Pacificorp dba Rocky Mtn Power ID SCHEDULES.pdf

IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Aug. 28, 2006 Sept. 15, 2006
Jean D. Jewell Secretary
I.P.U.C. No.1 Original Sheet No. A
ELECTRIC RATE SCHEDULES
of
ROCKY MOUNTAIN POWER
Salt Lake City, Utah
for
ELECTRIC SERVICE
in the
STATE OF IDAHO
Under
IDAHO PUBLIC UTILITIES COMMISSION
TARIFFNO.1
CANCELSALLPREVIOUSSCHEDULESFORELECTRICSERVICE
Submitted Under Advice Letter No. 06-06
ISSUED: August 14, 2006
Issuing Officer
D. Douglas Larson
Vice President, Regulation
Salt Lake City, UT
EFFECTIVE: September 15, 2006

Fifth Revision of Sheet No. B.1 I.P.U.C. No. 1 Canceling Fourth Revision of Sheet No. B.1

Submitted Under Case No. PAC-E-21-07 ISSUED: November 8, 2021 EFFECTIVE: January 1, 2022
ROCKY MOUNTAIN POWER ELECTRIC SERVICE SCHEDULES STATE OF IDAHO
Schedule Sheet No. Class of Service No.
1 Residential Service 1.1 & 1.2 6 General Service - Large Power 6.1 - 6.3
6A General Service - Large Power (Residential and Farm) 6A.1 - 6A.4 7 Security Area Lighting 7.1 - 7.2 7A Security Area Lighting (Residential and Farm) 7A.1 - 7A.3 9 General Service - High Voltage 9.1 - 9.3 10 Irrigation and Soil Drainage Pumping Power Service 10.1 - 10.4
11 Street Lighting Service- Company-Owned System 11.1 - 11.3 12 Street and Security Area Lighting Service- Consumer-Owned System 12.1 - 12.5
14 Temporary Service Connection Facilities – No New Service* 14
21 Low Income Weatherization Services 21.1 - 21.6 (Continued)
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Feb. 1, 2022 Jan. 1, 2022
Per O.N. 35277
Jan Noriyuki Secretary

Fourteenth Revision of Sheet No. B.2
I.P.U.C. No. 1 Canceling Thirteenth Revision of Sheet No. B.2

ELECTRIC SERVICE SCHEDULES - Continued
Schedule Sheet
No. Class of Service No.

23 General Service - Small Power 23.1 - 23.3

23A General Service - Small Power (Residential and Farm) 23A.1 - 23A.4

24 Interruptible Power Service 24.1 - 24.5

31 Partial Requirements Service – High Voltage 31.1 – 31.6

34 Pacific Northwest Electric Power Planning and Conservation Act - 34.1 - 34.3
Residential and Farm Kilowatt-Hour Credit

35 Optional Time-of-Day General Service – Distribution Voltage 35.1 - 35.3

35A Optional Time-of-Day General Service – Distribution Voltage (Farm) 35A.1 -35A.4
38 Qualifying Facility Avoided Cost Procedures 38.1 – 38.11

36 Optional Time of Day Residential Service 36.1 - 36.3

70 Renewable Energy Rider – Optional 70.1 - 70.4

73 Renewable Energy Rider - Optional - Bulk Purchase Option 73.1 – 73.4

94 Energy Cost Adjustment 94.1

118 Home Energy Saver Incentive Program 118.1 - 118.2

(Continued)
Submitted Under Advice No. 16-04

ISSUED: April 20, 2016 EFFECTIVE: April 15, 2016
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
May 2, 2016 April 15, 2016
Per O.N. 33474
Jean D. Jewell Secretary

I.P.U.C. No. 1 Sixth Revision of Sheet No. B.3 Canceling Fifth Revision of Sheet No. B.3

Submitted Under Case No. PAC-E-21-07 ISSUED: November 8, 2021 EFFECTIVE: January 1, 2022
ELECTRIC SERVICE SCHEDULES - Continued Schedule Sheet No. Class of Service No. 135 Net Metering Service 135.1 - 135.3
136 Net Billing Service 136.1 - 136.4 140 Non-Residential Energy Efficiency 140.1 - 140.3 191 Customer Efficiency Services Rate Adjustment 191
197 Federal Tax Act Adjustment 197 300 Regulation Charges 300.1 - 300.4
400 Special Contract 400.1
Schedule numbers not listed are not currently used. * These schedules are not available to new customers or premises.

IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Feb. 1, 2022 Jan. 1, 2022
Per O.N. 35277
Jan Noriyuki Secretary

Twelfth Revision of Sheet No. 1.1 I.P.U.C. No. 1 Canceling Eleventh Revision of Sheet No. 1.1

Submitted Under Case No. PAC-E-22-15
ISSUED: June 9, 2023 EFFECTIVE: June 1, 2023
ROCKY MOUNTAIN POWER ELECTRIC SERVICE SCHEDULE NO. 1
STATE OF IDAHO
______________ Residential Service ______________
AVAILABILITY: At any point on the Company's interconnected system where there are facilities of adequate capacity.
APPLICATION: This Schedule is for alternating current electric service supplied at approximately 120 or 240 volts through one kilowatt-hour meter at a single point of delivery for all service required on the premises for Residential purposes. When conditions are such that service is supplied through one meter to more than one dwelling or apartment unit, the charge for such service will be computed by multiplying the minimum charges by the maximum number of dwelling or apartment units that may be served.
When a portion of a dwelling is used regularly for business, professional or other gainful purposes, the premises will be classified as nonresidential and the appropriate schedule applied. However, if the
wiring is so arranged that the service for Residential purposes can be metered separately, this Schedule will be applied to such service.
MONTHLY BILL: Year 1 Year 2 Year 3 Year 4 Year 5 6/1/2023 6/1/2024 6/1/2025 6/1/2026 6/1/2027 to to to to5/31/2024 5/31/2025 5/31/2026 5/31/2027Customer Service Charge
Energy Charge (¢/kWh)
Seasonal Service Charge
(Continued)
IDAHO PUBLIC UTILITIES COMMISSIONApproved EffectiveJuly 6, 2023 June 1, 2023 Per ON 35843 Jan Noriyuki Secretary

Twelfth Revision of Sheet No. 1.2 I.P.U.C. No. 1 Canceling Eleventh Revision of Sheet No. 1.2

Submitted Under Case No. PAC-E-22-15
ISSUED: June 9, 2023 EFFECTIVE: June 1, 2023
ELECTRIC SERVICE SCHEDULE NO. 1 – Continued
MONTHLY BILLING REDUCTION: Rates in this schedule shall be reduced by the monthly kilowatt-hour credit adjustment set forth under “Monthly Rates” in the currently effective Electric Service Schedule No. 34. SEASONAL SERVICE: When seasonal service is supplied under this Schedule, the minimum seasonal charge will be applied plus energy charges. CONTRACT PERIOD: One year or longer.
ELECTRIC SERVICE REGULATIONS: Service under this Schedule will be in accordance with the terms of the Electric Service Agreement between the Customer and the Company. The Electric Service Regulations of the Company on file with and approved by the Idaho Public Utilities Commission, including
future applicable amendments, will be considered as forming a part of and incorporated in said Agreement.

IDAHO PUBLIC UTILITIES COMMISSIONApproved EffectiveJuly 6, 2023 June 1, 2023 Per ON 35843 Jan Noriyuki Secretary
Ninth Revision of Sheet No. 6.1 I.P.U.C. No. 1 Canceling Eighth Revision of Sheet No. 6.1

Submitted Under Case No. PAC-E-21-07 ISSUED: November 8, 2021 EFFECTIVE: January 1, 2022
ROCKY MOUNTAIN POWER ELECTRIC SERVICE SCHEDULE NO. 6 STATE OF IDAHO ______________
General Service - Large Power ______________
AVAILABILITY: At any point on the Company's interconnected system where there are facilities
of adequate capacity. APPLICATION: This Schedule is for alternating current, single or three-phase electric service supplied at Company's available voltage through one metering installation at a single point of delivery for all service required on the premises. MONTHLY BILL: Rate: Billing Months June through October, Inclusive Billing Months November through May, Inclusive : Secondary voltage
delivery (Less than 2300 volts) $ 38.00 per Customer $ 38.00 per Customer
Primary voltage
delivery (2300 volts or higher) $ 114.00 per Customer $ 114.00 per Customer
: $ 13.62 per kW for all kW $ 12.27 per kW for all kW : 4.2506¢ per kWh for all kWh 4.2506¢ per kWh for all kWh (Continued)
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Feb. 1, 2022 Jan. 1, 2022
Per O.N. 35277
Jan Noriyuki Secretary

Fifth Revision of Sheet No. 6.2 I.P.U.C. No. 1 Canceling Fourth Revision of Sheet No. 6.2

Submitted Under Case No. PAC-E-21-07 ISSUED: November 8, 2021 EFFECTIVE: January 1, 2022
ELECTRIC SERVICE SCHEDULE NO. 6 - Continued Power Factor: This rate is based on the Customer maintaining at all times a power factor of 85% lagging, or higher, as determined by measurement. If the average power factor is found to be less
than 85% lagging, the Power as recorded by the Company's meter will be increased by 3/4 of 1% for every 1% that the power factor is less than 85%.
Voltage Discount: Where Customer takes service from Company's available lines of 2300 volts or higher and provides and maintains all transformers and other necessary equipment, the voltage discount
based on measured Power will be: $0.65 per kW for all kW of Power Minimum Bill: The Customer Service Charge. POWER: The kW as shown by or computed from the readings of Company's Power meter for the 15-minute period of Customer's greatest use during the month, determined to the nearest kW. SEASONAL SERVICE: Service for annually recurring periods of seasonal use where service is normally discontinued or curtailed during a part of the year may be contracted for under this Schedule under
either of the following conditions: (a) Customer may contract for service under this Schedule on a year-round basis paying for all
service, including transformer losses where applicable, under the rates set forth under "Monthly Bill" above including the monthly minimum bill during those months service is curtailed or is not utilized in the Customer's operation.
(b) Customer may contract for seasonal service under this Schedule with a net minimum seasonal payment as follows: $ 456.00 plus Power and Energy Charges for Customer taking service at less than 2300 volts and $ 1,368.00 plus Power and Energy Charges for Customer taking service at 2300 volts or higher. (Continued)
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Feb. 1, 2022 Jan. 1, 2022
Per O.N. 35277
Jan Noriyuki Secretary
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Aug. 28, 2006 Sept. 15, 2006
Jean D. Jewell Secretary
I.P.U.C. No.1
ELECTRIC SERVICE SCHEDULE NO. 6 -Continued
CONTRACT PERIOD: One year or longer.
Original Sheet No. 6.3
ELECTRIC SERVICE REGULATIONS: Service under this Schedule will be in accordance with
the terms of the Electric Service Agreement between the Customer and the Company. The Electric Service
Regulations of the Company on file with and approved by the Idaho Public Utilities Commission, including
future applicable amendments, will be considered as forming a part of and incorporated in said Agreement.
Submitted Under Advice Letter No. 06-06
ISSUED: August 14, 2006 EFFECTIVE: September 15, 2006

Ninth Revision of Sheet No. 6A.1 I.P.U.C. No. 1 Canceling Eighth Revision of Sheet No. 6A.1

Submitted Under Case No. PAC-E-21-07 ISSUED: November 8, 2021 EFFECTIVE: January 1, 2022
ROCKY MOUNTAIN POWER ELECTRIC SERVICE SCHEDULE NO. 6A STATE OF IDAHO
______________ General Service - Large Power (Residential and Farm) ______________ AVAILABILITY: At any point on the Company's interconnected system where there are facilities of adequate capacity for service to any customer who qualifies as a "Residential Load" or "Farm Load" under both (1) the Pacific Northwest Electric Power Planning and Conservation Act, P.L. 96-501 as the same may be amended, and (2) a Residential Purchase and Sale Agreement, under Section 5(c) of such Act and in effect between the Company and the Bonneville Power Administration. APPLICATION: This Schedule is for alternating current, single or three-phase electric service supplied at Company's available voltage through one metering installation at a single point of delivery for all service required on the premises. MONTHLY BILL:
Customer Service
Charge
Power Rate
Energy Rate (Continued)
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Feb. 1, 2022 Jan. 1, 2022
Per O.N. 35277
Jan Noriyuki Secretary

Third Revision of Sheet No. 6A.2
I.P.U.C. No. 1 Canceling Second Revision of Sheet No. 6A.2

Submitted Under Advice No. 12-03

ISSUED: October 19, 2012 EFFECTIVE: January 1, 2013
ELECTRIC SERVICE SCHEDULE NO. 6A - Continued

Power Factor:
This rate is based on the Customer maintaining at all times a power factor of 85% lagging,
or higher, as determined by measurement. If the average power factor is found to be less
than 85% lagging, the Power as recorded by the Company's meter will be increased by 3/4
of 1% for every 1% that the power factor is less than 85%.

Voltage Discount:
Where Customer takes service from Company's available lines of 2300 volts or higher and
provides and maintains all transformers and other necessary equipment, the voltage discount
based on measured Power will be:
$0.65 per kW for all kW of Power

Minimum Bill:
The Customer Service Charge.

MONTHLY BILLING REDUCTION: Rates in this Schedule shall be reduced by the monthly
kilowatt-hour credit adjustment set forth under "Monthly Rates" in the currently effective Electric Service
Schedule No. 34.

POWER: The kW as shown by or computed from the readings of Company's Power meter for the
15-minute period of Customer's greatest use during the month, determined to the nearest kW.

SEASONAL SERVICE: Service for annually recurring periods of seasonal use where service is
normally discontinued or curtailed during a part of the year may be contracted for under this Schedule under
either of the following conditions:

(a) Customer may contract for service under this Schedule on a year-round basis paying for all
service, including transformer losses where applicable, under the rates set forth under
"Monthly Bill" above including the monthly minimum bill during those months service is
curtailed or is not utilized in the Customer's operation.

(Continued)
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Oct. 29, 2012 Jan. 1, 2013
Jean D. Jewell Secretary

Fifth Revision of Sheet No. 6A.3 I.P.U.C. No. 1 Canceling Fourth Revision of Sheet No. 6A.3

Submitted Under Case No. PAC-E-21-07 ISSUED: November 8, 2021 EFFECTIVE: January 1, 2022
ELECTRIC SERVICE SCHEDULE NO. 6A - Continued SEASONAL SERVICE: (continued) (b) Customer may contract for seasonal service under this Schedule with a net minimum seasonal payment as follows:
$ 456.00 plus Power and Energy Charges for Customer taking service at less than 2300 volts and
$1,368.00 plus Power and Energy Charges for Customer taking service at 2300 volts or higher.
CONTRACT PERIOD: One year or longer. SPECIAL CONDITION: Domestic use means all usual residential, apartment, seasonal dwelling, and mobile home court use including domestic water pumping. Farm use means all usual farm electrical loads for raising of crops, livestock or pasturage and includes primary processing necessary for safe and efficient storage or shipment and irrigation pumping. Contiguous parcels land under single-ownership or leasehold shall be considered to be one Farm and noncontiguous parcels of land under single-ownership or leasehold shall be considered as one Farm unit when operated as a single Farm, unless demonstrated otherwise by the owner or lessee of the parcels.
A number of factors shall determine whether contiguous or noncontiguous parcels constitute one or more Farms. These factors shall include, but are not limited to:
-- size -- use -- ownership
-- control -- operating practices -- distance between parcels -- custom in the trade -- billing treatment by the utility Operators of Farms may be required to certify to the utility all irrigation accounts, including horsepower rating. (Continued)
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Feb. 1, 2022 Jan. 1, 2022
Per O.N. 35277
Jan Noriyuki Secretary
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Aug. 28, 2006 Sept. 15, 2006
Jean D. Jewell Secretary
I.P.U.C. No. 1 Original Sheet No. 6A.4
ELECTRIC SERVICE SCHEDULE NO. 6A -Continued
SPECIAL CONDITION: (continued)
Customers who feel they meet the definitions of a Farm will have to make application with
the Company for review. If Customer application is denied by the Company, the Customer may appeal the
decision to the Idaho Public Utilities Commission.
ELECTRIC SERVICE REGULATIONS: Service under this Schedule will be in accordance with
the terms of the Electric Service Agreement between the Customer and the Company. The Electric Service
Regulations of the Company on file with and approved by the Idaho Public Utilities Commission, including
future applicable amendments, will be considered as forming a part of and incorporated in said Agreement.
Submitted Under Advice Letter No. 06-06
ISSUED: August 14, 2006 EFFECTIVE: September 15, 2006

Tenth Revision of Sheet No. 7.1
I.P.U.C. No. 1 Canceling Ninth Revision of Sheet No. 7.1

Submitted Under Tariff Advice No. 22-01

ISSUED: April 20, 2022 EFFECTIVE: July 1, 2022
ROCKY MOUNTAIN POWER

ELECTRIC SERVICE SCHEDULE NO. 7

STATE OF IDAHO

______________

Security Area Lighting
______________

AVAILABILITY: At any point on the Company's interconnected system. Lights installed on a
structure other than an existing distribution pole are closed to new service.

APPLICATION: This Schedule is for electric service required for Security Area Lighting and for
Security Flood Lighting service where service is supplied from a Company-owned pole.

MONTHLY BILL:

Rate:

Light Level LED Equivalent Lumen Range
Monthly
kWh Total
Level 1 <=5,500 19 $12.96
Level 2 5,501-12,000 34 $14.72
Level 3 >12,000 57 $17.48

(Continued)

IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
June 1, 2022 July 1, 2022
Jan Noriyuki Secretary
Seventh Revision of Sheet No. 7.2 I.P.U.C. No. 1 Canceling Sixth Revision of Sheet No. 7.2

Submitted Under Case No. PAC-E-21-07 ISSUED: November 8, 2021 EFFECTIVE: January 1, 2022
ELECTRIC SERVICE SCHEDULE NO. 7 – Continued MONTHLY BILL: (continued) SPECIFICATIONS AND SERVICE FOR SECURITY AREA LIGHTING: Security flood lights may be mounted on Company-owned poles or on Customer-owned supports acceptable to the Company. The type and kind of fixtures and supports will be in accord-
ance with the Company's specifications. Service includes energy supplied from the Company's overhead circuits, maintenance and lamp and glassware renewals. Lamps will be controlled by the Company to burn each night from dusk to dawn.
CONVERSIONS: The Company, upon written request of customer, will convert existing street lighting facilities to other types of lamps (i.e., convert mercury vapor fixtures and
lamps to sodium vapor fixtures and lamps, etc.). In such an event, customer shall pay to Company an amount equal to the depreciated value of all Company-owned facilities removed from service and replaced with new equipment plus the cost of removal less any salvage value. Priority in making conversions shall be determined by the order in which requests are received by the Company. CONTRACT PERIOD: Five years or longer. PROVISIONS 1. Inoperable lights will be repaired as soon as reasonably possible, during regular business hours or as allowed by company’s operating schedule and requirements, provided the Company receives notification of inoperable lights from Customer or a member of the public by either notifying Rocky
Mountain Power’s customer service (1-888-221-7070) or www.rockymountainpower.net/streetlights Rocky Mountain Power’s obligation to repair lights is limited to this tariff. 2. The Company reserves the right to contract for the maintenance of lighting service provided
hereunder. 3. Temporary disconnection and subsequent reconnection of electrical service requested by the Customer shall be at the Customer’s expense. The Customer may request temporary suspension of
power for lighting by written notice. During such periods, the monthly rate will be reduced by the Company’s estimated average monthly relamping and energy costs for the luminaire. The facilities may be considered idle and may be removed after 12 months of inactivity.
4. Pole re-painting, when requested by the Customer and not required for safety reasons, shall be done at the Customer’s expense, using the original pole color. 5. Glare or vandalism shielding, when requested by the Customer, and subject to availability, shall be installed at the Customer’s expense. In cases of repetitive vandalism, the Company may notify the Customer of the need to install vandal shields at the Customer’s expense, or otherwise have the lighting removed. ELECTRIC SERVICE REGULATIONS: Service under this Schedule will be in accordance with the terms of the Electric Service Agreement between the Customer and the Company. The Electric Service Regulations of the Company on file with and approved by the Idaho Public Utilities Commission, including future applicable amendments, will be considered as forming a part of and incorporated in said Agreement.
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Feb. 1, 2022 Jan. 1, 2022
Per O.N. 35277
Jan Noriyuki Secretary
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Aug. 28, 2006 Sept. 15, 2006
Jean D. Jewell Secretary
ROCKY MOUNTAIN
POWER
A DIVISION OF PACIFICORP
I.P.U.C. No. 1 Original Sheet No. 7 .3
ELECTRIC SERVICE SCHEDULE NO. 7 -Continued
MONTHLY BILL: ( continued)
The unit charge includes installation, maintenance and energy costs for unit on existing or
one new wood pole without guys. Where more than one wood pole and more than 200 feet
of extension are required, an additional charge of 1.5% of the estimated additional cost will
be made. Should Customer desire a steel pole instead of a wood pole, an additional charge
will be made according to the following schedule:
1. All steel poles installed prior to June 1, 1973.
11 gauge $1.00 per pole per month
3 gauge $1.50 per pole per month
2. Steel poles installed after June 1, 1973.
30 ft., 11 gauge, direct buried $2.35 per pole per month
30 ft., 3 gauge, direct buried $3.95 per pole per month
35 ft., 11 gauge, direct buried $2.85 per pole per month
35 ft., 3 gauge, direct buried $4.65 per pole per month
For anchor base poles, add 20¢ per pole per month to all poles
installed after June 1, 1973.
SPECIFICATIONS AND SERVICE FOR SECURITY AREA LIGHTING: Security
flood lights may be mounted on Company-owned poles or on Customer-owned supports
acceptable to the Company. The type and kind of fixtures and supports will be in accord­
ance with the Company's specifications. Service includes energy supplied from the
Company's overhead circuits, maintenance and lamp and glassware renewals. Lamps will
be controlled by the Company to bum each night from dusk to dawn.
CONVERSIONS: The Company, upon written request of customer, will convert existing
street lighting facilities to other types of lamps (i.e., convert mercury vapor fixtures and
lamps to sodium vapor fixtures and lamps, etc.). In such an event, customer shall pay to
Company an amount equal to the depreciated value of all Company-owned facilities
removed from service and replaced with new equipment plus the cost of removal less any
salvage value. Priority in making conversions shall be determined by the order in which
requests are received by the Company.
CONTRACT PERIOD: Five years or longer.
(Continued)
Submitted Under Advice Letter No. 06-06
ISSUED: August 14, 2006 EFFECTIVE: September 15, 2006
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Dec. 14, 2016 Jan. 1, 2017
Per O.N. 33668
Diane M. Hanian Secretary ROCKY MOUNTAIN
POWER
A DIVISION 01' PACIFICOIIP
I.P.U.C. No. 1
Eighth Revision of Sheet No. 7.4
Canceling Seventh Revision of Sheet No. 7.4
ELECTRIC SERVICE SCHEDULE NO. 7 -Continued
MONTHLY BILL: (continued)
(2) Customer-Owned/Customer-Maintained Area Lighting
Energy Only (No New Service):
Initial Lumens
16,000 Sodium Vapor Flood
CONTRACT PERIOD: One year or longer.
PROVISIONS
Watts
150
Per Lamp
$15.13
I. Inoperable lights will be repaired as soon as reasonably possible, during regular business hours or as
allowed by company's operating schedule and requirements, provided the Company receives
notification of inoperable lights form Customer or a member of the public by either notifying Rocky
Mountain Power's customer service (1-888-221-7070) or www.rockymountainpower.net/streetlights.
Rocky Mountain Power's obligation to repair lights is limited to this tariff.
2. The Company reserves the right to contract for the maintenance of lighting service provided
hereunder.
3. Temporary disconnection and subsequent reconnection of electrical service requested by the
Customer shall be at the Customer's expense. The Customer may request temporary suspension of
power for lighting by written notice. During such periods, the monthly rate will be reduced by the
Company's estimated average monthly relamping and energy costs for the luminaire. The facilities
may be considered idle and may be removed after 12 months of inactivity.
4. Pole re-painting, when requested by the Customer and not required for safety reasons, shall be done
at the Customer's expense, using the original pole color.
5. Glare or vandalism shielding, when requested by the Customer, and subject to availability, shall be
installed at the Customer's expense. In cases of repetitive vandalism, the Company may notify the
Customer of the need to install vandal shields at the Customer's expense, or otherwise have the
lighting removed.
ELECTRIC SERVICE REGULATIONS: Service under this Schedule will be in accordance with
the terms of the Electric Service Agreement between the Customer and the Company. The Electric Service
Regulations of the Company on file with and approved by the Idaho Public Utilities Commission, including
future applicable amendments, will be considered as forming a part of and incorporated in said Agreement.
Submitted Under Case No. PAC-E-16-12
ISSUED: November 11, 2016 EFFECTIVE: January I, 2017

Ninth Revision of Sheet No. 7A.1
I.P.U.C. No. 1 Canceling Eighth Revision of Sheet No. 7A.1

Submitted Under Tariff Advice No. 22-01

ISSUED: April 20, 2022 EFFECTIVE: July 1, 2022
ROCKY MOUNTAIN POWER

ELECTRIC SERVICE SCHEDULE NO. 7A

STATE OF IDAHO

______________

Security Area Lighting (Residential and Farm)
______________

AVAILABILITY: At any point on the Company's interconnected system for service to any
customer who qualifies as a "Residential Load" or "Farm Load" under both (1) the Pacific Northwest
Electric Power Planning and Conservation Act, P.L. 96-501 as the same may be amended, and (2) a
Residential Purchase and Sale Agreement, under Section 5(c) of such Act and in effect between the
Company and the Bonneville Power Administration. Lights installed on a structure other than an existing
distribution pole are closed to new service.

