECTION 2: INTERCONNECTION OF GENERATION FACILITIES (Continued) SECURITY FOR PAYMENT OF INTERCONNECTION COSTS Sellers will provide adequate security for payment of the costs of the Generator Interconnection Process. Adequate security for Generation Facilities larger than 30 MW can be provided in accordance with the Large Generator Interconnection Procedures contained in Attachment M to the Company’s OATT. Adequate security for Generation Facilities up to 30 MW can be provided in one of the following ways 1. Sellers that meet the Company’s credit worthiness standards for unsecured credit are not required to provide additional security. The Company’s minimum credit standards for unsecured credit are described in Attachment L to the OATT. 2. Sellers that do not meet the credit worthiness standards for unsecured credit will be notified of the reason for the determination and shall be given the option to provide alternative security acceptable to Idaho Power. In lieu of providing a cash deposit, Seller may establish an escrow account, provide a letter of credit or provide guarantee of payment by another person or entity which meets the credit worthiness standards for unsecured credit. Arrangements for alternative security must be acceptable to Idaho Power. TRANSFER OF INTERCONNECTION FACILITIES Transfer of Interconnection Facilities is available only for Generation Facilities with nameplate ratings greater than 100 kW. 1. Transfer at First Energy Date. If the Seller desires to transfer and the Company desires to accept any Seller-Furnished Facilities at the First Energy Date, the following will apply: a. Prior to the beginning of construction, the Seller shall cause the contractor that is constructing the Seller-Furnished Facilities to provide the Company with a certificate naming the Company as an additional insured in the amount of not less than $1,000,000 under the contractor's general liability policy. b. The Company will provide the Seller's contractor with construction and material specifications and will have final approval of the design of the Seller-Furnished Facilities. c. During construction and upon completion, the Company will inspect the Seller- Furnished Facilities to be transferred to the Company. The cost of such inspection will be borne by the Seller. IDAHO PUBLIC UTILITIES COMMISSION Approved Effective March 23, 2021 March 23, 2021 Per ON 34955 Jan Noriyuki Secretary Idaho Power Company Fourth Revised Sheet No. 72-10 Cancels I.P.U.C. No. 29, Tariff No. 101 Third Revised Sheet No. 72-10 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 72 GENERATOR INTERCONNECTIONS TO PURPA QUALIFYING FACILITY SELLERS (Continued) SECTION 2: INTERCONNECTION OF GENERATION FACILITIES (Continued) TRANSFER OF INTERCONNECTION FACILITIES (Continued) d. If the Seller-Furnished Facilities meet the Company's design, material and construction specifications, are free from defects in materials and workmanship, and the Seller has provided the Company with acceptable easements, bills of sale and assurance against labor or materials liens, the Company will accept ownership effective as of the First Energy Date. In the bill of sale, the Seller will warrant to the Company that the Seller-Furnished Facilities are free of any liens or encumbrances and will be free from any defects in materials and workmanship for a period of one year from the First Energy Date. 2. Subsequent Transfer. If, after the First Energy Date, the Seller desires to transfer and the Company desires to accept any Seller-Furnished Facilities, the following will apply: a. The Company will inspect the facilities proposed for sale to determine if they meet the Company's design, material and construction specifications. b. The Company will determine the Transfer Cost of such facilities. The Transfer Cost will be equal to the depreciated Construction Cost the Company would have incurred if it had originally constructed the facilities plus the cost, if any, of bringing the facilities into compliance with the Company's design, material and construction specifications. Depreciation of the facilities proposed for transfer will be determined on the same basis as the Company depreciates its own facilities in accordance with the appropriate FERC account numbers for the type and size of line or equipment involved. The time period used for the calculation of the depreciated transfer cost will extend from the First Energy Date until the agreed upon transfer date. The Transfer Cost will be paid to the Company in cash at the time of transfer. At the same time, the Company will pay the Seller in cash an amount equal to the depreciated Construction Cost. c. As a condition of the Company's acceptance, the Seller will provide the Company with acceptable easements, bills of sale and acceptable assurance against labor and material liens. The bill of sale will include a warranty that the transferred facilities are free of all liens and encumbrances and will be free from any defects in materials and workmanship for a period of one year from the date of transfer. d. Effective as of the date of the transfer, the Company will operate and maintain the transferred facilities. VESTED INTEREST A Seller's eligibility for a Vested Interest refund will exist for 5 years after the date the Company completes construction of its portion of the Interconnection Facilities. IDAHO PUBLIC UTILITIES COMMISSION Approved Effective March 23, 2021 March 23, 2021 Per ON 34955 Jan Noriyuki Secretary Idaho Power Company Fourth Revised Sheet No. 72-11 Cancels I.P.U.C. No. 29, Tariff No. 101 Third Revised Sheet No. 72-11 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 72 GENERATOR INTERCONNECTIONS TO PURPA QUALIFYING FACILITY SELLERS (Continued) SECTION 2: INTERCONNECTION OF GENERATION FACILITIES (Continued) VESTED INTEREST (Continued) 1. The Company will provide a refund payment to each Seller holding a Vested Interest in Company-owned Interconnection Facilities when an Additional Applicant shares use of those Interconnection Facilities. 2. The refund payment will be based on the following formula: Linear Connected Original Refund = Footage x Load/Peak Generation x Interconnection Ratio Ratio Cost a. The Linear Footage Ratio is the length of jointly used Special Facilities divided by the length of the vested Special Facilities. b. The Connected Load/Peak Generation Ratio is the Connected Load or Peak Generation of the Additional Applicant divided by the sum of the Connected Load or Peak Generation of the Additional Applicant and all other Connected Loads and/or Peak Generation on the Special Facilities. c. The Original Interconnection Cost is the sum of the Company's Construction Cost and any Transfer Costs for the Interconnection Facilities to which the Additional Applicant intends to connect and share usage. 3. The Additional Applicant will pay the Company the amount of the Vested Interest refund(s). Additional Applicants making Vested Interest payments are in turn eligible to receive refunds within the 5 year limit described above. 4. Vested Interest refunds will not exceed 100 percent of the refundable portion of any party's cash payment to the Company. 5. Vested Interest refund payments may be waived by notifying the Company in writing. OPERATION AND MAINTENANCE OBLIGATIONS AND EXPENSES The Company will operate and maintain Company furnished Interconnection Facilities, as well as any Seller-Furnished Facilities transferred to the Company. Seller will pay the Company a monthly operation and maintenance charge equal to a percentage of the Construction Cost and Transfer Cost paid by the Seller. The percentage will change annually on the anniversary of the First Energy Date in accordance with the following tables: IDAHO PUBLIC UTILITIES COMMISSION Approved Effective March 23, 2021 March 23, 2021 Per ON 34955 Jan Noriyuki Secretary Idaho Power Company Fourth Revised Sheet No. 72-12 Cancels I.P.U.C. No. 29, Tariff No. 101 Fifth Revised Sheet No. 72-12 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 72 GENERATOR INTERCONNECTIONS TO PURPA QUALIFYING FACILITY SELLERS (Continued) SECTION 2: INTERCONNECTION OF GENERATION FACILITIES (Continued) OPERATION AND MAINTENANCE OBLIGATIONS AND EXPENSES (Continued) TABLE 1: MONTHLY OPERATION AND MAINTENANCE CHARGES FOR 138 kV and 161 kV Year 1 2 3 4 5 6 7 8 9 10 11 12 O&M Charge 0.26% 0.27% 0.28% 0.29% 0.30% 0.32% 0.33% 0.35% 0.36% 0.38% 0.40% 0.41% Year 13 14 15 16 17 18 19 20 21 22 23 24 O&M Charge 0.43% 0.45% 0.47% 0.49% 0.52% 0.54% 0.56% 0.59% 0.62% 0.64% 0.67% 0.70% Year 25 26 27 28 29 30 31 32 33 34 35 36+ O&M Charge 0.73% 0.77% 0.80% 0.84% 0.87% 0.91% 0.96% 1.00% 1.04% 1.09% 1.14% 0.40% TABLE 2: MONTHLY OPERATING AND MAINTENANCE CHARGES BELOW 138 kV Year 1 2 3 4 5 6 7 8 9 10 11 12 O&M Charge 0.47% 0.49% 0.52% 0.54% 0.56% 0.59% 0.61% 0.64% 0.67% 0.70% 0.73% 0.77% Year 13 14 15 16 17 18 19 20 21 22 23 24 O&M Charge 0.80% 0.84% 0.87% 0.91% 0.95% 1.00% 1.04% 1.09% 1.14% 1.19% 1.24% 1.30% Year 25 26 27 28 29 30 31 32 33 34 35 36+ O&M Charge 1.36% 1.42% 1.48% 1.55% 1.62% 1.69% 1.77% 1.85% 1.93% 2.02% 2.11% 0.70% The monthly operating and maintenance charges in Table 1 and Table 2 will be applied as a percentage of the applicable original interconnection investment. These monthly operating and maintenance charges escalate annually and are equivalent to 35-year levelized rates of 0.40% for Table 1 and 0.70% for Table 2. Where a Seller's interconnection will utilize Interconnection Facilities provided under a prior agreement(s) and the combined term(s) of the prior agreement(s) is less than 35 years, the operation and maintenance charge related to those existing Interconnection Facilities for the Seller's interconnection will be computed to include the expired term of the prior agreement(s). Where a Seller’s interconnection will utilize Interconnection Facilities provided under a prior agreement(s) and the combined term(s) of the prior agreement(s) is greater than 35 years, the operation and maintenance charge related to those existing Interconnection Facilities for the Seller’s interconnection will be computed at the applicable levelized rate designated at 36+ years. The cost upon which an individual Seller's operation and maintenance charge is based will be reduced by subsequent Vested Interest refunds. Additional Applicants who are Sellers will pay the monthly operation and maintenance charge on the amount they paid as an Additional Applicant. Seller-Furnished Facilities not transferred to the Company will be operated and maintained by the Seller at the Seller's sole risk and expense. IDAHO PUBLIC UTILITIES COMMISSION Approved Effective March 23, 2021 March 23, 2021 Per ON 34955 Jan Noriyuki Secretary Idaho Power Company Fourth Revised Sheet No. 72-13 Cancels I.P.U.C. No. 29, Tariff No. 101 Third Revised Sheet No. 72-13 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 72 GENERATOR INTERCONNECTIONS TO PURPA QUALIFYING FACILITY SELLERS (Continued) SECTION 2: INTERCONNECTION OF GENERATION FACILITIES (Continued) IDAHO POWER COMPANY UNIFORM INTERCONNECTION AGREEMENT (PURPA) This Interconnection Agreement (“Agreement”) is effective as of the ____ day of __________, 20___, between ____________________________, hereinafter called “Seller,” and Idaho Power Company, hereinafter called “Company.” RECITALS A. Seller will own or operate a Generation Facility that qualifies for service under Idaho Power’s Commission-approved Schedule 72 and any successor schedule. B. The Generation Facility covered by this Agreement is more particularly described in Attachment 1. AGREEMENTS 1. Capitalized terms used herein shall have the same meanings as defined in Schedule 72 or in the body of this Agreement. 2. This Agreement and Schedule 72 provide the rates, charges, terms and conditions under which the Seller’s Generation Facility will interconnect with, and operate in parallel with, the Company’s transmission/distribution system. Terms defined in Schedule 72 will have the same defined meaning in this Agreement. If there is any conflict between the terms of this Agreement and Schedule 72, Schedule 72 shall prevail. 3. This Agreement is not an agreement to purchase Seller’s power. Purchase of Seller’s power and other services that Seller may require will be covered under separate agreements. Nothing in this Agreement is intended to affect any other agreement between the Company and Seller. 4. Attached to this Agreement and included by reference are the following: Attachment 1 – Description and Costs of the Generation Facility, Interconnection Facilities, and Metering Equipment. Attachment 2 – One-line Diagram Depicting the Generation Facility, Interconnection Facilities, Metering Equipment and Upgrades. Attachment 3 – Milestones For Interconnecting the Generation Facility. IDAHO PUBLIC UTILITIES COMMISSION Approved Effective March 23, 2021 March 23, 2021 Per ON 34955 Jan Noriyuki Secretary Idaho Power Company Fourth Revised Sheet No. 72-14 Cancels I.P.U.C. No. 29, Tariff No. 101 Third Revised Sheet No. 72-14 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 72 GENERATOR INTERCONNECTIONS TO PURPA QUALIFYING FACILITY SELLERS (Continued) SECTION 2: INTERCONNECTION OF GENERATION FACILITIES (Continued) IDAHO POWER COMPANY UNIFORM INTERCONNECTION AGREEMENT (PURPA) (Continued) AGREEMENTS (Continued) Attachment 4 – Additional Operating Requirements for the Company’s Transmission System Needed to Support the Seller’s Generation Facility. Attachment 5 – Reactive Power. Attachment 6 – Description of Upgrades required to integrate the Generation Facility and Best Estimate of Upgrade Costs. 5. Effective Date, Term, Termination and Disconnection. 5.1 Term of Agreement. Unless terminated earlier in accordance with the provisions of this Agreement, this Agreement shall become effective on the date specified above and remain effective as long as Seller’s Generation Facility is eligible for service under Schedule 72. 5.2 Termination. 5.2.1 Seller may voluntarily terminate this Agreement upon expiration or termination of an agreement to sell power to the Company. 5.2.2 After a Default, either Party may terminate this Agreement pursuant to Section 6.5. 5.2.3 Upon termination or expiration of this Agreement, the Seller’s Generation Facility will be disconnected from the Company’s transmission/distribution system. The termination or expiration of this Agreement shall not relieve either Party of its liabilities and obligations, owed or continuing at the time of the termination. The provisions of this Section shall survive termination or expiration of this Agreement. IDAHO PUBLIC UTILITIES COMMISSION Approved Effective March 23, 2021 March 23, 2021 Per ON 34955 Jan Noriyuki Secretary Idaho Power Company Fourth Revised Sheet No. 72-15 Cancels I.P.U.C. No. 29, Tariff No. 101 Third Revised Sheet No. 72-15 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 72 GENERATOR INTERCONNECTIONS TO PURPA QUALIFYING FACILITY SELLERS (Continued) SECTION 2: INTERCONNECTION OF GENERATION FACILITIES (Continued) IDAHO POWER COMPANY UNIFORM INTERCONNECTION AGREEMENT (PURPA) (Continued) AGREEMENTS (Continued) 5.3 Temporary Disconnection. Temporary disconnection shall continue only for so long as reasonably necessary under “Good Utility Practice.” Good Utility Practice means any of the practices, methods and acts engaged in or approved by a significant portion of the electric industry during the relevant time period, or any of the practices, methods and acts which, in the exercise of reasonable judgment in light of the facts known at the time the decision was made, could have been expected to accomplish the desired result at a reasonable cost consistent with good business practices, reliability, safety and expedition. Good Utility Practice is not intended to be limited to the optimum practice, method, or act to the exclusion of all others, but rather to be acceptable practices, methods, or acts generally accepted in the region. Good Utility Practice includes compliance with WECC or NERC requirements. Payment of lost revenue resulting from temporary disconnection shall be governed by the power purchase agreement. 5.3.1 Emergency Conditions. "Emergency Condition" means a condition or situation: (1) that in the judgment of the Party making the claim is imminently likely to endanger life or property; or (2) that, in the case of the Company, is imminently likely (as determined in a non-discriminatory manner) to cause a material adverse effect on the security of, or damage to the Company’s transmission/distribution system, the Company’s Interconnection Facilities or the equipment of the Company’s customers; or (3) that, in the case of the Seller, is imminently likely (as determined in a non-discriminatory manner) to cause a material adverse effect on the reliability and security of, or damage to, the Generation Facility or the Seller’s Interconnection Facilities. Under Emergency Conditions, either the Company or the Seller may immediately suspend interconnection service and temporarily disconnect the Generation Facility. The Company shall notify the Seller promptly when it becomes aware of an Emergency Condition that may reasonably be expected to affect the Seller’s operation of the Generation Facility. The Seller shall notify the Company promptly when it becomes aware of an Emergency Condition that may reasonably be expected to affect the Company’s equipment or service to the Company’s customers. To the extent information is known, the notification shall describe the Emergency Condition, the extent of the damage or deficiency, the expected effect on the operation of both Parties' facilities and operations, its anticipated duration, and the necessary corrective action. IDAHO PUBLIC UTILITIES COMMISSION Approved Effective March 23, 2021 March 23, 2021 Per ON 34955 Jan Noriyuki Secretary Idaho Power Company Fourth Revised Sheet No. 72-16 Cancels I.P.U.C. No. 29, Tariff No. 101 Third Revised Sheet No. 72-16 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 72 GENERATOR INTERCONNECTIONS TO PURPA QUALIFYING FACILITY SELLERS (Continued) SECTION 2: INTERCONNECTION OF GENERATION FACILITIES (Continued) IDAHO POWER COMPANY UNIFORM INTERCONNECTION AGREEMENT (PURPA) (Continued) AGREEMENTS (Continued) 5.3.2 Routine Maintenance, Construction, and Repair. The Company may interrupt interconnection service or curtail the output of the Seller’s Generation Facility and temporarily disconnect the Generation Facility from the Company’s transmission/distribution system when necessary for routine maintenance, construction, and repairs on the Company’s transmission/distribution system. The Company will make a reasonable attempt to contact the Seller prior to exercising its rights to interrupt interconnection or curtail deliveries from the Seller’s Facility. Seller understands that in the case of emergency circumstances, real time operations of the electrical system, and/or unplanned events, the Company may not be able to provide notice to the Seller prior to interruption, curtailment or reduction of electrical energy deliveries to the Company. The Company shall use reasonable efforts to coordinate such reduction or temporary disconnection with the Seller. 5.3.3 Scheduled Maintenance. On or before January 31 of each calendar year, Seller shall submit a written proposed maintenance schedule of significant Facility maintenance for that calendar year and the Company and Seller shall mutually agree as to the acceptability of the proposed schedule. The Parties determination as to the acceptability of the Seller’s timetable for scheduled maintenance will take into consideration Good Utility Practices, Idaho Power system requirements and the Seller’s preferred schedule. Neither Party shall unreasonably withhold acceptance of the proposed maintenance schedule. 5.3.4. Maintenance Coordination. The Seller and the Company shall, to the extent practical, coordinate their respective transmission/distribution system and Generation Facility maintenance schedules such that they occur simultaneously. Seller shall provide and maintain adequate protective equipment sufficient to prevent damage to the Generation Facility and Seller-furnished Interconnection Facilities. In some cases, some of Seller’s protective relays will provide back-up protection for Idaho Power’s facilities. In that event, Idaho Power will test such relays annually and Seller will pay the actual cost of such annual testing. IDAHO PUBLIC UTILITIES COMMISSION Approved Effective March 23, 2021 March 23, 2021 Per ON 34955 Jan Noriyuki Secretary Idaho Power Company Fifth Revised Sheet No. 72-17 Cancels I.P.U.C. No. 29, Tariff No. 101 Fourth Revised Sheet No. 72-17 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 72 GENERATOR INTERCONNECTIONS TO PURPA QUALIFYING FACILITY SELLERS (Continued) SECTION 2: INTERCONNECTION OF GENERATION FACILITIES (Continued) IDAHO POWER COMPANY UNIFORM INTERCONNECTION AGREEMENT (PURPA) (Continued) AGREEMENTS (Continued) 5.3.5 Forced Outages. During any forced outage, the Company may suspend interconnection service to effect immediate repairs on the Company’s transmission/distribution system. The Company shall use reasonable efforts to provide the Seller with prior notice. If prior notice is not given, the Company shall, upon request, provide the Seller written documentation after the fact explaining the circumstances of the disconnection. 5.3.6 Adverse Operating Effects. The Company shall notify the Seller as soon as practicable if, based on Good Utility Practice, operation of the Seller’s Generation Facility may cause disruption or deterioration of service to other customers served from the same electric system, or if operating the Generation Facility could cause damage to the Company’s transmission/distribution system or other affected systems. Supporting documentation used to reach the decision to disconnect shall be provided to the Seller upon request. If, after notice, the Seller fails to remedy the adverse operating effect within a reasonable time, the Company may disconnect the Generation Facility. The Company shall provide the Seller with reasonable notice of such disconnection, unless the provisions of Article 5.3.1 apply. 