HomeMy WebLinkAboutPacificorp dba Rocky Mtn Power ID SCHEDULES.pdfIDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Aug. 28, 2006 Sept. 15, 2006
Jean D. Jewell Secretary
Fourth Revision of Sheet No. B.1
I.P.U.C. No. 1 Canceling Third Revision of Sheet No. B.1
Submitted Under Case No. PAC-E-12-12
ISSUED: August 13, 2012 EFFECTIVE: January 1, 2013
ROCKY MOUNTAIN POWER
ELECTRIC SERVICE SCHEDULES
STATE OF IDAHO
Schedule Sheet
No. Class of Service No.
1 Residential Service 1.1 & 1.2
6 General Service - Large Power 6.1 - 6.3
6A General Service - Large Power (Residential and Farm) 6A.1 - 6A.4
7 Security Area Lighting 7.1 - 7.4
7A Security Area Lighting (Residential and Farm) 7A.1 - 7A.5
9 General Service - High Voltage 9.1 & 9.2
10 Irrigation and Soil Drainage Pumping Power Service 10.1 - 10.4
11 Street Lighting Service- Company-Owned System 11.1 - 11.3
12 Street Lighting Service- Consumer-Owned System 12.1 - 12.5
14 Temporary Service Connection Facilities – No New Service* 14
19 Commercial and Industrial Space Heating – No New Service* 19.1 - 19.4
21 Low Income Weatherization Services 21.1 - 21.6
(Continued)
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Dec. 28, 2012 Jan. 1, 2013
Per O.N. 32704
Jean D. Jewell Secretary
Fourteenth Revision of Sheet No. B.2
I.P.U.C. No. 1 Canceling Thirteenth Revision of Sheet No. B.2
ELECTRIC SERVICE SCHEDULES - Continued
Schedule Sheet
No. Class of Service No.
23 General Service - Small Power 23.1 - 23.3
23A General Service - Small Power (Residential and Farm) 23A.1 - 23A.4
24 Interruptible Power Service 24.1 - 24.5
31 Partial Requirements Service – High Voltage 31.1 – 31.6
34 Pacific Northwest Electric Power Planning and Conservation Act - 34.1 - 34.3
Residential and Farm Kilowatt-Hour Credit
35 Optional Time-of-Day General Service – Distribution Voltage 35.1 - 35.3
35A Optional Time-of-Day General Service – Distribution Voltage (Farm) 35A.1 -35A.4
38 Qualifying Facility Avoided Cost Procedures 38.1 – 38.11
36 Optional Time of Day Residential Service 36.1 - 36.3
70 Renewable Energy Rider – Optional 70.1 - 70.4
73 Renewable Energy Rider - Optional - Bulk Purchase Option 73.1 – 73.4
94 Energy Cost Adjustment 94.1
118 Home Energy Saver Incentive Program 118.1 - 118.2
(Continued)
Submitted Under Advice No. 16-04
ISSUED: April 20, 2016 EFFECTIVE: April 15, 2016
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
May 2, 2016 April 15, 2016
Per O.N. 33474
Jean D. Jewell Secretary
‘ROCKY MOUNTAIN
POWER
A DMSON OF PACRCORP
I.P.U.C.No.1 Fifth Revision of Sheet No.B.3
Canceling Fourth Revision of Sheet No.B.3
ELECTRIC SERVICE SCHEDULES -Continued
Schedule Sheet
No.Class of Service No.
135 Net Metering Service 135.1 —135.3
140 Non-Residential Energy Efficiency 140.1 —140.3
191 Customer Efficiency Services Rate Adjustment 191
300 Regulation Charges 300.1 —300.4
400 Special Contract 400.1
401 Special Contract 401.1
Schedule numbers not listed are not currently used.
*These schedules are not available to new customers or premises.
Submitted Under Case No.PAC-E-14-08
ISSUED:November 18,2014 EFFECTIVE:November 1,2014
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Dec. 1, 2014 Nov. 13, 2014
Per O.N. 33178
Jean D. Jewell Secretary
ROCKY MOUNTAIN
POWER
A DMS0N OF PFIOP
Tenth Revision of Sheet No.1.1
T.P.U.C.No.1 Canceling Ninth Revision of Sheet No.1.1
ROCKY MOUNTAIN POWER
ELECTRIC SERVICE SCHEDULE NO.1
STATE OF IDAHO
Residential Service
AVAILABLLITY:At any point on the Company’s interconnected system where there are facilities
of adequate capacity.
APPLICATION:This Schedule is for alternating current electric service supplied at
approximately 120 or 240 volts through one kilowatt-hour meter at a single point of delivery for all service
required ott the premises for Residential purposes.
When conditions are such that service is supplied through one meter to more than one dwelling or
apartment unit,the charge for such service will be computed by multiplying the minimum charges by the
maximum number of th.elling or apartment units that may he served.
When a portion of a dwelling is used regularly for business.professional or other gainful purposes,
the premises will be classified as nonresidential and the appropriate schedule applied.However,if the
wiring is so arranged that the service for Residential purposes can be metered separately, this Schedule will
be applied to such service.
MONTHLY BILL:
Customer Service Charge:
$5.00 per Customer
Energy Charge:
(1)Billing months rvlay
through October inclusive
11.13160 per kWh first 700 kWh
14.9382 0 per kWh all additional kWh
(Continued)
Submitted Under Case No.PAC-E-16-12
ISSUED:November 11,2016 EFFECTIVE:January 1,2017
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Dec. 14, 2016 Jan. 1, 2017
Per O.N. 33668
Diane M. Hanian Secretary
ROCKY MOUNTAIN
POWER
A DIViSION OF PACIFICORP
Tenth Revision of Sheet No.1.2
I.P.U.C.No.1 Canceling Ninth Revision of Sheet No.1.2
ELECTRIC SERVICE SCHEDULE NO.1-Continued
MONTHLY BILL:(continued)
(2)Billing months November
through April inclusive
8.58060 per kWh first 1,000 kWh
I 1.49430 per kWh all additional kWh
MONTHLY BILLING REDUCTION:Rates in this schedule shall be reduced by the monthly
kilowatt-hour credit adjustment set thrth under “Monthly Rates”in the currently effective Electric Service
Schedule No.34.
SEASONAL SERVICE:When seasonal service is supplied under this Schedule,the minimum
seasonal charge will be $60.00.
CONTRACT PERIOD:One year or longer.
ELECTRIC SERVICE REGULATIONS:Service under this Schedule will be in accordance with
the terms of the Electric Service Agreement between the Customer and the Company.The Electric Service
Regulations of the Company on file with and approved by the Idaho Public Utilities Commission,including
future applicable amendments,will be considered as forming a part of and incorporated in said Agreement.
Submitted Under Case No.PAC-E-16-12
ISSUED:November 11.2016 EFFECTIVE:January 1,2017
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Dec. 14, 2016 Jan. 1, 2017
Per O.N. 33668
Diane M. Hanian Secretary
ROCKY MOUNTAIN
POWER
A DIVISION OF PACIFIcORP
Eighth Revision of Sheet No.6.1
I.P.U.C.No.I Canceling Seventh Revision of Sheet No.6.1
ROCKY MOUNTAIN POWER
ELECTRIC SERVICE SCHEDULE NO.6
STATE OF IDAHO
General Service -Large Power
AVAILABILITY:At any point on the Company’s interconnected system where there are facilities
of adequate capacity.
APPLICATION:This Schedule is for alternating current,single or three-phase electric service
supplied at Company’s available voltage through one metering installation at a single point of delivery for
all service required on the premises.
MONTHLY BILL:
Rate:
Billing Months May Billing Months November
through October,Inclusive through April,Inclusive
Customer Service
Charge:
Secondary voltage
delivery (Less than
2300 volts)$37.00 per Customer $37.00 per Customer
Primary voltage
delivery (2300 volts
or higher)$111.00 per Customer $111.00 per Customer
Power Rate:$14.36 per kW for all l.W $11.81 per kW for all kW
Energy Rate:3.9880 per kWh for all kWh 3.98800 per kWh for all kWh
(Continued)
Submitted Under Case No.PAC-E-16-12
ISSUED:November 11,2016 EFFECTIVE:January 1,2017
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Dec. 14, 2016 Jan. 1, 2017
Per O.N. 33668
Diane M. Hanian Secretary
Fourth Revision of Sheet No. 6.2
I.P.U.C. No. 1 Canceling Third Revision of Sheet No. 6.2
Submitted Under Advice No. 12-03
ISSUED: October 19, 2012 EFFECTIVE: January 1, 2013
ELECTRIC SERVICE SCHEDULE NO. 6 - Continued
Power Factor:
This rate is based on the Customer maintaining at all times a power factor of 85% lagging,
or higher, as determined by measurement. If the average power factor is found to be less
than 85% lagging, the Power as recorded by the Company's meter will be increased by 3/4
of 1% for every 1% that the power factor is less than 85%.
Voltage Discount:
Where Customer takes service from Company's available lines of 2300 volts or higher and
provides and maintains all transformers and other necessary equipment, the voltage discount
based on measured Power will be:
$0.65 per kW for all kW of Power
Minimum Bill:
The Customer Service Charge.
POWER: The kW as shown by or computed from the readings of Company's Power meter for the
15-minute period of Customer's greatest use during the month, determined to the nearest kW.
SEASONAL SERVICE: Service for annually recurring periods of seasonal use where service is
normally discontinued or curtailed during a part of the year may be contracted for under this Schedule under
either of the following conditions:
(a) Customer may contract for service under this Schedule on a year-round basis paying for all
service, including transformer losses where applicable, under the rates set forth under
"Monthly Bill" above including the monthly minimum bill during those months service is
curtailed or is not utilized in the Customer's operation.
(b) Customer may contract for seasonal service under this Schedule with a net minimum
seasonal payment as follows:
$ 444.00 plus Power and Energy Charges for Customer taking service at less than
2300 volts and
$ 1,332.00 plus Power and Energy Charges for Customer taking service at 2300 volts
or higher.
(Continued)
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Oct. 29, 2012 Jan. 1, 2013
Jean D. Jewell Secretary
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Aug. 28, 2006 Sept. 15, 2006
Jean D. Jewell Secretary
ROCKY MOUNTAIN
POWER
A DIVISION OFPACIFICORP
Eighth Revision of Sheet No.6A.l
J.P.U.C.No.1 Canceling Seventh Revision of Sheet No.6A.1
ROCKY MOUNTAIN POWER
ELECTRIC SERVICE SCHEDULE NO.6A
STATE OF IDAHO
General Service -Large Power (Residential and Farm)
AVAILABiLITY:At any point on the Company’s interconnected system where there are facilities
of adequate capacity for service to any customer who qualifies as a “Residential Load’or “Farm Load”
under both (I)the Pacific Northwest Electric Power Planning and Conservation Act,P.L.96-501 as the
same may be amended,and (2)a Residential Purchase and Sale Agreement,under Section 5(c)of such Act
and in effect between the Company and the Bonneville Power Administration.
APPLICATION:This Schedule is for alternating current.single or three-phase electric service
supplied at Company’s available voltage through one metering installation at a single point of delivery for
all service required on the premises.
MONTHLY BILL:
Billing Months May Billing Months November
through October,Inclusive through April.Inclusive
Customer Service
Charge:
Secondary voltage
delivery (Less than
2300 volts)$37,00 per Customer $37.00 per Customer
Primary voltage
delivery (2300 volts
or higher)$111.00 per Customer $111.00 per Customer
Power Rate:$14.36 per kW for all kW $11.81 per kW for all kW
Energy Rate:3.98800 per kWh for all kWh 3.98800 per kWh for all kWh
(Continued)
Submitted Under Case No.PAC-E-l6-12
ISSUED:November 11,2016 EFFECTIVE:January 1,2017
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Dec. 14, 2016 Jan. 1, 2017
Per O.N. 33668
Diane M. Hanian Secretary
Third Revision of Sheet No. 6A.2
I.P.U.C. No. 1 Canceling Second Revision of Sheet No. 6A.2
Submitted Under Advice No. 12-03
ISSUED: October 19, 2012 EFFECTIVE: January 1, 2013
ELECTRIC SERVICE SCHEDULE NO. 6A - Continued
Power Factor:
This rate is based on the Customer maintaining at all times a power factor of 85% lagging,
or higher, as determined by measurement. If the average power factor is found to be less
than 85% lagging, the Power as recorded by the Company's meter will be increased by 3/4
of 1% for every 1% that the power factor is less than 85%.
