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HomeMy WebLinkAboutPacificorp dba Rocky Mtn Power ID SCHEDULES.pdfIDAHO PUBLIC UTILITIES COMMISSION Approved Effective Aug. 28, 2006 Sept. 15, 2006 Jean D. Jewell Secretary Fourth Revision of Sheet No. B.1 I.P.U.C. No. 1 Canceling Third Revision of Sheet No. B.1 Submitted Under Case No. PAC-E-12-12 ISSUED: August 13, 2012 EFFECTIVE: January 1, 2013 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 - 7.4 7A Security Area Lighting (Residential and Farm) 7A.1 - 7A.5 9 General Service - High Voltage 9.1 & 9.2 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 Lighting Service- Consumer-Owned System 12.1 - 12.5 14 Temporary Service Connection Facilities – No New Service* 14 19 Commercial and Industrial Space Heating – No New Service* 19.1 - 19.4 21 Low Income Weatherization Services 21.1 - 21.6 (Continued) IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Dec. 28, 2012 Jan. 1, 2013 Per O.N. 32704 Jean D. Jewell 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 ‘ROCKY MOUNTAIN POWER A DMSON OF PACRCORP I.P.U.C.No.1 Fifth Revision of Sheet No.B.3 Canceling Fourth Revision of Sheet No.B.3 ELECTRIC SERVICE SCHEDULES -Continued Schedule Sheet No.Class of Service No. 135 Net Metering Service 135.1 —135.3 140 Non-Residential Energy Efficiency 140.1 —140.3 191 Customer Efficiency Services Rate Adjustment 191 300 Regulation Charges 300.1 —300.4 400 Special Contract 400.1 401 Special Contract 401.1 Schedule numbers not listed are not currently used. *These schedules are not available to new customers or premises. Submitted Under Case No.PAC-E-14-08 ISSUED:November 18,2014 EFFECTIVE:November 1,2014 IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Dec. 1, 2014 Nov. 13, 2014 Per O.N. 33178 Jean D. Jewell Secretary ROCKY MOUNTAIN POWER A DMS0N OF PFIOP Tenth Revision of Sheet No.1.1 T.P.U.C.No.1 Canceling Ninth Revision of Sheet No.1.1 ROCKY MOUNTAIN POWER ELECTRIC SERVICE SCHEDULE NO.1 STATE OF IDAHO Residential Service AVAILABLLITY: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 ott 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 th.elling or apartment units that may he 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: Customer Service Charge: $5.00 per Customer Energy Charge: (1)Billing months rvlay through October inclusive 11.13160 per kWh first 700 kWh 14.9382 0 per kWh all additional kWh (Continued) Submitted Under Case No.PAC-E-16-12 ISSUED:November 11,2016 EFFECTIVE:January 1,2017 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 OF PACIFICORP Tenth Revision of Sheet No.1.2 I.P.U.C.No.1 Canceling Ninth Revision of Sheet No.1.2 ELECTRIC SERVICE SCHEDULE NO.1-Continued MONTHLY BILL:(continued) (2)Billing months November through April inclusive 8.58060 per kWh first 1,000 kWh I 1.49430 per kWh all additional kWh MONTHLY BILLING REDUCTION:Rates in this schedule shall be reduced by the monthly kilowatt-hour credit adjustment set thrth 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 $60.00. 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 Case No.PAC-E-16-12 ISSUED:November 11.2016 EFFECTIVE:January 1,2017 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 OF PACIFIcORP Eighth Revision of Sheet No.6.1 I.P.U.C.No.I Canceling Seventh Revision of Sheet No.6.1 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 May Billing Months November through October,Inclusive through April,Inclusive Customer Service Charge: Secondary voltage delivery (Less than 2300 volts)$37.00 per Customer $37.00 per Customer Primary voltage delivery (2300 volts or higher)$111.00 per Customer $111.00 per Customer Power Rate:$14.36 per kW for all l.W $11.81 per kW for all kW Energy Rate:3.9880 per kWh for all kWh 3.98800 per kWh for all kWh (Continued) Submitted Under Case No.PAC-E-16-12 ISSUED:November 11,2016 EFFECTIVE:January 1,2017 IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Dec. 14, 2016 Jan. 1, 2017 Per O.N. 33668 Diane M. Hanian Secretary Fourth Revision of Sheet No. 6.2 I.P.U.C. No. 1 Canceling Third Revision of Sheet No. 6.2 Submitted Under Advice No. 12-03 ISSUED: October 19, 2012 EFFECTIVE: January 1, 2013 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: $ 444.00 plus Power and Energy Charges for Customer taking service at less than 2300 volts and $ 1,332.00 plus Power and Energy Charges for Customer taking service at 2300 volts or higher. (Continued) IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Oct. 29, 2012 Jan. 1, 2013 Jean D. Jewell Secretary IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Aug. 28, 2006 Sept. 15, 2006 Jean D. Jewell Secretary ROCKY MOUNTAIN POWER A DIVISION OFPACIFICORP Eighth Revision of Sheet No.6A.l J.P.U.C.No.1 Canceling Seventh Revision of Sheet No.6A.1 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 (I)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: Billing Months May Billing Months November through October,Inclusive through April.Inclusive Customer Service Charge: Secondary voltage delivery (Less than 2300 volts)$37,00 per Customer $37.00 per Customer Primary voltage delivery (2300 volts or higher)$111.00 per Customer $111.00 per Customer Power Rate:$14.36 per kW for all kW $11.81 per kW for all kW Energy Rate:3.98800 per kWh for all kWh 3.98800 per kWh for all kWh (Continued) Submitted Under Case No.PAC-E-l6-12 ISSUED:November 11,2016 EFFECTIVE:January 1,2017 IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Dec. 14, 2016 Jan. 1, 2017 Per O.N. 33668 Diane M. Hanian 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 Fourth Revision of Sheet No. 6A.3 I.P.U.C. No. 1 Canceling Third Revision of Sheet No. 6A.3 Submitted Under Advice No. 12-03 ISSUED: October 19, 2012 EFFECTIVE: January 1, 2013 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: $ 444.00 plus Power and Energy Charges for Customer taking service at less than 2300 volts and $1,332.00 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 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 Oct. 29, 2012 Jan. 1, 2013 Jean D. Jewell Secretary IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Aug. 28, 2006 Sept. 15, 2006 Jean D. Jewell Secretary ROCKY MOUNTAIN POWER A DMSON OF PACIFICORP Eighth Revision of Sheet No.7.1 I.P.U.C.No.1 Canceling Seventh Revision of Sheet No.7.1 ROCKY MOUNTAIN POWER ELECTRIC SERVICE SCHEDULE NO.7 STATE OF IDAHO Security Area Lighting Closed to New Service AVAILABILiTY:At any point on the Company’s interconnected system.No new Mercury Vapor Lamps will be installed after May 3,1985. APPLICATION:This Schedule is for (1)electric service required for Security Area Lighting and for Security Flood Lighting service where service is supplied from a Company-owned overhead wood pole system and (2)Customer-owned/Customer-maintained Area Lighting. MONTHLY BILL: Rate: (I)Security Area Lightigg Nominal Lamp Rating: Initial Lumens Watts Per Lamp Mercury Vapor Lamp: 7,000 175 $27.22 per lamp 20,000 400 $48.54 per lamp (Continued) Submitted Under Case No.PAC-E-16-12 ISSUED:November II.2016 EFFECTIVE:January 1,2017 IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Dec. 14, 2016 Jan. 1, 2017 Per O.N. 33668 Diane M. Hanian Secretary ROCKY MOUNTAiN POWER A OMSIONOF PACIFICORP Sixth Revision of Sheet No.7.2 I.P.U.C.No.1 Canceling Fifth Revision of Sheet No.7.2 ELECTRIC SERVICE SCHEDULE NO.7 -Continued MONTHLY BILL:(continued) Sodium Vapor Lamps: 5,600 high intensity discharge 70 $17.29 per lamp on new pole $13.76 per lamp if no new pole is required 9,500 high intensity discharge 100 $19.80 per lamp on new pole $16.26 per lamp if no new pole is required 16,000 high intensity discharge 150 $26.07 per lamp on new pole $23.21 per lamp if no new pole is required 27,500 high intensity discharge 250 $37.51 per lamp on new pole $33.96 per lamp if no new pole is required 50,000 high intensity discharge 400 $52.41 per lamp on new pole $46.39 per lamp if no new pole is required Sodium Vapor Flood Lamps: 16,000 high intensity discharge 150 $26.07 per lamp on new pole $23.21 per lamp if no new pole is required 27,500 high intensity discharge 250 $37.51 per lamp on new pole $33.96 per lamp if no new pole is required 50,000 high intensity discharge 400 $52.41 per lamp on new pole $46.39 per lamp if no new pole is required (Continued) Submitted Under Case No.PAC-E-1 6 12 ISSUED:November 11,2016 EFFECTIVE:January 1,2017 IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Dec. 14, 2016 Jan. 1, 2017 Per O.N. 33668 Diane M. Hanian Secretary IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Aug. 28, 2006 Sept. 15, 2006 Jean D. Jewell Secretary ROCKY MOUNTAIN ‘POWER ‘A DSION OPPACIFICOMP Eighth Revision of Sheet No.7.4 I.P.U.C.No.1 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 Watts Per Lamp 16,000 Sodium Vapor Flood 150 $15.13 CONTRACT PERIOD:One year or longer. PRO VISIONS I.Inoperable lights will he 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 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-l2 ISSUED:November 11,2016 EFFECTIVE:January 1,2017 IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Dec. 14, 2016 Jan. 1, 2017 Per O.N. 33668 Diane M. Hanian Secretary ROCKY MOUNTAIN ‘POWER A OIVISION OFPACIFICORP Seventh Revision of Sheet No.7A.l I.P.U.C.No.1 Canceling Sixth Revision of Sheet No.7A.1 ROCKY MOUNTAIN POWER ELECTRIC SERVICE SCHEDULE NO. 7A STATE OF IDAHO Security Area Lighting (Residential and Farm) Closed to New Service 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 (I)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.No new Mercury Vapor Lamps will be installed after May 3,1985. 