5.3.7 Modification of the Generation Facility. The Seller must receive written authorization from the Company before making any change to the Generation Facility that may have a material impact on the safety or reliability of the Company’s transmission/distribution system. Such authorization shall not be unreasonably withheld. Modifications shall be done in accordance with Good Utility Practice. If the Seller makes such modification without the Company’s prior written authorization, the latter shall have the right to temporarily disconnect the Generation Facility. 5.3.8 Reconnection. The Parties shall cooperate with each other to restore the Generation Facility, Interconnection Facilities, and the Company’s transmission/distribution system to their normal operating state as soon as reasonably practicable following a temporary disconnection. IDAHO PUBLIC UTILITIES COMMISSION Approved Effective March 23, 2021 March 23, 2021 Per ON 34955 Jan Noriyuki Secretary Idaho Power Company Fifth Revised Sheet No. 72-18 Cancels I.P.U.C. No. 29, Tariff No. 101 Fourth Revised Sheet No. 72-18 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 72 GENERATOR INTERCONNECTIONS TO PURPA QUALIFYING FACILITY SELLERS (Continued) SECTION 2: INTERCONNECTION OF GENERATION FACILITIES (Continued) IDAHO POWER COMPANY UNIFORM INTERCONNECTION AGREEMENT (PURPA) (Continued) AGREEMENTS (Continued) 5.3.9 Voltage Levels. Seller, in accordance with Good Utility Practices, shall minimize voltage fluctuations and maintain voltage levels acceptable to Idaho Power. Idaho Power may, in accordance with Good Utility Practices, upon one hundred eighty (180) days' notice to the Seller, change its nominal operating voltage level by more than ten percent (10%) at the Point of Delivery, in which case Seller shall modify, at Idaho Power's expense, Seller's equipment as necessary to accommodate the modified nominal operating voltage level. 5.4 Land Rights. 5.4.1 Seller to Provide Access. Seller 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 property of Seller. Seller 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. 5.4.2 Use of Public Rights-of-Way. The Parties agree that it is necessary to avoid the adverse environmental and operating impacts that would occur as a result of duplicate electric lines being constructed in close proximity. Therefore, subject to Idaho Power's compliance with Paragraph 5.4.4, Seller agrees that should Seller seek and receive from any local, state or federal governmental body the right to erect, construct and maintain Seller-furnished Interconnection Facilities upon, along and over any and all public roads, streets and highways, then the use by Seller of such public right-of-way shall be subordinate to any future use by Idaho Power of such public right-of-way for construction and/or maintenance of electric distribution and transmission facilities and Idaho Power may claim use of such public right-of-way for such purposes at any time. Except as required by Paragraph 5.4.4, Idaho Power shall not be required to compensate Seller for exercising its rights under this Paragraph 5.4.2. IDAHO PUBLIC UTILITIES COMMISSION Approved Effective March 23, 2021 March 23, 2021 Per ON 34955 Jan Noriyuki Secretary Idaho Power Company Fourth Revised Sheet No. 72-19 Cancels I.P.U.C. No. 29, Tariff No. 101 Third Revised Sheet No. 72-19 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 72 GENERATOR INTERCONNECTIONS TO PURPA QUALIFYING FACILITY SELLERS (Continued) SECTION 2: INTERCONNECTION OF GENERATION FACILITIES (Continued) IDAHO POWER COMPANY UNIFORM INTERCONNECTION AGREEMENT (PURPA) (Continued) AGREEMENTS (Continued) 5.4.3 Joint Use of Facilities. Subject to Idaho Power's compliance with Paragraph 15.4.4, Idaho Power may use and attach its distribution and/or transmission facilities to Seller's Interconnection Facilities, may reconstruct Seller's Interconnection Facilities to accommodate Idaho Power's usage or Idaho Power may construct its own distribution or transmission facilities along, over and above any public right-of-way acquired from Seller pursuant to Paragraph 5.4.2, attaching Seller's Interconnection Facilities to such newly constructed facilities. Except as required by Paragraph 5.4.4, Idaho Power shall not be required to compensate Seller for exercising its rights under this Paragraph 5.4.3. 5.4.4 Conditions of Use. It is the intention of the Parties that the Seller be left in substantially the same condition, both financially and electrically, as Seller existed prior to Idaho Power's exercising its rights under this Paragraph 5.4. Therefore, the Parties agree that the exercise by Idaho Power of any of the rights enumerated in Paragraphs 5.4.2 and 5.4.3 shall: (1) comply with all applicable laws, codes and Good Utility Practices, (2) equitably share the costs of installing, owning and operating jointly used facilities and rights-of-way. If the Parties are unable to agree on the method of apportioning these costs, the dispute will be submitted to the Commission for resolution and the decision of the Commission will be binding on the Parties, and (3) shall provide Seller with an interconnection to Idaho Power's system of equal capacity and durability as existed prior to Idaho Power exercising its rights under this Paragraph 5.4. 6. Assignment, Liability, Indemnity, Force majeure, Consequential Damages and Default. 6.1 Assignment. 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: 6.1.1 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. IDAHO PUBLIC UTILITIES COMMISSION Approved Effective March 23, 2021 March 23, 2021 Per ON 34955 Jan Noriyuki Secretary Idaho Power Company Fourth Revised Sheet No. 72-20 Cancels I.P.U.C. No. 29, Tariff No. 101 Third Revised Sheet No. 72-20 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 72 GENERATOR INTERCONNECTIONS TO PURPA QUALIFYING FACILITY SELLERS (Continued) SECTION 2: INTERCONNECTION OF GENERATION FACILITIES (Continued) IDAHO POWER COMPANY UNIFORM INTERCONNECTION AGREEMENT (PURPA) (Continued) AGREEMENTS (Continued) 6.1.2 The Seller shall have 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 Seller will promptly notify the Company of any such contingent assignment. 6.1.3 Any attempted assignment that violates this article is void and ineffective. Assignment shall not relieve a Party of its obligations, nor shall a 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 Seller. Where required, consent to assignment will not be unreasonably withheld, conditioned or delayed. 6.2 Limitation of Liability. Each Party's liability to the other Party for any loss, cost, claim, injury, liability, or expense, including reasonable attorney's fees, relating to or arising from any act or omission in its performance of this Agreement, shall be limited to the amount of direct damage actually incurred. In no event shall either Party be liable to the other Party for any indirect, special, consequential, or punitive damages, except as authorized by this Agreement. 6.3 Indemnity. 6.3.1 This provision protects each Party from liability incurred to third parties as a result of carrying out the provisions of this Agreement. Liability under this provision is exempt from the general limitations on liability found in Article 6.2. 6.3.2 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. IDAHO PUBLIC UTILITIES COMMISSION Approved Effective March 23, 2021 March 23, 2021 Per ON 34955 Jan Noriyuki Secretary Idaho Power Company Fourth Revised Sheet No. 72-21 Cancels I.P.U.C. No. 29, Tariff No. 101 Third Revised Sheet No. 72-21 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 72 GENERATOR INTERCONNECTIONS TO PURPA QUALIFYING FACILITY SELLERS (Continued) SECTION 2: INTERCONNECTION OF GENERATION FACILITIES (Continued) IDAHO POWER COMPANY UNIFORM INTERCONNECTION AGREEMENT (PURPA) (Continued) AGREEMENTS (Continued) 6.3.3 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. 6.3.4 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. 6.3.5 Promptly after receipt by an indemnified person of any claim or notice of the commencement of any action or administrative or legal proceeding or investigation as to which the indemnity provided for in this article may apply, the indemnified person shall notify the indemnifying party of such fact. Any failure of or delay in such notification shall be a Material Breach and shall not affect a Party's indemnification obligation unless such failure or delay is materially prejudicial to the indemnifying party. 6.4 Force Majeure. As used in this Agreement, “Force Majeure” or “an event of Force Majeure” means any cause beyond the control of the Seller or of the Company which, despite the exercise of due diligence, such Party is unable to prevent or overcome. Force Majeure includes, but is not limited to, acts of God, fire, flood, storms, wars, hostilities, civil strife, strikes and other labor disturbances, earthquakes, fires, lightning, epidemics, sabotage, or changes in law or regulation occurring after the Operation Date, which, by the exercise of reasonable foresight such party could not reasonably have been expected to avoid and by the exercise of due diligence, it shall be unable to overcome. If either Party is rendered wholly or in part unable to perform its obligations under this Agreement because of an event of Force Majeure, both Parties shall be excused from whatever performance is affected by the event of Force Majeure, provided that: (1) The non-performing Party shall, as soon as is reasonably possible after the occurrence of the Force Majeure, give the other Party written notice describing the particulars of the occurrence. IDAHO PUBLIC UTILITIES COMMISSION Approved Effective March 23, 2021 March 23, 2021 Per ON 34955 Jan Noriyuki Secretary Idaho Power Company Fourth Revised Sheet No. 72-22 Cancels I.P.U.C. No. 29, Tariff No. 101 Third Revised Sheet No. 72-22 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 72 GENERATOR INTERCONNECTIONS TO PURPA QUALIFYING FACILITY SELLERS (Continued) SECTION 2: INTERCONNECTION OF GENERATION FACILITIES (Continued) IDAHO POWER COMPANY UNIFORM INTERCONNECTION AGREEMENT (PURPA) (Continued) AGREEMENTS (Continued) (2) The suspension of performance shall be of no greater scope and of no longer duration than is required by the event of Force Majeure. (3) No obligations of either Party which arose before the occurrence causing the suspension of performance and which could and should have been fully performed before such occurrence shall be excused as a result of such occurrence. 6.5 Default and Material Breaches. 6.5.1 Defaults. If either Party fails to perform any of the terms or conditions of this Agreement (a “Default” or an “Event of Default”), the nondefaulting Party shall cause notice in writing to be given to the defaulting Party, specifying the manner in which such default occurred. If the defaulting Party shall fail to cure such Default within the sixty (60) days after service of such notice, or if the defaulting Party reasonably demonstrates to the other Party that the Default can be cured within a commercially reasonable time but not within such sixty (60) day period and then fails to diligently pursue such cure, then, the nondefaulting Party may, at its option, terminate this Agreement and/or pursue its legal or equitable remedies. 6.5.2 Material Breaches. The notice and cure provisions in Paragraph 6.6.1 do not apply to Defaults identified in this Agreement as Material Breaches. Material Breaches must be cured as expeditiously as possible following occurrence of the breach. 7. Insurance. During the term of this Agreement, Seller shall secure and continuously carry the following insurance coverage: 7.1 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. 7.2 The above insurance coverage shall be placed with an insurance company with an A.M. Best Company rating of A- or better and shall include: IDAHO PUBLIC UTILITIES COMMISSION Approved Effective March 23, 2021 March 23, 2021 Per ON 34955 Jan Noriyuki Secretary Idaho Power Company Fourth Revised Sheet No. 72-23 Cancels I.P.U.C. No. 29, Tariff No. 101 Third Revised Sheet No. 72-23 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 72 GENERATOR INTERCONNECTIONS TO PURPA QUALIFYING FACILITY SELLERS (Continued) SECTION 2: INTERCONNECTION OF GENERATION FACILITIES (Continued) IDAHO POWER COMPANY UNIFORM INTERCONNECTION AGREEMENT (PURPA) (Continued) AGREEMENTS (Continued) (a) An endorsement naming Idaho Power as an additional insured and loss payee as applicable; and (b) 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. 7.3 Seller to Provide Certificate of Insurance. As required in Paragraph 7 herein and annually thereafter, Seller shall furnish the Company a certificate of insurance, together with the endorsements required therein, evidencing the coverage as set forth above. 7.4 Seller to Notify Idaho Power of Loss of Coverage. If the insurance coverage required by Paragraph 7.1 shall lapse for any reason, Seller will immediately notify Idaho Power in writing. The notice will advise Idaho Power of the specific reason for the lapse and the steps Seller 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 5.3 and will be a Material Breach. 8. Miscellaneous. 8.1 Governing Law. The validity, interpretation and enforcement of this Agreement and each of its provisions shall be governed by the laws of the State of Idaho without regard to its conflicts of law principles. 8.2 Salvage. No later than sixty (60) days after the termination or expiration of this Agreement, Idaho Power will prepare and forward to Seller an estimate of the remaining value of those Idaho Power furnished Interconnection Facilities as required under Schedule 72 and/or described in this Agreement, less the cost of removal and transfer to Idaho Power's nearest warehouse, if the Interconnection Facilities will be removed. If Seller elects not to obtain ownership of the Interconnection Facilities but instead wishes that Idaho Power reimburse the Seller for said Facilities the Seller may invoice Idaho Power for the net salvage value as estimated by Idaho Power and Idaho Power shall pay such amount to Seller within thirty (30) days after receipt of the invoice. Seller shall have the right to offset the invoice amount against any present or future payments due Idaho Power. IDAHO PUBLIC UTILITIES COMMISSION Approved Effective March 23, 2021 March 23, 2021 Per ON 34955 Jan Noriyuki Secretary Idaho Power Company Fourth Revised Sheet No. 72-24 Cancels I.P.U.C. No. 29, Tariff No. 101 Third Revised Sheet No. 72-24 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 72 GENERATOR INTERCONNECTIONS TO PURPA QUALIFYING FACILITY SELLERS (Continued) SECTION 2: INTERCONNECTION OF GENERATION FACILITIES (Continued) IDAHO POWER COMPANY UNIFORM INTERCONNECTION AGREEMENT (PURPA) (Continued) AGREEMENTS (Continued) 9. Notices. 9.1 General. Unless otherwise provided in this Agreement, any written notice, demand, or request required or authorized in connection with this Agreement ("Notice") shall be deemed properly given if delivered in person, delivered by recognized national currier service, or sent by first class mail, postage prepaid, to the person specified below: If to the Seller: Seller: Attention: Address: City: State: Zip: Phone: Fax: If to the Company: Company Attention: Address: City: State: Zip: Phone: Fax: 9.2 Billing and Payment. Billings and payments shall be sent to the addresses set out below: Seller: Attention: Address: City: State: Zip: Phone: Fax: Company: Attention: Address: City: State: Zip: Phone: Fax: IDAHO PUBLIC UTILITIES COMMISSION Approved Effective March 23, 2021 March 23, 2021 Per ON 34955 Jan Noriyuki Secretary Idaho Power Company Fourth Revised Sheet No. 72-25 Cancels I.P.U.C. No. 29, Tariff No. 101 Third Revised Sheet No. 72-25 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 72 GENERATOR INTERCONNECTIONS TO PURPA QUALIFYING FACILITY SELLERS (Continued) SECTION 2: INTERCONNECTION OF GENERATION FACILITIES (Continued) IDAHO POWER COMPANY UNIFORM INTERCONNECTION AGREEMENT (PURPA) (Continued) AGREEMENTS (Continued) 9.3 Designated Operating Representative. The Parties may also designate operating representatives to conduct the communications which may be necessary or convenient for the administration of this Agreement. This person will also serve as the point of contact with respect to operations and maintenance of the Party’s facilities. Seller’s Operating Representative: Seller: Attention: Address: City: State: Zip: Phone: Fax: Company’s Operating Representative: Company: Attention: Address: City: State: Zip: Phone: Fax: 9.5 Changes to the Notice Information. Either Party may change this information by giving five Business Days written notice prior to the effective date of the change. 10. Signatures. IN WITNESS WHEREOF, the Parties have caused this Agreement to be executed by their respective duly authorized representatives. For the Company Name: Title: Date: For the Seller Name: Title: Date: IDAHO PUBLIC UTILITIES COMMISSION Approved Effective March 23, 2021 March 23, 2021 Per ON 34955 Jan Noriyuki Secretary Idaho Power Company Fourth Revised Sheet No. 72-26 Cancels I.P.U.C. No. 29, Tariff No. 101 Third Revised Sheet No. 72-26 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 72 GENERATOR INTERCONNECTIONS TO PURPA QUALIFYING FACILITY SELLERS (Continued) SECTION 2: INTERCONNECTION OF GENERATION FACILITIES (Continued) IDAHO POWER COMPANY UNIFORM INTERCONNECTION AGREEMENT (PURPA) (Continued) Attachment 1 Description and Costs of the Generation Facility, Interconnection Facilities and Metering Equipment In this attachment the Generation Facility and Interconnection Facilities, including Special Facilities and upgrades, are itemized and identified as being owned by the Seller or the Company. As provided in Schedule 72, Payment For 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 Small Generation Facility, Interconnection Facilities, Metering Equipment and Upgrades IDAHO PUBLIC UTILITIES COMMISSION Approved Effective March 23, 2021 March 23, 2021 Per ON 34955 Jan Noriyuki Secretary Idaho Power Company Fourth Revised Sheet No. 73-27 Cancels I.P.U.C. No. 29, Tariff No. 101 Third Revised Sheet No. 72-27 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 72 GENERATOR INTERCONNECTIONS TO PURPA QUALIFYING FACILITY SELLERS (Continued) SECTION 2: INTERCONNECTION OF GENERATION FACILITIES (Continued) IDAHO POWER COMPANY UNIFORM INTERCONNECTION AGREEMENT (PURPA) (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 Seller________________________ Date______________ IDAHO PUBLIC UTILITIES COMMISSION Approved Effective March 23, 2021 March 23, 2021 Per ON 34955 Jan Noriyuki Secretary Idaho Power Company Fourth Revised Sheet No. 72-28 Cancels I.P.U.C. No. 29, Tariff No. 101 Third Revised Sheet No. 72-28 thru 72-34 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 72 GENERATOR INTERCONNECTIONS TO PURPA QUALIFYING FACILITY SELLERS (Continued) SECTION 2: INTERCONNECTION OF GENERATION FACILITIES (Continued) IDAHO POWER COMPANY UNIFORM INTERCONNECTION AGREEMENT (PURPA) (Continued) Attachment 4 Additional Operating Requirements for the Company’s Transmission System and Affected Systems Needed to Support the Seller’s Needs The Company shall also provide requirements that must be met by the Seller 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 Seller, based upon information provided by the Seller. 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, Seller 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 Seller. Payment of these costs will be in accordance with Schedule 72 and the total reactive power cost will be included in the calculation of the Monthly Operation and Maintenance Charges specified in Schedule 72. Attachment 6 Company’s Description of Upgrades Required to Integrate the Generation Facility and Best Estimate of Upgrade Costs As provided in Schedule 72 this Attachment describes Upgrades, including best work upgrades, and provides an itemized best estimate of the cost of the Upgrades. IDAHO PUBLIC UTILITIES COMMISSION Approved Effective March 23, 2021 March 23, 2021 Per ON 34955 Jan Noriyuki Secretary Idaho Power Company Sixth Revised Sheet No. 84-1 Cancels I.P.U.C. No. 29, Tariff No. 101 Fifth Revised Sheet No. 84-1 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 84 CUSTOMER ENERGY PRODUCTION NET METERING SERVICE AVAILABILITY Service under this schedule is available throughout the Company’s service territory 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. APPLICABILITY Service under this schedule is applicable to any Customer that: 1. Does not take service under Schedule 4, 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 for the loads served at the Point of Delivery adjacent to the Generation Interconnection Point 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 the Company’s existing watt-hour retail meter. 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 One Meter Option is available if: IDAHO PUBLIC UTILITIES COMMISSION Approved Effective March 23, 2021 March 23, 2021 Per ON 34955 Jan Noriyuki Secretary Idaho Power Company Fourth Revised Sheet No. 84-3 Cancels I.P.U.C. No. 29, Tariff No. 101 Third Revised Sheet No. 84-3 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 84 CUSTOMER ENERGY PRODUCTION NET METERING SERVICE (Continued) DEFINITIONS Basic Load Capacity (BLC) is the average of the two greatest non-zero monthly Billing Demands established during the 12-month period which includes and ends with the current Billing Period. 