Voltage Discount:
Where Customer takes service from Company's available lines of 2300 volts or higher and
provides and maintains all transformers and other necessary equipment, the voltage discount
based on measured Power will be:
$0.65 per kW for all kW of Power
Minimum Bill:
The Customer Service Charge.
MONTHLY BILLING REDUCTION: Rates in this Schedule shall be reduced by the monthly
kilowatt-hour credit adjustment set forth under "Monthly Rates" in the currently effective Electric Service
Schedule No. 34.
POWER: The kW as shown by or computed from the readings of Company's Power meter for the
15-minute period of Customer's greatest use during the month, determined to the nearest kW.
SEASONAL SERVICE: Service for annually recurring periods of seasonal use where service is
normally discontinued or curtailed during a part of the year may be contracted for under this Schedule under
either of the following conditions:
(a) Customer may contract for service under this Schedule on a year-round basis paying for all
service, including transformer losses where applicable, under the rates set forth under
"Monthly Bill" above including the monthly minimum bill during those months service is
curtailed or is not utilized in the Customer's operation.
(Continued)
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Oct. 29, 2012 Jan. 1, 2013
Jean D. Jewell Secretary
Fourth Revision of Sheet No. 6A.3
I.P.U.C. No. 1 Canceling Third Revision of Sheet No. 6A.3
Submitted Under Advice No. 12-03
ISSUED: October 19, 2012 EFFECTIVE: January 1, 2013
ELECTRIC SERVICE SCHEDULE NO. 6A - Continued
SEASONAL SERVICE: (continued)
(b) Customer may contract for seasonal service under this Schedule with a net minimum
seasonal payment as follows:
$ 444.00 plus Power and Energy Charges for Customer taking service at less than
2300 volts and
$1,332.00 plus Power and Energy Charges for Customer taking service at 2300 volts
or higher.
CONTRACT PERIOD: One year or longer.
SPECIAL CONDITION: Domestic use means all usual residential, apartment, seasonal dwelling,
and mobile home court use including domestic water pumping. Farm use means all usual farm electrical
loads for raising of crops, livestock or pasturage and includes primary processing necessary for safe and
efficient storage or shipment and irrigation pumping.
Contiguous parcels of land under single-ownership or leasehold shall be considered to be one Farm
and noncontiguous parcels of land under single-ownership or leasehold shall be considered as one Farm unit
when operated as a single Farm, unless demonstrated otherwise by the owner or lessee of the parcels.
A number of factors shall determine whether contiguous or noncontiguous parcels constitute one or
more Farms. These factors shall include, but are not limited to:
-- size
-- use
-- ownership
-- control
-- operating practices
-- distance between parcels
-- custom in the trade
-- billing treatment by the utility
Operators of Farms may be required to certify to the utility all irrigation accounts, including
horsepower rating.
(Continued)
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Oct. 29, 2012 Jan. 1, 2013
Jean D. Jewell Secretary
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Aug. 28, 2006 Sept. 15, 2006
Jean D. Jewell Secretary
ROCKY MOUNTAIN
POWER
A DMSON OF PACIFICORP
Eighth Revision of Sheet No.7.1
I.P.U.C.No.1 Canceling Seventh Revision of Sheet No.7.1
ROCKY MOUNTAIN POWER
ELECTRIC SERVICE SCHEDULE NO.7
STATE OF IDAHO
Security Area Lighting
Closed to New Service
AVAILABILiTY:At any point on the Company’s interconnected system.No new Mercury Vapor
Lamps will be installed after May 3,1985.
APPLICATION:This Schedule is for (1)electric service required for Security Area Lighting and
for Security Flood Lighting service where service is supplied from a Company-owned overhead wood pole
system and (2)Customer-owned/Customer-maintained Area Lighting.
MONTHLY BILL:
Rate:
(I)Security Area Lightigg
Nominal Lamp Rating:
Initial Lumens Watts Per Lamp
Mercury Vapor Lamp:
7,000 175 $27.22 per lamp
20,000 400 $48.54 per lamp
(Continued)
Submitted Under Case No.PAC-E-16-12
ISSUED:November II.2016 EFFECTIVE:January 1,2017
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Dec. 14, 2016 Jan. 1, 2017
Per O.N. 33668
Diane M. Hanian Secretary
ROCKY MOUNTAiN
POWER
A OMSIONOF PACIFICORP
Sixth Revision of Sheet No.7.2
I.P.U.C.No.1 Canceling Fifth Revision of Sheet No.7.2
ELECTRIC SERVICE SCHEDULE NO.7 -Continued
MONTHLY BILL:(continued)
Sodium Vapor Lamps:
5,600 high intensity discharge 70 $17.29 per lamp on new pole
$13.76 per lamp if no new
pole is required
9,500 high intensity discharge 100 $19.80 per lamp on new pole
$16.26 per lamp if no new
pole is required
16,000 high intensity discharge 150 $26.07 per lamp on new pole
$23.21 per lamp if no new
pole is required
27,500 high intensity discharge 250 $37.51 per lamp on new pole
$33.96 per lamp if no new
pole is required
50,000 high intensity discharge 400 $52.41 per lamp on new pole
$46.39 per lamp if no new
pole is required
Sodium Vapor Flood Lamps:
16,000 high intensity discharge 150 $26.07 per lamp on new pole
$23.21 per lamp if no new
pole is required
27,500 high intensity discharge 250 $37.51 per lamp on new pole
$33.96 per lamp if no new
pole is required
50,000 high intensity discharge 400 $52.41 per lamp on new pole
$46.39 per lamp if no new
pole is required
(Continued)
Submitted Under Case No.PAC-E-1 6 12
ISSUED:November 11,2016 EFFECTIVE:January 1,2017
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Dec. 14, 2016 Jan. 1, 2017
Per O.N. 33668
Diane M. Hanian Secretary
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Aug. 28, 2006 Sept. 15, 2006
Jean D. Jewell Secretary
ROCKY MOUNTAIN
‘POWER
‘A DSION OPPACIFICOMP
Eighth Revision of Sheet No.7.4
I.P.U.C.No.1 Canceling Seventh Revision of Sheet No.7.4
ELECTRIC SERVICE SCHEDULE NO.7-Continued
MONTHLY BILL:(continued)
(2)Customer-Owned/Customer-Maintained Area Lighting
Energy Only (No New Service):
Initial Lumens Watts Per Lamp
16,000 Sodium Vapor Flood 150 $15.13
CONTRACT PERIOD:One year or longer.
PRO VISIONS
I.Inoperable lights will he repaired as soon as reasonably possible,during regular business hours or as
allowed by company’s operating schedule and requirements,provided the Company receives
notification of inoperable Lights form Customer or a member of the public by either notifying Rocky
Mountain Power’s customer service (1-888-221-7070)or
Rocky Mountain Power’s obligation to repair lights is limited to this tariff.
2,The Company reserves the right to contract for the maintenance of lighting service provided
hereunder.
3.Temporary disconnection and subsequent reconnection of electrical service requested by the
Customer shall be at the Customer’s expense.The Customer may request temporary suspension of
power for lighting by written notice.During such periods,the monthly rate will be reduced by the
Company’s estimated average monthly relamping and energy costs for the luminaire.The facilities
may be considered idle and may be removed after 12 months of inactivity.
4.Pole re-painting, when requested by the Customer and not required for safety reasons,shall be done
at the Customer’s expense,using the original pole color.
5.Glare or vandalism shielding,when requested by the Customer,and subject to availability,shall be
installed at the Customer’s expense.In cases of repetitive vandalism,the Company may notify the
Customer of the need to install vandal shields at the Customer’s expense,or otherwise have the
lighting removed.
ELECTRIC SERVICE REGULATIONS:Service under this Schedule will be in accordance with
the terms of the Electric Service Agreement between the Customer and the Company.The Electric Service
Regulations of the Company on file with and approved by the Idaho Public Utilities Commission, including
future applicable amendments,wiLl be considered as forming a part of and incorporated in said Agreement.
Submitted Under Case No,PAC-E-16-l2
ISSUED:November 11,2016 EFFECTIVE:January 1,2017
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Dec. 14, 2016 Jan. 1, 2017
Per O.N. 33668
Diane M. Hanian Secretary
ROCKY MOUNTAIN
‘POWER
A OIVISION OFPACIFICORP
Seventh Revision of Sheet No.7A.l
I.P.U.C.No.1 Canceling Sixth Revision of Sheet No.7A.1
ROCKY MOUNTAIN POWER
ELECTRIC SERVICE SCHEDULE NO. 7A
STATE OF IDAHO
Security Area Lighting (Residential and Farm)
Closed to New Service
AVAILABILITY:At any point on the Company’s interconnected system for service to any
customer who qualifies as a “Residential Load’or “Farm Load”under both (I)the Pacific Northwest
Electric Power Planning and Conservation Act,P.L.96-501 as the same may be amended,and (2)a
Residential Purchase and Sale Agreement,under Section 5(c)of such Act and in effect between the
Company and the Bonneville Power Administration.No new Mercury Vapor Lamps will be installed after
May 3,1985.
APPLICATION:This Schedule is for electric service required for Security Area Lighting and for
Security Flood Lighting service where service is supplied from a Company-owned overhead wood pole
system.
MONTHLY BILL:
Rate:
(1)Security Area Lighting
Nominal Lamp Rating:
Initial Lumens Watts Per Lamp
Mercury Vapor Lamp:
7,000 175 $27.22 per lamp
20,000 400 $48.54 per lamp
(Continued)
Submitted Under Case No.PAC-E-16-l2
ISSUED:November 11,2016 EFFECTIVE:January 1,2017
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Dec. 14, 2016 Jan. 1, 2017
Per O.N. 33668
Diane M. Hanian Secretary
ROCKY MOUNTAIN
POWER
A OMSION OF PAt FCORP
Sixth Revision of Sheet No.7A.2
I.P.U.C.No.1 Canceling Fifth Revision of Sheet No.7A.2
ELECTRIC SERVICE SCHEDULE NO.7A -Continued
MONTHLY BILL:(continued)
Rate:
Sodium Vapor Lamps:
5,600 high intensity discharge 70 $17.29 per lamp on new pole
$13.76 per lamp if no new
pole is required
9,500 high intensity discharge 100 $19.80 per lamp on new pole
$16.26 per lamp if no new
pole is required
16,000 high intensity discharge ISO $26.07 per lamp on new pole
$23.21 per lamp if no new
pole is required
27,500 high intensity discharge 250 $37.51 per lamp on new pole
$33.96 per lamp if no new
pole is required
50,000 high intensity discharge 400 $52.41 per lamp on new pole
$46.39 per lamp if no new
pole is required
Sodium Vapor Flood Lamps:
16,000 high intensity discharge 150 $26.07 per lamp on new pole
$23.21 per lamp if no new
pole is required
27,500 high intensity discharge 250 $37.51 per lamp on new pole
$33.96 per lamp if no new
pole is required
50,000 high intensity discharge 400 $52.41 per lamp on new pole
$46.39 per lamp if no new
pole is required
(Continued)
Submitted Under Case No.PAC-E-16-12
ISSUED:November 11,2016 EFFECTIVE:January 1,2017
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Dec. 14, 2016 Jan. 1, 2017
Per O.N. 33668
Diane M. Hanian Secretary
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Aug. 28, 2006 Sept. 15, 2006
Jean D. Jewell Secretary
I.P.U.C. No.1
Third Revision of Sheet No.7 A.4
Canceling Second Revision of Sheet No.7 A.4
ELECTRIC SERVICE SCHEDULE NO.7 A -Continued
MONTHLY BILL: (continued)
CONTRACT PERIOD: One year or longer.
SPECIAL CONDITION: Domestic use means all usual residential, apartment, seasonal dwelling,
and mobile home court use including domestic water pumping. Farm use means all usual farm electrical
loads for raising of crops, livestock or pasturage and includes primary processing necessary for safe and
efficient storage or shipment and irrigation pumping.
Contiguous parcels of land under single-ownership or leasehold shall be considered to be one Farm
and noncontiguous parcels of land under single-ownership or leasehold shall be considered as one Farm unit
when operated as a single Farm, unless demonstrated otherwise by the owner or lessee of the parcels.
