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Home My WebLink About20230814Affidavit of J. Kruck_Exhibit 1.pdfExhibit 1 - Electric Service Regulations Case No. PAC-E-23-12 First Revision of Sheet No. C I.P.U.C. No. 1 Canceling Original Sheet No. C ELECTRIC SERVICE REGULATIONS of ROCKY MOUNTAIN POWER Salt Lake City, Utah for ELECTRIC SERVICE In The STATE OF IDAHO Under IDAHO PUBLIC UTILITIES COMMISSION TARIFF NO. 1 _____________________ Issuing Officer Joelle R. Steward Vice President, Regulation Salt Lake City, UT Submitted Under Case No. PAC-E-21-07 ISSUED: November 8, 2021 EFFECTIVE: January 1, 2022 IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Feb. 1, 2022 Jan. 1, 2022 Per O.N. 35277 Jan Noriyuki Secretary Third Revision of Sheet No. D.1 I.P.U.C. No. 1 Canceling Second Revision of Sheet No. D.1 ELECTRIC SERVICE REGULATIONS STATE OF IDAHO ____________ Table of Contents ____________ Regulation No. Subject Sheet No. 1 General Provisions Sheet No. 1R.1 2 General Definitions Sheet Nos. 2R.1 - 2R.4 3 Electric Service Agreements Sheet Nos. 3R.1 - 3R.3 4 Supply and Use of Service Sheet Nos. 4R.1 - 4R.3 5 Customer's Installation Sheet Nos. 5R.1 - 5R.4 6 Company's Installation Sheet No. 6R.1 7 Metering Sheet Nos. 7R.1 - 7R.3 8 Billings Sheet Nos. 8R.1 - 8R.2 9 Deposits and Advance Payments Sheet Nos. 9R.1 - 9R.4 10 Termination of Service and Payment Arrangements Sheet Nos. 10R.1 - 10R.9 11 Taxes Sheet No. 11R.1 12 Line Extensions Sheet No. 12R.1 - 12R.15 13 Curtailment Plan for Electric Energy Sheet Nos. 13R.1 - 13R.6 25 Customer Guarantees Sheet Nos. 25R.1 - 25R.4 Electric Service Regulations are not necessarily reprinted when new Electric Service Schedules are issued. Therefore, Regulations from prior tariffs should be retained until updated. When a Regulation is updated it will be given the same tariff number as the Electric Service Schedules in effect at the time of the update. Submitted Under Case No. PAC-E-16-13 ISSUED: October 3, 2016 EFFECTIVE: February 28, 2017 IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Feb. 24, 2017 Feb. 28, 2017 Per O.N. 33721 Diane M. Hanian Secretary IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Aug. 28, 2006 Sept. 15, 2006 Jean D. Jewell Secretary IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Aug. 28, 2006 Sept. 15, 2006 Jean D. Jewell Secretary IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Aug. 28, 2006 Sept. 15, 2006 Jean D. Jewell Secretary IDAHO PUBLIC UTILITIES COMMISSION Approved Effective June 15, 2009 Sept. 1, 2009 Jean D. Jewell Secretary ~~\ ~~OUNTAIN IDAHO PUBLIC UTILITIES COMMISSIONApproved EffectiveAug. 28, 2006 Sept. 15,2006 Jean D. Jewell Secretary C. No.Original Sheet No. 2R.4 Temporary Service: Service requested for a limited period of time or of questionable duration such as, but not limited to, service for construction power, seasonal sales lots, carnivals, rock crushers or paving plants. Temporary service does not include emergency, breakdown or standby service. Termination of Service: The disconnection of electric service to a given Customer at a given location. Tract or Subdivision: An area for dwelling which may be identified by filed subdivision plats or as an area in which a group of dwellings may be constructed about the same time, either by a single builder or by several builders working on a coordinated basis. Transfer of Service: The providing of electric service to the same Customer at a different location or to a different Customer at the same location, as the facts of the situation may require. Unimproved Subdivision: A platted subdivision where the electrical distribution system was not installed by the developer. Year: The period between the date of commencement of service under the application for electric service, electric service agreement or contract and the same date of the following calendar year. Submitted Under Advice Letter No. 06- ISSUED: August 14, 2006 EFFECTIVE: September IS, 2006 IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Aug. 28, 2006 Sept. 15, 2006 Jean D. Jewell Secretary IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Aug. 28, 2006 Sept. 15, 2006 Jean D. Jewell Secretary IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Aug. 28, 2006 Sept. 15, 2006 Jean D. Jewell Secretary IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Aug. 28, 2006 Sept. 15, 2006 Jean D. Jewell Secretary ROCKY MOUNTAINPOWER A DIVISION OF PACIFICORP Second Revision of Sheet No.4R.2I.P.U.C.No.1 Canceling First Revision of Sheet No.4R.2 1.SUPPLY OF SERVICE (continued) (c)Unmetered Service 1)Fixed Loads -Service to fixed loads,with fixed periods of operation,such as streetlights,traffic lights and other similar installations may,for the convenience and mutualbenefitoftheCustomerandCompany,be unmetered.The average monthly use (one-twelfth of the annual use determined by test or estimated from equipment ratings)shall bebilledmonthlyinaccordancewiththeapplicableschedule. (2)Small Usage Devices -Devices whose total connected load does not exceed 2,000 wattsperpointofconnectionmaybeprovidedunmeteredserviceif,at the sole discretion of theCompany,usage is impractical or unsafe to meter.The kWh billed each month shall bedeterminedasthetotalkWcapacityrequirementoftheCustomer's equipment multiplied by730hours.The Customer shall specify the capacity requirement on the application forservice.Connections will be made by Company,subject to the Customer's installationmeetingalloftheCompany's design and installation requirements. The Customer shall not change the capacity requirement or other aspects of their installationwithoutfirstprovidinginwritingtotheCompanyaminimumof30daysnoticebeforechangesaremade.Customer changes that render the service ineligible for unmeteredserviceshallresultinservicebeingmetered.Under such circumstances,the Companyapprovedmeteringpoint(s)must be installed by the Customer within 30 days followingnotificationorservicewillbedisconnected. The Company shall not be required to adjust billings due to failure of the Customer'sequipment.The Company shall havethe right to test the capacity requirements of the smallusagedevicesfromtimetotime.If the Company determinesthat the capacity was under-reported by the Customeror that the Customer otherwise failed to notify the Company of anincreaseincapacity,the Company may back-bill for the incremental kWh associated withsuchincreasedcapacityasprovidedinRegulation8,section 6 -Adjustment for BillingError. 2.CUSTOMER'S USE OF SERVICE Electric service will be supplied only to those for whom the Company is the sole source of electricpowerandenergyunlessotherwiseprovidedunderanappropriateagreement.Services shall be usedbyCustomeronlyforthepurposesspecifiedintheserviceagreementandapplicableelectricservicescheduleorschedules.The Customer shall not extend his electric facilities for service to othercustomersorpremisesexceptwheretheelectricityispurchasedfromtheCompanyasdefinedinSection61-129,Idaho Code,for electric vehicle battery charging services as provided by order orruleoftheCommission. SubmittedUnder Case No.PAC-E-19-14 ISSUED:September27,2019 EFFECTIVE: IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Dec. 13, 2019 Dec. 13, 2019 Per O.N. 34504 Diane M. Hanian Secretary ROCKY MOUNTAINPOWER A DIVISION OE PACIFICORP I.P.U.C.No.1 First Revision of Sheet No.4R.3 Canceling Original Sheet No.4R.3 3.CONTINUITY OF ELECTRIC SERVICE AND INTERRUPTION (FORCE MAJEURE) Unless otherwise specified in a service agreement,electric service is intended to be continuouslyavailable.It is inherent,however,that there will at times be some degree of failure,interruption, suspension,curtailment or fluctuations.Company does not guarantee constant or uninterrupteddeliveryofElectricServiceandshallhavenoliabilitytoitsCustomersoranyotherpersonsforanyinterruption,suspension,curtailment or fluctuation in Electric Service or for any loss or damage caused thereby if such interruption,suspension,curtailment or fluctuation results from the following: (a)Causes beyond Company's reasonable control including,but not limited to,accident orcasualty,fire,flood,drought,wind,action of the elements,court orders,litigation,breakdown of or damage to facilities of Company or of third parties,acts of God,strikes orotherlabordisputes,civil,military or governmental authority,electrical disturbancesoriginatingonortransmittedthroughelectricalsystemswithwhichCompany's system isinterconnectedandactsoromissionsofthirdparties. (b)Repair,maintenance,improvement,renewal or replacement of facilities,or anydiscontinuanceofservicewhich,in Company'sjudgment,is necessary to permit repairs or changes to be made in Company's generating,transmission or distribution facilities or toeliminatethepossibilityofdamagetoCompany's property or to the persons or property ofothers.To the extent practicable,such work,repairs or changes shall be done in a mannerwhichwillminimizeinconveniencetotheCustomerand,whenever practicable,theCustomershallbegivenreasonablenoticeofsuchwork,repairs or changes. (c)Automatic or manual actions taken by Company,which in its sole judgment are necessary orprudenttoprotecttheperformance,integrity,reliability or stability of Company'selectrical system or any electrical system with which it is interconnected.Such actions shall include,but shall not be limited to,the operation of automatic or manual protection equipmentinstalledinCompany's electrical system,including,without limitation,such equipment asautomaticrelays,generatorcontrols,circuit breakers and switches. Submitted Under Case No.PAC-E-19-14 ISSUED:September 27,2019 EFFECTIVE: IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Dec. 13, 2019 Dec. 13, 2019 Per O.N. 34504 Diane M. Hanian Secretary IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Aug. 28, 2006 Sept. 15, 2006 Jean D. Jewell Secretary IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Jan. 28, 2008 Feb. 1, 2008 Jean D. Jewell Secretary IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Jan. 28, 2008 Feb. 1, 2008 Jean D. Jewell Secretary IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Aug. 28, 2006 Sept. 15, 2006 Jean D. Jewell Secretary ROCKY MOUNTAINPOWER A DIVISION OF PACIFICORP Second Revision of Sheet No.6R.1I.P.U.C.No.1 Canceling First Revision of Sheet No.6R.1 ELECTRIC SERVICE REGULATION NO.6 STATE OF IDAHO Company's Installation 1.COMPANY'S INSTALLATION Except as otherwise provided in these Regulations,an Electric Service Agreement,or the ElectricServiceSchedules,the Company will install and maintain its lines and equipment on its side of thePointofDelivery,but shall not be required to install or maintain any lines or equipment except meters and accessories beyond that point.Only the Company is authorizedto make the connections at the Point of Delivery.Electric service furnished under this tariff will be alternating current,60 hertz,single or three-phase.Primary servicevoltage will be at one of the nominal standard voltagesavailablefromtheCompanyatorneartheCustomer's location.Secondary service voltage will belimitedto: Single-phase,120 volts,2-wire,grounded Single-phase,120/240volts,3-wire,grounded Single-phase,240/480 volts,3-wire,grounded Three-phase,208Y/120 volts,4-wire,grounded,wye Three-phase,480Y/277 volts,4-wire,grounded,wye 2.COMPANY FACILITIES ON CUSTOMER'S PREMISES (a)All materials furnished and installed by the Company on the Customer's premises,shall be, and remain,the property of the Company.The Customer shall not break the Company's meter seals.In the event of loss or damage to the Company'sproperty,arising from neglect, carelessness,or misuse by the Customer,the cost of necessary repairs or replacementshall be paid by the Customer. (b)Customer without expense to the Company shall make or procure conveyance to theCompanyofsatisfactoryRights-of-Way Easements across the property owned or controlledbytheCustomerfortheCompany's lines or extensions thereof necessary or incidental to thefurnishingofservicetotheCustomer. (c)The Customershall permit safe,access to Company'srepresentativesat all hours to maintaintheCompany's electric distribution facilities.The Customer shall also permit the CompanytotrimtreesandothervegetationtotheextentnecessarytoavoidinterferencewiththeCompany's lines and to protect public safety. (d)The Customer shall provide safe,unencumbered access to Company's representatives atreasonabletimes,for the purpose of reading meters,inspecting,repairing or removingmeteringdevicesandwiringoftheCompany. SubmittedUnder Case No.PAC-E-19-12 ISSUED:September 13,2019 EFFECTIVE: IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Jan. 8, 2020 Jan. 8, 2020 Per O.N. 34526 Diane M. Hanian Secretary IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Aug. 28, 2006 Sept. 15, 2006 Jean D. Jewell Secretary IDAHO PUBLIC UTILITIES COMMISSION Approved Effective August 31, 2009 Sept. 1, 2009 Jean D. Jewell Secretary IDAHO PUBLIC UTILITIES COMMISSION Approved Effective August 31, 2009 Sept. 1, 2009 Jean D. Jewell Secretary IDAHO PUBLIC UTILITIES COMMISSION Approved Effective August 31, 2009 Sept. 1, 2009 Jean D. Jewell Secretary Second Revision of Sheet No. 8R.2 I.P.U.C. No. 1 Canceling First Revision of Sheet No. 8R.2 Submitted Under Case No. PAC-E-21-07 ISSUED: November 8, 2021 EFFECTIVE: January 1, 2022 6. ADJUSTMENT FOR BILLING ERROR Corrected billings may be made to adjust for billing errors including but not limited to reasons such as a meter malfunctioned or failed, bills were estimated, metering equipment was incorrectly installed or programmed, or bills were inaccurately prepared as follows: (a) If the time when the malfunction or error began cannot be reasonably determined to have occurred within a specific billing period, the corrected billings shall not exceed the most recent six months before the discovery of the malfunction or error. (b) If the time when the malfunction or error began can be reasonably determined and the Customer was undercharged, the corrected billing may not exceed the most recent six (6) months. If a reasonable person should have known of the incorrect billing, the adjustment may be extended for a period not to exceed three (3) years. (c) If the time when the malfunction or error began can be reasonably determined and the Customer was overcharged, the corrected billing may go back to that time but not to exceed three (3) years from the time the malfunction or error occurred. Under no circumstances shall the adjustment exceed three (3) years. 7. BILLING UNDER INAPPROPRIATE TARIFF SCHEDULE Corrected billings shall be made to adjust for billing under inappropriate tariff Schedules as follows: (a) If the time when the error began cannot be reasonably determined to have occurred within a specific billing period, the corrected bill shall not exceed the most recent six (6) months. (b) If the time when the error began can be reasonably determined and the Customer was undercharged, the corrected billing shall not exceed the most recent six (6) months. If a reasonable person should have known of the incorrect billing, the adjustment may be extended for a period not to exceed three (3) years. (c) If the time when the error can be reasonably determined and the Company determined the Customer was overcharged the corrected billing shall go back to that time, but not to exceed three (3) years from the time the error occurred. The Company shall not be required to adjust billings when it has acted in good faith based on the best available information or when the Customer was given written notice of options under the tariff schedules and did not make timely election to choose available options. 8. RETURNED PAYMENT CHARGE A charge as specified in Schedule 300 may be made and collected by Company for each payment returned by a bank to the Company. 9. PAPERLESS BILL CREDIT The Company will provide a Paperless Bill Credit as shown in Schedule 300 to Customers on a metered service schedule who enroll in paperless billing. IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Feb. 1, 2022 Jan. 1, 2022 Per O.N. 35277 Jan Noriyuki Secretary IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Aug. 28, 2006 Sept. 15, 2006 Jean D. Jewell Secretary First Revision of Sheet No. 9R.2 I.P.U.C. No. 1 Canceling Original Sheet No. 9R.2 Submitted Under Case No. PAC-E-16-06 ISSUED: February 16, 2016 EFFECTIVE: June 7, 2016 (b) Small Commercial Customers An applicant may be required to pay a deposit as a condition of service for the reasons stated in (a) above, or additionally, when the applicant is applying for service for the first time from the Company. (c) Industrial and Large Commercial Customers The Company may require a deposit from current and prospective industrial or large commercial customers for the reasons stated in (b) above, or additionally: (1) The customer fails to pay the account on or before the date such payment is delinquent. (2) The nature of the customer's operation is extremely speculative or subject to a high probability of failure. (d) Irrigation Customers The Company may require a deposit or advance from past, current, and prospective irrigation (Schedule 10) customers prior to providing electric service. (1) Irrigation Advance A. An advance may be required from current, previous, or prospective Schedule 10 customers prior to providing electric service under the following conditions: 1. If the customer had a cumulative past due balance equal to or greater than $25,000 on December 31; 2. If the customer had service disconnected for nonpayment during the last four (4) years; or 3. If at any time the customer sought any form of relief under the Federal Bankruptcy Laws, or has been discharged from bankruptcy, or whose receivership proceeding has been terminated, or whose bankruptcy proceedings have been dismissed. B. As an alternative to payment, an advance may be satisfied by: 1. A guarantee of payment from a bank or financial institution acceptable to the Company; or 2. A guarantor acceptable to the Company. (Continued) IDAHO PUBLIC UTILITIES COMMISSION Approved Effective July 5, 2016 June 7, 2016 Per O.N. 33533 Jean D. Jewell Secretary Second Revision of Sheet No. 9R.3 I.P.U.C. No. 1 Canceling First Revision of Sheet No. 9R.3 Submitted Under Case No. PAC-E-16-06 ISSUED: February 16, 2016 EFFECTIVE: June 7, 2016 (d) Irrigation Customers (continued) (1) Irrigation Advance (continued) C. The customer may be required to pay an advance on all Schedule 10 accounts for which the customer is financially responsible and requesting service. D. The advance will be equal to the estimated monthly billings for the upcoming irrigation season, based upon the previous 12 months of metered usage at each service point or estimated using the new customer’s connected horsepower. If the previous 12 months includes inactivity the estimate may include earlier periods. 1. A portion of the advance will be applied to satisfy each monthly bill until the advance is depleted. (2) Irrigation Deposit A. A deposit may be required from a current or previous Schedule 10 customer prior to providing electric service under the following conditions: 1. If the customer received two (2) or more past due notices for non-payment of Schedule 10 service during the most recent irrigation season or the last 12 month period during which service was received; 2. If the Schedule 10 customer was required to pay an advance for the previous irrigation season and the balance on December 31 was less than $25,000; or 3. If the applicant is requesting service for the first time. B. As an alternative to payment of a deposit, the applicant may obtain: 1. A guarantee of payment from a bank or financial institution acceptable to the Company; or 2. A guarantor acceptable to the Company. C. A Schedule 10 customer that meets the requirements for payment of a deposit may be required to pay a deposit for each Schedule 10 account for which the customer is financially responsible and requesting service. (Continued) IDAHO PUBLIC UTILITIES COMMISSION Approved Effective July 5, 2016 June 7, 2016 Per O.N. 33533 Jean D. Jewell Secretary First Revision of Sheet No. 9R.4 I.P.U.C. No. 1 Canceling Original Sheet No. 9R.4 Submitted Under Case No. PAC-E-16-06 ISSUED: February 16, 2016 EFFECTIVE: June 7, 2016 (d) Irrigation Customers (continued) (2) Irrigation Deposit (continued) D. The deposit for each metered service point is equal to the estimated monthly bill for the two highest months of usage within the last two (2) irrigation seasons. For new customers, deposits will be calculated using the bills from the previous customer at the new customer’s location or estimated using the new customer’s connected horsepower. (3) Irrigation Advance or Deposit Guarantor To be considered acceptable to the Company a guarantor must be: A. An active Rocky Mountain Power Schedule 10 customer; B. Current on all accounts at the time of the application with no more than one past due notice in the previous twelve months; and C. Have cumulative usage for all active Schedule 10 metered services during the previous season that equals or exceeds the estimated usage for the customer or applicant needing a guarantor. 2. BANKRUPT CUSTOMERS If an applicant for service or a customer has sought any form of relief under the Federal Bankruptcy Laws, has been brought within the jurisdiction of the bankruptcy court for any reason in an involuntary manner, or has had a receiver appointed in a state court proceeding, then a deposit or advance may be required as a condition of service. 3. EXPLANATION OF DENIAL OF SERVICE OR REQUIREMENT OF DEPOSIT If the Company denies service or requires a deposit as a condition of providing service, then it must immediately provide an explanation regarding the reason for the deposit or denial of service. If service is currently being provided to the premises occupied by an applicant, the Company shall provide written notice of its refusal to serve. 4. AMOUNT OF DEPOSIT A deposit required as a condition of service shall not exceed one-sixth of the Company's estimate of annual billings for residential and small commercial customers. For industrial and large commercial customers, deposits shall not exceed two (2) months of the Company's estimated peak billings. The Company shall advise the customer or applicant that the deposit may be paid in two (2) equal installments with the first installment paid at the time of application and the second installment paid in one (1) month. For Irrigation customers, see Sheet No. 9R.4 (d) (2) D. (Continued) IDAHO PUBLIC UTILITIES COMMISSION Approved Effective July 5, 2016 June 7, 2016 Per O.N. 33533 Jean D. Jewell Secretary I.P.U.C. No. 1 Original Sheet No. 9R.5 Submitted Under Case No. PAC-E-16-06 ISSUED: February 16, 2016 EFFECTIVE: June 7, 2016 5. INTEREST ON DEPOSITS Interest on deposits held by the Company shall be accrued at the rate established annually by the order of the Idaho Public Utilities Commission. Interest shall be computed from the time the deposit is made until it is returned or applied to the bill. Interest will not accrue on a deposit if service is terminated temporarily at the request of a customer who leaves the deposit with the Company for future use as a deposit, or if service has been permanently terminated and the Company has been unsuccessful in its attempt to refund a deposit. 6. RETURN OF DEPOSIT – ALL CUSTOMER CLASSES (a) If the customer has paid all undisputed bills and has no more than one (1) past due notice during the past twelve (12) consecutive months of service, the Company shall promptly return the deposit (with accrued interest) by either crediting the customer’s current account or issuing a refund. (b) Upon termination of service, the deposit, with accrued interest, shall be credited to the final bill. The balance of the deposit remaining, if any, shall be returned promptly to the customer. (c) The Company may withhold the release of the deposit pending the resolution of a dispute. For residential and small commercial Customers, interest will be paid for the entire period over which the deposit was held. For industrial, large commercial and irrigation customers, the Company will continue to pay interest if the resolution is in the Customer's favor. 7. TRANSFER OF DEPOSIT A Deposit, less any outstanding balance, shall be transferable and applicable for service to the same customer at a new location within the Company's service area. Deposits shall not be transferred from one customer to another customer or between classes of service. 8. RECEIPT FOR DEPOSIT When payment of a deposit is made, a receipt shall be furnished to each applicant or customer for the amount deposited. 9. RETURN OF IRRIGATION ADVANCE PAYMENTS Any customer advance remaining at the end of the irrigation season will first be applied to any required deposit for the upcoming season before being refunded to the customer. Upon customer request, the Company will conduct an in-season review of the actual electric consumption and associated advance payment. The Company may refund at the customer’s request, the portion of the advance in excess of the revised usage estimate for the remainder of that season. (Continued) IDAHO PUBLIC UTILITIES COMMISSION Approved Effective July 5, 2016 June 7, 2016 Per O.N. 33533 Jean D. Jewell Secretary I.P.U.C. No. 1 Original Sheet No. 9R.6 Submitted Under Case No. PAC-E-16-06 ISSUED: February 16, 2016 EFFECTIVE: June 7, 2016 10. LARGER OR NEW DEPOSITS AND IRRIGATION ADVANCES Nothing in this regulation shall prevent the Company from requiring a deposit or advance or a larger deposit or advance from existing customers in conformity with the standards set forth in this regulation. Should a larger or new deposit or advance be required, the reason therefor shall be specified in writing to the customer. IDAHO PUBLIC UTILITIES COMMISSION Approved Effective July 5, 2016 June 7, 2016 Per O.N. 33533 Jean D. Jewell Secretary IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Aug. 28, 2006 Sept. 15, 2006 Jean D. Jewell Secretary IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Aug. 28, 2006 Sept. 15, 2006 Jean D. Jewell Secretary IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Aug. 28, 2006 Sept. 15, 2006 Jean D. Jewell Secretary IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Aug. 28, 2006 Sept. 15, 2006 Jean D. Jewell Secretary IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Aug. 28, 2006 Sept. 15, 2006 Jean D. Jewell Secretary IDAHO PUBLIC UTILITIES COMMISSION Approved Effective August 31, 2009 Sept. 1, 2009 Jean D. Jewell Secretary Second Revision of Sheet No. 10R.7 I.P.U.C. No. 1 Canceling First Revision of Sheet No. 10R.7 Submitted Under Advice Letter No. 15-01 ISSUED: April 23, 2015 EFFECTIVE: May 18, 2015 7. RESTRICTIONS ON TERMINATION OF SERVICE (continued) (e) The Company will not terminate service without written notice to the residents or occupants of a building or mobile home court where service is master-metered or a residence where the Customer billed is not a resident or occupant of the premises being served. The Company will notify the residents or occupants of its intent to terminate service at least two (2) calendar days, excluding weekends and holidays, prior to the proposed date of termination and shall afford the person or persons receiving the service, a reasonable opportunity to negotiate directly with the Company and to purchase service in their own names. 8. PAYMENT ARRANGEMENTS (a) When a Customer cannot pay a bill in full, the Company shall continue to serve the Customer if the Customer and the Company agree on a reasonable portion of the outstanding bill to be paid immediately, and the manner in which the balance of the outstanding bill shall be paid. (b) In deciding on the reasonableness of a particular agreement, the Company will take into account the Customer's ability to pay, the size of the unpaid balance, the Customer's payment history, and the amount of time and reasons why the debt is outstanding. (c) Payments are to be applied to the oldest balance owed on the Customer's bill, except in the case of a disputed bill. If the Customer disputes a bill, the Customer's payments are to be applied to the oldest undisputed amount. (d) If a Customer fails to make the payment agreed upon by the date that it is due, the Company may, but is not obligated to, enter into a second such agreement. (e) No payment arrangement shall be binding upon a Customer if it requires the Customer to forego any right provided for in these regulations. (f) Payment arrangements may be in the form of a Level Pay Plan that will equalize monthly payments of all arrears, if any, and anticipated future bill amounts over a period of not less than one year. No Customer agreeing to a reasonable payment arrangement is required to choose this plan. (g) The first payment under the arrangement will be due one business day after the arrangement, unless the Company grants an extension. If the initial payment is not made, or if any check not honored by the bank is offered as initial payment, the Company may terminate service upon 24-hour notice to the Customer. (Continued) IDAHO PUBLIC UTILITIES COMMISSION Approved Effective May 11, 2015 May 18, 2015 Jean D. Jewell Secretary Second Revision of Sheet No. 10R.8 I.P.U.C. No. 1 Canceling First Revision of Sheet No. 10R.8 Submitted Under Advice No. 15-01 ISSUED: April 23, 2015 EFFECTIVE: May 18, 2015 8. PAYMENT ARRANGEMENTS (continued) (h) If the Company has been unable to contact a Customer concerning termination, but has contacted the Customer's third party and has failed to receive a response from the Customer within seven days after the third party was contacted, the Company may treat the Customer as one who has been contacted and has declined to enter into a reasonable payment arrangement. 9. CHARGES FOR COLLECTION ACTIVITY (a) Reconnection Charge: Whenever service has been discontinued by Company because of any default by the Customer, as provided in these rules, a charge to cover the cost of reconnection as specified in Schedule 300 may be collected by Company before service is restored. Customers who make satisfactory arrangements with Company between the hours of 8:00 a.m. and 7:00 p.m., Monday through Friday, excluding holidays, or between the hours of 8:00 a.m. and 4:00 p.m. on holidays and weekends, will have service reconnected the same day. Except for medical emergencies, reconnections required for safety reasons or where customers are disconnected in error, requests for reconnection received by Company during all other hours will be completed on the following day. (b) Tampering/Unauthorized Reconnection Charge: Where damage to Company’s facilities has occurred due to tampering or where reconnection of service has been made by other than Company Personnel a Tampering/Unauthorized Reconnection Charge may be collected as specified in Schedule No. 300. This charge is not a waiver by Company of the rights to recover losses due to tampering. In addition to the above mentioned charge, person receiving service shall be responsible for paying for any damages to the Company’s equipment as a result of tampering. (c) Field Visit Charge: The Company may assess the Customer the Field Visit Charge shown on Schedule 300 when an employee visits a Customer’s address, intending to disconnect service, but at the time of the visit, disconnection is either delayed or postponed to provide the Customer additional time to pay, make payment arrangements, or provide proof of payment; or the disconnection is prevented by an intentional action taken by the Customer, such as obstructing access to the Customer’s meter or threatening to cause or causing physical harm to the Company representative. 10. RESTORATION OF SERVICE The Company will restore service only when the following conditions are met: (a) The cause of the discontinuance has been removed if that cause was for any reason other than for the nonpayment of proper charges when due; (Continued) IDAHO PUBLIC UTILITIES COMMISSION Approved Effective May 11, 2015 May 18, 2015 Jean D. Jewell Secretary IDAHO PUBLIC UTILITIES COMMISSION Approved Effective August 31, 2009 Sept. 1, 2009 Jean D. Jewell Secretary IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Aug. 28, 2006 Sept. 15, 2006 Jean D. Jewell Secretary First Revision of Sheet No. 12R.1 I.P.U.C. No. 1 Canceling Original Sheet No. 12R.1 ELECTRIC SERVICE REGULATION NO. 12 STATE OF IDAHO __________ Line Extensions __________ 1. CONDITIONS AND DEFINITIONS (a) Contracts -- Before building an Extension, the Company may require the Applicant to sign a contract. Where a tenant occupies the service location, the Company may require the property owner to sign the contract. (b) Contract Minimum Billing -- The Contract Minimum Billing is the greater of: (1) the Customer's monthly bill; or (2) 80% of the Customer's monthly bill plus the Facilities Charges. Customers on a seasonal rate receive an annual Contract Minimum Billing of the greater of (1) the Customer's annual bill; or (2) 80% of the Customer's annual bill plus the Annual Facilities Charge. The Annual Facilities Charge is twelve (12) times the Facilities Charges. Any Contracted Minimum Billings shall begin upon the date service is first delivered or 30 days after the completion of the extension whichever occurs first, as determined by the Company, unless a later date is mutually agreed upon. Subsequent Customers shall also pay the Contract Minimum Billing as specified in Regulation 3. (c) Engineering Costs -- The Company includes designing, engineering and estimating in its Extension Costs. The Company will provide these services at no charge unless, in the Company’s judgment, it determines the extension is large, complex or speculative. For large, complex or speculative Extensions, the Applicant or Customer must advance the Company’s estimated Engineering Costs, but not less than the minimum specified in Schedule 300. The Company will apply this advance payment to its Extension Costs. If the Extension Allowance exceeds the Extension Costs, the Company will refund the excess up to the amount of the Applicant’s or Customer’s advance. (Continued) Submitted Under Case No. PAC-E-16-13 ISSUED: October 3, 2016 EFFECTIVE: February 28, 2017 IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Feb. 24, 2017 Feb. 28, 2017 Per O.N. 33721 Diane M. Hanian Secretary ROCKY MOUNTAINPOWER Third Revision of Sheet No.12R.2 I.P.U.C.No.1 Canceling Second Revision of Sheet No.12R.2 1.CONDITIONS AND DEFINITIONS (continued) (c)Engineering Costs --(continued) If the Applicant or Customer requests changes that require additional estimates,they must advance the Company's estimated Engineering Costs,but not less than the minimum speciñed in Schedule 300 for each additional estimate.The Company will not refund or credit this payment. (d)Extension --A branch from,or a continuation of,a Company owned transmission or distribution line where a line has not been removed,at customer request,within the last five (5)years.An extension may be single-phase,three-phase,a conversion of a single-phase line to a three-phase line,the provision of additionalcapacity in existing lines,substations or other facilities,or addition of new distribution or transmission facilities.The Company will own,operate and maintain all Extensions made under this regulation. (e)Extension Allowance -The Extension Allowance is the portion of the Extension that the Company provides or allows without cost to the Applicant.The portion will vary with the class of service that the Applicant requests and is the lesser of:the maximum potential extension allowance;or the Extension Cost.The Extension Allowance does not include costs resulting from:additional voltages;duplicate facilities;additional points of delivery; or any other Applicant requested facilities that add to,or substitute for,the Company's standard construction methods or preferredroute.An Extension Allowance will be provided only if the Company has reasonable assurance as to the permanent continuation of required revenue.The Extension Allowance is not available to customers receiving electric service under special pricing contracts. (f)Extension Costs --Extension Costs are the Company's total costs for constructing an Extension using the Company's standard construction methods,including services, transformers and meters,labor,materials and overheads. (g)Extension Limits --The provisions of this regulation apply to Line Extensions that require standard construction and will produce sufficient revenues to cover the ongoing costs associated with them.The Company will construct Line Extensions with special requirements or limited revenues under the terms of special contracts. Examples of special requirements include,but are not limited to,unusual costs incurred for obtainingrights-of-way,overtime wages,use of special equipment and facilities,accelerated work schedules to meet the applicant's request,or non-standard construction requirements. (Continued) Submitted UnderCase No.PAC-E-19-19 ISSUED:November22,2019 EFFECTIVE:February 21,2020 IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Feb. 20, 2020 Feb. 21, 2020 Per O.N. 34558 Diane M. Hanian Secretary ROCKY MOUNTAINPOWER OF PA BCORP Second Revision of Sheet No.12R.3I.P.U.C.No.1 Canceling First Revision of Sheet No.12R.3 1.CONDITIONSAND DEFINITIONS (continued) (h)Facilities Charges --The Facilities Charges are those costs associated with the ownership, operation and maintenance of facilities built to provide service and are in addition to rate schedule billings.Schedule 300 specifies the Facilities Charges. (i)Mixed Use -Refers to an Extension request with both residential and non-residentialloads. Shared Extension costs are allocated to residential and non-residentialproportional to their respective loads to the total load on the shared facilities.The provisions for Residential Extensions will be applied to the residential share of the costs and the provisions forNonresidentialExtensionswillbeappliedtothenonresidentialshareofthecosts. (j)Permanent Service -Service to Customers where the Company is assured of continued useformorethanfiveyears,unless a contract specifies otherwise. (k)Refunds -An Applicant who paid a refundableadvance on an Extension,acquired right-of- way,and/or provided labor and material on an undergroundExtension,is eligible for up tofourrefundsduringthefirstfive(5)years.Within that five (5)year period the Applicant may waive any refund that is less than 20%of the Applicant's total fund base amount in order to accept four (4)refunds ofTering greater value.An Applicant is not eligible for refunds from future Extension applications from themselves. The refund base amount (refundableadvance)on an Applicant's advance are those Extension costs that meet the eligibility criteria of an Extension Allowance.This occurs when the eligible Extension costs exceed the maximum potential allowance.The refundbase amount for Applicant acquired right-of-way will be determined by using the Company's standard right-of-way costing.For privateproperty this is a percentage of the right-of-way land value as determined from the county assessor's property land value.Where there aremultipleright-of-way segments,the refund will be determined using an average of the costs. The refund base amount for Applicant provided labor and material on an underground Extension will be determined by applying the Company'saverage costs for standard trenching,conduits and vaults (equipmentfoundations)with footages and sizes as per the Company's design. Advances,right-of-way,labor,and material are not refundableif there is an allocation based on Applicant demand.The Applicant pays and providestheir share and the Company pays and providesthe remainder. For non-waived refunds the additional Applicants must pay the Company,prior to connection,as provided in the section for the original Applicant.The Company will refund such payments to the Applicant(s)who paid the refundableadvance,acquired right-of-way, and/or provided labor and material on an undergroundExtension.The Company will not collect from additional Applicants any portion of a waived refund. (continued) Submitted Under Case No.PAC-E-19-19 ISSUED:November22,2019 EFFECTIVE:February 21,2020 IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Feb. 20, 2020 Feb. 21, 2020 Per O.N. 34558 Diane M. Hanian Secretary ROCKY MOUNTAINPOWER A DiviSION OF P^DFICORP Fourth Revision of Sheet No.12R.4I.P.U.C.No.l Canceling Third Revision of Sheet No.12R.4 1.CONDITIONS AND DEFINITIONS (continued) An Applicant to whom a refund is due,but who the Company has failed to identify or has been unable to locate,has 24 months from the connection of the additional Applicant to request theirrefund. (1)Restrictions --The Company's Extension of facilities is subject to restrictions imposed during war or other emergencies,by the laws of the United States,the State of Idaho,by executive and administrative proclamations,by orders or regulations of the Commission or by any lawful requirementof a governmentalbody. (m)Routes,Easements and Rights-of-Way --The Company will select the route of an Extension in cooperation with the Applicant.The Applicant must pay all costs,including renewal costs,of obtaining complete,unencumbered,rights-of-way,easements,or licenses to use land,andforanypreparationorclearingtheCompanymayrequire.Any requiredeasements will be prepared on Company-provided forms.If requested by the Applicant,the Company will assist in obtaining rights-of-way,easements or licenses as described above at the Applicant's expense. (n)Regulation Previously in Effect --Regulation changes do not modify existing Extension contracts.If a Customer advanced funds for an Extension under a regulation or a contract previously in effect,the Company will make refunds for additional Customers as specified in the previousregulationor contract. (o)Service Conductors --The secondary-voltageconductors extending from the pole line,the underground secondary-voltagemain,a secondary-voltagetransformer,or a secondary- voltage switch cabinet to the Point of Delivery. 