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. 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. Grandfathered Status refers to the ability for a system to receive the compensation structure in place on December 1, 2020. The compensation structure applicable to systems with a Grandfather Status includes net monthly one-for-one kWh credit compensation for Excess Net Energy. 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 Generation Facility to the Point of Delivery or Generation Interconnection Point. 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 customer generation or its successor schedule(s) as approved by the Commission. IDAHO PUBLIC UTILITIES COMMISSION Approved Effective March 23, 2021 March 23, 2021 Per ON 34955 Jan Noriyuki Secretary Idaho Power Company Fourth Revised Sheet No. 84-4 Cancels I.P.U.C. No. 29, Tariff No. 101 Third Revised Sheet No. 84-4 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 84 CUSTOMER ENERGY PRODUCTION NET METERING SERVICE (Continued) MONTHLY BILLING The Customer shall be billed in accordance with the Customer’s applicable standard service schedule, including appropriate monthly charges. CONDITIONS OF PURCHASE AND SALE The conditions listed below shall apply to all transactions 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. b. Effective at the beginning of each Customer’s January 2014 Billing Period, 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 at the end of the Customer’s December Billing Period 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 IDAHO PUBLIC UTILITIES COMMISSION Approved Effective March 23, 2021 March 23, 2021 Per ON 34955 Jan Noriyuki Secretary Idaho Power Company Second Revised Sheet No. 84-5 Cancels I.P.U.C. No. 29, Tariff No. 101 First Revised Sheet No. 84-5 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 84 CUSTOMER ENERGY PRODUCTION NET METERING SERVICE (Continued) CONDITIONS OF PURCHASE AND SALE (Continued) 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 January 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 on January 1 of 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 the same rate schedule as the Designated Meter. Remaining Excess Net Energy credits may then be applied to offset consumption at eligible meters on differing 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. 3. The Customer shall never deliver or attempt to deliver energy to the Company’s system when the Company’s system serving the Customer’s Generation Facility is de-energized for any reason. IDAHO PUBLIC UTILITIES COMMISSION Approved Effective March 23, 2021 March 23, 2021 Per ON 34955 Jan Noriyuki Secretary Idaho Power Company First Revised Sheet No. 84-6 Cancels I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 84-6 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 84 CUSTOMER ENERGY PRODUCTION NET METERING SERVICE (Continued) CONDITIONS OF PURCHASE AND SALE (Continued) 4. 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. 5. The Customer is responsible for all costs associated with the Generation Facility 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 Generation Facility in order to maintain a safe, reliable electrical system. 6. 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. 7. 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. 8. 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. 9. 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 PUBLIC UTILITIES COMMISSION Approved Effective March 23, 2021 March 23, 2021 Per ON 34955 Jan Noriyuki Secretary (LEGISLATIVE FORMAT) Idaho Power Company First Revised Sheet No. 6-1 Cancels I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 6-1 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34046955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – June 1, 2018March 23, 2021 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 Small On-Site Generation Exporting Systems to generate electricity to reduce all or part of the monthly energy usage. 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 pParallel with the Idaho Power System. 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. 6. Customer meets all applicable requirements applicable to Small On-Site Generation Systems detailed in the Company’s Schedule 72, Interconnections to Non-Utility Generation Schedule 68, Interconnections to Customer Distributed Energy Resources. DEFINITIONS Designated Meter is the retail meter physically connected to the Small On-Site Generation Exporting System. 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. Idaho Power Company First Revised Sheet No. 6-2 Cancels I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 6-2 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34046955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – June 1, 2018March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 6 RESIDENTIAL SERVICE ON-SITE GENERATION (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 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. 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. 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 Generation Facility to the Point of Delivery. 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 7268 is the Company’s service schedule which provides for interconnection to non-utility generation customer generation or its successor schedule(s) as approved by the Commission. Small On-Site Generation Service is the Company’s service which provides for transfer of electric energy to the Company under the terms of this Schedule and of Schedule 72 or their successor(s) as approved by the Commission. This optional service provides for Customers to install Generation Facilities to interconnect to the Company’s system to offset all or a portion of their electrical usage. This service is comprised of all customers taking service under Schedule 6 or Schedule 8. Small On-Site Generation System is a Customer-owned Generation Facility, with a total nameplate capacity rating of 25 kW or less, interconnected to the Company’s system under the applicable terms of Schedule 72 and this schedule. Idaho Power Company First Revised Sheet No. 6-2 Cancels I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 6-2 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34046955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – June 1, 2018March 23, 2021 1221 West Idaho Street, Boise, Idaho 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 First Revised Sheet No. 6-4 Cancels I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 6-4 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34046955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – June 1, 2018March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 6 RESIDENTIAL SERVICE ON-SITE GENERATION (Continued) CONDITIONS OF PURCHASE AND SALE (Continued) 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 Small On-Site Generation 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 at the end of the Customer’s December Billing Period 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 Small On-Site Generation 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 January 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 on January 1 of the following year. Idaho Power Company First Revised Sheet No. 6-5 Cancels I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 6-5 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34046955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – June 1, 2018March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 6 RESIDENTIAL SERVICE ON-SITE GENERATION (Continued) CONDITIONS OF PURCHASE AND SALE (Continued) 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 the same rate schedule as the Designated Meter. Remaining Excess Net Energy credits may then be applied to offset consumption at eligible meters on differing 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. 3. The Customer shall never deliver or attempt to deliver energy to the Company’s system when the Company’s system serving the Customer’s Generation Facility is de-energized for any reason. 4. The Company shall not be liable directly or indirectly for permitting or continuing to allow an attachment of an Small On-Site Generation 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. 5. The Customer is responsible for all costs associated with the Generation Facility 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 Generation Facility in order to maintain a safe, reliable electrical system. 6. 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. 7. 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. 8. 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 Third Fourth Revised Sheet No. 6-6 Cancels I.P.U.C. No. 29, Tariff No. 101 Second Third Revised Sheet No. 6-6 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34885955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – January 1, 2021March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 6 RESIDENTIAL SERVICE ON-SITE GENERATION (Continued) CONDITIONS OF PURCHASE AND SALE (Continued) 9. The Customer shall notify the Company immediately if an Small On-Site Generation Exporting System is permanently removed or disabled. Permanent removal or disablement for the purposes of this Schedule is any removal or disablement of an Small On-Site Generation 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 August 31 of each year. The non- summer season begins on September 1 of each year and ends on May 31 of each year. 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), and Schedule 98 (Residential and Small Farm Energy Credit). The following rate structure and charges are subject to change upon Commission approval: Summer Non-summer Service Charge, per month $5.00 $5.00 Energy Charge, per kWh First 800 kWh 8.5005¢ 7.8984¢ 801-2000 kWh 10.2214¢ 8.7077¢ All Additional kWh Over 2000 12.1424¢ 9.6437¢ 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 First Second Revised Sheet No. 8-1 Cancels I.P.U.C. No. 29, Tariff No. 101 Original First Revised Sheet No. 8-1 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34686955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – June 5, 2020March 23, 2021 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 Small On-Site Generation Exporting Systems under this schedule to generate electricity to reduce all or part of their monthly energy usage. APPLICABILITY Effective until a final order is issued that addresses metering configuration for Schedule 84 customers, and any appeal period has passed or the order has been upheld on appeal, existing Schedule 8 customers who no longer meet the energy usage requirement of Schedule 8 that ‘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[,]’ can elect Schedule 8. 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 pParallel with the Idaho Power System. 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. Idaho Power Company First Second Revised Sheet No. 8-1 Cancels I.P.U.C. No. 29, Tariff No. 101 Original First Revised Sheet No. 8-1 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34686955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – June 5, 2020March 23, 2021 1221 West Idaho Street, Boise, Idaho 3. Customer meets all requirements applicable requirements to Small On-Site Generation Systems detailed in the Company’s Schedule 72, Interconnections to Non-Utility Generation Schedule 68, Interconnections to Customer Distributed Energy Resources. Idaho Power Company First Revised Sheet No. 8-2 Cancels I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 8-2 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34046955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – June 1, 2018March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 8 SMALL GENERAL SERVICE ON-SITE GENERATION (Continued) DEFINITIONS Designated Meter is the retail meter physically connected to the Small On-Site GenerationExporting 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. 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 Generation Facility to the Point of Delivery. 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 7268 is the Company’s service schedule which provides for interconnection to non-utility generation customer generation or its successor schedule(s) as approved by the Commission. Small On-Site Generation Service is the Company’s service which provides for transfer of electric energy to the Company under the terms of this Schedule and of Schedule 72 or their successor(s) as approved by the Commission. This optional service provides for Customers to install Generation Idaho Power Company First Revised Sheet No. 8-2 Cancels I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 8-2 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34046955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – June 1, 2018March 23, 2021 1221 West Idaho Street, Boise, Idaho Facilities to interconnect to the Company’s system to offset all or a portion of their electrical usage. This service is comprised of all customers taking service under Schedule 6 or Schedule 8. Small On-Site Generation System is a Customer-owned Generation Facility, with a total nameplate capacity rating of 25 kW or less, interconnected to the Company’s system under the applicable terms of Schedule 72 and this schedule. 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. Idaho Power Company First Revised Sheet No. 8-3 Cancels I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 8-3 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34046955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – June 1, 2018March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 8 SMALL GENERAL SERVICE ON-SITE GENERATION (Continued) CONDITIONS OF PURCHASE AND SALE The conditions listed below shall apply to all transactions 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 Small On-Site Generation 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 at the end of the Customer’s December Billing Period 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 Idaho Power Company First Revised Sheet No. 8-4 Cancels I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 8-4 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34046955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – June 1, 2018March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 8 SMALL GENERAL SERVICE ON-SITE GENERATION (Continued) CONDITIONS OF PURCHASE AND SALE (Continued) iii. The meter is served by the same primary feeder as the Designated Meter at the time the Customer files the application for the Small On-Site Generation 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 January 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 on January 1 of 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 the same rate schedule as the Designated Meter. Remaining Excess Net Energy credits may then be applied to offset consumption at eligible meters on differing 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. 3. The Customer shall never deliver or attempt to deliver energy to the Company’s system when the Company’s system serving the Customer’s Generation Facility is de-energized for any reason. 4. The Company shall not be liable directly or indirectly for permitting or continuing to allow an attachment of an Small On-Site Generation 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. 5. The Customer is responsible for all costs associated with the Generation Facility 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 Generation Facility in order to maintain a safe, reliable electrical system. 6. 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 Idaho Power Company First Revised Sheet No. 8-4 Cancels I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 8-4 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34046955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – June 1, 2018March 23, 2021 1221 West Idaho Street, Boise, Idaho construction or maintenance requirements, emergencies, or other critical operating conditions on its system. Idaho Power Company Third Fourth Revised Sheet No. 8-5 Cancels I.P.U.C. No. 29, Tariff No. 101 Second Third Revised Sheet No. 8-5 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34885955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – January 1, 2021March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 8 SMALL GENERAL SERVICE ON-SITE GENERATION (Continued) CONDITIONS OF PURCHASE AND SALE (Continued) 7. 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. 8. 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. 9. The Customer shall notify the Company immediately if an Small On-Site Generation Exporting System is permanently removed or disabled. Permanent removal or disablement for the purposes of this Schedule is any removal or disablement of an Small On-Site Generation 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 August 31 of each year. The non- summer season begins on September 1 of each year and ends on May 31 of each year. 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), and Schedule 98 (Residential and Small Farm Energy Credit). The following charges are subject to change upon Commission approval: Summer Non-summer Service Charge, per month $5.00 $5.00 Energy Charge, per kWh First 300 kWh 9.6908¢ 9.6908¢ All Additional kWh 11.5418¢ 10.1676¢ 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 Third Fourth Revised Sheet No. 8-5 Cancels I.P.U.C. No. 29, Tariff No. 101 Second Third Revised Sheet No. 8-5 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34885955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – January 1, 2021March 23, 2021 1221 West Idaho Street, Boise, Idaho Idaho Power Company I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 68-1 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – March 23, 2021 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. Non- Exporting Systems 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. 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 I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 68-2 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – March 23, 2021 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 I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 68-3 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – March 23, 2021 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 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 I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 68-4 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – March 23, 2021 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, 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 I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 68-5 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – March 23, 2021 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” 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. 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. 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 Generation Facility are deemed by the Company to be in default or delinquent. Idaho Power Company I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 68-6 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 68 INTERCONNECTIONS TO CUSTOMER DISTRIBUTED ENERGY RESOURCES (Continued) SECTION 1: GENERAL INTERCONNECTION REQUIREMENTS (Continued) DISCONNECTION EQUIPMENT (Continued) 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 Customer Generator Systems less than 3 MVA are described further in Section 2 of this tariff. Disconnection provisions specific to Non-Exporting Systems greater than 3 MVA are described further in Section 4 of this tariff. 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, 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. INVERTER REQUIREMENTS All inverter-based Customer Generator Systems must use a Smart Inverter programmed with the required settings described in the following section. Idaho Power Company I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 68-7 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 68 INTERCONNECTIONS TO CUSTOMER DISTRIBUTED ENERGY RESOURCES (Continued) SECTION 1: GENERAL INTERCONNECTION REQUIREMENTS (Continued) 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. Table 1: VOLTAGE-REACTIVE POWER SETTINGS FOR SMART INVERTERS Voltage-reactive power parameters Default Settings V1 0.92% per unit of nominal voltage Q1 44% of nameplate apparent power rating, injecting V2 0.98%per unit of nominal voltage Q2 0 V3 1.03%per unit of nominal voltage Q3 0 V4 1.06%per unit of nominal voltage Q4 44% of nameplate apparent power rating, absorption Open-loop response time 5 seconds ENERGY STORAGE DEVICE Energy Storage Devices may share an inverter with a Generation Facility (“DC Coupled”), or Energy Storage Devices may have a stand-alone inverter (“AC Coupled”). Energy Storage Devices that are not coupled with a Generation Facility taking service under Schedules 6, 8, or 84 may not export energy onto Idaho Power’s system. The Total Nameplate Capacity is determined as follows: 1. DC Coupled: For Energy Storage Devices that are DC Coupled with a Generation Facility, the Total Nameplate Capacity of the Customer Generator System is defined by the inverter (kVA). A DC coupled system can be an Exporting or Non-Exporting system. 2. AC Coupled: i. AC Coupled with an Exporting System: For an Energy Storage Device coupled with an Exporting System taking service under Schedules 6, 8, or 84, the Total Nameplate Capacity is the aggregate Total Nameplate Capacity of all DERs on the Customer’s side of the Interconnection Point. ii. AC Coupled with a Non-Exporting System: An Energy Storage Device coupled with a Non-Exporting System is subject to the provisions of Section 3 of this Schedule. The Total Nameplate Capacity of the Energy Storage Device shall be considered 0 kVA. Idaho Power Company I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 68-8 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 68 INTERCONNECTIONS TO CUSTOMER DISTRIBUTED ENERGY RESOURCES (Continued) SECTION 1: GENERAL INTERCONNECTION REQUIREMENTS (Continued) 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 tariff. 