APPLICATION: This Schedule is for electric service required for Security Area Lighting and for
Security Flood Lighting service where service is supplied from a Company-owned pole.

MONTHLY BILL:

Rate:

Light Level LED Equivalent Lumen Range
Monthly
kWh Total
Level 1 <=5,500 19 $12.96
Level 2 5,501-12,000 34 $14.72
Level 3 >12,000 57 $17.48

MONTHLY BILLING REDUCTION: Rates in this Schedule shall be reduced by the monthly
kilowatt-hour credit adjustment set forth under "Monthly Rates" in the currently effective Electric Service
Schedule No. 34.

SPECIFICATIONS AND SERVICE FOR SECURITY AREA LIGHTING: Security flood
lights may be mounted on Company-owned poles or on Customer-owned supports acceptable to the
Company. The type and kind of fixtures and supports will be in accordance with the Company's
specifications. Service includes energy supplied from the Company's overhead circuits, maintenance and
lamp and glassware renewals. Lamps will be controlled by the Company to burn each night from dusk to
dawn.

IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
June 1, 2022 July 1, 2022
Jan Noriyuki Secretary

Eighth Revision of Sheet No. 7A.2
I.P.U.C. No. 1 Canceling Seventh Revision of Sheet No. 7A.2

Submitted Under Tariff Advice No. 22-01

ISSUED: April 20, 2022 EFFECTIVE: July 1, 2022
ELECTRIC SERVICE SCHEDULE NO. 7A - Continued

MONTHLY BILL: (continued)
CONTRACT PERIOD: Five years or longer.

SPECIAL CONDITION: Domestic use means all usual residential, apartment, seasonal dwelling,
and mobile home court use including domestic water pumping. Farm use means all usual farm electrical
loads for raising of crops, livestock or pasturage and includes primary processing necessary for safe and
efficient storage or shipment and irrigation pumping.

Contiguous parcels of land under single-ownership or leasehold shall be considered to be one Farm
and noncontiguous parcels of land under single-ownership or leasehold shall be considered as one Farm unit
when operated as a single Farm, unless demonstrated otherwise by the owner or lessee of the parcels.

A number of factors shall determine whether contiguous or noncontiguous parcels constitute one or more
Farms. These factors shall include, but are not limited to:

-- size
-- use
-- ownership
-- control
-- operating practices
-- distance between parcels
-- custom in the trade
-- billing treatment by the utility

Operators of Farms may be required to certify to the utility all irrigation accounts, including
horsepower rating.

(Continued)

IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
June 1, 2022 July 1, 2022
Jan Noriyuki Secretary

First Revision of Sheet No. 7A.3 I.P.U.C. No. 1 Canceling Original Sheet No. 7A.3

Submitted Under Case No. PAC-E-21-07 ISSUED: November 8, 2021 EFFECTIVE: January 1, 2022
ELECTRIC SERVICE SCHEDULE NO. 7A - Continued SPECIAL CONDITION: (continued) Customers who feel they meet the definitions of a Farm will have to make application with the Company for review. If Customer application is denied by the Company, the Customer may appeal the
decision to the Idaho Public Utilities Commission. PROVISIONS
1. Inoperable lights will be repaired as soon as reasonably possible, during regular business hours or as allowed by company’s operating schedule and requirements, provided the Company receives notification of inoperable lights from Customer or a member of the public by either notifying Rocky
Mountain Power’s customer service (1-888-221-7070) or www.rockymountainpower.net/streetlights Rocky Mountain Power’s obligation to repair lights is limited to this tariff. 2. The Company reserves the right to contract for the maintenance of lighting service provided hereunder. 3. Temporary disconnection and subsequent reconnection of electrical service requested by the Customer shall be at the Customer’s expense. The Customer may request temporary suspension of
power for lighting by written notice. During such periods, the monthly rate will be reduced by the Company’s estimated average monthly relamping and energy costs for the luminaire. The facilities may be considered idle and may be removed after 12 months of inactivity. 4. Pole re-painting, when requested by the Customer and not required for safety reasons, shall be done at the Customer’s expense, using the original pole color. 5. Glare or vandalism shielding, when requested by the Customer, and subject to availability, shall be installed at the Customer’s expense. In cases of repetitive vandalism, the Company may notify the Customer of the need to install vandal shields at the Customer’s expense, or otherwise have the
lighting removed. ELECTRIC SERVICE REGULATIONS: Service under this Schedule will be in accordance with
the terms of the Electric Service Agreement between the Customer and the Company. The Electric Service Regulations of the Company on file with and approved by the Idaho Public Utilities Commission, including future applicable amendments, will be considered as forming a part of and incorporated in said Agreement.
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Feb. 1, 2022 Jan. 1, 2022
Per O.N. 35277
Jan Noriyuki Secretary
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
April 27, 2012 April 24, 2012
Per O.N. 32519
Jean D. Jewell Secretary
I.P.U.C. No. 1
Third Revision of Sheet No. 7 A.4
Canceling Second Revision of Sheet No. 7 A.4
ELECTRIC SERVICE SCHEDULE NO. 7 A -Continued
MONTHLY BILL: ( continued)
CONTRACT PERIOD: One year or longer.
SPECIAL CONDITION: Domestic use means all usual residential, apartment, seasonal dwelling,
and mobile home court use including domestic water pumping. Farm use means all usual farm electrical
loads for raising of crops, livestock or pasturage and includes primary processing necessary for safe and
efficient storage or shipment and irrigation pumping.
Contiguous parcels of land under single-ownership or leasehold shall be considered to be one Farm
and noncontiguous parcels of land under single-ownership or leasehold shall be considered as one Farm unit
when operated as a single Farm, unless demonstrated otherwise by the owner or lessee of the parcels.
A number of factors shall determine whether contiguous or noncontiguous parcels constitute one or more
Farms. These factors shall include, but are not limited to:
size
use
ownership
control
operating practices
distance between parcels
custom in the trade
billing treatment by the utility
Operators of Farms may be required to certify to the utility all irrigation accounts, including
horsepower rating.
Submitted Under Case No. PAC-E-12-04
ISSUED: January 18, 2012
(Continued)
EFFECTIVE: April 24, 2012

Second Revision of Sheet No. 7A.5
I.P.U.C. No. 1 Canceling First Revision of Sheet No. 7A.5

Submitted Under Advice No. 16-03

ISSUED: February 10, 2016 EFFECTIVE: March 15, 2016
ELECTRIC SERVICE SCHEDULE NO. 7A - Continued

SPECIAL CONDITION: (continued)
Customers who feel they meet the definitions of a Farm will have to make application with the
Company for review. If Customer application is denied by the Company, the Customer may appeal the
decision to the Idaho Public Utilities Commission.

PROVISIONS
1. Inoperable lights will be repaired as soon as reasonably possible, during regular business hours or as
allowed by company’s operating schedule and requirements, provided the Company receives
notification of inoperable lights from Customer or a member of the public by either notifying Rocky
Mountain Power’s customer service (1-888-221-7070) or www.rockymountainpower.net/streetlights
Rocky Mountain Power’s obligation to repair lights is limited to this tariff.
2. The Company reserves the right to contract for the maintenance of lighting service provided
hereunder.
3. Temporary disconnection and subsequent reconnection of electrical service requested by the
Customer shall be at the Customer’s expense. The Customer may request temporary suspension of
power for lighting by written notice. During such periods, the monthly rate will be reduced by the
Company’s estimated average monthly relamping and energy costs for the luminaire. The facilities
may be considered idle and may be removed after 12 months of inactivity.
4. Pole re-painting, when requested by the Customer and not required for safety reasons, shall be done
at the Customer’s expense, using the original pole color.
5. Glare or vandalism shielding, when requested by the Customer, and subject to availability, shall be
installed at the Customer’s expense. In cases of repetitive vandalism, the Company may notify the
Customer of the need to install vandal shields at the Customer’s expense, or otherwise have the
lighting removed.

ELECTRIC SERVICE REGULATIONS: Service under this Schedule will be in accordance with
the terms of the Electric Service Agreement between the Customer and the Company. The Electric Service
Regulations of the Company on file with and approved by the Idaho Public Utilities Commission, including
future applicable amendments, will be considered as forming a part of and incorporated in said Agreement.

.
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Feb. 22, 2016 March 15, 2016
Jean D. Jewell Secretary

First Revision of Sheet No. 9.1 I.P.U.C. No. 1 Canceling Original Sheet No. 9.1

Submitted Under Case No. PAC-E-21-07 ISSUED: November 8, 2021 EFFECTIVE: January 1, 2022
ROCKY MOUNTAIN POWER ELECTRIC SERVICE SCHEDULE NO. 9 STATE OF IDAHO
______________ General Service -- High Voltage ______________ AVAILABILITY: At any point on the Company's interconnected system where there are facilities of adequate capacity. APPLICATION: This Schedule is for alternating current, three phase electric service supplied at approximately 44,000 volts or 69,000 volts or greater, through a single point of delivery, for all service required on the Customer's premises by customers contracting for not less than 80 kW nor more than 30,000 kW. Seasonal service will be available only under other appropriate schedules. Service under this Schedule is limited to a maximum power requirement of 30,000 kW. When a Customer's load reaches a level in excess of 30,000 kW, continued service will require special contract arrangements; provided, however, that special contract arrangements will not be required in those cases where electric service is being supplied by Company under this Schedule to operations existing as of the effective date of this Schedule which, because
of emergency conditions, or which on sporadic occasions only, may exceed 30,000 kW. This Schedule is not available to new loads in excess of 30,000 kW nor to existing operations whose maximum power requirement, because of increased operations, plant expansion or equipment additions, exceeds 30,000 kW.
In this latter case, a maximum power requirement in excess of 30,000 kW shall be deemed to exist when a Customer's maximum power requirement exceeds 30,000 kW in at least three (3) months of any continuous period of six (6) successive months.
(Continued)
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Feb. 1, 2022 Jan. 1, 2022
Per O.N. 35277
Jan Noriyuki Secretary

Ninth Revision of Sheet No. 9.2 I.P.U.C. No. 1 Canceling Eighth Revision of Sheet No. 9.2

Submitted Under Case No. PAC-E-21-07 ISSUED: November 8, 2021 EFFECTIVE: January 1, 2022
ELECTRIC SERVICE SCHEDULE NO. 9 - Continued MONTHLY BILL: Rate:
Customer Service Charge
Power Rate
Energy Rate On-Peak Off-Peak
5.1115¢ 3.9086¢
per kWh per kWh
4.6365¢ 3.5213¢
per kWh per kWh
TIME PERIODS: On-Peak: November through May inclusive
6:00 a.m. to 9:00 a.m. and 6:00 p.m. to 11:00 p.m., all days. June through October inclusive 3:00 p.m. to 11:00 p.m., all days. Off-Peak: All other times.
Power Factor: This rate is based on the Customer maintaining at all times a power factor of 85% lagging, or higher, as determined by measurement. If the average power factor is found to be less than 85% lagging, the Power as recorded by the Company's meter will be increased by 3/4
of 1% for every 1% that the power factor is less than 85%. Minimum:
The Customer Service Charge plus the minimum Power Charge and appropriate Energy Charges. (continued)

IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Feb. 1, 2022 Jan. 1, 2022
Per O.N. 35277
Jan Noriyuki Secretary

I.P.U.C. No. 1 Original Sheet No. 9.3

Submitted Under Case No. PAC-E-21-07 ISSUED: November 8, 2021 EFFECTIVE: January 1, 2022
ELECTRIC SERVICE SCHEDULE NO. 9 - Continued MONTHLY BILL (continued): POWER: The kW as shown by or computed from the readings of Company's Power meter for the 15-minute period of Customer's greatest use during the month, adjusted for power factor as specified,
determined to the nearest kW, but not less than 80 kW. CONTRACT PERIOD: One year or longer.
ELECTRIC SERVICE REGULATIONS: Service under this Schedule will be in accordance with the terms of the Electric Service Agreement between the Customer and the Company. The Electric Service
Regulations of the Company on file with and approved by the Idaho Public Utilities Commission, including future applicable amendments, will be considered as forming a part of and incorporated in said Agreement.
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Feb. 1, 2022 Jan. 1, 2022
Per O.N. 35277
Jan Noriyuki Secretary

Sixth Revision of Sheet No. 10.1
I.P.U.C. No. 1 Canceling Fifth Revision of Sheet No. 10.1

Submitted Under Advice No. 12-03

ISSUED: October 19, 2012 EFFECTIVE: January 1, 2013
ROCKY MOUNTAIN POWER

ELECTRIC SERVICE SCHEDULE NO. 10

STATE OF IDAHO

______________

Irrigation and Soil Drainage Pumping Power Service
______________

AVAILABILITY: At any point on the Company's interconnected system where there are facilities
of adequate capacity.

APPLICATION: This Schedule is for alternating current, single or three-phase electric service
supplied at the Company's available voltage through a single point of delivery for service to motors on
pumps and machinery used for irrigation and soil drainage.

IRRIGATION SEASON AND POST-SEASON SERVICE: The Irrigation Season is from June 1
to September 15 each year. Service for post-season pumping may be taken by the same Customer at the
same point of delivery and through the same facilities used for supplying regular irrigation pumping service
during months from September 16 to the following May 31.

MONTHLY BILL:

Irrigation Season Rate
Customer Service Charge:
Small Pumping Operations:
15 horsepower or less total connected horsepower
served through one service connection - $14.00 per Customer

Large Pumping Operations:
16 horsepower or more total connected horsepower
served through one service connection - $41.00 per Customer

(Continued)
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Oct. 29, 2012 Jan. 1, 2013
Jean D. Jewell Secretary

Eleventh Revision of Sheet No. 10.2 I.P.U.C. No. 1 Canceling Tenth Revision of Sheet No. 10.2

Submitted Under Case No. PAC-E-21-07 ISSUED: November 8, 2021 EFFECTIVE: January 1, 2022
ELECTRIC SERVICE SCHEDULE No. 10 - Continued MONTHLY BILL: (Continued) Power Rate: $5.96 per kW for all kW Energy Rate: 8.8388¢ per kWh for first 25,000 kWh 6.6054¢ per kWh for the next 225,000 kWh
4.9435¢ per kWh for all additional kWh Power Factor: This rate is based on the Customer maintaining at all times a power factor
of 85% lagging, or higher, as determined by measurement. If the average power factor is found to be less than 85% lagging, the power as recorded by the Company's meter will be increased by 3/4 of 1% for every 1% that the power factor is less than 85%. Minimum: The Customer Service Charge. Post-Season Rate Customer Service Charge: $23.00 per Customer Energy Rate: 7.5110¢ per kWh for all kWh Minimum: The Customer Service Charge. ADJUSTMENTS: All monthly bills shall be adjusted in accordance with Schedules 34 and 94.
PAYMENT: All monthly service billings will be due and payable when rendered and will be considered delinquent if not paid within fifteen (15) days. An advance payment may be required of the Customer by the Company in accordance with Electric Service Regulation No. 9. An advance may be
required under any of the following conditions: (1) the Customer failed to pay all amounts owed to the Company when due and
payable; (2) the Customer paid an advance the previous season that did not adequately cover bills for the entire season and the Customer failed to pay any balance owing by the due date of the final billing issued for the season. (Continued)
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Feb. 1, 2022 Jan. 1, 2022
Per O.N. 35277
Jan Noriyuki Secretary
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Aug. 28, 2006 Sept. 15, 2006
Jean D. Jewell Secretary
I.P.U.C. No. 1 Original Sheet No.10.3
ELECTRIC SERVICE SCHEDULE No. 10 -Continued
PAYMENT: ( continued)
An adequate assurance of payment (advance) may be required from a Customer who has filed bankruptcy.
Advances which may be required of the Customer may be paid with cash payment or guarantee, as required
by the Company, or with a letter of escrow acceptable to the Company from an authorized bank in the
Company's service area. This letter of escrow shall provide that upon termination of service to the
Customer, the Company shall receive, upon demand, cash equal to the unpaid balance of the Customer's bill
which is not disputed or the full amount of the advance, whichever is the lesser amount.
CONNECTION AND DISCONNECTION CHARGES: Company will not routinely seasonally
connect and disconnect service to irrigation pumps. However, upon oral or written request the Company
will connect and disconnect service at the beginning and end of Customer's pumping operation each year
without charge. Customer shall give Company at least two (2) weeks advance notice of the date
disconnection and connection of seasonal service is desired. The actual expense incurred for additional
connection and disconnection shall be paid by Customer. Customer shall give Company at least two (2)
weeks advance notice of the date any additional connection and/or an additional disconnection of service is
desired. Meters will not be read and bills will not be issued from November 1 to March 1 unless the
customer requests in writing a different ending or beginning point for billing. The bill issued in March will
include charges for any unbilled energy used during the period of November 1 to March 1.
POWER: The kW as shown by or computed from the readings of the Company's power meter for
the 15-minute period of Customer's greatest use during the month, adjusted for power factor as specified,
determined to the nearest kW. Metered power demands in kilowatts which exceed one hundred and thirty
percent ( 13 0%) of the total connected horsepower served through one service connection will not be used
for billing purposes unless and until verified by field test in the presence of the Company to be the result of
normal pumping operations. If a demand in excess of 130% of connected horsepower is the result of
abnormal conditions existing on the Company's interconnected system or the Customer's system, including
accidental equipment failure or electrical supply interruption which results in temporary separation of the
Company and Customer's system, the billing demand shall be 130% of the connected horsepower. The
Customer may appeal the Company's billing decision to the Idaho Public Utilities Commission in cases of
dispute.
CONTRACT PERIOD: One year or longer.
(Continued)
Submitted Under Advice Letter No. 06-06
ISSUED: August 14, 2006 EFFECTIVE: September 15, 2006
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Aug. 28, 2006 Sept. 15, 2006
Jean D. Jewell Secretary
I.P.U.C. No. 1 Original Sheet No. 10.4
ELECTRIC SERVICE SCHEDULE No. 10 -Continued
ELECTRIC SERVICE REGULATIONS: Service under this Schedule will be in accordance with
the terms of the Electric Service Agreement between the Customer and the Company. The Electric Service
Regulations of the Company on file with and approved by the Idaho Public Utilities Commission, including
future applicable amendments, will be considered as forming a part of and incorporated in said Agreement.
Submitted Under Advice Letter No. 06-06
ISSUED: August 14, 2006 EFFECTIVE: September 15, 2006

Eleventh Revision of Sheet No. 11.1
I.P.U.C. No. 1 Canceling Tenth Revision of Sheet No. 11.1

Submitted Under Tariff Advice No. 22-01

ISSUED: April 20, 2022 EFFECTIVE: July 1, 2022
ROCKY MOUNTAIN POWER

ELECTRIC SERVICE SCHEDULE NO. 11

STATE OF IDAHO
______________

Street Lighting Service
Company-Owned System
______________

AVAILABILITY: In all territory served by the Company in the State of Idaho.

APPLICATION: To unmetered lighting service provided to municipalities or agencies of
municipal, county, state or federal governments for dusk to dawn illumination of public streets, highways
and thoroughfares by means of Company owned, operated and maintained street lighting systems controlled
by a photoelectric control or time switch.

MONTHLY BILL: The Monthly Billing shall be the rate per luminaire as specified in the rate
tables below.

Functional Lighting
LED Equivalent
Lumen Range
Monthly
kWh Total
Level 1 <=3,500 8 $16.24
Level 2 3,501-5,500 15 $17.32
Level 3 5,501-8,000 25 $17.84
Level 4 8,001-12,000 34 $18.44
Level 5 12,001-15,500 44 $19.48
Level 6 >15,500 57 $23.21

(Continued)
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
June 1, 2022 July 1, 2022
Jan Noriyuki Secretary

Fifth Revision of Sheet No. 11.2 I.P.U.C. No. 1 Canceling Fourth Revision of Sheet No. 11.2

Submitted Under Case No. PAC-E-21-07 ISSUED: November 8, 2021 EFFECTIVE: January 1, 2022
ELECTRIC SERVICE SCHEDULE NO. 11 - Continued
DEFINITIONS: Functional Lighting: Common, less expensive luminaires that may be mounted either on wood, fiberglass or non-decorative metal poles.
PROVISIONS:
1. Installation, daily operation, repair and maintenance of lights on this rate schedule to be performed by the Company, providing that the facilities furnished remain readily accessible for maintenance purposes.
2. Company will install only Company approved street lighting equipment at locations acceptable to Company.
3. Inoperable lights will be repaired as soon as reasonably possible, during regular business hours or as allowed by Company’s operating schedule and requirements, provided the Company
receives notification of inoperable lights from the Customer or a member of the public by either notifying Rocky Mountain Power’s customer service at (1-888-221-7070) or www.rockymountainpower.net/streetlights. Rocky Mountain Power’s obligation to repair street
lights is limited to this tariff.
4. Existing fixtures and facilities that are deemed irreparable will be replaced with comparable fixtures and facilities from the Company’s Construction Standards.
5. The Company will, upon written request of Customer, convert existing street lighting facilities
to other types of Company approved facilities. In such event, should the revenue increase, the streetlighting extension allowance defined in Rule 12, section 3.f is applicable only to the increase in annual revenue due to the replacement. If there is no increase in revenue, there is no allowance. The Customer shall advance the estimated cost of all materials and labor associated with installation and removal, less the estimated salvage on all the removed facilities, in excess of the applicable allowance.
6. The entire system, including initial lamp requirements and wiring suitable for connection to Company’s system, will be furnished and installed by the Company. The Customer is responsible for all associated costs that exceed the Street Lighting Extension Allowance as
described in the General Rules of this tariff. Customer shall not perform the electrical connection of meters or service conductor to the point of delivery. (Continued)
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Feb. 1, 2022 Jan. 1, 2022
Per O.N. 35277
Jan Noriyuki Secretary

Fourth Revision of Sheet No. 11.3
I.P.U.C. No. 1 Canceling Third Revision of Sheet No. 11.3

Submitted Under Advice No. 16-03

ISSUED: February 10, 2016 EFFECTIVE: March 15, 2016
ELECTRIC SERVICE SCHEDULE NO. 11 - Continued

PROVISIONS: (continued)

7. Temporary disconnection and subsequent reconnection of electrical service requested by the
Customer shall be at the Customer’s expense. The Customer may request temporary suspension
of power by written notice. During such periods, the monthly rate will be reduced by the
Company’s estimated average energy costs for the luminaire. The facilities may be considered
idle and may be removed after 12 months of inactivity.