2.RESIDENTIAL EXTENSIONS (a)Standard Residential (1)Extension Allowances The Extension Allowance for a permanent residential application in a planned developmentwhere secondary voltage service has been provided to the lot line by the developer,and only a service and meter is required,is $550 per residence.The Extension Allowance for all other permanent residential applications is $1550 per residence.The Extension Allowance for upgrades necessitated by additional load is $550 if just the service requires an upgrade,and $1550 if secondary or the transformer require upgrading,if the Customer is responsible for the upgrade as given in section 2(d)TransformationFacilities. (continued) Submitted UnderCase No.PAC-E-19-19 ISSUED:November22,2019 EFFECTIVE:February 21,2020 IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Feb. 20, 2020 Feb. 21, 2020 Per O.N. 34558 Diane M. Hanian Secretary ROCKY MOUNTAINPOWER Fourth Revision of Sheet No.12R.5 I.P.U.C.No.1 Canceling Third Revision of Sheet No.12R.5 2.RESIDENTIAL EXTENSIONS (a)Standard Residential (continued) (2)Additional Customers,Advances and Refunds A Customer that pays for a portion of the construction of an Extension,acquires right-of-way,and/or provides labor and material on an undergroundExtension,mayreceiverefundsifadditionalApplicantsconnecttotheExtension.The Customer is eligible for refunds during the first five (5)years following construction of an Extension for up to four (4)additional Applicants as given in section 1(k)Refunds. Each of these four (4)Applicants utilizing any portion of the initial extension,for which a refund was not waived,must pay the Company,prior to connect,20%of the refund base amount of shared facilities.The Company will refund such payments to the initial Customer. (b)Remote Service (1)Extension Allowances Residential Customers defined as Remote Service Customers either at a single location or a group of locations,as in Unimproved Subdivisions,have the same Extension Allowance as Standard Residential Customers. (2)Contracts The Company will make Extensions for residential Remote Service Applicants according to the terms of a written contract.The contract will require the Applicant to advance the estimated cost of facilities in excess of the Extension Allowance.As long as the Applicant meets the definition of Remote Service they shall also pay a Contract Minimum Billing.Primary residences with revenues equal to or greater than average residential revenues will no longer be considered Remote when the density of such residences exceeds one residence per one-half mile of line. Facilities Charges will cease when Customers are no longer considered Remote. The Contract Minimum Billing will not include Facilities Charges on the first one- half mile of line from the Company's existing distribution facilities.Where there are groups of remote facilities only the first one-half mile is exempt from Facilities Charges. After the initial five (5)year contract period,Remote service Contract Minimum Billings also end upon termination of electric serve to the Customer's premises and Customer payment of all removal costs for inactive facilities. (continued) Submitted Under Case No.PAC-E-19-19 ISSUED:November22,2019 EFFECTIVE:February 21,2020 IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Feb. 20, 2020 Feb. 21, 2020 Per O.N. 34558 Diane M. Hanian Secretary ROCKY MOUNTAIN POWER A DIVISION OF PActFICORP Fourth Revision of Sheet No.12R.6 I.P.U.C.No.1 Canceling Third Revision of Sheet No.12R.6 (b)RemoteService (continued) (3)Additional Customers,Advances and Refunds The initial Customer that pays an advance for a portion of the construction of an Extension,acquires right-of-way,and/or provides labor and material on an undergroundExtension,may receiverefunds if additional Applicants connect to the Extension.The Customer is eligible for refunds during the first five (5)years following construction of the Extension for up to four (4)additional Applicants as given in section l(k)Refunds.Each of these four (4)Applicants utilizing any portion of the initial extension,for which a refund was not waived,must pay the Company,prior to connection,20%of the reftmd base amount of shared facilities. The Company will refund such payments to the initial Customer. Additional Applicants who pay an advance that is refunded to a Remote Service Customer are also responsible for the Facilities Charges,if any,associated with the facilities for which the refund was made.They must also pay the estimated cost of facilities for their extension exceeding their Extension Allowance and are responsible for the Facilities Charges on their extension in accordance with section 2(b)(2)Contracts. (c)Three Phase Residential Service In addition to other applicable charges,where three phase residential service is requested, the Applicant shall pay the differencein cost between single phase and three phase service. (d)Transformation Facilities When an existing residential Customer adds load,or a new residential Customer builds in a subdivision where a secondary service connection point has been installed at the lot line as provided under section 4(b)of this regulation,and the cumulative loads exceed the existing transformer's,service conductor's or other equipment's rated design capacity: (1)The facility upgradeshall be treated as a standard line extension if Customer°s demandexceeds 25 kVA.or if the facilities only serve that Customer. (2)The facility upgradeshall be treated as a system improvement and not be chargedto the Customer if the Customer's demand does not exceed 25 kVA and the facilities are shared by two (2)or more customers. Upgrades and modifications to correct service quality issues are done at the expense of the Customer causing the service quality issue. Submitted UnderCase No.PAC-E-19-19 ISSUED:November 22,2019 EFFECTIVE:February 21,2020 IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Feb. 20, 2020 Feb. 21, 2020 Per O.N. 34558 Diane M. Hanian Secretary ROCKY MOUNTAINPOWER A DIVI5lON OF PACIFICORP Fourth Revision of Sheet No.12R.7 I.P.U.C.No.1 Canceling Fifth Revision Sheet No.12R.7 2.RESIDENTIAL EXTENSIONS (continued) (e)Underground Extensions The Company will construct undergroundExtensions when requested by the Applicant or if required by local ordinance or conditions.In addition to the requirements of the preceding sections,the Applicant must provide,at their expense,all trenching and backfilling, imported backfill material,conduits,and equipment foundations that the Company requires for the Extension. For conversionof any existing overhead facilities to underground,the terms of Section 6. Relocation or Replacement of Facilities apply. 3.NONRESIDENTIAL EXTENSIONS Applicant loads of a speculative nature or of questionable permanency either in duration or size of load that exceed the Company's engineering loading limits for one circuit at the local primary distribution voltage shall take delivery at the locally available transmission voltage (at or above 46,000 volts). (a)Extension Allowances -Delivery at 46,000 Volts and above The Company will grant Customers taking service at 46.000 volts or greater an extension allowance of the meter,current transformers and potential transformers necessary to measure the Customer's usage.Other than the extension allowance,the Customer is subject to the same Extension provisionsas a Customer who takes service at less than 46,000 volts. (b)Extension Allowances -Delivery at less than 46,000 Volts (1)Less than 1,000 kVA The Company will grant Nonresidential Applicants requiring less than 1,000 kVA an Extension Allowance equal to nine (9)times the estimated average monthly revenue the Applicant will pay the Company.The Applicant must advance the costs exceeding the Extension Allowance prior to the start of construction. The Company may require the Customer to pay a Contract Minimum Billing for five (5)years.Remote Service customers must pay a Contract Minimum Billing for as long as service is taken,but in no case less than five (5)years,nor more than 30 years. (2)1,000 kVA or Greater The Company will grant Nonresidential Applicants requiring 1,000 kW or greater an Extension Allowance equal to nine (9)times the estimated average monthly revenue the Applicant will pay the Company.The Applicant must advance the costs exceeding the Extension Allowance.Fifty percent of the advance is due when the contract is executed with the remaining balance due upon completion of the Extension. (continued) Submitted Under Case No.PAC-E-19-19 ISSUED:November22,2019 EFFECTIVE:February 21,2020 IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Feb. 20, 2020 Feb. 21, 2020 Per O.N. 34558 Diane M. Hanian Secretary Fifth Revision of Sheet No. 12R.8 I.P.U.C. No. 1 Canceling Fourth Revision of Sheet No. 12R.8 Submitted Under Advice No. PAC-E-20-01 ISSUED: October 12, 2020 EFFECTIVE: December 15, 2020 (2) 1,000 kVA or Greater (continued) The Customer must pay a Contract Minimum Billing for as long as service is taken, but in no case less than five (5) years, nor more than thirty years. If service is terminated within the first 10 years, the Customer must pay a termination charge equal to the Extension Allowance less 1/10th of the allowance for each year service was taken. (3) Additional Capacity The Extension Allowance for Customers where it is necessary for the Company to increase the capacity of their facilities to serve the Customer’s additional load is calculated on the increase in revenue as a result of the load increase. (c) Additional Customers, Advances and Refunds For facilities that a Customer pays for a portion of a Line Extension upgrade, based on the ratio of their new load to the available capacity and the Company pays for the remainder, there are no refunds. However during the first five (5) years following construction of the Line Extension upgrade, each of the next four 1,000 kVA or greater Applicants utilizing these facilities must pay the Company, prior to connection, their proportionate share of the upgrade costs. Otherwise a Customer that pays for a portion of the construction of an Extension, acquires right-of-way, and/or provides labor and material on an underground Extension, may receive refunds if additional Customers connect to the Extension. The Customer is eligible for refunds during the first five (5) years following construction of an Extension for up to four (4) additional Applicants as given in section 1(k) Refunds. Each of these four (4) Applicants utilizing any segment of the initial Extension, for which a refund was not waived, must pay the Company, prior to connection, a proportionate share of the refund base amount of the shared facilities. The Company will refund such payments to the preceding Customer(s). Proportionate Share = (A + B) x C Where: A = [Shared footage of line] x [Average cost per foot of the line] B = Cost of the other shared distribution equipment, if applicable C = [New additional connected load]/[Total connected load] The Facilities Charges of refunds are re-allocated to the Applicant paying the refund. (d) Reduction in Contract Capacity or Demand The Company is not obligated to reserve capacity in Company substations or on Company lines, or maintain service facilities in place in excess of the maximum recorded and billed Customer demand in the most recent 36 months, unless contract provisions providing for greater demand are less than 36 months old. (continued) IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Oct. 20, 2020 Dec. 15, 2020 Jan Noriyuki Secretary ROCKY MOUNTAINPOWER A DIVISION OF PACIFICORP Third Revision of Sheet No.12R.9 I.P.U.C.No.1 Canceling Second Revision to Sheet No.12R.9 3.NONRESIDENTIAL EXTENSIONS (continued) (e)Underground Extensions The Company will construct underground Extensions when requested by the Applicant or if required by local ordinance or conditions.For underground,in addition to the preceding sections,the Applicant must provide,at their expense,all trenching and backfilling. imported backñll material,conduits,and equipment foundationsthat the Company requires for the Extension.When the Extension is to property that is not part of an improved development,the Company may require the Applicant to pay for facilities on the Applicant's property to provide for additional service reliability or for future development. For conversion of any existing overhead facilities to underground,the terms of Section 6. Relocation or Replacement of Facilities apply. (f)Other Requirements When the Extension is to property that is not part of an improved development,the Company may require the Applicant to pay for the line Extension within or along sideApplicant's property as part of installing a loop feed or to provide for future development. (g)Street Lighting The Extension Allowance to street lights taking service under Rate Schedule I l or 12 is equal to five times the annual revenue from the lights to be added.The Applicant must provide a non-reftmdableadvance for costs exceeding the Extension Allowance prior to the lights being added.Facilities charges and Contract Minimum Billings do not apply to streetlighting. 4.EXTENSIONS TO NON-RESIDENTIAL AND RESIDENTIAL PLANNED DEVELOPMENTS (a)General Planned developments,including subdivisions,commercial parks and industrial parks.are areas where groups of dwellings or buildings are planned to be constructed at or about the same time. (1)Improved Planned Developments The Company will install facilities in planned developments.for which a recorded plat has been provided,before there are actual Applicants for service under the terms of a written contract.The Company shall not be required to make Extensions to areas where there is not reasonable assurance of actual Applicants for service withinfive(5)years. (continued) Submitted Under Case No.PAC-E-19-19 ISSUED:November22,2019 EFFECTIVE:February 2!,2020 IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Feb. 20, 2020 Feb. 21, 2020 Per O.N. 34558 Diane M. Hanian Secretary ROCKY MOUNTAIN POWER A DIVISION OF PACIFICORP Third Revision of Sheet No.12R.10I.P.U.C.No.1 Canceling Second Revision of Sheet No.12R.10 (a)General (continued) (2)Unimproved Planned Developments Unimproved planned developments are those where the developer has not contracted with the Company to install facilities to serve each lot before there are actual Applicants for service.Applicants for service in an unimproveddevelopment will receive service under the provisions for residential and non-residential extensions,but with the design and installation of the extension within the unimproveddevelopmentincluding accommodation for future loads on platted lots along the route of the extension. (b)Allowances and Advances for Improved Planned Developments For residential developments the Company will provide the Developer an ExtensionAllowanceof$1000 for each lot to which secondary voltage service is made availableat the lot line.If,due to lot size or other constraints,the Company determines the voltagedrop on future service runs is likely to exceed that allowed.transformers and secondary will not be installed,and no allowancegranted to the developerfor those lots.The Developermust pay an advance for all costs in excess of the allowance.Service to dwellings on the lots will be provided under the provision of section 2.Residential Extensions. For nonresidential developments the Developer must pay an advance of the Company's estimated installed costs to provide primary voltageconnection points to each lot.Service to the buildings will be provided from the primary voltage connection points under the provisions of section 3.NonresidentialExtensions. For both residential and nonresidential developments the Company may require the Developerto pay for line Extensions to,within and alongside their developmentas part of installing a loop feed or to provide for future development. (c)Refunds The Company will make no refunds on Developeradvances,Developer acquired right-of- way,and/or Developer provided labor and material for facilities installed within a developmentfor the exclusive purpose of servingthe development. A Developerwho paid a reftmdableadvance on an Extension,acquired right-of-way,and/or has provided labor and material on an undergroundExtension,may receive reftmds when an Applicant outside the developmentreceives power from the Extension by connecting to a primary voltage line installed to.alongside,or through the development.The Developeris eligible for refunds during the first five (5)years following construction of the Extension for up to four (4)additional Applicants as given in section 1(k)Refunds.Each of these Applicants,for which a refund was not waived,must pay the Company prior to connection, 20%of the Developer's refund base amotmt for the shared facilities.The Company will reftmd such payments to the Developer. (continued) Submitted UnderCase No.PAC-E-19-19 ISSUED:November 22,2019 EFFECTIVE:February 21,2020 IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Feb. 20, 2020 Feb. 21, 2020 Per O.N. 34558 Diane M. Hanian Secretary ROCKY MOUNTAINPOWER A DIVISION OF PACIFICORP Third Revision of Sheet No.12R.ll I.P-U.C.No.1 Canceling Second Revision of Sheet No.12R.11 (c)Refunds (continued) For facilities that a Developer pays a portion of the cost based on the ratio of their new load to the available capacity,and the Cornpany pays the remainder,there are no refunds. (d)Underground Extensions The Company will construct undergroundExtensions when requested by the Developeror requiredby local ordinances or conditions.The Developermust provide.at their expense,alltrenchingandbacktilling,imported backfill material.conduits,and equipment foundations that the Company requires. For conversionof any existing overhead facilities to underground.the terms of Section 6. Relocation or Replacement of Facilities of this regulationapply. 5.EXTENSION EXCEPTIONS (a)Applicant Built Line Extensions (1)General An Applicant may contract with someone other than the Company to build a LineExtension.The following circumstances.however,are not an option for Applicant Built Line Extensions:relocations.conversions from overhead to underground,going from single phase to three-phase,or increasing the capacity of facilities.TheApplicantmustcontractwiththeCompanybeforestartingconstructionofanApplicantBuiltLineExtension.When the Applicant has completed construction of the Line Extension and the Company approves it,the Company will connect it to the Company's facilities and assume ownership. (2)Liability and Insurance The Applicant assumes all risks for the Construction of an Applicant Built Line Extension.Before starting construction,the Applicant must furnish a certificate naming the Company as an additional insured for a minimum of $1,000,000.TheApplicantmaycancelthepolicyaftertheCompanyacceptsownershipoftheLine Extension. (3)Advance for Design,Specifications,Material Standards and Inspections The Applicant must advance the Company's estimated costs for design, specifications,material standards and inspections.When the Applicant has completed construction,the Company will determine its actual costs and may adjust that portion of the Applicant's advance.If the actual costs exceed the Applicant's advance,the Applicant must pay the differencebefore the Company will accept and energize the I.ine Extension.If the actual costs are less than the Applicant's advance,the Company will refund the difference. Submitted Under Case No.PAC-E-l9-19 ISSUED:November 22,2019 EFFECTIVE:February 21,2020 IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Feb. 20, 2020 Feb. 21, 2020 Per O.N. 34558 Diane M. Hanian Secretary ROCKY MOUNTAINPOWER A DIVISION OF PACIFICOAP Third Revision of Sheet No.12R.12I.P.U.C.No.I Canceling Second Revision of Sheet No.12R.12 (3)Advance for Design,Specifications,Material Standards and Inspections (continued) The Company will estimate the frequency of inspections and convey this to the Applicant prior to the signing of the contract.For undergroundLine Extensions,the Company may require that an inspector be present whenever installation work is done. (4)Construction Standard The Applicant must construct the Line Extension in accordance with the Company's design,specifications,and material standards and along the Company's selected route.Otherwise,the Company will not accept or energize the Line Extension. (5)Transfer of Ownership Upon approvalof the construction.the Company will assume ownershipof the Line Extension.The Applicant must provide the Company unencumbered title to the Line Extension. (6)Rights-of-Way The Applicant must provide to the Company all required rights-of-way,easements and permits in accordance with paragraph 1.(m)in this regulation. (7)Contract Minimum Billing The Company may require the Applicant to pay a Contract Minimum Billing asdefinedinparagraph1.(b)in this regulation. (8)Deficiencies in Construction If.within 24 months of the time the Company energized the Line Extension.it determines that the Applicant provided deficient material or workmanship,the Applicant must pay the cost to correct the deficiency.At its discretion,the Company may require that the Applicant provide a faithful performance bond before the Applicant begins construction. (9)Line Extension Value The Company will calculate the value of a Line Extension using its standard estimating methods.The Company will use the Line Extension Value to calculate Contract Minimum Billings.reimbursements,and refunds. (10)Line Extension Allowance After assuming ownership,the Company will calculate the appropriate Extension Allowance.The Company will then reimburse the Applicant for the construction costs covered by the Extension Allowance,less the cost of any Company provided equipment or services,but in no case more than the Line Extension Value. (continued) Submitted Linder Case No.PAC-E-19-19 ISSUED:November22.2019 EFFECTIVE:February 2 I,2020 IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Feb. 20, 2020 Feb. 21, 2020 Per O.N. 34558 Diane M. Hanian Secretary ROCKY MOUNTAIN POWER 'DiviblON OF PACIRCORP Third Revision of Sheet No.12R.13 I.P.U.C.No.I Canceling Second Revision of Sheet No.12R.13 5.EXTENSION EXCEPTIONS (continued) (b)Duplicate Service Facilities The Company will furnish Duplicate Service Facilities if the Customer advances the estimated costs for facilities in excess of those which the Company would otherwise provide.The Customer also must pay Facilities Charges for the Duplicate Facilities for as long as service is taken,but in no case less than five (5)years. (c)Emergency Service The Company will grant Applicants requesting Emergency Service an Extension Allowance equal to the nine times the estimated average monthly revenue the Applicant will pay the Company.The Applicant must advance the costs exceeding the Extension Allowance prior to the start of construction.The Applicant must also pay a Contract Minimum Billing for as long as service is taken,but in no case less than five (5)years. (d)Highly Fluctuating Loads The Companywill furnish facilities for Highly Fluctuating Loads as defined in Regulation2 of this tariff,provided that the Applicant agrees to advance to the Company the estimated installed cost of such facilities over the cost of facilities which the Company,in its sole discretion,would otherwise provide.The Applicant shall also pay a Contract Minimum Billing as long as service is taken but in no case less than five (5)years.The Company reserves the right,should the effect of load fluctuations become in the Company's sole judgment a detriment to service to other Customers,to provide or require the Customer to provide corrective facilities.Where the Company provides such facilities the Customer shall pay the cost of all such facilities plus the associated Contract Minimum Billing. (e)Nouresidential Remote Loads in Isolated Locations The Companywill furnish facilities for Remote Service,as defined in RegulationNo.2,for nonresidentialloads under the terms of this tariff However if the cost to provide service to the point of delivery is more than five times the estimated annual revenue from the remote nonresidentialCustomer,the Contract Minimum Billing will continue for as long as service continues unless and until the load is no longer distant nor isolated.An isolated location is one where additional developmentis unlikely due to geographicalconstraints. (f)Temporary Service (1)For Temporary Service requests requiring only a service loop connection and where there are 120/240 volt facilities of adequate capacity available,the Customer shall pay the connect and disconnect charge specified in Schedule 300. (2)For all other TemporaryService requests the Customer shall pay a.the estimated installation cost,plus b.the estimated removal cost,plus c.the estimated cost for rearrangingany existing facilities,less d.the estimated salvage value of the facilities required to provide Temporary Service. (continued) Submitted Under Case No.PAC-E-19-19 ISSUED:November22,2019 EFFECTIVE:February 21,2020 IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Feb. 20, 2020 Feb. 21, 2020 Per O.N. 34558 Diane M. Hanian Secretary ROCKY MOUNTAINPOWER A DIVISION OF PAClRCORP First Revision of Sheet No.12R.14I.P.U.C.No.1 Canceling Original Sheet No.12R.14 (1)Temporary Service (continued) (3)The Customer is also responsible for electric service supplied under the appropriate rate schedule;any advances required for sharing previous Extensions;and,dependingon the customer class,Contract Minimum Billings. (4)If a Customer takes Temporary Service continuously for 60 consecutive months, the Company will classify the Extension as permanent and refund any payment the Customer made over that requiredof a permanent Customer.The Company will not refund the Facilities Charges. (g)Line Capacity in Excess of that Required if the Company desires to construct lines having a larger capacity or more expensive type of construction than is practical under the circumstances or necessary in accordance with soundengineeringstandardsandpracticestosupplytheenergyrequirementsofCustomerswho obtain service in accordance with this regulation,the cost of construction of that additional line capacity shall be borne completely by the Company and not be considered indeterminingtheContractMinimumBillingoradvancesmadebyApplicantsforservice, 6.RELOCATION OR REPLACEMENT OF FACILITIES (a)Relocation of Facilities if requested by an Applicant or Customer,and adequate clearances can be maintained and adequate easements/rights-of-waycan be obtained,the Company will:relocate distributionfacilitiesonto,or adjacent to,the Customer's premises;and/or,replace existing overheaddistributionfacilitieswithcomparableunderground.If existing easements are insufficientforthenewfacilities,the Applicant or Customer is responsible for obtainingnew easements. Substation facilities and transmission voltage facilities will be relocated at the discretion of the Company. For overhead to undergroundrelocations (conversions),the new undergroundsystem must not impair the use of the remaining overhead system.The Applicant or Customer must elect either:to provide all trenching and backfilling,imported backfill material,conduits,andequipmentfoundationsthattheCompanyrequiresfortheExtension;or,to pay the Company to provide these items. In addition,the Applicant or Customer must advance the following: (1)The estimated installed cost of the new facilities plus the estimated removal expenseoftheexistingfacilities,less (2)The estimated salvage value plus accrued depreciation of the facilities to beremoved. This Advance is not refundable.The Company is not responsible for allocating costs andresponsibilitiesamongmultipleApplicants. (continued) Submitted UnderCase No.PAC-E-19-19 ISSUED:November 22,2019 EFFECTIVE:February 2l,2020 IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Feb. 20, 2020 Feb. 21, 2020 Per O.N. 34558 Diane M. Hanian Secretary ROCKY MOUNTAINPOWER A DIVISION OF PActFICORP First Revision of Original Sheet No.12R.15 LP.U.C.No.1 First Revision of Sheet No. 12R.15 6.RELOCATION OR REPLACEMENT OF FACILITIES (continued) (b) Local Governments When required by a governmentalentity in accordance with Idaho Code 50-2501 to 50- 2523,the Company will replace existing overhead with undergrounddistribution facilities provided the entity pays the Company in accordance with paragraph 6.(a)Relocation of Facilities,and provided the entity adopts an ordinance creating an undergrounddistrict requiring: (1)All existing overhead communicationand electric distribution facilities be removed: (2)Each property owner to make the changes necessary to receive service from the undergroundfacilities as soon as the Company makes them available;and, (3)Authorizes the Company to discontinue overheadservice when it has completed construction of the undergroundfacilities. 7.CONTRACT ADMINISTRATION ALLOWANCE When a Line Extension includes a reftmdable advance.a Customer may waive all refunds and receive the Contract Administration Allowance specified in Schedule 300.The customer's choice to receive the Contract Administration Allowance must be made at the time the Extension advance is paid. Submitted UnderCase No.PAC-E-19-19 ISSUED:November 22, 2019 EFFECTIVE:February 21.2020 IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Feb. 20, 2020 Feb. 21, 2020 Per O.N. 34558 Diane M. Hanian Secretary ROCKY MOUNTAIN POWER I.P.U.C. No.1 Second Revision of Sheet No. 13R.1 Canceling First Revision of Sheet No. 13Rl to ELECTRIC SERVICE REGULATION NO. 13 STATE OT'IDAHO Curtailment Plan for Electric Energy INTRODUCTION: The Idaho Public Utilities Commission orderedrthe Company and other suppliers of electric service operating in the State of Idaho to adopt provisions relating to electric service curtailment. This document summarizes the curtailment plan employed by the Company to temporarily intemrpt electric service to its customers during emergencies and power shortages. It is intended to provide equitable procedures for the curtailment of power, minimize adverse impacts to essential servicesn and customers, while maintain overall system reliability. The curtailment plan is operational 24 hours a day, 365 days a year, to help ensure that the Company is able Match customer demand and electrical supply generation; Maintain the integrity of the electrical network; Deploy available resources to restore electrical supply to normal as soon as is practicable; Apply existing processes to keep customers and stakeholders informed of the state and progress of the incident or emergency;o Utilize communication avenues to appeal to customers to reduce electricity consumption;o Coordinate with appropriate agencies to provide options to lessen the impact to customers;o Meet applicable operating standards. Operating Standards The Company is a member of the Western Electricity Coordinating Council (WECC), one of the eight Regional Entities of the North American Electric Reliability Corporation (NERC). The Company also supports Regional Reliability Coordinators, who monitor voltages, frequencies, and other reliability indices. WECC develops and implements Regional Reliability Standards and Criteria for the Westem Interconnection and is the regional entity responsible for compliance monitoring and enforcement with delegated authority from the North American Electric Reliability Corporation GIERC) and Federal Energy Regulatory Commission (FERC). (Continued) I Order No. 25259- November 24- 1993- Submitted Under Case No. PAC-E-22-04 ISSUED: February 22,2022 EFFECTM: June 1,2022 IDAHO PUBLIC UTILITIES COMMISSION Approved Effective May 25, 2022 June 1, 2022 Per ON 35416 Jan Noriyuki Secretary ROCKY MOUNTAIN POWER A DIVISION OF PAOFICORP I.P.U.C. No.1 Second Revision of Sheet No. 13R.2 Canceling X'irst Revision of Sheet No. 13R2 Operating Standards (continued) Bulk electric system reliability and operating standards for utilities in the westem part of the United States provide for a coordinated effort to effectively manage enerry shortage situations and includes shedding firm load in an emergency situation using the Company's Under Frequency and/or Under Voltage Load Shedding programs to arrest declining frequency, assist recovery offrequency following under frequency events and provide last resort system preservation measures to prevent a blackout or voltage collapse. Emergencies that threaten the integrity of the electric system can develop at any time due to shortage of generation or disturbances on the system, either locally or within the Westem Interconnect. The actions necessary to prevent total collapse of the system will be to; restrict customer demand, match generation availability, implement network capacity limitations. The circumstances necessitating a reduction in the demand or consumption of electricity in the short term will require that immediate emergency action is taken and may potentially lead directly to firm load curtailment. SECTION I. PURPOSE AND OVERVIEW OT'TIIE CURTAILMENT PLAN This plan identifies the process by which the Company would initiate and implement regional load curtailment. The goal of this plan is to accomplish curtailment while treating customers fairly and equitably, minimizing adverse impacts from curtailment, complying with existing State laws and regulations, and providing for smooth, effi cient, and effective curtailment administration. SECTION tr. LOAD CURTAILMENT The Company will comply with all State and Federal mandates to curtail the electric energy used by its customers to stabilize system voltage and frequency in order to prevent a regional system collapse. Events that may trigger load curtailment, either upon notice from state agencies, the RC West Regional Reliability Coordinator, or at the discretion of the Company, include but not limited to: . Loss of major generation or transmission equipment due to mechanical or electrical failure. o Extreme hot or cold temperatures that create a network peak where generation capacity does not meet load center requirements.. System disturbance within the regional balancing area. Initiation of Load Curtailment Load curtailment will be initiated when directed by the North American Electric Reliability Corporation (NERC), the Western Electricity Coordinating Council (WECC) authorities, or by order of the Idatro Public Utilities Commission under authority provided for in ldaho Code $ 61-534. However, nothing precludes the Company from requesting voluntary load reduction at any time. ISSUED: February 22, 2022 (Continued) EFFECTM: June 1,2022 Submitted Under Case No. PAC-E-22-04 IDAHO PUBLIC UTILITIES COMMISSION Approved Effective May 25, 2022 June 1, 2022 Per ON 35416 Jan Noriyuki Secretary ROCKY MOUNTAIN POWER A DIVISION OF PACIFICORP I.P.U.C. No. I Second Revision of Sheet No. 13R.3 Canceling First Revision of Sheet No. 13R3 SECTION II. LOAD CLTRTAILMENT (continued) Automatic, Remote and Manual Actions Automatic actions occur