A number of factors shall determine whether contiguous or noncontiguous parcels constitute one or more
Farms. These factors shall include, but are not limited to:
sIze
use
ownership
control
operating practices
distance between parcels
custom in the trade
billing treatment by the utility
Operators of Farms may be required to certifY to the utility all irrigation accounts, including
horsepower rating.
(Continued)
Submitted Under Case No. PAC-E-12-04
ISSUED: January 18,2012 EFFECTIVE: April 24, 2012
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
April 27, 2012 April 24, 2012
Per O.N. 32519
Jean D. Jewell Secretary
Second Revision of Sheet No. 7A.5
I.P.U.C. No. 1 Canceling First Revision of Sheet No. 7A.5
Submitted Under Advice No. 16-03
ISSUED: February 10, 2016 EFFECTIVE: March 15, 2016
ELECTRIC SERVICE SCHEDULE NO. 7A - Continued
SPECIAL CONDITION: (continued)
Customers who feel they meet the definitions of a Farm will have to make application with the
Company for review. If Customer application is denied by the Company, the Customer may appeal the
decision to the Idaho Public Utilities Commission.
PROVISIONS
1. Inoperable lights will be repaired as soon as reasonably possible, during regular business hours or as
allowed by company’s operating schedule and requirements, provided the Company receives
notification of inoperable lights from Customer or a member of the public by either notifying Rocky
Mountain Power’s customer service (1-888-221-7070) or www.rockymountainpower.net/streetlights
Rocky Mountain Power’s obligation to repair lights is limited to this tariff.
2. The Company reserves the right to contract for the maintenance of lighting service provided
hereunder.
3. Temporary disconnection and subsequent reconnection of electrical service requested by the
Customer shall be at the Customer’s expense. The Customer may request temporary suspension of
power for lighting by written notice. During such periods, the monthly rate will be reduced by the
Company’s estimated average monthly relamping and energy costs for the luminaire. The facilities
may be considered idle and may be removed after 12 months of inactivity.
4. Pole re-painting, when requested by the Customer and not required for safety reasons, shall be done
at the Customer’s expense, using the original pole color.
5. Glare or vandalism shielding, when requested by the Customer, and subject to availability, shall be
installed at the Customer’s expense. In cases of repetitive vandalism, the Company may notify the
Customer of the need to install vandal shields at the Customer’s expense, or otherwise have the
lighting removed.
ELECTRIC SERVICE REGULATIONS: Service under this Schedule will be in accordance with
the terms of the Electric Service Agreement between the Customer and the Company. The Electric Service
Regulations of the Company on file with and approved by the Idaho Public Utilities Commission, including
future applicable amendments, will be considered as forming a part of and incorporated in said Agreement.
.
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Feb. 22, 2016 March 15, 2016
Jean D. Jewell Secretary
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Aug. 28, 2006 Sept. 15, 2006
Jean D. Jewell Secretary
‘ROCKY MOUNTAIN
POWER
A DIVISION OFPACIFICORP
Eighth Revision of Sheet No.9.2I.P.U.C.No.1 Canceling Seventh Revision of Sheet No.9.2
ELECTRIC SERVICE SCHEDULE NO.9-Continued
MONTHLY BILL:
Rate:
Billing Months May Billing Months November
through October,Inclusive through April,Inclusive
Customer Service
Charge:$370.00 per Customer $370.00 per Customer
Power Rate:$10.26 per kW for all kW $7.74 per kW for all kW
Energy Rate:4.18720 per kWh for all kWh 4.18720 per kWh for all kWh
Power Factor:
This rate is based on the Customer maintaining at all times a power factor of 85%Lagging,
or higher,as determined by tneasurement.If the average power factor is found to be less
than 85%lagging,the Power as recorded by the Company’s meter will be increased by 3/4
of 1%for every 1%that the power factor is less than 85%.
Minimum:
The Customer Service Charge plus the minimum Power Charge and appropriate Energy
Charges.
POWER:The kW as shown by or computed from the readings of Company’s Power meter for the
15-minute period of Customer’s greatest use during the month,adjusted for power factor as specified,
determined to the nearest kW,but not less than 80 kW.
CONTRACT PERIOD:One year or longer.
ELECTRIC SERVICE REGULATIONS:Service under this Schedule will be in accordance with
the terms of the Electric Service Agreement between the Customer and the Company.The Electric Service
Regulations ofthe Company on file with and approved by the Idaho Public Utilities Commission,including
future applicable amendments,will be considered as forming a part of and incorporated in said Agreement.
Submitted Under Case No.PAC-E-16-12
ISSUED:November II,2016 EFFECTIVE:January 1,2017
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Dec. 14, 2016 Jan. 1, 2017
Per O.N. 33668
Diane M. Hanian Secretary
Sixth Revision of Sheet No. 10.1
I.P.U.C. No. 1 Canceling Fifth Revision of Sheet No. 10.1
Submitted Under Advice No. 12-03
ISSUED: October 19, 2012 EFFECTIVE: January 1, 2013
ROCKY MOUNTAIN POWER
ELECTRIC SERVICE SCHEDULE NO. 10
STATE OF IDAHO
______________
Irrigation and Soil Drainage Pumping Power Service
______________
AVAILABILITY: At any point on the Company's interconnected system where there are facilities
of adequate capacity.
APPLICATION: This Schedule is for alternating current, single or three-phase electric service
supplied at the Company's available voltage through a single point of delivery for service to motors on
pumps and machinery used for irrigation and soil drainage.
IRRIGATION SEASON AND POST-SEASON SERVICE: The Irrigation Season is from June 1
to September 15 each year. Service for post-season pumping may be taken by the same Customer at the
same point of delivery and through the same facilities used for supplying regular irrigation pumping service
during months from September 16 to the following May 31.
MONTHLY BILL:
Irrigation Season Rate
Customer Service Charge:
Small Pumping Operations:
15 horsepower or less total connected horsepower
served through one service connection - $14.00 per Customer
Large Pumping Operations:
16 horsepower or more total connected horsepower
served through one service connection - $41.00 per Customer
(Continued)
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Oct. 29, 2012 Jan. 1, 2013
Jean D. Jewell Secretary
‘ROCKY MOUNTAIN
POWER
OMSION OF PAOFCORP
Tenth Revision of Sheet No.10.2
LP.U.C.No.1 Canceling Ninth Revision of Sheet No. 10.2
ELECTRIC SERVICE SCHEDULE No.10 -Continued
MONTHLY BILL:(Continued)
Power Rate:$5.98 per kW for all kW
Energy Rate:8.871 l per kWh for first 25,000 kWh
6.62960 per kWh for the next 225,000 kWh
4.96 160 per kWh for all additional kWh
Power Factor:This rate is based on the Customer maintaining at all times a power factor
of 85%lagging.or higher,as determined by measurement.If the average power factor is
found to be less than 85%lagging,the power as recorded by the Company’s meter will be
increased by 3/4 of 1%for every 1%that the power factor is less than 85%.
Minimum:The Customer Service Charge.
Post-Season Rate
Customer Service Charge:$23.00 per Customer
Energy Rate:7.54410 per kWh for all kWh
Minimum:The Customer Service Charge.
ADJUSTMENTS:All monthly bills shall be adjusted in accordance with Schedules 34 and 94.
PAYMENT:All monthly service billings will be due and payable when rendered and will he
considered delinquent if not paid within fifleen (15)days.An advance payment may be required of the
Customer by the Company in accordance with Electric Service Regulation No.9,An advance may be
required under any of the following conditions:
(1)the Customer failed to pay all amounts owed to the Company when due and
payable;
(2)the Customer paid an advance the previous season that did not adequately cover
bills for the entire season and the Customer failed to pay any balance owing by the
due date of the final billing issued for the season.
(Continued)
Submitted Under Case No.PAC-E-l6-12
LSSUED:November 11,2016 EFFECTIVE:January 1,2017
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Dec. 14, 2016 Jan. 1, 2017
Per O.N. 33668
Diane M. Hanian Secretary
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Aug. 28, 2006 Sept. 15, 2006
Jean D. Jewell Secretary
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Aug. 28, 2006 Sept. 15, 2006
Jean D. Jewell Secretary
ROCKY MOUNTAIN
‘POWER
A OIUISION OF PACIFICORP
Ninth Revision of Sheet No.11.1
LP.U.C.No.I Canceling Eighth Revision of Sheet No.11.1
ROCKY MOUNTAIN POWER
ELECTRIC SERVICE SCHEDULE NO.11
STATE OF IDAHO
Street Lighting Service
Company-Owned System
AVAILABILITY:In all territory served by the Company in the State of Idaho.
APPLICATION:To unmetered lighting service provided to municipalities or agencies of
municipal, county,state or federal governments for dusk to dawn illumination of public streets,highways
and thoroughfares by means of Company owned,operated and maintained street lighting systems controlled
by a photoelectric control or time switch.
MONTHLY BILL:The Monthly Billing shall be the rate per luminaire as specified in the rate
tables below.
Light-Emitting Diode (LED)
___________________________________________________
Lumen Rating (Minimum)4,000 6,200 13,000 16,800
Watts (Maximum)50 75 135 185
Functional [.ighting $15.34 $16.83 $22.84 $28.94
High Pressure Sodium Vapor
Lumen Rating -5,800*9,500 16,000 27,500 50,000
Watts 70 100 150 250 400
Monthly kWh 28 39 59 96 148
Functional Lighting $15.35 $19.15 $26.10 $36.44 $53.49
Decorative -Series I N/A $31.68 $34.76 N/A N/A
Decorative-Series 2 N/A $26.07 $29.07 N/A N/A
*Existing fixtures only.Service is not available under this schedule to new 5,800 lumen Kigh
Pressure Sodium vapor Fixtures.
(Continued)
Submitted Under Case No.PAC-E-16-l 2
ISSUED:November 11,2016 EFFECTIVE:January 1,2017
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Dec. 14, 2016 Jan. 1, 2017
Per O.N. 33668
Diane M. Hanian Secretary
Fourth Revision of Sheet No. 11.2
I.P.U.C. No. 1 Canceling Third Revision of Sheet No. 11.2
Submitted Under Advice No. 16-03
ISSUED: February 10, 2016 EFFECTIVE: March 15, 2016
ELECTRIC SERVICE SCHEDULE NO. 11 - Continued
DEFINITIONS:
Functional Lighting: Common, less expensive luminaires that may be mounted either on wood, fiberglass
or non-decorative metal poles.
Decorative Lighting: More stylish luminaires mounted vertically on decorative metal poles. The Company
will maintain a listing of standard decorative street light fixtures that are available under this Electric
Service Schedule. Available decorative lighting fixtures are grouped into different Decorative Series 1 and
Decorative Series 2 according to cost.
PROVISIONS:
1. Installation, daily operation, repair and maintenance of lights on this rate schedule to be
performed by the Company, providing that the facilities furnished remain readily accessible for
maintenance purposes.
2. Company will install only Company approved street lighting equipment at locations acceptable
to Company.
3. Inoperable lights will be repaired as soon as reasonably possible, during regular business hours
or as allowed by Company’s operating schedule and requirements, provided the Company
receives notification of inoperable lights from the Customer or a member of the public by either
notifying Rocky Mountain Power’s customer service at (1-888-221-7070) or
www.rockymountainpower.net/streetlights. Rocky Mountain Power’s obligation to repair street
lights is limited to this tariff.
4. Existing fixtures and facilities that are deemed irreparable will be replaced with comparable
fixtures and facilities from the Company’s Construction Standards.
5. The Company will, upon written request of Customer, convert existing street lighting facilities
to other types of Company approved facilities. In such event, should the revenue increase, the
streetlighting extension allowance defined in Rule 12, section 3.f is applicable only to the
increase in annual revenue due to the replacement. If there is no increase in revenue, there is no
allowance. The Customer shall advance the estimated cost of all materials and labor associated
with installation and removal, less the estimated salvage on all the removed facilities, in excess
of the applicable allowance.
6. The entire system, including initial lamp requirements and wiring suitable for connection to
Company’s system, will be furnished and installed by the Company. The Customer is
responsible for all associated costs that exceed the Street Lighting Extension Allowance as
described in the General Rules of this tariff. Customer shall not perform the electrical
connection of meters or service conductor to the point of delivery.