8. Where approved by the company, all pole mounted outlets used for holiday or other decorations
will be supplied with service on a metered General Service rate via a Customer-installed meter
base.

9. Pole re-painting, when requested by the Customer and not required for safety reasons, shall be
done at Customer’s expense using the original pole color.

10. Glare or vandalism shielding, when requested by the Customer, and subject to availability, shall
be installed at the Customer’s expense. In cases of repetitive vandalism, the Company may
notify the Customer of the need to install vandal shields at the Customer’s expense, or
otherwise have the lighting removed.

CONTRACT PERIOD: Not less than five (5) years for both new and replacement fixtures.
After the end of the contract term, the Customer can request removal of lights with a minimum of 2 months
written notice. The Customer will be charged with costs of removal. If the lights are removed before the end
of the contract term, the Customer is responsible for the cost of removal plus depreciated remaining life of
the assets less any salvage value.

ELECTRIC SERVICE REGULATIONS: Service under this schedule is subject to the General
Rules and Regulations contained in the tariff of which this schedule is part and to those prescribed by
regulatory authorities.

IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Feb. 22, 2016 March 15, 2016
Jean D. Jewell Secretary

Ninth Revision of Sheet No. 12.1 I.P.U.C. No. 1 Canceling Eighth Revision of Sheet No. 12.1

Submitted Under Case No. PAC-E-21-07 ISSUED: November 8, 2021 EFFECTIVE: January 1, 2022
ROCKY MOUNTAIN POWER ELECTRIC SERVICE SCHEDULE NO. 12 STATE OF IDAHO ______________ Street and Security Area Lighting Service Customer-Owned System ______________ AVAILABILITY: In all territory served by the Company in the State of Idaho. APPLICATION: To lighting service provided to municipalities or agencies of municipal, county, state or federal governments for dusk to dawn illumination of public streets, highways and thoroughfares by
means of Customer owned street lighting systems controlled by a photoelectric control or time switch. Security Area Lighting service on this Schedule is closed to new service. MONTHLY BILL: 1. Energy Only Service – Rate per Luminaire
Energy Only Service includes energy supplied from Company’s overhead or underground circuits and does not include any maintenance to Customer’s facilities. The Monthly Billing shall be the rate per luminaire as specified in the rate tables below.
High Pressure Sodium Vapor– No Maintenance
(Continued)
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Feb. 1, 2022 Jan. 1, 2022
Per O.N. 35277
Jan Noriyuki Secretary
I
...
Ninth Revision of Sheet No. 12.2 I.P.U.C. No. 1 Canceling Eighth Revision of Sheet No. 12.2

Submitted Under Case No. PAC-E-21-07 ISSUED: November 8, 2021 EFFECTIVE: January 1, 2022
ELECTRIC SERVICE SCHEDULE NO. 12 - Continued MONTHLY BILL: (continued)

Lumen Rating 9,000 12,000 19,500 32,000 107,800
Watts 100 175 250 400 1000
Monthly kWh 39 69 93 145 352
Energy Only Service $3.54 $6.21 $8.50 $13.36 $31.99

Low Pressure Sodium Vapor - No Maintenance

Sodium Vapor Security Area Flood Light - No Maintenance
For non-listed luminaires, the cost will be calculated for 4167 annual hours of operation including applicable loss factors for ballasts and starting aids at the cost per kWh given below.
(Continued)
Non-Listed Luminaire
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Feb. 1, 2022 Jan. 1, 2022
Per O.N. 35277
Jan Noriyuki Secretary
I
...
...
...
-
-
-

Eighth Revision of Sheet No. 12.3 I.P.U.C. No. 1 Canceling Seventh Revision of Sheet No. 12.3

Submitted Under Case No. PAC-E-21-07 ISSUED: November 8, 2021 EFFECTIVE: January 1, 2022
ELECTRIC SERVICE SCHEDULE NO. 12 - Continued MONTHLY BILL: (continued) 2. Maintenance Service (No New Service) Monthly maintenance is only applicable for existing monthly maintenance service agreements in
effect prior to June 29, 2007. A. Street Lighting, “Partial Maintenance”

Mercury Vapor – Partial Maintenance

High Pressure Sodium – Partial Maintenance

B. Street Lighting, “Full Maintenance”
High Pressure Sodium – Full Maintenance

(Continued)
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Feb. 1, 2022 Jan. 1, 2022
Per O.N. 35277
Jan Noriyuki Secretary
...
...
...
...
Fourth Revision of Sheet No. 12.4 I.P.U.C. No. 1 Canceling Third Revision of Sheet No. 12.4

Submitted Under Case No. PAC-E-21-07 ISSUED: November 8, 2021 EFFECTIVE: January 1, 2022
ELECTRIC SERVICE SCHEDULE NO. 12 - Continued MONTHLY BILL: (continued) SPECIFICATIONS AND SERVICE FOR STREET LIGHTING WITH PARTIAL AND FULL MAINTENANCE (NO NEW SERVICE): Installations must have met Company construction standards in place at the time of installation
in order to receive “full maintenance.” If Company is unable to obtain materials to perform maintenance, the street light facilities will be deemed obsolete and must be upgraded at customer expense in order to qualify for maintenance under the Electric Service Schedule.
Street Lighting Service under “partial maintenance” includes energy, lamp and glassware renewals and cleaning of glassware.
Street Lighting Service under “full maintenance” includes energy, lamp and glassware replacements and cleaning of glassware, and replacement of damaged or inoperative photocells, ballasts, starting aids, poles, mast arms and luminaires: provided, however, that any costs for materials which are over and above costs for Company’s standard materials, as determined by the Company, are not included in this Electric Service Schedule. Such extra costs shall be paid by Customer. Burning-hours of lamps will be controlled by the Company. The Company shall not be liable under the maintenance provided under “Full Maintenance” for damages caused by (a) war; (b) earthquakes; and (c) acts of God, excepting lightning strikes; or (d) sabotage. The costs associated with replacements and repairs to Customer-owned facilities associated with these acts will be billed to the Customer on an as if and when basis.
PROVISIONS:
1. The Company will not maintain new Customer owned street lights. Such maintenance will be the responsibility of the Customer; however the Company may install pole identification tags for the purposes of tracking unmetered Customer owned lights.
(continued)
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Feb. 1, 2022 Jan. 1, 2022
Per O.N. 35277
Jan Noriyuki Secretary

Second Revision of Sheet No. 12.5 I.P.U.C. No. 1 Canceling First Revision of Sheet No. 12.5

Submitted Under Case No. PAC-E-21-07 ISSUED: November 8, 2021 EFFECTIVE: January 1, 2022
ELECTRIC SERVICE SCHEDULE NO. 12 - Continued PROVISIONS: (continued) 2. Customer owned lights, mounted to Company owned distribution poles, shall be installed, maintained, transferred or removed only by qualified personnel. Appurtenances or other
alterations to the Company’s standard will not be supported by, or become the responsibility of, the Company. Following notification by the Customer, inoperable lights under this provision will be repaired as soon as possible, during regular business hours or as allowed by Company’s
operating schedule and requirements. Costs described in this provision will be invoiced to the Customer upon completion of the work.
3. The entire system, including the design of facilities, installation of fixtures on Customer poles, and wiring suitable for connection to Company’s system, will be furnished by the Customer. 4. Customer must notify the Company in writing of any changes to the street lighting system which would affect billing, including new installations, removals or wattage changes. Standard notification procedure will be through online forms at www.rockymtnpower.net/streetlights. 5. All new underground-fed lights on this schedule will require a Customer installed means of disconnect acceptable to both the Company and the local electrical inspecting authority. 6. Temporary disconnection and subsequent reconnection of electrical service requested by the
Consumer shall be at the Consumer’s expense. 7. Where approved by the Company, all new pole mounted outlets used for holiday or other
decorations, as well as traffic or other signal systems, will be supplied with service on a metered General Service rate schedule via a Consumer-installed meter base. CONTRACT PERIOD: Not less than one (1) year for both new and replacement fixtures. ELECTRIC SERVICE REGULATIONS: Service under this schedule is subject to the General Rules and Regulations contained in the tariff of which this schedule is part and to those prescribed by regulatory authorities.

IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Feb. 1, 2022 Jan. 1, 2022
Per O.N. 35277
Jan Noriyuki Secretary
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Aug. 28, 2006 Sept. 15, 2006
Jean D. Jewell Secretary
I.P.U.C. No. 1
ROCKY MOUNTAIN POWER
ELECTRIC SERVICE SCHEDULE NO. 14
STATE OF IDAHO
Temporary Service Connection Facilities
No new Service
Original Sheet No. 14
AVAILABILITY: To any Customer requiring a temporary power connection at any point on
Company's interconnected system where there are facilities of appropriate voltage and adequate capacity.
APPLICATION: This Schedule is for the rental of a pre-assembled service connection loop for
providing temporary 120/240 volt power service.
INSTALLATION AND DISCONNECT CHARGE: $45.00 payable in advance each time a pre­
assembled service loop installation is connected to Company's service facilities.
MONTHLY RENTAL FEE: $7.50 per month for each pre-assembled service loop installed by the
Company, prorated for any partial month after the first month that service loop is connected.
SERVICE CONDITIONS: The Company will furnish and install a pre-assembled service loop
consisting of a housing, necessary receptacles, circuit-breakers, meter socket, conduit, wire, grounding
material and connectors. The pre-assembled service loop will meet all provisions of the National Electrical
Code as required for permanent installations. The service loop may be either bonded to or attached with
conduit straps to a standard Company distribution pole. Energy requirements will be supplied under the
Company's Electric Service Schedule No. 1, 6, 23, or 36 and in accordance with the provisions of the
Company's Electric Service Regulation No. 12 for temporary service.
CONTRACT PERIOD: One month or longer.
ELECTRIC SERVICE REGULATIONS: Service under this Schedule will be in accordance with
the terms of the Electric Service Agreement between the Customer and the Company. The Electric Service
Regulations of the Company on file with and approved by the Idaho Public Utilities Commission, including
future applicable amendments, will be considered as forming a part of and incorporated in said agreement.
Submitted under Advice Letter No. 06-06
ISSUED: August 14, 2006 EFFECTIVE: September 15, 2006
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Aug. 28, 2006 Sept. 15, 2006
Jean D. Jewell Secretary
I.P.U.C. No.1
ROCKY MOUNTAIN POWER
ELECTRIC SERVICE SCHEDULE NO. 19
STATE OF IDAHO
Commercial and Industrial Space Heating
(No New Service)
Original Sheet No. 19.1
AVAILABILITY: At any point on the Company's interconnected system where there are facilities
of adequate capacity.
APPLICATION: This Schedule is for alternating current single or three-phase electric service to
Commercial and Industrial Customers at Company's available voltage for all service required on the
Customer's premises subject to the terms and conditions set forth herein. Service for electric resistance
heaters and year round heat pumps will be supplied through a special circuit and metered through one
kilowatt-hour meter. All other lighting and power requirements will be supplied through a separate circuit
and will be separately metered, except that electric motor-drived compressors installed to provide comfort
cooling and electric water heating equipment may be connected to the special space heating circuit. No
other equipment shall be connected to the wiring serving the space heating equipment.
This Schedule is available for space heating only when the Customer regularly uses electric energy
for all other service requirements including but not limited to lighting, cooking, water heating, air
conditioning, and the operation of machines and other equipment.
(Continued)
Submitted Under Advice Letter No. 06-06
ISSUED: August 14, 2006 EFFECTIVE: September 15, 2006
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Dec. 14, 2016 Jan. 1, 2017
Per O.N. 33668
Diane M. Hanian Secretary
I.P.U,C. No. 1
Tenth Revision of Sheet No. 19.2
Canceling Ninth Revision of Sheet No. 19.2
ELECTRIC SERVICE SCHEDULE NO. 19 -Continued
MONTHLY BILL:
Rate for space heating:
Billing Months May
through October. Inclusive
Customer
Service Charge: $23.00 per Customer
Energy Rate: 9.6502¢ per kWh for all kWh
Rate for all other service:
Billing Months November
through April, Inclusive
$23.00
7.2175¢
per Customer
per kWh for all kWh
All other service requirements will be supplied under Electric Service Schedule No. 6, or
Electric Service Schedule No. 6A, or Electric Service Schedule No. 23, or Electric Service
Schedule No. 23A, or Electric Service Schedule No.35, or Electric Service Schedule No. 35A.
SPACE HEATING: All space heating equipment shall be permanently installed and shall be the
sole means of heating the building space occupied by the Customer. All space heating equipment and
installation thereof and all supply wiring shall conform with the Company's specifications.
AIR CONDITIONING: All air conditioning equipment shall be permanently installed and shall be
the sole means of providing comfort cooling for the building space occupied by the Customer. All air
conditioning equipment and installation thereof and all supply wiring shall conform with the Company's
specifications. Electric service for comfort cooling will be metered and billed at the above rate only when
Customer also uses electric service for his total space heating requirements.
WATER HEATING: Water heaters served hereunder shall be insulated storage, single or
multiple-unit type of construction approved by the Company, the heating units of which shall be
noninductive ~d controlled by separate thermostats. Electric service of storage water heating will be
metered and billed at the above rate only when Customer also uses electric service for his total space
heating requirements.
Submitted Under Case No. PAC-E-16-12
ISSUED: November 11, 2016
(Continued)
EFFECTIVE: January 1, 2017
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Aug. 28, 2006 Sept. 15, 2006
Jean D. Jewell Secretary
I.P.U.C. No. 1 Original Sheet No. 19.3
ELECTRIC SERVICE SCHEDULE NO. 19 -Continued
WATERHEATING: (continued)
Water heaters shall have a minimum capacity of 30 gallons each and the total capacity of heating
elements in each heater shall not exceed 50 kilowatts except that, when heaters are operated for swimming
pool heating, more than 50 kilowatts capacity in a heater may be permitted upon written authorization of the
Company. All equipment shall be so designed and controlled that not more than 10 kilowatts will be
switched on or off at one time unless otherwise permitted by written authorization of the Company.
INSULATION STANDARDS: Commercial and industrial buildings constructed after September
1, 1984, and such buildings constructed prior to September 1, 1984, but which previously did not otherwise
qualify for service under this electric service schedule must now also meet the following minimum
insulation standards in order to qualify for service under this electric service schedule.
The maximum heat loss of the building to be heated while maintaining a reasonable and appropriate
indoor air temperature during periods of winter design outdoor weather conditions as defined in the latest
ASHRAE Handbook of Fundamentals including infiltration and excluding ventilation losses for electrically
heated buildings shall not exceed 21 btu/hour/square foot in new buildings or 24 btu/hour/square foot in
converted buildings. Electrically heated buildings shall have double glass except where it may be
impractical such as at entrance doors or display windows etc.
Electrically heated buildings can be considered to meet the requirements if the following criteria are
met:
"U"
Factor
Ceilings 0.032
Opaque Walls 0.096
Floors Over Vented Crawl
Spaces or Over Unheated
Basements 0.053
Walls of Heated Basement 0.077
Submitted Under Advice Letter No. 06-06
ISSUED: August 14, 2006
Minimum Insulation Factors
New Buildings Converted Buildings
"R"
Factor
31
(Continued)
10.4
19
13
"U"
Factor
0.032
0.156
0.053
0.125
"R"
Factor
31
6.4
19
8
EFFECTIVE: September 15, 2006
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Aug. 28, 2006 Sept. 15, 2006
Jean D. Jewell Secretary
I.P.U.C. No. 1 Original Sheet No. 19.4
ELECTRIC SERVICE SCHEDULE NO. 19 -Continued
INSULATION STANDARDS: (continued)
Concrete slabs on grade shall have insulation 24" wide by 2" thick around the perimeter of the slab.
This requirement may be waived for converted buildings at the discretion of the Company.
Glazing shall be double glass except where it may be impractical such as at entrance doors or
display windows, etc. Weather stripping shall be installed on all exterior doors and windows. Ducts and
Plenums, both supply and return, not enclosed within the heated space, shall have a minimum of 2"
insulation (U = 0.13).
CONTRACT PERIOD: One year or longer.
ELECTRIC SERVICE REGULATIONS: Service under this Schedule will be in accordance with
the terms of the Electric Service Agreement between the Customer and the Company. The Electric Service
Regulations of the Company on file with and approved by the Idaho Public Utilities Commission, including
future applicable amendments, will be considered as forming a part of and incorporated in said Agreement.
Submitted Under Advice Letter No. 06-06
ISSUED: August 14, 2006 EFFECTIVE: September 15, 2006

I.P.U.C. No. 1 First Revision of Sheet No. 21.1
Canceling Original Sheet No. 21.1

Submitted Under Docket No. PAC-E-06-10 - Advice Letter No. 07-03

ISSUED: January 10, 2007 EFFECTIVE: April 1, 2007
ROCKY MOUNTAIN POWER

ELECTRIC SERVICE SCHEDULE NO. 21

STATE OF IDAHO

______________

Low Income Weatherization Services
Optional For Income Qualifying Customers
_____________

PURPOSE: Service under this schedule is intended to maximize the efficient utilization of the
electricity requirements of existing residential dwellings inhabited by customers that meet income guidelines
through the installation of energy efficient materials. The decision to extend service under this schedule
shall be based upon the eligibility requirements contained herein.

AVAILABILITY: This tariff is applicable to residential customers in all territory served by the
Company in the state of Idaho.

1. ENERGY CONSERVATION SERVICE TO LOW INCOME CUSTOMERS:

This program is available to existing single family and multi-family residential units. It is
intended to reduce the electricity requirements and increase the penetration of weatherization and
electric efficiency measures in residential dwellings inhabited by low income households through
the installation of permanent energy efficiency materials. The decision to extend service under this
schedule shall be based on eligibility requirements contained herein.

A. Definitions:

1. "Dwelling" is real or personal property within the state inhabited as the principal
residence of a dwelling owner or a tenant. “Dwelling” includes a manufactured
home, a single-family home, duplex or multi-unit residential housing. “Dwelling”
does not include a recreational vehicle.

a. Duplexes and fourplexes are eligible if at least one half of the dwelling is
occupied by low income tenants.

(Continued)
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Feb. 8, 2007 April 1, 2007
Per O.N. 30239
Jean D. Jewell Secretary

I.P.U.C. No. 1 Fourth Revision of Sheet No. 21.2
Canceling Third Revision of Sheet No. 21.2

ELECTRIC SERVICE SCHEDULE NO. 21 – (Continued)

A. Definitions (Continued):
b. Triplexes and multi-family dwellings are eligible if at least 66% of the units
are occupied by low income tenants.

2. "Agency" means a non-profit group, Municipality or County authorized to receive
funds for installation of energy efficiency materials in low income properties.

3. "Low Income" means households qualifying under the Federal low income
guidelines and certified for eligibility according to agency procedure. Income
eligibility is based on 200% of federal poverty guidelines.

4. "Major Measure" means ceiling insulation, wall insulation, floor insulation and
window replacements applicable in dwellings with permanently installed electric
space heating systems. When cost-effective (Savings to Investment Ratio (“SIR”)
of 1.0 or greater as determined by a U.S. Department of Energy (“DOE”) approved
energy audit), all major measures must be installed or in place or financial assistance
under this schedule will not be offered. If physical barriers exist that prohibit the
installation of a measure, then the measure is not required as a condition for
financial assistance under this schedule.

5. "Supplemental Measures and Additional Measures" are not required measures under
this schedule, but may qualify for a Company reimbursement.

B. Financial Assistance:

1. The Company will reimburse Agency 85% of the installed cost of all eligible
Energy Conservation Measures listed in Section C of this Tariff, with the exception
of ductless heat pumps, which will be reimbursed up to 100% of related installed
costs. Reimbursements on weatherized homes will be provided one time only on
any individual measure, and up to two times per dwelling.

(Continued)
Submitted Under Advice No. 19-01

ISSUED: January 16, 2019 EFFECTIVE: March 6, 2019
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
March 5, 2019 March 6, 2019
Diane M. Hanian Secretary

I.P.U.C. No. 1 Fourth Revision of Sheet No. 21.3
Canceling Third Revision of Sheet No. 21.3

Submitted Under Advice No. 16-02

ISSUED: January 19, 2016 EFFECTIVE: March 1, 2016
ELECTRIC SERVICE SCHEDULE NO. 21 - Continued

B. Financial Assistance (Continued):

2. The Company will reimburse Agency for administrative costs based on 15% of Rocky
Mountain Power’s rebate on installed measures, not to exceed the following total
administrative payment per building:
Dwelling Units in Building Maximum Administrative Payment
1 to 4 $350
5 to 10 $800
11 to 15 $1200
16 to 20 $1400
21 to 25 $1600
26 to 30 $1800
31+ $2100

The minimum reimbursement will be $150 on homes with one or more Major Measure
installed and $50 on homes without the installation of a Major Measure.

3. Agencies must invoice Company within 120 days of job completion.

4. A maximum of $300,000 in Company reimbursements will be available annually (April
1 through March 31). Reimbursements related to health and safety measures are limited
to 15% of the annual cost of total jobs performed by each agency.

5. Annual funding of $25,000 in total will be provided to Eastern Idaho Community
Action Partnership and SouthEastern Idaho Community Action Agency for
conservation education.

C. Energy Conservation Measures:

Financial assistance will be provided based on the results of a cost effective analysis
through a Department of Energy approved energy audit. The energy efficient measures
eligible for funding must be installed in dwellings with permanently installed operable
electric space heat except where noted. The electric space heating system must be designed
to heat at least 51% of the home. All Major and Supplemental Measures indicated below
may qualify for a company reimbursement when audit results indicate a measure has a
Savings to Investment Ratio of 1.0 or greater. The energy efficient measures that may be
eligible for funding are listed as follows:

Major Measures – Electric Heating System Required:

1. Ceiling insulation up to R-48 for ceilings with less than R-30 in place. R-30 or better
attics will not be further insulated.