through the operation of programmed protective equipment installed in the Company's electrical system, including, without limitation, such equipment as automatic relays, generator controls, circuit breakers, and switches. This equipment is preset to operate under certain prescribed conditions which, in the sole judgment of the Company, threaten system performance, integrity, reliability or stability. Where Supervisory Control and Data Acquisition (*SCADA") equipment is installed, the Company will remotely control switches, circuit breakers, relays, voltage regulators or other equipment. [n areas where no SCADA equipment is installed, actions are performed manually by on-site field personnel. If actions are undertaken, then to the extent permitted by the operating characteristics of the electrical system, the Company will perform such actions so that intemrption, curtailment, or fluctuation of service to customers will be accomplished sequentially, unless it is necessary in the sole judgment of the Company, or if required by the RC West Regional Reliability Coordinatorto vary said sequence in orderto protect system performance, integrity, reliability, or stability. SECTION TII. CI'RTAILMENT STAGES State curtailment directives apply to all retail loads served within the State of Idaho. The curtailment stages are associated with increasing energy deficits. The circumstances necessitating a reduction in the demand or consumption of electricity in the short term will normally require that immediate emergency action is taken and there may be no warning. Sudden equipment outages or loss of generation could potentially lead directly to any curtailment stage without prior notice or progression of the stages described below. Stage #Nature Estimeted Curtailment Percent Type of Curtailment Stage I Mandatory 5o/o +l- Demand Side Management Programs activated Stage 2 Voluntary - public appeal to restrict usage No specified %Uniform among all customers Stage 3 Mandatory - peak curtailment block rotation 2.5 to 3.5o/o +l-General Use Customers Residential Customers Stage 4 Mandatory --curtailment block rotation 30%o of peak +l-General Use Customers Residential Customers Stage 5 Mandatory - Emergency Load Shed Groups o/o determinate upon RC West Regional Reliability Coordinator directive Uniform among all customers ISSUED: February 22,2022 (Continued) EFFECTM: June 1,2022 Submitted Under Case No. PAC-E-22-04 IDAHO PUBLIC UTILITIES COMMISSION Approved Effective May 25, 2022 June 1, 2022 Per ON 35416 Jan Noriyuki Secretary ROCKY MOUNTAIN EPH,E,^N",, I.P.U.C. No.1 Second Revision of Sheet No. 13R4 Cancelins First Revision Sheet No. 13R4 SECTION TV. INITIATION OF LOAD CURTAILMENT Block Rotation Selected distribution feeders throughout the service territory have been grouped into blocks ofapproximately 100 MW in size. These blocks provide for two (2) hour rotational curtailments to be used in scheduled combinations to ensure that the required load shed amount is achieved. Block rotation may be utilized to support system stabilization following a system disturbance, or to maintain system integrity during peak load periods. During load curtailment the Company would rotate through the blocks until curtailment is no longer necessary. Block rotation is dependent on what day of the week and time of day the curtailment event is enacted. This provides for equitable treatment to affected customers. Blocks are aggregated to match reduction thresholds during events. Emergency Load Shed Groups Predetermined localized load shed groups are utilized for situations where load reductions might be necessary for specific high load areas. These areas generally require specialized load curtailment schemes to accommodate transmission path restrictions. Load shed groups contain only SCADA controllable circuits. Minimization of Imoact The Company will implement rotational curtailment in as fair and equitable a manner as practicable, with the goal of minimizing the impacts on communities. Where known and feasible within operational parameters, distribution feeders serving facilities essential to the public welfare are avoided during rotational curtailment. However, it should be noted that the Company cannot definitively account for all such facilities, nor is it possible to exclude every known facility from the impacts of curtailment. Such essential facilities include:. Hospitals o 9l I centers. Airports and FAA facilities o Large sewer and water treatment plants. Major metropolitan downtown core areas o Facilities critical to electric system operation o Prisons, police, and fire stations including related computer and communication centers. Radio, TV news, emergency broadcast stations and transmitting facilities o U.S. Military installations (Continued) Submitted Under Case No. PAC-E-22-04 ISSUED: February 22,2022 EFFECTM: June 1,2022 IDAHO PUBLIC UTILITIES COMMISSION Approved Effective May 25, 2022 June 1, 2022 Per ON 35416 Jan Noriyuki Secretary ROCKY MOUNTAIN POWER A DIVISION OF PACIFGORP LP.U.C. No. 1 Second Revision of Sheet No. 13R.5 Canceling First Revision of Sheet No. 13R5 SECTION V. NOTIFICATIONS AND ACTIONS Throughout the curtailment period the Company will provide customers and external State and regulatory stakeholders with as much information as possible utilizing established processes and protocols. The Company's incident management strategy for an energy emergency is consistent with the National Incident Management System and Incident Command System, and provides effective coordination through: o Procedures that allow system and field operations to focus on critical functional responsibilities;. Providing pertinent information to internal and extemal stakeholders, customers, regulators, media outlets, etc.;o Flexible response to changing circumstances, special customer needs and emergencies. Stage 1: Demand Side Management Programs The Company would not normally contact the public or news media when it exercises options under demand side management programs. Stage 2: Public Appealfor Conservation At the Company's discretion, a public appeal for voluntary enerry conservation may be issued through media outlets, social media platforms, and automated outbound calling of customers requesting voluntary curtailment ofnonessential uses. Additionally, the Company will initiate curtailment of all nonessential Company use, request curtailment of nonessential use by govemmental agencies and institutions at all levels, request voluntary curtailment of nonessential use in all large buildings, and direct specific requests to major use customers for voluntary curtailment of nonessential use. If additional curtailment is required the Company will intensiff its request to the public, including requests to curtail less-essential uses, and notice that if curtailment does not occur, mandatory curtailment may be necessary by utilizing block rotation methods. Stage j: Peak Load Curtailment Prior to any rotating outages, the Company, to the best of its ability will contact key external stakeholders to inform them ofthe situation. To the extent possible, areas targeted for rotating outages may be disclosed at this time, together with some estimate of how long the outages will be necessary. The magnitude of the event will dictate the administrative level to which external notifications will be made. (Continued) EI'FECTM: June l,2022 Submitted Under Case No. PAC-E-22-04 ISSUED: February 22,2022 IDAHO PUBLIC UTILITIES COMMISSION Approved Effective May 25, 2022 June 1, 2022 Per ON 35416 Jan Noriyuki Secretary Y ROCKY MOUNTAIN POWER A DIVISION OF PACIFICORP LP.U.C. No.1 Second Revision of Sheet No. 13R6 Canceling X'irst Revision of Sheet No. 13R6 SECTION V. NOTIFICATIONS AIID ACTIONS (continued) Key external stakeholders include, but are not limited to:o Governor's officeo Public Utilities Commissiono State enerry/emergency response officials. Legislativeleadership. Key customer accounts Stage 1: Bloch Load Curtailment In addition to the actions above, to the extent possible, customers in the areas targeted for rotating outages will be notified as soon as practicable and provided with an estimate of the time their block will be curtailed and the expected duration. Stage 5: Emcrgency Load Shed Groups Generally, no advance notice of an event necessitating emergency load shed is available. Thereforen it is to be expected that all intemal and extemal notifications will occur as soon as information is known. Submitted Under Case No. PAC-E-22-04 ISSUED: February 22, 2022 EI'FECTM: June l,2022 IDAHO PUBLIC UTILITIES COMMISSION Approved Effective May 25, 2022 June 1, 2022 Per ON 35416 Jan Noriyuki Secretary IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Aug. 28, 2006 Sept. 15, 2006 Jean D. Jewell Secretary IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Aug. 28, 2006 Sept. 15, 2006 Jean D. Jewell Secretary IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Aug. 28, 2006 Sept. 15, 2006 Jean D. Jewell Secretary IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Aug. 28, 2006 Sept. 15, 2006 Jean D. Jewell Secretary IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Aug. 28, 2006 Sept. 15, 2006 Jean D. Jewell Secretary IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Aug. 28, 2006 Sept. 15, 2006 Jean D. Jewell Secretary IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Aug. 28, 2006 Sept. 15, 2006 Jean D. Jewell Secretary IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Aug. 28, 2006 Sept. 15, 2006 Jean D. Jewell Secretary IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Aug. 28, 2006 Sept. 15, 2006 Jean D. Jewell Secretary Exhibit 1 - Electric Service Schedules Case No. PAC-E-23-12 IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Aug. 28, 2006 Sept. 15, 2006 Jean D. Jewell Secretary I.P.U.C. No.1 Original Sheet No. A ELECTRIC RATE SCHEDULES of ROCKY MOUNTAIN POWER Salt Lake City, Utah for ELECTRIC SERVICE in the STATE OF IDAHO Under IDAHO PUBLIC UTILITIES COMMISSION TARIFFNO.1 CANCELSALLPREVIOUSSCHEDULESFORELECTRICSERVICE Submitted Under Advice Letter No. 06-06 ISSUED: August 14, 2006 Issuing Officer D. Douglas Larson Vice President, Regulation Salt Lake City, UT EFFECTIVE: September 15, 2006 Fifth Revision of Sheet No. B.1 I.P.U.C. No. 1 Canceling Fourth Revision of Sheet No. B.1 Submitted Under Case No. PAC-E-21-07 ISSUED: November 8, 2021 EFFECTIVE: January 1, 2022 ROCKY MOUNTAIN POWER ELECTRIC SERVICE SCHEDULES STATE OF IDAHO Schedule Sheet No. Class of Service No. 1 Residential Service 1.1 & 1.2 6 General Service - Large Power 6.1 - 6.3 6A General Service - Large Power (Residential and Farm) 6A.1 - 6A.4 7 Security Area Lighting 7.1 - 7.2 7A Security Area Lighting (Residential and Farm) 7A.1 - 7A.3 9 General Service - High Voltage 9.1 - 9.3 10 Irrigation and Soil Drainage Pumping Power Service 10.1 - 10.4 11 Street Lighting Service- Company-Owned System 11.1 - 11.3 12 Street and Security Area Lighting Service- Consumer-Owned System 12.1 - 12.5 14 Temporary Service Connection Facilities – No New Service* 14 21 Low Income Weatherization Services 21.1 - 21.6 (Continued) IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Feb. 1, 2022 Jan. 1, 2022 Per O.N. 35277 Jan Noriyuki Secretary Fourteenth Revision of Sheet No. B.2 I.P.U.C. No. 1 Canceling Thirteenth Revision of Sheet No. B.2 ELECTRIC SERVICE SCHEDULES - Continued Schedule Sheet No. Class of Service No. 23 General Service - Small Power 23.1 - 23.3 23A General Service - Small Power (Residential and Farm) 23A.1 - 23A.4 24 Interruptible Power Service 24.1 - 24.5 31 Partial Requirements Service – High Voltage 31.1 – 31.6 34 Pacific Northwest Electric Power Planning and Conservation Act - 34.1 - 34.3 Residential and Farm Kilowatt-Hour Credit 35 Optional Time-of-Day General Service – Distribution Voltage 35.1 - 35.3 35A Optional Time-of-Day General Service – Distribution Voltage (Farm) 35A.1 -35A.4 38 Qualifying Facility Avoided Cost Procedures 38.1 – 38.11 36 Optional Time of Day Residential Service 36.1 - 36.3 70 Renewable Energy Rider – Optional 70.1 - 70.4 73 Renewable Energy Rider - Optional - Bulk Purchase Option 73.1 – 73.4 94 Energy Cost Adjustment 94.1 118 Home Energy Saver Incentive Program 118.1 - 118.2 (Continued) Submitted Under Advice No. 16-04 ISSUED: April 20, 2016 EFFECTIVE: April 15, 2016 IDAHO PUBLIC UTILITIES COMMISSION Approved Effective May 2, 2016 April 15, 2016 Per O.N. 33474 Jean D. Jewell Secretary I.P.U.C. No. 1 Sixth Revision of Sheet No. B.3 Canceling Fifth Revision of Sheet No. B.3 Submitted Under Case No. PAC-E-21-07 ISSUED: November 8, 2021 EFFECTIVE: January 1, 2022 ELECTRIC SERVICE SCHEDULES - Continued Schedule Sheet No. Class of Service No. 135 Net Metering Service 135.1 - 135.3 136 Net Billing Service 136.1 - 136.4 140 Non-Residential Energy Efficiency 140.1 - 140.3 191 Customer Efficiency Services Rate Adjustment 191 197 Federal Tax Act Adjustment 197 300 Regulation Charges 300.1 - 300.4 400 Special Contract 400.1 Schedule numbers not listed are not currently used. * These schedules are not available to new customers or premises. IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Feb. 1, 2022 Jan. 1, 2022 Per O.N. 35277 Jan Noriyuki Secretary Twelfth Revision of Sheet No. 1.1 I.P.U.C. No. 1 Canceling Eleventh Revision of Sheet No. 1.1 Submitted Under Case No. PAC-E-22-15 ISSUED: June 9, 2023 EFFECTIVE: June 1, 2023 ROCKY MOUNTAIN POWER ELECTRIC SERVICE SCHEDULE NO. 1 STATE OF IDAHO ______________ Residential Service ______________ AVAILABILITY: At any point on the Company's interconnected system where there are facilities of adequate capacity. APPLICATION: This Schedule is for alternating current electric service supplied at approximately 120 or 240 volts through one kilowatt-hour meter at a single point of delivery for all service required on the premises for Residential purposes. When conditions are such that service is supplied through one meter to more than one dwelling or apartment unit, the charge for such service will be computed by multiplying the minimum charges by the maximum number of dwelling or apartment units that may be served. When a portion of a dwelling is used regularly for business, professional or other gainful purposes, the premises will be classified as nonresidential and the appropriate schedule applied. 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. MONTHLY BILL: Year 1 Year 2 Year 3 Year 4 Year 5 6/1/2023 6/1/2024 6/1/2025 6/1/2026 6/1/2027 to to to to5/31/2024 5/31/2025 5/31/2026 5/31/2027Customer Service Charge Energy Charge (¢/kWh) Seasonal Service Charge (Continued) IDAHO PUBLIC UTILITIES COMMISSIONApproved EffectiveJuly 6, 2023 June 1, 2023 Per ON 35843 Jan Noriyuki Secretary Twelfth Revision of Sheet No. 1.2 I.P.U.C. No. 1 Canceling Eleventh Revision of Sheet No. 1.2 Submitted Under Case No. PAC-E-22-15 ISSUED: June 9, 2023 EFFECTIVE: June 1, 2023 ELECTRIC SERVICE SCHEDULE NO. 1 – Continued MONTHLY BILLING REDUCTION: Rates in this schedule shall be reduced by the monthly kilowatt-hour credit adjustment set forth under “Monthly Rates” in the currently effective Electric Service Schedule No. 34. SEASONAL SERVICE: When seasonal service is supplied under this Schedule, the minimum seasonal charge will be applied plus energy charges. CONTRACT PERIOD: One year or longer. ELECTRIC SERVICE REGULATIONS: Service under this Schedule will be in accordance with the terms of the Electric Service Agreement between the Customer and the Company. The Electric Service Regulations of the Company on file with and approved by the Idaho Public Utilities Commission, including future applicable amendments, will be considered as forming a part of and incorporated in said Agreement. IDAHO PUBLIC UTILITIES COMMISSIONApproved EffectiveJuly 6, 2023 June 1, 2023 Per ON 35843 Jan Noriyuki Secretary Ninth Revision of Sheet No. 6.1 I.P.U.C. No. 1 Canceling Eighth Revision of Sheet No. 6.1 Submitted Under Case No. PAC-E-21-07 ISSUED: November 8, 2021 EFFECTIVE: January 1, 2022 ROCKY MOUNTAIN POWER ELECTRIC SERVICE SCHEDULE NO. 6 STATE OF IDAHO ______________ General Service - Large Power ______________ AVAILABILITY: At any point on the Company's interconnected system where there are facilities of adequate capacity. APPLICATION: This Schedule is for alternating current, single or three-phase electric service supplied at Company's available voltage through one metering installation at a single point of delivery for all service required on the premises. MONTHLY BILL: Rate: Billing Months June through October, Inclusive Billing Months November through May, Inclusive : Secondary voltage delivery (Less than 2300 volts) $ 38.00 per Customer $ 38.00 per Customer Primary voltage delivery (2300 volts or higher) $ 114.00 per Customer $ 114.00 per Customer : $ 13.62 per kW for all kW $ 12.27 per kW for all kW : 4.2506¢ per kWh for all kWh 4.2506¢ per kWh for all kWh (Continued) IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Feb. 1, 2022 Jan. 1, 2022 Per O.N. 35277 Jan Noriyuki Secretary Fifth Revision of Sheet No. 6.2 I.P.U.C. No. 1 Canceling Fourth Revision of Sheet No. 6.2 Submitted Under Case No. PAC-E-21-07 ISSUED: November 8, 2021 EFFECTIVE: January 1, 2022 ELECTRIC SERVICE SCHEDULE NO. 6 - Continued Power Factor: This rate is based on the Customer maintaining at all times a power factor of 85% lagging, or higher, as determined by measurement. If the average power factor is found to be less than 85% lagging, the Power as recorded by the Company's meter will be increased by 3/4 of 1% for every 1% that the power factor is less than 85%. Voltage Discount: Where Customer takes service from Company's available lines of 2300 volts or higher and provides and maintains all transformers and other necessary equipment, the voltage discount based on measured Power will be: $0.65 per kW for all kW of Power Minimum Bill: The Customer Service Charge. POWER: The kW as shown by or computed from the readings of Company's Power meter for the 15-minute period of Customer's greatest use during the month, determined to the nearest kW. SEASONAL SERVICE: Service for annually recurring periods of seasonal use where service is normally discontinued or curtailed during a part of the year may be contracted for under this Schedule under either of the following conditions: (a) Customer may contract for service under this Schedule on a year-round basis paying for all service, including transformer losses where applicable, under the rates set forth under "Monthly Bill" above including the monthly minimum bill during those months service is curtailed or is not utilized in the Customer's operation. (b) Customer may contract for seasonal service under this Schedule with a net minimum seasonal payment as follows: $ 456.00 plus Power and Energy Charges for Customer taking service at less than 2300 volts and $ 1,368.00 plus Power and Energy Charges for Customer taking service at 2300 volts or higher. (Continued) IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Feb. 1, 2022 Jan. 1, 2022 Per O.N. 35277 Jan Noriyuki Secretary IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Aug. 28, 2006 Sept. 15, 2006 Jean D. Jewell Secretary I.P.U.C. No.1 ELECTRIC SERVICE SCHEDULE NO. 6 -Continued CONTRACT PERIOD: One year or longer. Original Sheet No. 6.3 ELECTRIC SERVICE REGULATIONS: Service under this Schedule will be in accordance with the terms of the Electric Service Agreement between the Customer and the Company. The Electric Service Regulations of the Company on file with and approved by the Idaho Public Utilities Commission, including future applicable amendments, will be considered as forming a part of and incorporated in said Agreement. Submitted Under Advice Letter No. 06-06 ISSUED: August 14, 2006 EFFECTIVE: September 15, 2006 Ninth Revision of Sheet No. 6A.1 I.P.U.C. No. 1 Canceling Eighth Revision of Sheet No. 6A.1 Submitted Under Case No. PAC-E-21-07 ISSUED: November 8, 2021 EFFECTIVE: January 1, 2022 ROCKY MOUNTAIN POWER ELECTRIC SERVICE SCHEDULE NO. 6A STATE OF IDAHO ______________ General Service - Large Power (Residential and Farm) ______________ AVAILABILITY: At any point on the Company's interconnected system where there are facilities of adequate capacity for service to any customer who qualifies as a "Residential Load" or "Farm Load" under both (1) the Pacific Northwest Electric Power Planning and Conservation Act, P.L. 96-501 as the same may be amended, and (2) a Residential Purchase and Sale Agreement, under Section 5(c) of such Act and in effect between the Company and the Bonneville Power Administration. APPLICATION: This Schedule is for alternating current, single or three-phase electric service supplied at Company's available voltage through one metering installation at a single point of delivery for all service required on the premises. MONTHLY BILL: Customer Service Charge Power Rate Energy Rate (Continued) IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Feb. 1, 2022 Jan. 1, 2022 Per O.N. 35277 Jan Noriyuki Secretary Third Revision of Sheet No. 6A.2 I.P.U.C. No. 1 Canceling Second Revision of Sheet No. 6A.2 Submitted Under Advice No. 12-03 ISSUED: October 19, 2012 EFFECTIVE: January 1, 2013 ELECTRIC SERVICE SCHEDULE NO. 6A - Continued Power Factor: This rate is based on the Customer maintaining at all times a power factor of 85% lagging, or higher, as determined by measurement. If the average power factor is found to be less than 85% lagging, the Power as recorded by the Company's meter will be increased by 3/4 of 1% for every 1% that the power factor is less than 85%. Voltage Discount: Where Customer takes service from Company's available lines of 2300 volts or higher and provides and maintains all transformers and other necessary equipment, the voltage discount based on measured Power will be: $0.65 per kW for all kW of Power Minimum Bill: The Customer Service Charge. MONTHLY BILLING REDUCTION: Rates in this Schedule shall be reduced by the monthly kilowatt-hour credit adjustment set forth under "Monthly Rates" in the currently effective Electric Service Schedule No. 34. POWER: The kW as shown by or computed from the readings of Company's Power meter for the 15-minute period of Customer's greatest use during the month, determined to the nearest kW. SEASONAL SERVICE: Service for annually recurring periods of seasonal use where service is normally discontinued or curtailed during a part of the year may be contracted for under this Schedule under either of the following conditions: (a) Customer may contract for service under this Schedule on a year-round basis paying for all service, including transformer losses where applicable, under the rates set forth under "Monthly Bill" above including the monthly minimum bill during those months service is curtailed or is not utilized in the Customer's operation. (Continued) IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Oct. 29, 2012 Jan. 1, 2013 Jean D. Jewell Secretary Fifth Revision of Sheet No. 6A.3 I.P.U.C. No. 1 Canceling Fourth Revision of Sheet No. 6A.3 Submitted Under Case No. PAC-E-21-07 ISSUED: November 8, 2021 EFFECTIVE: January 1, 2022 ELECTRIC SERVICE SCHEDULE NO. 6A - Continued SEASONAL SERVICE: (continued) (b) Customer may contract for seasonal service under this Schedule with a net minimum seasonal payment as follows: $ 456.00 plus Power and Energy Charges for Customer taking service at less than 2300 volts and $1,368.00 plus Power and Energy Charges for Customer taking service at 2300 volts or higher. CONTRACT PERIOD: One year or longer. SPECIAL CONDITION: Domestic use means all usual residential, apartment, seasonal dwelling, and mobile home court use including domestic water pumping. Farm use means all usual farm electrical loads for raising of crops, livestock or pasturage and includes primary processing necessary for safe and efficient storage or shipment and irrigation pumping. Contiguous parcels land under single-ownership or leasehold shall be considered to be one Farm and noncontiguous parcels of land under single-ownership or leasehold shall be considered as one Farm unit when operated as a single Farm, unless demonstrated otherwise by the owner or lessee of the parcels. A number of factors shall determine whether contiguous or noncontiguous parcels constitute one or more Farms. These factors shall include, but are not limited to: -- size -- use -- ownership -- control -- operating practices -- distance between parcels -- custom in the trade -- billing treatment by the utility Operators of Farms may be required to certify to the utility all irrigation accounts, including horsepower rating. (Continued) IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Feb. 1, 2022 Jan. 1, 2022 Per O.N. 35277 Jan Noriyuki Secretary IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Aug. 28, 2006 Sept. 15, 2006 Jean D. Jewell Secretary I.P.U.C. No. 1 Original Sheet No. 6A.4 ELECTRIC SERVICE SCHEDULE NO. 6A -Continued SPECIAL CONDITION: (continued) Customers who feel they meet the definitions of a Farm will have to make application with the Company for review. If Customer application is denied by the Company, the Customer may appeal the decision to the Idaho Public Utilities Commission. ELECTRIC SERVICE REGULATIONS: Service under this Schedule will be in accordance with the terms of the Electric Service Agreement between the Customer and the Company. The Electric Service Regulations of the Company on file with and approved by the Idaho Public Utilities Commission, including future applicable amendments, will be considered as forming a part of and incorporated in said Agreement. Submitted Under Advice Letter No. 06-06 ISSUED: August 14, 2006 EFFECTIVE: September 15, 2006 Tenth Revision of Sheet No. 7.1 I.P.U.C. No. 1 Canceling Ninth Revision of Sheet No. 7.1 Submitted Under Tariff Advice No. 22-01 ISSUED: April 20, 2022 EFFECTIVE: July 1, 2022 ROCKY MOUNTAIN POWER ELECTRIC SERVICE SCHEDULE NO. 7 STATE OF IDAHO ______________ Security Area Lighting ______________ AVAILABILITY: At any point on the Company's interconnected system. Lights installed on a structure other than an existing distribution pole are closed to new service. APPLICATION: This Schedule is for electric service required for Security Area Lighting and for Security Flood Lighting service where service is supplied from a Company-owned pole. MONTHLY BILL: Rate: Light Level LED Equivalent Lumen Range Monthly kWh Total Level 1 <=5,500 19 $12.96 Level 2 5,501-12,000 34 $14.72 Level 3 >12,000 57 $17.48 (Continued) IDAHO PUBLIC UTILITIES COMMISSION Approved Effective June 1, 2022 July 1, 2022 Jan Noriyuki Secretary Seventh Revision of Sheet No. 7.2 I.P.U.C. No. 1 Canceling Sixth Revision of Sheet No. 7.2 Submitted Under Case No. PAC-E-21-07 ISSUED: November 8, 2021 EFFECTIVE: January 1, 2022 ELECTRIC SERVICE SCHEDULE NO. 7 – Continued MONTHLY BILL: (continued) SPECIFICATIONS AND SERVICE FOR SECURITY AREA LIGHTING: Security flood lights may be mounted on Company-owned poles or on Customer-owned supports acceptable to the Company. The type and kind of fixtures and supports will be in accord- ance with the Company's specifications. Service includes energy supplied from the Company's overhead circuits, maintenance and lamp and glassware renewals. Lamps will be controlled by the Company to burn each night from dusk to dawn. CONVERSIONS: The Company, upon written request of customer, will convert existing street lighting facilities to other types of lamps (i.e., convert mercury vapor fixtures and lamps to sodium vapor fixtures and lamps, etc.). In such an event, customer shall pay to Company an amount equal to the depreciated value of all Company-owned facilities removed from service and replaced with new equipment plus the cost of removal less any salvage value. Priority in making conversions shall be determined by the order in which requests are received by the Company. CONTRACT PERIOD: Five years or longer. PROVISIONS 1. Inoperable lights will be repaired as soon as reasonably possible, during regular business hours or as allowed by company’s operating schedule and requirements, provided the Company receives notification of inoperable lights from Customer or a member of the public by either notifying Rocky Mountain Power’s customer service (1-888-221-7070) or www.rockymountainpower.net/streetlights Rocky Mountain Power’s obligation to repair lights is limited to this tariff. 2. The Company reserves the right to contract for the maintenance of lighting service provided hereunder. 3. Temporary disconnection and subsequent reconnection of electrical service requested by the Customer shall be at the Customer’s expense. The Customer may request temporary suspension of power for lighting by written notice. During such periods, the monthly rate will be reduced by the Company’s estimated average monthly relamping and energy costs for the luminaire. The facilities may be considered idle and may be removed after 12 months of inactivity. 4. Pole re-painting, when requested by the Customer and not required for safety reasons, shall be done at the Customer’s expense, using the original pole color. 5. Glare or vandalism shielding, when requested by the Customer, and subject to availability, shall be installed at the Customer’s expense. In cases of repetitive vandalism, the Company may notify the Customer of the need to install vandal shields at the Customer’s expense, or otherwise have the lighting removed. ELECTRIC SERVICE REGULATIONS: Service under this Schedule will be in accordance with the terms of the Electric Service Agreement between the Customer and the Company. The Electric Service Regulations of the Company on file with and approved by the Idaho Public Utilities Commission, including future applicable amendments, will be considered as forming a part of and incorporated in said Agreement. IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Feb. 1, 2022 Jan. 1, 2022 Per O.N. 35277 Jan Noriyuki Secretary IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Aug. 28, 2006 Sept. 15, 2006 Jean D. Jewell Secretary ROCKY MOUNTAIN POWER A DIVISION OF PACIFICORP I.P.U.C. No. 1 Original Sheet No. 7 .3 ELECTRIC SERVICE SCHEDULE NO. 7 -Continued MONTHLY BILL: ( continued) The unit charge includes installation, maintenance and energy costs for unit on existing or one new wood pole without guys. Where more than one wood pole and more than 200 feet of extension are required, an additional charge of 1.5% of the estimated additional cost will be made. Should Customer desire a steel pole instead of a wood pole, an additional charge will be made according to the following schedule: 1. All steel poles installed prior to June 1, 1973. 11 gauge $1.00 per pole per month 3 gauge $1.50 per pole per month 2. Steel poles installed after June 1, 1973. 30 ft., 11 gauge, direct buried $2.35 per pole per month 30 ft., 3 gauge, direct buried $3.95 per pole per month 35 ft., 11 gauge, direct buried $2.85 per pole per month 35 ft., 3 gauge, direct buried $4.65 per pole per month For anchor base poles, add 20¢ per pole per month to all poles installed after June 1, 1973. SPECIFICATIONS AND SERVICE FOR SECURITY AREA LIGHTING: Security flood lights may be mounted on Company-owned poles or on Customer-owned supports acceptable to the Company. The type and kind of fixtures and supports will be in accord ance with the Company's specifications. Service includes energy supplied from the Company's overhead circuits, maintenance and lamp and glassware renewals. Lamps will be controlled by the Company to bum each night from dusk to dawn. CONVERSIONS: The Company, upon written request of customer, will convert existing street lighting facilities to other types of lamps (i.e., convert mercury vapor fixtures and lamps to sodium vapor fixtures and lamps, etc.). In such an event, customer shall pay to Company an amount equal to the depreciated value of all Company-owned facilities removed from service and replaced with new equipment plus the cost of removal less any salvage value. Priority in making conversions shall be determined by the order in which requests are received by the Company. CONTRACT PERIOD: Five years or longer. (Continued) Submitted Under Advice Letter No. 06-06 ISSUED: August 14, 2006 EFFECTIVE: September 15, 2006 IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Dec. 14, 2016 Jan. 1, 2017 Per O.N. 33668 Diane M. Hanian Secretary ROCKY MOUNTAIN POWER A DIVISION 01' PACIFICOIIP I.P.U.C. No. 1 Eighth Revision of Sheet No. 7.4 Canceling Seventh Revision of Sheet No. 7.4 ELECTRIC SERVICE SCHEDULE NO. 7 -Continued MONTHLY BILL: (continued) (2) Customer-Owned/Customer-Maintained Area Lighting Energy Only (No New Service): Initial Lumens 16,000 Sodium Vapor Flood CONTRACT PERIOD: One year or longer. PROVISIONS Watts 150 Per Lamp $15.13 I. Inoperable lights will be repaired as soon as reasonably possible, during regular business hours or as allowed by company's operating schedule and requirements, provided the Company receives notification of inoperable lights form Customer or a member of the public by either notifying Rocky Mountain Power's customer service (1-888-221-7070) or www.rockymountainpower.net/streetlights. Rocky Mountain Power's obligation to repair lights is limited to this tariff. 2. The Company reserves the right to contract for the maintenance of lighting service provided hereunder. 3. Temporary disconnection and subsequent reconnection of electrical service requested by the Customer shall be at the Customer's expense. The Customer may request temporary suspension of power for lighting by written notice. During such periods, the monthly rate will be reduced by the Company's estimated average monthly relamping and energy costs for the luminaire. The facilities may be considered idle and may be removed after 12 months of inactivity. 4. Pole re-painting, when requested by the Customer and not required for safety reasons, shall be done at the Customer's expense, using the original pole color. 5. Glare or vandalism shielding, when requested by the Customer, and subject to availability, shall be installed at the Customer's expense. In cases of repetitive vandalism, the Company may notify the Customer of the need to install vandal shields at the Customer's expense, or otherwise have the lighting removed. ELECTRIC SERVICE REGULATIONS: Service under this Schedule will be in accordance with the terms of the Electric Service Agreement between the Customer and the Company. The Electric Service Regulations of the Company on file with and approved by the Idaho Public Utilities Commission, including future applicable amendments, will be considered as forming a part of and incorporated in said Agreement. Submitted Under Case No. PAC-E-16-12 ISSUED: November 11, 2016 EFFECTIVE: January I, 2017 Ninth Revision of Sheet No. 7A.1 I.P.U.C. No. 1 Canceling Eighth Revision of Sheet No. 7A.1 Submitted Under Tariff Advice No. 22-01 ISSUED: April 20, 2022 EFFECTIVE: July 1, 2022 ROCKY MOUNTAIN POWER ELECTRIC SERVICE SCHEDULE NO. 7A STATE OF IDAHO ______________ Security Area Lighting (Residential and Farm) ______________ AVAILABILITY: At any point on the Company's interconnected system for service to any customer who qualifies as a "Residential Load" or "Farm Load" under both (1) the Pacific Northwest Electric Power Planning and Conservation Act, P.L. 96-501 as the same may be amended, and (2) a Residential Purchase and Sale Agreement, under Section 5(c) of such Act and in effect between the Company and the Bonneville Power Administration. Lights installed on a structure other than an existing distribution pole are closed to new service. APPLICATION: This Schedule is for electric service required for Security Area Lighting and for Security Flood Lighting service where service is supplied from a Company-owned pole. MONTHLY BILL: Rate: Light Level LED Equivalent Lumen Range Monthly kWh Total Level 1 <=5,500 19 $12.96 Level 2 5,501-12,000 34 $14.72 Level 3 >12,000 57 $17.48 MONTHLY BILLING REDUCTION: Rates in this Schedule shall be reduced by the monthly kilowatt-hour credit adjustment set forth under "Monthly Rates" in the currently effective Electric Service Schedule No. 34. SPECIFICATIONS AND SERVICE FOR SECURITY AREA LIGHTING: Security flood lights may be mounted on Company-owned poles or on Customer-owned supports acceptable to the Company. The type and kind of fixtures and supports will be in accordance with the Company's specifications. Service includes energy supplied from the Company's overhead circuits, maintenance and lamp and glassware renewals. Lamps will be controlled by the Company to burn each night from dusk to dawn. IDAHO PUBLIC UTILITIES COMMISSION Approved Effective June 1, 2022 July 1, 2022 Jan Noriyuki Secretary Eighth Revision of Sheet No. 7A.2 I.P.U.C. No. 1 Canceling Seventh Revision of Sheet No. 7A.2 Submitted Under Tariff Advice No. 22-01 ISSUED: April 20, 2022 EFFECTIVE: July 1, 2022 ELECTRIC SERVICE SCHEDULE NO. 7A - Continued MONTHLY BILL: (continued) CONTRACT PERIOD: Five years or longer. SPECIAL CONDITION: Domestic use means all usual residential, apartment, seasonal dwelling, and mobile home court use including domestic water pumping. Farm use means all usual farm electrical loads for raising of crops, livestock or pasturage and includes primary processing necessary for safe and efficient storage or shipment and irrigation pumping. Contiguous parcels of land under single-ownership or leasehold shall be considered to be one Farm and noncontiguous parcels of land under single-ownership or leasehold shall be considered as one Farm unit when operated as a single Farm, unless demonstrated otherwise by the owner or lessee of the parcels. A number of factors shall determine whether contiguous or noncontiguous parcels constitute one or more Farms. These factors shall include, but are not limited to: -- size -- use -- ownership -- control -- operating practices -- distance between parcels -- custom in the trade -- billing treatment by the utility Operators of Farms may be required to certify to the utility all irrigation accounts, including horsepower rating. (Continued) IDAHO PUBLIC UTILITIES COMMISSION Approved Effective June 1, 2022 July 1, 2022 Jan Noriyuki Secretary First Revision of Sheet No. 7A.3 I.P.U.C. No. 1 Canceling Original Sheet No. 7A.3 Submitted Under Case No. PAC-E-21-07 ISSUED: November 8, 2021 EFFECTIVE: January 1, 2022 ELECTRIC SERVICE SCHEDULE NO. 7A - Continued SPECIAL CONDITION: (continued) Customers who feel they meet the definitions of a Farm will have to make application with the Company for review. If Customer application is denied by the Company, the Customer may appeal the decision to the Idaho Public Utilities Commission. PROVISIONS 1. Inoperable lights will be repaired as soon as reasonably possible, during regular business hours or as allowed by company’s operating schedule and requirements, provided the Company receives notification of inoperable lights from Customer or a member of the public by either notifying Rocky Mountain Power’s customer service (1-888-221-7070) or www.rockymountainpower.net/streetlights Rocky Mountain Power’s obligation to repair lights is limited to this tariff. 