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 overhead wood pole system. MONTHLY BILL: Rate: (1)Security Area Lighting Nominal Lamp Rating: Initial Lumens Watts Per Lamp Mercury Vapor Lamp: 7,000 175 $27.22 per lamp 20,000 400 $48.54 per lamp (Continued) Submitted Under Case No.PAC-E-16-l2 ISSUED:November 11,2016 EFFECTIVE:January 1,2017 IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Dec. 14, 2016 Jan. 1, 2017 Per O.N. 33668 Diane M. Hanian Secretary ROCKY MOUNTAIN POWER A OMSION OF PAt FCORP Sixth Revision of Sheet No.7A.2 I.P.U.C.No.1 Canceling Fifth Revision of Sheet No.7A.2 ELECTRIC SERVICE SCHEDULE NO.7A -Continued MONTHLY BILL:(continued) Rate: Sodium Vapor Lamps: 5,600 high intensity discharge 70 $17.29 per lamp on new pole $13.76 per lamp if no new pole is required 9,500 high intensity discharge 100 $19.80 per lamp on new pole $16.26 per lamp if no new pole is required 16,000 high intensity discharge ISO $26.07 per lamp on new pole $23.21 per lamp if no new pole is required 27,500 high intensity discharge 250 $37.51 per lamp on new pole $33.96 per lamp if no new pole is required 50,000 high intensity discharge 400 $52.41 per lamp on new pole $46.39 per lamp if no new pole is required Sodium Vapor Flood Lamps: 16,000 high intensity discharge 150 $26.07 per lamp on new pole $23.21 per lamp if no new pole is required 27,500 high intensity discharge 250 $37.51 per lamp on new pole $33.96 per lamp if no new pole is required 50,000 high intensity discharge 400 $52.41 per lamp on new pole $46.39 per lamp if no new pole is required (Continued) Submitted Under Case No.PAC-E-16-12 ISSUED:November 11,2016 EFFECTIVE:January 1,2017 IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Dec. 14, 2016 Jan. 1, 2017 Per O.N. 33668 Diane M. Hanian Secretary IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Aug. 28, 2006 Sept. 15, 2006 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. (Continued) Submitted Under Case No. PAC-E-12-04 ISSUED: January 18,2012 EFFECTIVE: April 24, 2012 IDAHO PUBLIC UTILITIES COMMISSION Approved Effective April 27, 2012 April 24, 2012 Per O.N. 32519 Jean D. Jewell Secretary 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 IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Aug. 28, 2006 Sept. 15, 2006 Jean D. Jewell Secretary ‘ROCKY MOUNTAIN POWER A DIVISION OFPACIFICORP Eighth Revision of Sheet No.9.2I.P.U.C.No.1 Canceling Seventh Revision of Sheet No.9.2 ELECTRIC SERVICE SCHEDULE NO.9-Continued MONTHLY BILL: Rate: Billing Months May Billing Months November through October,Inclusive through April,Inclusive Customer Service Charge:$370.00 per Customer $370.00 per Customer Power Rate:$10.26 per kW for all kW $7.74 per kW for all kW Energy Rate:4.18720 per kWh for all kWh 4.18720 per kWh for all 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 tneasurement.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. 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 ofthe 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 II,2016 EFFECTIVE:January 1,2017 IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Dec. 14, 2016 Jan. 1, 2017 Per O.N. 33668 Diane M. Hanian 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 ‘ROCKY MOUNTAIN POWER OMSION OF PAOFCORP Tenth Revision of Sheet No.10.2 LP.U.C.No.1 Canceling Ninth Revision of Sheet No. 10.2 ELECTRIC SERVICE SCHEDULE No.10 -Continued MONTHLY BILL:(Continued) Power Rate:$5.98 per kW for all kW Energy Rate:8.871 l per kWh for first 25,000 kWh 6.62960 per kWh for the next 225,000 kWh 4.96 160 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:7.54410 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 he considered delinquent if not paid within fifleen (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) Submitted Under Case No.PAC-E-l6-12 LSSUED:November 11,2016 EFFECTIVE:January 1,2017 IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Dec. 14, 2016 Jan. 1, 2017 Per O.N. 33668 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 ROCKY MOUNTAIN ‘POWER A OIUISION OF PACIFICORP Ninth Revision of Sheet No.11.1 LP.U.C.No.I Canceling Eighth Revision of Sheet No.11.1 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. Light-Emitting Diode (LED) ___________________________________________________ Lumen Rating (Minimum)4,000 6,200 13,000 16,800 Watts (Maximum)50 75 135 185 Functional [.ighting $15.34 $16.83 $22.84 $28.94 High Pressure Sodium Vapor Lumen Rating -5,800*9,500 16,000 27,500 50,000 Watts 70 100 150 250 400 Monthly kWh 28 39 59 96 148 Functional Lighting $15.35 $19.15 $26.10 $36.44 $53.49 Decorative -Series I N/A $31.68 $34.76 N/A N/A Decorative-Series 2 N/A $26.07 $29.07 N/A N/A *Existing fixtures only.Service is not available under this schedule to new 5,800 lumen Kigh Pressure Sodium vapor Fixtures. (Continued) Submitted Under Case No.PAC-E-16-l 2 ISSUED:November 11,2016 EFFECTIVE:January 1,2017 IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Dec. 14, 2016 Jan. 1, 2017 Per O.N. 33668 Diane M. Hanian Secretary Fourth Revision of Sheet No. 11.2 I.P.U.C. No. 1 Canceling Third Revision of Sheet No. 11.2 Submitted Under Advice No. 16-03 ISSUED: February 10, 2016 EFFECTIVE: March 15, 2016 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. Decorative Lighting: More stylish luminaires mounted vertically on decorative metal poles. The Company will maintain a listing of standard decorative street light fixtures that are available under this Electric Service Schedule. Available decorative lighting fixtures are grouped into different Decorative Series 1 and Decorative Series 2 according to cost. 