(Continued)
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Feb. 22, 2016 March 15, 2016
Jean D. Jewell Secretary
Fourth Revision of Sheet No. 11.3
I.P.U.C. No. 1 Canceling Third Revision of Sheet No. 11.3
Submitted Under Advice No. 16-03
ISSUED: February 10, 2016 EFFECTIVE: March 15, 2016
ELECTRIC SERVICE SCHEDULE NO. 11 - Continued
PROVISIONS: (continued)
7. Temporary disconnection and subsequent reconnection of electrical service requested by the
Customer shall be at the Customer’s expense. The Customer may request temporary suspension
of power by written notice. During such periods, the monthly rate will be reduced by the
Company’s estimated average energy costs for the luminaire. The facilities may be considered
idle and may be removed after 12 months of inactivity.
8. Where approved by the company, all pole mounted outlets used for holiday or other decorations
will be supplied with service on a metered General Service rate via a Customer-installed meter
base.
9. Pole re-painting, when requested by the Customer and not required for safety reasons, shall be
done at Customer’s expense using the original pole color.
10. Glare or vandalism shielding, when requested by the Customer, and subject to availability, shall
be installed at the Customer’s expense. In cases of repetitive vandalism, the Company may
notify the Customer of the need to install vandal shields at the Customer’s expense, or
otherwise have the lighting removed.
CONTRACT PERIOD: Not less than five (5) years for both new and replacement fixtures.
After the end of the contract term, the Customer can request removal of lights with a minimum of 2 months
written notice. The Customer will be charged with costs of removal. If the lights are removed before the end
of the contract term, the Customer is responsible for the cost of removal plus depreciated remaining life of
the assets less any salvage value.
ELECTRIC SERVICE REGULATIONS: Service under this schedule is subject to the General
Rules and Regulations contained in the tariff of which this schedule is part and to those prescribed by
regulatory authorities.
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Feb. 22, 2016 March 15, 2016
Jean D. Jewell Secretary
ROCKY MOUNTAIN
‘POWER
A ONISION OF PAC1FCORP
Eighth Revision of Sheet No.12.1
I.P.U.C.No.I Canceling Seventh Revision of Sheet No.12.1
ROCKY MOUNTAIN POWER
ELECTRIC SERVICE SCHEDULE NO.12
STATE OF IDAHO
Street Lighting Service
Customer-Owned System
AVAILABILITY:In all territory served by the Company in the State of idaho.
APPLICATION:To lighting service provided to municipalities or agencies of municipal,county.
state or federal governments for dusk to dawn illumination of public streets, highways and thoroughfares by
means of Customer owned street lighting systems controlled by a photoelectric control or time switch.
MONTHLY BILL:
1.Energy Only Service —Rate per Luminaire
Energy Only Service includes energy supplied from Company’s overhead or underground circuits
and does not include any maintenance to Customer’s facilities.
The Monthly Billing shall be the rate per luminaire as specified in the rate tables below.
High Pressure Sodium Vapor—No
Maintenance
Lumen Rating 5,800 9.500 16,000 27,500 50,000
Watts 70 100 150 250 400
Monthly kWh 28 39 59 96 148
Energy Only Service $2.90 $4.06 $6.04 $10.32 $15.85
(Continued)
Submitted Under Case No.PAC-E-16.12
ISSUED: November 11,2016 EFFECTIVE:January 1,2017
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Dec. 14, 2016 Jan. 1, 2017
Per O.N. 33668
Diane M. Hanian Secretary
‘ROCKY MOUNTAIN
POWER
A DMSION OF PACIF1COAP
I,P.U.C.No.1
Eighth Revision of Sheet No.12.2
Canceling Seventh Revision of Sheet No.12.2
ELECTRIC SERVICE SCHEDULE NO.12 Continued
MONTHLY BILL:(continued)
Metal Halide —No Maintenance
Lumen Rating 33,000
Watts 180
Monthly kWh 74
Energy Only Service $9.36
For non-listed luminaires,the cost will be calculated for 4167 annual hours of operation including
applicable loss factors for ballasts and starting aids at the cost per kWh given below.
Non-Listed Luminaire $/kWh
Energy Only Service $0.105 139
2.Maintenance Service (No New Service)
Monthly maintenance is only applicable for existing monthly maintenance service agreements in
effect prior to June 29,2007.
A.Street Lighting..“Partial Maintenance”
Mercury Vapor—Partial
Maintenance
Lumen Rating 10,000 20,000
Watts 250 400
Monthly kWh 93 145
Partial Maintenance
Service $16.79 $22.47
Submitted Under Case No.PAC-E-16-12
(Continued)
Lumen Rating 9,000 12,000 19,500 32,000 107,800
Watts 100 175 250 400 1000
MonthLy kWh 39 69 93 145 352
Energy Only Service $4.10 $7.20 $9.86 $15.49 $37.09
Low Pressure Sodium Vapor -No
Maintenance
ISSUED:November 11,2016 EFFECTIVE:January 1,2017
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Dec. 14, 2016 Jan. 1, 2017
Per O.N. 33668
Diane M. Hanian Secretary
ROCKY MOUNTAIN
POWER
A DIVISION OF PACIFICOAP
Seventh Revision of Sheet No.12.3
I.P.U.C.No.1 Canceling Sixth Revision of Sheet No. 12.3
ELECTRIC SERVICE SCHEDULE NO.12-Continued
MONTHLY BILL:(continued)
High Pressure Sodium —
Partial Maintenance
Lumen Rating 5,800 9,500 27,500 50,000
Watts 70 100 250 400
Monthly kWh 28 39 96 148
Partial Maintenance
Service $602 $7.75 $12.40 $16.71
13.Street Lighting,“Full Maintenanc
High Pressure Sodium —
Full Maintenance
Lumen Rating 5,800 9,500 16.000 27,500 50,000
Watts 70 100 150 250 400
Monthly kWh 28 39 59 96 148
Full Maintenance
Service $6.7!$8.56 $10.27 $13.45 $17.93
SPECIFICATIONS AND SERVICE FOR STREET LIGHTING WITH PARTIAL AND
FULL MAINTENANCE (NO NEW SERVICE):Installations must have met Company
construction standards in place at the time of installation in order to receive “full maintenance.”
If Company is unable to obtain materials to perform maintenance,the street light facilities will
be deemed obsolete and must be upgraded at customer expense in order to qualify for
maintenance under the Electric Service Schedule,Street Lighting Service under “partial
tnaintenance”includes energy,lamp and glassware renewals and cleaning of glassware.
Street Lighting Service under “full maintenance”includes energy,lamp and glassware
replacements and cleaning of glassware,and replacement of damaged or inoperative photocells.
ballasts, starting aids,poles,mast arms and luminaires: provided,however,that any costs for
materials which are over and above costs for Company’s standard materials,as determined by
the Company.are not included in this Electric Service Schedule.Such extra costs shall be paid
by Customer. Burning-hours of lamps will be controlled by the Company.
(Continued)
Submitted Under Case No.PAC-E-16-l2
ISSUED:November Il,2016 EFFECTIVE:January 1,2017
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Dec. 14, 2016 Jan. 1, 2017
Per O.N. 33668
Diane M. Hanian Secretary
Third Revision of Sheet No. 12.4
I.P.U.C. No. 1 Canceling Second Revision of Sheet No. 12.4
Submitted Under Advice No. 16-03
ISSUED: February 10, 2016 EFFECTIVE: March 15, 2016
ELECTRIC SERVICE SCHEDULE NO. 12 - Continued
MONTHLY BILL: (continued)
SPECIFICATIONS AND SERVICE FOR STREET LIGHTING WITH PARTIAL AND
FULL MAINTENANCE (NO NEW SERVICE): (continued)
The Company shall not be liable under the maintenance provided under “Full Maintenance”
for damages caused by (a) war; (b) earthquakes; and (c) acts of God, excepting lightning
strikes; or (d) sabotage. The costs associated with replacements and repairs to Customer-
owned facilities associated with these acts will be billed to the Customer on an as if and when
basis.
PROVISIONS:
1. The Company will not maintain new Customer owned street lights. Such maintenance will be
the responsibility of the Customer; however the Company may install pole identification tags
for the purposes of tracking unmetered Customer owned lights.
2. Customer owned lights, mounted to Company owned distribution poles, shall be installed,
maintained, transferred or removed only by qualified personnel. Appurtenances or other
alterations to the Company’s standard will not be supported by, or become the responsibility of,
the Company. Following notification by the Customer, inoperable lights under this provision
will be repaired as soon as possible, during regular business hours or as allowed by Company’s
operating schedule and requirements. Costs described in this provision will be invoiced to the
Customer upon completion of the work.
3. The entire system, including the design of facilities, installation of fixtures on Customer poles,
and wiring suitable for connection to Company’s system, will be furnished by the Customer.
4. Customer must notify the Company in writing of any changes to the street lighting system
which would affect billing, including new installations, removals or wattage changes. Standard
notification procedure will be through online forms at www.rockymtnpower.net/streetlights.
5. All new underground-fed lights on this schedule will require a Customer installed means of
disconnect acceptable to both the Company and the local electrical inspecting authority.
(Continued)
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Feb. 22, 2016 March 15, 2016
Jean D. Jewell Secretary
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Jan. 28, 2008 Feb. 15, 2008
Jean D. Jewell Secretary
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Aug. 28, 2006 Sept. 15, 2006
Jean D. Jewell Secretary
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Aug. 28, 2006 Sept. 15, 2006
Jean D. Jewell Secretary
‘ROCKY MOUNTAIN
POWER
A DIVISION OF PACIFICOP
Tenth Revision of Sheet No.19.2
I.P.U.C.No.1 Canceling Ninth Revision of Sheet No.19.2
ELECTRIC SERVICE SCHEDULE NO.19-Continued
MONTHLY BILL:
Rate for space heating:
Billing Months May Billing Months November
through October, Inclusive through April,Inclusive
Customer
Service Charge:$23.00 per Customer $23.00 per Customer
Energy Rate:9.65020 per kWh for all kWh 7.21750 per kWh for all kWh
Rate for all other service:
All other service requirements will be supplied under Electric Service Schedule No.6,or
Electric Service Schedule No.6A,or Electric Service Schedule No.23,or Electric Service
Schedule No.23A.or Electric Service Schedule No.35,or Electric Service Schedule No.35A.
SPACE HEATING:All space heating equipment shall be permanently installed and shall be the
sole means of heating the building space occupied by the Customer. All space heating equipment and
installation thereof and all supply wiring shall conform with the Company’s specifications.
AIR CONDITIONING:All air conditioning equipment shall be permanently installed and shall be
the sole means of providing comfort cooling for the building space occupied by the Customer.All air
conditioning equipment and installation thereof and all supply wiring shall conform with the Company’s
specifications.Electric service for comfort cooling will be metered and billed at the above rate only when
Customer also uses electric service for his total space heating requirements.
WATER HEATING:Water heaters served hereunder shall be insulated storage, single or
multiple-unit type of construction approved by the Company,the heating units of which shall be
noninductive and controlled by separate thermostats.Electric service of storage water heating will be
metered and billed at the above rate only when Customer also uses electric service for his total space
heating requirements.
(Continued)
Submitted Under Case No.PAC-E-l6-1 2
ISSUED:November 11,2016 EFFECTWE:January 1,2017
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Dec. 14, 2016 Jan. 1, 2017
Per O.N. 33668
Diane M. Hanian Secretary
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Aug. 28, 2006 Sept. 15, 2006
Jean D. Jewell Secretary
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Aug. 28, 2006 Sept. 15, 2006
Jean D. Jewell Secretary
I.P.U.C. No. 1 First Revision of Sheet No. 21.1
Canceling Original Sheet No. 21.1
Submitted Under Docket No. PAC-E-06-10 - Advice Letter No. 07-03
ISSUED: January 10, 2007 EFFECTIVE: April 1, 2007
ROCKY MOUNTAIN POWER
ELECTRIC SERVICE SCHEDULE NO. 21
STATE OF IDAHO
______________
Low Income Weatherization Services
Optional For Income Qualifying Customers
_____________
PURPOSE: Service under this schedule is intended to maximize the efficient utilization of the
electricity requirements of existing residential dwellings inhabited by customers that meet income guidelines
through the installation of energy efficient materials. The decision to extend service under this schedule
shall be based upon the eligibility requirements contained herein.