2. The Company reserves the right to contract for the maintenance of lighting service provided hereunder. 3. Temporary disconnection and subsequent reconnection of electrical service requested by the Customer shall be at the Customer’s expense. The Customer may request temporary suspension of power for lighting by written notice. During such periods, the monthly rate will be reduced by the Company’s estimated average monthly relamping and energy costs for the luminaire. The facilities may be considered idle and may be removed after 12 months of inactivity. 4. Pole re-painting, when requested by the Customer and not required for safety reasons, shall be done at the Customer’s expense, using the original pole color. 5. Glare or vandalism shielding, when requested by the Customer, and subject to availability, shall be installed at the Customer’s expense. In cases of repetitive vandalism, the Company may notify the Customer of the need to install vandal shields at the Customer’s expense, or otherwise have the lighting removed. ELECTRIC SERVICE REGULATIONS: Service under this Schedule will be in accordance with the terms of the Electric Service Agreement between the Customer and the Company. The Electric Service Regulations of the Company on file with and approved by the Idaho Public Utilities Commission, including future applicable amendments, will be considered as forming a part of and incorporated in said Agreement. IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Feb. 1, 2022 Jan. 1, 2022 Per O.N. 35277 Jan Noriyuki Secretary IDAHO PUBLIC UTILITIES COMMISSION Approved Effective April 27, 2012 April 24, 2012 Per O.N. 32519 Jean D. Jewell Secretary I.P.U.C. No. 1 Third Revision of Sheet No. 7 A.4 Canceling Second Revision of Sheet No. 7 A.4 ELECTRIC SERVICE SCHEDULE NO. 7 A -Continued MONTHLY BILL: ( continued) CONTRACT PERIOD: One year or longer. SPECIAL CONDITION: Domestic use means all usual residential, apartment, seasonal dwelling, and mobile home court use including domestic water pumping. Farm use means all usual farm electrical loads for raising of crops, livestock or pasturage and includes primary processing necessary for safe and efficient storage or shipment and irrigation pumping. Contiguous parcels of land under single-ownership or leasehold shall be considered to be one Farm and noncontiguous parcels of land under single-ownership or leasehold shall be considered as one Farm unit when operated as a single Farm, unless demonstrated otherwise by the owner or lessee of the parcels. A number of factors shall determine whether contiguous or noncontiguous parcels constitute one or more Farms. These factors shall include, but are not limited to: size use ownership control operating practices distance between parcels custom in the trade billing treatment by the utility Operators of Farms may be required to certify to the utility all irrigation accounts, including horsepower rating. Submitted Under Case No. PAC-E-12-04 ISSUED: January 18, 2012 (Continued) EFFECTIVE: April 24, 2012 Second Revision of Sheet No. 7A.5 I.P.U.C. No. 1 Canceling First Revision of Sheet No. 7A.5 Submitted Under Advice No. 16-03 ISSUED: February 10, 2016 EFFECTIVE: March 15, 2016 ELECTRIC SERVICE SCHEDULE NO. 7A - Continued SPECIAL CONDITION: (continued) Customers who feel they meet the definitions of a Farm will have to make application with the Company for review. If Customer application is denied by the Company, the Customer may appeal the decision to the Idaho Public Utilities Commission. PROVISIONS 1. Inoperable lights will be repaired as soon as reasonably possible, during regular business hours or as allowed by company’s operating schedule and requirements, provided the Company receives notification of inoperable lights from Customer or a member of the public by either notifying Rocky Mountain Power’s customer service (1-888-221-7070) or www.rockymountainpower.net/streetlights Rocky Mountain Power’s obligation to repair lights is limited to this tariff. 2. The Company reserves the right to contract for the maintenance of lighting service provided hereunder. 3. Temporary disconnection and subsequent reconnection of electrical service requested by the Customer shall be at the Customer’s expense. The Customer may request temporary suspension of power for lighting by written notice. During such periods, the monthly rate will be reduced by the Company’s estimated average monthly relamping and energy costs for the luminaire. The facilities may be considered idle and may be removed after 12 months of inactivity. 4. Pole re-painting, when requested by the Customer and not required for safety reasons, shall be done at the Customer’s expense, using the original pole color. 5. Glare or vandalism shielding, when requested by the Customer, and subject to availability, shall be installed at the Customer’s expense. In cases of repetitive vandalism, the Company may notify the Customer of the need to install vandal shields at the Customer’s expense, or otherwise have the lighting removed. ELECTRIC SERVICE REGULATIONS: Service under this Schedule will be in accordance with the terms of the Electric Service Agreement between the Customer and the Company. The Electric Service Regulations of the Company on file with and approved by the Idaho Public Utilities Commission, including future applicable amendments, will be considered as forming a part of and incorporated in said Agreement. . IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Feb. 22, 2016 March 15, 2016 Jean D. Jewell Secretary First Revision of Sheet No. 9.1 I.P.U.C. No. 1 Canceling Original Sheet No. 9.1 Submitted Under Case No. PAC-E-21-07 ISSUED: November 8, 2021 EFFECTIVE: January 1, 2022 ROCKY MOUNTAIN POWER ELECTRIC SERVICE SCHEDULE NO. 9 STATE OF IDAHO ______________ General Service -- High Voltage ______________ AVAILABILITY: At any point on the Company's interconnected system where there are facilities of adequate capacity. APPLICATION: This Schedule is for alternating current, three phase electric service supplied at approximately 44,000 volts or 69,000 volts or greater, through a single point of delivery, for all service required on the Customer's premises by customers contracting for not less than 80 kW nor more than 30,000 kW. Seasonal service will be available only under other appropriate schedules. Service under this Schedule is limited to a maximum power requirement of 30,000 kW. When a Customer's load reaches a level in excess of 30,000 kW, continued service will require special contract arrangements; provided, however, that special contract arrangements will not be required in those cases where electric service is being supplied by Company under this Schedule to operations existing as of the effective date of this Schedule which, because of emergency conditions, or which on sporadic occasions only, may exceed 30,000 kW. This Schedule is not available to new loads in excess of 30,000 kW nor to existing operations whose maximum power requirement, because of increased operations, plant expansion or equipment additions, exceeds 30,000 kW. In this latter case, a maximum power requirement in excess of 30,000 kW shall be deemed to exist when a Customer's maximum power requirement exceeds 30,000 kW in at least three (3) months of any continuous period of six (6) successive months. (Continued) IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Feb. 1, 2022 Jan. 1, 2022 Per O.N. 35277 Jan Noriyuki Secretary Ninth Revision of Sheet No. 9.2 I.P.U.C. No. 1 Canceling Eighth Revision of Sheet No. 9.2 Submitted Under Case No. PAC-E-21-07 ISSUED: November 8, 2021 EFFECTIVE: January 1, 2022 ELECTRIC SERVICE SCHEDULE NO. 9 - Continued MONTHLY BILL: Rate: Customer Service Charge Power Rate Energy Rate On-Peak Off-Peak 5.1115¢ 3.9086¢ per kWh per kWh 4.6365¢ 3.5213¢ per kWh per kWh TIME PERIODS: On-Peak: November through May inclusive 6:00 a.m. to 9:00 a.m. and 6:00 p.m. to 11:00 p.m., all days. June through October inclusive 3:00 p.m. to 11:00 p.m., all days. Off-Peak: All other times. Power Factor: This rate is based on the Customer maintaining at all times a power factor of 85% lagging, or higher, as determined by measurement. If the average power factor is found to be less than 85% lagging, the Power as recorded by the Company's meter will be increased by 3/4 of 1% for every 1% that the power factor is less than 85%. Minimum: The Customer Service Charge plus the minimum Power Charge and appropriate Energy Charges. (continued) IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Feb. 1, 2022 Jan. 1, 2022 Per O.N. 35277 Jan Noriyuki Secretary I.P.U.C. No. 1 Original Sheet No. 9.3 Submitted Under Case No. PAC-E-21-07 ISSUED: November 8, 2021 EFFECTIVE: January 1, 2022 ELECTRIC SERVICE SCHEDULE NO. 9 - Continued MONTHLY BILL (continued): POWER: The kW as shown by or computed from the readings of Company's Power meter for the 15-minute period of Customer's greatest use during the month, adjusted for power factor as specified, determined to the nearest kW, but not less than 80 kW. CONTRACT PERIOD: One year or longer. ELECTRIC SERVICE REGULATIONS: Service under this Schedule will be in accordance with the terms of the Electric Service Agreement between the Customer and the Company. The Electric Service Regulations of the Company on file with and approved by the Idaho Public Utilities Commission, including future applicable amendments, will be considered as forming a part of and incorporated in said Agreement. IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Feb. 1, 2022 Jan. 1, 2022 Per O.N. 35277 Jan Noriyuki Secretary Sixth Revision of Sheet No. 10.1 I.P.U.C. No. 1 Canceling Fifth Revision of Sheet No. 10.1 Submitted Under Advice No. 12-03 ISSUED: October 19, 2012 EFFECTIVE: January 1, 2013 ROCKY MOUNTAIN POWER ELECTRIC SERVICE SCHEDULE NO. 10 STATE OF IDAHO ______________ Irrigation and Soil Drainage Pumping Power Service ______________ AVAILABILITY: At any point on the Company's interconnected system where there are facilities of adequate capacity. APPLICATION: This Schedule is for alternating current, single or three-phase electric service supplied at the Company's available voltage through a single point of delivery for service to motors on pumps and machinery used for irrigation and soil drainage. IRRIGATION SEASON AND POST-SEASON SERVICE: The Irrigation Season is from June 1 to September 15 each year. Service for post-season pumping may be taken by the same Customer at the same point of delivery and through the same facilities used for supplying regular irrigation pumping service during months from September 16 to the following May 31. MONTHLY BILL: Irrigation Season Rate Customer Service Charge: Small Pumping Operations: 15 horsepower or less total connected horsepower served through one service connection - $14.00 per Customer Large Pumping Operations: 16 horsepower or more total connected horsepower served through one service connection - $41.00 per Customer (Continued) IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Oct. 29, 2012 Jan. 1, 2013 Jean D. Jewell Secretary Eleventh Revision of Sheet No. 10.2 I.P.U.C. No. 1 Canceling Tenth Revision of Sheet No. 10.2 Submitted Under Case No. PAC-E-21-07 ISSUED: November 8, 2021 EFFECTIVE: January 1, 2022 ELECTRIC SERVICE SCHEDULE No. 10 - Continued MONTHLY BILL: (Continued) Power Rate: $5.96 per kW for all kW Energy Rate: 8.8388¢ per kWh for first 25,000 kWh 6.6054¢ per kWh for the next 225,000 kWh 4.9435¢ per kWh for all additional kWh Power Factor: This rate is based on the Customer maintaining at all times a power factor of 85% lagging, or higher, as determined by measurement. If the average power factor is found to be less than 85% lagging, the power as recorded by the Company's meter will be increased by 3/4 of 1% for every 1% that the power factor is less than 85%. Minimum: The Customer Service Charge. Post-Season Rate Customer Service Charge: $23.00 per Customer Energy Rate: 7.5110¢ per kWh for all kWh Minimum: The Customer Service Charge. ADJUSTMENTS: All monthly bills shall be adjusted in accordance with Schedules 34 and 94. PAYMENT: All monthly service billings will be due and payable when rendered and will be considered delinquent if not paid within fifteen (15) days. An advance payment may be required of the Customer by the Company in accordance with Electric Service Regulation No. 9. An advance may be required under any of the following conditions: (1) the Customer failed to pay all amounts owed to the Company when due and payable; (2) the Customer paid an advance the previous season that did not adequately cover bills for the entire season and the Customer failed to pay any balance owing by the due date of the final billing issued for the season. (Continued) IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Feb. 1, 2022 Jan. 1, 2022 Per O.N. 35277 Jan Noriyuki Secretary IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Aug. 28, 2006 Sept. 15, 2006 Jean D. Jewell Secretary I.P.U.C. No. 1 Original Sheet No.10.3 ELECTRIC SERVICE SCHEDULE No. 10 -Continued PAYMENT: ( continued) An adequate assurance of payment (advance) may be required from a Customer who has filed bankruptcy. Advances which may be required of the Customer may be paid with cash payment or guarantee, as required by the Company, or with a letter of escrow acceptable to the Company from an authorized bank in the Company's service area. This letter of escrow shall provide that upon termination of service to the Customer, the Company shall receive, upon demand, cash equal to the unpaid balance of the Customer's bill which is not disputed or the full amount of the advance, whichever is the lesser amount. CONNECTION AND DISCONNECTION CHARGES: Company will not routinely seasonally connect and disconnect service to irrigation pumps. However, upon oral or written request the Company will connect and disconnect service at the beginning and end of Customer's pumping operation each year without charge. Customer shall give Company at least two (2) weeks advance notice of the date disconnection and connection of seasonal service is desired. The actual expense incurred for additional connection and disconnection shall be paid by Customer. Customer shall give Company at least two (2) weeks advance notice of the date any additional connection and/or an additional disconnection of service is desired. Meters will not be read and bills will not be issued from November 1 to March 1 unless the customer requests in writing a different ending or beginning point for billing. The bill issued in March will include charges for any unbilled energy used during the period of November 1 to March 1. POWER: The kW as shown by or computed from the readings of the Company's power meter for the 15-minute period of Customer's greatest use during the month, adjusted for power factor as specified, determined to the nearest kW. Metered power demands in kilowatts which exceed one hundred and thirty percent ( 13 0%) of the total connected horsepower served through one service connection will not be used for billing purposes unless and until verified by field test in the presence of the Company to be the result of normal pumping operations. If a demand in excess of 130% of connected horsepower is the result of abnormal conditions existing on the Company's interconnected system or the Customer's system, including accidental equipment failure or electrical supply interruption which results in temporary separation of the Company and Customer's system, the billing demand shall be 130% of the connected horsepower. The Customer may appeal the Company's billing decision to the Idaho Public Utilities Commission in cases of dispute. CONTRACT PERIOD: One year or longer. (Continued) Submitted Under Advice Letter No. 06-06 ISSUED: August 14, 2006 EFFECTIVE: September 15, 2006 IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Aug. 28, 2006 Sept. 15, 2006 Jean D. Jewell Secretary I.P.U.C. No. 1 Original Sheet No. 10.4 ELECTRIC SERVICE SCHEDULE No. 10 -Continued ELECTRIC SERVICE REGULATIONS: Service under this Schedule will be in accordance with the terms of the Electric Service Agreement between the Customer and the Company. The Electric Service Regulations of the Company on file with and approved by the Idaho Public Utilities Commission, including future applicable amendments, will be considered as forming a part of and incorporated in said Agreement. Submitted Under Advice Letter No. 06-06 ISSUED: August 14, 2006 EFFECTIVE: September 15, 2006 Eleventh Revision of Sheet No. 11.1 I.P.U.C. No. 1 Canceling Tenth Revision of Sheet No. 11.1 Submitted Under Tariff Advice No. 22-01 ISSUED: April 20, 2022 EFFECTIVE: July 1, 2022 ROCKY MOUNTAIN POWER ELECTRIC SERVICE SCHEDULE NO. 11 STATE OF IDAHO ______________ Street Lighting Service Company-Owned System ______________ AVAILABILITY: In all territory served by the Company in the State of Idaho. APPLICATION: To unmetered lighting service provided to municipalities or agencies of municipal, county, state or federal governments for dusk to dawn illumination of public streets, highways and thoroughfares by means of Company owned, operated and maintained street lighting systems controlled by a photoelectric control or time switch. MONTHLY BILL: The Monthly Billing shall be the rate per luminaire as specified in the rate tables below. Functional Lighting LED Equivalent Lumen Range Monthly kWh Total Level 1 <=3,500 8 $16.24 Level 2 3,501-5,500 15 $17.32 Level 3 5,501-8,000 25 $17.84 Level 4 8,001-12,000 34 $18.44 Level 5 12,001-15,500 44 $19.48 Level 6 >15,500 57 $23.21 (Continued) IDAHO PUBLIC UTILITIES COMMISSION Approved Effective June 1, 2022 July 1, 2022 Jan Noriyuki Secretary Fifth Revision of Sheet No. 11.2 I.P.U.C. No. 1 Canceling Fourth Revision of Sheet No. 11.2 Submitted Under Case No. PAC-E-21-07 ISSUED: November 8, 2021 EFFECTIVE: January 1, 2022 ELECTRIC SERVICE SCHEDULE NO. 11 - Continued DEFINITIONS: Functional Lighting: Common, less expensive luminaires that may be mounted either on wood, fiberglass or non-decorative metal poles. PROVISIONS: 1. Installation, daily operation, repair and maintenance of lights on this rate schedule to be performed by the Company, providing that the facilities furnished remain readily accessible for maintenance purposes. 2. Company will install only Company approved street lighting equipment at locations acceptable to Company. 3. Inoperable lights will be repaired as soon as reasonably possible, during regular business hours or as allowed by Company’s operating schedule and requirements, provided the Company receives notification of inoperable lights from the Customer or a member of the public by either notifying Rocky Mountain Power’s customer service at (1-888-221-7070) or www.rockymountainpower.net/streetlights. Rocky Mountain Power’s obligation to repair street lights is limited to this tariff. 4. Existing fixtures and facilities that are deemed irreparable will be replaced with comparable fixtures and facilities from the Company’s Construction Standards. 5. The Company will, upon written request of Customer, convert existing street lighting facilities to other types of Company approved facilities. In such event, should the revenue increase, the streetlighting extension allowance defined in Rule 12, section 3.f is applicable only to the increase in annual revenue due to the replacement. If there is no increase in revenue, there is no allowance. The Customer shall advance the estimated cost of all materials and labor associated with installation and removal, less the estimated salvage on all the removed facilities, in excess of the applicable allowance. 6. The entire system, including initial lamp requirements and wiring suitable for connection to Company’s system, will be furnished and installed by the Company. The Customer is responsible for all associated costs that exceed the Street Lighting Extension Allowance as described in the General Rules of this tariff. Customer shall not perform the electrical connection of meters or service conductor to the point of delivery. (Continued) IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Feb. 1, 2022 Jan. 1, 2022 Per O.N. 35277 Jan Noriyuki Secretary Fourth Revision of Sheet No. 11.3 I.P.U.C. No. 1 Canceling Third Revision of Sheet No. 11.3 Submitted Under Advice No. 16-03 ISSUED: February 10, 2016 EFFECTIVE: March 15, 2016 ELECTRIC SERVICE SCHEDULE NO. 11 - Continued PROVISIONS: (continued) 7. Temporary disconnection and subsequent reconnection of electrical service requested by the Customer shall be at the Customer’s expense. The Customer may request temporary suspension of power by written notice. During such periods, the monthly rate will be reduced by the Company’s estimated average energy costs for the luminaire. The facilities may be considered idle and may be removed after 12 months of inactivity. 8. Where approved by the company, all pole mounted outlets used for holiday or other decorations will be supplied with service on a metered General Service rate via a Customer-installed meter base. 9. Pole re-painting, when requested by the Customer and not required for safety reasons, shall be done at Customer’s expense using the original pole color. 10. Glare or vandalism shielding, when requested by the Customer, and subject to availability, shall be installed at the Customer’s expense. In cases of repetitive vandalism, the Company may notify the Customer of the need to install vandal shields at the Customer’s expense, or otherwise have the lighting removed. CONTRACT PERIOD: Not less than five (5) years for both new and replacement fixtures. After the end of the contract term, the Customer can request removal of lights with a minimum of 2 months written notice. The Customer will be charged with costs of removal. If the lights are removed before the end of the contract term, the Customer is responsible for the cost of removal plus depreciated remaining life of the assets less any salvage value. ELECTRIC SERVICE REGULATIONS: Service under this schedule is subject to the General Rules and Regulations contained in the tariff of which this schedule is part and to those prescribed by regulatory authorities. IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Feb. 22, 2016 March 15, 2016 Jean D. Jewell Secretary Ninth Revision of Sheet No. 12.1 I.P.U.C. No. 1 Canceling Eighth Revision of Sheet No. 12.1 Submitted Under Case No. PAC-E-21-07 ISSUED: November 8, 2021 EFFECTIVE: January 1, 2022 ROCKY MOUNTAIN POWER ELECTRIC SERVICE SCHEDULE NO. 12 STATE OF IDAHO ______________ Street and Security Area Lighting Service Customer-Owned System ______________ AVAILABILITY: In all territory served by the Company in the State of Idaho. APPLICATION: To lighting service provided to municipalities or agencies of municipal, county, state or federal governments for dusk to dawn illumination of public streets, highways and thoroughfares by means of Customer owned street lighting systems controlled by a photoelectric control or time switch. Security Area Lighting service on this Schedule is closed to new service. MONTHLY BILL: 1. Energy Only Service – Rate per Luminaire Energy Only Service includes energy supplied from Company’s overhead or underground circuits and does not include any maintenance to Customer’s facilities. The Monthly Billing shall be the rate per luminaire as specified in the rate tables below. High Pressure Sodium Vapor– No Maintenance (Continued) IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Feb. 1, 2022 Jan. 1, 2022 Per O.N. 35277 Jan Noriyuki Secretary I ... Ninth Revision of Sheet No. 12.2 I.P.U.C. No. 1 Canceling Eighth Revision of Sheet No. 12.2 Submitted Under Case No. PAC-E-21-07 ISSUED: November 8, 2021 EFFECTIVE: January 1, 2022 ELECTRIC SERVICE SCHEDULE NO. 12 - Continued MONTHLY BILL: (continued) Lumen Rating 9,000 12,000 19,500 32,000 107,800 Watts 100 175 250 400 1000 Monthly kWh 39 69 93 145 352 Energy Only Service $3.54 $6.21 $8.50 $13.36 $31.99 Low Pressure Sodium Vapor - No Maintenance Sodium Vapor Security Area Flood Light - No Maintenance For non-listed luminaires, the cost will be calculated for 4167 annual hours of operation including applicable loss factors for ballasts and starting aids at the cost per kWh given below. (Continued) Non-Listed Luminaire IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Feb. 1, 2022 Jan. 1, 2022 Per O.N. 35277 Jan Noriyuki Secretary I ... ... ... - - - Eighth Revision of Sheet No. 12.3 I.P.U.C. No. 1 Canceling Seventh Revision of Sheet No. 12.3 Submitted Under Case No. PAC-E-21-07 ISSUED: November 8, 2021 EFFECTIVE: January 1, 2022 ELECTRIC SERVICE SCHEDULE NO. 12 - Continued MONTHLY BILL: (continued) 2. Maintenance Service (No New Service) Monthly maintenance is only applicable for existing monthly maintenance service agreements in effect prior to June 29, 2007. A. Street Lighting, “Partial Maintenance” Mercury Vapor – Partial Maintenance High Pressure Sodium – Partial Maintenance B. Street Lighting, “Full Maintenance” High Pressure Sodium – Full Maintenance (Continued) IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Feb. 1, 2022 Jan. 1, 2022 Per O.N. 35277 Jan Noriyuki Secretary ... ... ... ... Fourth Revision of Sheet No. 12.4 I.P.U.C. No. 1 Canceling Third Revision of Sheet No. 12.4 Submitted Under Case No. PAC-E-21-07 ISSUED: November 8, 2021 EFFECTIVE: January 1, 2022 ELECTRIC SERVICE SCHEDULE NO. 12 - Continued MONTHLY BILL: (continued) SPECIFICATIONS AND SERVICE FOR STREET LIGHTING WITH PARTIAL AND FULL MAINTENANCE (NO NEW SERVICE): Installations must have met Company construction standards in place at the time of installation in order to receive “full maintenance.” If Company is unable to obtain materials to perform maintenance, the street light facilities will be deemed obsolete and must be upgraded at customer expense in order to qualify for maintenance under the Electric Service Schedule. Street Lighting Service under “partial maintenance” includes energy, lamp and glassware renewals and cleaning of glassware. Street Lighting Service under “full maintenance” includes energy, lamp and glassware replacements and cleaning of glassware, and replacement of damaged or inoperative photocells, ballasts, starting aids, poles, mast arms and luminaires: provided, however, that any costs for materials which are over and above costs for Company’s standard materials, as determined by the Company, are not included in this Electric Service Schedule. Such extra costs shall be paid by Customer. Burning-hours of lamps will be controlled by the Company. The Company shall not be liable under the maintenance provided under “Full Maintenance” for damages caused by (a) war; (b) earthquakes; and (c) acts of God, excepting lightning strikes; or (d) sabotage. The costs associated with replacements and repairs to Customer-owned facilities associated with these acts will be billed to the Customer on an as if and when basis. PROVISIONS: 1. The Company will not maintain new Customer owned street lights. Such maintenance will be the responsibility of the Customer; however the Company may install pole identification tags for the purposes of tracking unmetered Customer owned lights. (continued) IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Feb. 1, 2022 Jan. 1, 2022 Per O.N. 35277 Jan Noriyuki Secretary Second Revision of Sheet No. 12.5 I.P.U.C. No. 1 Canceling First Revision of Sheet No. 12.5 Submitted Under Case No. PAC-E-21-07 ISSUED: November 8, 2021 EFFECTIVE: January 1, 2022 ELECTRIC SERVICE SCHEDULE NO. 12 - Continued PROVISIONS: (continued) 2. Customer owned lights, mounted to Company owned distribution poles, shall be installed, maintained, transferred or removed only by qualified personnel. Appurtenances or other alterations to the Company’s standard will not be supported by, or become the responsibility of, the Company. Following notification by the Customer, inoperable lights under this provision will be repaired as soon as possible, during regular business hours or as allowed by Company’s operating schedule and requirements. Costs described in this provision will be invoiced to the Customer upon completion of the work. 3. The entire system, including the design of facilities, installation of fixtures on Customer poles, and wiring suitable for connection to Company’s system, will be furnished by the Customer. 4. Customer must notify the Company in writing of any changes to the street lighting system which would affect billing, including new installations, removals or wattage changes. Standard notification procedure will be through online forms at www.rockymtnpower.net/streetlights. 5. All new underground-fed lights on this schedule will require a Customer installed means of disconnect acceptable to both the Company and the local electrical inspecting authority. 6. Temporary disconnection and subsequent reconnection of electrical service requested by the Consumer shall be at the Consumer’s expense. 7. Where approved by the Company, all new pole mounted outlets used for holiday or other decorations, as well as traffic or other signal systems, will be supplied with service on a metered General Service rate schedule via a Consumer-installed meter base. CONTRACT PERIOD: Not less than one (1) year for both new and replacement fixtures. ELECTRIC SERVICE REGULATIONS: Service under this schedule is subject to the General Rules and Regulations contained in the tariff of which this schedule is part and to those prescribed by regulatory authorities. IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Feb. 1, 2022 Jan. 1, 2022 Per O.N. 35277 Jan Noriyuki Secretary IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Aug. 28, 2006 Sept. 15, 2006 Jean D. Jewell Secretary I.P.U.C. No. 1 ROCKY MOUNTAIN POWER ELECTRIC SERVICE SCHEDULE NO. 14 STATE OF IDAHO Temporary Service Connection Facilities No new Service Original Sheet No. 14 AVAILABILITY: To any Customer requiring a temporary power connection at any point on Company's interconnected system where there are facilities of appropriate voltage and adequate capacity. APPLICATION: This Schedule is for the rental of a pre-assembled service connection loop for providing temporary 120/240 volt power service. INSTALLATION AND DISCONNECT CHARGE: $45.00 payable in advance each time a pre assembled service loop installation is connected to Company's service facilities. MONTHLY RENTAL FEE: $7.50 per month for each pre-assembled service loop installed by the Company, prorated for any partial month after the first month that service loop is connected. SERVICE CONDITIONS: The Company will furnish and install a pre-assembled service loop consisting of a housing, necessary receptacles, circuit-breakers, meter socket, conduit, wire, grounding material and connectors. The pre-assembled service loop will meet all provisions of the National Electrical Code as required for permanent installations. The service loop may be either bonded to or attached with conduit straps to a standard Company distribution pole. Energy requirements will be supplied under the Company's Electric Service Schedule No. 1, 6, 23, or 36 and in accordance with the provisions of the Company's Electric Service Regulation No. 12 for temporary service. CONTRACT PERIOD: One month or longer. ELECTRIC SERVICE REGULATIONS: Service under this Schedule will be in accordance with the terms of the Electric Service Agreement between the Customer and the Company. The Electric Service Regulations of the Company on file with and approved by the Idaho Public Utilities Commission, including future applicable amendments, will be considered as forming a part of and incorporated in said agreement. Submitted under Advice Letter No. 06-06 ISSUED: August 14, 2006 EFFECTIVE: September 15, 2006 IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Aug. 28, 2006 Sept. 15, 2006 Jean D. Jewell Secretary I.P.U.C. No.1 ROCKY MOUNTAIN POWER ELECTRIC SERVICE SCHEDULE NO. 19 STATE OF IDAHO Commercial and Industrial Space Heating (No New Service) Original Sheet No. 19.1 AVAILABILITY: At any point on the Company's interconnected system where there are facilities of adequate capacity. APPLICATION: This Schedule is for alternating current single or three-phase electric service to Commercial and Industrial Customers at Company's available voltage for all service required on the Customer's premises subject to the terms and conditions set forth herein. Service for electric resistance heaters and year round heat pumps will be supplied through a special circuit and metered through one kilowatt-hour meter. All other lighting and power requirements will be supplied through a separate circuit and will be separately metered, except that electric motor-drived compressors installed to provide comfort cooling and electric water heating equipment may be connected to the special space heating circuit. No other equipment shall be connected to the wiring serving the space heating equipment. This Schedule is available for space heating only when the Customer regularly uses electric energy for all other service requirements including but not limited to lighting, cooking, water heating, air conditioning, and the operation of machines and other equipment. (Continued) Submitted Under Advice Letter No. 06-06 ISSUED: August 14, 2006 EFFECTIVE: September 15, 2006 IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Dec. 14, 2016 Jan. 1, 2017 Per O.N. 33668 Diane M. Hanian Secretary I.P.U,C. No. 1 Tenth Revision of Sheet No. 19.2 Canceling Ninth Revision of Sheet No. 19.2 ELECTRIC SERVICE SCHEDULE NO. 19 -Continued MONTHLY BILL: Rate for space heating: Billing Months May through October. Inclusive Customer Service Charge: $23.00 per Customer Energy Rate: 9.6502¢ per kWh for all kWh Rate for all other service: Billing Months November through April, Inclusive $23.00 7.2175¢ per Customer per kWh for all kWh All other service requirements will be supplied under Electric Service Schedule No. 6, or Electric Service Schedule No. 6A, or Electric Service Schedule No. 23, or Electric Service Schedule No. 23A, or Electric Service Schedule No.35, or Electric Service Schedule No. 35A. SPACE HEATING: All space heating equipment shall be permanently installed and shall be the sole means of heating the building space occupied by the Customer. All space heating equipment and installation thereof and all supply wiring shall conform with the Company's specifications. AIR CONDITIONING: All air conditioning equipment shall be permanently installed and shall be the sole means of providing comfort cooling for the building space occupied by the Customer. All air conditioning equipment and installation thereof and all supply wiring shall conform with the Company's specifications. Electric service for comfort cooling will be metered and billed at the above rate only when Customer also uses electric service for his total space heating requirements. WATER HEATING: Water heaters served hereunder shall be insulated storage, single or multiple-unit type of construction approved by the Company, the heating units of which shall be noninductive ~d controlled by separate thermostats. Electric service of storage water heating will be metered and billed at the above rate only when Customer also uses electric service for his total space heating requirements. Submitted Under Case No. PAC-E-16-12 ISSUED: November 11, 2016 (Continued) EFFECTIVE: January 1, 2017 IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Aug. 28, 2006 Sept. 15, 2006 Jean D. Jewell Secretary I.P.U.C. No. 1 Original Sheet No. 19.3 ELECTRIC SERVICE SCHEDULE NO. 19 -Continued WATERHEATING: (continued) Water heaters shall have a minimum capacity of 30 gallons each and the total capacity of heating elements in each heater shall not exceed 50 kilowatts except that, when heaters are operated for swimming pool heating, more than 50 kilowatts capacity in a heater may be permitted upon written authorization of the Company. All equipment shall be so designed and controlled that not more than 10 kilowatts will be switched on or off at one time unless otherwise permitted by written authorization of the Company. INSULATION STANDARDS: Commercial and industrial buildings constructed after September 1, 1984, and such buildings constructed prior to September 1, 1984, but which previously did not otherwise qualify for service under this electric service schedule must now also meet the following minimum insulation standards in order to qualify for service under this electric service schedule. The maximum heat loss of the building to be heated while maintaining a reasonable and appropriate indoor air temperature during periods of winter design outdoor weather conditions as defined in the latest ASHRAE Handbook of Fundamentals including infiltration and excluding ventilation losses for electrically heated buildings shall not exceed 21 btu/hour/square foot in new buildings or 24 btu/hour/square foot in converted buildings. Electrically heated buildings shall have double glass except where it may be impractical such as at entrance doors or display windows etc. Electrically heated buildings can be considered to meet the requirements if the following criteria are met: "U" Factor Ceilings 0.032 Opaque Walls 0.096 Floors Over Vented Crawl Spaces or Over Unheated Basements 0.053 Walls of Heated Basement 0.077 Submitted Under Advice Letter No. 06-06 ISSUED: August 14, 2006 Minimum Insulation Factors New Buildings Converted Buildings "R" Factor 31 (Continued) 10.4 19 13 "U" Factor 0.032 0.156 0.053 0.125 "R" Factor 31 6.4 19 8 EFFECTIVE: September 15, 2006 IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Aug. 28, 2006 Sept. 15, 2006 Jean D. Jewell Secretary I.P.U.C. No. 1 Original Sheet No. 19.4 ELECTRIC SERVICE SCHEDULE NO. 19 -Continued INSULATION STANDARDS: (continued) Concrete slabs on grade shall have insulation 24" wide by 2" thick around the perimeter of the slab. This requirement may be waived for converted buildings at the discretion of the Company. Glazing shall be double glass except where it may be impractical such as at entrance doors or display windows, etc. Weather stripping shall be installed on all exterior doors and windows. Ducts and Plenums, both supply and return, not enclosed within the heated space, shall have a minimum of 2" insulation (U = 0.13). CONTRACT PERIOD: One year or longer. ELECTRIC SERVICE REGULATIONS: Service under this Schedule will be in accordance with the terms of the Electric Service Agreement between the Customer and the Company. The Electric Service Regulations of the Company on file with and approved by the Idaho Public Utilities Commission, including future applicable amendments, will be considered as forming a part of and incorporated in said Agreement. Submitted Under Advice Letter No. 06-06 ISSUED: August 14, 2006 EFFECTIVE: September 15, 2006 I.P.U.C. No. 1 First Revision of Sheet No. 21.1 Canceling Original Sheet No. 21.1 Submitted Under Docket No. PAC-E-06-10 - Advice Letter No. 07-03 ISSUED: January 10, 2007 EFFECTIVE: April 1, 2007 ROCKY MOUNTAIN POWER ELECTRIC SERVICE SCHEDULE NO. 21 STATE OF IDAHO ______________ Low Income Weatherization Services Optional For Income Qualifying Customers _____________ PURPOSE: Service under this schedule is intended to maximize the efficient utilization of the electricity requirements of existing residential dwellings inhabited by customers that meet income guidelines through the installation of energy efficient materials. The decision to extend service under this schedule shall be based upon the eligibility requirements contained herein. AVAILABILITY: This tariff is applicable to residential customers in all territory served by the Company in the state of Idaho. 