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. 22, 2016 March 15, 2016 Jean D. Jewell 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 ROCKY MOUNTAIN ‘POWER A ONISION OF PAC1FCORP Eighth Revision of Sheet No.12.1 I.P.U.C.No.I Canceling Seventh Revision of Sheet No.12.1 ROCKY MOUNTAIN POWER ELECTRIC SERVICE SCHEDULE NO.12 STATE OF IDAHO Street 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. 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 Lumen Rating 5,800 9.500 16,000 27,500 50,000 Watts 70 100 150 250 400 Monthly kWh 28 39 59 96 148 Energy Only Service $2.90 $4.06 $6.04 $10.32 $15.85 (Continued) Submitted Under Case No.PAC-E-16.12 ISSUED: November 11,2016 EFFECTIVE:January 1,2017 IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Dec. 14, 2016 Jan. 1, 2017 Per O.N. 33668 Diane M. Hanian Secretary ‘ROCKY MOUNTAIN POWER A DMSION OF PACIF1COAP I,P.U.C.No.1 Eighth Revision of Sheet No.12.2 Canceling Seventh Revision of Sheet No.12.2 ELECTRIC SERVICE SCHEDULE NO.12 Continued MONTHLY BILL:(continued) Metal Halide —No Maintenance Lumen Rating 33,000 Watts 180 Monthly kWh 74 Energy Only Service $9.36 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. Non-Listed Luminaire $/kWh Energy Only Service $0.105 139 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 Lumen Rating 10,000 20,000 Watts 250 400 Monthly kWh 93 145 Partial Maintenance Service $16.79 $22.47 Submitted Under Case No.PAC-E-16-12 (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 $4.10 $7.20 $9.86 $15.49 $37.09 Low Pressure Sodium Vapor -No Maintenance ISSUED:November 11,2016 EFFECTIVE:January 1,2017 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 OF PACIFICOAP Seventh Revision of Sheet No.12.3 I.P.U.C.No.1 Canceling Sixth Revision of Sheet No. 12.3 ELECTRIC SERVICE SCHEDULE NO.12-Continued MONTHLY BILL:(continued) High Pressure Sodium — Partial Maintenance Lumen Rating 5,800 9,500 27,500 50,000 Watts 70 100 250 400 Monthly kWh 28 39 96 148 Partial Maintenance Service $602 $7.75 $12.40 $16.71 13.Street Lighting,“Full Maintenanc High Pressure Sodium — Full Maintenance Lumen Rating 5,800 9,500 16.000 27,500 50,000 Watts 70 100 150 250 400 Monthly kWh 28 39 59 96 148 Full Maintenance Service $6.7!$8.56 $10.27 $13.45 $17.93 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 tnaintenance”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. (Continued) Submitted Under Case No.PAC-E-16-l2 ISSUED:November Il,2016 EFFECTIVE:January 1,2017 IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Dec. 14, 2016 Jan. 1, 2017 Per O.N. 33668 Diane M. Hanian Secretary Third Revision of Sheet No. 12.4 I.P.U.C. No. 1 Canceling Second Revision of Sheet No. 12.4 Submitted Under Advice No. 16-03 ISSUED: February 10, 2016 EFFECTIVE: March 15, 2016 ELECTRIC SERVICE SCHEDULE NO. 12 - Continued MONTHLY BILL: (continued) SPECIFICATIONS AND SERVICE FOR STREET LIGHTING WITH PARTIAL AND FULL MAINTENANCE (NO NEW SERVICE): (continued) 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. 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. (Continued) IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Feb. 22, 2016 March 15, 2016 Jean D. Jewell Secretary IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Jan. 28, 2008 Feb. 15, 2008 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 MOUNTAIN POWER A DIVISION OF PACIFICOP Tenth Revision of Sheet No.19.2 I.P.U.C.No.1 Canceling Ninth Revision of Sheet No.19.2 ELECTRIC SERVICE SCHEDULE NO.19-Continued MONTHLY BILL: Rate for space heating: Billing Months May Billing Months November through October, Inclusive through April,Inclusive Customer Service Charge:$23.00 per Customer $23.00 per Customer Energy Rate:9.65020 per kWh for all kWh 7.21750 per kWh for all kWh Rate for all other service: 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 and 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. (Continued) Submitted Under Case No.PAC-E-l6-1 2 ISSUED:November 11,2016 EFFECTWE:January 1,2017 IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Dec. 14, 2016 Jan. 1, 2017 Per O.N. 33668 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 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 ROCKY MOUNTAIN POWER A DM5ION OF C1F1cORP Eighth Revision of Sheet No.23.1 LP.U.C.No.1 Canceling Seventh Revision of Sheet No.23.1 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: Billing Months May Billing Months November through October,Inclusive through April,Inclusive Customer Service Charge: Secondary voltage delivery (Less than 2300 volts)$16.00 per Customer $16.00 per Customer Primary voltage delivery (2300 volts or higher)$49.00 per Customer $49.00 per Customer Energy Rate:9.44 I0 per kWh for all kWh 8.2742 per kWh for all kWh (Continued) Submitted Under Case