AVAILABILITY: This tariff is applicable to residential customers in all territory served by the
Company in the state of Idaho.
1. ENERGY CONSERVATION SERVICE TO LOW INCOME CUSTOMERS:
This program is available to existing single family and multi-family residential units. It is
intended to reduce the electricity requirements and increase the penetration of weatherization and
electric efficiency measures in residential dwellings inhabited by low income households through
the installation of permanent energy efficiency materials. The decision to extend service under this
schedule shall be based on eligibility requirements contained herein.
A. Definitions:
1. "Dwelling" is real or personal property within the state inhabited as the principal
residence of a dwelling owner or a tenant. “Dwelling” includes a manufactured
home, a single-family home, duplex or multi-unit residential housing. “Dwelling”
does not include a recreational vehicle.
a. Duplexes and fourplexes are eligible if at least one half of the dwelling is
occupied by low income tenants.
(Continued)
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Feb. 8, 2007 April 1, 2007
Per O.N. 30239
Jean D. Jewell Secretary
I.P.U.C. No. 1 Fourth Revision of Sheet No. 21.2
Canceling Third Revision of Sheet No. 21.2
ELECTRIC SERVICE SCHEDULE NO. 21 – (Continued)
A. Definitions (Continued):
b. Triplexes and multi-family dwellings are eligible if at least 66% of the units
are occupied by low income tenants.
2. "Agency" means a non-profit group, Municipality or County authorized to receive
funds for installation of energy efficiency materials in low income properties.
3. "Low Income" means households qualifying under the Federal low income
guidelines and certified for eligibility according to agency procedure. Income
eligibility is based on 200% of federal poverty guidelines.
4. "Major Measure" means ceiling insulation, wall insulation, floor insulation and
window replacements applicable in dwellings with permanently installed electric
space heating systems. When cost-effective (Savings to Investment Ratio (“SIR”)
of 1.0 or greater as determined by a U.S. Department of Energy (“DOE”) approved
energy audit), all major measures must be installed or in place or financial assistance
under this schedule will not be offered. If physical barriers exist that prohibit the
installation of a measure, then the measure is not required as a condition for
financial assistance under this schedule.
5. "Supplemental Measures and Additional Measures" are not required measures under
this schedule, but may qualify for a Company reimbursement.
B. Financial Assistance:
1. The Company will reimburse Agency 85% of the installed cost of all eligible
Energy Conservation Measures listed in Section C of this Tariff, with the exception
of ductless heat pumps, which will be reimbursed up to 100% of related installed
costs. Reimbursements on weatherized homes will be provided one time only on
any individual measure, and up to two times per dwelling.
(Continued)
Submitted Under Advice No. 19-01
ISSUED: January 16, 2019 EFFECTIVE: March 6, 2019
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
March 5, 2019 March 6, 2019
Diane M. Hanian Secretary
I.P.U.C. No. 1 Fourth Revision of Sheet No. 21.3
Canceling Third Revision of Sheet No. 21.3
Submitted Under Advice No. 16-02
ISSUED: January 19, 2016 EFFECTIVE: March 1, 2016
ELECTRIC SERVICE SCHEDULE NO. 21 - Continued
B. Financial Assistance (Continued):
2. The Company will reimburse Agency for administrative costs based on 15% of Rocky
Mountain Power’s rebate on installed measures, not to exceed the following total
administrative payment per building:
Dwelling Units in Building Maximum Administrative Payment
1 to 4 $350
5 to 10 $800
11 to 15 $1200
16 to 20 $1400
21 to 25 $1600
26 to 30 $1800
31+ $2100
The minimum reimbursement will be $150 on homes with one or more Major Measure
installed and $50 on homes without the installation of a Major Measure.
3. Agencies must invoice Company within 120 days of job completion.
4. A maximum of $300,000 in Company reimbursements will be available annually (April
1 through March 31). Reimbursements related to health and safety measures are limited
to 15% of the annual cost of total jobs performed by each agency.
5. Annual funding of $25,000 in total will be provided to Eastern Idaho Community
Action Partnership and SouthEastern Idaho Community Action Agency for
conservation education.
C. Energy Conservation Measures:
Financial assistance will be provided based on the results of a cost effective analysis
through a Department of Energy approved energy audit. The energy efficient measures
eligible for funding must be installed in dwellings with permanently installed operable
electric space heat except where noted. The electric space heating system must be designed
to heat at least 51% of the home. All Major and Supplemental Measures indicated below
may qualify for a company reimbursement when audit results indicate a measure has a
Savings to Investment Ratio of 1.0 or greater. The energy efficient measures that may be
eligible for funding are listed as follows:
Major Measures – Electric Heating System Required:
1. Ceiling insulation up to R-48 for ceilings with less than R-30 in place. R-30 or better
attics will not be further insulated.
(Continued)
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Feb. 29, 2016 March 1, 2016
Jean D. Jewell Secretary
I.P.U.C. No. 1 Second Revision of Sheet No. 21.4
Canceling First Revision of Sheet No. 21.4
Submitted Under Advice No. 16-02
ISSUED: January 19, 2016 EFFECTIVE: March 1, 2016
ELECTRIC SERVICE SCHEDULE NO. 21 - Continued
C. Energy Conservation Measures: (Continued)
2. Floor insulation over unheated spaced up to R-30.
3. Wall insulation up to R-26 for walls with no insulation installed (financing will not
be available for the installation of urea-formaldehyde wall insulation).
4. Replacement windows with a U-value of 0.30 or less.
Nothing shall preclude the Company from providing a reimbursement for the
installation of a greater R value on insulation for the above items that are determined to be
cost effective (SIR is 1.0 or greater) through the audit process.
Supplemental Measures – Electric Heating System Required:
1. Attic ventilation excluding power ventilators, whole house mechanical ventilation
and spot ventilation for kitchen and baths.
2. Ground cover.
3. Forced air electric space heating duct insulation and sealing in unheated spaces.
4. Weather stripping and/or caulking, including blower door assisted air sealing and
duct sealing.
5. Thermal doors.
(Continued)
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Feb. 29, 2016 March 1, 2016
Jean D. Jewell Secretary
I.P.U.C. No. 1 Third Revision of Sheet No. 21.5
Canceling Second Revision of Sheet No. 21.5
ELECTRIC SERVICE SCHEDULE NO. 21 - Continued
C. Energy Conservation Measures: (Continued)
Supplemental Measures – Electric Heating System Required (continued)
6. Timed thermostats on centrally controlled multi-room heating/cooling systems
except when used with heat pumps and Smart thermostats with occupancy sensors.
Heat anticipating type thermostats for zonal electric resistance heating systems.
7. Electric furnace repair and replacement.
8. Ductless heat pumps.
Additional Measures – No Electric Heating System Requirement:
1. Pipe insulation, energy efficient showerheads and aerators where electric water
heaters are present.
2. Light emitting diodes (LED) and/or compact fluorescent (CFL) light bulbs
applicable in all homes – Energy Star certified bulbs placed in fixtures that are on
2 hours or more per day.
3. LED light fixtures.
4. Existing Refrigerator with monitored results listed in the Weatherization
Assistance Program Technical Assistance center database with a savings to
investment ration of 1.0 or greater may be replaced with an Energy Star model.
Replaced refrigerators must be removed and recycled in accordance with EPA
guidelines.
5. Electric water heater repair and replacement.
6. Measures that promote health and safety related to electricity usage.
D. Provisions of Service for Energy Conservation Service to Low Income Customers:
1. Measures installed are intended to improve upon the electric efficiencies of
participating homes and must be included in the U.S. Department of Energy’s
Weatherization Assistance Program available to Agency.
(Continued)
Submitted Under Advice No. 17-01
ISSUED: November 27, 2017 EFFECTIVE: February 1, 2018
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Jan. 22, 2018 Feb. 1, 2018
Diane M. Hanian Secretary
I.P.U.C. No. 1 First Revision of Sheet No. 21.6
Canceling Original Sheet No. 21.6
Submitted Under Docket No. PAC-E-06-10 – Advice Letter No. 07-03
ISSUED: January 10, 2007 EFFECTIVE: April 1, 2007
ELECTRIC SERVICE SCHEDULE NO. 21 – (Continued)
D. Provisions of Service for Energy Conservation Service to Low Income Customers:
(Continued)
2. A DOE-approved energy audit must be completed by the Agency prior to
installation of Major and Supplemental Measures.
3. Agency must qualify residential customers for assistance using the Federal low
income guidelines.
4. Installation shall meet Federal, state and local building codes.
5. Measures installed under this schedule shall not receive financial incentives from
other Company programs.
6. Agency shall inspect the installation to insure that the services meet or exceed
required specifications.
7. Company may audit Agency weatherization and financial records and inspect the
installations in dwellings of customers receiving services under this program
8. Company shall pay Agency the amount established under the terms of their contract
when provisions of this schedule have been met.
ELECTRIC SERVICE REGULATIONS: Service under this schedule is subject to the
Electric Service Regulations of the Company on file with and approved by the Idaho Public Utilities
Commission, including future applicable amendments and additional regulations prescribed by regulatory
authorities.
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Feb. 8, 2007 April 1, 2007
Per O.N. 30239
Jean D. Jewell Secretary
ROCKY MOUNTAIN
POWER
A DM5ION OF C1F1cORP
Eighth Revision of Sheet No.23.1
LP.U.C.No.1 Canceling Seventh Revision of Sheet No.23.1
ROCKY MOUNTAIN POWER
ELECTRIC SERViCE SCHEDULE NO.23
STATE OF IDAHO
General Service
AVAILABILITY:At any point on the Company’s interconnected system where there are facilities of
adequate capacity.
APPLICATION:This Schedule is for alternating current,single or three-phase electric service
supplied at Company’s available voltage through one metering installation at a single point of delivery for all
service required on the premises.
MONTHLY BILL:
Billing Months May Billing Months November
through October,Inclusive through April,Inclusive
Customer Service
Charge:
Secondary voltage
delivery (Less than
2300 volts)$16.00 per Customer $16.00 per Customer
Primary voltage
delivery (2300 volts
or higher)$49.00 per Customer $49.00 per Customer
Energy Rate:9.44 I0 per kWh for all kWh 8.2742 per kWh for all kWh
(Continued)
Submitted Under Case No.PAC-E-16-12
ISSUED:November 11,2016 EFFECTIVE:January 1,2017
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Dec. 14, 2016 Jan. 1, 2017
Per O.N. 33668
Diane M. Hanian Secretary
Fourth Revision of Sheet No. 23.2
I.P.U.C. No. 1 Canceling Third Revision of Sheet No. 23.2
Submitted Under Advice No. 12-03
ISSUED: October 19, 2012 EFFECTIVE: January 1, 2013
ELECTRIC SERVICE SCHEDULE NO. 23 - Continued
Power Factor:
This rate is based on the Customer maintaining at all times a power factor of 85% lagging, or
higher, as determined by measurement. If the average power factor is found to be less than
85% lagging, Customer will be billed for 3/4 of 1% of the Power recorded by the Company’s
meter for every 1% that the power factor is less than 85%. This Power will be billed at the
Power Rate stated in Electric Service Schedule No. 6.
Voltage Discount:
Where Customer takes service from Company's available lines of 2,300 volts or higher and
provides and maintains all transformers and other necessary equipment, the voltage discount
based on measured Energy will be:
0.4397¢ per kWh for all kWh.
Minimum Bill:
The Customer Service Charge
POWER: The kW as shown by or computed from the readings of the Company’s Power meter for
the 15-minute period of Customer’s greatest use during the month, determined to the nearest kW.
SEASONAL SERVICE: Service for annually recurring periods of seasonal use where service is
normally discontinued or curtailed during a part of the year may be contracted for under this Schedule under
either of the following conditions:
(a) Customer may contract for service under this Schedule on a year-round basis paying for all
service, including transformer losses where applicable, under the rates set forth under
"Monthly Bill" above including the monthly minimum bill during those months service is
curtailed or is not utilized in the Customer's operations.
(b) Customer may contract for seasonal service under this Schedule with a net minimum seasonal
payment as follows:
$192.00 plus Energy Charges for Customer taking service at less than 2,300 volts and
$588.00 plus Energy Charges for Customer taking service at 2,300 volts or higher.
CONTRACT PERIOD: One year or longer.