1. ENERGY CONSERVATION SERVICE TO LOW INCOME CUSTOMERS: This program is available to existing single family and multi-family residential units. It is intended to reduce the electricity requirements and increase the penetration of weatherization and electric efficiency measures in residential dwellings inhabited by low income households through the installation of permanent energy efficiency materials. The decision to extend service under this schedule shall be based on eligibility requirements contained herein. A. Definitions: 1. "Dwelling" is real or personal property within the state inhabited as the principal residence of a dwelling owner or a tenant. “Dwelling” includes a manufactured home, a single-family home, duplex or multi-unit residential housing. “Dwelling” does not include a recreational vehicle. a. Duplexes and fourplexes are eligible if at least one half of the dwelling is occupied by low income tenants. (Continued) IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Feb. 8, 2007 April 1, 2007 Per O.N. 30239 Jean D. Jewell Secretary I.P.U.C. No. 1 Fourth Revision of Sheet No. 21.2 Canceling Third Revision of Sheet No. 21.2 ELECTRIC SERVICE SCHEDULE NO. 21 – (Continued) A. Definitions (Continued): b. Triplexes and multi-family dwellings are eligible if at least 66% of the units are occupied by low income tenants. 2. "Agency" means a non-profit group, Municipality or County authorized to receive funds for installation of energy efficiency materials in low income properties. 3. "Low Income" means households qualifying under the Federal low income guidelines and certified for eligibility according to agency procedure. Income eligibility is based on 200% of federal poverty guidelines. 4. "Major Measure" means ceiling insulation, wall insulation, floor insulation and window replacements applicable in dwellings with permanently installed electric space heating systems. When cost-effective (Savings to Investment Ratio (“SIR”) of 1.0 or greater as determined by a U.S. Department of Energy (“DOE”) approved energy audit), all major measures must be installed or in place or financial assistance under this schedule will not be offered. If physical barriers exist that prohibit the installation of a measure, then the measure is not required as a condition for financial assistance under this schedule. 5. "Supplemental Measures and Additional Measures" are not required measures under this schedule, but may qualify for a Company reimbursement. B. Financial Assistance: 1. The Company will reimburse Agency 85% of the installed cost of all eligible Energy Conservation Measures listed in Section C of this Tariff, with the exception of ductless heat pumps, which will be reimbursed up to 100% of related installed costs. Reimbursements on weatherized homes will be provided one time only on any individual measure, and up to two times per dwelling. (Continued) Submitted Under Advice No. 19-01 ISSUED: January 16, 2019 EFFECTIVE: March 6, 2019 IDAHO PUBLIC UTILITIES COMMISSION Approved Effective March 5, 2019 March 6, 2019 Diane M. Hanian Secretary I.P.U.C. No. 1 Fourth Revision of Sheet No. 21.3 Canceling Third Revision of Sheet No. 21.3 Submitted Under Advice No. 16-02 ISSUED: January 19, 2016 EFFECTIVE: March 1, 2016 ELECTRIC SERVICE SCHEDULE NO. 21 - Continued B. Financial Assistance (Continued): 2. The Company will reimburse Agency for administrative costs based on 15% of Rocky Mountain Power’s rebate on installed measures, not to exceed the following total administrative payment per building: Dwelling Units in Building Maximum Administrative Payment 1 to 4 $350 5 to 10 $800 11 to 15 $1200 16 to 20 $1400 21 to 25 $1600 26 to 30 $1800 31+ $2100 The minimum reimbursement will be $150 on homes with one or more Major Measure installed and $50 on homes without the installation of a Major Measure. 3. Agencies must invoice Company within 120 days of job completion. 4. A maximum of $300,000 in Company reimbursements will be available annually (April 1 through March 31). Reimbursements related to health and safety measures are limited to 15% of the annual cost of total jobs performed by each agency. 5. Annual funding of $25,000 in total will be provided to Eastern Idaho Community Action Partnership and SouthEastern Idaho Community Action Agency for conservation education. C. Energy Conservation Measures: Financial assistance will be provided based on the results of a cost effective analysis through a Department of Energy approved energy audit. The energy efficient measures eligible for funding must be installed in dwellings with permanently installed operable electric space heat except where noted. The electric space heating system must be designed to heat at least 51% of the home. All Major and Supplemental Measures indicated below may qualify for a company reimbursement when audit results indicate a measure has a Savings to Investment Ratio of 1.0 or greater. The energy efficient measures that may be eligible for funding are listed as follows: Major Measures – Electric Heating System Required: 1. Ceiling insulation up to R-48 for ceilings with less than R-30 in place. R-30 or better attics will not be further insulated. (Continued) IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Feb. 29, 2016 March 1, 2016 Jean D. Jewell Secretary I.P.U.C. No. 1 Second Revision of Sheet No. 21.4 Canceling First Revision of Sheet No. 21.4 Submitted Under Advice No. 16-02 ISSUED: January 19, 2016 EFFECTIVE: March 1, 2016 ELECTRIC SERVICE SCHEDULE NO. 21 - Continued C. Energy Conservation Measures: (Continued) 2. Floor insulation over unheated spaced up to R-30. 3. Wall insulation up to R-26 for walls with no insulation installed (financing will not be available for the installation of urea-formaldehyde wall insulation). 4. Replacement windows with a U-value of 0.30 or less. Nothing shall preclude the Company from providing a reimbursement for the installation of a greater R value on insulation for the above items that are determined to be cost effective (SIR is 1.0 or greater) through the audit process. Supplemental Measures – Electric Heating System Required: 1. Attic ventilation excluding power ventilators, whole house mechanical ventilation and spot ventilation for kitchen and baths. 2. Ground cover. 3. Forced air electric space heating duct insulation and sealing in unheated spaces. 4. Weather stripping and/or caulking, including blower door assisted air sealing and duct sealing. 5. Thermal doors. (Continued) IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Feb. 29, 2016 March 1, 2016 Jean D. Jewell Secretary I.P.U.C. No. 1 Third Revision of Sheet No. 21.5 Canceling Second Revision of Sheet No. 21.5 ELECTRIC SERVICE SCHEDULE NO. 21 - Continued C. Energy Conservation Measures: (Continued) Supplemental Measures – Electric Heating System Required (continued) 6. Timed thermostats on centrally controlled multi-room heating/cooling systems except when used with heat pumps and Smart thermostats with occupancy sensors. Heat anticipating type thermostats for zonal electric resistance heating systems. 7. Electric furnace repair and replacement. 8. Ductless heat pumps. Additional Measures – No Electric Heating System Requirement: 1. Pipe insulation, energy efficient showerheads and aerators where electric water heaters are present. 2. Light emitting diodes (LED) and/or compact fluorescent (CFL) light bulbs applicable in all homes – Energy Star certified bulbs placed in fixtures that are on 2 hours or more per day. 3. LED light fixtures. 4. Existing Refrigerator with monitored results listed in the Weatherization Assistance Program Technical Assistance center database with a savings to investment ration of 1.0 or greater may be replaced with an Energy Star model. Replaced refrigerators must be removed and recycled in accordance with EPA guidelines. 5. Electric water heater repair and replacement. 6. Measures that promote health and safety related to electricity usage. D. Provisions of Service for Energy Conservation Service to Low Income Customers: 1. Measures installed are intended to improve upon the electric efficiencies of participating homes and must be included in the U.S. Department of Energy’s Weatherization Assistance Program available to Agency. (Continued) Submitted Under Advice No. 17-01 ISSUED: November 27, 2017 EFFECTIVE: February 1, 2018 IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Jan. 22, 2018 Feb. 1, 2018 Diane M. Hanian Secretary I.P.U.C. No. 1 First Revision of Sheet No. 21.6 Canceling Original Sheet No. 21.6 Submitted Under Docket No. PAC-E-06-10 – Advice Letter No. 07-03 ISSUED: January 10, 2007 EFFECTIVE: April 1, 2007 ELECTRIC SERVICE SCHEDULE NO. 21 – (Continued) D. Provisions of Service for Energy Conservation Service to Low Income Customers: (Continued) 2. A DOE-approved energy audit must be completed by the Agency prior to installation of Major and Supplemental Measures. 3. Agency must qualify residential customers for assistance using the Federal low income guidelines. 4. Installation shall meet Federal, state and local building codes. 5. Measures installed under this schedule shall not receive financial incentives from other Company programs. 6. Agency shall inspect the installation to insure that the services meet or exceed required specifications. 7. Company may audit Agency weatherization and financial records and inspect the installations in dwellings of customers receiving services under this program 8. Company shall pay Agency the amount established under the terms of their contract when provisions of this schedule have been met. ELECTRIC SERVICE REGULATIONS: Service under this schedule is subject to the Electric Service Regulations of the Company on file with and approved by the Idaho Public Utilities Commission, including future applicable amendments and additional regulations prescribed by regulatory authorities. IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Feb. 8, 2007 April 1, 2007 Per O.N. 30239 Jean D. Jewell Secretary Ninth Revision of Sheet No. 23.1 I.P.U.C. No. 1 Canceling Eighth Revision of Sheet No. 23.1 Submitted Under Case No. PAC-E-21-07 ISSUED: November 8, 2021 EFFECTIVE: January 1, 2022 ROCKY MOUNTAIN POWER ELECTRIC SERVICE SCHEDULE NO. 23 STATE OF IDAHO ______________ General Service ______________ AVAILABILITY: At any point on the Company's interconnected system where there are facilities of adequate capacity. APPLICATION: This Schedule is for alternating current, single or three-phase electric service supplied at Company's available voltage through one metering installation at a single point of delivery for all service required on the premises. MONTHLY BILL: Customer Service Charge Energy Rate (Continued) IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Feb. 1, 2022 Jan. 1, 2022 Per O.N. 35277 Jan Noriyuki Secretary Fifth Revision of Sheet No. 23.2 I.P.U.C. No. 1 Canceling Fourth Revision of Sheet No. 23.2 Submitted Under Case No. PAC-21-07 ISSUED: November 8, 2021 EFFECTIVE: January 1, 2022 ELECTRIC SERVICE SCHEDULE NO. 23 - Continued Power Factor: This rate is based on the Customer maintaining at all times a power factor of 85% lagging, or higher, as determined by measurement. If the average power factor is found to be less than 85% lagging, Customer will be billed for 3/4 of 1% of the Power recorded by the Company’s meter for every 1% that the power factor is less than 85%. This Power will be billed at the Power Rate stated in Electric Service Schedule No. 6. Voltage Discount: Where Customer takes service from Company's available lines of 2,300 volts or higher and provides and maintains all transformers and other necessary equipment, the voltage discount based on measured Energy will be: 0.4397¢ per kWh for all kWh. Minimum Bill: The Customer Service Charge POWER: The kW as shown by or computed from the readings of the Company’s Power meter for the 15-minute period of Customer’s greatest use during the month, determined to the nearest kW. SEASONAL SERVICE: Service for annually recurring periods of seasonal use where service is normally discontinued or curtailed during a part of the year may be contracted for under this Schedule under either of the following conditions: (a) Customer may contract for service under this Schedule on a year-round basis paying for all service, including transformer losses where applicable, under the rates set forth under "Monthly Bill" above including the monthly minimum bill during those months service is curtailed or is not utilized in the Customer's operations. (b) Customer may contract for seasonal service under this Schedule with a net minimum seasonal payment as follows: $216.00 plus Energy Charges for Customer taking service at less than 2,300 volts and $576.00 plus Energy Charges for Customer taking service at 2,300 volts or higher. CONTRACT PERIOD: One year or longer. (Continued) IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Feb. 1, 2022 Jan. 1, 2022 Per O.N. 35277 Jan Noriyuki Secretary IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Aug. 28, 2006 Sept. 15, 2006 Jean D. Jewell Secretary I.P.U.C. No. 1 Original Sheet No. 23.3 ELECTRIC SERVICE SCHEDULE NO. 23 -Continued ELECTRIC SERVICE REGULATIONS: Service under this Schedule will be in accordance with the terms of the Electric Service Agreement between the Customer and the Company. The Electric Service Regulations of the Company on file with and approved by the Idaho Public Utilities Commission, including future applicable amendments, will be considered as forming a part of and incorporated in said Agreement. Submitted Under Advice Letter No. 06-06 ISSUED: August 14, 2006 EFFECTIVE: September 15, 2006 Ninth Revision of Sheet No. 23A.1 I.P.U.C. No. 1 Canceling Eighth Revision of Sheet No. 23A.1 Submitted Under Case No. PAC-E-21-07 ISSUED: November 8, 2021 EFFECTIVE: January 1, 2022 ROCKY MOUNTAIN POWER ELECTRIC SERVICE SCHEDULE NO. 23A STATE OF IDAHO ______________ General Service (Residential and Farm) ______________ AVAILABILITY: At any point on the Company's interconnected system where there are facilities of adequate capacity for service to any customer who qualifies as a "Residential Load" or "Farm Load" under both (1) the Pacific Northwest Electric Power Planning and Conservation Act, P.L. 96-501 as the same may be amended, and (2) a Residential Purchase and Sale Agreement, under Section 5(c) of such Act and in effect between the Company and the Bonneville Power Administration. APPLICATION: This Schedule is for alternating current, single or three-phase electric service supplied at Company's available voltage through one metering installation at a single point of delivery for all service required on the premises. MONTHLY BILL: Customer Service Charge Energy Rate (Continued) IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Feb. 1, 2022 Jan. 1, 2022 Per O.N. 35277 Jan Noriyuki Secretary Fourth Revision of Sheet No. 23A.2 I.P.U.C. No. 1 Canceling Third Revision of Sheet No. 23A.2 Submitted Under Advice No. 12-03 ISSUED: October 19, 2012 EFFECTIVE: January 1, 2013 ELECTRIC SERVICE SCHEDULE NO. 23A - Continued Power Factor: This rate is based on the Customer maintaining at all times a power factor of 85% lagging, or higher, as determined by measurement. If the average power factor is found to be less than 85% lagging, Customer will be billed for 3/4 of 1% of the Power recorded by the Company’s meter for every 1% that the power factor is less than 85%. This Power will be billed at the Power Rate stated in Electric Service Schedule No. 6. Voltage Discount: Where Customer takes service from Company's available lines of 2,300 volts or higher and provides and maintains all transformers and other necessary equipment, the voltage discount based on measured Energy will be: 0.4397¢ per kWh for all kWh. Minimum Bill: The Customer Service Charge POWER: The kW as shown by or computed from the readings of the Company’s Power meter for the 15-minute period of Customer’s greatest use during the month, determined to the nearest kW. MONTHLY BILLING REDUCTION: Rates in this Schedule shall be reduced by the monthly kilowatt-hour credit adjustment set forth under "Monthly Rates" in the currently effective Electric Service Schedule No. 34. SEASONAL SERVICE: Service for annually recurring periods of seasonal use where service is normally discontinued or curtailed during a part of the year may be contracted for under this Schedule under either of the following conditions: (a) Customer may contract for service under this Schedule on a year-round basis paying for all service, including transformer losses where applicable, under the rates set forth under "Monthly Bill" above including the monthly minimum bill during those months service is curtailed or is not utilized in the Customer's operations. (Continued) IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Oct. 29, 2012 Jan. 1, 2013 Jean D. Jewell Secretary Fourth Revision of Sheet No. 23A.3 I.P.U.C. No. 1 Canceling Third Revision of Sheet No. 23A.3 Submitted Under Case No. PAC-E-21-07 ISSUED: November 8, 2021 EFFECTIVE: January 1, 2022 ELECTRIC SERVICE SCHEDULE NO. 23A – Continued SEASONAL SERVICE: (continued) (b) Customer may contract for seasonal service under this Schedule with a net minimum seasonal payment as follows: $216.00 plus Energy Charges for Customer taking service at less than 2,300 volts and $576.00 plus Energy Charges for Customer taking service at 2,300 volts or higher. CONTRACT PERIOD: One year or longer. SPECIAL CONDITION: Domestic use means all usual residential, apartment, seasonal dwelling, and mobile home court use including domestic water pumping. Farm use means all usual farm electrical loads for raising of crops, livestock or pasturage and includes primary processing necessary for safe and efficient storage or shipment and irrigation pumping. Contiguous parcels of land under single-ownership or leasehold shall be considered to be one Farm and noncontiguous parcels of land under single-ownership or leasehold shall be considered as one Farm unit when operated as a single Farm, unless demonstrated otherwise by the owner or lessee of the parcels. A number of factors shall determine whether contiguous or noncontiguous parcels constitute one or more Farms. These factors shall include, but are not limited to: -- size -- use -- ownership -- control -- operating practices -- distance between parcels -- custom in the trade -- billing treatment by the utility Operators of Farms may be required to certify to the utility all irrigation accounts, including horsepower rating. Customers who feel they meet the definitions of a Farm will have to make application with the Company for review. If Customer application is denied by the Company, the Customer may appeal the decision to the Idaho Public Utilities Commission. (Continued) IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Feb. 1, 2022 Jan. 1, 2022 Per O.N. 35277 Jan Noriyuki Secretary IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Aug. 28, 2006 Sept. 15, 2006 Jean D. Jewell Secretary I.P.U.C. No. 1 Original Sheet No. 23A.4 ELECTRIC SERVICE SCHEDULE NO. 23A-Continued ELECTRIC SERVICE REGULATIONS: Service under this Schedule will be in accordance with the terms of the Electric Service Agreement between the Customer and the Company. The Electric Service Regulations of the Company on file with and approved by the Idaho Public Utilities Commission, including future applicable amendments, will be considered as forming a part of and incorporated in said Agreement. Submitted Under Advice Letter No. 06-06 ISSUED: August 14, 2006 EFFECTIVE: September 15, 2006 IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Aug. 28, 2006 Sept. 15, 2006 Jean D. Jewell Secretary I.P.U.C. No. 1 ROCKY MOUNTAIN POWER ELECTRIC SERVICE SCHEDULE NO. 24 STATE OF IDAHO Interruptible Power Service Original Sheet No. 24.1 AVAILABILITY: For power loads of 1000 kW or greater at any point on the Company's interconnected system where there are facilities of adequate capacity. APPLICATION: This Schedule is for the supply of alternating current, three-phase electric service at available delivery voltages through a single point of delivery for all service required on the Customer's premises. Service hereunder may be interrupted to the degree and under the conditions hereinafter set forth. MONTHLY BILL: Rate: I. Delivery at 46 kV or Higher A. Guaranteed Availability of 90% (Computer Code 124) Power Rate: All kW $6.94 per kW Energy Rate: All kWh 3.7163¢ per kWh B. Guaranteed Availability of 80% (Computer Code 125) Power Rate: All kW $6.60 per kW Energy Rate: All kWh 3.7163¢ per kWh (Continued) Submitted Under Advice Letter No. 06-06 ISSUED: August 14, 2006 EFFECTIVE: September 15, 2006 IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Aug. 28, 2006 Sept. 15, 2006 Jean D. Jewell Secretary I.P.U.C. No. 1 Original Sheet No. 24.2 ELECTRIC SERVICE SCHEDULE NO. 24 -Continued MONTHLY BILL: ( continued) C. Guaranteed Availability of 70% (Computer Code 126) Power Rate: All kW Energy Rate: All kWh $5.68 per kW 3.7163¢ per kWh D. Guaranteed Availability of 60% (Computer Code 127) Power Rate: All kW $4.78 per kW Energy Rate: All kWh Customer Charge: 3.7163¢ per kWh $326.34 per Customer II. Delivery at Primary Voltage (2.3 kV to Less than 46 kV) A. Guaranteed Availability of 90% (Computer Code 128) Power Rate: All kW $8.69 per kW Energy Rate: All kWh 4.0536¢ per kWh B. Guaranteed Availability of 80% (Computer Code 129) Power Rate: All kW $8.42 per kW Energy Rate: All kWh 4.0536¢ per kWh (Continued) Submitted Under Advice Letter No. 06-06 ISSUED: August 14, 2006 EFFECTIVE: September 15, 2006 IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Aug. 28, 2006 Sept. 15, 2006 Jean D. Jewell Secretary I.P.U.C. No. 1 Original Sheet No. 24.3 ELECTRIC SERVICE SCHEDULE NO. 24 -Continued MONTHLY BILL: ( continued) C. Guaranteed Availability of 70% (Computer Code 130) Power Rate: All kW $7.74 per kW Energy Rate: All kWh 4.0536¢ per kWh D. Guaranteed Availability of 60% (Computer Code 131) Power Rate: All kW $7.06 per kW Energy Rate: All kWh Customer Charge: Contract Demand: 4.0536¢ per kWh $266.11 per Customer "Total Contract Demand" as used herein shall mean the maximum Power contracted for by Customer, and in excess of which the Company is under no obligation to supply, as set forth in the Electric Service Agreement executed by and between Customer and Company. Power Factor: This rate is based on the Customer maintaining at all times a power factor of 90% lagging, or higher, as determined by measurement. If the average power factor is found to be less than 90% lagging, the Power as recorded by the Company's meter will be increased by 3/4 of 1 % for every 1 % that the power factor is less than 90%. Minimum Bill: The monthly minimum bill shall be the Customer Service Charge plus the Power Charge plus the appropriate monthly Energy Charge. POWER: The kW as shown by or computed from the readings of the Company's Power meter for the 15-minute period of Customer's greatest use during the month, adjusted for power factor as specified, determined to the nearest kW. (Continued) Submitted Under Advice Letter No. 06-06 ISSUED: August 14, 2006 EFFECTIVE: September 15, 2006 IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Aug. 28, 2006 Sept. 15, 2006 Jean D. Jewell Secretary I.P.U.C. No. 1 Original Sheet No. 24.4 ELECTRIC SERVICE SCHEDULE NO. 24 -Continued GUARANTEED AVAILABILITY: Customer may contract for an annual guaranteed availability of supply of 60%, 70%, 80%, or 90%. Guaranteed Availability shall mean the annual amount of energy in kWh that Company guarantees to make available to Customer over any Contract Year and is determined by multiplying 8760 hours by the Contract Demand in kW and then multiplying this product by the Guaranteed Availability expressed as a fraction; i.e., 90% Guaranteed Availability is expressed as the fraction 9/l 0. CONTRACT YEAR: Contract Year, as used herein, shall mean the period of 12 monthly billing periods between the date of initial service hereunder or any anniversary thereof and the same date of the following calendar year. INTERRUPTION OF SERVICE: All electric power delivered hereunder shall be subject to curtailment when in the Company's sole judgment its spinning reserve, its transmission margin or both are needed to meet the demands of its regular customers on firm rates, or there is an actual or threatened need for such reserve or margin. Customer, upon notice from the Company, shall curtail his use of electric power except plant lighting, fire protection load, and other safety and security load, to the extent requested by and as scheduled by the Company. Curtailment shall be effected by Customer (1) immediately upon request from the Company in cases of emergencies not reasonably predictable by the Company, and (2) in all other instances on notice as specified in the standard form contract. Total annual interruption in kWh during any Contract Year shall not exceed the difference between the Contract Demand in kW multiplied by 8760 hours and the Guaranteed Availability in kWh contracted for by Customer. All electric power delivered hereunder except plant lighting, fire protection load, and other safety and security load, shall be subject to interruption. Customer shall install to Company's specifications and maintain at his sole expense a digital under frequency relay with adjustable contacts set to close at the Scheduled Frequency, associated relay facilities and communication channels to the Company's switching center. Company shall have the right to inspect these facilities upon reasonable notice to Customer. After any interruption hereunder, Customer shall not resume use of electric power except upon notice from Company. In addition to or in lieu of interruption of electric power at the Scheduled Frequency Company may require that electric power by interrupted automatically in the event of a reduction in voltage or in the event of such other operating conditions as may appear appropriate to the Company from time to time. (Continued) Submitted Under Advice Letter No. 06-06 ISSUED: August 14, 2006 EFFECTIVE: September 15, 2006 IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Aug. 28, 2006 Sept. 15, 2006 Jean D. Jewell Secretary I.P.U.C. No. 1 Original Sheet No. 24.5 ELECTRIC SERVICE SCHEDULE NO. 24 -Continued PRIOR RIGHTS: Any right to service under this schedule shall be subject to any prior rights established in Company's existing contracts with customers providing for the supply of interruptible service and specifically rights of Monsanto Company and Amax including right of first refusal to interruptible service. CONTRACT PERIOD: One year or longer. ELECTRIC SERVICE REGULATIONS: Service under this Schedule will be in accordance with the terms of the Electric Service Agreement between the Customer and the Company. The Electric Service Regulations of the Company on file with and approved by the Idaho Public Utilities Commission, including future applicable amendments, will be considered as forming a part of and incorporated in said Agreement. Submitted Under Advice Letter No. 06-06 ISSUED: August 14, 2006 EFFECTIVE: September 15, 2006 Second Revision of Sheet No. 31.1 I.P.U.C. No. 1 Canceling First Revision of Sheet No. 31.1 (continued) Submitted Under Case No. PAC-E-21-07 ISSUED: November 8, 2021 EFFECTIVE: January 1, 2022 ROCKY MOUNTAIN POWER ELECTRIC SERVICE SCHEDULE NO. 31 STATE OF IDAHO ______________ Partial Requirements Service -- Large General Service – 1,000 kW and Over ______________ AVAILABILITY: At any point on the Company's interconnected system where there are facilities of adequate capacity. APPLICATION: This Schedule is for alternating current, three phase electric service supplied at Company’s available voltage through a single point of delivery for Supplementary, Back-up, Maintenance Power or Excess Service (partial requirements service) in addition to regular electric requirements obtained from any service other than the Company, including on-site generation. This Schedule is applicable to customers with on-site generation of more than 1,000 kW but that does not exceed 30,000 kW. Customers not contracting for Back-up Power shall not be subject to this Schedule and shall receive electric service under the applicable general service schedule. This Schedule is not applicable to service for resale, intermittent or highly fluctuating loads, or seasonal use. This Schedule is not required where on-site generation is used only for emergency supply during times of utility outage. This Schedule is not available to loads in excess of 30,000 kW, a maximum power requirement in excess of 30,000 kW shall be deemed to exist when a Customer’s maximum power requirement exceeds 30,000 kW in at least three (3) months of any continuous period of six (6) successive months. MONTHLY BILL: Rate: Customer Service Charge Primary Voltage Transmission $114.00 $372.00 per Customer per Customer $114.00 $372.00 per Customer per Customer Back-up Facilities Rate: Secondary Voltage Primary Voltage Transmission Voltage $8.14 $7.77 $5.73 per kW for all kW per kW for all kW per kW for all kW $6.65 $6.28 $4.32 per kW for all kW per kW for all kW per kW for all kW The Facilities Rate applies to the kW of Back-up Contract Power IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Feb. 1, 2022 Jan. 1, 2022 Per O.N. 35277 Jan Noriyuki Secretary Fourth Revision of Sheet No. 31.2 I.P.U.C. No. 1 Canceling Third Revision of Sheet No. 31.2 (continued) Submitted Under Case No. PAC-E-21-07 ISSUED: November 8, 2021 EFFECTIVE: January 1, 2022 ELECTRIC SERVICE SCHEDULE NO. 31 - Continued MONTHLY BILL: Rate: Back-up Power Rate: Secondary Voltage Primary Voltage Transmission $0.27 $0.26 $0.19 all kW Day all kW Day all kW Day $0.23 $0.22 $0.14 all kW Day all kW Day all kW Day minute period of the Customer's greatest use of Back-up Power during the day Excess Power Rate: Secondary Voltage Primary Voltage Transmission Voltage Supplementary Power Rate: Secondary Voltage Primary Voltage Transmission Voltage Supplementary and Back-up Energy Rate: Secondary Voltage Primary Voltage Transmission Voltage On-Peak Off-Peak $29.44 $28.10 $20.62 $13.62 $12.97 $10.31 4.2506¢ 4.2506¢ 5.1115¢ 3.9086¢ per kW for all kW per kW for all kW per kW for all kW per kW for all kW per kW for all kW per kW for all kW per kWh per kWh per kWh per kWh $24.21 $22.88 $15.55 $12.27 $11.62 $9.29 4.2506¢ 4.2506¢ 4.6365¢ 3.5213¢ per kW for all kW per kW for all kW per kW for all kW per kW for all kW per kW for all kW per kW for all kW per kWh per kWh per kWh per kWh TIME PERIODS: On-Peak: November through May inclusive 6:00 a.m. to 9:00 a.m. and 6:00 p.m. to 11:00 p.m., all days. June through October inclusive 3:00 p.m. to 11:00 p.m., all days. Off-Peak: All other times. IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Feb. 1, 2022 Jan. 1, 2022 Per O.N. 35277 Jan Noriyuki Secretary First Revision of Sheet No. 31.3 I.P.U.C. No. 1 Canceling Original Sheet No. 31.3 Submitted Under Case No. PAC-E-21-07 ISSUED: November 8, 2021 EFFECTIVE: January 1, 2022 ELECTRIC SERVICE SCHEDULE NO. 31 - Continued POWER FACTOR: This rate is based on the Customer maintaining at all times a power factor of 85% lagging, or higher, as determined by measurement. If the average power factor is found to be less than 85% lagging, the Power as recorded by the Company’s meter will be increased by ¾ of 1% for every 1% that the power factor is less than 85%. VOLTAGE LEVELS: Secondary Voltage applies where a distribution Customer takes service from Company’s available lines of less than 2,300 volts. Primary Voltage applies where a distribution Customer takes service from Company’s available lines of 2,300 to less than 46,000 volts and provides and maintains all transformers and other necessary related equipment. Transmission Voltage applies where service is supplied at approximately 46,000 volts or greater through a single point of delivery. POWER: The kW as shown by or computed from the readings of Company's Power meter for the 15-minute period of Customer's greatest use during the month or day, adjusted for power factor as specified, determined to the nearest kW. TYPE OF SERVICE: Whether Power is considered scheduled maintenance, supplementary, back-up, or excess is determined as follows. When the Customer has pre-scheduled Maintenance Service, the power measurements from 0 kW up to the level equal to the pre-scheduled Back-up Power shall be considered Scheduled Maintenance Power. Power measurements above the Scheduled Maintenance Power up to the level equal to the Supplementary Contract Power shall be considered supplementary power. Power measured above the sum of the Scheduled Maintenance Power and Supplementary Contract Power level up to the Total Contract Power (the sum of the Supplementary Contract Power and the Back-up Contract Power) shall be considered Back-up Power. Power measurements in excess of Total Contract Power shall be considered Excess Power. When the Customer has not pre-scheduled Maintenance Service, power measurements from 0 kW up to the level equal to the Supplementary Contract Power shall be considered Supplementary Power. Power measurements above the Supplementary Contract Power level but less than Total Contract Power (the sum of the Supplementary Contract Power and the Back-up Contract Power) shall be considered back-up power. Power measurements in excess of Total Contract Power shall be considered Excess Power. DEFINITIONS: BACK-UP CONTRACT POWER: The specified Power in kilowatts of Back-up Power that the Customer contracts with the Company to supply and which the Company agrees to have available for delivery to the Customer in excess of which the Company is under no obligation to supply. The Back-up Contract Power shall be established by agreement between the Customer and the Company. The level of Back-up Contract Power shall not exceed the total output capacity of the Customer's generation facilities. (continued) IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Feb. 1, 2022 Jan. 1, 2022 Per O.N. 35277 Jan Noriyuki Secretary First Revision of Sheet No. 31.4 I.P.U.C. No. 1 Canceling Original Sheet No. 31.4 Submitted Under Case No. PAC-E-21-07 ISSUED: November 8, 2021 EFFECTIVE: January 1, 2022 ELECTRIC SERVICE SCHEDULE NO. 31 - Continued DEFINITIONS (continued): BACK-UP POWER – DAILY: The kW of Back-up Contract Power supplied by the Company to the Customer. Back-up Power shall be determined for each day of the Billing Period. The kW of Back-up Power each day shall be the kW for the fifteen (15) minute period of the Customer's greatest use of Back-up Power that day, adjusted for power factor as specified, determined to the nearest kW. The Back-up Power for the Billing Period shall be the sum of the Back-up Power for each day of the Billing Period. For each fifteen minute period, Back-up Power shall equal the Measured Power minus the Supplementary Contract Power but shall not be less than zero nor greater than the Back-up Contract Power. BACK-UP SERVICE: Back-up service is electric service used by the Customer to replace electric service ordinarily generated by the Customer's own generation equipment during outages of the facility. BILLING PERIOD: The period of approximately 30 days intervening between regular successive meter reading dates. There shall be 12 billing periods per year. POWER: The rate in kilowatts at which electric energy is generated, transferred or used. Power measurements are calculated based on the average (integrated) usage over consecutive 15 minute periods of time. Power measurements may be based on any one such fifteen minute period in a Billing Period, on the period of greatest use during the Billing Period, or on the period of greatest use during each day, adjusted for power factor as specified, determined to the nearest kW. EXCESS POWER: Excess Power is the power supplied by the Company to the Customer in excess of the Total Contract Power. The kW of Excess Power for the Billing Period shall be the kW for the 15 minute period of the Customer's greatest use of Excess Power during the Billing Period, adjusted for power factor as specified, determined to the nearest kW. For each 15 minute period, Excess Power shall equal the Measured Power minus the Total Contract Power but shall not be less than zero. EXCESS SERVICE: Excess service is service used by the Customer over and above the contracted amount for both Supplementary Service and Back-up Service or Maintenance Service. MAINTENANCE SERVICE: Maintenance service is electric service used by the Customer to replace electric service ordinarily generated by the Customer's own generation equipment during scheduled outages of the facility. MEASURED POWER: The kW as shown by or computed from the readings of the Power meter located at the Company's point of delivery, for the 15 minute period of the Customer’s greatest use during the Billing Period or that day. MEASURED ENERGY: The electric energy in kWh as shown by or computed from the readings of the kilowatt-hour meter located at the Company's point of delivery. (continued) IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Feb. 1, 2022 Jan. 1, 2022 Per O.N. 35277 Jan Noriyuki Secretary I.P.U.C. No. 1 First Revision of Sheet No. 31.5 Canceling Original Sheet No. 31.5 Submitted Under Case No. PAC-E-21-07 ISSUED: November 8, 2021 EFFECTIVE: January 1, 2022 ELECTRIC SERVICE SCHEDULE NO. 31 - Continued DEFINITIONS (continued): SCHEDULED MAINTENANCE POWER: Electric Power and energy made available by the Company to a Customer during the scheduled maintenance periods established in accordance with the provisions of this schedule to replace Back-up Power. Scheduled Maintenance Power shall not exceed the Back-up Contract Power. SUPPLEMENTARY CONTRACT POWER: The specified Power in kW of Supplementary Power that the Customer contracts with the Company to supply and which the Company agrees to have available for delivery to the Customer. The Supplementary Contract Power shall be established by agreement between the Customer and the Company. Measured Power in excess of the Supplementary Contract Power shall not establish new Supplementary Contract Power. SUPPLEMENTARY POWER: The kW of Supplementary Contract Power supplied by the Company to the Customer. The kW of Supplementary Power for the Billing Period shall be the kW for the 15 minute period of the Customer's greatest use of Supplementary Power during the Billing Period, adjusted for power factor as specified, determined to the nearest kW. For each 15 minute period during the Billing Period, Supplementary Power shall equal the Measured Power but shall not be less than zero nor greater than the Supplementary Contract Power. SUPPLEMENTARY SERVICE: Supplementary service is electric service regularly used by a Customer in addition to that which the Customer generates itself. TOTAL CONTRACT POWER: The sum of the Supplementary Contract Power and the Back-up Contract Power. SCHEDULED MAINTENANCE: Customer shall submit to the Company, in writing, Customer's proposed maintenance schedule and nominated Scheduled Maintenance Power for each month of an 18 month period beginning with the date of the Customer's initial receipt of service under this schedule. Customer shall, prior to September 1st of each subsequent year, submit to the Company, in writing, Customer's proposed maintenance schedule for each month of an 18 month period beginning with January 1st of the following year. The proposed schedules will not be deemed a request for Maintenance Service unless so designated by the Customer and accepted by the Company in writing. Maintenance shall be scheduled for a maximum of 30 days per year. These 30 days may be taken in either one continuous period, or two continuous 15 day periods. Solely at the discretion of the Company and for good cause, the maintenance maximum may be extended. 