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. Idaho Power Company I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 68-9 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – March 23, 2021 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 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. 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. Idaho Power Company I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 68-10 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – March 23, 2021 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 The following section is applicable to all Customer Generators 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 provide the Customer with a written or electronic notification that the application has been received and all necessary information has been provided. 3. The Company will perform within seven (7) business days, unless it is determined that additional studies are necessary, the Feasibility Review based on 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. 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. Idaho Power Company I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 68-11 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – March 23, 2021 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) 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. 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. 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. Idaho Power Company I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 68-12 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – March 23, 2021 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) 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. h. Verification of Total Nameplate Capacity. 7. A return trip charge of $61.00 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. 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 written notice from the Customer indicating Customer’s Generation System meets all applicable federal, state, and local requirements and is suitable for connection. Idaho Power Company I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 68-13 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 68 INTERCONNECTIONS TO CUSTOMER DISTRIBUTED ENERGY RESOURCES (Continued) 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. NON-EXPORT CONTROL SYSTEM 1. Non-Export Systems must incorporate one of the following three options: a. Option 1: (“Advanced Functionality”): The use of an internal transfer relay, Energy Management System, or other customer facility hardware or software system(s) may be used to ensure power is never exported across the Interconnection Point. To ensure that Inadvertent Export of power is limited to acceptable levels, all of the following conditions must be met: (a) inverter-based DERs must utilize a Smart Inverter; (b) the DER must monitor the total Inadvertent Export; (c) the DER must disconnect from the Company’s distribution system or halt energy production within two seconds after the period of continuous Inadvertent Export exceeds 30 seconds; (d) the DER must enter a safe operating mode where Inadvertent Export will not occur as a result of a failure of the control or Smart Inverter system for more than 30 seconds, which results in loss of control signal, loss of control power or single component failure or related control sensing of the control circuitry. b. Option 2: (“Reverse Power Protection”): To ensure power is never exported, a reverse power relay protective function must be implemented at the Interconnection Point. The default setting for this Protection Equipment, when used, shall be 0.1% (export) of the DERs Total Nameplate Capacity, with a maximum 2.0 second time delay. 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. Idaho Power Company I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 68-14 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – March 23, 2021 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 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. 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 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 I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 68-15 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 68 INTERCONNECTIONS TO CUSTOMER DISTRIBUTED ENERGY RESOURCES (Continued) SECTION 4: ADDITIONAL INTERCONNECTION REQUIREMENTS OF NON-EXPORTING SYSTEMS 3 MVA OR GREATER In addition to Section 1 and 3, the following section is applicable to all Customers requesting interconnection of Non-Exporting Systems 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 I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 68-16 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 68 INTERCONNECTIONS TO CUSTOMER DISTRIBUTED ENERGY RESOURCES (Continued) SECTION 4: ADDITIONAL INTERCONNECTION REQUIREMENTS OF NON-EXPORTING SYSTEMS 3 MVA OR GREATER (Continued) CUSTOMER GENERATOR INTERCONNECTION PROCESS (Continued) c. The Facility Study: The Facility Study includes the engineering to determine the design specifications of the project. The Facility Study Agreement includes a deposit of 5% of the total project costs that were determined in the System Impact Study Report (“SISR”) or the Feasibility Study Report if a SISR is not required, capped at $30,000. At the end of each stage of the three-step study process, the Company will provide the Customer Generator with an increasingly more refined and detailed report that, among other things, will present a list of required Interconnection Facilities and a non-binding, good faith estimate of Customer Generator’s cost responsibility for the Interconnection Facilities. If long-lead-time equipment items need to be ordered to meet Customer Generator’s construction schedule, the Company will request advance funding by the Customer Generator to cover these equipment costs. 5. Customer Generator Interconnection Agreement. The Customer Generator Interconnection Agreement (“CGIA”), will be offered to the Customer Generator following completion of the Study Phase. The CGIA will utilize the Uniform Customer Generator Interconnection Agreement template included in this schedule. INTERCONNECTION FACILITIES REQUIREMENTS DER greater than 3 MVA Total Nameplate Capacity will require additional Company-Furnished Protection, Metering, and communications Equipment. This equipment will be further defined in the CGIA Attachment 1. Idaho Power Company I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 68-17 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 68 INTERCONNECTIONS TO CUSTOMER DISTRIBUTED ENERGY RESOURCES (Continued) SECTION 4: ADDITIONAL INTERCONNECTION REQUIREMENTS OF NON-EXPORTING SYSTEMS 3 MVA OR GREATER (Continued) COST OF INTERCONNECTION FACILITIES The Customer Generator will pay all costs of interconnecting a Generation Facility 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. 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 I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 68-18 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 68 INTERCONNECTIONS TO CUSTOMER DISTRIBUTED ENERGY RESOURCES (Continued) SECTION 4: ADDITIONAL INTERCONNECTION REQUIREMENTS OF NON-EXPORTING SYSTEMS 3 MVA OR GREATER (Continued) 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. 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. Idaho Power Company I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 68-19 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 68 INTERCONNECTIONS TO CUSTOMER DISTRIBUTED ENERGY RESOURCES (Continued) SECTION 4: ADDITIONAL INTERCONNECTION REQUIREMENTS OF NON-EXPORTING SYSTEMS 3 MVA OR GREATER (Continued) IDAHO POWER COMPANY UNIFORM CUSTOMER GENERATOR INTERCONNECTION AGREEMENT (Continued) AGREEMENT (Continued) 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. 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. Idaho Power Company I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 68-20 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 68 INTERCONNECTIONS TO CUSTOMER DISTRIBUTED ENERGY RESOURCES (Continued) SECTION 4: ADDITIONAL INTERCONNECTION REQUIREMENTS OF NON-EXPORTING SYSTEMS 3 MVA OR GREATER (Continued) IDAHO POWER COMPANY UNIFORM CUSTOMER GENERATOR INTERCONNECTION AGREEMENT (Continued) AGREEMENT (Continued) 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. 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. Idaho Power Company I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 68-21 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 68 INTERCONNECTIONS TO CUSTOMER DISTRIBUTED ENERGY RESOURCES (Continued) SECTION 4: ADDITIONAL INTERCONNECTION REQUIREMENTS OF NON-EXPORTING SYSTEMS 3 MVA OR GREATER (Continued) IDAHO POWER COMPANY UNIFORM CUSTOMER GENERATOR INTERCONNECTION AGREEMENT (Continued) AGREEMENT (Continued) 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. 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. Idaho Power Company I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 68-22 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 68 INTERCONNECTIONS TO CUSTOMER DISTRIBUTED ENERGY RESOURCES (Continued) SECTION 4: ADDITIONAL INTERCONNECTION REQUIREMENTS OF NON-EXPORTING SYSTEMS 3 MVA OR GREATER (Continued) IDAHO POWER COMPANY UNIFORM CUSTOMER GENERATOR INTERCONNECTION AGREEMENT (Continued) AGREEMENT (Continued) 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. 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: Idaho Power Company I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 68-23 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 68 INTERCONNECTIONS TO CUSTOMER DISTRIBUTED ENERGY RESOURCES (Continued) SECTION 4: ADDITIONAL INTERCONNECTION REQUIREMENTS OF NON-EXPORTING SYSTEMS 3 MVA OR GREATER (Continued) IDAHO POWER COMPANY UNIFORM CUSTOMER GENERATOR INTERCONNECTION AGREEMENT (Continued) AGREEMENT (Continued) 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. 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. Idaho Power Company I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 68-24 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 68 INTERCONNECTIONS TO CUSTOMER DISTRIBUTED ENERGY RESOURCES (Continued) SECTION 4: ADDITIONAL INTERCONNECTION REQUIREMENTS OF NON-EXPORTING SYSTEMS 3 MVA OR GREATER (Continued) IDAHO POWER COMPANY UNIFORM CUSTOMER GENERATOR INTERCONNECTION AGREEMENT (Continued) AGREEMENT (Continued) 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 I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 68-25 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 68 INTERCONNECTIONS TO CUSTOMER DISTRIBUTED ENERGY RESOURCES (Continued) SECTION 4: ADDITIONAL INTERCONNECTION REQUIREMENTS OF NON-EXPORTING SYSTEMS 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 I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 68-26 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 68 INTERCONNECTIONS TO CUSTOMER DISTRIBUTED ENERGY RESOURCES (Continued) SECTION 4: ADDITIONAL INTERCONNECTION REQUIREMENTS OF NON-EXPORTING SYSTEMS 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 I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 68-27 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 68 INTERCONNECTIONS TO CUSTOMER DISTRIBUTED ENERGY RESOURCES (Continued) SECTION 4: ADDITIONAL INTERCONNECTION REQUIREMENTS OF NON-EXPORTING SYSTEMS 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 I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 68-28 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 68 INTERCONNECTIONS TO CUSTOMER DISTRIBUTED ENERGY RESOURCES (Continued) SECTION 4: ADDITIONAL INTERCONNECTION REQUIREMENTS OF NON-EXPORTING SYSTEMS 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 Third Fourth Revised Sheet No. 72-1 Cancels I.P.U.C. No. 29, Tariff No. 101Second Third Revised Sheet No. 72-1 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 3404634955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – June 1, 2018March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 72 INTERCONNECTIONS TOGENERATOR INTERCONNECTIONS NON-UTILITY GENERATION TO PURPA QUALIFYING FACILITY SELLERS AVAILABILITY Service under this schedule is available throughout the Company's service area within the State of Idaho to Sellers owning or operating Qualifying Facilities that sign a Uniform Interconnection Agreement or Generation Facilities that qualify for Schedule 6, Schedule 8, or Schedule 84. Generation Facilities that qualify for Schedule 6, Schedule 8, or Schedule 84 are not required to sign a Uniform Interconnection Agreement. The interconnection procedures and requirements for customer-owned generation facilities, including those that qualify for Schedule 6, Schedule 8, Schedule 84 or non-export customer generation are governed by Schedule 68. APPLICABILITY Service under this schedule applies to the construction, operation, maintenance, Upgrade, Relocation, or removal of transmission and/or distribution lines and equipment necessary to safely interconnect a Seller's Generation Facility to the Company's system. DEFINITIONS Additional Applicant is a person or entity whose request for electrical connection requires the Company to utilize existing Interconnection Facilities which are subject to a Vested Interest. Company is the Idaho Power Company. Connected Load is the combined input rating of the Customer's motors and other energy consuming devices. Construction Cost is the cost, as determined by the Company, of Upgrades, Relocation or construction of Company furnished Interconnection Facilities. 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 Seller to the Company's system, including enclosures or other equipment as may be required to ensure that only the Company will have access to certain of the devices. First Energy Date is the date when the Seller begins delivering energy to the Company's system. Generation Facility means equipment used to produce electric energy at a specific physical location which meets the requirements to be a Qualifying Facility or that qualifies for Schedule 6, Schedule 8, or Schedule 84. Generator Interconnection Process is the Company’s Generation Facility interconnection application, engineering review and construction process. The intent of the Generator Interconnection Process is to ensure a safe and reliable generation interconnection in compliance with all applicable regulatory requirements, good utility practices and national safety standards. Idaho Power Company Third Fourth Revised Sheet No. 72-1 Cancels I.P.U.C. No. 29, Tariff No. 101Second Third Revised Sheet No. 72-1 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 3404634955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – June 1, 2018March 23, 2021 1221 West Idaho Street, Boise, Idaho Interconnection Facilities are all facilities which are reasonably required by good utility practices and the National Electric Safety Code to interconnect and to allow the delivery of energy from the Seller's Generation Facility to the Company's system, including, but not limited to, Special Facilities, Disconnection Equipment and Metering Equipment. Idaho Power Company Third Fourth Revised Sheet No. 72-2 Cancels I.P.U.C. No. 29, Tariff No. 101Second Third Revised Sheet No. 72-2 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 3404634955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – June 1, 2018March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 72 INTERCONNECTIONS TOGENERATOR INTERCONNECTIONS NON-UTILITY GENERATION TO PURPA QUALIFYING FACILITY SELLERS (Continued) DEFINITIONS (Continued) Interconnection Facilities are all facilities which are reasonably required by good utility practices and the National Electric Safety Code to interconnect and to allow the delivery of energy from the Seller's Generation Facility to the Company's system, including, but not limited to, Special Facilities, Disconnection Equipment and Metering Equipment. Interconnection Point is the point where the Seller’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 Seller's Generation Facility and the Company's system. Feasibility Review is the Company’s standard engineering review of proposed Net Metering Systems or Small On-Site Generation Systems. This review is intended to ensure that the Company’s system is sufficiently equipped to incorporate proposed Net Metering Systems or Small On-Site Generation Systems in a manner that conforms with good utility practices and the National Electric Safety Code. Net Metering Service is the Company’s service which provides for transfer of electric energy to the Company by means of a net metering arrangement or its successor(s) as approved by the Commission. This optional service provides for Customers to install Generation Facilities to interconnect to the Company’s system to offset all or a portion of their electrical usage. This service is comprised of all customers taking service under Schedule 84. Net Metering System is a Customer-owned Generation Facility interconnected to the Company’s system under the terms of Schedule 84. OATT is the Company’s Federal Energy Regulatory Commission (FERC) approved Open Access Transmission Tariff. Protection Equipment is the circuit-interrupting device, protective relaying, and associated instrument transformers. PURPA means the Public Utility Regulatory Policies Act of 1978. Qualifying Facility is a cogeneration facility or a small power production facility which meets the PURPA criteria for qualification set forth in Subpart B of Part 292, Subchapter K, Chapter I, Title 18, of the Code of Federal Regulations. Relocation is a change in the location of existing Company-owned transmission and/or distribution lines, poles or equipment. Idaho Power Company Third Fourth Revised Sheet No. 72-2 Cancels I.P.U.C. No. 29, Tariff No. 101Second Third Revised Sheet No. 72-2 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 3404634955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – June 1, 2018March 23, 2021 1221 West Idaho Street, Boise, Idaho Seller is a non-utility generator who has contracted or will contract with the Company to interconnect a Generation Facility to the Company’s system to sell electric energy to the Company. Seller-Furnished Facilities are those portions of the Interconnection Facilities provided by the Seller. 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 Seller's Generation Facility to the Company's system. Transfer Cost is the cost, as determined by the Company, for acceptance by the Company of Seller-Furnished Facilities. Upgrades are those improvements to the Company's existing system which are reasonably required by good practices and the National Electric Safety Code to safely interconnect the Seller’s Generation Facility. Such improvements include, but are not limited to, additional or larger conductors, transformers, poles, and related equipment. Vested Interest is the claim for refund that a Seller or Additional Applicant holds in a specific portion of Company-owned Interconnection Facilities. The Vested Interest expires 5 years from the date the Company completes construction of its portion of the Interconnection Facilities unless fully refunded earlier. Idaho Power Company Third Fourth Revised Sheet No. 72-3 Cancels I.P.U.C. No. 29, Tariff No. 101Second Third Revised Sheet No. 72-3 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 3404634955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – June 1, 2018March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 72 INTERCONNECTIONS TOGENERATOR INTERCONNECTIONS NON-UTILITY GENERATIONTO PURPA QUALIFYING FACILITY SELLERS (Continued) DEFINITIONS (Continued) Seller is a non-utility generator who has contracted or will contract with the Company to interconnect a Generation Facility to the Company’s system to sell electric energy to the Company, or a Customer taking service under Schedule 6, Schedule 8, or Schedule 84. Seller-Furnished Facilities are those portions of the Interconnection Facilities provided by the Seller. Small On-Site Generation Service is the Company’s service which provides for transfer of electric energy to the Company by means of a Small On-Site Generation System as approved by the Commission. This optional service provides for Customers to install Generation Facilities to interconnect to the Company’s system to offset all or a portion of their electrical usage. This service is comprised of all customers taking service under Schedule 6 or Schedule 8. Small On-Site Generation System is a Customer-owned Generation Facility, with a total nameplate capacity rating of 25 kW or less, interconnected to the Company’s system under the terms of Schedule 6 or Schedule 8. 