(Continued)
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Feb. 29, 2016 March 1, 2016
Jean D. Jewell Secretary

I.P.U.C. No. 1 Second Revision of Sheet No. 21.4
Canceling First Revision of Sheet No. 21.4

Submitted Under Advice No. 16-02

ISSUED: January 19, 2016 EFFECTIVE: March 1, 2016
ELECTRIC SERVICE SCHEDULE NO. 21 - Continued

C. Energy Conservation Measures: (Continued)

2. Floor insulation over unheated spaced up to R-30.

3. Wall insulation up to R-26 for walls with no insulation installed (financing will not
be available for the installation of urea-formaldehyde wall insulation).

4. Replacement windows with a U-value of 0.30 or less.

Nothing shall preclude the Company from providing a reimbursement for the
installation of a greater R value on insulation for the above items that are determined to be
cost effective (SIR is 1.0 or greater) through the audit process.

Supplemental Measures – Electric Heating System Required:

1. Attic ventilation excluding power ventilators, whole house mechanical ventilation
and spot ventilation for kitchen and baths.

2. Ground cover.

3. Forced air electric space heating duct insulation and sealing in unheated spaces.

4. Weather stripping and/or caulking, including blower door assisted air sealing and
duct sealing.

5. Thermal doors.

(Continued)
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Feb. 29, 2016 March 1, 2016
Jean D. Jewell Secretary

I.P.U.C. No. 1 Third Revision of Sheet No. 21.5
Canceling Second Revision of Sheet No. 21.5

ELECTRIC SERVICE SCHEDULE NO. 21 - Continued

C. Energy Conservation Measures: (Continued)
Supplemental Measures – Electric Heating System Required (continued)

6. Timed thermostats on centrally controlled multi-room heating/cooling systems
except when used with heat pumps and Smart thermostats with occupancy sensors.
Heat anticipating type thermostats for zonal electric resistance heating systems.

7. Electric furnace repair and replacement.

8. Ductless heat pumps.

Additional Measures – No Electric Heating System Requirement:

1. Pipe insulation, energy efficient showerheads and aerators where electric water
heaters are present.

2. Light emitting diodes (LED) and/or compact fluorescent (CFL) light bulbs
applicable in all homes – Energy Star certified bulbs placed in fixtures that are on
2 hours or more per day.

3. LED light fixtures.

4. Existing Refrigerator with monitored results listed in the Weatherization
Assistance Program Technical Assistance center database with a savings to
investment ration of 1.0 or greater may be replaced with an Energy Star model.
Replaced refrigerators must be removed and recycled in accordance with EPA
guidelines.

5. Electric water heater repair and replacement.

6. Measures that promote health and safety related to electricity usage.

D. Provisions of Service for Energy Conservation Service to Low Income Customers:

1. Measures installed are intended to improve upon the electric efficiencies of
participating homes and must be included in the U.S. Department of Energy’s
Weatherization Assistance Program available to Agency.

(Continued)
Submitted Under Advice No. 17-01

ISSUED: November 27, 2017 EFFECTIVE: February 1, 2018
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Jan. 22, 2018 Feb. 1, 2018
Diane M. Hanian Secretary

I.P.U.C. No. 1 First Revision of Sheet No. 21.6
Canceling Original Sheet No. 21.6

Submitted Under Docket No. PAC-E-06-10 – Advice Letter No. 07-03

ISSUED: January 10, 2007 EFFECTIVE: April 1, 2007
ELECTRIC SERVICE SCHEDULE NO. 21 – (Continued)

D. Provisions of Service for Energy Conservation Service to Low Income Customers:
(Continued)

2. A DOE-approved energy audit must be completed by the Agency prior to
installation of Major and Supplemental Measures.

3. Agency must qualify residential customers for assistance using the Federal low
income guidelines.

4. Installation shall meet Federal, state and local building codes.

5. Measures installed under this schedule shall not receive financial incentives from
other Company programs.

6. Agency shall inspect the installation to insure that the services meet or exceed
required specifications.

7. Company may audit Agency weatherization and financial records and inspect the
installations in dwellings of customers receiving services under this program

8. Company shall pay Agency the amount established under the terms of their contract
when provisions of this schedule have been met.

ELECTRIC SERVICE REGULATIONS: Service under this schedule is subject to the
Electric Service Regulations of the Company on file with and approved by the Idaho Public Utilities
Commission, including future applicable amendments and additional regulations prescribed by regulatory
authorities.

IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Feb. 8, 2007 April 1, 2007
Per O.N. 30239
Jean D. Jewell Secretary

Ninth Revision of Sheet No. 23.1 I.P.U.C. No. 1 Canceling Eighth Revision of Sheet No. 23.1

Submitted Under Case No. PAC-E-21-07 ISSUED: November 8, 2021 EFFECTIVE: January 1, 2022
ROCKY MOUNTAIN POWER ELECTRIC SERVICE SCHEDULE NO. 23 STATE OF IDAHO
______________ General Service ______________ AVAILABILITY: At any point on the Company's interconnected system where there are facilities of
adequate capacity. APPLICATION: This Schedule is for alternating current, single or three-phase electric service supplied at Company's available voltage through one metering installation at a single point of delivery for all service required on the premises. MONTHLY BILL:
Customer Service Charge
Energy Rate (Continued)
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Feb. 1, 2022 Jan. 1, 2022
Per O.N. 35277
Jan Noriyuki Secretary

Fifth Revision of Sheet No. 23.2 I.P.U.C. No. 1 Canceling Fourth Revision of Sheet No. 23.2

Submitted Under Case No. PAC-21-07 ISSUED: November 8, 2021 EFFECTIVE: January 1, 2022
ELECTRIC SERVICE SCHEDULE NO. 23 - Continued Power Factor: This rate is based on the Customer maintaining at all times a power factor of 85% lagging, or higher, as determined by measurement. If the average power factor is found to be less than 85% lagging, Customer will be billed for 3/4 of 1% of the Power recorded by the Company’s
meter for every 1% that the power factor is less than 85%. This Power will be billed at the Power Rate stated in Electric Service Schedule No. 6.
Voltage Discount: Where Customer takes service from Company's available lines of 2,300 volts or higher and provides and maintains all transformers and other necessary equipment, the voltage discount
based on measured Energy will be: 0.4397¢ per kWh for all kWh. Minimum Bill: The Customer Service Charge POWER: The kW as shown by or computed from the readings of the Company’s Power meter for the 15-minute period of Customer’s greatest use during the month, determined to the nearest kW. SEASONAL SERVICE: Service for annually recurring periods of seasonal use where service is normally discontinued or curtailed during a part of the year may be contracted for under this Schedule under
either of the following conditions: (a) Customer may contract for service under this Schedule on a year-round basis paying for all
service, including transformer losses where applicable, under the rates set forth under "Monthly Bill" above including the monthly minimum bill during those months service is curtailed or is not utilized in the Customer's operations.
(b) Customer may contract for seasonal service under this Schedule with a net minimum seasonal payment as follows: $216.00 plus Energy Charges for Customer taking service at less than 2,300 volts and $576.00 plus Energy Charges for Customer taking service at 2,300 volts or higher. CONTRACT PERIOD: One year or longer. (Continued)
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Feb. 1, 2022 Jan. 1, 2022
Per O.N. 35277
Jan Noriyuki Secretary
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Aug. 28, 2006 Sept. 15, 2006
Jean D. Jewell Secretary
I.P.U.C. No. 1 Original Sheet No. 23.3
ELECTRIC SERVICE SCHEDULE NO. 23 -Continued
ELECTRIC SERVICE REGULATIONS: Service under this Schedule will be in accordance with
the terms of the Electric Service Agreement between the Customer and the Company. The Electric Service
Regulations of the Company on file with and approved by the Idaho Public Utilities Commission, including
future applicable amendments, will be considered as forming a part of and incorporated in said Agreement.
Submitted Under Advice Letter No. 06-06
ISSUED: August 14, 2006 EFFECTIVE: September 15, 2006
Ninth Revision of Sheet No. 23A.1 I.P.U.C. No. 1 Canceling Eighth Revision of Sheet No. 23A.1

Submitted Under Case No. PAC-E-21-07 ISSUED: November 8, 2021 EFFECTIVE: January 1, 2022
ROCKY MOUNTAIN POWER ELECTRIC SERVICE SCHEDULE NO. 23A STATE OF IDAHO ______________ General Service (Residential and Farm) ______________ AVAILABILITY: At any point on the Company's interconnected system where there are facilities of adequate capacity for service to any customer who qualifies as a "Residential Load" or "Farm Load" under both (1) the Pacific Northwest Electric Power Planning and Conservation Act, P.L. 96-501 as the same may be amended, and (2) a Residential Purchase and Sale Agreement, under Section 5(c) of such Act and in effect between the Company and the Bonneville Power Administration.
APPLICATION: This Schedule is for alternating current, single or three-phase electric service supplied at Company's available voltage through one metering installation at a single point of delivery for all
service required on the premises. MONTHLY BILL:
Customer Service Charge
Energy Rate (Continued)
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Feb. 1, 2022 Jan. 1, 2022
Per O.N. 35277
Jan Noriyuki Secretary

Fourth Revision of Sheet No. 23A.2
I.P.U.C. No. 1 Canceling Third Revision of Sheet No. 23A.2

Submitted Under Advice No. 12-03

ISSUED: October 19, 2012 EFFECTIVE: January 1, 2013
ELECTRIC SERVICE SCHEDULE NO. 23A - Continued

Power Factor:
This rate is based on the Customer maintaining at all times a power factor of 85% lagging, or
higher, as determined by measurement. If the average power factor is found to be less than
85% lagging, Customer will be billed for 3/4 of 1% of the Power recorded by the Company’s
meter for every 1% that the power factor is less than 85%. This Power will be billed at the
Power Rate stated in Electric Service Schedule No. 6.

Voltage Discount:
Where Customer takes service from Company's available lines of 2,300 volts or higher and
provides and maintains all transformers and other necessary equipment, the voltage discount
based on measured Energy will be:
0.4397¢ per kWh for all kWh.

Minimum Bill:
The Customer Service Charge

POWER: The kW as shown by or computed from the readings of the Company’s Power meter for
the 15-minute period of Customer’s greatest use during the month, determined to the nearest kW.

MONTHLY BILLING REDUCTION: Rates in this Schedule shall be reduced by the monthly
kilowatt-hour credit adjustment set forth under "Monthly Rates" in the currently effective Electric Service
Schedule No. 34.

SEASONAL SERVICE: Service for annually recurring periods of seasonal use where service is
normally discontinued or curtailed during a part of the year may be contracted for under this Schedule under
either of the following conditions:

(a) Customer may contract for service under this Schedule on a year-round basis paying for all
service, including transformer losses where applicable, under the rates set forth under
"Monthly Bill" above including the monthly minimum bill during those months service is
curtailed or is not utilized in the Customer's operations.

(Continued)
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Oct. 29, 2012 Jan. 1, 2013
Jean D. Jewell Secretary
Fourth Revision of Sheet No. 23A.3 I.P.U.C. No. 1 Canceling Third Revision of Sheet No. 23A.3

Submitted Under Case No. PAC-E-21-07 ISSUED: November 8, 2021 EFFECTIVE: January 1, 2022
ELECTRIC SERVICE SCHEDULE NO. 23A – Continued SEASONAL SERVICE: (continued) (b) Customer may contract for seasonal service under this Schedule with a net minimum seasonal payment as follows: $216.00 plus Energy Charges for Customer taking service at less than 2,300 volts and
$576.00 plus Energy Charges for Customer taking service at 2,300 volts or higher. CONTRACT PERIOD: One year or longer.
SPECIAL CONDITION: Domestic use means all usual residential, apartment, seasonal dwelling, and mobile home court use including domestic water pumping. Farm use means all usual farm electrical loads
for raising of crops, livestock or pasturage and includes primary processing necessary for safe and efficient storage or shipment and irrigation pumping. Contiguous parcels of land under single-ownership or leasehold shall be considered to be one Farm and noncontiguous parcels of land under single-ownership or leasehold shall be considered as one Farm unit when operated as a single Farm, unless demonstrated otherwise by the owner or lessee of the parcels. A number of factors shall determine whether contiguous or noncontiguous parcels constitute one or more Farms. These factors shall include, but are not limited to: -- size
-- use -- ownership -- control
-- operating practices -- distance between parcels -- custom in the trade
-- billing treatment by the utility Operators of Farms may be required to certify to the utility all irrigation accounts, including horsepower rating. Customers who feel they meet the definitions of a Farm will have to make application with the Company for review. If Customer application is denied by the Company, the Customer may appeal the decision to the Idaho Public Utilities Commission. (Continued)
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Feb. 1, 2022 Jan. 1, 2022
Per O.N. 35277
Jan Noriyuki Secretary
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Aug. 28, 2006 Sept. 15, 2006
Jean D. Jewell Secretary
I.P.U.C. No. 1 Original Sheet No. 23A.4
ELECTRIC SERVICE SCHEDULE NO. 23A-Continued
ELECTRIC SERVICE REGULATIONS: Service under this Schedule will be in accordance with the terms
of the Electric Service Agreement between the Customer and the Company. The Electric Service Regulations
of the Company on file with and approved by the Idaho Public Utilities Commission, including future
applicable amendments, will be considered as forming a part of and incorporated in said Agreement.
Submitted Under Advice Letter No. 06-06
ISSUED: August 14, 2006 EFFECTIVE: September 15, 2006
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Aug. 28, 2006 Sept. 15, 2006
Jean D. Jewell Secretary
I.P.U.C. No. 1
ROCKY MOUNTAIN POWER
ELECTRIC SERVICE SCHEDULE NO. 24
STATE OF IDAHO
Interruptible Power Service
Original Sheet No. 24.1
AVAILABILITY: For power loads of 1000 kW or greater at any point on the Company's
interconnected system where there are facilities of adequate capacity.
APPLICATION: This Schedule is for the supply of alternating current, three-phase electric
service at available delivery voltages through a single point of delivery for all service required on the
Customer's premises. Service hereunder may be interrupted to the degree and under the conditions
hereinafter set forth.
MONTHLY BILL:
Rate:
I. Delivery at 46 kV or Higher
A. Guaranteed Availability of 90% (Computer Code 124)
Power Rate:
All kW $6.94 per kW
Energy Rate:
All kWh 3.7163¢ per kWh
B. Guaranteed Availability of 80% (Computer Code 125)
Power Rate:
All kW $6.60 per kW
Energy Rate:
All kWh 3.7163¢ per kWh
(Continued)
Submitted Under Advice Letter No. 06-06
ISSUED: August 14, 2006 EFFECTIVE: September 15, 2006
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Aug. 28, 2006 Sept. 15, 2006
Jean D. Jewell Secretary
I.P.U.C. No. 1 Original Sheet No. 24.2
ELECTRIC SERVICE SCHEDULE NO. 24 -Continued
MONTHLY BILL: ( continued)
C. Guaranteed Availability of 70% (Computer Code 126)
Power Rate:
All kW
Energy Rate:
All kWh
$5.68 per kW
3.7163¢ per kWh
D. Guaranteed Availability of 60% (Computer Code 127)
Power Rate:
All kW $4.78 per kW
Energy Rate:
All kWh
Customer Charge:
3.7163¢ per kWh
$326.34 per Customer
II. Delivery at Primary Voltage (2.3 kV to Less than 46 kV)
A. Guaranteed Availability of 90% (Computer Code 128)
Power Rate:
All kW $8.69 per kW
Energy Rate:
All kWh 4.0536¢ per kWh
B. Guaranteed Availability of 80% (Computer Code 129)
Power Rate:
All kW $8.42 per kW
Energy Rate:
All kWh 4.0536¢ per kWh
(Continued)
Submitted Under Advice Letter No. 06-06
ISSUED: August 14, 2006 EFFECTIVE: September 15, 2006
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Aug. 28, 2006 Sept. 15, 2006
Jean D. Jewell Secretary
I.P.U.C. No. 1 Original Sheet No. 24.3
ELECTRIC SERVICE SCHEDULE NO. 24 -Continued
MONTHLY BILL: ( continued)
C. Guaranteed Availability of 70% (Computer Code 130)
Power Rate:
All kW $7.74 per kW
Energy Rate:
All kWh 4.0536¢ per kWh
D. Guaranteed Availability of 60% (Computer Code 131)
Power Rate:
All kW $7.06 per kW
Energy Rate:
All kWh
Customer Charge:
Contract Demand:
4.0536¢ per kWh
$266.11 per Customer
"Total Contract Demand" as used herein shall mean the maximum Power contracted for by
Customer, and in excess of which the Company is under no obligation to supply, as set forth
in the Electric Service Agreement executed by and between Customer and Company.
Power Factor:
This rate is based on the Customer maintaining at all times a power factor of 90% lagging,
or higher, as determined by measurement. If the average power factor is found to be less
than 90% lagging, the Power as recorded by the Company's meter will be increased by 3/4
of 1 % for every 1 % that the power factor is less than 90%.
Minimum Bill:
The monthly minimum bill shall be the Customer Service Charge plus the Power Charge
plus the appropriate monthly Energy Charge.
POWER: The kW as shown by or computed from the readings of the Company's Power meter
for the 15-minute period of Customer's greatest use during the month, adjusted for power factor as specified,
determined to the nearest kW.
(Continued)
Submitted Under Advice Letter No. 06-06
ISSUED: August 14, 2006 EFFECTIVE: September 15, 2006
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Aug. 28, 2006 Sept. 15, 2006
Jean D. Jewell Secretary
I.P.U.C. No. 1 Original Sheet No. 24.4
ELECTRIC SERVICE SCHEDULE NO. 24 -Continued
GUARANTEED AVAILABILITY: Customer may contract for an annual guaranteed
availability of supply of 60%, 70%, 80%, or 90%. Guaranteed Availability shall mean the annual amount of
energy in kWh that Company guarantees to make available to Customer over any Contract Year and is
determined by multiplying 8760 hours by the Contract Demand in kW and then multiplying this product by
the Guaranteed Availability expressed as a fraction; i.e., 90% Guaranteed Availability is expressed as the
fraction 9/l 0.
CONTRACT YEAR: Contract Year, as used herein, shall mean the period of 12 monthly billing
periods between the date of initial service hereunder or any anniversary thereof and the same date of the
following calendar year.
INTERRUPTION OF SERVICE: All electric power delivered hereunder shall be subject to
curtailment when in the Company's sole judgment its spinning reserve, its transmission margin or both are
needed to meet the demands of its regular customers on firm rates, or there is an actual or threatened need
for such reserve or margin. Customer, upon notice from the Company, shall curtail his use of electric power
except plant lighting, fire protection load, and other safety and security load, to the extent requested by and
as scheduled by the Company. Curtailment shall be effected by Customer (1) immediately upon request
from the Company in cases of emergencies not reasonably predictable by the Company, and (2) in all other
instances on notice as specified in the standard form contract. Total annual interruption in kWh during any
Contract Year shall not exceed the difference between the Contract Demand in kW multiplied by 8760
hours and the Guaranteed Availability in kWh contracted for by Customer.
All electric power delivered hereunder except plant lighting, fire protection load, and other safety
and security load, shall be subject to interruption. Customer shall install to Company's specifications and
maintain at his sole expense a digital under frequency relay with adjustable contacts set to close at the
Scheduled Frequency, associated relay facilities and communication channels to the Company's switching
center. Company shall have the right to inspect these facilities upon reasonable notice to Customer. After
any interruption hereunder, Customer shall not resume use of electric power except upon notice from
Company.
In addition to or in lieu of interruption of electric power at the Scheduled Frequency Company may
require that electric power by interrupted automatically in the event of a reduction in voltage or in the event
of such other operating conditions as may appear appropriate to the Company from time to time.
(Continued)
Submitted Under Advice Letter No. 06-06
ISSUED: August 14, 2006 EFFECTIVE: September 15, 2006
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Aug. 28, 2006 Sept. 15, 2006
Jean D. Jewell Secretary
I.P.U.C. No. 1 Original Sheet No. 24.5
ELECTRIC SERVICE SCHEDULE NO. 24 -Continued
PRIOR RIGHTS: Any right to service under this schedule shall be subject to any prior rights
established in Company's existing contracts with customers providing for the supply of interruptible service
and specifically rights of Monsanto Company and Amax including right of first refusal to interruptible
service.
CONTRACT PERIOD: One year or longer.
ELECTRIC SERVICE REGULATIONS: Service under this Schedule will be in
accordance with the terms of the Electric Service Agreement between the Customer and the Company. The
Electric Service Regulations of the Company on file with and approved by the Idaho Public Utilities
Commission, including future applicable amendments, will be considered as forming a part of and
incorporated in said Agreement.
Submitted Under Advice Letter No. 06-06
ISSUED: August 14, 2006 EFFECTIVE: September 15, 2006
Second Revision of Sheet No. 31.1
I.P.U.C. No. 1 Canceling First Revision of Sheet No. 31.1

(continued) Submitted Under Case No. PAC-E-21-07 ISSUED: November 8, 2021 EFFECTIVE: January 1, 2022
ROCKY MOUNTAIN POWER ELECTRIC SERVICE SCHEDULE NO. 31 STATE OF IDAHO ______________ Partial Requirements Service -- Large General Service – 1,000 kW and Over ______________ AVAILABILITY: At any point on the Company's interconnected system where there are facilities of adequate capacity. APPLICATION: This Schedule is for alternating current, three phase electric service supplied at Company’s available voltage through a single point of delivery for Supplementary, Back-up, Maintenance Power or Excess Service (partial requirements service) in addition to regular electric requirements obtained from any service other than the Company, including on-site generation. This Schedule is applicable to customers with on-site generation of more than 1,000 kW but that does not exceed 30,000 kW. Customers not contracting for Back-up Power shall not be subject to this Schedule and shall receive electric service under the applicable general service schedule. This Schedule is not applicable to service for resale, intermittent or highly fluctuating
loads, or seasonal use. This Schedule is not required where on-site generation is used only for emergency supply during times of utility outage. This Schedule is not available to loads in excess of 30,000 kW, a maximum power requirement in excess of 30,000 kW shall be deemed to exist when a Customer’s maximum
power requirement exceeds 30,000 kW in at least three (3) months of any continuous period of six (6) successive months.
MONTHLY BILL: Rate:
Customer Service Charge
Primary Voltage Transmission $114.00 $372.00 per Customer per Customer $114.00 $372.00 per Customer per Customer
Back-up Facilities Rate: Secondary Voltage
Primary Voltage Transmission Voltage
$8.14
$7.77 $5.73
per kW for all kW
per kW for all kW per kW for all kW
$6.65
$6.28 $4.32
per kW for all kW
per kW for all kW per kW for all kW
The Facilities Rate applies to the kW of Back-up Contract Power
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Feb. 1, 2022 Jan. 1, 2022
Per O.N. 35277
Jan Noriyuki Secretary
Fourth Revision of Sheet No. 31.2 I.P.U.C. No. 1 Canceling Third Revision of Sheet No. 31.2