1. The Customer may present a request for a maintenance outage in writing to the Company no less than 30 days in advance of the date of the scheduled maintenance with the nominated Scheduled Maintenance Power. The Company reserves the right to modify Customer’s requested maintenance schedule. Any modifications by the Company must be made with reason within seven days after that schedule has been received by the Company. (continued) IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Feb. 1, 2022 Jan. 1, 2022 Per O.N. 35277 Jan Noriyuki Secretary I.P.U.C. No. 1 Original Sheet No. 31.6 Submitted Under Case No. PAC-E-12-12 ISSUED: August 13, 2012 EFFECTIVE: January 1, 2013 ELECTRIC SERVICE SCHEDULE NO. 31 – Continued SCHEDULED MAINTENANCE (continued): 2. The Customer may request an adjustment in a scheduled maintenance outage up to 14 days in advance of the expected maintenance. Company approval, or disapproval with reason, for such adjustment shall be given within seven days of such request. 3. The Company may with reason cancel a scheduled maintenance outage at any time with seven days notice prior to the beginning of a scheduled maintenance outage. Subject to the mutual agreement of the Customer and the Company, that scheduled maintenance outage(s) canceled by the Company may be rescheduled. Total Contract Demand, Supplementary Contract Demand, and Back-up Contract Demand The Customer shall contract for Total Contract Demand. This is the sum of the Supplementary Contract Demand and the Back-up Contract Demand. The Customer may elect to increase Total Contract Demand by increasing Supplementary Contract Demand and/or Back-up Contract Demand prospectively at any time, provided there are facilities of adequate capacity, by providing notice to the Company. The Customer may elect to increase Total Contract Demand by increasing Supplementary Contract Demand and/or Back-up Contract Demand retroactively to the most recently completed Billing Period, provided there are facilities of adequate capacity, by providing notice to the Company by the statement due date of the Billing Period. The Supplementary Contract Demand may be reduced for a continuous period of each year provided that at least 12 month's written notice has been provided to the Company or as specified in contract. Only one request to reduce Supplementary Contract Demand may be outstanding for each account. Customer may reduce Back-up Contract Demand by providing written notice to PacifiCorp no less than six months in advance of the effective date of the desired reduction, provided, only one such request may be made in any 12-month period. Within 15 days of receipt of a timely written request by Customer, PacifiCorp shall advise Customer of the terms upon which PacifiCorp would accept a reduction in contract demand. A period of reduction shall commence at the beginning of a billing cycle and terminate at the end of a billing cycle. FORCE MAJEURE: The Company shall not be subject to any liability or damages for inability to provide service, and the Customer shall not be subject to any liability or damage for such inability to receive service, to the extent that such inability shall be due to causes beyond the control of the party as specified in Electric Service Regulation No. 4, Supply and Use of Service, Section 3. Should any of the foregoing occur, the facilities charge shall be applied to only such Back-up Contract Demand as the Company is able to supply and the Customer is able to receive and the minimum Billing Demand applicable to Supplemental Power under this Schedule shall be waived. The Customer will have no liability for full service until such time as the Customer is able to resume such service, except for any term minimum guarantees designed to cover special facilities extension costs, if any. The party claiming Force Majeure under this provision shall make every reasonable attempt to remedy the cause thereof as diligently and expeditiously as possible. (continued) IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Dec. 28, 2012 Jan. 1, 2013 Per O.N. 32704 Jean D. Jewell Secretary I.P.U.C. No. 1 Original Sheet No. 31.7 Submitted Under Case No. PAC-E-12-12 ISSUED: August 13, 2012 EFFECTIVE: January 1, 2013 ELECTRIC SERVICE SCHEDULE NO. 31 – Continued CONTRACT PERIOD: One year or longer. ELECTRIC SERVICE REGULATIONS: Service under this Schedule will be in accordance with the terms of the Electric Service Agreement between the Customer and the Company. The Electric Service Regulations of the Company on file with and approved by the Idaho Public Utilities Commission, including future applicable amendments, will be considered as forming a part of and incorporated in said Agreement. IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Dec. 28, 2012 Jan. 1, 2013 Per O.N. 32704 Jean D. Jewell Secretary Eighth Revision of Sheet No. 34.1 I.P.U.C. No. 1 Canceling Seventh Revision of Sheet No. 34.1 Submitted Under Case No. PAC-E-21-07 ISSUED: November 8, 2021 EFFECTIVE: January 1, 2022 ROCKY MOUNTAIN POWER ELECTRIC SERVICE SCHEDULE NO. 34 STATE OF IDAHO ______________ Pacific Northwest Electric Power Planning and Conservation Act Residential and Farm Kilowatt-Hour Credit ______________ APPLICATION AND AVAILABILITY: This Schedule is applicable and available to qualifying Residential and/or Farm Customers of the Company under the jurisdiction of the Idaho Public Utilities Commission. MONTHLY RATES: The monthly charges for service under each of the Electric Service Schedules shown below shall be reduced by the appropriate kilowatt-hour credit for all qualifying kilowatt-hours of residential and/or farm use. Kilowatt-Hour Credit Adjustments: Irrigation Customers: $0.010133 per kWh Schedule No. 10 Non-Irrigation Customers: $0.010133 per kWh Schedule Nos. 1, 6A, 7A, 23A 35A, 36 (continued) IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Feb. 1, 2022 Jan. 1, 2022 Per O.N. 35277 Jan Noriyuki Secretary First Revision of Sheet No. 34.2 I.P.U.C. No. 1 Canceling Original Sheet No. 34.2 Submitted Under Advice Letter No. 13-01 ISSUED: August 20, 2013 EFFECTIVE: October 1, 2013 ELECTRIC SERVICE SCHEDULE NO. 34 - Continued MONTHLY RATES: (continued) The above kilowatt-hour credit is subject to revision periodically, upon little or no notice, in order that the monthly reduction in revenues may reflect the cost benefits received from the Bonneville Power Administration under the Residential Purchase and Sale Agreement by and between the Bonneville Power Administration, and Rocky Mountain Power (formerly Utah Power & Light Company) dated September 30, 1981. BONNEVILLE POWER ADMINISTRATION BALANCING ACCOUNT: There shall be established upon the books of account of the Company a balancing account. The account shall be used to account for and record all amounts to be passed through to the Company's residential load in accordance with the provisions of the Residential Purchase and Sale Agreement executed by the United States of America, Department of Energy, acting by and through the Bonneville Power Administration and Rocky Mountain Power (formerly Utah Power & Light Company) dated September 30, 1981. Amounts included in this account shall be based upon the cost benefits resulting from transactions with the Bonneville Power Administration and amounts actually passed through as credits to the Company's customers. The account and the kilowatt-hour credit herein shall be adjusted periodically to reflect actual net cost benefits which result from the transactions with Bonneville Power Administration and to reflect the actual credits passed through to the Company's customers. Following such adjustments, any balance in such account, whether positive or negative, shall be carried forward and considered in determining to increase or decrease the rate adjustment under this Electric Service Schedule 34. Under no circumstances shall the Company be required to pass on credits to its customers under this Electric Service Schedule which would exceed the net cost benefits received by the Company after all final adjustments and any disallowance of benefits in connection with any transaction between the Company and Bonneville Power Administration. (continued) IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Sept. 30, 2013 Oct. 1, 2013 Jean D. Jewell Secretary Second Revision of Sheet No. 34.3 I.P.U.C. No. 1 Canceling First Revision of Sheet No. 34.3 Submitted Under Advice Letter No. 13-01 ISSUED: August 20, 2013 EFFECTIVE: October 1, 2013 ELECTRIC SERVICE SCHEDULE NO. 34 - Continued BONNEVILLE POWER ADMINISTRATION BALANCING ACCOUNT: (continued) Should Bonneville Power Administration reduce cost benefit payments to the Company, for any reason including determination that certain customers were not qualified under the Residential Purchase and Sale Agreement to receive the kilowatt- hour credit then and in that event, the balancing account shall be adjusted sufficiently to permit the Company to recover the amount of reduced cost benefit payments. Any recoveries received from customers as provided in the qualifying Electric Service Schedules shown above shall be included in the computation of the net cost benefits. SPECIAL CONDITION: 1. Each person claiming a credit under eligible residential, general service, or irrigation Electric Service Schedules listed on Sheet No. 34.1 with residential or farm electrical load at or above 100,000 kilowatt hours per year, and irrigation/pumping load at or above 250,000 kilowatt hours per year shall file with the Company Bonneville Power Administration’s certificate to be eligible for Residential Exchange Program benefits. A residence is a structure used by one or more persons for daily living and associated activities. A residence is eligible for REP benefits as long as its purpose is to provide shelter on a non-transient (greater than 30 days) basis. A farm consists of one or more parcels of land owned or leased by one or more persons or entities (including partnerships, corporations, and any legal entity capable of owning farm land except the government as defined as Federal, state, and local agencies in the Customer Load Eligibility Guidelines) that is used primarily for agriculture. A qualified irrigation/pumping load may receive benefits up to a maximum 400 horsepower per month (222,000 kilowatt hours per month) of qualified irrigation/pumping load consumed by the specific farm. If the owner of a large farm attempts to subdivide the farm into smaller parcels in order to increase the amount of benefits, the farmer would be subverting the intent of Congress. Such subdivision is not permitted. Bonneville Power Administration’s Customer Load Eligibility Guidelines for the Residential Exchange Program and Certificates shall be found at www.rockymountainpower.net/about/rar/iri/bpac.html# under Regulatory Documents for Idaho. IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Sept. 30, 2013 Oct. 1 2013 Jean D. Jewell Secretary First Revision of Sheet No. 35.1 I.P.U.C. No. 1 Canceling Original Sheet No. 35.1 Submitted Under Case No. PAC-E-21-07 ISSUED: November 8, 2021 EFFECTIVE: January 1, 2022 ROCKY MOUNTAIN POWER ELECTRIC SERVICE SCHEDULE NO. 35 STATE OF IDAHO ______________ Optional Time-of-Day General Service - Distribution Voltage ______________ AVAILABILITY: At any point on the Company's interconnected system where there are facilities of adequate capacity to a limited number of customers each year on a priority basis, and is dependent upon the ability of the Company to obtain adequate metering equipment. The priority is based on the time the application is filed with the Company. Those customers applying first would have the highest priority. APPLICATION: This Schedule is for alternating current, single or three-phase electric service supplied at Company's available voltage, but less than 46,000 volts through a single point of delivery for non-residential, non-irrigation, non-street lighting, and non-area lighting customers, for all service required on the Customer's premises by Customers contracting for not more than 30,000 kW. Service under this Schedule is limited to a maximum power requirement of 30,000 kW. When a Customer's load reaches a level in excess of 30,000 kW, continued service will require special contract arrangements; provided, however, that special contract arrangements will not be required in those cases where electric service is being supplied by Company under this Schedule to operations existing as of the effective date of this Schedule which, because of emergency conditions, or which on sporadic occasions only, may exceed 30,000 kW. This Schedule is not available to new loads in excess of 30,000 kW nor to existing operations whose maximum power requirements, because of increased operations, plant expansion or equipment additions, exceeds 30,000 kW. In this latter case, a maximum power requirement in excess of 30,000 kW shall be deemed to exist when a Customer's maximum power requirement exceeds 30,000 kW in at least three (3) months of any continuous period of six (6) successive months. (Continued) IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Feb. 1, 2022 Jan. 1, 2022 Per O.N. 35277 Jan Noriyuki Secretary Eleventh Revision of Sheet No. 35.2 I.P.U.C. No. 1 Canceling Tenth Revision of Sheet No. 35.2 Submitted Under Advice No. 23-01 ISSUED: January 18, 2023 EFFECTIVE: February 17, 2023 ELECTRIC SERVICE SCHEDULE NO. 35 - Continued MONTHLY BILL: Customer Service Charge: Secondary voltage delivery (Less than 2300 volts) $ 69.00 per Customer Primary voltage delivery (2300 volts or higher) $170.00 per Customer Power Charge: On-Peak kW $ 16.95 per kW Energy Charge: Per kWh for all kWh 5.3792¢ TIME PERIODS: On-Peak 7:00 a.m. to 10:00 p.m., Monday thru Friday, except holidays. Off-Peak All other times. Holidays include only New Year's Day, President's Day, Memorial Day, Independence Day, Labor Day, Thanksgiving Day, and Christmas Day. When a holiday falls on a Saturday or Sunday, the Friday before the holiday (if the holiday falls on a Saturday) or the Monday following the holiday (if the holiday falls on a Sunday) will be considered a holiday and consequently Off-Peak. Power Factor: This rate is based on the Customer maintaining at all times a Power factor of 85% lagging, or higher, as determined by measurement. If the average Power factor is found to be less than 85% lagging the Power as recorded by the Company's meter will be increased by 3/4 of 1% for every 1% that the Power factor is less than 85%. Voltage Discount: Where Customer takes service from Company's available lines of 2,300 volts or higher and provides and maintains all transformers and other necessary equipment, the voltage discount based on highest measured Power during the billing cycle will be: $0.84 per kW Minimum: Customer Service Charge plus applicable Demand and Energy charges. (Continued) IDAHO PUBLIC UTILITIES COMMISSIONApproved EffectiveFeb. 7, 2023 Feb. 17, 2023 Jan Noriyuki Secretary Fifth Revision of Sheet No. 35.3 I.P.U.C. No. 1 Canceling Fourth Revision of Sheet No. 35.3 Submitted Under Case No. PAC-E-21-07 ISSUED: November 8, 2021 EFFECTIVE: January 1, 2022 ELECTRIC SERVICE SCHEDULE NO. 35 - Continued POWER: The On-Peak kW shall be the kW as shown by or computed from the readings of Company's Power meter for the 15-minute period of Customer's greatest use during the On-Peak periods during the month as previously defined, adjusted for Power Factor as specified, determined to the nearest kW. SEASONAL SERVICE: Service for annually recurring periods of seasonal use where service is normally discontinued or curtailed during a part of the year may be contracted for under this schedule under either of the following conditions: (a) Customer may contract for service under this schedule on a year-round basis paying for all service, including transformer losses where applicable, under the rates set forth under "Monthly Bill" above including the monthly minimum bill during those months service is curtailed or is not utilized in the Customer's operation. (b) Customer may contract for seasonal service under this schedule with a net minimum seasonal payment as follows: $ 828.00 plus Power and Energy Charges for Customer taking service at less than 2300 volts, and $2,040.00 plus Power and Energy Charges for Customer taking service at 2300 volts or higher. CONTRACT PERIOD: One year or longer. ELECTRIC SERVICE REGULATIONS: Service under this Schedule will be in accordance with the terms of the Electric Service Agreement between the Customer and the Company. The Electric Service Regulations of the Company on file with and approved by the Idaho Public Utilities Commission, including future applicable amendments, will be considered as forming a part of and incorporated in said Agreement. IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Feb. 1, 2022 Jan. 1, 2022 Per O.N. 35277 Jan Noriyuki Secretary First Revision of Sheet No. 35A.1 I.P.U.C. No. 1 Canceling Original Sheet No. 35A.1 Submitted Under Case Letter No. PAC-E-21-07 ISSUED: November 8, 2021 EFFECTIVE: January 1, 2022 ROCKY MOUNTAIN POWER ELECTRIC SERVICE SCHEDULE NO. 35A STATE OF IDAHO ______________ Optional Time-of-Day General Service - Distribution Voltage (Farm) ______________ AVAILABILITY: This Electric Service Schedule is available at any point on the Company's interconnected system where there are facilities of adequate capacity to a limited number of customers each year on a priority basis. Such availability is dependent upon the ability of the Company to obtain adequate metering equipment. The priority is based on the time the application is filed with the Company. Those customers applying first would have the highest priority. This schedule is for service to any customer who qualifies as "Farm Load" under both (1) the Pacific Northwest Electric Power Planning and Conservation Act, P.L. 96-501 as the same may be amended, and (2) a Residential Purchase and Sale Agreement, under Section 5(c) of such Act and in effect between the Company and the Bonneville Power Administration. APPLICATION: This Schedule is for alternating current, single or three-phase electric service supplied at Company's available voltage, but less than 46,000 volts through a single point of delivery for non-residential, non-irrigation, non-street lighting, and non-area lighting customers, for all service required on the Customer's premises by Customers contracting for not more than 30,000 kW. Service under this Schedule is limited to a maximum power requirement of 30,000 kW. When a Customer's load reaches a level in excess of 30,000 kW, continued service will require special contract arrangements; provided, however, that special contract arrangements will not be required in those cases where electric service is being supplied by Company under this Schedule to operations existing as of the effective date of this Schedule which, because of emergency conditions, or which on sporadic occasions only, may exceed 30,000 kW. This Schedule is not available to new loads in excess of 30,000 kW nor to existing operations whose maximum power requirements, because of increased operations, plant expansion or equipment additions, exceeds 30,000 kW. In this latter case, a maximum power requirement in excess of 30,000 kW shall be deemed to exist when a Customer's maximum power requirement exceeds 30,000 kW in at least three (3) months of any continuous period of six (6) successive months. (Continued) IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Feb. 1, 2022 Jan. 1, 2022 Per O.N. 35277 Jan Noriyuki Secretary Eleventh Revision of Sheet No. 35A.2 I.P.U.C. No. 1 Canceling Tenth Revision of Sheet No. 35A.2 Submitted Under Advice No. 23-01 ISSUED: January 18, 2023 EFFECTIVE: February 17, 2023 ELECTRIC SERVICE SCHEDULE NO. 35A - Continued MONTHLY BILL: Customer Service Charge: Secondary voltage delivery (Less than 2300 volts) $ 69.00 per Customer Primary voltage delivery (2300 volts or higher) $170.00 per Customer Power Charge: On-Peak kW $ 16.95 per kW Energy Charge: Per kWh for all kWh 5.3792¢ TIME PERIODS: On-Peak 7:00 a.m. to 10:00 p.m., Monday thru Friday, except holidays. Off-Peak All other times. Holidays include only New Year's Day, President's Day, Memorial Day, Independence Day, Labor Day, Thanksgiving Day, and Christmas Day. When a holiday falls on a Saturday or Sunday, the Friday before the holiday (if the holiday falls on a Saturday) or the Monday following the holiday (if the holiday falls on a Sunday) will be considered a holiday and consequently Off-Peak. Power Factor: This rate is based on the Customer maintaining at all times a Power factor of 85% lagging, or higher, as determined by measurement. If the average Power factor is found to be less than 85% lagging the Power as recorded by the Company's meter will be increased by 3/4 of 1% for every 1% that the Power factor is less than 85%. Voltage Discount: Where Customer takes service from Company's available lines of 2,300 volts or higher and provides and maintains all transformers and other necessary equipment, the voltage discount based on highest measured Power during the billing cycle will be: $0.84 per kW Minimum: Customer Service Charge plus applicable Demand and Energy charges. (Continued) IDAHO PUBLIC UTILITIES COMMISSIONApproved EffectiveFeb. 7, 2023 Feb. 17, 2023 Jan Noriyuki Secretary Fifth Revision of Sheet No. 35A.3 I.P.U.C. No. 1 Canceling Fourth Revision of Sheet No. 35A.3 Submitted Under Case No. PAC-E-21-07 ISSUED: November 8, 2021 EFFECTIVE: January 1, 2022 ELECTRIC SERVICE SCHEDULE NO. 35A - Continued MONTHLY BILLING REDUCTION: Rates in this schedule shall be reduced by the monthly kilowatt-hour credit adjustment set forth under "Monthly Rates" in the currently effective Electric Service Schedule No. 34. POWER: The On-Peak kW shall be the kW as shown by or computed from the readings of Company's Power meter for the 15-minute period of Customer's greatest use during the On-Peak periods during the month as previously defined, adjusted for Power Factor as specified, determined to the nearest kW. SEASONAL SERVICE: Service for annually recurring periods of seasonal use where service is normally discontinued or curtailed during a part of the year may be contracted for under this schedule under either of the following conditions: (a) Customer may contract for service under this schedule on a year-round basis paying for all service, including transformer losses where applicable, under the rates set forth under "Monthly Bill" above including the monthly minimum bill during those months service is curtailed or is not utilized in the Customer's operation. (b) Customer may contract for seasonal service under this schedule with a net minimum seasonal payment as follows: $ 828.00 plus Power and Energy Charges for Customer taking service at less than 2300 volts, and $2,040.00 plus Power and Energy Charges for Customer taking service at 2300 volts or higher. CONTRACT PERIOD: One year or longer. SPECIAL CONDITION: Farm use means all usual farm electrical loads for raising of crops, livestock or pasturage and includes primary processing necessary for safe and efficient storage or shipment. Contiguous parcels of land under single-ownership or leasehold shall be considered to be one Farm and noncontiguous parcels of land under single-ownership or leasehold shall be considered as one Farm unit when operated as a single Farm, unless demonstrated otherwise by the owner or lessee of the parcels. (Continued) IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Feb. 1, 2022 Jan. 1, 2022 Per O.N. 35277 Jan Noriyuki Secretary IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Aug. 28, 2006 Sept. 15, 2006 Jean D. Jewell Secretary I.P.U.C. No. 1 Original Sheet No. 35A.4 ELECTRIC SERVICE SCHEDULE NO. 35A -Continued SPECIAL CONDITION: (continued) A number of factors shall determine whether contiguous or noncontiguous parcels constitute one or more Farms. These factors shall include, but are not limited to: --size --use --ownership --control --operating practices --distance between parcels --custom in the trade --billing treatment by the utility Customers who feel they meet the definitions of a Farm will have to make application with the Company for review. If Customer application is denied by the Company, the customer may appeal the decision to the Idaho Public Utilities Commission. ELECTRIC SERVICE REGULATIONS: Service under this Schedule will be in accordance with the terms of the Electric Service Agreement between the Customer and the Company. The Electric Service Regulations of the Company on file with and approved by the Idaho Public Utilities Commission, including future applicable amendments, will be considered as forming a part of and incorporated in said Agreement. Submitted Under Advice Letter No. 06-06 ISSUED: August 14, 2006 EFFECTIVE: September 15, 2006 IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Aug. 28, 2006 Sept. 15, 2006 Jean D. Jewell Secretary I.P.U.C. No. 1 ROCKY MOUNTAIN POWER ELECTRIC SERVICE SCHEDULE NO. 36 STATE OF IDAHO Optional Time of Day -Residential Service Original Sheet No. 36.1 AVAILABILITY: At any point on the Company's interconnected system where there are facilities of adequate capacity. APPLICATION: This Schedule is for alternating current electric service supplied at approximately 120 or 240 volts through one kilowatt-hour meter at a single point of delivery for all service required on the premises for Residential purposes. When conditions are such that service is supplied through one meter to more than one dwelling or apartment unit, the charge for such service will be computed by multiplying the number of kWh in each block and the minimum charges by the maximum number of dwelling or apartment units that may be served. When a portion of a dwelling is used regularly for business, professional or other gainful purposes, the premises will be classified as nonresidential and the appropriate schedule applied. 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. (Continued) Submitted Under Advice Letter No. 06-06 ISSUED: August 14, 2006 EFFECTIVE: September 15, 2006 Fourteenth Revision of Sheet No. 36.2 I.P.U.C. No. 1 Canceling Thirteenth Revision of Sheet No. 36.2 Submitted Under Case No. PAC-E-22-15 ISSUED: June 9, 2023 EFFECTIVE: June 1, 2023 ELECTRIC SERVICE SCHEDULE NO. 36 - Continued MONTHLY BILL: 6/1/2023 6/1/2024 6/1/2025 6/1/2026 6/1/2027 to to to to 5/31/2024 5/31/2025 5/31/2026 5/31/2027 Customer Service Charge Energy Charge (¢/kWh) Seasonal Service Charge On Peak: Before June 1, 2025 - May through October inclusive 8:00 a.m. to 11:00 p.m., Monday through Friday, except holidays. November through April inclusive 7:00 a.m. to 10:00 p.m., Monday through Friday, except holidays. Holidays include only: New Year's Day, President's Day, Memorial Day, Independence Day, Labor Day, Thanksgiving Day, and Christmas Day. On and after June 1, 2025 - June through October inclusive 3:00 p.m. to 11:00 p.m., all days. November through May inclusive 6:00 a.m. to 9:00 a.m. and 6:00 p.m. to 11:00 p.m., all days. Off Peak: All other kWh usage. SEASONAL SERVICE: When seasonable service is supplied under this Schedule, the minimum seasonal charge will be applied plus energy charges. CONTRACT PERIOD: One year or longer. MONTHLY BILLING REDUCTION: Rates in this schedule shall be reduced by the monthly kilowatt-hour credit adjustment set forth under “Monthly Rates” in the currently effective Electric Service Schedule No. 34. (Continued) IDAHO PUBLIC UTILITIES COMMISSIONApproved EffectiveJuly 6, 2023 June 1, 2023 Per ON 35843 Jan Noriyuki Secretary IDAHO PUBLIC UTILITIES COMMISSION Approved Effective July 24, 2006 March 1, 2007 Jean D. Jewell Secretary I.P.U.C. No. 1 First Revised Sheet No. 36.3 Canceling Original Sheet No. 36.3 ELECTRIC SERVICE SCHEDULE NO. 36 -Continued ELECTRIC SERVICE REGULATIONS: Service under this Schedule will be in accordance with the terms of the electric Service Agreement between the Customer and the Company. The Electric Service Regulations of the Company on file with and approved by the Idaho Public Utilities Commission, including future applicable amendments, will be considered as forming a part of and incorporated in said Agreement. Submitted Under Advice No. 06-05 ISSUED: July 5, 2006 EFFECTIVE: March 1, 2007 I.P.U.C. No. 1 Original Sheet No. 38.1 Submitted Under Case No. PAC-E-16-01 ISSUED: January 13, 2016 EFFECTIVE: April 15, 2016 ROCKY MOUNTAIN POWER ELECTRIC SERVICE SCHEDULE NO. 38 STATE OF IDAHO ______________ Qualifying Facility Avoided Cost Procedures ______________ PREFACE: 1. The process outlined in this Schedule is typically applicable to projects already under development. 2. All submissions, responses and notices required in this Schedule must be done in electronic or hard copy format. Requests and information may be submitted to the Company at QFrequests@pacificorp.com . 3. The QF pricing queue referenced in this Schedule is independent of and unrelated to the interconnection and transmission services queue maintained and administered by PacifiCorp Transmission Services pursuant to PacifiCorp Transmission Service’s FERC approved Open Access Transmission Tariff (OATT), as posted on its Open Access Same-Time Information System (OASIS). The generation interconnection process is a critical and lengthy process that typically must be well underway before a power purchase agreement should be requested. QF Developers are strongly encouraged to gain a clear understanding of the transmission interconnection process and associated costs and timelines before requesting indicative pricing or a power purchase agreement under this schedule. 4. The Company must use its reasonable commercial efforts to meet all Company deadlines specified herein, and shall attempt to make up any Company delays in meeting subsequent Company deadlines. QF Developer deadlines will be extended to reflect Company delays beyond Company deadlines specified herein. Under extenuating circumstances, the Company or a QF Developer may request an extension of any deadlines from the Commission. IDAHO PUBLIC UTILITIES COMMISSION Approved Effective March 3, 2016 April 15, 2016 Per O.N. 33474 Jean D. Jewell Secretary I.P.U.C. No. 1 Original Sheet No. 38.2 Submitted Under Case No. PAC-E-16-01 ISSUED: January 13, 2016 EFFECTIVE: April 15, 2016 ELECTRIC SERVICE SCHEDULE NO. 38 - Continued PREFACE: (continued) 5. Subject to the specific tariff provisions provided below, the general timelines and deadlines for actions or responses for Developers and the Company in this tariff are summarized here for convenience, along with references to the relevant tariff provisions: a) Company must provide Developer illustrative, pro forma contract within seven (7) days of request [Section I.B.1]; b) Developer may request indicative pricing at any time by submitting required information [Section I.B.2]; c) Company must notify Developer whether request for indicative pricing is complete within seven (7) days of submission [Section I.B.3]; d) Company must provide indicative pricing within thirty (30) days of notice of completeness [Section I.B.4]; e) Developer must request draft power purchase agreement and submit required information within sixty (60) days of receipt of indicative pricing [Section I.B.5]; f) Company must notify Developer whether request for power purchase agreement and required information is complete within seven (7) days of submission to the Company [Section I.B.6]; g) Company must provide Developer with draft power purchase agreement within thirty (30) days of notice of completeness [Section I.B.6]; h) Developer must provide Company with initial comments on and proposed edits to draft power purchase agreement within thirty (30) days of receipt [Section I.B.7]; i) Company must respond to Developer’s initial comments and edits within thirty (30) days of receipt, and commence negotiations over areas of disagreement [Section I.B.8]; j) Indicative prices must be updated unless a PPA is executed within six (6) months after indicative pricing was provided by the Company [Section I.B.9]; k) Company must complete all internal reviews and approvals within twenty-one (21) days after agreement is reached on a proposed final version of a power purchase agreement [Section I.B.8]; l) PPA must be executed within five (5) months after Developer’s receipt of draft power purchase agreement [Section I.B.10]; m) Company must submit power purchase agreement to Commission for approval within seven (7) days of execution [Section I.B.8]; and n) Company must submit Transmission Service Request within seven (7) days after execution of purchase power agreement [Section I.B.8]. IDAHO PUBLIC UTILITIES COMMISSION Approved Effective March 3, 2016 April 15, 2016 Per O.N. 33474 Jean D. Jewell Secretary I.P.U.C. No. 1 Original Sheet No. 38.3 Submitted Under Case No. PAC-E-16-01 ISSUED: January 13, 2016 EFFECTIVE: April 15, 2016 ELECTRIC SERVICE SCHEDULE NO. 38 - Continued PREFACE: (continued) 6. QF Developers should pay special attention to the fact that, as specified in the tariff sections that follow, a QF project will typically be removed from the QF pricing queue, and any indicative or proposed prices or agreements will no longer be valid, upon occurrence of any of the following events: a) Failure of the QF Developer to submit to the Company a request for a power purchase agreement within sixty (60) days of its receipt of indicative pricing, as specified in Section I.B.5; b) Failure of the QF Developer to submit written comments and proposals within thirty (30) days of its receipt of a proposed power purchase agreement, as specified in Section I.B.7; c) Failure of the parties to execute a power purchase agreement within five (5) months after a draft power purchase agreement was provided by the Company to the QF Developer, as specified in Section I.B.10.e.; or d) A material change in the point of interconnection, a change in design capacity of more than 10%, a change in generation technology, or a change of more than three (3) months in the online date, as specified in Sections I.B.10.a.