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 Seller's Generation Facility to the Company's system. System Verification Form is the form that a Customer must provide to the Company prior to the connection of Net Metering Service or Small On-Site Generation Service as described in Section 2 of this schedule. Transfer Cost is the cost, as determined by the Company, for acceptance by the Company of Seller-Furnished Facilities. Upgrades are those improvements to the Company's existing system which are reasonably required by good practices and the National Electric Safety Code to safely interconnect the Seller’s Generation Facility. Such improvements include, but are not limited to, additional or larger conductors, transformers, poles, and related equipment. Vested Interest is the claim for refund that a Seller or Additional Applicant holds in a specific portion of Company-owned Interconnection Facilities. The Vested Interest expires 5 years from the date the Company completes construction of its portion of the Interconnection Facilities unless fully refunded earlier. SECTION 1: GENERAL INTERCONNECTION REQUIREMENTS The following provisions apply to all Sellers requesting interconnection to the Company’s system. Idaho Power Company Third Fourth Revised Sheet No. 72-3 Cancels I.P.U.C. No. 29, Tariff No. 101Second Third Revised Sheet No. 72-3 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 3404634955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – June 1, 2018March 23, 2021 1221 West Idaho Street, Boise, Idaho CONSTRUCTION AND OPERATION OF INTERCONNECTION FACILITIES All Seller-Furnished Interconnection Facilities will be constructed and maintained in a manner to be in full compliance with all good utility practices, National Electric Safety Code, and all other applicable federal, state, and local safety and electrical codes and standards at all times. The Seller shall: 1. Submit proof to the Company that all licenses, permits, inspections, and approvals necessary for the construction and operation of the Seller's Generation and Interconnection Facilities under this schedule have been obtained from applicable federal, state, or local authorities. 2. Submit the designs, plans, specifications, and performance data for the Generation Facility and Seller-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 Generation Facility or Seller-Furnished Facilities. The Company will retain the right to inspect this equipment at its discretion. 3. Demonstrate to the Company's satisfaction that the Seller's Generation Facility and Seller- Furnished Facilities have been completed, and that all features and equipment of the Seller’s Generation Facility and Seller-Furnished Facilities are capable of operating safely to commence deliveries of Energy into the Company's system. 4. Provide and maintain adequate protective equipment sufficient to prevent damage to the Generation Facility, Seller-Furnished Facilities and any other Seller-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. 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 Seller of such arrangements in advance. The Company will provide a telephone number to the Seller so that the Seller can obtain information about Company activity impacting the Seller’s facility. Idaho Power Company Third Fourth Revised Sheet No. 72-34 Cancels I.P.U.C. No. 29, Tariff No. 101Second Third Revised Sheet No. 72-43 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 3404634955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – June 1, 2018March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 72 INTERCONNECTIONS TO NON-UTILITY GENERATION (Continued) SECTION 1: GENERAL INTERCONNECTION REQUIREMENTS The following provisions apply to all Sellers requesting interconnection to the Company’s system. CONSTRUCTION AND OPERATION OF INTERCONNECTION FACILITIES All Seller-Furnished Interconnection Facilities will be constructed and maintained in a manner to be in full compliance with all good utility practices, National Electric Safety Code, and all other applicable federal, state, and local safety and electrical codes and standards at all times. The Seller shall: 1. Submit proof to the Company that all licenses, permits, inspections, and approvals necessary for the construction and operation of the Seller's Generation and Interconnection Facilities under this schedule have been obtained from applicable federal, state, or local authorities. 2. Submit the designs, plans, specifications, and performance data for the Generation Facility and Seller-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 Generation Facility or Seller-Furnished Facilities. The Company will retain the right to inspect this equipment at its discretion. 3. Demonstrate to the Company's satisfaction that the Seller's Generation Facility and Seller- Furnished Facilities have been completed, and that all features and equipment of the Seller’s Generation Facility and Seller-Furnished Facilities are capable of operating safely to commence deliveries of Energy into the Company's system. 4. Provide and maintain adequate protective equipment sufficient to prevent damage to the Generation Facility, Seller-Furnished Facilities and any other Seller-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. 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 Seller of such arrangements in advance. The Company will provide a telephone number to the Seller so that the Seller can obtain information about Company activity impacting the Seller’s facility. Idaho Power Company Third Fourth Revised Sheet No. 72-45 Cancels I.P.U.C. No. 29, Tariff No. 101Second Third Revised Sheet No. 72-45 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 3404634955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – June 1, 2018March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 72 INTERCONNECTIONS TOGENERATOR INTERCONNECTIONS NON-UTILITY GENERATIONTO PURPA QUALIFYING FACILITY SELLERS (Continued) SECTION 1: GENERAL INTERCONNECTION REQUIREMENTS (Continued) 5. Provide and maintain Disconnection Equipment in accordance with all applicable electrical and safety codes and requirements as described within this Schedule. 6. 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 Seller of such arrangements in advance. The Company will provide a telephone number to the Seller so that the Seller can obtain information about Company activity impacting the Seller’s facility. DISCONNECTION EQUIPMENT Disconnection Equipment is required for all Seller Generation Facilities. The Disconnection Equipment shall be installed at an electrical location to allow complete isolation of Seller’s Generation and Interconnection Facilities from the Company’s system. Disconnection Equipment for Net Metering Systems or Small On-Site Generation Systems will be installed at an electrical location on the Seller’s side of the Company’s retail metering point to allow complete isolation of the Seller’s Generation and Interconnection Facilities from the Seller’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” with permanent 3/8 inch or larger letters. 3. Physically installed at a location within 10 feet of the Interconnection Point or exact, permanent instructions posted at the Interconnection Point indicating the precise location of the Disconnection Equipment’s operating device. 4. Of a design manually operated and lockable in the open position with a standard Company padlock. 5. For Net Metering Systems under Schedule 84 or Small On-Site Generation Systems under Schedules 6 and 8, 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 visually inspect the actual conductors. Circuit breakers and/or switches do not satisfy this requirement if the conductors are not visible. Operation of Disconnection Equipment. If, in the reasonable opinion of the Company, the Seller's operation or maintenance of the Generation Facility or Interconnection Facilities is unsafe or may otherwise adversely affect the Company's equipment, personnel, or service to its customers, the Company may physically disconnect the Seller’s Generation Facility or Interconnection Facilities by operation of the disconnection device or by any other means the Company deems necessary to adequately disconnect the Seller’s Generation and Interconnection Facilities from the Company’s system. Idaho Power Company Third Fourth Revised Sheet No. 72-45 Cancels I.P.U.C. No. 29, Tariff No. 101Second Third Revised Sheet No. 72-45 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 3404634955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – June 1, 2018March 23, 2021 1221 West Idaho Street, Boise, Idaho 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 Seller’s Generation and Interconnection Facilities in the event of any planned or unplanned maintenance or repair of the Company’s system connected to the Seller’s Generation 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 Seller of the time and duration of the planned outage. The Company will disconnect the Seller’s Generation Facility and Interconnection Facilities in the event that any terms and conditions of any applicable Company tariff or contract enabling the interconnection of the Seller’s Generation Facility is deemed by the Company to be in default or delinquent. All expenses of disconnection and reconnection incurred by the Company will be billed to the Seller. Idaho Power Company Third Fourth Revised Sheet No. 72-56 Cancels I.P.U.C. No. 29, Tariff No. 101Second Third Revised Sheet No. 72-56 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 3404634955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – June 1, 2018March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 72 INTERCONNECTIONS TOGENERATOR INTERCONNECTIONS NON-UTILITY GENERATIONTO PURPA QUALIFYING FACILITY SELLERS (Continued) SECTION 1: GENERAL INTERCONNECTION REQUIREMENTS (Continued) DISCONNECTION EQUIPMENT (Continued) The Company will disconnect the Seller’s Generation Facility and Interconnection Facilities in the event that any terms and conditions of any applicable Company tariff or contract enabling the interconnection of the Seller’s Generation Facility is deemed by the Company to be in default or delinquent. All expenses of disconnection and reconnection incurred by the Company will be billed to the Seller. Net Metering Customers and Customers with Small On-Site Generation Systems will only be subject to disconnection and reconnection charges if the expenses are incurred as the result of a Customer’s Net Metering System or Small On-Site Generation Systems and/or a Customer’s failure to abide by the provisions of Schedule 72. In the case of Net Metering Systems or Small On-Site Generation Systems, disconnection of the service may be necessary. The disconnection may result in interruption of both energy deliveries from the Seller’s Generation Facility to the Company as well as interruption of energy deliveries from the Company to the Seller. Disconnection provisions specific to Customers taking service under Schedule 6, Schedule 8, or Schedule 84 are described further in Section 2 of this tariff. The Company will establish the settings of Protection Equipment to disconnect the Seller’s Generation Facility and Interconnection Facilities for the protection of the Company’s system and personnel consistent with good utility practices. If the Seller 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 Seller’s Generation and Interconnection Facilities to the Company’s system. GENERAL REQUIREMENTS OF INTERCONNECTED PROJECTS 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 Seller’s Generation Facility and/or Interconnection Facilities designating the existence of the Seller’s Generation Facility as required by good utility practices. 3. The Seller will be required to submit all specific designs, equipment specifications, and test results of the Seller-Furnished Facilities to the Company for review. 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. OPERATIONS AND MAINTENANCE OBLIGATIONS AND EXPENSES Idaho Power Company Third Fourth Revised Sheet No. 72-56 Cancels I.P.U.C. No. 29, Tariff No. 101Second Third Revised Sheet No. 72-56 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 3404634955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – June 1, 2018March 23, 2021 1221 West Idaho Street, Boise, Idaho The Company will operate and maintain Company furnished Interconnection Facilities, as well as any Seller-Furnished Facilities transferred to the Company. SECTION 2: INTERCONNECTION OF GENERATION FACILITIES The following section is applicable to all Sellers requesting interconnection of non-utility generation. SPECIFIC PROJECT REQUIREMENTS 1. Generation Facilities Less than 1 MW Nameplate Rating The following requirements are for Generation Facilities with nameplate ratings of less than 1 MW. Idaho Power Company Third Fourth Revised Sheet No. 72-7 Cancels I.P.U.C. No. 29, Tariff No. 101Second Third Revised Sheet No. 72-7 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 3404634955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – June 1, 2018March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 72 INTERCONNECTIONS TO NON-UTILITY GENERATION (Continued) SECTION 1: GENERAL INTERCONNECTION REQUIREMENTS (Continued) OPERATIONS AND MAINTENANCE OBLIGATIONS AND EXPENSES The Company will operate and maintain Company furnished Interconnection Facilities as well as any Seller-Furnished Facilities transferred to the Company. SECTION 2: INTERCONNECTION OF NET METERING OR SMALL ON-SITE GENERATION FACILITIES The following section is applicable to all Customers taking Net Metering Service under Schedule 84 and Customers taking Small On-Site Generation Service under Schedule 6 or Schedule 8. APPLICATION PROCESS Customers requesting Net Metering Service or Small On-Site Generation Service are required to complete the following application process prior to interconnection: 1. Customers must submit a completed application form and $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 provide the Customer with written or electronic mail notification that the application has been received and all necessary information has been provided. 3. The Company will perform within seven (7) business days the Feasibility Review based on project information provided in the application. The Feasibility Review for Net Metering Systems or Small On-Site Generation Service determines the capability of the Company’s electrical system to incorporate the proposed Net Metering System or Small On-Site Generation Service 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 via written or electronic mail. 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 mail 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. Idaho Power Company Third Revised Sheet No. 72-8 Cancels I.P.U.C. No. 29, Tariff No. 101 Second Revised Sheet No. 72-8 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34046 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – June 1, 2018 1221 West Idaho Street, Boise, Idaho SCHEDULE 72 INTERCONNECTIONS TO NON-UTILITY GENERATION (Continued) SECTION 2: INTERCONNECTION OF NET METERING OR SMALL ON-SITE GENERATION FACILITIES (Continued) APPLICATION PROCESS (Continued) 4. Following receipt of “Approval to Proceed” the Customer is responsible for completing the installation of the Net Metering System or Small On-Site Generation System and fulfilling all applicable federal, state, and local inspection requirements. Upon completion, the Customer must provide all forms of documentation outlined in Section 1-1 above verifying that all federal, state, and local requirements have been met. Customers must also provide the Company with a completed System Verification Form detailing the specifications of all installed components of the completed Net Metering System or Small On-Site Generation System. System Verification Forms can be found on the Company’s website or will be provided upon request. 5. Once all required documentation has been submitted and the Company has verified that all applicable federal, state, and local requirements have been met, the Company will complete, barring conditions beyond the Company’s control, an on-site inspection within ten (10) business days. Company on-site inspections will not be performed until the system has passed all applicable federal, state, and local inspection requirements as described above. The Company on-site inspection includes the following: a. Verification that actual installed components correspond to information provided on the initial application and the System Verification Form b. Verification that the disconnect is functional and reconnection time complies with IEEE Standard 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. Evaluation of inverters: i. Systems utilizing verifiable UL 1741 or IEEE 1547 inverters will not be subject to additional testing ii. Systems utilizing all inverters other than UL 1741 or IEEE 1547 will be subject to third-party testing performed at the Customer’s expense 6. Successful completion of the Company on-site inspection constitutes the conclusion of the application process. The Company must make a reasonable effort to move the Customer to the appropriate Net Metering Service or Small On-Site Generation Service 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 written or electronic mail confirmation that the application process has been successfully completed. Idaho Power Company Third Revised Sheet No. 72-9 Cancels I.P.U.C. No. 29, Tariff No. 101 Second Revised Sheet No. 72-9 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34046 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – June 1, 2018 1221 West Idaho Street, Boise, Idaho SCHEDULE 72 INTERCONNECTIONS TO NON-UTILITY GENERATION (Continued) SECTION 2: INTERCONNECTION OF NET METERING OR SMALL ON-SITE GENERATION FACILITIES (Continued) APPLICATION PROCESS (Continued) 7. In the event that a Net Metering System or a Small On-Site Generation System fails inspection, the system will be locked and a tag providing Company contact information will be placed on the device. A Company representative will then follow up via telephone with the Customer regarding the reason(s) for failure, and assist the Customer in steps needed to bring the system into compliance with inspection requirements. Once all issues have been addressed and the Customer indicates that the system has passed all applicable federal, state, and local requirements, Idaho Power will re-inspect the system. APPLICATION EXPIRATION 1. 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 above. RECERTIFICATION 1. The Company will perform full recertification inspections of all Net Metering Systems and Small On-Site Generation Systems once every three years at no charge to the Customer. The Company will provide the Customer 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 Net Metering System and Small On-Site Generation Systems inspections described above. 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’s expense. The Company reserves the right to inspect any Net Metering System and Small On-Site Generation Systems at any time if conditions are unsafe or may otherwise adversely affect the Company’s equipment, personnel, or service to its Customers. SYSTEM EXPANSIONS 1. Any modifications to Net Metering Systems or Small On-Site Generation Systems that impact the generation capacity of the system or modify the system in any way that may impact the safety or reliability of the Company’s electrical system are considered system expansions for the purposes of this tariff. 2. Customers wishing to install system expansions must submit an application form and a $100 feasibility review and inspection fee, and complete the application process according to the procedures required for a new installation. 3. Systems that have been expanded in the manner described above without gaining prior Company approval are considered unauthorized installations subject to the provisions of this schedule described below. Idaho Power Company Third Revised Sheet No. 72-10 Cancels I.P.U.C. No. 29, Tariff No. 101 Second Revised Sheet No. 72-10 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34046 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – June 1, 2018 1221 West Idaho Street, Boise, Idaho SCHEDULE 72 INTERCONNECTIONS TO NON-UTILITY GENERATION (Continued) SECTION 2: INTERCONNECTION OF NET METERING OR SMALL ON-SITE GENERATION FACILITIES (Continued) UNAUTHORIZED INSTALLATIONS AND EXPANSIONS 1. Net Metering Systems and Small On-Site Generation 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 of approved systems. The process described herein provides the Company the ability to offer Net Metering Service and Small On-Site Generation Systems in an efficient, safe, and reliable manner. 2. Unauthorized installations are subject to immediate Company inspection without notice. a. If proper disconnection equipment is present, the Company will open and lock the disconnect. When the system is disconnected, the Company will leave a tag on the system providing the reason for disconnection and Company contact information. A door hanger or card will also be left at the front door at the time of disconnection. Within twenty-four (24) hours of the disconnection, the Customer will be called and written notification will be sent via U.S. Mail. Upon completion of the full application process the system will be reinstated. b. If proper disconnection equipment is not present, the Company will evaluate installed inverters: i. If the system utilizes UL 1741 or IEEE 1547 inverters, the Company will contact the Customer either in person or via telephone in addition to written communication regarding the unauthorized installation. This communication will include the necessary steps to bring the system into compliance according to the following procedures: 1. Within fifteen (15) days of notification, the Customer must submit a completed application and $100 fee. 2. Within thirty (30) days of completion of the Feasibility Review, the Customer must complete the remainder of the inspection requirements described above. 