No.PAC-E-16-12 ISSUED:November 11,2016 EFFECTIVE:January 1,2017 IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Dec. 14, 2016 Jan. 1, 2017 Per O.N. 33668 Diane M. Hanian Secretary Fourth Revision of Sheet No. 23.2 I.P.U.C. No. 1 Canceling Third Revision of Sheet No. 23.2 Submitted Under Advice No. 12-03 ISSUED: October 19, 2012 EFFECTIVE: January 1, 2013 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: $192.00 plus Energy Charges for Customer taking service at less than 2,300 volts and $588.00 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 Oct. 29, 2012 Jan. 1, 2013 Jean D. Jewell Secretary IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Aug. 28, 2006 Sept. 15, 2006 Jean D. Jewell Secretary ‘ROCKY MOUNTAIN POWER A DIVISION OF PACIFICOAP Eighth Revision of Sheet No.23A.1 I.P.U.C.No.1 Canceling Seventh Revision of Sheet No.23A.1 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: Billing Months May Billing Months November through October,inclusive through April,Inclusive Customer Service Charge: Secondary voltage delivery (Less than 2300 volts)$16.00 per Customer $16.00 per Customer Primary voltage delivery (2300 volts or higher)$49.00 per Customer $49.00 per Customer Energy Rate:9.44100 per kWh for all kWh 8.27420 per kwh for all kWh (Continued) Submitted Under Case No.PAC-E-16-12 ISSUED:November 11,2016 EFFECTIVE:January 1,2017 IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Dec. 14, 2016 Jan. 1, 2017 Per O.N. 33668 Diane M. Hanian 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 Third Revision of Sheet No. 23A.3 I.P.U.C. No. 1 Canceling Second Revision of Sheet No. 23A.3 Submitted Under Advice No. 12-03 ISSUED: October 19, 2012 EFFECTIVE: January 1, 2013 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: $192.00 plus Energy Charges for Customer taking service at less than 2,300 volts and $588.00 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 Oct. 29, 2012 Jan. 1, 2013 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 I.P.U.C. No. 1 Original Sheet No. 31.1 Submitted Under Case No. PAC-E-12-12 ISSUED: August 13, 2012 EFFECTIVE: January 1, 2013 ROCKY MOUNTAIN POWER ELECTRIC SERVICE SCHEDULE NO. 31 STATE OF IDAHO ______________ Partial Requirements 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 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. Customers not contracting for Back-up Power shall not be subject to this Schedule and shall receive electric service under Electric Service Schedule No. 9. 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 15,000 kW, a maximum power requirement in excess of 15,000 kW shall be deemed to exist when a Customer’s maximum power requirement exceeds 15,000 kW in at least three (3) months of any continuous period of six (6) successive months. (continued) IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Dec. 28, 2012 Jan. 1, 2013 Per O.N. 32704 Jean D. Jewell Secretary ROCKY MOUNTAIN POWER A DMSON OF PIFICORP Second Revision of Sheet No.31.2 I.P.U.C.No.1 Canceling First Revision of Sheet No.31.2 ELECTRIC SERVICE SCHEDULE NO.31-Continued MONTHLY BILL: Rate: Billing Months May Billing Months November through October. Inclusive through April.Inclusive Customer Service Charge:$370.00 per Customer $370.00 per Customer Back-up Facilities Rate:$5.70 per kW for all kW $4.30 per kW for all kW The Facilities Rate applies to the kW of Back-up Contract Power Back-up Power Rate:$0.19 allkWDay $0.14 AIlkWDay Back-up Power is billed on a per day basis and is based on the fifteen (15) minute period of the Customers greatest use of Back-up Power during the day. Scheduled Maintenance Power rate is one half(1/2)ofthe Back-up Power Rate. Excess Power $20.52 per kW for all kW $15.48 per kW for all kW Rate: Supplementary $10.26 per kW for all kW $7.74 per kW for all kW Power Rate: Supplementary 4.1 8720 per kWh 4.18720 per kWh and Back-up Energy Rate: POWER FACTOR:This rate is based on the Customer maintaining at all times a power factor of85% lagging,or higher,as determined by measurement.If the average power factor is tbund to be less than 85% lagging,the Power as recorded by the Company’s meter will be increased by ¾of 1%for every 1%that the power factor is less than 85%. (continued) Submitted Under Case No.PAC-E-16-12 ISSUED:November 11,2016 EFFECTiVE:January 1,2017 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 Original Sheet No. 31.3 Submitted Under Case No. PAC-E-12-12 ISSUED: August 13, 2012 EFFECTIVE: January 1, 2013 ELECTRIC SERVICE SCHEDULE NO. 31 - 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 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. 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. (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. 31.4 Submitted Under Case No. PAC-E-12-12 ISSUED: August 13, 2012 EFFECTIVE: January 1, 2013 ELECTRIC SERVICE SCHEDULE NO. 31 - Continued DEFINITIONS (continued): 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 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. (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. 