-d. 7. When a QF project is removed from the QF pricing queue, the developer may request new indicative pricing and a new agreement by timely following all of the steps outlined below, in which case it will be placed in the QF pricing queue as a new project. AVAILABILITY: To owners of Qualifying Facilities (QFs) in all territory served by the Company in the state of Idaho. APPLICATION: To owners of existing or proposed wind or solar QFs with a design capacity greater than 100 kW, or Seasonal or Non-Seasonal Hydro projects and all other projects greater than 10 a MW who desire to make sales to the Company and to QFs who are not able to obtain pricing under the standard published rates. Such owners will be required to enter into written power purchase and interconnection agreements with the Company pursuant to the procedures set forth below. Additional or different requirements may apply to Idaho QFs seeking to make sales to third-parties, or out-of-system QFs seeking to wheel power to Idaho for sale to the Company. IDAHO PUBLIC UTILITIES COMMISSION Approved Effective March 3, 2016 April 15, 2016 Per O.N. 33474 Jean D. Jewell Secretary I.P.U.C. No. 1 Original Sheet No. 38.4 Submitted Under Case No. PAC-E-16-01 ISSUED: January 13, 2016 EFFECTIVE: April 15, 2016 ELECTRIC SERVICE SCHEDULE NO. 38 – Continued I. Process For Negotiating Power Purchase Agreements A. Communications Unless otherwise directed by the Company, all communications to the Company regarding QF power purchase agreements should be directed in writing as follows: Rocky Mountain Power Manager - QF Contracts 825 NE Multnomah St, Suite 600 Portland, Oregon 97232 QFrequests@pacificorp.com The Company will respond to all such communications in a timely manner. If the Company is unable to respond on the basis of incomplete or missing information from the QF owner, the Company shall indicate what additional information is required. Thereafter, the Company will respond in a timely manner following receipt of all required information. B. Procedures 1. Request for Pro Forma Contract. The Company shall provide a QF Developer with a pro forma power purchase agreement within seven (7) days of its receipt of a request for the same. The pro forma document provided (i) does not constitute an offer to enter into an agreement, (ii) may include general proposed terms and conditions, and (iii) will not include pricing or project specific information. Anyone who desires to enter into a power purchase agreement with the Company must proceed in accordance with this Schedule to request indicative pricing under Section I.B.2, to request a proposed power purchase agreement under Section I.B.5, and to negotiate and execute a power purchase agreement that is executed by the Company and approved by the Commission. 2. Request for Indicative Pricing. To obtain indicative pricing with respect to a proposed project, a QF Developer must provide to the Company the following general project information: a) A general description of the QF project and the QF Developer, including email address and other contact information; b) generation technology and other related technology applicable to the site and for solar projects specify fixed ground mount or solar tracking; IDAHO PUBLIC UTILITIES COMMISSION Approved Effective March 3, 2016 April 15, 2016 Per O.N. 33474 Jean D. Jewell Secretary I.P.U.C. No. 1 Original Sheet No. 38.5 Submitted Under Case No. PAC-E-16-01 ISSUED: January 13, 2016 EFFECTIVE: April 15, 2016 ELECTRIC SERVICE SCHEDULE NO. 38 – Continued I. B. Procedures (continued) c) design capacity (MW), station service requirements, and net amount of power to be delivered to the Company's electric system; d) quantity and timing of monthly power deliveries (including project’s ability to respond to dispatch orders from the Company) and an hourly generation profile (12X24 profile minimum, 8760 preferred) in Excel or other spreadsheet format with all formulae intact, and the expected generation degradation per year and whether the degradation rate is calculated against the first year or against the prior year, or a forecast of annual generation for each contract year over the life of the requested contract term; e) proposed site location and electrical interconnection point; f) proposed on-line date and outstanding permitting requirements; g) demonstration of ability to obtain QF status (FERC Form 556); h) fuel type(s) and source(s); i) plans for fuel and transportation agreements (Motive force plans); j) proposed length of contract term; k) status of transmission interconnection arrangements including interconnection queue number; and l) other information promptly and reasonably requested by the Company. 3. Notice of Completeness and Queue Position. Within seven (7) days of its receipt of a request for indicative pricing and supporting materials as specified above, the Company shall confirm its receipt of the same and notify the QF Developer whether the submission is substantially complete or if additional information is required. The Company shall not be obligated to provide indicative pricing until all information described in Paragraph I.B.2 has been received from the QF Developer. Indicative pricing will be determined in light of other QF projects in the QF pricing queue ahead of the project, and using inputs and procedures as approved by the Commission. A QF will be added to the QF pricing queue as of the date the Company has confirmed receipt of all project information required in Paragraph I.B.2 and will retain its priority position in the QF pricing queue for purposes of subsequent requests for indicative pricing unless and until removed from the QF pricing queue as provided herein. The Company will notify the QF Developer of the date its project was added to the QF pricing queue. Once a QF Project has been added to the QF pricing queue, in the event additional clarifying information is reasonably required by the Company in order to calculate indicative prices, the deadlines in Section I.B.4 shall be extended IDAHO PUBLIC UTILITIES COMMISSION Approved Effective March 3, 2016 April 15, 2016 Per O.N. 33474 Jean D. Jewell Secretary I.P.U.C. No. 1 Original Sheet No. 38.6 Submitted Under Case No. PAC-E-16-01 ISSUED: January 13, 2016 EFFECTIVE: April 15, 2016 ELECTRIC SERVICE SCHEDULE NO. 38 – Continued on a day for day basis until the requested clarifying information has been provided. I. B. Procedures (continued) 4. Indicative Pricing. Within thirty (30) days following the date a QF project was added to the QF pricing queue under Section I.B.3, the Company shall provide the QF Developer with indicative pricing, which may include other indicative terms and conditions, tailored to the individual characteristics of the proposed project. An indicative pricing proposal provided by the Company may be used by the QF Developer to make determinations regarding project planning, financing and feasibility. However, such prices are indicative only and may be subject to change by the Company as specified herein or by the Commission. Prices and other terms and conditions are only final and binding to the extent contained in a power purchase agreement executed by both parties and approved by the Commission. The Commission may approve, reject or conditionally approve a power purchase agreement and may at any time make changes to this Schedule, QF pricing methods and inputs, or terms and conditions applicable to QF pricing and power purchase agreements. 5. Request for Draft Power Purchase Agreement. If a QF Developer desires to precede forward with the project it must, within sixty (60) days of its receipt of indicative pricing, request that the Company prepare and submit for the Developer’s review a proposed power purchase agreement. Absent timely submittal of such request, the project will be removed from the QF pricing queue and the indicative prices will no longer be valid. In connection with its request for a power purchase agreement, the Developer must provide the Company with the following additional project information: IDAHO PUBLIC UTILITIES COMMISSION Approved Effective March 3, 2016 April 15, 2016 Per O.N. 33474 Jean D. Jewell Secretary I.P.U.C. No. 1 Original Sheet No. 38.7 Submitted Under Case No. PAC-E-16-01 ISSUED: January 13, 2016 EFFECTIVE: April 15, 2016 ELECTRIC SERVICE SCHEDULE NO. 38 - Continued I. B. Procedures (continued) a) any available updates to the information specified in Paragraph I.B.2; b) evidence of adequate control of proposed site; c) identification of and timelines for obtaining any necessary governmental permits, approvals or authorizations; d) assurance of fuel supply or motive force; e) anticipated timelines for completion of key project milestones; f) evidence that any necessary interconnection studies are underway and that the necessary interconnection arrangements can timely be completed in accordance with Part II sufficient for the project to reach energization by the proposed on-line date; g) information describing the developer/owner of the proposed project, including name, address, and ownership organization chart; and h) other information promptly and reasonably requested by the Company. 6. Notice of Completeness and Draft PPA. Within seven (7) days of its receipt of a request for a power purchase agreement and the information specified in Section I.B.5, the Company shall confirm its receipt of the same and notify the Developer whether any additional information is needed. The Company shall provide the Developer with a proposed power purchase agreement within thirty (30) days following the date of the Company’s notice that the information required in Paragraph I.B.5 has been received and is substantially complete. The proposed power purchase agreement shall contain a comprehensive set of proposed terms and conditions, including specific pricing based on the indicative pricing provided, as adjusted if necessary in light of specifics of the project. The proposed power purchase agreement will also specify project specific data and exhibits that must be provided by the QF Developer prior to final approval or execution of the PPA. The proposal submitted by the Company shall serve as the basis for subsequent negotiations. 7. Developer’s Initial Comments and Edits. Within thirty (30) days of receiving a proposed power purchase agreement, the QF Developer shall prepare and deliver to the Company an initial set of written comments and proposals, failing which the Project will be removed from the QF pricing queue and the proposed agreement and prices will no longer be valid. 8. Company’s Response and Responsibilities. If the QF Developer’s proposals are not acceptable, the Company shall commence negotiations on all outstanding areas of disagreement, and: IDAHO PUBLIC UTILITIES COMMISSION Approved Effective March 3, 2016 April 15, 2016 Per O.N. 33474 Jean D. Jewell Secretary I.P.U.C. No. 1 Original Sheet No. 38.8 Submitted Under Case No. PAC-E-16-01 ISSUED: January 13, 2016 EFFECTIVE: April 15, 2016 ELECTRIC SERVICE SCHEDULE NO. 38 - Continued I. B. Procedures (continued) a) shall respond to the developer’s initial comments and proposals within thirty (30) days, and thereafter respond timely to subsequent comments and proposals; b) will not unreasonably delay negotiations and will respond in good faith to any additions, deletions or modifications to the draft power purchase agreement that are proposed by the QF Developer; c) may request to visit the site of the proposed project if such a visit has not previously occurred; d) may request additional information from the Developer if reasonably necessary to finalize the terms of the power purchase agreement and satisfy the Company's due diligence with respect to the Project; and e) shall submit to PacifiCorp Transmission Services a request for network transmission service relating to the project within seven (7) days after execution of a power purchase agreement, or otherwise as early as practicable based on the applicable PacifiCorp Transmission Services tariff; f) shall complete credit, legal, upper management and any other required internal reviews of proposed terms and conditions within twenty-one (21) days after agreement was reached on a proposed final version of a power purchase agreement; and g) shall submit a fully executed power purchase agreement to the Commission for approval within seven (7) days of execution. 9. Required Pricing Update. The prices in the proposed power purchase agreement provided by the Company under Section I.B.6 shall be recalculated by the Company using the most recent available pricing inputs and methods approved by the Commission, but without a change in the QF project’s pricing queue priority, if the QF Developer and the Company have not executed a power purchase agreement within six months after indicative pricing was provided by the Company under Section I.B.4, except to the extent delays are caused by Company actions or inactions, which may include delays in obtaining legal, credit or upper management approval by the Company. 10. Removal from QF Pricing Queue. In addition to the circumstances described in I.B.5 and I.B.7, at any time during the process outlined in I.B.3 through I.B.9, the Company shall remove a QF project from the QF pricing queue, and any associated indicative prices, proposed prices or proposed agreement previously provided will no longer be valid, if any of the following occurs with respect to a QF project: IDAHO PUBLIC UTILITIES COMMISSION Approved Effective March 3, 2016 April 15, 2016 Per O.N. 33474 Jean D. Jewell Secretary I.P.U.C. No. 1 Original Sheet No. 38.9 Submitted Under Case No. PAC-E-16-01 ISSUED: January 13, 2016 EFFECTIVE: April 15, 2016 ELECTRIC SERVICE SCHEDULE NO. 38 - Continued I. B. Procedures (continued) a) A material change in the point of interconnection; b) A change in design capacity of 10% or more of the original specified design capacity; c) A change in generation technology (i.e. solar, wind, thermal), including a change between fixed tilt and tracking solar projects. Changes in the quantity and timing of monthly power deliveries will not cause removal from the QF pricing queue so long as the basic generation technology and design capacity have not changed; d) A change in the online date specified in the information provided under Section I.B.2.f of more than three months earlier or later; or e) A PPA has not been executed by both parties within five (5) months after the draft PPA was provided by the Company to the Developer, except to the extent delays are caused by Company actions or inactions. 11. Standard PPA Terms. Absent Commission approval to the contrary for good cause shown, a power purchase agreement executed under this Schedule shall include the following terms and conditions, among others: a) The scheduled commercial operation date must not be greater than thirty (30) months after the execution date of the power purchase agreement; b) The QF Developer must sign a System Impact Study Agreement with PacifiCorp Transmission (refer to Section 42.2 or Section 51.4 of PacifiCorp’s OATT) within 120 days of the date a Commission Order approving the agreement has become final and non-appealable; and c) The QF Developer must provide 100% of the project development security within 30 days of the date a Commission Order approving the PPA has become final and non-appealable. II. Process for Negotiating Interconnection Agreements In addition to negotiating a power purchase agreement, QFs intending to make sales to the Company are also required to enter into an interconnection agreement that governs the physical interconnection of the project to the Company's transmission or distribution system. The Company's obligation to make purchases from a QF is conditioned upon all necessary interconnection arrangements being consummated. It is recommended that the owner initiate its request for interconnection as early in the planning process as possible, to ensure that necessary interconnection arrangements proceed in a timely manner on a parallel track with negotiation of the power purchase agreement. Interconnection agreements (both transmission and distribution level voltages) are handled by the Company's power delivery function, PacifiCorp Transmission Services. IDAHO PUBLIC UTILITIES COMMISSION Approved Effective March 3, 2016 April 15, 2016 Per O.N. 33474 Jean D. Jewell Secretary I.P.U.C. No. 1 Original Sheet No. 38.10 Submitted Under Case No. PAC-E-16-01 ISSUED: January 13, 2016 EFFECTIVE: April 15, 2016 ELECTRIC SERVICE SCHEDULE NO. 38 - Continued II. Process for Negotiating Interconnection Agreements (continued) A. Communications Initial communications regarding interconnection agreements should be directed to the Company in writing as follows: PacifiCorp Transmission Services Interconnection Requests 825 NE Multnomah St, Suite 1600 Portland, Oregon 97232 QFrequests@pacificorp.com B. Procedures Generally, the interconnection process involves (1) initiating a request for interconnection, (2) completion of studies to determine the system impacts associated with the interconnection and the design, cost, and schedules for constructing any necessary interconnection facilities, (3) execution of an interconnection agreement. The QF project owner is responsible for all interconnection costs assessed by the Company on a nondiscriminatory basis. For interconnections greater than twenty (20) megawatts, the Company will process the interconnection application through PacifiCorp Transmission Services generally following the procedures for studying the generation interconnection described in the Company’s Open Access Transmission Tariff, PacifiCorp FERC Electric Tariff, Fifth Revised Volume No. 11 Pro Forma Open Access Transmission Tariff (OATT), as the same may be changed or updated, on file with the Federal Energy Regulatory Commission (FERC). A copy of the OATT is available on-line at http//www.oasis.pacificorp.com. The Company’s interconnection forms and agreements, are provided electronically at the following address: http://www.pacificorp.com/tran/ts/gip/qf.html IDAHO PUBLIC UTILITIES COMMISSION Approved Effective March 3, 2016 April 15, 2016 Per O.N. 33474 Jean D. Jewell Secretary I.P.U.C. No. 1 Original Sheet No. 38.11 Submitted Under Case No. PAC-E-16-01 ISSUED: January 13, 2016 EFFECTIVE: April 15, 2016 ELECTRIC SERVICE SCHEDULE NO. 38 - Continued III. Process for Filing a Complaint with the Commission on Contract Terms The Commission has both informal and formal dispute resolution processes which can be reviewed on the Commission website at the following address: http://www.puc.idaho.gov/forms/consumerassistance These processes are available for any matter as to which the Commission has jurisdiction, which may include (i) QF PPA contracts, (ii) small QF interconnection agreements (less than 20 MW), and (iii) large QF interconnection agreements (more than 20 MW), so long as all of the QF output is sold exclusively to the Company. To the extent any portion of the QF output is sold to anyone other than the Company, a QF generation interconnection may be subject to FERC jurisdiction. Nothing in this Schedule will affect the jurisdiction of the Commission or FERC, and all parties will retain any and all rights they may have under any applicable state or federal statutes or regulations. IDAHO PUBLIC UTILITIES COMMISSION Approved Effective March 3, 2016 April 15, 2016 Per O.N. 33474 Jean D. Jewell Secretary IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Feb. 6, 2020 Jan. 1, 2020 Per O.N. 34545 Diane M. Hanian Secretary --.. I.P.U.C. No. 1 Fifth Revision of Sheet No. 70.1 Canceling Fourth Revision of Sheet No. 70.1 ROCKY MOUNTAIN POWER ELECTRIC SERVICE SCHEDULE NO. 70 STATE OF IDAHO Renewable Energy Rider -Optional AVAILABILITY: In all territory served by the Company in the state of Idaho. APPLICATION: To Customers receiving service under the Company's Electric Service Schedules. ADMINISTRATION: Funds received from Customers under this Schedule will cover program costs and match Renewable Energy purchases to Block purchases. Funds not spent after covering program costs and matching Renewable Energy purchases may be used to fund Qualifying Initiatives as defined below. BLOCK: I Block equals 200 kWh of Renewable Energy. CHARGE PER BLOCK: $1.95 per month MONTHLY BILL: The Monthly Bill shall be the number of Blocks the Customer has agreed to purchase multiplied by the Charge per Block. The Monthly Bill is in addition to all other charges contained in Customer's applicable tariff schedule. This rider 's Monthly Bill shall be applied to the Customer's billing regardless of actual energy consumption. RENEWABLE ENERGY: Renewable Energy includes bundled power or Renewable Energy Credits (RECs) derived from the following fuels: • wind; • solar • geothermal energy; • certified low impact hydroelectric; • hydrogen derived from photovoltaic electrolysis or a non-hydrocarbon derivation process; • pipeline or irrigation canal hydroelectric systems; • wave or tidal action; and Submitted Under Case No. PAC-E-19-17 ISSUED: October 24, 2019 (Continued) EFFECTIVE: January 1, 2020 IDAHO PUBLIC UTILITIES COMMISSION Approved Effective April 23, 2007 May 1, 2007 Jean D. Jewell Secretary I.P.U.C. No. 1 First Revision of Sheet No. 70.2 Canceling Original Sheet No. 70.2 ELECTRIC SERVICE SCHEDULE NO. 70 -CONTINUED RENEWABLE ENERGY: (continued) • low emissions biomass based on digester methane gas from landfills, sewage treatment plants or animal waste and biomass energy based on solid organic fuels from wood, forest or field residues or dedicated crops that do not include wood pieces that have been treated with chemical preservatives such as creosote, pentachlorophenol or copper chrome arsenic. Renewable Energy Credits (also known as Tradable Renewable Energy Credits, Renewable Energy Certificates, Green Tags or Carbon Credits) represent all of the regional and global environmental and emissions benefits associated with one unit of output from a qualifying renewable electricity generating resource. In some markets, the credits are certified by an independent third party and include a serial number for tracking purposes. Offering must consist of 100% new Renewable Energy. New Renewable Energy is (1) placed in operation (generating electricity) on or after January 28, 2000; (2) repowered on or after January 28, 2000 such that 80% of the fair market value of the project derives from new generation equipment installed as part of the repowering, or (3) a separable improvement to or enhancement of an operating existing facility that was first placed in operation prior to January 28, 2000, such that the proposed incremental generation is contractually available for sale and metered separately than existing generation at the facility. Any enhancement of a fuel source that increases generation at an existing facility, without the construction of a new or repowered, separately metered generating unit, is not eligible to participate. Preference will be given to resources within Pacific Power & Light Company and Rocky Mountain Power service territories. Renewable Energy purchases made to match Customer Block purchases are in addition to investments associated with the Company's Integrated Resource Plan, and are not considered for purposes of any Renewable Portfolio Standard requirements. Renewable Energy generated in response to any federal or state statutory requirement to construct or contract for the Renewable Energy is not eligible. (Continued) Submitted Under Advice Letter No. 07-04 ISSUED: March 26, 2007 EFFECTIVE: May 1, 2007 IDAHO PUBLIC UTILITIES COMMISSION Approved Effective April 6, 2009 April 12, 2009 Jean D. Jewell Secretary ROCKY MOUNTAIN POWER A DIVISION OF PACIFICORP I.P.U.C. No. 1 Second Revision of Sheet No. 70.3 Canceling First Revision of Sheet No. 70.3 ELECTRIC SERVICE SCHEDULE NO. 70 -CONTINUED QUALIFYING INITIATIVES: l. Funding for locally-owned commercial-scale Renewable Energy projects that produce less than 10 MW of electricity. The preference is for local community based projects that provide strong environmental and economic benefit to local communities and Customers the Company services under this Schedule. 2. Funding for research and development projects encouraging Renewable Energy market transformation in order to accelerate marketability of Renewable Energy technologies. 3. Investment in the above market costs associated with the construction of Renewable Energy facilities or purchase by contract of Renewable Energy, reducing the costs of Renewable Energy to be competitive with cost-effective resources. 4. To the extent a project in paragraphs 1, 2, and 3 above is able to generate RECs, the recipient agrees that the Company has the right to claim a share of the project's REC output. The share amount is expressed as a percentage of output when comparing the Company's financial contribution to the overall cost of the project. The share amount of these RECs will be retired on behalf of program participants across the Company's service territories. The Company will also be given the opportunity to purchase additional RECs off the project. 5. Qualifying Initiatives are not considered for purposes of any Renewable Portfolio Standard requirements. Renewable Energy generated in response to any federal or state statutory requirement to construct or contract for The Renewable Energy is not eligible. SPECIAL CONDITIONS: 1. Customers may apply for this Schedule anytime during the year. 2. The Company may accept enrollments for accounts that have a time-payment agreement in effect, or have received two or more disconnect notices, or have been disconnected within the last 12 months. 3. The Company will purchase Renewable Energy within two years of a Customer's purchase. (Continued) Submitted Under Advice Letter No. 09-02 ISSUED: March 11, 2009 EFFECTIVE: April 12, 2009 IDAHO PUBLIC UTILITIES COMMISSION Approved Effective April 23, 2007 May 1, 2007 Jean D. Jewell Secretary I.P.U.C. No. 1 Original Sheet No. 70.4 ELECTRIC SERVICE SCHEDULE NO. 70 -CONTINUED SPECIAL CONDITIONS: ( continued) 4. To ensure that all costs and benefits of this program are isolated to the participants of this program, all funds collected under this program will be separately identified and tracked. On the effective date of this Schedule, the Company will establish a regulatory liability for all funds collected and will debit the regulatory liability as funds are spent. The Company will endeavor to match spending to collection within each calendar year. ELECTRIC SERVICE REGULATIONS: Service under this Schedule will be in accordance with the terms of the Electric Service Agreement between the Customer and the Company. The Electric Service Regulations of the Company on file with and approved by the Idaho Public Utilities Commission, including future applicable amendments, will be considered as forming a part of and incorporated in said Agreement. Submitted Under Advice Letter No. 07-04 ISSUED: March 26, 2007 EFFECTIVE: May 1, 2007 IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Feb. 6, 2020 Jan. 1, 2020 Per O.N. 34545 Diane M. Hanian Secretary I.P.U.C. No. 1 Fourth Revision of Sheet No. 73.1 Canceling Third Revision of Sheet No. 73.1 ROCKY MOUNTAIN POWER ELECTRIC SERVICE SCHEDULE NO. 73 STATE OF IDAHO Renewable Energy Rider -Optional Bulk Purchase Option AVAILABILITY: In all territory served by the Company in the state ofldaho. APPLICATION: To Customers receiving service under The Company's non-residential Electric Service Schedules. ADMINISTRATION: Funds received from Customers under this Schedule will cover program costs and match Renewable Energy purchases to Block purchases. Funds not spent after covering program costs and matching Renewable Energy purchases to Block purchases may be used to fund Qualifying Initiatives as defined below. BLOCK: 1 Block equals 200 kWh of Renewable Energy. This program requires a minimum purchase of 1,212 Blocks per year. For the purpose of qualifying for this Schedule, Customers with multiple sites can sum their Block purchases across all Pacific Power and Rocky Mountain Power service territories to meet the minimum purchase requirement. CHARGE PER BLOCK: $0.70 per month Plus $1,500.00 per year fixed charge For Purchase commitments over two years in length or large purchases over 75,000 MWh per year, individually negotiated arrangements may be available, pursuant to the execution of a written contract. CHARGE: The Charge can be billed either monthly, twice yearly or annually and shall be the number of Blocks the Customer has agreed to purchase multiplied by the Charge per Block, plus the $1,500 yearly fixed charge divided between the customer's billing choice (monthly, twice yearly or annually) and added to the Customer's standard bill. The Charge is in addition to all other charges contained in Customer's applicable tariff schedule. This rider's Charge shall be applied to the Customer's billing regardless of actual energy consumption. ( continued) Submitted Under Case No. PAC-E-19-17 FILED: October 24, 2019 EFFECTIVE: January 1, 2020 IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Feb. 09, 2010 Feb. 12, 2010 Jean D. Jewell Secretary ROCKY MOUNTAIN POWER A DIVISION OF PACIFICORP I.P.U.C. No. 1 Second Revision of Sheet No. 73.2 Canceling First Revision of Sheet No. 73.2 ELECTRIC SERVICE SCHEDULE NO. 73 -Continued RENEW ABLE ENERGY: Renewable Energy includes bundled power or Renewable Energy Credits (RECs) derived from the following fuels: • wind; • solar; • geothermal energy; • certified low impact hydroelectric; • hydrogen derived from photovoltaic electrolysis or a non-hydrocarbon derivation process; • pipeline or irrigation canal hydroelectric systems; • wave or tidal action; and • low emissions biomass based on digester methane gas from landfills, sewage treatment plants or animal waste and biomass energy based on solid organic fuels from wood, forest or field residues or dedicated crops that do not include wood pieces that have been treated with chemical preservations such as creosote, pentachlorophenol or copper chrome arsenic. Renewable Energy Credits ( also known as Tradable Renewable Energy Credits, Renewable Energy Certificates, Green Tags or Carbon Credits) represent all of the regional and global environmental and emissions benefits associated with one unit of output from a qualifying renewable electricity generating resource. In some markets, the credits are certified by an independent third party and include a serial number for tracking purposes. Offering must consist of 100% new Renewable Energy. New Renewable Energy is (1) placed in operation (generating electricity) on or after January 28, 2000; (2) repowered on or after January 28, 2000 such that 80% of the fair market value of the project derives from new generation equipment installed as part of the repowering, or (3) a separable improvement to or enhancement of an operating existing facility that was first placed in operation prior to January 28, 2000, such that the proposed incremental generation is contractually available for sale and metered separately than existing generation at the facility. Any enhancement of a fuel source that increases generation at an existing facility, without the construction of a new or repowered, separately metered generating unit, is not eligible to participate. Preference will be given to resources within Pacific Power & Light Company and Rocky Mountain Power service territories. ( continued) Submitted Under Advice Letter No. 10-01 FILED: January 13, 2010 EFFECTIVE: February 12, 2010 IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Aug. 9, 2007 Aug. 27, 2007 Jean D. Jewell Secretary I.P.U.C. No. 1 First Revision of Sheet No. 73.3 Canceling Original Sheet No. 73.3 ELECTRIC SERVICE SCHEDULE NO. 73 -Continued RENEWABLE ENERGY: (continued) Renewable Energy purchases made to match Customer Block purchases are in addition to investments associated with the Company's Integrated Resource Plan, and are not considered for purposes of any Renewable Portfolio Standard requirements. Renewable Energy generated in responses to any federal or state statutory requirement to construct or contract for the Renewable Energy is not eligible. QUALIFYING INITIATIVES 1. Funding for locally-owned commercial-scale Renewable Energy projects that produce less than 10 MW of electricity. The preference is for local community based projects that provide strong environmental and economic benefit to local communities and Customers the Company services under this Schedule. 2. Funding for research and development projects encouraging Renewable Energy market transformation in order to accelerate marketability of Renewable Energy technologies. 3. Investment in the above market costs associated with the construction of Renewable Energy facilities or purchase by contract of Renewable Energy, reducing the costs of Renewable Energy to be competitive with cost-effective resources. 4. To the extent a project in paragraphs 1, 2, and 3 above is able to generate RECs, the recipient agrees that the Company has the right to claim a share of the project's REC output. The share amount is expressed as a percentage of output when comparing the Company's financial contribution to the overall cost of the project. The share amount of these RECs will be retired on behalf of program participants across the Company's service territories. The Company will also be given the opportunity to purchase additional RECs off the project. 5. Qualifying Initiatives are not considered for purposes of any Renewable Portfolio Standard requirements. Renewable Energy generated in response to any federal or state statutory requirement to construct or contract for the Renewable Energy is not eligible. ( continued) Submitted Under Advice Letter No. 07-10 FILED: July 26, 2007 EFFECTIVE: August 27, 2007 IDAHO PUBLIC UTILITIES COMMISSION Approved Effective April 6, 2009 April 12, 2009 Jean D. Jewell Secretary ✓ ROCKY MOUNTAIN POWER A DIVISION OF PACIFICORP I.P.U.C. No. 1 First Revision of Sheet No. 73.4 Canceling Original Sheet No. 73.4 ELECTRIC SERVICE SCHEDULE NO. 73 -Continued SPECIAL CONDITIONS: 1. Customers may apply for this Schedule anytime during the year. 2. The Company may accept enrollments for accounts that have a time-payment agreement in effect, or have received two or more disconnect notices, or have been disconnected within the last 12 months. 3. The Company will purchase Renewable Energy within two years of a Customer's purchase. 4. To ensure that all costs and benefits of this program are isolated to the participants of this program, all funds collected under this program will be separately identified and tracked. On the effective date of this Schedule, the Company will establish a regulatory liability for all funds collected and will debit the regulatory liability as funds are spent. The Company will endeavor to match spending to collection within each calendar year. ELECTRIC SERVICE REGULATIONS: Service under this Schedule will be in accordance with the terms of the Electric Service Agreement between the Customer and the Company. The Electric Service Regulations of the Company on file with and approved by the Idaho Public Utilities Commission, including future applicable amendments, will be considered as forming a part of and incorporated in said Agreement. Submitted Under Advice Letter No. 09-02 FILED: March 24, 2009 EFFECTIVE: April 12, 2009 Twelfth Revision of Sheet No. 94.1 I.P.U.C. No. 1 Canceling Eleventh Revision of Sheet No. 94.1 Submitted Under Case No. PAC-E-21-07 ISSUED: November 24, 2021 EFFECTIVE: January 1, 2022 ROCKY MOUNTAIN POWER ELECTRIC SERVICE SCHEDULE NO. 94 STATE OF IDAHO ______________ Energy Cost Adjustment ______________ AVAILABILITY: At any point on the Company’s interconnected system. APPLICATION: This Schedule shall be applicable to all retail tariff Customers taking service under the Company’s electric service schedules. ENERGY COST ADJUSTMENT: The Energy Cost Adjustment is calculated to collect the accumulated difference between total Company Base Net Power Cost and total Company Actual Net Power Cost calculated on a cents per kWh basis. MONTHLY BILL: In addition to the Monthly Charges contained in the Customer's applicable schedule, all monthly bills shall have applied the following cents per kilowatt-hour rate by delivery voltage. IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Feb. 1, 2022 Jan. 1, 2022 Per O.N. 35277 Jan Noriyuki Secretary First Revison of Sheet 114.1 I.P.U.C. No. 1 Canceling Original Sheet No. 114.1 Submitted Under Case No. PAC-E-22-13 FILED: May 10, 2023 EFFECTIVE: April 1, 2023 ROCKY MOUNTAIN POWER ELECTRIC SERVICE SCHEDULE NO. 114 STATE OF IDAHO _____________________ Load Management Program _____________________ APPLICABLE: This tariff is applicable to eligible Customers who have premises located in designated areas. Customers served by the Company in the state of Idaho taking service under the Company’s electric service schedules listed on Schedule 191 – Customer Efficiency Services Rate Adjustment located within the designated areas are eligible to participate in a Load Management Program (Program). PURPOSE: To manage electric loads through a Company-dispatched Direct Load Control System (System). PROGRAM DESCRIPTION: Detailed descriptions of Programs can be found on the Company website. CUSTOMER PARTICIPATION: Participating premises are considered Program participants for the duration of the Program(s). Customers may cancel their participation in the Program(s) at any time. The Company or its Program contractors shall have the right to qualify program participants, at their sole discretion based on criteria the Company or Program contractors consider necessary to ensure the effective operation of the Program(s) and utility System. Program details can be viewed on the Company’s website. PROVISIONS OF SERVICE FOR LOAD MANAGEMENT PROGRAMS: 1. Qualifying Equipment or Services, incentive amounts, and participation procedures will be listed on the program website. 2. Incentive delivery may vary by technology and may include cash payments and/or bill credits. Incentive payouts for the Wattsmart Battery 5-Year Pilot Program will be available through 2031. 3. Incentives may be offered year-round or for selected time periods. 4. Incentive offer availability, incentive levels, and Qualifying Equipment or Services may be changed to reflect changing codes and standards, sales volumes, quality assurance data, or to enhance program cost effectiveness. 