3. Customers who do not wish to bring their systems into compliance with this schedule may choose to disable their systems. Customers choosing to do so must notify the Company of their decision within thirty (30) days of receiving the initial Company notification regarding the unauthorized installation. Idaho Power Company Third Fourth Revised Sheet No. 72-117 Cancels I.P.U.C. No. 29, Tariff No. 101Second Third Revised Sheet No. 72-117 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 3404634955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – June 1, 2018March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 72 INTERCONNECTIONS TO NON-UTILITY GENERATION (Continued) SECTION 2: INTERCONNECTION OF NET METERING OR SMALL ON-SITE GENERATION FACILITIES (Continued) UNAUTHORIZED INSTALLATIONS AND EXPANSIONS (Continued) 4. Customers that fail to complete the application process within the allotted timeframe and/or do not disable their systems within thirty (30) days will be subject to termination of electric service. ii. If the system utilizes inverters other than UL 1741 or IEEE 1547, or if the presence of UL 1741 or IEEE 1547 inverters cannot be verified, the Customer will be subject to immediate termination of service without notice. 3. Customers subject to termination of service under this Schedule are provided two options for restoration of service. Under both options Customers are responsible for reconnection costs per the Company’s standard fees contained in Schedule 66. a. Customers may choose to permanently disconnect Net Metering Systems or Small On-Site Generation Systems from service. Permanent disconnection must, at a minimum, include the physical removal of Interconnection Facilities at the associated Generation Interconnection Point or physical removal of the General Facility itself. Opening a breaker or switch does not constitute permanent disconnection. Customers choosing to permanently disconnect their Net Metering System or Small On-Site Generation System must receive confirmation from a state electrical inspector that the Net Metering System or Small On-Site Generation System is no longer operational and interconnected to the Company’s system. The results of this inspection must be provided to the Company prior to restoration of service. b. Customers can bring the system into compliance with the provisions of this schedule by completing the full application process described above. SECTION 3SECTION 2: INTERCONNECTION OF GENERATION FACILITIES OTHER THAN NET METERING AND SMALL ON-SITE GENERATION FACILITIES The following section is applicable to all Sellers requesting interconnection of non-utility generation not taking service under Schedule 6, Schedule 8, or Schedule 84. SPECIFIC PROJECT REQUIREMENTS 1. Generation Facilities Less than 1 MW Nameplate Rating The following requirements are for Generation Facilities with nameplate ratings of less than 1 MW. Idaho Power Company Third Fourth Revised Sheet No. 72-126 Cancels I.P.U.C. No. 29, Tariff No. 101Second Third Revised Sheet No. 72-126 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 3404634955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – June 1, 2018March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 72 INTERCONNECTIONS TOGENERATOR INTERCONNECTIONS NON-UTILITY GENERATIONTO PURPA QUALIFYING FACILITY SELLERS (Continued) SECTION 2: INTERCONNECTION OF GENERATION FACILITIES (Continued) SECTION 3SECTION 2: INTERCONNECTION OF GENERATION FACILITIES OTHER THAN NET METERING AND SMALL ON-SITE GENERATION FACILITIES (Continued) SPECIFIC PROJECT REQUIREMENTS (Continued) SPECIFIC PROJECT REQUIREMENTS (Continued) a. The Company shall procure, install, own and maintain Metering Equipment to record energy deliveries to the Company. This metering will be separate from any other metering of the Seller’s load and may be located on either side of the Interconnection Point. All acquisition, installation, maintenance, inspection and testing costs related to Meter Equipment installed to measure the Seller’s energy deliveries to the Company shall be borne by the Seller. b. The Seller is responsible for all costs incurred by the Company for the review, evaluation and testing of Seller supplied designs and equipment regardless as to the outcome of the review or test results. c. The Seller, upon completion of installation and prior to interconnection of the Generation Facility to the Company’s system, will provide the Company with certification from a professional engineer licensed in the State of Idaho stating that the Seller’s Generation Facility and Interconnection Facilities are in compliance with IEEE Standard 1547 and all applicable electrical and safety codes to enable safe and reliable operation. d. The Seller will obtain and provide to the Company an annual certification and testing by a professional engineer licensed in the State of Idaho, certifying the ongoing compliance with IEEE Standard 1547 and all applicable electrical and safety codes and that the Seller-Furnished Facilities successfully meet applicable testing requirements and standards. In the event the Company does not receive and accept the annual certification within thirty (30) days of the annual anniversary date of the agreement, the project will be disconnected from the Company’s system until such time as the certification is completed and accepted by the Company. e. In addition to the requirements specified in sections a through d, Generation Facilities that are greater than 100 kW and less than 1 MW total nameplate rating require the following: i. If the Company owns the transformer interconnecting the Seller’s Generation Facility, then the Seller may own and maintain a secondary voltage disconnection device that can be operated by both the Seller and the Company. ii. If the Seller owns the transformer interconnecting the Seller’s Generation Facility, then the Company will own, operate and maintain a primary voltage disconnection device at the Seller’s expense. iii. The Company will construct, own, operate and maintain all protective relays and any associated equipment required to operate the protective relays. 2. Generation Facilities Greater Than 1 MW Nameplate Rating Idaho Power Company Third Fourth Revised Sheet No. 72-126 Cancels I.P.U.C. No. 29, Tariff No. 101Second Third Revised Sheet No. 72-126 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 3404634955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – June 1, 2018March 23, 2021 1221 West Idaho Street, Boise, Idaho The Company will own, maintain and operate all Interconnection Facilities and Disconnection Equipment at the Seller’s expense. Idaho Power Company Third Fourth Revised Sheet No. 72-137 Cancels I.P.U.C. No. 29, Tariff No. 101Second Third Revised Sheet No. 72-137 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 3404634955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – June 1, 2018March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 72 INTERCONNECTIONS TOGENERATOR INTERCONNECTIONS NON-UTILITY GENERATIONTO PURPA QUALIFYING FACILITY SELLERS (Continued) SECTION 3SECTION 2: INTERCONNECTION OF GENERATION FACILITIES OTHER THAN NET METERING AND SMALL ON-SITE GENERATION FACILITIES (Continued) GENERATOR INTERCONNECTION PROCESS 1. Seller 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 Seller, 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 Generator Interconnection Process. 3. The deposit amounts for Generation Facilities up to 30 MW are specified in this schedule. Deposit amounts for Generation Facilities 30 MW and larger are covered by the FERC-approved Large Generator Interconnection Procedures posted on the Company’s website. 4. Application. The Seller will submit a completed interconnection application in the form posted on the Company’s website. The application form includes a general description of the Generation Facility 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 for a Generation Facility up to 30 MW. 5. Study Agreements. If the Seller desires to proceed beyond the Application stage, the Seller will be offered a series of study agreements. The individual study agreements establish the time to perform the study and the deposit the Seller is to provide prior to commencement of the study. The deposit amount may be waived if a Seller meets the Company’s credit worthiness standards for unsecured credit specified in Attachment L to the Company’s OATT. The studies consist of: a. The Feasibility Study: The Feasibility Study includes a general review of project impact, e.g. exceeding equipment capabilities and violation of electrical performance requirements. The Feasibility Study Agreement states that no deposit is required, since the deposit is covered by the application fee. b. The System Impact Study: The System Impact Study provides a detailed assessment of the distribution and/or transmission system adequacy to accommodate the Generation Facility 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 Third Fourth Revised Sheet No. 72-148 Cancels I.P.U.C. No. 29, Tariff No. 101Second Third Revised Sheet No. 72-148 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 3404634955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – June 1, 2018March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 72 INTERCONNECTIONS TOGENERATOR INTERCONNECTIONS NON-UTILITY GENERATIONTO PURPA QUALIFYING FACILITY SELLERS (Continued) SECTION 3SECTION 2: INTERCONNECTION OF GENERATION FACILITIES OTHER THAN NET METERING AND SMALL ON-SITE GENERATION FACILITIES (Continued) GENERATOR INTERCONNECTION PROCESS (Continued) c. The Facility Study: The Facility Study includes the engineering to determine the design specifications of the project. The Facility Study Agreement includes a deposit of 5% of the total project costs that were determined in the System Impact Study Report (“SISR”) or the Feasibility Study Report if a SISR is not required, capped at $30,000. At the end of each stage of the three-step study process, the Company will provide the Seller 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 Seller’s cost responsibility for the Interconnection Facilities. If long-lead time equipment items need to be ordered to meet Seller’s construction schedule, the Company will request advance funding by the Seller to cover these equipment costs. 6. Generator Interconnection Agreement. The Generator Interconnection Agreement (“GIA”), will be offered to Seller following completion of the Facility Study. The GIA will utilize the Uniform Interconnection Agreement template included in this schedule. COST OF INTERCONNECTION FACILITIES All Interconnection Facilities provided under this schedule will be valued at the Company's Construction Cost and/or the Transfer Cost for vesting purposes, as well as for operation and maintenance payment obligations. PAYMENT FOR INTERCONNECTION FACILITIES Unless specifically agreed otherwise by written agreement between the Seller and the Company, the Seller will pay all costs of interconnecting a Generation Facility to the Company's system. Costs of interconnection include the costs of furnishing and constructing required Interconnection Facilities, including Upgrades. Each request for interconnection will go through the Generator Interconnection Process. Throughout the Generator Interconnection Process, the Company will periodically bill the Seller for costs incurred or obligated. Failure to pay an invoice within the time specified in the invoice will result in suspension of work on the interconnection and if the suspension of work extends beyond thirty (30) calendar days, the Generation Facility will be removed from the interconnection queue. Seller can end the Generator Interconnection Process at any time. If Seller decides to end the 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 Seller for costs incurred prior to cancellation. Idaho Power Company Third Fourth Revised Sheet No. 72-159 Cancels I.P.U.C. No. 29, Tariff No. 101Second Third Revised Sheet No. 72-159 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 3404634955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – June 1, 2018March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 72 INTERCONNECTIONS TOGENERATOR INTERCONNECTIONS NON-UTILITY GENERATIONTO PURPA QUALIFYING FACILITY SELLERS (Continued) SECTION 3SECTION 2: INTERCONNECTION OF GENERATION FACILITIES OTHER THAN NET METERING AND SMALL ON-SITE GENERATION FACILITIES (Continued) SECURITY FOR PAYMENT OF INTERCONNECTION COSTS Sellers will provide adequate security for payment of the costs of the Generator Interconnection Process. Adequate security for Generation Facilities larger than 30 MW can be provided in accordance with the Large Generator Interconnection Procedures contained in Attachment M to the Company’s OATT. Adequate security for Generation Facilities up to 30 MW can be provided in one of the following ways 1. Sellers that meet the Company’s credit worthiness standards for unsecured credit are not required to provide additional security. The Company’s minimum credit standards for unsecured credit are described in Attachment L to the OATT. 2. Sellers that do not meet the credit worthiness standards for unsecured credit will be notified of the reason for the determination and shall be given the option to provide alternative security acceptable to Idaho Power. In lieu of providing a cash deposit, Seller may establish an escrow account, provide a letter of credit or provide guarantee of payment by another person or entity which meets the credit worthiness standards for unsecured credit. Arrangements for alternative security must be acceptable to Idaho Power. TRANSFER OF INTERCONNECTION FACILITIES Transfer of Interconnection Facilities is available only for Generation Facilities with nameplate ratings greater than 100 kW. 1. Transfer at First Energy Date. If the Seller desires to transfer and the Company desires to accept any Seller-Furnished Facilities at the First Energy Date, the following will apply: a. Prior to the beginning of construction, the Seller shall cause the contractor that is constructing the Seller-Furnished Facilities to provide the Company with a certificate naming the Company as an additional insured in the amount of not less than $1,000,000 under the contractor's general liability policy. b. The Company will provide the Seller's contractor with construction and material specifications and will have final approval of the design of the Seller-Furnished Facilities. c. During construction and upon completion, the Company will inspect the Seller- Furnished Facilities to be transferred to the Company. The cost of such inspection will be borne by the Seller. Idaho Power Company Third Fourth Revised Sheet No. 72-1610 Cancels I.P.U.C. No. 29, Tariff No. 101Second Third Revised Sheet No. 72-1610 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 3404634955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – June 1, 2018March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 72 INTERCONNECTIONS TOGENERATOR INTERCONNECTIONS NON-UTILITY GENERATIONTO PURPA QUALIFYING FACILITY SELLERS (Continued) SECTION 3SECTION 2: INTERCONNECTION OF GENERATION FACILITIES OTHER THAN NET METERING AND SMALL ON-SITE GENERATION FACILITIES (Continued) TRANSFER OF INTERCONNECTION FACILITIES (Continued) d. If the Seller-Furnished Facilities meet the Company's design, material and construction specifications, are free from defects in materials and workmanship, and the Seller has provided the Company with acceptable easements, bills of sale and assurance against labor or materials liens, the Company will accept ownership effective as of the First Energy Date. In the bill of sale, the Seller will warrant to the Company that the Seller-Furnished Facilities are free of any liens or encumbrances and will be free from any defects in materials and workmanship for a period of one year from the First Energy Date. 2. Subsequent Transfer. If, after the First Energy Date, the Seller desires to transfer and the Company desires to accept any Seller-Furnished Facilities, the following will apply: a. The Company will inspect the facilities proposed for sale to determine if they meet the Company's design, material and construction specifications. b. The Company will determine the Transfer Cost of such facilities. The Transfer Cost will be equal to the depreciated Construction Cost the Company would have incurred if it had originally constructed the facilities plus the cost, if any, of bringing the facilities into compliance with the Company's design, material and construction specifications. Depreciation of the facilities proposed for transfer will be determined on the same basis as the Company depreciates its own facilities in accordance with the appropriate FERC account numbers for the type and size of line or equipment involved. The time period used for the calculation of the depreciated transfer cost will extend from the First Energy Date until the agreed upon transfer date. The Transfer Cost will be paid to the Company in cash at the time of transfer. At the same time, the Company will pay the Seller in cash an amount equal to the depreciated Construction Cost. c. As a condition of the Company's acceptance, the Seller will provide the Company with acceptable easements, bills of sale and acceptable assurance against labor and material liens. The bill of sale will include a warranty that the transferred facilities are free of all liens and encumbrances and will be free from any defects in materials and workmanship for a period of one year from the date of transfer. d. Effective as of the date of the transfer, the Company will operate and maintain the transferred facilities. VESTED INTEREST A Seller's eligibility for a Vested Interest refund will exist for 5 years after the date the Company completes construction of its portion of the Interconnection Facilities. Idaho Power Company Fourth Fourth Revised Sheet No. 72-1711 Cancels I.P.U.C. No. 29, Tariff No. 101Third Third Revised Sheet No. 72-1711 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 3404634955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – June 1, 2018March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 72 INTERCONNECTIONS TOGENERATOR INTERCONNECTIONS NON-UTILITY GENERATIONTO PURPA QUALIFYING FACILITY SELLERS (Continued) SECTION 3SECTION 2: INTERCONNECTION OF GENERATION FACILITIES OTHER THAN NET METERING AND SMALL ON-SITE GENERATION FACILITIES (Continued) VESTED INTEREST (Continued) 1. The Company will provide a refund payment to each Seller holding a Vested Interest in Company-owned Interconnection Facilities when an Additional Applicant shares use of those Interconnection Facilities. 2. The refund payment will be based on the following formula: Linear Connected Original Refund = Footage x Load/Peak Generation x Interconnection Ratio Ratio Cost a. The Linear Footage Ratio is the length of jointly used Special Facilities divided by the length of the vested Special Facilities. b. The Connected Load/Peak Generation Ratio is the Connected Load or Peak Generation of the Additional Applicant divided by the sum of the Connected Load or Peak Generation of the Additional Applicant and all other Connected Loads and/or Peak Generation on the Special Facilities. c. The Original Interconnection Cost is the sum of the Company's Construction Cost and any Transfer Costs for the Interconnection Facilities to which the Additional Applicant intends to connect and share usage. 3. The Additional Applicant will pay the Company the amount of the Vested Interest refund(s). Additional Applicants making Vested Interest payments are in turn eligible to receive refunds within the 5 year limit described above. 4. Vested Interest refunds will not exceed 100 percent of the refundable portion of any party's cash payment to the Company. 