31.5 Submitted Under Case No. PAC-E-12-12 ISSUED: August 13, 2012 EFFECTIVE: January 1, 2013 ELECTRIC SERVICE SCHEDULE NO. 31 - Continued DEFINITIONS (continued): 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 Dec. 28, 2012 Jan. 1, 2013 Per O.N. 32704 Jean D. Jewell 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 ROCKY MOUNTAIN Po\AIER A Or\nSro}ri OF mOflCORP I.P.U.C. No. 1 Sixth Revision of Sheet No. 34.1 Canceling Fifth Revision of Sheet No. 34.1 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 ofresidential and/or farm use. Kilowatt-Hour Credit Adj ustments : Irrigation Customers: Schedule No. 10 $0.008403 per kWh Non-lrrigation Customers: $0.008403 per kWh Schedule Nos. 1, 64, 7 A, 234 35A,36,19 with 64 19 with 23A,19 with 35A Submitted Under Case No. PAC-E-17-10 ISSUED: August 18,2017 (continued) EFFECTM: October 1, 2017 IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Sept. 29, 2017 Oct. 1, 2017 Per O.N. 33896 Diane M. Hanian 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 IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Aug. 28, 2006 Sept. 15, 2006 Jean D. Jewell Secretary ROCKY MOUNTAIN POWER A OIVSION OF PACIFICORP Ninth Revision of Sheet No.35.2 LP.U.C.No.1 Canceling Eighth Revision of Sheet No.35.2 ELECTRIC SERVICE SCHEDULE NO.35-Continued MONTHLY BILL: Customer Service Charge: Secondary voltage delivery (Less than 2300 volts)$67.00 per Customer Primary voltage delivery (2300 volts or higher)$165.00 per Customer Power Charge: On-Peak kW $16.45 per kW Energy Charge: Per kWh for all kWh 5.21970 TIME PERIODS: On-Peak 7:00 n.m.to 10:00 p.m.,Monday thru Friday,except holidays. Off-Peak All other times. Due to the expansions of Daylight Saving Time (DST)as adopted under Section 110 of the U.S.Energy Policy Act of 2005 the time periods shown above will begin and end one hour later for the period between the second Sunday in March and the first Sunday in April,and for the period between the last Sunday in October and the first Sunday in November. 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) Submitted Under Case No.PAC-E-16-12 ISSUED: November 11,2016 EFFECTIVE:January 1,2017 IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Dec. 14, 2016 Jan. 1, 2017 Per O.N. 33668 Diane M. Hanian Secretary Fourth Revision of Sheet No. 35.3 I.P.U.C. No. 1 Canceling Third Revision of Sheet No. 35.3 Submitted Under Advice No. 12-03 ISSUED: October 19, 2012 EFFECTIVE: January 1, 2013 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: $ 804.00 plus Power and Energy Charges for Customer taking service at less than 2300 volts, and $1,980.00 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 Oct. 29, 2012 Jan. 1, 2013 Jean D. Jewell Secretary IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Aug. 28, 2006 Sept. 15, 2006 Jean D. Jewell Secretary ROCKY MOUNTAIN POWER ADIVISION QF PACIflCORP Ninth Revision of Sheet No.35A.2 I.P.U.C.No.1 Canceling Eighth Revision of Sheet No.35A.2 ELECTRIC SERVICE SCHEDULE NO.35A -Continued MONTHLY BILL: Customer Service Charge: Secondary voltage delivery (Less than 2300 volts)$67.00 per Customer Primary voltage delivery (2300 volts or higher)$165.00 per Customer Power Charge: On-Peak kW $16.45 per kW Energy Charge: Per kWh for all kWh 5.21 97 TIME PERIODS: On-Peak 7:00 a.m.to 10:00 p.m..Monday thru Friday.except holidays. OffPeak All other times. I)ue to the expansions of Daylight Saving Time (DST)as adopted under Section 110 of the U.S. Energy Policy Act of 2005 the time periods shown above will begin and end one hour later for the period between the second Sunday in March and the first Sunday in April.and for the period between the last Sunday in October and the first Sunday in November. 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) Submitted Under Case No.PAC-E-16-12 ISSUED:November Ii,2016 EFFECTIVE:January 1,2017 IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Dec. 14, 2016 Jan. 1, 2017 Per O.N. 33668 Diane M. Hanian Secretary Fourth Revision of Sheet No. 35A.3 I.P.U.C. No. 1 Canceling Third Revision of Sheet No. 35A.3 Submitted Under Advice No. 12-03 ISSUED: October 19, 2012 EFFECTIVE: January 1, 2013 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: $ 804.00 plus Power and Energy Charges for Customer taking service at less than 2300 volts, and $1,980.00 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 Oct. 29, 2012 Jan. 1, 2013 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 MOUNTAIN POWER A DMS)ON OF PAFICORP Eleventh Revision of Sheet No.36.2 IP.U.C.No.I Canceling Tenth Revision of Sheet No.36.2 ELECTRIC SERVICE SCHEDULE NO.36 -Continued MONTHLY BILL: Rate: Billing Months May Billing Months November through October.Inclusive through April.Inclusive Customer Service $14.00 per Customer $14.00 per Customer Charge: On Peak Energy Charge:14.78220 per kWh 12.66440 per kWh Off Peak Energy 5.21280 perkWh 4.79260 perkWh Charge: Minimum Bill:Customer Service Charge. On Peak Summer months--All kWh used from 8:00 AM.to 11:00 P.M.,Monday through Friday, except holidays. Winter months--All kWh used from 7:00 AM.