(Continued)
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Oct. 29, 2012 Jan. 1, 2013
Jean D. Jewell Secretary
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Aug. 28, 2006 Sept. 15, 2006
Jean D. Jewell Secretary
‘ROCKY MOUNTAIN
POWER
A DIVISION OF PACIFICOAP
Eighth Revision of Sheet No.23A.1
I.P.U.C.No.1 Canceling Seventh Revision of Sheet No.23A.1
ROCKY MOUNTAIN POWER
ELECTRIC SERVICE SCHEDULE NO.23A
STATE OF IDAHO
General Service (Residential and Farm)
AVAILABILITY:At any point on the Company’s interconnected system where there are facilities of
adequate capacity for service to any customer who qualifies as a ‘Residential Load”or “Farm Load”under
both (1)the Pacific Northwest Electric Power Planning and Conservation Act,P.L.96-501 as the same may be
amended,and (2)a Residential Purchase and Sale Agreement,under Section 5(c)of such Act and in effect
between the Company and the Bonneville Power Administration.
APPLICATiON:This Schedule is for alternating current,single or three-phase electric service
supplied at Company’s available voltage through one metering installation at a single point of delivery for all
service required on the premises.
MONTHLY BILL:
Billing Months May Billing Months November
through October,inclusive through April,Inclusive
Customer Service
Charge:
Secondary voltage
delivery (Less than
2300 volts)$16.00 per Customer $16.00 per Customer
Primary voltage
delivery (2300 volts
or higher)$49.00 per Customer $49.00 per Customer
Energy Rate:9.44100 per kWh for all kWh 8.27420 per kwh for all kWh
(Continued)
Submitted Under Case No.PAC-E-16-12
ISSUED:November 11,2016 EFFECTIVE:January 1,2017
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Dec. 14, 2016 Jan. 1, 2017
Per O.N. 33668
Diane M. Hanian Secretary
Fourth Revision of Sheet No. 23A.2
I.P.U.C. No. 1 Canceling Third Revision of Sheet No. 23A.2
Submitted Under Advice No. 12-03
ISSUED: October 19, 2012 EFFECTIVE: January 1, 2013
ELECTRIC SERVICE SCHEDULE NO. 23A - Continued
Power Factor:
This rate is based on the Customer maintaining at all times a power factor of 85% lagging, or
higher, as determined by measurement. If the average power factor is found to be less than
85% lagging, Customer will be billed for 3/4 of 1% of the Power recorded by the Company’s
meter for every 1% that the power factor is less than 85%. This Power will be billed at the
Power Rate stated in Electric Service Schedule No. 6.
Voltage Discount:
Where Customer takes service from Company's available lines of 2,300 volts or higher and
provides and maintains all transformers and other necessary equipment, the voltage discount
based on measured Energy will be:
0.4397¢ per kWh for all kWh.
Minimum Bill:
The Customer Service Charge
POWER: The kW as shown by or computed from the readings of the Company’s Power meter for
the 15-minute period of Customer’s greatest use during the month, determined to the nearest kW.
MONTHLY BILLING REDUCTION: Rates in this Schedule shall be reduced by the monthly
kilowatt-hour credit adjustment set forth under "Monthly Rates" in the currently effective Electric Service
Schedule No. 34.
SEASONAL SERVICE: Service for annually recurring periods of seasonal use where service is
normally discontinued or curtailed during a part of the year may be contracted for under this Schedule under
either of the following conditions:
(a) Customer may contract for service under this Schedule on a year-round basis paying for all
service, including transformer losses where applicable, under the rates set forth under
"Monthly Bill" above including the monthly minimum bill during those months service is
curtailed or is not utilized in the Customer's operations.
(Continued)
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Oct. 29, 2012 Jan. 1, 2013
Jean D. Jewell Secretary
Third Revision of Sheet No. 23A.3
I.P.U.C. No. 1 Canceling Second Revision of Sheet No. 23A.3
Submitted Under Advice No. 12-03
ISSUED: October 19, 2012 EFFECTIVE: January 1, 2013
ELECTRIC SERVICE SCHEDULE NO. 23A – Continued
SEASONAL SERVICE: (continued)
(b) Customer may contract for seasonal service under this Schedule with a net minimum seasonal
payment as follows:
$192.00 plus Energy Charges for Customer taking service at less than 2,300 volts and
$588.00 plus Energy Charges for Customer taking service at 2,300 volts or higher.
CONTRACT PERIOD: One year or longer.
SPECIAL CONDITION: Domestic use means all usual residential, apartment, seasonal dwelling,
and mobile home court use including domestic water pumping. Farm use means all usual farm electrical loads
for raising of crops, livestock or pasturage and includes primary processing necessary for safe and efficient
storage or shipment and irrigation pumping.
Contiguous parcels of land under single-ownership or leasehold shall be considered to be one Farm and
noncontiguous parcels of land under single-ownership or leasehold shall be considered as one Farm unit when
operated as a single Farm, unless demonstrated otherwise by the owner or lessee of the parcels.
A number of factors shall determine whether contiguous or noncontiguous parcels constitute one or
more Farms. These factors shall include, but are not limited to:
-- size
-- use
-- ownership
-- control
-- operating practices
-- distance between parcels
-- custom in the trade
-- billing treatment by the utility
Operators of Farms may be required to certify to the utility all irrigation accounts, including
horsepower rating.
Customers who feel they meet the definitions of a Farm will have to make application with the
Company for review. If Customer application is denied by the Company, the Customer may appeal the
decision to the Idaho Public Utilities Commission.
(Continued)
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Oct. 29, 2012 Jan. 1, 2013
Jean D. Jewell Secretary
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Aug. 28, 2006 Sept. 15, 2006
Jean D. Jewell Secretary
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Aug. 28, 2006 Sept. 15, 2006
Jean D. Jewell Secretary
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Aug. 28, 2006 Sept. 15, 2006
Jean D. Jewell Secretary
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Aug. 28, 2006 Sept. 15, 2006
Jean D. Jewell Secretary
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Aug. 28, 2006 Sept. 15, 2006
Jean D. Jewell Secretary
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Aug. 28, 2006 Sept. 15, 2006
Jean D. Jewell Secretary
I.P.U.C. No. 1 Original Sheet No. 31.1
Submitted Under Case No. PAC-E-12-12
ISSUED: August 13, 2012 EFFECTIVE: January 1, 2013
ROCKY MOUNTAIN POWER
ELECTRIC SERVICE SCHEDULE NO. 31
STATE OF IDAHO
______________
Partial Requirements Service -- High Voltage
______________
AVAILABILITY: At any point on the Company's interconnected system where there are facilities
of adequate capacity.
APPLICATION: This Schedule is for alternating current, three phase electric service supplied at
approximately 44,000 volts or 69,000 volts or greater, through a single point of delivery for Supplementary,
Back-up, Maintenance Power or Excess Service (partial requirements service) in addition to regular electric
requirements obtained from any service other than the Company, including on-site generation. Customers not
contracting for Back-up Power shall not be subject to this Schedule and shall receive electric service under
Electric Service Schedule No. 9. This Schedule is not applicable to service for resale, intermittent or highly
fluctuating loads, or seasonal use. This Schedule is not required where on-site generation is used only for
emergency supply during times of utility outage. This Schedule is not available to loads in excess of 15,000 kW,
a maximum power requirement in excess of 15,000 kW shall be deemed to exist when a Customer’s maximum
power requirement exceeds 15,000 kW in at least three (3) months of any continuous period of six (6)
successive months.
(continued)
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Dec. 28, 2012 Jan. 1, 2013
Per O.N. 32704
Jean D. Jewell Secretary
ROCKY MOUNTAIN
POWER
A DMSON OF PIFICORP
Second Revision of Sheet No.31.2
I.P.U.C.No.1 Canceling First Revision of Sheet No.31.2
ELECTRIC SERVICE SCHEDULE NO.31-Continued
MONTHLY BILL:
Rate:
Billing Months May Billing Months November
through October. Inclusive through April.Inclusive
Customer Service
Charge:$370.00 per Customer $370.00 per Customer
Back-up Facilities
Rate:$5.70 per kW for all kW $4.30 per kW for all kW
The Facilities Rate applies to the kW of Back-up Contract Power
Back-up Power
Rate:$0.19 allkWDay $0.14 AIlkWDay
Back-up Power is billed on a per day basis and is based on the fifteen (15)
minute period of the Customers greatest use of Back-up Power during the
day.
Scheduled Maintenance Power rate is one half(1/2)ofthe Back-up Power
Rate.
Excess Power $20.52 per kW for all kW $15.48 per kW for all kW
Rate:
Supplementary $10.26 per kW for all kW $7.74 per kW for all kW
Power Rate:
Supplementary 4.1 8720 per kWh 4.18720 per kWh
and Back-up
Energy Rate:
POWER FACTOR:This rate is based on the Customer maintaining at all times a power factor of85%
lagging,or higher,as determined by measurement.If the average power factor is tbund to be less than 85%
lagging,the Power as recorded by the Company’s meter will be increased by ¾of 1%for every 1%that the power
factor is less than 85%.
(continued)
Submitted Under Case No.PAC-E-16-12
ISSUED:November 11,2016 EFFECTiVE:January 1,2017
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Dec. 14, 2016 Jan. 1, 2017
Per O.N. 33668
Diane M. Hanian Secretary
I.P.U.C. No. 1 Original Sheet No. 31.3
Submitted Under Case No. PAC-E-12-12
ISSUED: August 13, 2012 EFFECTIVE: January 1, 2013
ELECTRIC SERVICE SCHEDULE NO. 31 - Continued
POWER: The kW as shown by or computed from the readings of Company's Power meter for the
15-minute period of Customer's greatest use during the month or day, adjusted for power factor as specified,
determined to the nearest kW.
TYPE OF SERVICE: Whether Power is considered scheduled maintenance, supplementary, back-
up, or excess is determined as follows. When the Customer has pre-scheduled Maintenance Service, the power
measurements from 0 kW up to the level equal to the pre-scheduled Back-up Power shall be considered
Scheduled Maintenance Power. Power measurements above the Scheduled Maintenance Power up to the level
equal to the Supplementary Contract Power shall be considered supplementary power. Power measured above
the sum of the Scheduled Maintenance Power and Supplementary Contract Power level up to the Total Contract
Power (the sum of the Supplementary Contract Power and the Back-up Contract Power) shall be considered
Back-up Power. Power measurements in excess of Total Contract Power shall be considered Excess Power.
When the Customer has not pre-scheduled Maintenance Service, power measurements from 0 kW up to
the level equal to the Supplementary Contract Power shall be considered Supplementary Power. Power
measurements above the Supplementary Contract Power level but less than Total Contract Power (the sum of
the Supplementary Contract Power and the Back-up Contract Power) shall be considered back-up power. Power
measurements in excess of Total Contract Power shall be considered Excess Power.
DEFINITIONS:
BACK-UP CONTRACT POWER: The specified Power in kilowatts of Back-up Power that the
Customer contracts with the Company to supply and which the Company agrees to have available for delivery to
the Customer in excess of which the Company is under no obligation to supply. The Back-up Contract Power
shall be established by agreement between the Customer and the Company. The level of Back-up Contract
Power shall not exceed the total output capacity of the Customer's generation facilities.
BACK-UP POWER – DAILY: The kW of Back-up Contract Power supplied by the Company to the
Customer. Back-up Power shall be determined for each day of the Billing Period. The kW of Back-up Power
each day shall be the kW for the fifteen (15) minute period of the Customer's greatest use of Back-up Power that
day, adjusted for power factor as specified, determined to the nearest kW. The Back-up Power for the Billing
Period shall be the sum of the Back-up Power for each day of the Billing Period. For each fifteen minute period,
Back-up Power shall equal the Measured Power minus the Supplementary Contract Power but shall not be less
than zero nor greater than the Back-up Contract Power.
BACK-UP SERVICE: Back-up service is electric service used by the Customer to replace electric
service ordinarily generated by the Customer's own generation equipment during outages of the facility.
(continued)
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Dec. 28, 2012 Jan. 1, 2013
Per O.N. 32704
Jean D. Jewell Secretary
I.P.U.C. No. 1 Original Sheet No. 31.4
Submitted Under Case No. PAC-E-12-12
ISSUED: August 13, 2012 EFFECTIVE: January 1, 2013
ELECTRIC SERVICE SCHEDULE NO. 31 - Continued
DEFINITIONS (continued):
BILLING PERIOD: The period of approximately 30 days intervening between regular successive
meter reading dates. There shall be 12 billing periods per year.