5. Vested Interest refund payments may be waived by notifying the Company in writing. OPERATION AND MAINTENANCE OBLIGATIONS AND EXPENSES The Company will operate and maintain Company furnished Interconnection Facilities, as well as any Seller-Furnished Facilities transferred to the Company. For all projects not interconnecting as a Schedule 6, Schedule 8, or Schedule 84 customer, the Seller will pay the Company a monthly operation and maintenance charge equal to a percentage of the Construction Cost and Transfer Cost paid by the Seller. The percentage will change annually on the anniversary of the First Energy Date in accordance with the following tables: Idaho Power Company Fourth Fourth Revised Sheet No. 72-1812 Cancels I.P.U.C. No. 29, Tariff No. 101Third Fifth Revised Sheet No. 72-1812 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34046 34955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – June 1, 2018March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 72 INTERCONNECTIONS TOGENERATOR INTERCONNECTIONS NON-UTILITY GENERATIONTO PURPA QUALIFYING FACILITY SELLERS (Continued) SECTION 3SECTION 2: INTERCONNECTION OF GENERATION FACILITIES OTHER THAN NET METERING AND SMALL ON-SITE GENERATION FACILITIES (Continued) OPERATION AND MAINTENANCE OBLIGATIONS AND EXPENSES (Continued) TABLE 1: MONTHLY OPERATION AND MAINTENANCE CHARGES FOR 138 kV and 161 kV Year 1 2 3 4 5 6 7 8 9 10 11 12 O&M Charge 0.26% 0.27% 0.28% 0.29% 0.30% 0.32% 0.33% 0.35% 0.36% 0.38% 0.40%0.41% Year 13 14 15 16 17 18 19 20 21 22 23 24 O&M Charge 0.43% 0.45% 0.47% 0.49% 0.52% 0.54% 0.56% 0.59% 0.62% 0.64% 0.67%0.70% Year 25 26 27 28 29 30 31 32 33 34 35 36+ O&M Charge 0.73% 0.77% 0.80% 0.84% 0.87% 0.91% 0.96% 1.00% 1.04% 1.09% 1.14%0.40% TABLE 2: MONTHLY OPERATING AND MAINTENANCE CHARGES BELOW 138 kV Year 1 2 3 4 5 6 7 8 9 10 11 12 O&M Charge 0.47% 0.49% 0.52% 0.54% 0.56% 0.59% 0.61% 0.64% 0.67% 0.70% 0.73% 0.77% Year 13 14 15 16 17 18 19 20 21 22 23 24 O&M Charge 0.80% 0.84% 0.87% 0.91% 0.95% 1.00% 1.04% 1.09% 1.14% 1.19% 1.24% 1.30% Year 25 26 27 28 29 30 31 32 33 34 35 36+ O&M Charge 1.36% 1.42% 1.48% 1.55% 1.62% 1.69% 1.77% 1.85% 1.93% 2.02% 2.11% 0.70% The monthly operating and maintenance charges in Table 1 and Table 2 will be applied as a percentage of the applicable original interconnection investment. These monthly operating and maintenance charges escalate annually and are equivalent to 35-year levelized rates of 0.40% for Table 1 and 0.70% for Table 2. Where a Seller's interconnection will utilize Interconnection Facilities provided under a prior agreement(s) and the combined term(s) of the prior agreement(s) is less than 35 years, the operation and maintenance charge related to those existing Interconnection Facilities for the Seller's interconnection will be computed to include the expired term of the prior agreement(s). Where a Seller’s interconnection will utilize Interconnection Facilities provided under a prior agreement(s) and the combined term(s) of the prior agreement(s) is greater than 35 years, the operation and maintenance charge related to those existing Interconnection Facilities for the Seller’s interconnection will be computed at the applicable levelized rate designated at 36+ years. The cost upon which an individual Seller's operation and maintenance charge is based will be reduced by subsequent Vested Interest refunds. Additional Applicants who are Sellers will pay the monthly operation and maintenance charge on the amount they paid as an Additional Applicant. Idaho Power Company Fourth Fourth Revised Sheet No. 72-1812 Cancels I.P.U.C. No. 29, Tariff No. 101Third Fifth Revised Sheet No. 72-1812 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34046 34955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – June 1, 2018March 23, 2021 1221 West Idaho Street, Boise, Idaho Seller-Furnished Facilities not transferred to the Company will be operated and maintained by the Seller at the Seller's sole risk and expense. Idaho Power Company Third Fourth Revised Sheet No. 72-1913 Cancels I.P.U.C. No. 29, Tariff No. 101Second Third Revised Sheet No. 72-1913 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 3404634955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – June 1, 2018March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 72 INTERCONNECTIONS TOGENERATOR INTERCONNECTIONS NON-UTILITY GENERATIONTO PURPA QUALIFYING FACILITY SELLERS (Continued) SECTION 3SECTION 2: INTERCONNECTION OF GENERATION FACILITIES OTHER THAN NET METERING AND SMALL ON-SITE GENERATION FACILITIES (Continued) IDAHO POWER COMPANY UNIFORM INTERCONNECTION AGREEMENT (PURPA) This Interconnection Agreement (“Agreement”) is effective as of the ____ day of __________, 20___, between ____________________________, hereinafter called “Seller,” and Idaho Power Company, hereinafter called “Company.” RECITALS A. Seller will own or operate a Generation Facility that qualifies for service under Idaho Power’s Commission-approved Schedule 72 and any successor schedule. B. The Generation Facility covered by this Agreement is more particularly described in Attachment 1. AGREEMENTS 1. Capitalized terms used herein shall have the same meanings as defined in Schedule 72 or in the body of this Agreement. 2. This Agreement and Schedule 72 provide the rates, charges, terms and conditions under which the Seller’s Generation Facility will interconnect with, and operate in parallel with, the Company’s transmission/distribution system. Terms defined in Schedule 72 will have the same defined meaning in this Agreement. If there is any conflict between the terms of this Agreement and Schedule 72, Schedule 72 shall prevail. 3. This Agreement is not an agreement to purchase Seller’s power. Purchase of Seller’s power and other services that Seller may require will be covered under separate agreements. Nothing in this Agreement is intended to affect any other agreement between the Company and Seller. 4. Attached to this Agreement and included by reference are the following: Attachment 1 – Description and Costs of the Generation Facility, Interconnection Facilities, and Metering Equipment. Attachment 2 – One-line Diagram Depicting the Generation Facility, Interconnection Facilities, Metering Equipment and Upgrades. Attachment 3 – Milestones For Interconnecting the Generation Facility. Idaho Power Company ThirdFourth Revised Sheet No. 72-2014 Cancels I.P.U.C. No. 29, Tariff No. 101Second Third Revised Sheet No. 72-2014 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 3404634955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – June 1, 2018March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 72 INTERCONNECTIONS TOGENERATOR INTERCONNECTIONS NON-UTILITY GENERATIONTO PURPA QUALIFYING FACILITY SELLERS (Continued) SECTION 3SECTION 2: INTERCONNECTION OF GENERATION FACILITIES OTHER THAN NET METERING AND SMALL ON-SITE GENERATION FACILITIES (Continued) IDAHO POWER COMPANY UNIFORM INTERCONNECTION AGREEMENT (PURPA) (Continued) AGREEMENTS (Continued) Attachment 4 – Additional Operating Requirements for the Company’s Transmission System Needed to Support the Seller’s Generation Facility. Attachment 5 – Reactive Power. Attachment 6 – Description of Upgrades required to integrate the Generation Facility and Best Estimate of Upgrade Costs. 5. Effective Date, Term, Termination and Disconnection. 5.1 Term of Agreement. Unless terminated earlier in accordance with the provisions of this Agreement, this Agreement shall become effective on the date specified above and remain effective as long as Seller’s Generation Facility is eligible for service under Schedule 72. 5.2 Termination. 5.2.1 Seller may voluntarily terminate this Agreement upon expiration or termination of an agreement to sell power to the Company. 5.2.2 After a Default, either Party may terminate this Agreement pursuant to Section 6.5. 5.2.3 Upon termination or expiration of this Agreement, the Seller’s Generation Facility will be disconnected from the Company’s transmission/distribution system. The termination or expiration of this Agreement shall not relieve either Party of its liabilities and obligations, owed or continuing at the time of the termination. The provisions of this Section shall survive termination or expiration of this Agreement. Idaho Power Company Third Fourth Revised Sheet No. 72-2115 Cancels I.P.U.C. No. 29, Tariff No. 101Second Third Revised Sheet No. 72-2115 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 3404634955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – June 1, 2018March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 72 INTERCONNECTIONS TOGENERATOR INTERCONNECTIONS NON-UTILITY GENERATIONTO PURPA QUALIFYING FACILITY SELLERS (Continued) SECTION 3SECTION 2: INTERCONNECTION OF GENERATION FACILITIES OTHER THAN NET METERING AND SMALL ON-SITE GENERATION FACILITIES (Continued) IDAHO POWER COMPANY UNIFORM INTERCONNECTION AGREEMENT (PURPA) (Continued) AGREEMENTS (Continued) 5.3 Temporary Disconnection. Temporary disconnection shall continue only for so long as reasonably necessary under “Good Utility Practice.” Good Utility Practice means any of the practices, methods and acts engaged in or approved by a significant portion of the electric industry during the relevant time period, or any of the practices, methods and acts which, in the exercise of reasonable judgment in light of the facts known at the time the decision was made, could have been expected to accomplish the desired result at a reasonable cost consistent with good business practices, reliability, safety and expedition. Good Utility Practice is not intended to be limited to the optimum practice, method, or act to the exclusion of all others, but rather to be acceptable practices, methods, or acts generally accepted in the region. Good Utility Practice includes compliance with WECC or NERC requirements. Payment of lost revenue resulting from temporary disconnection shall be governed by the power purchase agreement. 5.3.1 Emergency Conditions. "Emergency Condition" means a condition or situation: (1) that in the judgment of the Party making the claim is imminently likely to endanger life or property; or (2) that, in the case of the Company, is imminently likely (as determined in a non-discriminatory manner) to cause a material adverse effect on the security of, or damage to the Company’s transmission/distribution system, the Company’s Interconnection Facilities or the equipment of the Company’s customers; or (3) that, in the case of the Seller, is imminently likely (as determined in a non-discriminatory manner) to cause a material adverse effect on the reliability and security of, or damage to, the Generation Facility or the Seller’s Interconnection Facilities. Under Emergency Conditions, either the Company or the Seller may immediately suspend interconnection service and temporarily disconnect the Generation Facility. The Company shall notify the Seller promptly when it becomes aware of an Emergency Condition that may reasonably be expected to affect the Seller’s operation of the Generation Facility. The Seller shall notify the Company promptly when it becomes aware of an Emergency Condition that may reasonably be expected to affect the Company’s equipment or service to the Company’s customers. To the extent information is known, the notification shall describe the Emergency Condition, the extent of the damage or deficiency, the expected effect on the operation of both Parties' facilities and operations, its anticipated duration, and the necessary corrective action. Idaho Power Company Third Fourth Revised Sheet No. 72-2216 Cancels I.P.U.C. No. 29, Tariff No. 101Second Third Revised Sheet No. 72-2216 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 3404634955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – June 1, 2018March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 72 INTERCONNECTIONS TOGENERATOR INTERCONNECTIONS NON-UTILITY GENERATIONTO PURPA QUALIFYING FACILITY SELLERS (Continued) SECTION 3SECTION 2: INTERCONNECTION OF GENERATION FACILITIES OTHER THAN NET METERING AND SMALL ON-SITE GENERATION FACILITIES (Continued) IDAHO POWER COMPANY UNIFORM INTERCONNECTION AGREEMENT (PURPA) (Continued) AGREEMENTS (Continued) 5.3.2 Routine Maintenance, Construction, and Repair. The Company may interrupt interconnection service or curtail the output of the Seller’s Generation Facility and temporarily disconnect the Generation Facility from the Company’s transmission/distribution system when necessary for routine maintenance, construction, and repairs on the Company’s transmission/distribution system. The Company will make a reasonable attempt to contact the Seller prior to exercising its rights to interrupt interconnection or curtail deliveries from the Seller’s Facility. Seller understands that in the case of emergency circumstances, real time operations of the electrical system, and/or unplanned events, the Company may not be able to provide notice to the Seller prior to interruption, curtailment or reduction of electrical energy deliveries to the Company. The Company shall use reasonable efforts to coordinate such reduction or temporary disconnection with the Seller. 5.3.3 Scheduled Maintenance. On or before January 31 of each calendar year, Seller shall submit a written proposed maintenance schedule of significant Facility maintenance for that calendar year and the Company and Seller shall mutually agree as to the acceptability of the proposed schedule. The Parties determination as to the acceptability of the Seller’s timetable for scheduled maintenance will take into consideration Good Utility Practices, Idaho Power system requirements and the Seller’s preferred schedule. Neither Party shall unreasonably withhold acceptance of the proposed maintenance schedule. 5.3.4. Maintenance Coordination. The Seller and the Company shall, to the extent practical, coordinate their respective transmission/distribution system and Generation Facility maintenance schedules such that they occur simultaneously. Seller shall provide and maintain adequate protective equipment sufficient to prevent damage to the Generation Facility and Seller-furnished Interconnection Facilities. In some cases, some of Seller’s protective relays will provide back-up protection for Idaho Power’s facilities. In that event, Idaho Power will test such relays annually and Seller will pay the actual cost of such annual testing. Idaho Power Company Third Fifth Revised Sheet No. 72-2317 Cancels I.P.U.C. No. 29, Tariff No. 101Second Fourth Revised Sheet No. 72-2317 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 3404634955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – June 1, 2018March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 72 INTERCONNECTIONS TOGENERATOR INTERCONNECTIONS NON-UTILITY GENERATIONTO PURPA QUALIFYING FACILITY SELLERS (Continued) SECTION 3SECTION 2: INTERCONNECTION OF GENERATION FACILITIES OTHER THAN NET METERING AND SMALL ON-SITE GENERATION FACILITIES (Continued) IDAHO POWER COMPANY UNIFORM INTERCONNECTION AGREEMENT (PURPA) (Continued) AGREEMENTS (Continued) 5.3.5 Forced Outages. During any forced outage, the Company may suspend interconnection service to effect immediate repairs on the Company’s transmission/distribution system. The Company shall use reasonable efforts to provide the Seller with prior notice. If prior notice is not given, the Company shall, upon request, provide the Seller written documentation after the fact explaining the circumstances of the disconnection. 5.3.6 Adverse Operating Effects. The Company shall notify the Seller as soon as practicable if, based on Good Utility Practice, operation of the Seller’s Generation Facility may cause disruption or deterioration of service to other customers served from the same electric system, or if operating the Generation Facility could cause damage to the Company’s transmission/distribution system or other affected systems. Supporting documentation used to reach the decision to disconnect shall be provided to the Seller upon request. If, after notice, the Seller fails to remedy the adverse operating effect within a reasonable time, the Company may disconnect the Generation Facility. The Company shall provide the Seller with reasonable notice of such disconnection, unless the provisions of Article 5.3.1 apply. 5.3.7 Modification of the Generation Facility. The Seller must receive written authorization from the Company before making any change to the Generation Facility that may have a material impact on the safety or reliability of the Company’s transmission/distribution system. Such authorization shall not be unreasonably withheld. Modifications shall be done in accordance with Good Utility Practice. If the Seller makes such modification without the Company’s prior written authorization, the latter shall have the right to temporarily disconnect the Generation Facility. 5.3.8 Reconnection. The Parties shall cooperate with each other to restore the Generation Facility, Interconnection Facilities, and the Company’s transmission/distribution system to their normal operating state as soon as reasonably practicable following a temporary disconnection. Idaho Power Company Third Fifth Revised Sheet No. 72-2418 Cancels I.P.U.C. No. 29, Tariff No. 101Second Fourth Revised Sheet No. 72-2418 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 3404634955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – June 1, 2018March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 72 INTERCONNECTIONS TOGENERATOR INTERCONNECTIONS NON-UTILITY GENERATIONTO PURPA QUALIFYING FACILITY SELLERS (Continued) SECTION 3SECTION 2: INTERCONNECTION OF GENERATION FACILITIES OTHER THAN NET METERING AND SMALL ON-SITE GENERATION FACILITIES (Continued) IDAHO POWER COMPANY UNIFORM INTERCONNECTION AGREEMENT (PURPA) (Continued) AGREEMENTS (Continued) 5.3.9 Voltage Levels. Seller, in accordance with Good Utility Practices, shall minimize voltage fluctuations and maintain voltage levels acceptable to Idaho Power. Idaho Power may, in accordance with Good Utility Practices, upon one hundred eighty (180) days' notice to the Seller, change its nominal operating voltage level by more than ten percent (10%) at the Point of Delivery, in which case Seller shall modify, at Idaho Power's expense, Seller's equipment as necessary to accommodate the modified nominal operating voltage level. 5.4 Land Rights. 5.4.1 Seller to Provide Access. Seller 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 property of Seller. Seller 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. 5.4.2 Use of Public Rights-of-Way. The Parties agree that it is necessary to avoid the adverse environmental and operating impacts that would occur as a result of duplicate electric lines being constructed in close proximity. Therefore, subject to Idaho Power's compliance with Paragraph 5.4.4, Seller agrees that should Seller seek and receive from any local, state or federal governmental body the right to erect, construct and maintain Seller-furnished Interconnection Facilities upon, along and over any and all public roads, streets and highways, then the use by Seller of such public right-of-way shall be subordinate to any future use by Idaho Power of such public right-of-way for construction and/or maintenance of electric distribution and transmission facilities and Idaho Power may claim use of such public right-of-way for such purposes at any time. Except as required by Paragraph 5.4.4, Idaho Power shall not be required to compensate Seller for exercising its rights under this Paragraph 5.4.2. Idaho Power Company Third Fourth Revised Sheet No. 72-2519 Cancels I.P.U.C. No. 29, Tariff No. 101Second Third Revised Sheet No. 72-2519 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 3404634955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – June 1, 2018 March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 72 INTERCONNECTIONS TOGENERATOR INTERCONNECTIONS NON-UTILITY GENERATIONTO PURPA QUALIFYING FACILITY SELLERS (Continued) SECTION 3SECTION 2: INTERCONNECTION OF GENERATION FACILITIES OTHER THAN NET METERING AND SMALL ON-SITE GENERATION FACILITIES (Continued) IDAHO POWER COMPANY UNIFORM INTERCONNECTION AGREEMENT (PURPA) (Continued) AGREEMENTS (Continued) 5.4.3 Joint Use of Facilities. Subject to Idaho Power's compliance with Paragraph 15.4.4, Idaho Power may use and attach its distribution and/or transmission facilities to Seller's Interconnection Facilities, may reconstruct Seller's Interconnection Facilities to accommodate Idaho Power's usage or Idaho Power may construct its own distribution or transmission facilities along, over and above any public right-of-way acquired from Seller pursuant to Paragraph 5.4.2, attaching Seller's Interconnection Facilities to such newly constructed facilities. Except as required by Paragraph 5.4.4, Idaho Power shall not be required to compensate Seller for exercising its rights under this Paragraph 5.4.3. 5.4.4 Conditions of Use. It is the intention of the Parties that the Seller be left in substantially the same condition, both financially and electrically, as Seller existed prior to Idaho Power's exercising its rights under this Paragraph 5.4. Therefore, the Parties agree that the exercise by Idaho Power of any of the rights enumerated in Paragraphs 5.4.2 and 5.4.3 shall: (1) comply with all applicable laws, codes and Good Utility Practices, (2) equitably share the costs of installing, owning and operating jointly used facilities and rights-of-way. If the Parties are unable to agree on the method of apportioning these costs, the dispute will be submitted to the Commission for resolution and the decision of the Commission will be binding on the Parties, and (3) shall provide Seller with an interconnection to Idaho Power's system of equal capacity and durability as existed prior to Idaho Power exercising its rights under this Paragraph 5.4. 6. Assignment, Liability, Indemnity, Force majeure, Consequential Damages and Default. 6.1 Assignment. 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: 6.1.1 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. Idaho Power Company Third Fourth Revised Sheet No. 72-2620 Cancels I.P.U.C. No. 29, Tariff No. 101Second Third Revised Sheet No. 72-2620 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 3404634955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – June 1, 2018March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 72 INTERCONNECTIONS TOGENERATOR INTERCONNECTIONS NON-UTILITY GENERATIONTO PURPA QUALIFYING FACILITY SELLERS (Continued) SECTION 3SECTION 2: INTERCONNECTION OF GENERATION FACILITIES OTHER THAN NET METERING AND SMALL ON-SITE GENERATION FACILITIES (Continued) IDAHO POWER COMPANY UNIFORM INTERCONNECTION AGREEMENT (PURPA) (Continued) AGREEMENTS (Continued) 6.1.2 The Seller shall have 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 Seller will promptly notify the Company of any such contingent assignment. 6.1.3 Any attempted assignment that violates this article is void and ineffective. Assignment shall not relieve a Party of its obligations, nor shall a 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 Seller. Where required, consent to assignment will not be unreasonably withheld, conditioned or delayed. 6.2 Limitation of Liability. Each Party's liability to the other Party for any loss, cost, claim, injury, liability, or expense, including reasonable attorney's fees, relating to or arising from any act or omission in its performance of this Agreement, shall be limited to the amount of direct damage actually incurred. In no event shall either Party be liable to the other Party for any indirect, special, consequential, or punitive damages, except as authorized by this Agreement. 6.3 Indemnity. 6.3.1 This provision protects each Party from liability incurred to third parties as a result of carrying out the provisions of this Agreement. Liability under this provision is exempt from the general limitations on liability found in Article 6.2. 6.3.2 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. Idaho Power Company Third Fourth Revised Sheet No. 72-2721 Cancels I.P.U.C. No. 29, Tariff No. 101Second Third Revised Sheet No. 72-2721 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 3404634955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – June 1, 2018March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 72 INTERCONNECTIONS TOGENERATOR INTERCONNECTIONS NON-UTILITY GENERATIONTO PURPA QUALIFYING FACILITY SELLERS (Continued) SECTION 3SECTION 2: INTERCONNECTION OF GENERATION FACILITIES OTHER THAN NET METERING AND SMALL ON-SITE GENERATION FACILITIES (Continued) IDAHO POWER COMPANY UNIFORM INTERCONNECTION AGREEMENT (PURPA) (Continued) AGREEMENTS (Continued) 6.3.3 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. 