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. Off Peak: All other kWh usage. I)ue to the expansions of Daylight Saving Time (UST)as adopted under Section 110 of the U.S. Energy Policy Act of 2005 the time periods shown above will begin and end one hour later for the period between the second Sunday in March and the first Sunday in April,and for the period between the last Sunday in October and the first Sunday in November. SEASONAL SERVICE:When seasonable service is supplied under this Schedule,the minimum seasonal charge will be $168.00 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) Submitted Under Case No.PAC-E-16-12 ISSUED:November Il,2016 EFFECTIVE:January 1,2017 IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Dec. 14, 2016 Jan. 1, 2017 Per O.N. 33668 Diane M. Hanian Secretary IDAHO PUBLIC UTILITIES COMMISSION Approved Effective July 24, 2006 March 1, 2007 Jean D. Jewell Secretary 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 ROCKY MOUNTAIN POWER A DIVISION OF PACIFICORP I.P.U.C.No.1 Fourth Revisiou of Sheet No.70.1 Canceling Third 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 ofIdaho. 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:1 Block equals 100 kWh ofRenewable 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 ofactual 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 (Continued) Submitted Under Advice Letter No.12-02 ISSUED:October 2,2012 EFFECTIVE:November 2,2012 IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Oct. 9, 2012 Nov. 2, 2012 Jean D. Jewell Secretary ROCKY MOUNTAIN POWER 7 A DIVISION OF PACIFICORP 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 23, 2007 May 1, 2007 Jean D. Jewell Secretary IDAHO PUBLIC UTILITIES COMMISSION Approved Effective April 6, 2009 April 12, 2009 Jean D. Jewell Secretary ROCKY MOUNTAIN POWER 7 A DIVISION OF PAClFlCORP 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 April 23, 2007 May 1, 2007 Jean D. Jewell Secretary ROCKY MOUNTAIN POWER A DIVISION OF PACIFICORP I.P.V.C.No.1 Third Revision of Sheet No.73.1 Canceling Second 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 of Idaho. 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 100 kWh of Renewable Energy.This program requires a minimum purchase of 121.2 megawatt-hours (121,200 kWh or 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 &Light Company and Rocky Mountain Power service territories to meet the minimum purchase requirement. CHARGE PER BLOCK: Plus $0.70 per month per 100 kWh block $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 Advice Letter No.12-02 FILED:October 2,2012 EFFECTIVE:November 2,2012 IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Oct. 9, 2012 Nov. 2, 2012 Jean D. Jewell Secretary IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Feb. 09, 2010 Feb. 12, 2010 Jean D. Jewell Secretary IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Aug. 9, 2007 Aug. 27, 2007 Jean D. Jewell Secretary IDAHO PUBLIC UTILITIES COMMISSION Approved Effective April 6, 2009 April 12, 2009 Jean D. Jewell Secretary ROCKY MOUNTAINPOWER A DIVISION OF PACIFICORP Ninth Revision of Sheet No.94.1 f.P.U.C.No.1 Canceling Eighth Revision of Sheet No.94.1 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-hourrate by delivery voltage. Delivery Voltage Secondary Primary Transmission Schedule 1 0.316¢per kWh Schedule 6 0.316¢per kWh 0.302¢per kWh Schedule 6A 0.316¢per kWh 0.302¢per kWh Schedule 7 0.316¢per kWh Schedule 7A 0.316¢per kWh Schedule 9 0.292¢per kWh Schedule 10 0.316¢per kWh Schedule 11 0.316¢per kWh Schedule 12 0.316¢per kWh Schedule 19 0.316¢per kWh Schedule 23 0.316¢per kWh 0.302¢per kWh Schedule 23A 0.316¢per kWh 0.302¢per kWh Schedule 24 0.316¢per kWh 0.302¢per kWh Schedule 35 0.316¢per kWh 0.302¢per kWh Schedule 35A 0.316¢per kWh 0.302¢per kWh Schedule 36 0.316¢per kWh Schedule 400 0.292¢per kWh Schedule 401 0.292¢per kWh Submitted Under Case No.PAC-E-19-04 ISSUED:April 3,2019 EFFECTIVE:June 1,2019 IDAHO PUBLIC UTILITIES COMMISSION Approved Effective May 31, 2019 June 1, 2019 Per O.N. 34352 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 First Revision of Sheet No. 135.1 I.P.U.C. No. 1 Canceling Original Sheet No. 135.1 Submitted Under Case No. PAC-E-16-07 FILED: February 29, 2016 EFFECTIVE: May 1, 2016 ROCKY MOUNTAIN POWER ELECTRIC SERVICE SCHEDULE NO. 135 STATE OF IDAHO ______________ Net Metering 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 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 May 9, 2016 May 1, 2016 Per O.N. 33511 Jean D. Jewell Secretary I.P.U.C. No. 1 First Revision Sheet No. 135.2 Submitted Under Advice Letter No. 16-05 FILED: June 23, 2016 EFFECTIVE: July 31, 2016 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: 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 #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) IDAHO