(continued) Submitted Under Case No. PAC-E-21-07 ISSUED: November 8, 2021 EFFECTIVE: January 1, 2022
ELECTRIC SERVICE SCHEDULE NO. 31 - Continued MONTHLY BILL: Rate:
Back-up Power Rate: Secondary Voltage
Primary Voltage Transmission
$0.27
$0.26 $0.19
all kW Day
all kW Day all kW Day
$0.23
$0.22 $0.14
all kW Day
all kW Day all kW Day
minute period of the Customer's greatest use of Back-up Power during the day
Excess Power Rate: Secondary Voltage Primary Voltage Transmission Voltage Supplementary Power Rate: Secondary Voltage
Primary Voltage Transmission Voltage Supplementary and Back-up Energy Rate: Secondary Voltage Primary Voltage Transmission Voltage On-Peak Off-Peak
$29.44 $28.10 $20.62 $13.62
$12.97 $10.31
4.2506¢ 4.2506¢ 5.1115¢ 3.9086¢
per kW for all kW per kW for all kW per kW for all kW per kW for all kW
per kW for all kW per kW for all kW
per kWh per kWh per kWh per kWh
$24.21 $22.88 $15.55 $12.27
$11.62 $9.29
4.2506¢ 4.2506¢ 4.6365¢ 3.5213¢
per kW for all kW per kW for all kW per kW for all kW per kW for all kW
per kW for all kW per kW for all kW
per kWh per kWh per kWh per kWh
TIME PERIODS: On-Peak: November through May inclusive 6:00 a.m. to 9:00 a.m. and 6:00 p.m. to 11:00 p.m., all days. June through October inclusive
3:00 p.m. to 11:00 p.m., all days.
Off-Peak: All other times.
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Feb. 1, 2022 Jan. 1, 2022
Per O.N. 35277
Jan Noriyuki Secretary
First Revision of Sheet No. 31.3
I.P.U.C. No. 1 Canceling Original Sheet No. 31.3

Submitted Under Case No. PAC-E-21-07 ISSUED: November 8, 2021 EFFECTIVE: January 1, 2022
ELECTRIC SERVICE SCHEDULE NO. 31 - Continued POWER FACTOR: This rate is based on the Customer maintaining at all times a power factor of 85% lagging, or higher, as determined by measurement. If the average power factor is found to be less than 85% lagging, the Power as recorded by the Company’s meter will be increased by ¾ of 1% for every 1% that the
power factor is less than 85%. VOLTAGE LEVELS: Secondary Voltage applies where a distribution Customer takes service from
Company’s available lines of less than 2,300 volts. Primary Voltage applies where a distribution Customer takes service from Company’s available lines of 2,300 to less than 46,000 volts and provides and maintains all transformers and other necessary related equipment. Transmission Voltage applies where service is supplied at approximately 46,000 volts or greater through a single point of delivery. POWER: The kW as shown by or computed from the readings of Company's Power meter for the 15-minute period of Customer's greatest use during the month or day, adjusted for power factor as specified, determined to the nearest kW. TYPE OF SERVICE: Whether Power is considered scheduled maintenance, supplementary, back-up, or excess is determined as follows. When the Customer has pre-scheduled Maintenance Service, the power
measurements from 0 kW up to the level equal to the pre-scheduled Back-up Power shall be considered Scheduled Maintenance Power. Power measurements above the Scheduled Maintenance Power up to the level equal to the Supplementary Contract Power shall be considered supplementary power. Power measured above
the sum of the Scheduled Maintenance Power and Supplementary Contract Power level up to the Total Contract Power (the sum of the Supplementary Contract Power and the Back-up Contract Power) shall be considered Back-up Power. Power measurements in excess of Total Contract Power shall be considered Excess Power.
When the Customer has not pre-scheduled Maintenance Service, power measurements from 0 kW up to the level equal to the Supplementary Contract Power shall be considered Supplementary Power. Power measurements above the Supplementary Contract Power level but less than Total Contract Power (the sum of the Supplementary Contract Power and the Back-up Contract Power) shall be considered back-up power. Power measurements in excess of Total Contract Power shall be considered Excess Power. DEFINITIONS: BACK-UP CONTRACT POWER: The specified Power in kilowatts of Back-up Power that the Customer contracts with the Company to supply and which the Company agrees to have available for delivery to
the Customer in excess of which the Company is under no obligation to supply. The Back-up Contract Power shall be established by agreement between the Customer and the Company. The level of Back-up Contract Power shall not exceed the total output capacity of the Customer's generation facilities.

(continued)
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Feb. 1, 2022 Jan. 1, 2022
Per O.N. 35277
Jan Noriyuki Secretary
First Revision of Sheet No. 31.4
I.P.U.C. No. 1 Canceling Original Sheet No. 31.4

Submitted Under Case No. PAC-E-21-07 ISSUED: November 8, 2021 EFFECTIVE: January 1, 2022
ELECTRIC SERVICE SCHEDULE NO. 31 - Continued DEFINITIONS (continued): BACK-UP POWER – DAILY: The kW of Back-up Contract Power supplied by the Company to the
Customer. Back-up Power shall be determined for each day of the Billing Period. The kW of Back-up Power each day shall be the kW for the fifteen (15) minute period of the Customer's greatest use of Back-up Power that day, adjusted for power factor as specified, determined to the nearest kW. The Back-up Power for the Billing
Period shall be the sum of the Back-up Power for each day of the Billing Period. For each fifteen minute period, Back-up Power shall equal the Measured Power minus the Supplementary Contract Power but shall not be less than zero nor greater than the Back-up Contract Power.
BACK-UP SERVICE: Back-up service is electric service used by the Customer to replace electric service ordinarily generated by the Customer's own generation equipment during outages of the facility. BILLING PERIOD: The period of approximately 30 days intervening between regular successive meter reading dates. There shall be 12 billing periods per year. POWER: The rate in kilowatts at which electric energy is generated, transferred or used. Power
measurements are calculated based on the average (integrated) usage over consecutive 15 minute periods of time. Power measurements may be based on any one such fifteen minute period in a Billing Period, on the period of greatest use during the Billing Period, or on the period of greatest use during each day, adjusted for
power factor as specified, determined to the nearest kW.
EXCESS POWER: Excess Power is the power supplied by the Company to the Customer in excess of the Total Contract Power. The kW of Excess Power for the Billing Period shall be the kW for the 15 minute
period of the Customer's greatest use of Excess Power during the Billing Period, adjusted for power factor as specified, determined to the nearest kW. For each 15 minute period, Excess Power shall equal the Measured Power minus the Total Contract Power but shall not be less than zero. EXCESS SERVICE: Excess service is service used by the Customer over and above the contracted amount for both Supplementary Service and Back-up Service or Maintenance Service. MAINTENANCE SERVICE: Maintenance service is electric service used by the Customer to replace electric service ordinarily generated by the Customer's own generation equipment during scheduled outages of the facility.
MEASURED POWER: The kW as shown by or computed from the readings of the Power meter located at the Company's point of delivery, for the 15 minute period of the Customer’s greatest use during the Billing Period or that day. MEASURED ENERGY: The electric energy in kWh as shown by or computed from the readings of the kilowatt-hour meter located at the Company's point of delivery.
(continued)
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Feb. 1, 2022 Jan. 1, 2022
Per O.N. 35277
Jan Noriyuki Secretary

I.P.U.C. No. 1 First Revision of Sheet No. 31.5 Canceling Original Sheet No. 31.5
Submitted Under Case No. PAC-E-21-07 ISSUED: November 8, 2021 EFFECTIVE: January 1, 2022
ELECTRIC SERVICE SCHEDULE NO. 31 - Continued DEFINITIONS (continued): SCHEDULED MAINTENANCE POWER: Electric Power and energy made available by the Company to a Customer during the scheduled maintenance periods established in accordance with the
provisions of this schedule to replace Back-up Power. Scheduled Maintenance Power shall not exceed the Back-up Contract Power. SUPPLEMENTARY CONTRACT POWER: The specified Power in kW of Supplementary Power that the Customer contracts with the Company to supply and which the Company agrees to have available for delivery to the Customer. The Supplementary Contract Power shall be established by agreement between the Customer and the Company. Measured Power in excess of the Supplementary Contract Power shall not establish new Supplementary Contract Power. SUPPLEMENTARY POWER: The kW of Supplementary Contract Power supplied by the Company to the Customer. The kW of Supplementary Power for the Billing Period shall be the kW for the 15 minute period of the Customer's greatest use of Supplementary Power during the Billing Period, adjusted for power factor as specified, determined to the nearest kW. For each 15 minute period during the Billing Period, Supplementary Power shall equal the Measured Power but shall not be less than zero nor greater than the
Supplementary Contract Power. SUPPLEMENTARY SERVICE: Supplementary service is electric service regularly used by a
Customer in addition to that which the Customer generates itself. TOTAL CONTRACT POWER: The sum of the Supplementary Contract Power and the Back-up
Contract Power. SCHEDULED MAINTENANCE: Customer shall submit to the Company, in writing, Customer's proposed maintenance schedule and nominated Scheduled Maintenance Power for each month of an 18 month period beginning with the date of the Customer's initial receipt of service under this schedule. Customer shall, prior to September 1st of each subsequent year, submit to the Company, in writing, Customer's proposed maintenance schedule for each month of an 18 month period beginning with January 1st of the following year. The proposed schedules will not be deemed a request for Maintenance Service unless so designated by the Customer and accepted by the Company in writing. Maintenance shall be scheduled for a maximum of 30 days per year. These 30 days may be taken in either one continuous period, or two continuous 15 day periods. Solely at the discretion of the Company and for good cause, the maintenance maximum may be extended.
1. The Customer may present a request for a maintenance outage in writing to the Company no less than 30 days in advance of the date of the scheduled maintenance with the nominated Scheduled Maintenance Power. The Company reserves the right to modify Customer’s
requested maintenance schedule. Any modifications by the Company must be made with reason within seven days after that schedule has been received by the Company. (continued)
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Feb. 1, 2022 Jan. 1, 2022
Per O.N. 35277
Jan Noriyuki Secretary

I.P.U.C. No. 1 Original Sheet No. 31.6

Submitted Under Case No. PAC-E-12-12

ISSUED: August 13, 2012 EFFECTIVE: January 1, 2013
ELECTRIC SERVICE SCHEDULE NO. 31 – Continued

SCHEDULED MAINTENANCE (continued):

2. The Customer may request an adjustment in a scheduled maintenance outage up to 14 days in
advance of the expected maintenance. Company approval, or disapproval with reason, for such
adjustment shall be given within seven days of such request.

3. The Company may with reason cancel a scheduled maintenance outage at any time with seven
days notice prior to the beginning of a scheduled maintenance outage. Subject to the mutual
agreement of the Customer and the Company, that scheduled maintenance outage(s) canceled
by the Company may be rescheduled.

Total Contract Demand, Supplementary Contract Demand, and Back-up Contract Demand

The Customer shall contract for Total Contract Demand. This is the sum of the Supplementary Contract
Demand and the Back-up Contract Demand. The Customer may elect to increase Total Contract Demand by
increasing Supplementary Contract Demand and/or Back-up Contract Demand prospectively at any time,
provided there are facilities of adequate capacity, by providing notice to the Company. The Customer may elect
to increase Total Contract Demand by increasing Supplementary Contract Demand and/or Back-up Contract
Demand retroactively to the most recently completed Billing Period, provided there are facilities of adequate
capacity, by providing notice to the Company by the statement due date of the Billing Period. The
Supplementary Contract Demand may be reduced for a continuous period of each year provided that at least 12
month's written notice has been provided to the Company or as specified in contract. Only one request to reduce
Supplementary Contract Demand may be outstanding for each account. Customer may reduce Back-up Contract
Demand by providing written notice to PacifiCorp no less than six months in advance of the effective date of the
desired reduction, provided, only one such request may be made in any 12-month period. Within 15 days of
receipt of a timely written request by Customer, PacifiCorp shall advise Customer of the terms upon which
PacifiCorp would accept a reduction in contract demand. A period of reduction shall commence at the
beginning of a billing cycle and terminate at the end of a billing cycle.

FORCE MAJEURE: The Company shall not be subject to any liability or damages for inability to
provide service, and the Customer shall not be subject to any liability or damage for such inability to receive
service, to the extent that such inability shall be due to causes beyond the control of the party as specified in
Electric Service Regulation No. 4, Supply and Use of Service, Section 3. Should any of the foregoing occur, the
facilities charge shall be applied to only such Back-up Contract Demand as the Company is able to supply and
the Customer is able to receive and the minimum Billing Demand applicable to Supplemental Power under this
Schedule shall be waived. The Customer will have no liability for full service until such time as the Customer is
able to resume such service, except for any term minimum guarantees designed to cover special facilities
extension costs, if any. The party claiming Force Majeure under this provision shall make every reasonable
attempt to remedy the cause thereof as diligently and expeditiously as possible.

(continued)
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Dec. 28, 2012 Jan. 1, 2013
Per O.N. 32704
Jean D. Jewell Secretary

I.P.U.C. No. 1 Original Sheet No. 31.7

Submitted Under Case No. PAC-E-12-12

ISSUED: August 13, 2012 EFFECTIVE: January 1, 2013
ELECTRIC SERVICE SCHEDULE NO. 31 – Continued

CONTRACT PERIOD: One year or longer.

ELECTRIC SERVICE REGULATIONS: Service under this Schedule will be in accordance with
the terms of the Electric Service Agreement between the Customer and the Company. The Electric Service
Regulations of the Company on file with and approved by the Idaho Public Utilities Commission, including
future applicable amendments, will be considered as forming a part of and incorporated in said Agreement.

IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Dec. 28, 2012 Jan. 1, 2013
Per O.N. 32704
Jean D. Jewell Secretary
Ninth Revision of Sheet No. 34.1 I.P.U.C. No. 1 Canceling Eighth Revision of Sheet No. 34.1

Submitted Under Case No. PAC-E-23-19
ISSUED: August 30, 2023 EFFECTIVE: October 1, 2023
ROCKY MOUNTAIN POWER ELECTRIC SERVICE SCHEDULE NO. 34 STATE OF IDAHO ______________ Pacific Northwest Electric Power Planning and Conservation Act Residential and Farm Kilowatt-Hour Credit ______________ APPLICATION AND AVAILABILITY: This Schedule is applicable and available to qualifying
Residential and/or Farm Customers of the Company under the jurisdiction of the Idaho Public Utilities Commission.
MONTHLY RATES: The monthly charges for service under each of the Electric Service Schedules shown below shall be reduced by the appropriate kilowatt-hour credit for all qualifying kilowatt-hours of residential and/or farm use. Kilowatt-Hour Credit Adjustments: Irrigation Customers: $0.007376 per kWh Schedule No. 10 Non-Irrigation Customers: $0.007376 per kWh Schedule Nos. 1, 6A, 7A, 23A 35A, 36

(continued)
IDAHO PUBLIC UTILITIES COMMISSIONApproved EffectiveSept. 27, 2023 Oct. 1, 2023 Per ON 35933 Jan Noriyuki Secretary

First Revision of Sheet No. 34.2
I.P.U.C. No. 1 Canceling Original Sheet No. 34.2

Submitted Under Advice Letter No. 13-01

ISSUED: August 20, 2013 EFFECTIVE: October 1, 2013
ELECTRIC SERVICE SCHEDULE NO. 34 - Continued

MONTHLY RATES: (continued)
The above kilowatt-hour credit is subject to revision periodically, upon little or no notice, in order
that the monthly reduction in revenues may reflect the cost benefits received from the Bonneville Power
Administration under the Residential Purchase and Sale Agreement by and between the Bonneville Power
Administration, and Rocky Mountain Power (formerly Utah Power & Light Company) dated September 30,
1981.

BONNEVILLE POWER ADMINISTRATION BALANCING ACCOUNT: There shall be
established upon the books of account of the Company a balancing account. The account shall be used to
account for and record all amounts to be passed through to the Company's residential load in accordance
with the provisions of the Residential Purchase and Sale Agreement executed by the United States of
America, Department of Energy, acting by and through the Bonneville Power Administration and Rocky
Mountain Power (formerly Utah Power & Light Company) dated September 30, 1981.

Amounts included in this account shall be based upon the cost benefits resulting from transactions
with the Bonneville Power Administration and amounts actually passed through as credits to the Company's
customers.

The account and the kilowatt-hour credit herein shall be adjusted periodically to reflect actual net
cost benefits which result from the transactions with Bonneville Power Administration and to reflect the
actual credits passed through to the Company's customers. Following such adjustments, any balance in such
account, whether positive or negative, shall be carried forward and considered in determining to increase or
decrease the rate adjustment under this Electric Service Schedule 34.

Under no circumstances shall the Company be required to pass on credits to its customers under this
Electric Service Schedule which would exceed the net cost benefits received by the Company after all final
adjustments and any disallowance of benefits in connection with any transaction between the Company and
Bonneville Power Administration.

(continued)
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Sept. 30, 2013 Oct. 1, 2013
Jean D. Jewell Secretary

Second Revision of Sheet No. 34.3
I.P.U.C. No. 1 Canceling First Revision of Sheet No. 34.3

Submitted Under Advice Letter No. 13-01

ISSUED: August 20, 2013 EFFECTIVE: October 1, 2013
ELECTRIC SERVICE SCHEDULE NO. 34 - Continued

BONNEVILLE POWER ADMINISTRATION BALANCING ACCOUNT: (continued)
Should Bonneville Power Administration reduce cost benefit payments to the Company, for any
reason including determination that certain customers were not qualified under the Residential Purchase and
Sale Agreement to receive the kilowatt- hour credit then and in that event, the balancing account shall be
adjusted sufficiently to permit the Company to recover the amount of reduced cost benefit payments.

Any recoveries received from customers as provided in the qualifying Electric Service Schedules
shown above shall be included in the computation of the net cost benefits.

SPECIAL CONDITION:

1. Each person claiming a credit under eligible residential, general service, or irrigation
Electric Service Schedules listed on Sheet No. 34.1 with residential or farm electrical load at or above
100,000 kilowatt hours per year, and irrigation/pumping load at or above 250,000 kilowatt hours per year
shall file with the Company Bonneville Power Administration’s certificate to be eligible for Residential
Exchange Program benefits.

A residence is a structure used by one or more persons for daily living and associated activities. A
residence is eligible for REP benefits as long as its purpose is to provide shelter on a non-transient (greater
than 30 days) basis.

A farm consists of one or more parcels of land owned or leased by one or more persons or entities
(including partnerships, corporations, and any legal entity capable of owning farm land except the
government as defined as Federal, state, and local agencies in the Customer Load Eligibility Guidelines)
that is used primarily for agriculture.

A qualified irrigation/pumping load may receive benefits up to a maximum 400 horsepower per
month (222,000 kilowatt hours per month) of qualified irrigation/pumping load consumed by the specific
farm. If the owner of a large farm attempts to subdivide the farm into smaller parcels in order to increase the
amount of benefits, the farmer would be subverting the intent of Congress. Such subdivision is not
permitted.

Bonneville Power Administration’s Customer Load Eligibility Guidelines for the Residential
Exchange Program and Certificates shall be found at www.rockymountainpower.net/about/rar/iri/bpac.html#
under Regulatory Documents for Idaho.

IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Sept. 30, 2013 Oct. 1 2013
Jean D. Jewell Secretary
First Revision of Sheet No. 35.1
I.P.U.C. No. 1 Canceling Original Sheet No. 35.1

Submitted Under Case No. PAC-E-21-07 ISSUED: November 8, 2021 EFFECTIVE: January 1, 2022
ROCKY MOUNTAIN POWER ELECTRIC SERVICE SCHEDULE NO. 35 STATE OF IDAHO ______________ Optional Time-of-Day General Service - Distribution Voltage ______________ AVAILABILITY: At any point on the Company's interconnected system where there are facilities of adequate capacity to a limited number of customers each year on a priority basis, and is dependent upon the ability of the Company to obtain adequate metering equipment. The priority is based on the time the application is filed with the Company. Those customers applying first would have the highest priority.
APPLICATION: This Schedule is for alternating current, single or three-phase electric service supplied at Company's available voltage, but less than 46,000 volts through a single point of delivery for non-residential, non-irrigation, non-street lighting, and non-area lighting customers, for all service required
on the Customer's premises by Customers contracting for not more than 30,000 kW. Service under this Schedule is limited to a maximum power requirement of 30,000 kW. When a Customer's load reaches a level in excess of 30,000 kW, continued service will require special contract arrangements; provided,
however, that special contract arrangements will not be required in those cases where electric service is being supplied by Company under this Schedule to operations existing as of the effective date of this Schedule which, because of emergency conditions, or which on sporadic occasions only, may exceed 30,000 kW. This Schedule is not available to new loads in excess of 30,000 kW nor to existing operations whose maximum power requirements, because of increased operations, plant expansion or equipment additions, exceeds 30,000 kW. In this latter case, a maximum power requirement in excess of 30,000 kW shall be deemed to exist when a Customer's maximum power requirement exceeds 30,000 kW in at least three (3) months of any continuous period of six (6) successive months.