POWER: The rate in kilowatts at which electric energy is generated, transferred or used. Power
measurements are calculated based on the average (integrated) usage over consecutive 15 minute periods of
time. Power measurements may be based on any one such fifteen minute period in a Billing Period, on the
period of greatest use during the Billing Period, or on the period of greatest use during each day, adjusted for
power factor as specified, determined to the nearest kW.
EXCESS POWER: Excess Power is the power supplied by the Company to the Customer in excess
of the Total Contract Power. The kW of Excess Power for the Billing Period shall be the kW for the 15 minute
period of the Customer's greatest use of Excess Power during the Billing Period, adjusted for power factor as
specified, determined to the nearest kW. For each 15 minute period, Excess Power shall equal the Measured
Power minus the Total Contract Power but shall not be less than zero.
EXCESS SERVICE: Excess service is service used by the Customer over and above the contracted
amount for both Supplementary Service and Back-up Service or Maintenance Service.
MAINTENANCE SERVICE: Maintenance service is electric service used by the Customer to
replace electric service ordinarily generated by the Customer's own generation equipment during scheduled
outages of the facility.
MEASURED POWER: The kW as shown by or computed from the readings of the Power meter
located at the Company's point of delivery, for the 15 minute period of the Customer’s greatest use during the
Billing Period or that day.
MEASURED ENERGY: The electric energy in kWh as shown by or computed from the readings of
the kilowatt-hour meter located at the Company's point of delivery
SCHEDULED MAINTENANCE POWER: Electric Power and energy made available by the
Company to a Customer during the scheduled maintenance periods established in accordance with the
provisions of this schedule to replace Back-up Power. Scheduled Maintenance Power shall not exceed the
Back-up Contract Power.
(continued)
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Dec. 28, 2012 Jan. 1, 2013
Per O.N. 32704
Jean D. Jewell Secretary
I.P.U.C. No. 1 Original Sheet No. 31.5
Submitted Under Case No. PAC-E-12-12
ISSUED: August 13, 2012 EFFECTIVE: January 1, 2013
ELECTRIC SERVICE SCHEDULE NO. 31 - Continued
DEFINITIONS (continued):
SUPPLEMENTARY CONTRACT POWER: The specified Power in kW of Supplementary Power
that the Customer contracts with the Company to supply and which the Company agrees to have available for
delivery to the Customer. The Supplementary Contract Power shall be established by agreement between the
Customer and the Company. Measured Power in excess of the Supplementary Contract Power shall not establish
new Supplementary Contract Power.
SUPPLEMENTARY POWER: The kW of Supplementary Contract Power supplied by the Company
to the Customer. The kW of Supplementary Power for the Billing Period shall be the kW for the 15 minute
period of the Customer's greatest use of Supplementary Power during the Billing Period, adjusted for power
factor as specified, determined to the nearest kW. For each 15 minute period during the Billing Period,
Supplementary Power shall equal the Measured Power but shall not be less than zero nor greater than the
Supplementary Contract Power.
SUPPLEMENTARY SERVICE: Supplementary service is electric service regularly used by a
Customer in addition to that which the Customer generates itself.
TOTAL CONTRACT POWER: The sum of the Supplementary Contract Power and the Back-up
Contract Power.
SCHEDULED MAINTENANCE: Customer shall submit to the Company, in writing, Customer's
proposed maintenance schedule and nominated Scheduled Maintenance Power for each month of an 18 month
period beginning with the date of the Customer's initial receipt of service under this schedule. Customer shall,
prior to September 1st of each subsequent year, submit to the Company, in writing, Customer's proposed
maintenance schedule for each month of an 18 month period beginning with January 1st of the following year.
The proposed schedules will not be deemed a request for Maintenance Service unless so designated by the
Customer and accepted by the Company in writing.
Maintenance shall be scheduled for a maximum of 30 days per year. These 30 days may be taken in either one
continuous period, or two continuous 15 day periods. Solely at the discretion of the Company and for good
cause, the maintenance maximum may be extended.
1. The Customer may present a request for a maintenance outage in writing to the Company no
less than 30 days in advance of the date of the scheduled maintenance with the nominated
Scheduled Maintenance Power. The Company reserves the right to modify Customer’s
requested maintenance schedule. Any modifications by the Company must be made with
reason within seven days after that schedule has been received by the Company.
(continued)
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Dec. 28, 2012 Jan. 1, 2013
Per O.N. 32704
Jean D. Jewell Secretary
I.P.U.C. No. 1 Original Sheet No. 31.6
Submitted Under Case No. PAC-E-12-12
ISSUED: August 13, 2012 EFFECTIVE: January 1, 2013
ELECTRIC SERVICE SCHEDULE NO. 31 – Continued
SCHEDULED MAINTENANCE (continued):
2. The Customer may request an adjustment in a scheduled maintenance outage up to 14 days in
advance of the expected maintenance. Company approval, or disapproval with reason, for such
adjustment shall be given within seven days of such request.
3. The Company may with reason cancel a scheduled maintenance outage at any time with seven
days notice prior to the beginning of a scheduled maintenance outage. Subject to the mutual
agreement of the Customer and the Company, that scheduled maintenance outage(s) canceled
by the Company may be rescheduled.
Total Contract Demand, Supplementary Contract Demand, and Back-up Contract Demand
The Customer shall contract for Total Contract Demand. This is the sum of the Supplementary Contract
Demand and the Back-up Contract Demand. The Customer may elect to increase Total Contract Demand by
increasing Supplementary Contract Demand and/or Back-up Contract Demand prospectively at any time,
provided there are facilities of adequate capacity, by providing notice to the Company. The Customer may elect
to increase Total Contract Demand by increasing Supplementary Contract Demand and/or Back-up Contract
Demand retroactively to the most recently completed Billing Period, provided there are facilities of adequate
capacity, by providing notice to the Company by the statement due date of the Billing Period. The
Supplementary Contract Demand may be reduced for a continuous period of each year provided that at least 12
month's written notice has been provided to the Company or as specified in contract. Only one request to reduce
Supplementary Contract Demand may be outstanding for each account. Customer may reduce Back-up Contract
Demand by providing written notice to PacifiCorp no less than six months in advance of the effective date of the
desired reduction, provided, only one such request may be made in any 12-month period. Within 15 days of
receipt of a timely written request by Customer, PacifiCorp shall advise Customer of the terms upon which
PacifiCorp would accept a reduction in contract demand. A period of reduction shall commence at the
beginning of a billing cycle and terminate at the end of a billing cycle.
FORCE MAJEURE: The Company shall not be subject to any liability or damages for inability to
provide service, and the Customer shall not be subject to any liability or damage for such inability to receive
service, to the extent that such inability shall be due to causes beyond the control of the party as specified in
Electric Service Regulation No. 4, Supply and Use of Service, Section 3. Should any of the foregoing occur, the
facilities charge shall be applied to only such Back-up Contract Demand as the Company is able to supply and
the Customer is able to receive and the minimum Billing Demand applicable to Supplemental Power under this
Schedule shall be waived. The Customer will have no liability for full service until such time as the Customer is
able to resume such service, except for any term minimum guarantees designed to cover special facilities
extension costs, if any. The party claiming Force Majeure under this provision shall make every reasonable
attempt to remedy the cause thereof as diligently and expeditiously as possible.
(continued)
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Dec. 28, 2012 Jan. 1, 2013
Per O.N. 32704
Jean D. Jewell Secretary
I.P.U.C. No. 1 Original Sheet No. 31.7
Submitted Under Case No. PAC-E-12-12
ISSUED: August 13, 2012 EFFECTIVE: January 1, 2013
ELECTRIC SERVICE SCHEDULE NO. 31 – Continued
CONTRACT PERIOD: One year or longer.
ELECTRIC SERVICE REGULATIONS: Service under this Schedule will be in accordance with
the terms of the Electric Service Agreement between the Customer and the Company. The Electric Service
Regulations of the Company on file with and approved by the Idaho Public Utilities Commission, including
future applicable amendments, will be considered as forming a part of and incorporated in said Agreement.
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Dec. 28, 2012 Jan. 1, 2013
Per O.N. 32704
Jean D. Jewell Secretary
ROCKY MOUNTAIN
Po\AIER
A Or\nSro}ri OF mOflCORP
I.P.U.C. No. 1
Sixth Revision of Sheet No. 34.1
Canceling Fifth Revision of Sheet No. 34.1
ROCKY MOUNTAIN POWER
ELECTRIC SERVICE SCHEDULE NO.34
STATE OF IDAHO
Pacific Northwest Electric Power Planning and Conservation Act
Residential and Farm Kilowatt-Hour Credit
APPLICATION AND AVAILABILITY: This Schedule is applicable and available to qualifying
Residential and/or Farm Customers of the Company under the jurisdiction of the Idaho Public Utilities
Commission.
MONTHLY RATES: The monthly charges for service under each of the Electric Service
Schedules shown below shall be reduced by the appropriate kilowatt-hour credit for all qualifying kilowatt-
hours ofresidential and/or farm use.
Kilowatt-Hour Credit Adj ustments :
Irrigation Customers:
Schedule No. 10
$0.008403 per kWh
Non-lrrigation Customers: $0.008403 per kWh
Schedule Nos. 1, 64, 7 A, 234
35A,36,19 with 64
19 with 23A,19 with 35A
Submitted Under Case No. PAC-E-17-10
ISSUED: August 18,2017
(continued)
EFFECTM: October 1, 2017
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Sept. 29, 2017 Oct. 1, 2017
Per O.N. 33896
Diane M. Hanian Secretary
First Revision of Sheet No. 34.2
I.P.U.C. No. 1 Canceling Original Sheet No. 34.2
Submitted Under Advice Letter No. 13-01
ISSUED: August 20, 2013 EFFECTIVE: October 1, 2013
ELECTRIC SERVICE SCHEDULE NO. 34 - Continued
MONTHLY RATES: (continued)
The above kilowatt-hour credit is subject to revision periodically, upon little or no notice, in order
that the monthly reduction in revenues may reflect the cost benefits received from the Bonneville Power
Administration under the Residential Purchase and Sale Agreement by and between the Bonneville Power
Administration, and Rocky Mountain Power (formerly Utah Power & Light Company) dated September 30,
1981.
BONNEVILLE POWER ADMINISTRATION BALANCING ACCOUNT: There shall be
established upon the books of account of the Company a balancing account. The account shall be used to
account for and record all amounts to be passed through to the Company's residential load in accordance
with the provisions of the Residential Purchase and Sale Agreement executed by the United States of
America, Department of Energy, acting by and through the Bonneville Power Administration and Rocky
Mountain Power (formerly Utah Power & Light Company) dated September 30, 1981.
Amounts included in this account shall be based upon the cost benefits resulting from transactions
with the Bonneville Power Administration and amounts actually passed through as credits to the Company's
customers.
The account and the kilowatt-hour credit herein shall be adjusted periodically to reflect actual net
cost benefits which result from the transactions with Bonneville Power Administration and to reflect the
actual credits passed through to the Company's customers. Following such adjustments, any balance in such
account, whether positive or negative, shall be carried forward and considered in determining to increase or
decrease the rate adjustment under this Electric Service Schedule 34.
Under no circumstances shall the Company be required to pass on credits to its customers under this
Electric Service Schedule which would exceed the net cost benefits received by the Company after all final
adjustments and any disallowance of benefits in connection with any transaction between the Company and
Bonneville Power Administration.
(continued)
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Sept. 30, 2013 Oct. 1, 2013
Jean D. Jewell Secretary
Second Revision of Sheet No. 34.3
I.P.U.C. No. 1 Canceling First Revision of Sheet No. 34.3
Submitted Under Advice Letter No. 13-01
ISSUED: August 20, 2013 EFFECTIVE: October 1, 2013
ELECTRIC SERVICE SCHEDULE NO. 34 - Continued
BONNEVILLE POWER ADMINISTRATION BALANCING ACCOUNT: (continued)
Should Bonneville Power Administration reduce cost benefit payments to the Company, for any
reason including determination that certain customers were not qualified under the Residential Purchase and
Sale Agreement to receive the kilowatt- hour credit then and in that event, the balancing account shall be
adjusted sufficiently to permit the Company to recover the amount of reduced cost benefit payments.