PUBLIC UTILITIES COMMISSION Approved Effective July 18, 2016 July 31, 2016 Jean D. Jewell Secretary IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Aug. 28, 2006 Sept. 15, 2006 Jean D. Jewell Secretary ‘ROCKY MOUNTAIN POWER A OVISON OF PACFICOAP I.P.U.C.No.I Original Sheet No.140.1 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, 10,12,19,23.23A,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) Submitted Under Case No.PAC-E-14-08 ISSUED:November 18,2014 EFFECTIVE:November 1,2014 IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Dec. 1, 2014 Nov. 13, 2014 Per O.N. 33178 Jean D. Jewell Secretary wROCKY MOUNTAIN ‘POWER A DIVISION OF PACFCORP LP.U.C.No.1 Original Sheet No.140.2 ELECTRICAL SERVICE SCHEDULE NO.140 (Continued) PROVISIONS OF SERVICE: (I)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. (Continued) Submitted Under Case No.PAC-E-14-08 ISSUED:November 18,2014 EFFECTIVE:November .1,2014 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 PACFICORP LP.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:November2’,2014 IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Dec. 1, 2014 Nov. 13, 2014 Per O.N. 33178 Jean D. Jewell Secretary Sixth Revision of Sheet No. 191 I.P.U.C. No. 1 Canceling Fifth Revision of Sheet No. 191 Submitted Under Case No. PAC-E-16-02 ISSUED: January 19, 2016 EFFECTIVE: April 1, 2016 ROCKY MOUNTAIN POWER ELECTRIC SERVICE SCHEDULE NO. 191 STATE 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 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 the following percentage increases applied prior to the application of electric service Schedule 34. Schedule 1 2.70% Schedule 6 2.70% Schedule 6A 2.70% Schedule 7 2.70% Schedule 7A 2.70% Schedule 9 2.70% Schedule 10 2.70% Schedule 11 2.70% Schedule 12 – Street Lighting 2.70% Schedule 12 – Traffic Signal 2.70% Schedule 19 2.70% Schedule 23 2.70% Schedule 23A 2.70% Schedule 24 2.70% Schedule 35 2.70% Schedule 35A 2.70% Schedule 36 2.70% IDAHO PUBLIC UTILITIES COMMISSION Approved Effective March 31, 2016 April 1, 2016 Per O.N. 33491 Jean D. Jewell Secretary First Revision of Sheet No. 197.1 I.P.U.C. No. 1 Canceling Original Sheet No. 197.1 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. Submitted Under Case No. GNR-U-18-01 ISSUED: March 5, 2019 EFFECTIVE: June 1, 2019 IDAHO PUBLIC UTILITIES COMMISSION Approved Effective May 3, 2019 June 1, 2019 Per O.N. 34331 Diane M. Hanian Secretary First Revision of Sheet No. 300.1 I.P.U.C. No. 1 Canceling Original Sheet No. 300.1 Submitted Under Advice No. 15-01 ISSUED: April 23, 2015 EFFECTIVE: May 18, 2015 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.1 Meter Test for Accuracy Once in twelve months No charge Two or more times in twelve months Actual Cost 7R.2 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 Check Charge: $20.00 (continued) IDAHO PUBLIC UTILITIES COMMISSION Approved Effective May 11, 2015 May 18, 2015 Jean D. Jewell Secretary I.P.U.C. No. 1 Fifth Revision of Sheet No. 300.2 Canceling Fourth Revision of Sheet No. 300.2 Submitted Under Advice No. 15-01 ISSUED: April 23, 2015 EFFECTIVE: May 18, 2015 ELECTRIC SERVICE SCHEDULE NO. 300 - Continued Sheet No. Description Charge 9R.2 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: 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 May 11, 2015 May 18, 2015 Jean D. Jewell Secretary Second Revision of Sheet No. 300.3 I.P.U.C. No. 1 Canceling First Revision of Sheet No. 300.3 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 0.60% per month Facilities Installed at Company's Expense 1.30% per month Facilities Charges on Facilities at and above 46,000 Volts Facilities Installed at Customer's Expense 0.20% per month Facilities Installed at Company's Expense 0.90% per month 12R. 13 Temporary Service Charge: Service Drop and Meter only Single phase: $ 85.00 (Charge is for connection and Three phase: $115.00 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) 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 ‘ROCKY MOUNTAIN POWER A OIVISON OF PAOFICORP Eleventh Revision of Sheet No.400.1 I.P.U.C.No.1 Canceling Tenth Revision of Sheet No. 400.1 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, Availaijt’ 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 Poer and Ener: Firm Energy Charge:33.908 mills per kilowatt hour Customer Charge:$1,586.00 per Billing Period Firm Demand Charge:$15.91 per kW Interruptible Power and Energy: Interruptible Energy Charge:33.908 mills per kilowatt hour Interruptible Demand Charge:Firm Demand charge minus Interruptible Credit Excess KVAR:$0.96/KVAR Replacement Energy: Adlusted Index Price multiplied by Replacement hnergy, 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. Submitted Under Case No.PAC-E-I6l2 ISSUED:November 11.2016 EFFECTIVE:January 1,2017 IDAHO PUBLIC UTILITIES COMMISSION Approved Effective Dec. 14, 2016 Jan. 1, 2017 Per O.N. 33668 Diane M. Hanian 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