(Continued)
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Feb. 1, 2022 Jan. 1, 2022
Per O.N. 35277
Jan Noriyuki Secretary
Eleventh Revision of Sheet No. 35.2
I.P.U.C. No. 1 Canceling Tenth Revision of Sheet No. 35.2
Submitted Under Advice No. 23-01
ISSUED: January 18, 2023 EFFECTIVE: February 17, 2023
ELECTRIC SERVICE SCHEDULE NO. 35 - Continued
MONTHLY BILL: Customer Service Charge:
Secondary voltage delivery (Less than 2300 volts) $ 69.00 per Customer
Primary voltage delivery (2300 volts or higher) $170.00 per Customer
Power Charge: On-Peak kW $ 16.95 per kW
Energy Charge: Per kWh for all kWh 5.3792¢
TIME PERIODS: On-Peak 7:00 a.m. to 10:00 p.m., Monday thru Friday, except holidays. Off-Peak All other times.
Holidays include only New Year's Day, President's Day, Memorial Day, Independence Day, Labor Day, Thanksgiving Day, and Christmas Day. When a holiday falls on a Saturday or Sunday, the
Friday before the holiday (if the holiday falls on a Saturday) or the Monday following the holiday (if the holiday falls on a Sunday) will be considered a holiday and consequently Off-Peak.
Power Factor: This rate is based on the Customer maintaining at all times a Power factor of 85% lagging, or higher, as determined by measurement. If the average Power factor is found to be less than 85% lagging the Power as recorded by the Company's meter will be increased by 3/4 of 1% for every 1% that the Power factor is less than 85%.
Voltage Discount: Where Customer takes service from Company's available lines of 2,300 volts or
higher and provides and maintains all transformers and other necessary equipment, the voltage discount based on highest measured Power during the billing cycle will be: $0.84 per kW
Minimum: Customer Service Charge plus applicable Demand and Energy charges.
(Continued)
IDAHO PUBLIC UTILITIES COMMISSIONApproved EffectiveFeb. 7, 2023 Feb. 17, 2023 Jan Noriyuki Secretary
Fifth Revision of Sheet No. 35.3
I.P.U.C. No. 1 Canceling Fourth Revision of Sheet No. 35.3

Submitted Under Case No. PAC-E-21-07 ISSUED: November 8, 2021 EFFECTIVE: January 1, 2022
ELECTRIC SERVICE SCHEDULE NO. 35 - Continued
POWER: The On-Peak kW shall be the kW as shown by or computed from the readings of Company's Power meter for the 15-minute period of Customer's greatest use during the On-Peak periods
during the month as previously defined, adjusted for Power Factor as specified, determined to the nearest kW.
SEASONAL SERVICE: Service for annually recurring periods of seasonal use where service is normally discontinued or curtailed during a part of the year may be contracted for under this schedule under either of the following conditions: (a) Customer may contract for service under this schedule on a year-round basis paying for all service, including transformer losses where applicable, under the rates set forth under "Monthly Bill" above including the monthly minimum bill during those months service is curtailed or is not utilized in the Customer's operation. (b) Customer may contract for seasonal service under this schedule with a net minimum seasonal payment as follows:
$ 828.00 plus Power and Energy Charges for Customer taking service at less than 2300 volts, and
$2,040.00 plus Power and Energy Charges for Customer taking service at 2300 volts or higher.
CONTRACT PERIOD: One year or longer. ELECTRIC SERVICE REGULATIONS: Service under this Schedule will be in accordance with the terms of the Electric Service Agreement between the Customer and the Company. The Electric Service Regulations of the Company on file with and approved by the Idaho Public Utilities Commission, including future applicable amendments, will be considered as forming a part of and incorporated in said Agreement.
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Feb. 1, 2022 Jan. 1, 2022
Per O.N. 35277
Jan Noriyuki Secretary
First Revision of Sheet No. 35A.1
I.P.U.C. No. 1 Canceling Original Sheet No. 35A.1

Submitted Under Case Letter No. PAC-E-21-07 ISSUED: November 8, 2021 EFFECTIVE: January 1, 2022
ROCKY MOUNTAIN POWER ELECTRIC SERVICE SCHEDULE NO. 35A STATE OF IDAHO ______________ Optional Time-of-Day General Service - Distribution Voltage (Farm) ______________ AVAILABILITY: This Electric Service Schedule is available at any point on the Company's interconnected system where there are facilities of adequate capacity to a limited number of customers each year on a priority basis. Such availability is dependent upon the ability of the Company to obtain adequate metering equipment. The priority is based on the time the application is filed with the Company. Those
customers applying first would have the highest priority. This schedule is for service to any customer who qualifies as "Farm Load" under both (1) the Pacific Northwest Electric Power Planning and Conservation Act, P.L. 96-501 as the same may be amended, and (2) a Residential Purchase and Sale Agreement, under
Section 5(c) of such Act and in effect between the Company and the Bonneville Power Administration. APPLICATION: This Schedule is for alternating current, single or three-phase electric service
supplied at Company's available voltage, but less than 46,000 volts through a single point of delivery for non-residential, non-irrigation, non-street lighting, and non-area lighting customers, for all service required on the Customer's premises by Customers contracting for not more than 30,000 kW. Service under this Schedule is limited to a maximum power requirement of 30,000 kW. When a Customer's load reaches a level in excess of 30,000 kW, continued service will require special contract arrangements; provided, however, that special contract arrangements will not be required in those cases where electric service is being supplied by Company under this Schedule to operations existing as of the effective date of this Schedule which, because of emergency conditions, or which on sporadic occasions only, may exceed 30,000 kW. This Schedule is not available to new loads in excess of 30,000 kW nor to existing operations whose maximum power requirements, because of increased operations, plant expansion or equipment additions, exceeds 30,000 kW. In this latter case, a maximum power requirement in excess of 30,000 kW shall be
deemed to exist when a Customer's maximum power requirement exceeds 30,000 kW in at least three (3) months of any continuous period of six (6) successive months.
(Continued)

IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Feb. 1, 2022 Jan. 1, 2022
Per O.N. 35277
Jan Noriyuki Secretary
Eleventh Revision of Sheet No. 35A.2 I.P.U.C. No. 1 Canceling Tenth Revision of Sheet No. 35A.2
Submitted Under Advice No. 23-01
ISSUED: January 18, 2023 EFFECTIVE: February 17, 2023
ELECTRIC SERVICE SCHEDULE NO. 35A - Continued
MONTHLY BILL: Customer Service Charge: Secondary voltage delivery
(Less than 2300 volts) $ 69.00 per Customer
Primary voltage delivery
(2300 volts or higher) $170.00 per Customer
Power Charge: On-Peak kW $ 16.95 per kW
Energy Charge:
Per kWh for all kWh 5.3792¢
TIME PERIODS: On-Peak 7:00 a.m. to 10:00 p.m., Monday thru Friday, except holidays.
Off-Peak All other times.
Holidays include only New Year's Day, President's Day, Memorial Day, Independence Day, Labor Day, Thanksgiving Day, and Christmas Day. When a holiday falls on a Saturday or Sunday, the Friday before the holiday (if the holiday falls on a Saturday) or the Monday following the holiday (if the holiday falls on a Sunday) will be considered a holiday and consequently Off-Peak.
Power Factor: This rate is based on the Customer maintaining at all times a Power factor of 85%
lagging, or higher, as determined by measurement. If the average Power factor is found to be less than 85% lagging the Power as recorded by the Company's meter will be increased by 3/4 of 1% for every 1% that the Power factor is less than 85%.
Voltage Discount: Where Customer takes service from Company's available lines of 2,300 volts or higher and provides and maintains all transformers and other necessary equipment, the voltage discount based on highest measured Power during the billing cycle will be:
$0.84 per kW
Minimum: Customer Service Charge plus applicable Demand and Energy charges.
(Continued)
IDAHO PUBLIC UTILITIES COMMISSIONApproved EffectiveFeb. 7, 2023 Feb. 17, 2023 Jan Noriyuki Secretary
Fifth Revision of Sheet No. 35A.3
I.P.U.C. No. 1 Canceling Fourth Revision of Sheet No. 35A.3

Submitted Under Case No. PAC-E-21-07 ISSUED: November 8, 2021 EFFECTIVE: January 1, 2022
ELECTRIC SERVICE SCHEDULE NO. 35A - Continued
MONTHLY BILLING REDUCTION: Rates in this schedule shall be reduced by the monthly kilowatt-hour credit adjustment set forth under "Monthly Rates" in the currently effective Electric Service
Schedule No. 34. POWER: The On-Peak kW shall be the kW as shown by or computed from the readings of
Company's Power meter for the 15-minute period of Customer's greatest use during the On-Peak periods during the month as previously defined, adjusted for Power Factor as specified, determined to the nearest kW. SEASONAL SERVICE: Service for annually recurring periods of seasonal use where service is normally discontinued or curtailed during a part of the year may be contracted for under this schedule under either of the following conditions: (a) Customer may contract for service under this schedule on a year-round basis paying for all service, including transformer losses where applicable, under the rates set forth under "Monthly Bill" above including the monthly minimum bill during those months service is
curtailed or is not utilized in the Customer's operation. (b) Customer may contract for seasonal service under this schedule with a net minimum
seasonal payment as follows: $ 828.00 plus Power and Energy Charges for Customer taking service at less than
2300 volts, and $2,040.00 plus Power and Energy Charges for Customer taking service at 2300 volts or higher. CONTRACT PERIOD: One year or longer. SPECIAL CONDITION: Farm use means all usual farm electrical loads for raising of crops, livestock or pasturage and includes primary processing necessary for safe and efficient storage or shipment. Contiguous parcels of land under single-ownership or leasehold shall be considered to be one Farm and noncontiguous parcels of land under single-ownership or leasehold shall be considered as one Farm unit
when operated as a single Farm, unless demonstrated otherwise by the owner or lessee of the parcels.
(Continued)

IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Feb. 1, 2022 Jan. 1, 2022
Per O.N. 35277
Jan Noriyuki Secretary
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Aug. 28, 2006 Sept. 15, 2006
Jean D. Jewell Secretary
I.P.U.C. No. 1 Original Sheet No. 35A.4
ELECTRIC SERVICE SCHEDULE NO. 35A -Continued
SPECIAL CONDITION: (continued)
A number of factors shall determine whether contiguous or noncontiguous parcels constitute one or
more Farms. These factors shall include, but are not limited to:
--size
--use
--ownership
--control
--operating practices
--distance between parcels
--custom in the trade
--billing treatment by the utility
Customers who feel they meet the definitions of a Farm will have to make application with the
Company for review. If Customer application is denied by the Company, the customer may appeal the
decision to the Idaho Public Utilities Commission.
ELECTRIC SERVICE REGULATIONS: Service under this Schedule will be in accordance with
the terms of the Electric Service Agreement between the Customer and the Company. The Electric Service
Regulations of the Company on file with and approved by the Idaho Public Utilities Commission, including
future applicable amendments, will be considered as forming a part of and incorporated in said Agreement.
Submitted Under Advice Letter No. 06-06
ISSUED: August 14, 2006 EFFECTIVE: September 15, 2006
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Aug. 28, 2006 Sept. 15, 2006
Jean D. Jewell Secretary
I.P.U.C. No. 1
ROCKY MOUNTAIN POWER
ELECTRIC SERVICE SCHEDULE NO. 36
STATE OF IDAHO
Optional Time of Day -Residential Service
Original Sheet No. 36.1
AVAILABILITY: At any point on the Company's interconnected system where there are facilities
of adequate capacity.
APPLICATION: This Schedule is for alternating current electric service supplied at
approximately 120 or 240 volts through one kilowatt-hour meter at a single point of delivery for all service
required on the premises for Residential purposes.
When conditions are such that service is supplied through one meter to more than one dwelling or
apartment unit, the charge for such service will be computed by multiplying the number of kWh in each
block and the minimum charges by the maximum number of dwelling or apartment units that may be served.
When a portion of a dwelling is used regularly for business, professional or other gainful purposes,
the premises will be classified as nonresidential and the appropriate schedule applied. However, if the
wiring is so arranged that the service for Residential purposes can be metered separately, this Schedule will
be applied to such service.
(Continued)
Submitted Under Advice Letter No. 06-06
ISSUED: August 14, 2006 EFFECTIVE: September 15, 2006
Fourteenth Revision of Sheet No. 36.2 I.P.U.C. No. 1 Canceling Thirteenth Revision of Sheet No. 36.2

Submitted Under Case No. PAC-E-22-15
ISSUED: June 9, 2023 EFFECTIVE: June 1, 2023
ELECTRIC SERVICE SCHEDULE NO. 36 - Continued MONTHLY BILL: 6/1/2023 6/1/2024 6/1/2025 6/1/2026 6/1/2027 to to to to 5/31/2024 5/31/2025 5/31/2026 5/31/2027 Customer Service Charge
Energy Charge (¢/kWh)
Seasonal Service Charge
On Peak: Before June 1, 2025 - May through October inclusive 8:00 a.m. to 11:00 p.m., Monday through Friday, except holidays.
November through April inclusive 7:00 a.m. to 10:00 p.m., Monday through Friday, except holidays. Holidays include only: New Year's Day, President's Day, Memorial Day, Independence Day, Labor Day, Thanksgiving Day, and Christmas Day. On and after June 1, 2025 - June through October inclusive 3:00 p.m. to 11:00 p.m., all days. November through May inclusive 6:00 a.m. to 9:00 a.m. and 6:00 p.m. to 11:00 p.m., all days.
Off Peak:
All other kWh usage.
SEASONAL SERVICE: When seasonable service is supplied under this Schedule, the minimum seasonal charge will be applied plus energy charges.
CONTRACT PERIOD: One year or longer. MONTHLY BILLING REDUCTION: Rates in this schedule shall be reduced by the monthly
kilowatt-hour credit adjustment set forth under “Monthly Rates” in the currently effective Electric Service Schedule No. 34. (Continued)
IDAHO PUBLIC UTILITIES COMMISSIONApproved EffectiveJuly 6, 2023 June 1, 2023 Per ON 35843 Jan Noriyuki Secretary
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
July 24, 2006 March 1, 2007
Jean D. Jewell Secretary
I.P.U.C. No. 1 First Revised Sheet No. 36.3
Canceling Original Sheet No. 36.3
ELECTRIC SERVICE SCHEDULE NO. 36 -Continued
ELECTRIC SERVICE REGULATIONS: Service under this Schedule will be in accordance
with the terms of the electric Service Agreement between the Customer and the Company. The Electric
Service Regulations of the Company on file with and approved by the Idaho Public Utilities Commission,
including future applicable amendments, will be considered as forming a part of and incorporated in said
Agreement.
Submitted Under Advice No. 06-05
ISSUED: July 5, 2006 EFFECTIVE: March 1, 2007

I.P.U.C. No. 1 Original Sheet No. 38.1

Submitted Under Case No. PAC-E-16-01

ISSUED: January 13, 2016 EFFECTIVE: April 15, 2016
ROCKY MOUNTAIN POWER

ELECTRIC SERVICE SCHEDULE NO. 38

STATE OF IDAHO

______________

Qualifying Facility Avoided Cost Procedures
______________
PREFACE:
1. The process outlined in this Schedule is typically applicable to projects already under
development.

2. All submissions, responses and notices required in this Schedule must be done in
electronic or hard copy format. Requests and information may be submitted to the
Company at [e-mail] .

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
[e-mail]

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
[e-mail]

B. Procedures

Generally, the interconnection process involves (1) initiating a request for
interconnection, (2) completion of studies to determine the system impacts associated
with the interconnection and the design, cost, and schedules for constructing any
necessary interconnection facilities, (3) execution of an interconnection agreement.

The QF project owner is responsible for all interconnection costs assessed by the
Company on a nondiscriminatory basis.

For interconnections greater than twenty (20) megawatts, the Company will process
the interconnection application through PacifiCorp Transmission Services generally
following the procedures for studying the generation interconnection described in the
Company’s Open Access Transmission Tariff, PacifiCorp FERC Electric Tariff, Fifth
Revised Volume No. 11 Pro Forma Open Access Transmission Tariff (OATT), as the
same may be changed or updated, on file with the Federal Energy Regulatory
Commission (FERC). A copy of the OATT is available on-line at
http//www.oasis.pacificorp.com.

The Company’s interconnection forms and agreements, are provided electronically at the
following address: http://www.pacificorp.com/tran/ts/gip/qf.html
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
March 3, 2016 April 15, 2016
Per O.N. 33474
Jean D. Jewell Secretary

I.P.U.C. No. 1 Original Sheet No. 38.11

Submitted Under Case No. PAC-E-16-01

ISSUED: January 13, 2016 EFFECTIVE: April 15, 2016
ELECTRIC SERVICE SCHEDULE NO. 38 - Continued

III. Process for Filing a Complaint with the Commission on Contract Terms

The Commission has both informal and formal dispute resolution processes which can
be reviewed on the Commission website at the following
address: http://www.puc.idaho.gov/forms/consumerassistance

These processes are available for any matter as to which the Commission has
jurisdiction, which may include (i) QF PPA contracts, (ii) small QF interconnection
agreements (less than 20 MW), and (iii) large QF interconnection agreements (more
than 20 MW), so long as all of the QF output is sold exclusively to the Company. To
the extent any portion of the QF output is sold to anyone other than the Company, a
QF generation interconnection may be subject to FERC jurisdiction. Nothing in this
Schedule will affect the jurisdiction of the Commission or FERC, and all parties will
retain any and all rights they may have under any applicable state or federal statutes
or regulations.

IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
March 3, 2016 April 15, 2016
Per O.N. 33474
Jean D. Jewell Secretary
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Feb. 6, 2020 Jan. 1, 2020
Per O.N. 34545
Diane M. Hanian Secretary
--..
I.P.U.C. No. 1 Fifth Revision of Sheet No. 70.1
Canceling Fourth Revision of Sheet No. 70.1
ROCKY MOUNTAIN POWER
ELECTRIC SERVICE SCHEDULE NO. 70
STATE OF IDAHO
Renewable Energy
Rider -Optional
AVAILABILITY: In all territory served by the Company in the state of Idaho.
APPLICATION: To Customers receiving service under the Company's Electric Service
Schedules.
ADMINISTRATION: Funds received from Customers under this Schedule will cover program
costs and match Renewable Energy purchases to Block purchases. Funds not spent after covering program
costs and matching Renewable Energy purchases may be used to fund Qualifying Initiatives as defined
below.
BLOCK: I Block equals 200 kWh of Renewable Energy.
CHARGE PER BLOCK: $1.95 per month
MONTHLY BILL: The Monthly Bill shall be the number of Blocks the Customer has agreed to
purchase multiplied by the Charge per Block. The Monthly Bill is in addition to all other charges contained
in Customer's applicable tariff schedule. This rider 's Monthly Bill shall be applied to the Customer's billing
regardless of actual energy consumption.
RENEWABLE ENERGY: Renewable Energy includes bundled power or Renewable Energy
Credits (RECs) derived from the following fuels:
• wind;
• solar
• geothermal energy;
• certified low impact hydroelectric;
• hydrogen derived from photovoltaic electrolysis or a non-hydrocarbon derivation process;
• pipeline or irrigation canal hydroelectric systems;
• wave or tidal action; and
Submitted Under Case No. PAC-E-19-17
ISSUED: October 24, 2019
(Continued)
EFFECTIVE: January 1, 2020
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
April 23, 2007 May 1, 2007
Jean D. Jewell Secretary
I.P.U.C. No. 1 First Revision of Sheet No. 70.2
Canceling Original Sheet No. 70.2
ELECTRIC SERVICE SCHEDULE NO. 70 -CONTINUED
RENEWABLE ENERGY: (continued)
• low emissions biomass based on digester methane gas from landfills, sewage treatment
plants or animal waste and biomass energy based on solid organic fuels from wood, forest or
field residues or dedicated crops that do not include wood pieces that have been treated with
chemical preservatives such as creosote, pentachlorophenol or copper chrome arsenic.
Renewable Energy Credits (also known as Tradable Renewable Energy Credits, Renewable Energy
Certificates, Green Tags or Carbon Credits) represent all of the regional and global environmental and
emissions benefits associated with one unit of output from a qualifying renewable electricity generating
resource. In some markets, the credits are certified by an independent third party and include a serial number
for tracking purposes.
Offering must consist of 100% new Renewable Energy.
New Renewable Energy is (1) placed in operation (generating electricity) on or after January 28,
2000; (2) repowered on or after January 28, 2000 such that 80% of the fair market value of the project
derives from new generation equipment installed as part of the repowering, or (3) a separable improvement
to or enhancement of an operating existing facility that was first placed in operation prior to January 28,
2000, such that the proposed incremental generation is contractually available for sale and metered
separately than existing generation at the facility. Any enhancement of a fuel source that increases
generation at an existing facility, without the construction of a new or repowered, separately metered
generating unit, is not eligible to participate.
Preference will be given to resources within Pacific Power & Light Company and Rocky Mountain
Power service territories.
Renewable Energy purchases made to match Customer Block purchases are in addition to
investments associated with the Company's Integrated Resource Plan, and are not considered for purposes of
any Renewable Portfolio Standard requirements. Renewable Energy generated in response to any federal or
state statutory requirement to construct or contract for the Renewable Energy is not eligible.
(Continued)
Submitted Under Advice Letter No. 07-04
ISSUED: March 26, 2007 EFFECTIVE: May 1, 2007
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
April 6, 2009 April 12, 2009
Jean D. Jewell Secretary
ROCKY MOUNTAIN
POWER
A DIVISION OF PACIFICORP
I.P.U.C. No. 1
Second Revision of Sheet No. 70.3
Canceling First Revision of Sheet No. 70.3
ELECTRIC SERVICE SCHEDULE NO. 70 -CONTINUED
QUALIFYING INITIATIVES:
l. Funding for locally-owned commercial-scale Renewable Energy projects that produce less
than 10 MW of electricity. The preference is for local community based projects that
provide strong environmental and economic benefit to local communities and Customers the
Company services under this Schedule.
2. Funding for research and development projects encouraging Renewable Energy market
transformation in order to accelerate marketability of Renewable Energy technologies.
3. Investment in the above market costs associated with the construction of Renewable Energy
facilities or purchase by contract of Renewable Energy, reducing the costs of Renewable
Energy to be competitive with cost-effective resources.
4. To the extent a project in paragraphs 1, 2, and 3 above is able to generate RECs, the
recipient agrees that the Company has the right to claim a share of the project's REC output.
The share amount is expressed as a percentage of output when comparing the Company's
financial contribution to the overall cost of the project. The share amount of these RECs
will be retired on behalf of program participants across the Company's service territories.
The Company will also be given the opportunity to purchase additional RECs off the
project.
5. Qualifying Initiatives are not considered for purposes of any Renewable Portfolio Standard
requirements. Renewable Energy generated in response to any federal or state statutory
requirement to construct or contract for The Renewable Energy is not eligible.
SPECIAL CONDITIONS:
1. Customers may apply for this Schedule anytime during the year.
2. The Company may accept enrollments for accounts that have a time-payment agreement in
effect, or have received two or more disconnect notices, or have been disconnected within
the last 12 months.
3. The Company will purchase Renewable Energy within two years of a Customer's purchase.
(Continued)
Submitted Under Advice Letter No. 09-02
ISSUED: March 11, 2009 EFFECTIVE: April 12, 2009
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
April 23, 2007 May 1, 2007
Jean D. Jewell Secretary
I.P.U.C. No. 1 Original Sheet No. 70.4
ELECTRIC SERVICE SCHEDULE NO. 70 -CONTINUED
SPECIAL CONDITIONS: ( continued)
4. To ensure that all costs and benefits of this program are isolated to the participants
of this program, all funds collected under this program will be separately identified
and tracked. On the effective date of this Schedule, the Company will establish a
regulatory liability for all funds collected and will debit the regulatory liability as
funds are spent. The Company will endeavor to match spending to collection within
each calendar year.
ELECTRIC SERVICE REGULATIONS: Service under this Schedule will be in
accordance with the terms of the Electric Service Agreement between the Customer and the
Company. The Electric Service Regulations of the Company on file with and approved by the
Idaho Public Utilities Commission, including future applicable amendments, will be considered as
forming a part of and incorporated in said Agreement.
Submitted Under Advice Letter No. 07-04
ISSUED: March 26, 2007 EFFECTIVE: May 1, 2007
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Feb. 6, 2020 Jan. 1, 2020
Per O.N. 34545
Diane M. Hanian Secretary
I.P.U.C. No. 1 Fourth Revision of Sheet No. 73.1
Canceling Third Revision of Sheet No. 73.1
ROCKY MOUNTAIN POWER
ELECTRIC SERVICE SCHEDULE NO. 73
STATE OF IDAHO
Renewable Energy
Rider -Optional
Bulk Purchase Option
AVAILABILITY: In all territory served by the Company in the state ofldaho.
APPLICATION: To Customers receiving service under The Company's non-residential
Electric Service Schedules.
ADMINISTRATION: Funds received from Customers under this Schedule will cover
program costs and match Renewable Energy purchases to Block purchases. Funds not spent after
covering program costs and matching Renewable Energy purchases to Block purchases may be
used to fund Qualifying Initiatives as defined below.
BLOCK: 1 Block equals 200 kWh of Renewable Energy. This program requires a
minimum purchase of 1,212 Blocks per year. For the purpose of qualifying for this Schedule,
Customers with multiple sites can sum their Block purchases across all Pacific Power and Rocky
Mountain Power service territories to meet the minimum purchase requirement.
CHARGE PER BLOCK: $0.70 per month
Plus $1,500.00 per year fixed charge
For Purchase commitments over two years in length or large purchases over 75,000 MWh
per year, individually negotiated arrangements may be available, pursuant to the execution of a
written contract.
CHARGE: The Charge can be billed either monthly, twice yearly or annually and shall be
the number of Blocks the Customer has agreed to purchase multiplied by the Charge per Block,
plus the $1,500 yearly fixed charge divided between the customer's billing choice (monthly, twice
yearly or annually) and added to the Customer's standard bill. The Charge is in addition to all
other charges contained in Customer's applicable tariff schedule. This rider's Charge shall be
applied to the Customer's billing regardless of actual energy consumption.
( continued)
Submitted Under Case No. PAC-E-19-17
FILED: October 24, 2019 EFFECTIVE: January 1, 2020
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Feb. 09, 2010 Feb. 12, 2010
Jean D. Jewell Secretary
ROCKY MOUNTAIN
POWER
A DIVISION OF PACIFICORP
I.P.U.C. No. 1 Second Revision of Sheet No. 73.2
Canceling First Revision of Sheet No. 73.2
ELECTRIC SERVICE SCHEDULE NO. 73 -Continued
RENEW ABLE ENERGY: Renewable Energy includes bundled power or Renewable
Energy Credits (RECs) derived from the following fuels:
• wind;
• solar;
• geothermal energy;
• certified low impact hydroelectric;
• hydrogen derived from photovoltaic electrolysis or a non-hydrocarbon
derivation process;
• pipeline or irrigation canal hydroelectric systems;
• wave or tidal action; and
• low emissions biomass based on digester methane gas from landfills, sewage
treatment plants or animal waste and biomass energy based on solid organic
fuels from wood, forest or field residues or dedicated crops that do not
include wood pieces that have been treated with chemical preservations such
as creosote, pentachlorophenol or copper chrome arsenic.
Renewable Energy Credits ( also known as Tradable Renewable Energy Credits, Renewable
Energy Certificates, Green Tags or Carbon Credits) represent all of the regional and global
environmental and emissions benefits associated with one unit of output from a qualifying
renewable electricity generating resource. In some markets, the credits are certified by an
independent third party and include a serial number for tracking purposes.
Offering must consist of 100% new Renewable Energy.
New Renewable Energy is (1) placed in operation (generating electricity) on or after January
28, 2000; (2) repowered on or after January 28, 2000 such that 80% of the fair market value of the
project derives from new generation equipment installed as part of the repowering, or (3) a
separable improvement to or enhancement of an operating existing facility that was first placed in
operation prior to January 28, 2000, such that the proposed incremental generation is contractually
available for sale and metered separately than existing generation at the facility. Any enhancement
of a fuel source that increases generation at an existing facility, without the construction of a new or
repowered, separately metered generating unit, is not eligible to participate.
Preference will be given to resources within Pacific Power & Light Company and Rocky
Mountain Power service territories.
( continued)
Submitted Under Advice Letter No. 10-01
FILED: January 13, 2010 EFFECTIVE: February 12, 2010
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Aug. 9, 2007 Aug. 27, 2007
Jean D. Jewell Secretary
I.P.U.C. No. 1 First Revision of Sheet No. 73.3
Canceling Original Sheet No. 73.3
ELECTRIC SERVICE SCHEDULE NO. 73 -Continued
RENEWABLE ENERGY: (continued)
Renewable Energy purchases made to match Customer Block purchases are in addition to
investments associated with the Company's Integrated Resource Plan, and are not considered for
purposes of any Renewable Portfolio Standard requirements. Renewable Energy generated in
responses to any federal or state statutory requirement to construct or contract for the Renewable
Energy is not eligible.
QUALIFYING INITIATIVES
1. Funding for locally-owned commercial-scale Renewable Energy projects that
produce less than 10 MW of electricity. The preference is for local community
based projects that provide strong environmental and economic benefit to local
communities and Customers the Company services under this Schedule.
2. Funding for research and development projects encouraging Renewable Energy
market transformation in order to accelerate marketability of Renewable Energy
technologies.
3. Investment in the above market costs associated with the construction of Renewable
Energy facilities or purchase by contract of Renewable Energy, reducing the costs of
Renewable Energy to be competitive with cost-effective resources.
4. To the extent a project in paragraphs 1, 2, and 3 above is able to generate RECs, the
recipient agrees that the Company has the right to claim a share of the project's REC
output. The share amount is expressed as a percentage of output when comparing
the Company's financial contribution to the overall cost of the project. The share
amount of these RECs will be retired on behalf of program participants across the
Company's service territories. The Company will also be given the opportunity to
purchase additional RECs off the project.
5. Qualifying Initiatives are not considered for purposes of any Renewable Portfolio
Standard requirements. Renewable Energy generated in response to any federal or
state statutory requirement to construct or contract for the Renewable Energy is not
eligible.
( continued)
Submitted Under Advice Letter No. 07-10
FILED: July 26, 2007 EFFECTIVE: August 27, 2007
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
April 6, 2009 April 12, 2009
Jean D. Jewell Secretary
✓ ROCKY MOUNTAIN
POWER
A DIVISION OF PACIFICORP
I.P.U.C. No. 1 First Revision of Sheet No. 73.4
Canceling Original Sheet No. 73.4
ELECTRIC SERVICE SCHEDULE NO. 73 -Continued
SPECIAL CONDITIONS:
1. Customers may apply for this Schedule anytime during the year.
2. The Company may accept enrollments for accounts that have a time-payment
agreement in effect, or have received two or more disconnect notices, or have been
disconnected within the last 12 months.
3. The Company will purchase Renewable Energy within two years of a Customer's
purchase.
4. To ensure that all costs and benefits of this program are isolated to the participants of
this program, all funds collected under this program will be separately identified and
tracked. On the effective date of this Schedule, the Company will establish a
regulatory liability for all funds collected and will debit the regulatory liability as
funds are spent. The Company will endeavor to match spending to collection within
each calendar year.
ELECTRIC SERVICE REGULATIONS: Service under this Schedule will be in
accordance with the terms of the Electric Service Agreement between the Customer and the
Company. The Electric Service Regulations of the Company on file with and approved by the
Idaho Public Utilities Commission, including future applicable amendments, will be considered as
forming a part of and incorporated in said Agreement.
Submitted Under Advice Letter No. 09-02
FILED: March 24, 2009 EFFECTIVE: April 12, 2009
Twelfth Revision of Sheet No. 94.1 I.P.U.C. No. 1 Canceling Eleventh Revision of Sheet No. 94.1
Submitted Under Case No. PAC-E-21-07 ISSUED: November 24, 2021 EFFECTIVE: January 1, 2022
ROCKY MOUNTAIN POWER
ELECTRIC SERVICE SCHEDULE NO. 94 STATE OF IDAHO ______________ Energy Cost Adjustment ______________ AVAILABILITY: At any point on the Company’s interconnected system.
APPLICATION: This Schedule shall be applicable to all retail tariff Customers taking service under the Company’s electric service schedules. ENERGY COST ADJUSTMENT: The Energy Cost Adjustment is calculated to collect the accumulated difference between total Company Base Net Power Cost and total Company Actual Net Power Cost calculated on a cents per kWh basis. MONTHLY BILL: In addition to the Monthly Charges contained in the Customer's applicable schedule, all monthly bills shall have applied the following cents per kilowatt-hour rate by delivery voltage.

IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Feb. 1, 2022 Jan. 1, 2022
Per O.N. 35277
Jan Noriyuki Secretary
First Revison of Sheet 114.1 I.P.U.C. No. 1 Canceling Original Sheet No. 114.1

Submitted Under Case No. PAC-E-22-13 FILED: May 10, 2023 EFFECTIVE: April 1, 2023
ROCKY MOUNTAIN POWER ELECTRIC SERVICE SCHEDULE NO. 114 STATE OF IDAHO
_____________________ Load Management Program
_____________________ APPLICABLE: This tariff is applicable to eligible Customers who have premises located in designated areas. Customers served by the Company in the state of Idaho taking service under the
Company’s electric service schedules listed on Schedule 191 – Customer Efficiency Services Rate Adjustment located within the designated areas are eligible to participate in a Load Management Program (Program).
PURPOSE: To manage electric loads through a Company-dispatched Direct Load Control
System (System). PROGRAM DESCRIPTION: Detailed descriptions of Programs can be found on the Company website.
CUSTOMER PARTICIPATION: Participating premises are considered Program participants for the duration of the Program(s). Customers may cancel their participation in the Program(s) at any time. The Company or its Program contractors shall have the right to qualify program participants, at their sole discretion based on criteria the Company or Program contractors consider necessary to ensure
the effective operation of the Program(s) and utility System. Program details can be viewed on the Company’s website.
PROVISIONS OF SERVICE FOR LOAD MANAGEMENT PROGRAMS:
1. Qualifying Equipment or Services, incentive amounts, and participation procedures will be listed on the program website. 2. Incentive delivery may vary by technology and may include cash payments and/or bill credits. Incentive payouts for the Wattsmart Battery 5-Year Pilot Program will be available through 2031.
3. Incentives may be offered year-round or for selected time periods. 4. Incentive offer availability, incentive levels, and Qualifying Equipment or Services may be changed to reflect changing codes and standards, sales volumes, quality assurance data, or to enhance program cost effectiveness.
5. All changes will occur with a minimum of 45 days notice and be prominently displayed as a change on the Company’s website. ELECTRIC SERVICE REGULATIONS: Service under this Schedule will be in accordance with the terms of the Electric Service Agreement between the Customer and the Company. The Electric Service
Regulations of the Company on file with and approved by the Idaho Public Utilities Commission, including future applicable amendments, will be considered as forming a part of and incorporated in said Agreement.
IDAHO PUBLIC UTILITIES COMMISSIONApproved EffectiveMay 22, 2023 April 1, 2023 Per ON 35787 Jan Noriyuki Secretary
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Aug. 28, 2006 Sept. 15, 2006
Jean D. Jewell Secretary
I.P.U.C. No. 1 Original Sheet No. 118.1
ROCKY MOUNTAIN POWER
ELECTRIC SERVICE SCHEDULE NO. 118
STATE OF IDAHO
Home Energy Saver Incentive Program
PURPOSE: Service under this tariff is intended to maximize the efficient utilization of the
electricity requirements of new and existing loads in new and existing residences including
manufactured housing and multi-family dwellings.
APPLICABLE: To new and existing residential customers in all territory served by the
Company in the state of Idaho billed on Schedule 1 or Schedule 36. Landlords who own rental
properties served by the company in the state of Idaho where the tenant is billed on Schedule 1 or
Schedule 36 also qualify for this program.
CUSTOMER PARTICIPATION: Customer participation is voluntary and is initiated by
following the participation procedures listed on the program web site.
DESCRIPTION: On-going program to deliver incentives for a variety of equipment and
services intended for and located in residential dwellings. Home Energy Saver Incentive program
will be delivered by the Program Administrator and periodic changes will be made to insure or
enhance program cost effectiveness as defined by the Company.
QUALIFYING EQUIPMENT OR SERVICES: Equipment or services for residential
dwellings, which when correctly installed or performed, result in verifiable electric energy usage
reductions where such usage is compared to the existing equipment or baseline equipment as
determined by the Company.
PROGRAM ADMINISTRATOR: Qualified person or entity hired by the Company to
administer this program.
(Continued)
Submitted Under Advice Letter No. 06-:06
ISSUED: August 14, 2006 EFFECTIVE: September 15, 2006
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Aug. 28, 2006 Sept. 15, 2006
Jean D. Jewell Secretary
ROCKY MOUNTAIN
POWER
A DIVISION OF PACIFICORP
I.P.U.C. No. 1 Original Sheet No. 118.2
ELECTRIC SERVICE SCHEDULE NO. 118 -Continued
PROVISIONS OF SERVICE:
1. Qualifying Equipment or Services, incentive amounts, and participation procedures
will be listed on the program Web site.
2. Incentive delivery may vary by technology and may include any or all of the
following; post purchase mail-in, point-of-purchase buy-down, manufacturer buy­
down or pre-purchase off er and approval.
3. Incentives may be offered for year-round or for selected time periods.
4. Incentive offer availability, incentive levels and Qualifying Equipment or Services
may be changed by the Program Administrator after consultation with the Company
to reflect changing codes and standards, sales volumes, quality assurance data or to
enhance program cost effectiveness.
5. All changes will occur with a minimum of 45 days notice, be prominently displayed
as a change, include a minimum 45 day grace period for processing prior offers
( except for manufacturer buy-down incentive delivery) and be communicated at
least once to retailers who have participated within the last year.
6. Incentives paid directly to customers will be in the form of a check issued within 45
days of Program Administrator's receipt of a complete and approved incentive
application.
7. Company and/or Program Administrator will employ a variety of quality assurance
techniques during the delivery of the program. They may differ by equipment or
service type and may include, but are not limited to, pre and post installation
inspections, phone surveys, retailer invoice reconciliations and confirmation of
customer and equipment eligibility.
8. Company may verify or evaluate the energy savings of installed equipment or
services. Verification or evaluation may include, but are not limited to, telephone
survey, site visit, billing analysis, pre-and post-installation of monitoring equipment
as necessary to quantify actual energy savings.
ELECTRIC SERVICE REGULATIONS: Service under this schedule will be in
accordance with the terms of the Electric Service Agreement between the Customer and the
Company. The Electric Service Regulations of the Company on file with and approved by the
Idaho Public Utilities Commission, including future applicable amendments, will be considered as
forming a part of and incorporated in said Agreement.
Submitted Under Advice Letter No. 06-06
ISSUED: August 14, 2006 EFFECTIVE: September 15, 2006
Second Revision of Sheet No. 135.1 I.P.U.C. No. 1 Canceling First Revision of Sheet No. 135.1

Submitted Under Case No. PAC-E-19-08 FILED: October 12, 2020 EFFECTIVE: October 2, 2020
ROCKY MOUNTAIN POWER ELECTRIC SERVICE SCHEDULE NO. 135 STATE OF IDAHO ______________
Net Metering Service Closed to Applications for New Service as of October 2, 2020
______________ AVAILABILITY: At any point on the Company's interconnected system.
APPLICATION: On a first-come, first-served basis to any customer that owns and operates an Eligible Generating Plant that is located on the Customer’s premises, on the Customer’s side of the Point of
Delivery, is interconnected and operates in parallel with the Company’s existing transmission and distribution facilities and is intended primarily to offset part or all of the Customer’s own electrical requirements. TERM: Service under this Schedule will terminate on October 2, 2045. DEFINITIONS: Net Metering: The difference between the electricity supplied by the Company and the electricity generated by an eligible Customer and fed back to the electric grid over the applicable billing period.
Eligible Generating Plant: A facility that uses energy derived from the sun, wind, water, biomass or fuel cell technology to generate electricity. An Eligible Generating Plant may not have a generating capacity of more than twenty-five (25) kilowatts for customers taking service on Schedules 1, 36, 23 or 23A or one
hundred (100) kilowatts for all other customers. To qualify, a Customer must maintain its retail electric service account for the loads served at the Point of Delivery adjacent to the Generation Interconnection Point as active and in good standing.
Generation Interconnection Point: The point where the conductors installed to allow receipt of Customer’s generation connect to the Company’s facilities adjacent to the Customer’s Point of Delivery.
MONTHLY BILL: The Electric Service Charge shall be computed in accordance with the charges for the Monthly Bill in the applicable standard service tariff subject to the following Special Conditions.
(continued)
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Oct. 12, 2020 Oct. 2, 2020
Per O.N. 34798
Jan Noriyuki Secretary

Second Revision of Sheet No. 135.2
I.P.U.C. No. 1 Canceling First Revision Sheet No. 135.2

ELECTRIC SERVICE SCHEDULE NO. 135 - Continued

SPECIAL CONDITIONS:
1. If the energy supplied by the Company exceeds the energy generated by the Customer and delivered to
the Company, the Customer shall be billed for the appropriate Power and other non-energy charges and
the prices specified in the Energy Rate section of the Monthly Billing of the applicable standard service
tariff shall be applied to the net positive balance owed to the Company.
2. If the energy generated by the Customer and delivered to the Company exceeds the energy supplied by
the Company, the Customer shall be billed for the appropriate Power and other non-energy charges and
the excess energy shall be financially credited as outlined under sub-sections a. and b. below. Credits shall
remain on the account, and may only be used to offset the Customer’s energy charges at the meter
originating the credit or other eligible meters as outlined under Special Condition No. 12.
a. Customers taking retail service under Schedules 1, 36, 23 or 23A shall be financially credited for such
net energy at the Customer’s standard service schedule retail rate.
b. Customers taking retail service under all other Schedules shall be financially credited for such net
energy at the Net Metering Rate Credit specified in Special Condition No. 3.
3. Net Metering Rate Credit equals 85 percent of the monthly weighted average of the daily on-peak and off-
peak Mid-Columbia Intercontinental Exchange Electricity Price Index (Mid-C ICE Index) prices for non-
firm energy. This rate is calculated based upon the previous calendar month’s data. If the Mid-C ICE
Index prices are not reported for a particular day or days, the average of the immediately preceding and
following reporting periods or days will be used.
4. Net energy and the Net Metering Rate Credit for Customers taking service under any Time-of-Day
Schedule will be calculated separately for on-peak and off-peak usage.
5. The Customer shall execute an interconnection agreement with the Company prior to interconnection of
the Eligible Generating Plant with the Company's system. The Customer shall provide the interconnection
on Customer’s side of the meter. The Customer is responsible for all costs associated with the Eligible
Generating Plant and interconnection facilities, including additional metering necessary for service under
this schedule. At Customer’s expense, the Company shall make reasonable modifications to the
Company’s system necessary to accommodate the Customer’s facility. The payment for such
modifications is due in advance of construction. The Customer shall provide at the Customer’s expense
all equipment that is necessary to meet applicable local, state and national standards regarding electrical
and fire safety, power quality, and interconnection requirements established by the National Electrical
Code, the Institute of Electrical and Electronics Engineers, American National Standards Institute, and
Underwriters Laboratories.
(continued)
Submitted Under Case. No. PAC-E-19-03

FILED: March 15, 2019 EFFECTIVE: July 3, 2019
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Aug. 13, 2019 July 3, 2019
Per O.N. 34370
Diane M. Hanian Secretary

First Revision of Sheet No. 135.3
I.P.U.C. No. 1 Canceling Original Sheet No. 135.3

ELECTRIC SERVICE SCHEDULE NO. 135 - Continued
6. The Company’s written approval of the Customer’s protection-isolation method to ensure generator
disconnection in case of a power interruption from the Company is required before service is provided
under this schedule.
7. The Company shall not be obligated to accept, and the Company may require the Customer to curtail,
interrupt or reduce deliveries of energy if the Company, consistent with prudent electrical practices,
determines that curtailment, interruption or reduction is necessary because of line construction or
maintenance requirements, emergencies, or other critical operating conditions on its system.
8. If the Company is required by the Commission to institute curtailment of deliveries of electricity to its
customers, the Company may require the Customer to curtail its consumption of electricity in the same
manner and to the same degree as other Customers within the same customer class who do not receive
service under this schedule.
9. The Customer shall never deliver or attempt to deliver energy to the Company’s system when the
Company’s system serving the Customer’s generation facility is de-energized for any reason.
10. The Company shall not be liable directly or indirectly for permitting or continuing to allow an attachment
of a net metering facility, or for the acts or omissions of the Customer that cause loss or injury, including
death, to Customer or any third party.
11. The Customer shall grant to the Company access to all Company equipment and facilities including
adequate and continuing access rights to the property of the Customer for the purpose of installation,
operation, maintenance, replacement or any other service required of said equipment. The Company may
test and inspect an interconnection at times that it considers necessary to ensure the safety of electrical
workers and to preserve the integrity of the electric power grid.
12. Transfer of excess net financial credits:
a. If excess net financial credits exist at a meter at the end of the Customer’s February billing period the
Customer may request to transfer the unused financial credits to offset energy charges at the
Customer’s other eligible meters. Credits may be transferred to a meter or meters that meet the
following criteria:
i) The meter is located on, or contiguous to, the Premises on which the meter with excess financial
credit are located. For purposes of Schedule 135, parcels shall be considered contiguous if they
share a common boundary or corner, and includes parcels that would otherwise be considered
contiguous but are divided by a public right of way; and
ii) The meter is served by the same primary feeder as the meter with the excess financial credits; and
iii) The electricity recorded by the meter is on the same rate schedule as the meter with the excess
financial credits.
(continued)
Submitted Under Case No. PAC-E-19-03

FILED: March 15, 2019 EFFECTIVE: July 3, 2019
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Aug. 13, 2019 July 3, 2019
Per O.N. 34370
Diane M. Hanian Secretary

First Revision of Sheet No. 135.4 I.P.U.C. No. 1 Canceling Original Sheet No. 135.4

Submitted Under Case No. PAC-E-19-08 FILED: October 12, 2020 EFFECTIVE: October 2, 2020
ELECTRIC SERVICE SCHEDULE NO. 135 - Continued
12. Transfer of excess net financial credits: (continued)
b. Customers may submit written requests to transfer excess net financial credits between the eligible meter(s) March 1st through March 31st of each year. A $10 processing charge will apply to each meter receiving the transferred excess energy credits.
c. All requests must be received by Rocky Mountain Power by midnight on March 31st. If a Customer does not request to transfer excess net financial credits by March 31st, the credits will remain on the originating meter’s agreement until they become eligible for transfer on March 1st of the following
year.
13. A Customer submitting an application for service under this Schedule has 12 months from the Customer’s receipt of confirmation that the interconnection request is approved to interconnect.
14. A Customer whose Eligible Generating Plant is offline for over 6 months or an Eligible Generating Plant that is moved to a different site shall no longer be eligible for service under this Schedule.
15. To remain eligible for service under this Schedule, a Customer may not increase the capacity of a grandfathered Eligible Generating Plant by no more than 10% of the originally installed nameplate capacity, or 1 kW, whichever is greater.
16. Service under this Schedule is transferable to a subsequent Customer at the premises for which a valid Interconnection Agreement for Net Metering Service is in effect. Each Customer taking service under this Schedule will be responsible for complying with the terms and conditions of the Interconnection
Agreement for Net Metering Service in effect for that premises.
ELECTRIC SERVICE REGULATIONS: Service under this Schedule will be in accordance with the terms of the Electric Service Agreement between the Customer and the Company. The Electric Service
Regulations of the Company on file with and approved by the Idaho Public Utilities Commission, including future applicable amendments, will be considered as forming a part of and incorporated in said Agreement.
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Oct. 12, 2020 Oct. 2, 2020
Per O.N. 34798
Jan Noriyuki Secretary

I.P.U.C. No. 1 Original Sheet No. 136.1

(continued)
Submitted Under Case No. PAC-E-19-08 ISSUED: October 12, 2020 EFFECTIVE: November 1, 2020
ROCKY MOUNTAIN POWER ELECTRIC SERVICE SCHEDULE NO. 136 STATE OF IDAHO ______________ Net Billing Service ______________ AVAILABILITY: At any point on the Company's interconnected system. APPLICATION: On a first-come, first-served basis to any customer that owns and operates an Eligible Generating Plant that is located on the Customer’s premises, on the Customer’s side of the Point of
Delivery, is interconnected and operates in parallel with the Company’s existing transmission and distribution facilities and is intended primarily to offset part or all of the Customer’s own electrical requirements. DEFINITIONS: Net Billing: Charges for all electricity supplied by the Company and netted by the export credit for
the electricity generated by an eligible Customer and fed back to the electric grid over the applicable billing period. Eligible Generating Plant: A facility that uses energy derived from the sun, wind, water, biomass or fuel cell technology to generate electricity. An Eligible Generating Plant may not have a generating capacity of more than twenty-five (25) kilowatts for customers taking service on Schedules 1, 36, 23 or 23A or one hundred (100) kilowatts for all other customers. To qualify, a Customer must maintain its retail electric service account for the loads served at the Point of Delivery adjacent to the Generation Interconnection Point as active and in good standing. Generation Interconnection Point: The point where the conductors installed to allow receipt of
Customer’s generation connect to the Company’s facilities adjacent to the Customer’s Point of Delivery. Exported Customer-Generated Energy: The amount of customer-generated Energy in excess of the
customer’s on-site consumption. MONTHLY BILL: The Electric Service Charge shall be computed in accordance with the charges
for the Monthly Bill in the applicable standard service tariff and the Credits for Exported Customer-Generated Energy, if any, shall be computed at the following rates subject to the Special Conditions in this tariff. Exported Customer-Generated Energy Credit Rates are subject to change, as approved by the Commission.

IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Oct. 12, 2020 Nov. 1, 2020
Per O.N. 34798
Jan Noriyuki Secretary

First Revision Sheet No. 136.2
I.P.U.C. No. 1 Canceling Original Sheet No. 136.2

(continued)
Submitted Under Tariff Advice No. 22-02

ISSUED: June 14, 2022 EFFECTIVE: August 1, 2022
ELECTRIC SERVICE SCHEDULE NO. 136 - Continued

Exported Customer-Generated Energy Credit Rates:
1. Within the monthly billing period, all energy exported from the customer’s generating plant
to the Company’s system shall be financially credited at the otherwise applicable retail energy
rate. Any excess monthly credits shall be carried forward and shall be financially credited as
outlined under sub-sections a. and b. below. Credits shall remain on the account, and may
only be used to offset the Customer’s energy charges at the meter originating the credit or
other eligible meters as outlined under Special Condition No. 11.
a. Customers taking retail service under Schedules 1, 36, 23 or 23A shall be financially
credited for excess monthly exported energy at the Customer’s standard service
schedule retail rate.
b. Customers taking retail service under all other Schedules shall be financially credited
for excess monthly exported energy at the Net Billing Rate Credit specified in section
2.
2. Net Billing Rate Credit equals 85 percent of the monthly weighted average of the daily on-
peak and off-peak Mid-Columbia Intercontinental Exchange Electricity Price Index (Mid-C
ICE Index) prices for non-firm energy. This rate is calculated based upon the previous
calendar month’s data. If the Mid-C ICE Index prices are not reported for a particular day or
days, the average of the immediately preceding and following reporting periods or days will
be used.
3. Exported Customer-Generated Energy Credit Rates for Customers taking service under any
Time-of-Day Schedule will be calculated separately for on-peak and off-peak usage.

SPECIAL CONDITIONS:

1. Applications for service under this schedule will be subject to the following application fee:
$85 per application.

2. Energy charges for electricity supplied by the Company shall be computed in accordance with a
Customer’s applicable standard service tariff.

3. The credit value in dollars computed for the Exported Customer-Generated Energy will be applied against
charges on the Customer’s monthly bill. Excess credits will carry-over to the next monthly bill. Excess
credits may only be used to offset charges at the meter originating the credit or other eligible meters as
outlined under Special Condition No. 11.
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
July 5, 2022 August 1, 2022
Jan Noriyuki Secretary

I.P.U.C. No. 1 Original Sheet No. 136.3

(continued) Submitted Under Case No. PAC-E-19-08 ISSUED: October 12, 2020 EFFECTIVE: November 1, 2020
ELECTRIC SERVICE SCHEDULE NO. 136 - Continued SPECIAL CONDITIONS: (continued)
4. The Customer shall execute an interconnection agreement with the Company prior to interconnection of the Eligible Generating Plant with the Company's system. The Customer shall provide the interconnection
on Customer’s side of the meter. The Customer is responsible for all costs associated with the Eligible Generating Plant and interconnection facilities, including additional metering necessary for service under this schedule. At Customer’s expense, the Company shall make reasonable modifications to the
Company’s system necessary to accommodate the Customer’s facility. The payment for such modifications is due in advance of construction. The Customer shall provide at the Customer’s expense all equipment that is necessary to meet applicable local, state and national standards regarding electrical
and fire safety, power quality, and interconnection requirements established by the National Electrical Code, the Institute of Electrical and Electronics Engineers, American National Standards Institute, and Underwriters Laboratories.
5. The Company’s written approval of the Customer’s protection-isolation method to ensure generator disconnection in case of a power interruption from the Company is required before service is provided under this schedule.
6. The Company shall not be obligated to accept, and the Company may require the Customer to curtail, interrupt or reduce deliveries of energy if the Company, consistent with prudent electrical practices, determines that curtailment, interruption or reduction is necessary because of line construction or maintenance requirements, emergencies, or other critical operating conditions on its system.
7. If the Company is required by the Commission to institute curtailment of deliveries of electricity to its
customers, the Company may require the Customer to curtail its consumption of electricity in the same manner and to the same degree as other Customers within the same customer class who do not receive service under this schedule.
8. The Customer shall never deliver or attempt to deliver energy to the Company’s system when the Company’s system serving the Customer’s generation facility is de-energized for any reason.
9. The Company shall not be liable directly or indirectly for permitting or continuing to allow an attachment
of a net metering facility, or for the acts or omissions of the Customer that cause loss or injury, including death, to Customer or any third party.
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Oct. 12, 2020 Nov. 1, 2020
Per O.N. 34798
Jan Noriyuki Secretary

I.P.U.C. No. 1 Original Sheet No. 136.4

Submitted Under Case No. PAC-E-19-08 ISSUED: October 12, 2020 EFFECTIVE: November 1, 2020
ELECTRIC SERVICE SCHEDULE NO. 136 - Continued SPECIAL CONDITIONS: (continued)
10. The Customer shall grant to the Company access to all Company equipment and facilities including adequate and continuing access rights to the property of the Customer for the purpose of installation,
operation, maintenance, replacement or any other service required of said equipment. The Company may test and inspect an interconnection at times that it considers necessary to ensure the safety of electrical workers and to preserve the integrity of the electric power grid.
11. Transfer of excess credits:
a. If excess credits exist at a meter at the end of the Customer’s February billing period the Customer may request to transfer the unused excess credits to offset Power and Energy Charges at the
Customer’s other eligible meters. Excess credits may be transferred to a meter or meters that meet the following criteria:
i) The meter is located on, or contiguous to, the Premises on which the meter with excess credits are
located; and
ii) The meter is served by the same primary feeder as the meter with the excess credits; and
iii) The electricity recorded by the meter is on the same rate schedule as the meter with the excess credits.
b. Customers may submit written requests to transfer excess credits between the eligible meter(s) March 1st through March 31st of each year. A $10 processing charge will apply to each meter receiving the transferred excess credits.
c. All requests must be received by Rocky Mountain Power by midnight on March 31st.
ELECTRIC SERVICE REGULATIONS: Service under this Schedule will be in accordance with the terms of the Electric Service Agreement between the Customer and the Company. The Electric Service Regulations of the Company on file with and approved by the Idaho Public Utilities Commission, including
future applicable amendments, will be considered as forming a part of and incorporated in said Agreement.
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Oct. 12, 2020 Nov. 1, 2020
Per O.N. 34798
Jan Noriyuki Secretary
First Revision of Sheet No. 140.1 I.P.U.C. No. 1 Canceling Original Sheet No. 140.1
Submitted Under Case No. PAC-E-21-07 ISSUED: November 8, 2021 EFFECTIVE: January 1, 2022
ROCKY MOUNTAIN POWER ELECTRIC SERVICE SCHEDULE NO. 140 STATE OF IDAHO ______________ Non-Residential Energy Efficiency ______________
PURPOSE: Service under this Schedule is intended to maximize the efficient utilization of the electricity requirements of new and existing loads in Non-residential Facilities through the
installation of Energy Efficiency Measures and energy management protocols. Service under this Schedule is subject to funding availability.
APPLICABLE: To service under the Company's General Service Schedules 6, 6A, 7, 7A, 9,
10, 12, 23, 23A, 24, 35 and 35A in all territory served by the Company in the State of Idaho. This Schedule is applicable to new and existing Non-residential Facilities and dairy barns served under the Company’s residential rate schedules. CUSTOMER PARTICIPATION: Customer participation is voluntary and is initiated by following the participation procedures on the Idaho energy efficiency program section of the Company website, and available to customers without online access upon request. The Company
shall have the right to qualify participants, at its discretion, based on criteria the Company considers
necessary to ensure the effective operation of the measures and utility system. Criteria may include, but will not be limited to cost effectiveness.
DESCRIPTION: Ongoing program to provide incentives for a variety of equipment and
operational improvements intended for and located in Non-residential Facilities. Periodic program changes will be made to encourage customer participation in the program and to insure or enhance program cost-effectiveness as defined by the Company. QUALIFYING MEASURE: Measures which when installed in an eligible facility result in verifiable electric energy efficiency improvement compared to existing equipment or baseline equipment as defined by the Company. The baseline will be determined with reference to existing
equipment, applicable state or federal energy codes, industry standard practice and other relevant
factors.
QUALIFYING ENERGY MANAGEMENT:
Operational improvements which when implemented in an eligible facility result in verifiable electric
energy savings compared to standard operations as determined by the Company. (Continued)
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Feb. 1, 2022 Jan. 1, 2022
Per O.N. 35277
Jan Noriyuki Secretary
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Dec. 1, 2014 Nov. 13, 2014
Per O.N. 33178
Jean D. Jewell Secretary
ROCKY MOUNTAIN
POWER
A DIVISION OF PACIFICORP
I.P.U.C. No. 1 Original Sheet No. 140.2
ELECTRICAL SERVICE SCHEDULE NO. 140 (Continued)
PROVISIONS OF SERVICE:
( 1) Qualifying equipment or services, incentive amounts and other terms and conditions will
be listed on the Idaho energy efficiency program section of the Company website, and
are available to customers without online access upon request. Program changes may be
made by the Company with at least 45 days advanced notice. Such changes will be
prominently displayed on the Idaho energy efficiency program section of the Company
website and include a minimum 45 days for processing prior offers.
(2) Company may elect to offer energy efficiency measure ("EEM") incentives through
different channels and at different points in the sales process other than individual
Energy Efficiency Incentive Offer Letter(s) prior to EEM purchase. The differences will
depend on EEM and will be consistent for all EEMs of similar type.
(3) Incentives may be offered year-round or for selected time periods.
(4) Equipment or services receiving an incentive under this program are not eligible for
incentives under other Company programs.
(5) Company will employ a variety of quality assurance techniques during the delivery of
the program. They will differ by measure and may include pre-and post-installation
inspections, phone surveys, and confirmation of Owner/Customer and equipment
eligibility.
( 6) Company may verify or evaluate the energy savings of installed measures. This
verification may include a telephone survey, site visit, review of facility operation
characteristics, and pre-and post-installation of monitoring equipment as necessary to
quantify actual energy savings.
(7) Energy Project Manager co-funding is available according to the terms posted on the
Idaho energy efficiency program section of the Company website.
(8) Incentives will not be made available for fuel switching by Owner/Customer.
MINIMUM EQUIPMENT EFFICIENCY:
Retrofit energy efficiency projects must meet minimum equipment efficiency levels and
equipment eligibility requirements of qualifying equipment that are listed on the Idaho
energy efficiency program section of the Company website.
Submitted Under Case No. PAC-E-14-08
ISSUED: November 18, 2014
(Continued)
EFFECTIVE: November 2014
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Dec. 1, 2014 Nov. 13, 2014
Per O.N. 33178
Jean D. Jewell Secretary
ROCKY MOUNTAIN
POWER
A DIVISION OF PACIFICORP
I.P.U.C. No. 1 Original Sheet No. 140.3
ELECTRICAL SERVICE SCHEDULE NO. 140 (Continued)
ELECTRIC SERVICE REGULATIONS: Service under this Schedule will be in
accordance with the terms of the Electric Service Agreement between the Customer and the
Company. The Electric Service Regulations of the Company on file with and approved by
the Idaho Public Utilities Commission, including future applicable amendments, will be
considered as forming a part of and incorporated in said Agreement.
Submitted Under Case No. PAC-E-14-08
ISSUED: November 18, 2014 EFFECTIVE: November l, 2014
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Sept. 29, 2022 Oct. 1, 2022
Per ON 35546
Jan Noriyuki Secretary
I.P.U.C. No. 1
Ninth Revision of Sheet No. 191
Canceling Eighth Revision of Sheet No. 191
ROCKY MOUNTAIN POWER
ELECTRIC SERVICE SCHEDULE NO. 191
ST ATE OF IDAHO
Customer Efficiency Services Rate Adjustment
PURPOSE: The Customer Efficiency Services Rate Adjustment is designed to recover the costs
incurred by the Company associated with Commission-approved demand-side management expenditures.
APPLICATION: This Schedule shall be applicable to all retail tariff Customers taldng service under
the Company's electric service schedules.
MONTHLY BILL: In addition to the Monthly Charges contained in the Customer's applicable
schedule, all monthly bills shall have the following percentage increases applied prior to the application of
electric service Schedule 34.
Schedule I 2.50%
Schedule 6 2.50%
Schedule 6A 2.50%
Schedule 7 2.50%
Schedule 7A 2.50%
Schedule 9 2.50%
Schedule 10 2.50%
Schedule 11 2.50%
Schedule 12 2.50%
Schedule 23 2.50%
Schedule 23A 2.50%
Schedule 24 2.50%
Schedule 35 2.50%
Schedule 35A 2.50%
Schedule 36 2.50%
Submitted Under Case No. PAC-E-22-10
ISSUED: July 8, 2022 EFFECTIVE: October 1, 2022
Second Revision of Sheet No. 197.1 I.P.U.C. No. 1 Canceling First Revision of Sheet No. 197.1
Submitted Under Case No. PAC-E-21-07 ISSUED: November 8, 2021 EFFECTIVE: January 1, 2022
ROCKY MOUNTAIN POWER ELECTRIC SERVICE SCHEDULE NO. 197 STATE OF IDAHO ______________ Federal Tax Act Adjustment ______________
APPLICATION: This Schedule shall be applicable to all retail tariff Customers taking service under the Company’s electric service schedules. MONTHLY BILL: In addition to the Monthly Charges contained in the Customer's applicable schedule, all monthly bills shall have applied the following cents per kilowatt-hour rate.

IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Feb. 1, 2022 Jan. 1, 2022
Per O.N. 35277
Jan Noriyuki Secretary

Second Revision of Sheet No. 300.1 I.P.U.C. No. 1 Canceling First Revision of Sheet No. 300.1

Submitted Under Case No. PAC-E-21-07 ISSUED: November 8, 2021 EFFECTIVE: January 1, 2022
ROCKY MOUNTAIN POWER
ELECTRIC SERVICE SCHEDULE NO. 300
STATE OF IDAHO _____________ Regulation Charges ______________ AVAILABILITY: In all service territory served by the Company in the State of Idaho. APPLICATION: For all customers utilizing the services of the Company as defined and described in the Electric Service Regulations.
SERVICE CHARGES:
Sheet No. Description Charge 3R.1 Service Connection Charge: Normal Office Hours No Charge
Monday through Friday except holidays 4:00 P.M. to 7:00 P.M. $50.00 Weekends and holidays* 8:00 A.M. to 4:00 P.M. $50.00 *Charge assessed if connection is requested and completed on the following holidays:
7R.2 Meter Test for Accuracy
Once in twelve months No charge Two or more times in twelve months Actual Cost 7R.3 Fee paid to mobile home operators who sub-meter tenants $1.15 per month per occupied space 8R.1 Late Payment Charge: 1% of delinquent balance per month 8R.2 Returned Payment Charge: $12.00 (continued)
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Feb. 1, 2022 Jan. 1, 2022
Per O.N. 35277
Jan Noriyuki Secretary
I.P.U.C. No. 1 Seventh Revision of Sheet No. 300.2 Canceling Sixth Revision of Sheet No. 300.2

Submitted Under Case No. PAC-E-21-07 ISSUED: November 8, 2021 EFFECTIVE: January 1, 2022
ELECTRIC SERVICE SCHEDULE NO. 300 - Continued Sheet No. Description Charge 8R.2 Paperless Bill Credit -$0.50 9R.4 Security Deposit for New Service: Residential and Small Commercial Up to one sixth of estimated annual billings. Industrial and Large Commercial Up to two months peak billings.
10R.8 Reconnection Charges: Remote Reconnection $7.00 Non-Remote Reconnection Monday through Friday except holidays. 8:00 A.M. to 4:00 P.M. $25.00 4:00 P.M. to 7:00 P.M. $50.00
Weekends and holidays* 8:00 A.M. to 4:00 P.M. $50.00 *Charge assessed if reconnection is requested and completed on the following holidays:
10R.8 Tampering Unauthorized Reconnection Charge: $75.00 10R.8 Field Visit Charge: $20.00
11R.1 Taxes
Type of Amount of Date Ordinance Municipality Tax or Fee Ordinance No. Tax or Fee Adopted City of Arco Franchise No. 2007-B 3.0% July 23, 2007 City of Ammon Franchise No. 501 3.0% May 19, 2011
City of Bloomington Franchise No. 2012-01 10.0% May 10, 2012 City of Dubois Franchise No. 268 10.0% March 7, 2012 City of Firth Franchise No. 159 1.0% March 14, 2000 City of Franklin Franchise No. 2004-811 3.0% September 23, 2004 City of Iona Franchise No. 40 3.0% June 22, 1989 City of Lewisville Franchise No. 2011-2 2.0% September 14, 2011 City of McCammon Franchise No. 462 3.0% September 7, 2011 City of Mud Lake Franchise No. 60904 2.0% June 9, 2004 City of Paris Franchise No. 338 3.0% November 2, 1998 City of Preston Franchise No. 2005-4 3.0% August 8, 2005 (Continued)
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Feb. 1, 2022 Jan. 1, 2022
Per O.N. 35277
Jan Noriyuki Secretary

Fourth Revision of Sheet No. 300.3 I.P.U.C. No. 1 Canceling Third Revision of Sheet No. 300.3

Submitted Under Case No. PAC-E-21-07 ISSUED: November 8, 2021 EFFECTIVE: January 1, 2022
ELECTRIC SERVICE SCHEDULE NO. 300 - Continued Type of Amount of Date Ordinance Municipality Tax or Fee Ordinance No. Tax or Fee Adopted City of Rexburg Franchise No. 929 6.0% December 8, 2004 City of Rigby Franchise No. 453 3.0% May 21, 1996 City of Ririe Franchise No. 104 3.0% December 31, 1990
City of St. Anthony Franchise No. 20011-10 1.0% September 22, 2011 City of Shelley Franchise No. 375 3.0% October 1, 1995 City of Spencer Franchise No. 2008-1 2.0% June 20, 2008
City of Sugar City Franchise No. 204 3.0% June 13, 1996
Sheet No. Description Charge
12R.1 Minimum Engineering Costs $200
12R.3 Facilities Charges on Facilities less than 46,000 Volts Facilities Installed at Customer's Expense 0.35% per month Facilities Installed at Company's Expense 1.15% per month
Facilities Charges on Facilities at and above 46,000 Volts
Facilities Installed at Customer's Expense 0.15% per month Facilities Installed at Company's Expense 0.80% per month 12R.13 Temporary Service Charge: Service Drop and Meter only $200.00
(Charge is for connection and disconnection) 12R.15 Contract Administration Allowance $250 25R.1 Customer Guarantee Credit 1: Restoring Supply After an Outage $50.00
For each additional 12 hours $25.00
25R.2 Customer Guarantee Credit 2: Appointments $50.00 25R.2 Customer Guarantee Credit 3: Switching on Power $50.00
25R.2 Customer Guarantee Credit 4: Estimates for New Supply $50.00 (continued)
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Feb. 1, 2022 Jan. 1, 2022
Per O.N. 35277
Jan Noriyuki Secretary

First Revision of Sheet No. 300.4 I.P.U.C. No. 1 Canceling Original Sheet No. 300.4

Submitted Under Case No. PAC-E-21-07 ISSUED: November 8, 2021 EFFECTIVE: January 1, 2022
ELECTRIC SERVICE SCHEDULE NO. 300 - Continued Sheet No. Description Charge 25R.3 Customer Guarantee Credit 5: Responding to Bill Inquiries $50.00
25R.3 Customer Guarantee Credit 6: Resolving Meter Problems $50.00
25R.3 Customer Guarantee Credit 7: Notifying of Planned Interruptions $50.00

IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Feb. 1, 2022 Jan. 1, 2022
Per O.N. 35277
Jan Noriyuki Secretary

Twelfth Revision of Sheet No. 400.1 I.P.U.C. No. 1 Canceling Eleventh Revision of Sheet No. 400.1

Submitted Under Case No. PAC-E-21-07 ISSUED: November 8, 2021 EFFECTIVE: January 1, 2022
ROCKY MOUNTAIN POWER ELECTRIC SERVICE SCHEDULE NO. 400 STATE OF IDAHO ______________ Special Contract ______________ PURPOSE: The purpose of this Schedule is to describe generally the terms and conditions provided by the Company pursuant to a Special Contract approved by the Idaho Public Utility Commission. Availability This schedule is available for firm and interruptible retail service of electric power and energy
delivered for all service required on the Customer’s premises by customers contracting for not less than 150,000 kW as of May 18, 2006 and as provided in the Electric Service Agreement between the two parties.
Monthly Charge Firm Power and Energy:
Firm Energy Charge: 33.260 mills per kilowatt hour Customer Charge: $1,556.00 per Billing Period Firm Demand Charge: $15.61 per kW Interruptible Power and Energy: Interruptible Energy Charge: 33.260 mills per kilowatt hour Interruptible Demand Charge: Firm Demand charge minus Interruptible Credit Excess KVAR: $0.96/KVAR Replacement Energy: Adjusted Index Price multiplied by Replacement Energy. Tariff Rates: The Commission approved rates applicable to the Special Contract Customer,
including, but not limited to, customer charges, demand charges, energy charges, surcharges, and credits, as specified in Idaho Electric Service Schedule No. 400 or its successor.

IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Feb. 1, 2022 Jan. 1, 2022
Per O.N. 35277
Jan Noriyuki Secretary

Eleventh Revision of Sheet No. 401.1
I.P.U.C. No. 1 Canceling Tenth Revision of Sheet No. 401.1

ROCKY MOUNTAIN POWER

ELECTRIC SERVICE SCHEDULE NO. 401

STATE OF IDAHO

______________

Special Contract
______________

PURPOSE: The purpose of this Schedule is to describe generally the terms and conditions
provided by the Company pursuant to a Special Contract approved by the Idaho Public Utility
Commission.

Availability
This schedule is available for firm retail service of electric power and energy delivered for the
operations of Itafos Conda LLC’s facilities located at Soda Springs, Idaho, as provided in the Power
Supply Agreement between the two parties.

Monthly Charge

Tariff Rates: The Commission approved rates applicable to Itafos Conda LLC, including, but not
limited to, customer charges, demand charges, energy charges, surcharges, and credits, as specified
in Idaho Electric Service Schedule No. 401 or its successor.

Submitted Under Advice No. 18-01

ISSUED: January 12, 2018 EFFECTIVE: February 1, 2018
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Jan. 29, 2018 Feb. 1, 2018
Diane M. Hanian Secretary