6.3.4 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. 6.3.5 Promptly after receipt by an indemnified person of any claim or notice of the commencement of any action or administrative or legal proceeding or investigation as to which the indemnity provided for in this article may apply, the indemnified person shall notify the indemnifying party of such fact. Any failure of or delay in such notification shall be a Material Breach and shall not affect a Party's indemnification obligation unless such failure or delay is materially prejudicial to the indemnifying party. 6.4 Force Majeure. As used in this Agreement, “Force Majeure” or “an event of Force Majeure” means any cause beyond the control of the Seller or of the Company which, despite the exercise of due diligence, such Party is unable to prevent or overcome. Force Majeure includes, but is not limited to, acts of God, fire, flood, storms, wars, hostilities, civil strife, strikes and other labor disturbances, earthquakes, fires, lightning, epidemics, sabotage, or changes in law or regulation occurring after the Operation Date, which, by the exercise of reasonable foresight such party could not reasonably have been expected to avoid and by the exercise of due diligence, it shall be unable to overcome. If either Party is rendered wholly or in part unable to perform its obligations under this Agreement because of an event of Force Majeure, both Parties shall be excused from whatever performance is affected by the event of Force Majeure, provided that: (1) The non-performing Party shall, as soon as is reasonably possible after the occurrence of the Force Majeure, give the other Party written notice describing the particulars of the occurrence. Idaho Power Company Third Fourth Revised Sheet No. 72-2721 Cancels I.P.U.C. No. 29, Tariff No. 101Second Third Revised Sheet No. 72-2721 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 3404634955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – June 1, 2018March 23, 2021 1221 West Idaho Street, Boise, Idaho Idaho Power Company Third Fourth Revised Sheet No. 72-2822 Cancels I.P.U.C. No. 29, Tariff No. 101Second Third Revised Sheet No. 72-2822 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 3404634955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – June 1, 2018March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 72 INTERCONNECTIONS TOGENERATOR INTERCONNECTIONS NON-UTILITY GENERATIONTO PURPA QUALIFYING FACILITY SELLERS (Continued) SECTION 3SECTION 2: INTERCONNECTION OF GENERATION FACILITIES OTHER THAN NET METERING AND SMALL ON-SITE GENERATION FACILITIES (Continued) IDAHO POWER COMPANY UNIFORM INTERCONNECTION AGREEMENT (PURPA) (Continued) AGREEMENTS (Continued) (2) The suspension of performance shall be of no greater scope and of no longer duration than is required by the event of Force Majeure. (3) No obligations of either Party which arose before the occurrence causing the suspension of performance and which could and should have been fully performed before such occurrence shall be excused as a result of such occurrence. 6.5 Default and Material Breaches. 6.5.1 Defaults. If either Party fails to perform any of the terms or conditions of this Agreement (a “Default” or an “Event of Default”), the nondefaulting Party shall cause notice in writing to be given to the defaulting Party, specifying the manner in which such default occurred. If the defaulting Party shall fail to cure such Default within the sixty (60) days after service of such notice, or if the defaulting Party reasonably demonstrates to the other Party that the Default can be cured within a commercially reasonable time but not within such sixty (60) day period and then fails to diligently pursue such cure, then, the nondefaulting Party may, at its option, terminate this Agreement and/or pursue its legal or equitable remedies. 6.5.2 Material Breaches. The notice and cure provisions in Paragraph 6.6.1 do not apply to Defaults identified in this Agreement as Material Breaches. Material Breaches must be cured as expeditiously as possible following occurrence of the breach. 7. Insurance. During the term of this Agreement, Seller shall secure and continuously carry the following insurance coverage: 7.1 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. 7.2 The above insurance coverage shall be placed with an insurance company with an A.M. Best Company rating of A- or better and shall include: Idaho Power Company Second Fourth Revised Sheet No. 72-2923 Cancels I.P.U.C. No. 29, Tariff No. 101FirstThird Revised Sheet No. 72-2923 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 3404634955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – June 1, 2018March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 72 INTERCONNECTIONS TOGENERATOR INTERCONNECTIONS NON-UTILITY GENERATIONTO PURPA QUALIFYING FACILITY SELLERS (Continued) SECTION 3SECTION 2: INTERCONNECTION OF GENERATION FACILITIES OTHER THAN NET METERING AND SMALL ON-SITE GENERATION FACILITIES (Continued) IDAHO POWER COMPANY UNIFORM INTERCONNECTION AGREEMENT (PURPA) (Continued) AGREEMENTS (Continued) (a) An endorsement naming Idaho Power as an additional insured and loss payee as applicable; and (b) 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. 7.3 Seller to Provide Certificate of Insurance. As required in Paragraph 7 herein and annually thereafter, Seller shall furnish the Company a certificate of insurance, together with the endorsements required therein, evidencing the coverage as set forth above. 7.4 Seller to Notify Idaho Power of Loss of Coverage.- If the insurance coverage required by Paragraph 7.1 shall lapse for any reason, Seller will immediately notify Idaho Power in writing. The notice will advise Idaho Power of the specific reason for the lapse and the steps Seller 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 5.3 and will be a Material Breach. 8. Miscellaneous. 8.1 Governing Law. The validity, interpretation and enforcement of this Agreement and each of its provisions shall be governed by the laws of the State of Idaho without regard to its conflicts of law principles. 8.2 Salvage. No later than sixty (60) days after the termination or expiration of this Agreement, Idaho Power will prepare and forward to Seller an estimate of the remaining value of those Idaho Power furnished Interconnection Facilities as required under Schedule 72 and/or described in this Agreement, less the cost of removal and transfer to Idaho Power's nearest warehouse, if the Interconnection Facilities will be removed. If Seller elects not to obtain ownership of the Interconnection Facilities but instead wishes that Idaho Power reimburse the Seller for said Facilities the Seller may invoice Idaho Power for the net salvage value as estimated by Idaho Power and Idaho Power shall pay such amount to Seller within thirty (30) days after receipt of the invoice. Seller shall have the right to offset the invoice amount against any present or future payments due Idaho Power. Idaho Power Company FourthSecond Revised Sheet No. 72-3024 Cancels I.P.U.C. No. 29, Tariff No. 101First Third Revised Sheet No. 72-3024 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 3404634955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – June 1, 2018March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 72 INTERCONNECTIONS TOGENERATOR INTERCONNECTIONS NON-UTILITY GENERATIONTO PURPA QUALIFYING FACILITY SELLERS (Continued) SECTION 3SECTION 2: INTERCONNECTION OF GENERATION FACILITIES OTHER THAN NET METERING AND SMALL ON-SITE GENERATION FACILITIES (Continued) IDAHO POWER COMPANY UNIFORM INTERCONNECTION AGREEMENT (PURPA) (Continued) AGREEMENTS (Continued) 9. Notices. 9.1 General. Unless otherwise provided in this Agreement, any written notice, demand, or request required or authorized in connection with this Agreement ("Notice") shall be deemed properly given if delivered in person, delivered by recognized national currier service, or sent by first class mail, postage prepaid, to the person specified below: If to the Seller: Seller: Attention: Address: City: State: Zip: Phone: Fax: If to the Company: Company Attention: Address: City: State: Zip: Phone: Fax: 9.2 Billing and Payment. Billings and payments shall be sent to the addresses set out below: Seller: Attention: Address: City: State: Zip: Phone: Fax: Company: Attention: Address: City: State: Zip: Idaho Power Company FourthSecond Revised Sheet No. 72-3024 Cancels I.P.U.C. No. 29, Tariff No. 101First Third Revised Sheet No. 72-3024 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 3404634955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – June 1, 2018March 23, 2021 1221 West Idaho Street, Boise, Idaho Phone: Fax: Idaho Power Company First Fourth Revised Sheet No. 72-3125 Cancels I.P.U.C. No. 29, Tariff No. 101Original Third Revised Sheet No. 72-3125 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 3404634955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – June 1, 2018March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 72 INTERCONNECTIONS TOGENERATOR INTERCONNECTIONS NON-UTILITY GENERATIONTO PURPA QUALIFYING FACILITY SELLERS (Continued) SECTION 3SECTION 2: INTERCONNECTION OF GENERATION FACILITIES OTHER THAN NET METERING AND SMALL ON-SITE GENERATION FACILITIES (Continued) IDAHO POWER COMPANY UNIFORM INTERCONNECTION AGREEMENT (PURPA) (Continued) AGREEMENTS (Continued) 9.3 Designated Operating Representative. The Parties may also designate operating representatives to conduct the communications which may be necessary or convenient for the administration of this Agreement. This person will also serve as the point of contact with respect to operations and maintenance of the Party’s facilities. Seller’s Operating Representative: Seller: Attention: Address: City: State: Zip: Phone: Fax: Company’s Operating Representative: Company: Attention: Address: City: State: Zip: Phone: Fax: 9.5 Changes to the Notice Information. Either Party may change this information by giving five Business Days written notice prior to the effective date of the change. 10. Signatures. IN WITNESS WHEREOF, the Parties have caused this Agreement to be executed by their respective duly authorized representatives. For the Company Name: Title: Date: For the Seller Name: Title: Idaho Power Company First Fourth Revised Sheet No. 72-3125 Cancels I.P.U.C. No. 29, Tariff No. 101Original Third Revised Sheet No. 72-3125 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 3404634955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – June 1, 2018March 23, 2021 1221 West Idaho Street, Boise, Idaho Date: Idaho Power Company First Fourth Revised Sheet No. 72-2632 Cancels I.P.U.C. No. 29, Tariff No. 101Original Third Revised Sheet No. 72-2632 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 3404634955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – June 1, 2018March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 72 GINTERCONNECTIONS TOENERATOR INTERCONNECTIONS NON-UTILITY GENERATIONTO PURPA QUALIFYING FACILITY SELLERS (Continued) SECTION 3SECTION 2: INTERCONNECTION OF GENERATION FACILITIES OTHER THAN NET METERING AND SMALL ON-SITE GENERATION FACILITIES (Continued) IDAHO POWER COMPANY UNIFORM INTERCONNECTION AGREEMENT (PURPA) (Continued) Attachment 1 Description and Costs of the Generation Facility, Interconnection Facilities and Metering Equipment In this attachment the Generation Facility and Interconnection Facilities, including Special Facilities and upgrades, are itemized and identified as being owned by the Seller or the Company. As provided in Schedule 72, Payment For 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 Small Generation Facility, Interconnection Facilities, Metering Equipment and Upgrades Idaho Power Company First Fourth Revised Sheet No. 73-3327 Cancels I.P.U.C. No. 29, Tariff No. 101Original Third Revised Sheet No. 72-3327 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 3404634955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – June 1, 2018March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 72 INTERCONNECTIONS TOGENERATOR INTERCONNECTIONS NON-UTILITY GENERATIONTO PURPA QUALIFYING FACILITY SELLERS (Continued) SECTION 3SECTION 2: INTERCONNECTION OF GENERATION FACILITIES OTHER THAN NET METERING AND SMALL ON-SITE GENERATION FACILITIES (Continued) IDAHO POWER COMPANY UNIFORM INTERCONNECTION AGREEMENT (PURPA) (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 Seller________________________ Date______________ Idaho Power Company Fourth Revised Sheet No. 72-28 Cancels I.P.U.C. No. 29, Tariff No. 101Third Revised Sheet No. 72-28 thru Original Sheet No. 72-3434 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 3404634955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – June 1, 2018March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 72 INTERCONNECTIONS TOGENERATOR INTERCONNECTIONS NON-UTILITY GENERATIONTO PURPA QUALIFYING FACILITY SELLERS (Continued) SECTION 3SECTION 2: INTERCONNECTION OF GENERATION FACILITIES OTHER THAN NET METERING AND SMALL ON-SITE GENERATION FACILITIES (Continued) IDAHO POWER COMPANY UNIFORM INTERCONNECTION AGREEMENT (PURPA) (Continued) Attachment 4 Additional Operating Requirements for the Company’s Transmission System and Affected Systems Needed to Support the Seller’s Needs The Company shall also provide requirements that must be met by the Seller 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 Seller, based upon information provided by the Seller. 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, Seller 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 Seller. Payment of these costs will be in accordance with Schedule 72 and the total reactive power cost will be included in the calculation of the Monthly Operation and Maintenance Charges specified in Schedule 72. Attachment 6 Company’s Description of Upgrades Required to Integrate the Generation Facility and Best Estimate of Upgrade Costs As provided in Schedule 72 this Attachment describes Upgrades, including best work upgrades, and provides an itemized best estimate of the cost of the Upgrades. Idaho Power Company Fourth Revised Sheet No. 72-28 Cancels I.P.U.C. No. 29, Tariff No. 101Third Revised Sheet No. 72-28 thru Original Sheet No. 72-3434 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 3404634955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – June 1, 2018March 23, 2021 1221 West Idaho Street, Boise, Idaho Idaho Power Company Fifth Sixth Revised Sheet No. 84-1 Cancels I.P.U.C. No. 29, Tariff No. 101 Fourth Fifth Revised Sheet No. 84-1 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34854955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – December 2, 2020March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 84 CUSTOMER ENERGY PRODUCTION NET METERING SERVICE AVAILABILITY Service under this schedule is available throughout the Company’s service territory within the State of Idaho for Customers intending to operate Net Metering 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. APPLICABILITY Service under this schedule is applicable to any Customer that: 1. Does not take service under Schedule 4, 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 for the loads served at the Point of Delivery adjacent to the Generation Interconnection Point as active and in good standing; and 4. Meets all requirements applicable to Net Metering Exporting Systems detailed in the Company’s Schedule 72 Interconnections to Non-Utility Generation68, 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 the Company’s existing watt-hour retail meter. 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 One Meter Option is available if: Idaho Power Company Third Fourth Revised Sheet No. 84-3 Cancels I.P.U.C. No. 29, Tariff No. 101Second Third Revised Sheet No. 84-3 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34854955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – December 2, 2020March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 84 CUSTOMER ENERGY PRODUCTION NET METERING SERVICE (Continued) DEFINITIONS Basic Load Capacity (BLC) is the average of the two greatest non-zero monthly Billing Demands established during the 12-month period which includes and ends with the current Billing Period. Designated Meter is the retail meter physically connected to the Net Metering 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. 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. Grandfathered Status refers to the ability for a system to receive the compensation structure in place on December 1, 2020. The compensation structure applicable to systems with a Grandfather Status includes net monthly one-for-one kWh credit compensation for Excess Net Energy. 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 Generation Facility to the Point of Delivery or Generation Interconnection Point. Net Metering Service is the Company’s service that provides for transfer of electric energy to the Company by means of a net metering arrangement under the terms of Schedule 84 or its successor schedule(s) as approved by the Commission. This optional service provides for Customers to install Generation Facilities to interconnect to the Company’s system to offset all or a portion of their electrical usage. This service is comprised of all Customers taking service under Schedule 84. Net Metering System is a Customer-owned Generation Facility interconnected to the Company’s system under the applicable terms of Schedule 72 and Schedule 84. 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. Idaho Power Company Third Fourth Revised Sheet No. 84-3 Cancels I.P.U.C. No. 29, Tariff No. 101Second Third Revised Sheet No. 84-3 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34854955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – December 2, 2020March 23, 2021 1221 West Idaho Street, Boise, Idaho 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 7268 is the Company’s service schedule which provides for interconnection to non-utility generationcustomer generation or its successor schedule(s) as approved by the Commission. Idaho Power Company Third Fourth Revised Sheet No. 84-4 Cancels I.P.U.C. No. 29, Tariff No. 101Second Third Revised Sheet No. 84-4 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34854955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – December 2, 2020March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 84 CUSTOMER ENERGY PRODUCTION NET METERING SERVICE (Continued) MONTHLY BILLING The Customer shall be billed in accordance with the Customer’s applicable standard service schedule, including appropriate monthly charges. CONDITIONS OF PURCHASE AND SALE The conditions listed below shall apply to all transactions 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. b. Effective at the beginning of each Customer’s January 2014 Billing Period, 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 Net Metering 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 at the end of the Customer’s December Billing Period 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 Idaho Power Company First Second Revised Sheet No. 84-5 Cancels I.P.U.C. No. 29, Tariff No. 101 Original First Revised Sheet No. 84-5 I IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34854955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – December 2, 2020March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 84 CUSTOMER ENERGY PRODUCTION NET METERING SERVICE (Continued) CONDITIONS OF PURCHASE AND SALE (Continued) 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 Net Metering 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 January 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 on January 1 of 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 the same rate schedule as the Designated Meter. Remaining Excess Net Energy credits may then be applied to offset consumption at eligible meters on differing 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. 3. The Customer shall never deliver or attempt to deliver energy to the Company’s system when the Company’s system serving the Customer’s Generation Facility is de-energized for any reason. Idaho Power Company First Revised Sheet No. 84-6 Cancels I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 84-6 IDAHO Issued by IDAHO POWER COMPANY Issued per Order No. 34854955 Timothy E. Tatum, Vice President, Regulatory Affairs Effective – December 2, 2020March 23, 2021 1221 West Idaho Street, Boise, Idaho SCHEDULE 84 CUSTOMER ENERGY PRODUCTION NET METERING SERVICE (Continued) CONDITIONS OF PURCHASE AND SALE (Continued) 4. The Company shall not be liable directly or indirectly for permitting or continuing to allow an attachment of a Net Metering 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. 5. The Customer is responsible for all costs associated with the Generation Facility 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 Generation Facility in order to maintain a safe, reliable electrical system. 6. 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. 7. 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. 8. 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. 9. The Customer shall notify the Company immediately if an Net Metering Exporting System is permanently removed or disabled. Permanent removal or disablement for the purposes of this schedule is any removal or disablement of an Net Metering 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.