5. All changes will occur with a minimum of 45 days notice and be prominently displayed as a change on the Company’s website. ELECTRIC SERVICE REGULATIONS: Service under this Schedule will be in accordance with the terms of the Electric Service Agreement between the Customer and the Company. The Electric Service Regulations of the Company on file with and approved by the Idaho Public Utilities Commission, including future applicable amendments, will be considered as forming a part of and incorporated in said Agreement. IDAHO PUBLIC UTILITIES COMMISSIONApproved EffectiveMay 22, 2023 April 1, 2023 Per ON 35787 Jan Noriyuki Secretary IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Aug. 28, 2006 Sept. 15, 2006 Jean D. Jewell Secretary I.P.U.C. No. 1 Original Sheet No. 118.1 ROCKY MOUNTAIN POWER ELECTRIC SERVICE SCHEDULE NO. 118 STATE OF IDAHO Home Energy Saver Incentive Program PURPOSE: Service under this tariff is intended to maximize the efficient utilization of the electricity requirements of new and existing loads in new and existing residences including manufactured housing and multi-family dwellings. APPLICABLE: To new and existing residential customers in all territory served by the Company in the state of Idaho billed on Schedule 1 or Schedule 36. Landlords who own rental properties served by the company in the state of Idaho where the tenant is billed on Schedule 1 or Schedule 36 also qualify for this program. CUSTOMER PARTICIPATION: Customer participation is voluntary and is initiated by following the participation procedures listed on the program web site. DESCRIPTION: On-going program to deliver incentives for a variety of equipment and services intended for and located in residential dwellings. Home Energy Saver Incentive program will be delivered by the Program Administrator and periodic changes will be made to insure or enhance program cost effectiveness as defined by the Company. QUALIFYING EQUIPMENT OR SERVICES: Equipment or services for residential dwellings, which when correctly installed or performed, result in verifiable electric energy usage reductions where such usage is compared to the existing equipment or baseline equipment as determined by the Company. PROGRAM ADMINISTRATOR: Qualified person or entity hired by the Company to administer this program. (Continued) Submitted Under Advice Letter No. 06-:06 ISSUED: August 14, 2006 EFFECTIVE: September 15, 2006 IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Aug. 28, 2006 Sept. 15, 2006 Jean D. Jewell Secretary ROCKY MOUNTAIN POWER A DIVISION OF PACIFICORP I.P.U.C. No. 1 Original Sheet No. 118.2 ELECTRIC SERVICE SCHEDULE NO. 118 -Continued PROVISIONS OF SERVICE: 1. Qualifying Equipment or Services, incentive amounts, and participation procedures will be listed on the program Web site. 2. Incentive delivery may vary by technology and may include any or all of the following; post purchase mail-in, point-of-purchase buy-down, manufacturer buy down or pre-purchase off er and approval. 3. Incentives may be offered for year-round or for selected time periods. 4. Incentive offer availability, incentive levels and Qualifying Equipment or Services may be changed by the Program Administrator after consultation with the Company to reflect changing codes and standards, sales volumes, quality assurance data or to enhance program cost effectiveness. 5. All changes will occur with a minimum of 45 days notice, be prominently displayed as a change, include a minimum 45 day grace period for processing prior offers ( except for manufacturer buy-down incentive delivery) and be communicated at least once to retailers who have participated within the last year. 6. Incentives paid directly to customers will be in the form of a check issued within 45 days of Program Administrator's receipt of a complete and approved incentive application. 7. Company and/or Program Administrator will employ a variety of quality assurance techniques during the delivery of the program. They may differ by equipment or service type and may include, but are not limited to, pre and post installation inspections, phone surveys, retailer invoice reconciliations and confirmation of customer and equipment eligibility. 8. Company may verify or evaluate the energy savings of installed equipment or services. Verification or evaluation may include, but are not limited to, telephone survey, site visit, billing analysis, pre-and post-installation of monitoring equipment as necessary to quantify actual energy savings. ELECTRIC SERVICE REGULATIONS: Service under this schedule will be in accordance with the terms of the Electric Service Agreement between the Customer and the Company. The Electric Service Regulations of the Company on file with and approved by the Idaho Public Utilities Commission, including future applicable amendments, will be considered as forming a part of and incorporated in said Agreement. Submitted Under Advice Letter No. 06-06 ISSUED: August 14, 2006 EFFECTIVE: September 15, 2006 Second Revision of Sheet No. 135.1 I.P.U.C. No. 1 Canceling First Revision of Sheet No. 135.1 Submitted Under Case No. PAC-E-19-08 FILED: October 12, 2020 EFFECTIVE: October 2, 2020 ROCKY MOUNTAIN POWER ELECTRIC SERVICE SCHEDULE NO. 135 STATE OF IDAHO ______________ Net Metering Service Closed to Applications for New Service as of October 2, 2020 ______________ AVAILABILITY: At any point on the Company's interconnected system. APPLICATION: On a first-come, first-served basis to any customer that owns and operates an Eligible Generating Plant that is located on the Customer’s premises, on the Customer’s side of the Point of Delivery, is interconnected and operates in parallel with the Company’s existing transmission and distribution facilities and is intended primarily to offset part or all of the Customer’s own electrical requirements. TERM: Service under this Schedule will terminate on October 2, 2045. DEFINITIONS: Net Metering: The difference between the electricity supplied by the Company and the electricity generated by an eligible Customer and fed back to the electric grid over the applicable billing period. Eligible Generating Plant: A facility that uses energy derived from the sun, wind, water, biomass or fuel cell technology to generate electricity. An Eligible Generating Plant may not have a generating capacity of more than twenty-five (25) kilowatts for customers taking service on Schedules 1, 36, 23 or 23A or one hundred (100) kilowatts for all other customers. To qualify, a Customer must maintain 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. Generation Interconnection Point: The point where the conductors installed to allow receipt of Customer’s generation connect to the Company’s facilities adjacent to the Customer’s Point of Delivery. MONTHLY BILL: The Electric Service Charge shall be computed in accordance with the charges for the Monthly Bill in the applicable standard service tariff subject to the following Special Conditions. (continued) IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Oct. 12, 2020 Oct. 2, 2020 Per O.N. 34798 Jan Noriyuki Secretary Second Revision of Sheet No. 135.2 I.P.U.C. No. 1 Canceling First Revision Sheet No. 135.2 ELECTRIC SERVICE SCHEDULE NO. 135 - Continued SPECIAL CONDITIONS: 1. If the energy supplied by the Company exceeds the energy generated by the Customer and delivered to the Company, the Customer shall be billed for the appropriate Power and other non-energy charges and the prices specified in the Energy Rate section of the Monthly Billing of the applicable standard service tariff shall be applied to the net positive balance owed to the Company. 2. If the energy generated by the Customer and delivered to the Company exceeds the energy supplied by the Company, the Customer shall be billed for the appropriate Power and other non-energy charges and the excess energy shall be financially credited as outlined under sub-sections a. and b. below. Credits shall remain on the account, and may only be used to offset the Customer’s energy charges at the meter originating the credit or other eligible meters as outlined under Special Condition No. 12. a. Customers taking retail service under Schedules 1, 36, 23 or 23A shall be financially credited for such net energy at the Customer’s standard service schedule retail rate. b. Customers taking retail service under all other Schedules shall be financially credited for such net energy at the Net Metering Rate Credit specified in Special Condition No. 3. 3. Net Metering Rate Credit equals 85 percent of the monthly weighted average of the daily on-peak and off- peak Mid-Columbia Intercontinental Exchange Electricity Price Index (Mid-C ICE Index) prices for non- firm energy. This rate is calculated based upon the previous calendar month’s data. If the Mid-C ICE Index prices are not reported for a particular day or days, the average of the immediately preceding and following reporting periods or days will be used. 4. Net energy and the Net Metering Rate Credit for Customers taking service under any Time-of-Day Schedule will be calculated separately for on-peak and off-peak usage. 5. The Customer shall execute an interconnection agreement with the Company prior to interconnection of the Eligible Generating Plant with the Company's system. The Customer shall provide the interconnection on Customer’s side of the meter. The Customer is responsible for all costs associated with the Eligible Generating Plant and interconnection facilities, including additional metering necessary for service under this schedule. At Customer’s expense, the Company shall make reasonable modifications to the Company’s system necessary to accommodate the Customer’s facility. The payment for such modifications is due in advance of construction. The Customer shall provide at the Customer’s expense all equipment that is necessary to meet applicable local, state and national standards regarding electrical and fire safety, power quality, and interconnection requirements established by the National Electrical Code, the Institute of Electrical and Electronics Engineers, American National Standards Institute, and Underwriters Laboratories. (continued) Submitted Under Case. No. PAC-E-19-03 FILED: March 15, 2019 EFFECTIVE: July 3, 2019 IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Aug. 13, 2019 July 3, 2019 Per O.N. 34370 Diane M. Hanian Secretary First Revision of Sheet No. 135.3 I.P.U.C. No. 1 Canceling Original Sheet No. 135.3 ELECTRIC SERVICE SCHEDULE NO. 135 - Continued 6. The Company’s written approval of the Customer’s protection-isolation method to ensure generator disconnection in case of a power interruption from the Company is required before service is provided under this schedule. 7. 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. 8. 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 within the same customer class who do not receive service under this schedule. 9. 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. 10. The Company shall not be liable directly or indirectly for permitting or continuing to allow an attachment of a net metering facility, or for the acts or omissions of the Customer that cause loss or injury, including death, to Customer or any third party. 11. The Customer shall grant to the Company 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. The Company may test and inspect an interconnection at times that it considers necessary to ensure the safety of electrical workers and to preserve the integrity of the electric power grid. 12. Transfer of excess net financial credits: a. If excess net financial credits exist at a meter at the end of the Customer’s February billing period the Customer may request to transfer the unused financial credits to offset energy charges at the Customer’s other eligible meters. Credits may be transferred to a meter or meters that meet the following criteria: i) The meter is located on, or contiguous to, the Premises on which the meter with excess financial credit are located. For purposes of Schedule 135, parcels shall be considered contiguous if they share a common boundary or corner, and includes parcels that would otherwise be considered contiguous but are divided by a public right of way; and ii) The meter is served by the same primary feeder as the meter with the excess financial credits; and iii) The electricity recorded by the meter is on the same rate schedule as the meter with the excess financial credits. (continued) Submitted Under Case No. PAC-E-19-03 FILED: March 15, 2019 EFFECTIVE: July 3, 2019 IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Aug. 13, 2019 July 3, 2019 Per O.N. 34370 Diane M. Hanian Secretary First Revision of Sheet No. 135.4 I.P.U.C. No. 1 Canceling Original Sheet No. 135.4 Submitted Under Case No. PAC-E-19-08 FILED: October 12, 2020 EFFECTIVE: October 2, 2020 ELECTRIC SERVICE SCHEDULE NO. 135 - Continued 12. Transfer of excess net financial credits: (continued) b. Customers may submit written requests to transfer excess net financial credits between the eligible meter(s) March 1st through March 31st of each year. A $10 processing charge will apply to each meter receiving the transferred excess energy credits. c. All requests must be received by Rocky Mountain Power by midnight on March 31st. If a Customer does not request to transfer excess net financial credits by March 31st, the credits will remain on the originating meter’s agreement until they become eligible for transfer on March 1st of the following year. 13. A Customer submitting an application for service under this Schedule has 12 months from the Customer’s receipt of confirmation that the interconnection request is approved to interconnect. 14. A Customer whose Eligible Generating Plant is offline for over 6 months or an Eligible Generating Plant that is moved to a different site shall no longer be eligible for service under this Schedule. 15. To remain eligible for service under this Schedule, a Customer may not increase the capacity of a grandfathered Eligible Generating Plant by no more than 10% of the originally installed nameplate capacity, or 1 kW, whichever is greater. 16. Service under this Schedule is transferable to a subsequent Customer at the premises for which a valid Interconnection Agreement for Net Metering Service is in effect. Each Customer taking service under this Schedule will be responsible for complying with the terms and conditions of the Interconnection Agreement for Net Metering Service in effect for that premises. ELECTRIC SERVICE REGULATIONS: Service under this Schedule will be in accordance with the terms of the Electric Service Agreement between the Customer and the Company. The Electric Service Regulations of the Company on file with and approved by the Idaho Public Utilities Commission, including future applicable amendments, will be considered as forming a part of and incorporated in said Agreement. IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Oct. 12, 2020 Oct. 2, 2020 Per O.N. 34798 Jan Noriyuki Secretary I.P.U.C. No. 1 Original Sheet No. 136.1 (continued) Submitted Under Case No. PAC-E-19-08 ISSUED: October 12, 2020 EFFECTIVE: November 1, 2020 ROCKY MOUNTAIN POWER ELECTRIC SERVICE SCHEDULE NO. 136 STATE OF IDAHO ______________ Net Billing Service ______________ AVAILABILITY: At any point on the Company's interconnected system. APPLICATION: On a first-come, first-served basis to any customer that owns and operates an Eligible Generating Plant that is located on the Customer’s premises, on the Customer’s side of the Point of Delivery, is interconnected and operates in parallel with the Company’s existing transmission and distribution facilities and is intended primarily to offset part or all of the Customer’s own electrical requirements. DEFINITIONS: Net Billing: Charges for all electricity supplied by the Company and netted by the export credit for the electricity generated by an eligible Customer and fed back to the electric grid over the applicable billing period. Eligible Generating Plant: A facility that uses energy derived from the sun, wind, water, biomass or fuel cell technology to generate electricity. An Eligible Generating Plant may not have a generating capacity of more than twenty-five (25) kilowatts for customers taking service on Schedules 1, 36, 23 or 23A or one hundred (100) kilowatts for all other customers. To qualify, a Customer must maintain 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. Generation Interconnection Point: The point where the conductors installed to allow receipt of Customer’s generation connect to the Company’s facilities adjacent to the Customer’s Point of Delivery. Exported Customer-Generated Energy: The amount of customer-generated Energy in excess of the customer’s on-site consumption. MONTHLY BILL: The Electric Service Charge shall be computed in accordance with the charges for the Monthly Bill in the applicable standard service tariff and the Credits for Exported Customer-Generated Energy, if any, shall be computed at the following rates subject to the Special Conditions in this tariff. Exported Customer-Generated Energy Credit Rates are subject to change, as approved by the Commission. IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Oct. 12, 2020 Nov. 1, 2020 Per O.N. 34798 Jan Noriyuki Secretary First Revision Sheet No. 136.2 I.P.U.C. No. 1 Canceling Original Sheet No. 136.2 (continued) Submitted Under Tariff Advice No. 22-02 ISSUED: June 14, 2022 EFFECTIVE: August 1, 2022 ELECTRIC SERVICE SCHEDULE NO. 136 - Continued Exported Customer-Generated Energy Credit Rates: 1. Within the monthly billing period, all energy exported from the customer’s generating plant to the Company’s system shall be financially credited at the otherwise applicable retail energy rate. Any excess monthly credits shall be carried forward and shall be financially credited as outlined under sub-sections a. and b. below. Credits shall remain on the account, and may only be used to offset the Customer’s energy charges at the meter originating the credit or other eligible meters as outlined under Special Condition No. 11. a. Customers taking retail service under Schedules 1, 36, 23 or 23A shall be financially credited for excess monthly exported energy at the Customer’s standard service schedule retail rate. b. Customers taking retail service under all other Schedules shall be financially credited for excess monthly exported energy at the Net Billing Rate Credit specified in section 2. 2. Net Billing Rate Credit equals 85 percent of the monthly weighted average of the daily on- peak and off-peak Mid-Columbia Intercontinental Exchange Electricity Price Index (Mid-C ICE Index) prices for non-firm energy. This rate is calculated based upon the previous calendar month’s data. If the Mid-C ICE Index prices are not reported for a particular day or days, the average of the immediately preceding and following reporting periods or days will be used. 3. Exported Customer-Generated Energy Credit Rates for Customers taking service under any Time-of-Day Schedule will be calculated separately for on-peak and off-peak usage. SPECIAL CONDITIONS: 1. Applications for service under this schedule will be subject to the following application fee: $85 per application. 2. Energy charges for electricity supplied by the Company shall be computed in accordance with a Customer’s applicable standard service tariff. 3. The credit value in dollars computed for the Exported Customer-Generated Energy will be applied against charges on the Customer’s monthly bill. Excess credits will carry-over to the next monthly bill. Excess credits may only be used to offset charges at the meter originating the credit or other eligible meters as outlined under Special Condition No. 11. IDAHO PUBLIC UTILITIES COMMISSION Approved Effective July 5, 2022 August 1, 2022 Jan Noriyuki Secretary I.P.U.C. No. 1 Original Sheet No. 136.3 (continued) Submitted Under Case No. PAC-E-19-08 ISSUED: October 12, 2020 EFFECTIVE: November 1, 2020 ELECTRIC SERVICE SCHEDULE NO. 136 - Continued SPECIAL CONDITIONS: (continued) 4. The Customer shall execute an interconnection agreement with the Company prior to interconnection of the Eligible Generating Plant with the Company's system. The Customer shall provide the interconnection on Customer’s side of the meter. The Customer is responsible for all costs associated with the Eligible Generating Plant and interconnection facilities, including additional metering necessary for service under this schedule. At Customer’s expense, the Company shall make reasonable modifications to the Company’s system necessary to accommodate the Customer’s facility. The payment for such modifications is due in advance of construction. The Customer shall provide at the Customer’s expense all equipment that is necessary to meet applicable local, state and national standards regarding electrical and fire safety, power quality, and interconnection requirements established by the National Electrical Code, the Institute of Electrical and Electronics Engineers, American National Standards Institute, and Underwriters Laboratories. 5. The Company’s written approval of the Customer’s protection-isolation method to ensure generator disconnection in case of a power interruption from the Company is required before service is provided under this schedule. 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 within the same customer class who do not receive service under this schedule. 8. 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. 9. The Company shall not be liable directly or indirectly for permitting or continuing to allow an attachment of a net metering facility, or for the acts or omissions of the Customer that cause loss or injury, including death, to Customer or any third party. IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Oct. 12, 2020 Nov. 1, 2020 Per O.N. 34798 Jan Noriyuki Secretary I.P.U.C. No. 1 Original Sheet No. 136.4 Submitted Under Case No. PAC-E-19-08 ISSUED: October 12, 2020 EFFECTIVE: November 1, 2020 ELECTRIC SERVICE SCHEDULE NO. 136 - Continued SPECIAL CONDITIONS: (continued) 10. The Customer shall grant to the Company 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. The Company may test and inspect an interconnection at times that it considers necessary to ensure the safety of electrical workers and to preserve the integrity of the electric power grid. 11. Transfer of excess credits: a. If excess credits exist at a meter at the end of the Customer’s February billing period the Customer may request to transfer the unused excess credits to offset Power and Energy Charges at the Customer’s other eligible meters. Excess credits may be transferred to a meter or meters that meet the following criteria: i) The meter is located on, or contiguous to, the Premises on which the meter with excess credits are located; and ii) The meter is served by the same primary feeder as the meter with the excess credits; and iii) The electricity recorded by the meter is on the same rate schedule as the meter with the excess credits. b. Customers may submit written requests to transfer excess credits between the eligible meter(s) March 1st through March 31st of each year. A $10 processing charge will apply to each meter receiving the transferred excess credits. c. All requests must be received by Rocky Mountain Power by midnight on March 31st. ELECTRIC SERVICE REGULATIONS: Service under this Schedule will be in accordance with the terms of the Electric Service Agreement between the Customer and the Company. The Electric Service Regulations of the Company on file with and approved by the Idaho Public Utilities Commission, including future applicable amendments, will be considered as forming a part of and incorporated in said Agreement. IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Oct. 12, 2020 Nov. 1, 2020 Per O.N. 34798 Jan Noriyuki Secretary First Revision of Sheet No. 140.1 I.P.U.C. No. 1 Canceling Original Sheet No. 140.1 Submitted Under Case No. PAC-E-21-07 ISSUED: November 8, 2021 EFFECTIVE: January 1, 2022 ROCKY MOUNTAIN POWER ELECTRIC SERVICE SCHEDULE NO. 140 STATE OF IDAHO ______________ Non-Residential Energy Efficiency ______________ PURPOSE: Service under this Schedule is intended to maximize the efficient utilization of the electricity requirements of new and existing loads in Non-residential Facilities through the installation of Energy Efficiency Measures and energy management protocols. Service under this Schedule is subject to funding availability. APPLICABLE: To service under the Company's General Service Schedules 6, 6A, 7, 7A, 9, 10, 12, 23, 23A, 24, 35 and 35A in all territory served by the Company in the State of Idaho. This Schedule is applicable to new and existing Non-residential Facilities and dairy barns served under the Company’s residential rate schedules. CUSTOMER PARTICIPATION: Customer participation is voluntary and is initiated by following the participation procedures on the Idaho energy efficiency program section of the Company website, and available to customers without online access upon request. The Company shall have the right to qualify participants, at its discretion, based on criteria the Company considers necessary to ensure the effective operation of the measures and utility system. Criteria may include, but will not be limited to cost effectiveness. DESCRIPTION: Ongoing program to provide incentives for a variety of equipment and operational improvements intended for and located in Non-residential Facilities. Periodic program changes will be made to encourage customer participation in the program and to insure or enhance program cost-effectiveness as defined by the Company. QUALIFYING MEASURE: Measures which when installed in an eligible facility result in verifiable electric energy efficiency improvement compared to existing equipment or baseline equipment as defined by the Company. The baseline will be determined with reference to existing equipment, applicable state or federal energy codes, industry standard practice and other relevant factors. QUALIFYING ENERGY MANAGEMENT: Operational improvements which when implemented in an eligible facility result in verifiable electric energy savings compared to standard operations as determined by the Company. (Continued) IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Feb. 1, 2022 Jan. 1, 2022 Per O.N. 35277 Jan Noriyuki Secretary IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Dec. 1, 2014 Nov. 13, 2014 Per O.N. 33178 Jean D. Jewell Secretary ROCKY MOUNTAIN POWER A DIVISION OF PACIFICORP I.P.U.C. No. 1 Original Sheet No. 140.2 ELECTRICAL SERVICE SCHEDULE NO. 140 (Continued) PROVISIONS OF SERVICE: ( 1) Qualifying equipment or services, incentive amounts and other terms and conditions will be listed on the Idaho energy efficiency program section of the Company website, and are available to customers without online access upon request. Program changes may be made by the Company with at least 45 days advanced notice. Such changes will be prominently displayed on the Idaho energy efficiency program section of the Company website and include a minimum 45 days for processing prior offers. (2) Company may elect to offer energy efficiency measure ("EEM") incentives through different channels and at different points in the sales process other than individual Energy Efficiency Incentive Offer Letter(s) prior to EEM purchase. The differences will depend on EEM and will be consistent for all EEMs of similar type. (3) Incentives may be offered year-round or for selected time periods. (4) Equipment or services receiving an incentive under this program are not eligible for incentives under other Company programs. (5) Company will employ a variety of quality assurance techniques during the delivery of the program. They will differ by measure and may include pre-and post-installation inspections, phone surveys, and confirmation of Owner/Customer and equipment eligibility. ( 6) Company may verify or evaluate the energy savings of installed measures. This verification may include a telephone survey, site visit, review of facility operation characteristics, and pre-and post-installation of monitoring equipment as necessary to quantify actual energy savings. (7) Energy Project Manager co-funding is available according to the terms posted on the Idaho energy efficiency program section of the Company website. (8) Incentives will not be made available for fuel switching by Owner/Customer. MINIMUM EQUIPMENT EFFICIENCY: Retrofit energy efficiency projects must meet minimum equipment efficiency levels and equipment eligibility requirements of qualifying equipment that are listed on the Idaho energy efficiency program section of the Company website. Submitted Under Case No. PAC-E-14-08 ISSUED: November 18, 2014 (Continued) EFFECTIVE: November 2014 IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Dec. 1, 2014 Nov. 13, 2014 Per O.N. 33178 Jean D. Jewell Secretary ROCKY MOUNTAIN POWER A DIVISION OF PACIFICORP I.P.U.C. No. 1 Original Sheet No. 140.3 ELECTRICAL SERVICE SCHEDULE NO. 140 (Continued) ELECTRIC SERVICE REGULATIONS: Service under this Schedule will be in accordance with the terms of the Electric Service Agreement between the Customer and the Company. The Electric Service Regulations of the Company on file with and approved by the Idaho Public Utilities Commission, including future applicable amendments, will be considered as forming a part of and incorporated in said Agreement. Submitted Under Case No. PAC-E-14-08 ISSUED: November 18, 2014 EFFECTIVE: November l, 2014 IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Sept. 29, 2022 Oct. 1, 2022 Per ON 35546 Jan Noriyuki Secretary I.P.U.C. No. 1 Ninth Revision of Sheet No. 191 Canceling Eighth Revision of Sheet No. 191 ROCKY MOUNTAIN POWER ELECTRIC SERVICE SCHEDULE NO. 191 ST ATE OF IDAHO Customer Efficiency Services Rate Adjustment PURPOSE: The Customer Efficiency Services Rate Adjustment is designed to recover the costs incurred by the Company associated with Commission-approved demand-side management expenditures. APPLICATION: This Schedule shall be applicable to all retail tariff Customers taldng service under the Company's electric service schedules. MONTHLY BILL: In addition to the Monthly Charges contained in the Customer's applicable schedule, all monthly bills shall have the following percentage increases applied prior to the application of electric service Schedule 34. Schedule I 2.50% Schedule 6 2.50% Schedule 6A 2.50% Schedule 7 2.50% Schedule 7A 2.50% Schedule 9 2.50% Schedule 10 2.50% Schedule 11 2.50% Schedule 12 2.50% Schedule 23 2.50% Schedule 23A 2.50% Schedule 24 2.50% Schedule 35 2.50% Schedule 35A 2.50% Schedule 36 2.50% Submitted Under Case No. PAC-E-22-10 ISSUED: July 8, 2022 EFFECTIVE: October 1, 2022 Second Revision of Sheet No. 197.1 I.P.U.C. No. 1 Canceling First Revision of Sheet No. 197.1 Submitted Under Case No. PAC-E-21-07 ISSUED: November 8, 2021 EFFECTIVE: January 1, 2022 ROCKY MOUNTAIN POWER ELECTRIC SERVICE SCHEDULE NO. 197 STATE OF IDAHO ______________ Federal Tax Act Adjustment ______________ APPLICATION: This Schedule shall be applicable to all retail tariff Customers taking service under the Company’s electric service schedules. MONTHLY BILL: In addition to the Monthly Charges contained in the Customer's applicable schedule, all monthly bills shall have applied the following cents per kilowatt-hour rate. IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Feb. 1, 2022 Jan. 1, 2022 Per O.N. 35277 Jan Noriyuki Secretary Second Revision of Sheet No. 300.1 I.P.U.C. No. 1 Canceling First Revision of Sheet No. 300.1 Submitted Under Case No. PAC-E-21-07 ISSUED: November 8, 2021 EFFECTIVE: January 1, 2022 ROCKY MOUNTAIN POWER ELECTRIC SERVICE SCHEDULE NO. 300 STATE OF IDAHO _____________ Regulation Charges ______________ AVAILABILITY: In all service territory served by the Company in the State of Idaho. APPLICATION: For all customers utilizing the services of the Company as defined and described in the Electric Service Regulations. SERVICE CHARGES: Sheet No. Description Charge 3R.1 Service Connection Charge: Normal Office Hours No Charge Monday through Friday except holidays 4:00 P.M. to 7:00 P.M. $50.00 Weekends and holidays* 8:00 A.M. to 4:00 P.M. $50.00 *Charge assessed if connection is requested and completed on the following holidays: 7R.2 Meter Test for Accuracy Once in twelve months No charge Two or more times in twelve months Actual Cost 7R.3 Fee paid to mobile home operators who sub-meter tenants $1.15 per month per occupied space 8R.1 Late Payment Charge: 1% of delinquent balance per month 8R.2 Returned Payment Charge: $12.00 (continued) IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Feb. 1, 2022 Jan. 1, 2022 Per O.N. 35277 Jan Noriyuki Secretary I.P.U.C. No. 1 Seventh Revision of Sheet No. 300.2 Canceling Sixth Revision of Sheet No. 300.2 Submitted Under Case No. PAC-E-21-07 ISSUED: November 8, 2021 EFFECTIVE: January 1, 2022 ELECTRIC SERVICE SCHEDULE NO. 300 - Continued Sheet No. Description Charge 8R.2 Paperless Bill Credit -$0.50 9R.4 Security Deposit for New Service: Residential and Small Commercial Up to one sixth of estimated annual billings. Industrial and Large Commercial Up to two months peak billings. 10R.8 Reconnection Charges: Remote Reconnection $7.00 Non-Remote Reconnection Monday through Friday except holidays. 8:00 A.M. to 4:00 P.M. $25.00 4:00 P.M. to 7:00 P.M. $50.00 Weekends and holidays* 8:00 A.M. to 4:00 P.M. $50.00 *Charge assessed if reconnection is requested and completed on the following holidays: 10R.8 Tampering Unauthorized Reconnection Charge: $75.00 10R.8 Field Visit Charge: $20.00 11R.1 Taxes Type of Amount of Date Ordinance Municipality Tax or Fee Ordinance No. Tax or Fee Adopted City of Arco Franchise No. 2007-B 3.0% July 23, 2007 City of Ammon Franchise No. 501 3.0% May 19, 2011 City of Bloomington Franchise No. 2012-01 10.0% May 10, 2012 City of Dubois Franchise No. 268 10.0% March 7, 2012 City of Firth Franchise No. 159 1.0% March 14, 2000 City of Franklin Franchise No. 2004-811 3.0% September 23, 2004 City of Iona Franchise No. 40 3.0% June 22, 1989 City of Lewisville Franchise No. 2011-2 2.0% September 14, 2011 City of McCammon Franchise No. 462 3.0% September 7, 2011 City of Mud Lake Franchise No. 60904 2.0% June 9, 2004 City of Paris Franchise No. 338 3.0% November 2, 1998 City of Preston Franchise No. 2005-4 3.0% August 8, 2005 (Continued) IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Feb. 1, 2022 Jan. 1, 2022 Per O.N. 35277 Jan Noriyuki Secretary Fourth Revision of Sheet No. 300.3 I.P.U.C. No. 1 Canceling Third Revision of Sheet No. 300.3 Submitted Under Case No. PAC-E-21-07 ISSUED: November 8, 2021 EFFECTIVE: January 1, 2022 ELECTRIC SERVICE SCHEDULE NO. 300 - Continued Type of Amount of Date Ordinance Municipality Tax or Fee Ordinance No. Tax or Fee Adopted City of Rexburg Franchise No. 929 6.0% December 8, 2004 City of Rigby Franchise No. 453 3.0% May 21, 1996 City of Ririe Franchise No. 104 3.0% December 31, 1990 City of St. Anthony Franchise No. 20011-10 1.0% September 22, 2011 City of Shelley Franchise No. 375 3.0% October 1, 1995 City of Spencer Franchise No. 2008-1 2.0% June 20, 2008 City of Sugar City Franchise No. 204 3.0% June 13, 1996 Sheet No. Description Charge 12R.1 Minimum Engineering Costs $200 12R.3 Facilities Charges on Facilities less than 46,000 Volts Facilities Installed at Customer's Expense 0.35% per month Facilities Installed at Company's Expense 1.15% per month Facilities Charges on Facilities at and above 46,000 Volts Facilities Installed at Customer's Expense 0.15% per month Facilities Installed at Company's Expense 0.80% per month 12R.13 Temporary Service Charge: Service Drop and Meter only $200.00 (Charge is for connection and disconnection) 12R.15 Contract Administration Allowance $250 25R.1 Customer Guarantee Credit 1: Restoring Supply After an Outage $50.00 For each additional 12 hours $25.00 25R.2 Customer Guarantee Credit 2: Appointments $50.00 25R.2 Customer Guarantee Credit 3: Switching on Power $50.00 25R.2 Customer Guarantee Credit 4: Estimates for New Supply $50.00 (continued) IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Feb. 1, 2022 Jan. 1, 2022 Per O.N. 35277 Jan Noriyuki Secretary First Revision of Sheet No. 300.4 I.P.U.C. No. 1 Canceling Original Sheet No. 300.4 Submitted Under Case No. PAC-E-21-07 ISSUED: November 8, 2021 EFFECTIVE: January 1, 2022 ELECTRIC SERVICE SCHEDULE NO. 300 - Continued Sheet No. Description Charge 25R.3 Customer Guarantee Credit 5: Responding to Bill Inquiries $50.00 25R.3 Customer Guarantee Credit 6: Resolving Meter Problems $50.00 25R.3 Customer Guarantee Credit 7: Notifying of Planned Interruptions $50.00 IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Feb. 1, 2022 Jan. 1, 2022 Per O.N. 35277 Jan Noriyuki Secretary Twelfth Revision of Sheet No. 400.1 I.P.U.C. No. 1 Canceling Eleventh Revision of Sheet No. 400.1 Submitted Under Case No. PAC-E-21-07 ISSUED: November 8, 2021 EFFECTIVE: January 1, 2022 ROCKY MOUNTAIN POWER ELECTRIC SERVICE SCHEDULE NO. 400 STATE OF IDAHO ______________ Special Contract ______________ PURPOSE: The purpose of this Schedule is to describe generally the terms and conditions provided by the Company pursuant to a Special Contract approved by the Idaho Public Utility Commission. Availability This schedule is available for firm and interruptible retail service of electric power and energy delivered for all service required on the Customer’s premises by customers contracting for not less than 150,000 kW as of May 18, 2006 and as provided in the Electric Service Agreement between the two parties. Monthly Charge Firm Power and Energy: Firm Energy Charge: 33.260 mills per kilowatt hour Customer Charge: $1,556.00 per Billing Period Firm Demand Charge: $15.61 per kW Interruptible Power and Energy: Interruptible Energy Charge: 33.260 mills per kilowatt hour Interruptible Demand Charge: Firm Demand charge minus Interruptible Credit Excess KVAR: $0.96/KVAR Replacement Energy: Adjusted Index Price multiplied by Replacement Energy. Tariff Rates: The Commission approved rates applicable to the Special Contract Customer, including, but not limited to, customer charges, demand charges, energy charges, surcharges, and credits, as specified in Idaho Electric Service Schedule No. 400 or its successor. IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Feb. 1, 2022 Jan. 1, 2022 Per O.N. 35277 Jan Noriyuki Secretary Eleventh Revision of Sheet No. 401.1 I.P.U.C. No. 1 Canceling Tenth Revision of Sheet No. 401.1 ROCKY MOUNTAIN POWER ELECTRIC SERVICE SCHEDULE NO. 401 STATE OF IDAHO ______________ Special Contract ______________ PURPOSE: The purpose of this Schedule is to describe generally the terms and conditions provided by the Company pursuant to a Special Contract approved by the Idaho Public Utility Commission. Availability This schedule is available for firm retail service of electric power and energy delivered for the operations of Itafos Conda LLC’s facilities located at Soda Springs, Idaho, as provided in the Power Supply Agreement between the two parties. Monthly Charge Tariff Rates: The Commission approved rates applicable to Itafos Conda LLC, including, but not limited to, customer charges, demand charges, energy charges, surcharges, and credits, as specified in Idaho Electric Service Schedule No. 401 or its successor. Submitted Under Advice No. 18-01 ISSUED: January 12, 2018 EFFECTIVE: February 1, 2018 IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Jan. 29, 2018 Feb. 1, 2018 Diane M. Hanian Secretary