Any recoveries received from customers as provided in the qualifying Electric Service Schedules
shown above shall be included in the computation of the net cost benefits.
SPECIAL CONDITION:
1. Each person claiming a credit under eligible residential, general service, or irrigation
Electric Service Schedules listed on Sheet No. 34.1 with residential or farm electrical load at or above
100,000 kilowatt hours per year, and irrigation/pumping load at or above 250,000 kilowatt hours per year
shall file with the Company Bonneville Power Administration’s certificate to be eligible for Residential
Exchange Program benefits.
A residence is a structure used by one or more persons for daily living and associated activities. A
residence is eligible for REP benefits as long as its purpose is to provide shelter on a non-transient (greater
than 30 days) basis.
A farm consists of one or more parcels of land owned or leased by one or more persons or entities
(including partnerships, corporations, and any legal entity capable of owning farm land except the
government as defined as Federal, state, and local agencies in the Customer Load Eligibility Guidelines)
that is used primarily for agriculture.
A qualified irrigation/pumping load may receive benefits up to a maximum 400 horsepower per
month (222,000 kilowatt hours per month) of qualified irrigation/pumping load consumed by the specific
farm. If the owner of a large farm attempts to subdivide the farm into smaller parcels in order to increase the
amount of benefits, the farmer would be subverting the intent of Congress. Such subdivision is not
permitted.
Bonneville Power Administration’s Customer Load Eligibility Guidelines for the Residential
Exchange Program and Certificates shall be found at www.rockymountainpower.net/about/rar/iri/bpac.html#
under Regulatory Documents for Idaho.
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Sept. 30, 2013 Oct. 1 2013
Jean D. Jewell Secretary
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Aug. 28, 2006 Sept. 15, 2006
Jean D. Jewell Secretary
ROCKY MOUNTAIN
POWER
A OIVSION OF PACIFICORP
Ninth Revision of Sheet No.35.2
LP.U.C.No.1 Canceling Eighth Revision of Sheet No.35.2
ELECTRIC SERVICE SCHEDULE NO.35-Continued
MONTHLY BILL:
Customer Service Charge:
Secondary voltage delivery
(Less than 2300 volts)$67.00 per Customer
Primary voltage delivery
(2300 volts or higher)$165.00 per Customer
Power Charge:
On-Peak kW $16.45 per kW
Energy Charge:
Per kWh for all kWh 5.21970
TIME PERIODS:
On-Peak 7:00 n.m.to 10:00 p.m.,Monday thru Friday,except holidays.
Off-Peak All other times.
Due to the expansions of Daylight Saving Time (DST)as adopted under Section 110 of the
U.S.Energy Policy Act of 2005 the time periods shown above will begin and end one hour later for the
period between the second Sunday in March and the first Sunday in April,and for the period between the
last Sunday in October and the first Sunday in November.
Holidays include only New Year’s Day,President’s Day,Memorial Day,Independence Day,
Labor Day,Thanksgiving Day,and Christmas Day.When a holiday falls on a Saturday or Sunday,the
Friday before the holiday (if the holiday falls on a Saturday)or the Monday following the holiday (if the
holiday falls on a Sunday)will be considered a holiday and consequently Off-Peak.
Power Factor:This rate is based on the Customer maintaining at all times a Power factor of 85%
lagging,or higher,as determined by measurement. If the average Power factor is found to be less than 85%
lagging the Power as recorded by the Company’s meter will be increased by 3/4 of 1%for every 1%that the
Power factor is less than 85%.
Voltage Discount:Where Customer takes service from Company’s available lines of 2,300 volts or
higher and provides and maintains all transformers and other necessary equipment,the voltage discount
based on highest measured Power during the billing cycle will be:
$0.84 per kW
Minimum:Customer Service Charge plus applicable Demand and Energy charges.
(Continued)
Submitted Under Case No.PAC-E-16-12
ISSUED: November 11,2016 EFFECTIVE:January 1,2017
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Dec. 14, 2016 Jan. 1, 2017
Per O.N. 33668
Diane M. Hanian Secretary
Fourth Revision of Sheet No. 35.3
I.P.U.C. No. 1 Canceling Third Revision of Sheet No. 35.3
Submitted Under Advice No. 12-03
ISSUED: October 19, 2012 EFFECTIVE: January 1, 2013
ELECTRIC SERVICE SCHEDULE NO. 35 - Continued
POWER: The On-Peak kW shall be the kW as shown by or computed from the readings of
Company's Power meter for the 15-minute period of Customer's greatest use during the On-Peak periods
during the month as previously defined, adjusted for Power Factor as specified, determined to the nearest
kW.
SEASONAL SERVICE: Service for annually recurring periods of seasonal use where service
is normally discontinued or curtailed during a part of the year may be contracted for under this schedule
under either of the following conditions:
(a) Customer may contract for service under this schedule on a year-round basis paying for all
service, including transformer losses where applicable, under the rates set forth under
"Monthly Bill" above including the monthly minimum bill during those months service is
curtailed or is not utilized in the Customer's operation.
(b) Customer may contract for seasonal service under this schedule with a net minimum
seasonal payment as follows:
$ 804.00 plus Power and Energy Charges for Customer taking service at less than
2300 volts, and
$1,980.00 plus Power and Energy Charges for Customer taking service at 2300 volts or
higher.
CONTRACT PERIOD: One year or longer.
ELECTRIC SERVICE REGULATIONS: Service under this Schedule will be in
accordance with the terms of the Electric Service Agreement between the Customer and the Company. The
Electric Service Regulations of the Company on file with and approved by the Idaho Public Utilities
Commission, including future applicable amendments, will be considered as forming a part of and
incorporated in said Agreement.
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Oct. 29, 2012 Jan. 1, 2013
Jean D. Jewell Secretary
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Aug. 28, 2006 Sept. 15, 2006
Jean D. Jewell Secretary
ROCKY MOUNTAIN
POWER
ADIVISION QF PACIflCORP
Ninth Revision of Sheet No.35A.2
I.P.U.C.No.1 Canceling Eighth Revision of Sheet No.35A.2
ELECTRIC SERVICE SCHEDULE NO.35A -Continued
MONTHLY BILL:
Customer Service Charge:
Secondary voltage delivery
(Less than 2300 volts)$67.00 per Customer
Primary voltage delivery
(2300 volts or higher)$165.00 per Customer
Power Charge:
On-Peak kW $16.45 per kW
Energy Charge:
Per kWh for all kWh 5.21 97
TIME PERIODS:
On-Peak 7:00 a.m.to 10:00 p.m..Monday thru Friday.except holidays.
OffPeak All other times.
I)ue to the expansions of Daylight Saving Time (DST)as adopted under Section 110 of the U.S.
Energy Policy Act of 2005 the time periods shown above will begin and end one hour later for the period
between the second Sunday in March and the first Sunday in April.and for the period between the last
Sunday in October and the first Sunday in November.
Holidays include only New Year’s Day.President’s Day,Memorial Day,Independence Day,
Labor Day,Thanksgiving Day.and Christmas Day,When a holiday falls on a Saturday or Sunday,the
Friday before the holiday (if the holiday falls on a Saturday) or the Monday following the holiday (if the
holiday falls on a Sunday)will be considered a holiday and consequently Off-Peak.
Power Factor:This rate is based on the Customer maintaining at all times a Power factor of 85%
lagging,or higher.as determined by measurement.If the average Power factor is found to be less than 85%
lagging the Power as recorded by the Company’s meter will be increased by 3/4 of 1%for every 1%that the
Power factor is less than 85%.
Voltage Discount:Where Customer takes service from Company’s available lines of 2,300 volts or
higher and provides and maintains all transformers and other necessary equipment,the voltage discount
based on highest measured Power during the billing cycle will be:
$0.84 per kW
Minimum:Customer Service Charge plus applicable Demand and Energy charges.
(Continued)
Submitted Under Case No.PAC-E-16-12
ISSUED:November Ii,2016 EFFECTIVE:January 1,2017
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Dec. 14, 2016 Jan. 1, 2017
Per O.N. 33668
Diane M. Hanian Secretary
Fourth Revision of Sheet No. 35A.3
I.P.U.C. No. 1 Canceling Third Revision of Sheet No. 35A.3
Submitted Under Advice No. 12-03
ISSUED: October 19, 2012 EFFECTIVE: January 1, 2013
ELECTRIC SERVICE SCHEDULE NO. 35A - Continued
MONTHLY BILLING REDUCTION: Rates in this schedule shall be reduced by the monthly
kilowatt-hour credit adjustment set forth under "Monthly Rates" in the currently effective Electric Service
Schedule No. 34.
POWER: The On-Peak kW shall be the kW as shown by or computed from the readings of
Company's Power meter for the 15-minute period of Customer's greatest use during the On-Peak periods
during the month as previously defined, adjusted for Power Factor as specified, determined to the nearest
kW.
SEASONAL SERVICE: Service for annually recurring periods of seasonal use where service is
normally discontinued or curtailed during a part of the year may be contracted for under this schedule under
either of the following conditions:
(a) Customer may contract for service under this schedule on a year-round basis paying for all
service, including transformer losses where applicable, under the rates set forth under
"Monthly Bill" above including the monthly minimum bill during those months service is
curtailed or is not utilized in the Customer's operation.
(b) Customer may contract for seasonal service under this schedule with a net minimum
seasonal payment as follows:
$ 804.00 plus Power and Energy Charges for Customer taking service at less than
2300 volts, and
$1,980.00 plus Power and Energy Charges for Customer taking service at 2300 volts or
higher.
CONTRACT PERIOD: One year or longer.
SPECIAL CONDITION: Farm use means all usual farm electrical loads for raising of crops,
livestock or pasturage and includes primary processing necessary for safe and efficient storage or shipment.
Contiguous parcels of land under single-ownership or leasehold shall be considered to be one Farm
and noncontiguous parcels of land under single-ownership or leasehold shall be considered as one Farm unit
when operated as a single Farm, unless demonstrated otherwise by the owner or lessee of the parcels.
(Continued)
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Oct. 29, 2012 Jan. 1, 2013
Jean D. Jewell Secretary
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Aug. 28, 2006 Sept. 15, 2006
Jean D. Jewell Secretary
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Aug. 28, 2006 Sept. 15, 2006
Jean D. Jewell Secretary
ROCKY MOUNTAIN
POWER
A DMS)ON OF PAFICORP
Eleventh Revision of Sheet No.36.2
IP.U.C.No.I Canceling Tenth Revision of Sheet No.36.2
ELECTRIC SERVICE SCHEDULE NO.36 -Continued
MONTHLY BILL:
Rate:
Billing Months May Billing Months November
through October.Inclusive through April.Inclusive
Customer Service $14.00 per Customer $14.00 per Customer
Charge:
On Peak Energy Charge:14.78220 per kWh 12.66440 per kWh
Off Peak Energy 5.21280 perkWh 4.79260 perkWh
Charge:
Minimum Bill:Customer Service Charge.
On Peak
Summer months--All kWh used from 8:00 AM.to 11:00 P.M.,Monday through Friday,
except holidays.
Winter months--All kWh used from 7:00 AM.to 10:00 P.M.,Monday through Friday,
except holidays.
Holidays include only:New Year’s Day,President’s Day.Memorial Day,Independence
Day,Labor Day,Thanksgiving Day,and Christmas Day.
Off Peak:
All other kWh usage.
I)ue to the expansions of Daylight Saving Time (UST)as adopted under Section 110 of the U.S.
Energy Policy Act of 2005 the time periods shown above will begin and end one hour later for the period
between the second Sunday in March and the first Sunday in April,and for the period between the last
Sunday in October and the first Sunday in November.
SEASONAL SERVICE:When seasonable service is supplied under this Schedule,the minimum
seasonal charge will be $168.00 plus energy charges.
CONTRACT PERIOD:One year or longer.
MONTHLY BILLING REDUCTION:Rates in this schedule shall be reduced by the monthly
kilowatt-hour credit adjustment set forth under “Monthly Rates”in the currently effective Electric Service
Schedule No. 34,
(Continued)
Submitted Under Case No.PAC-E-16-12
ISSUED:November Il,2016 EFFECTIVE:January 1,2017
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Dec. 14, 2016 Jan. 1, 2017
Per O.N. 33668
Diane M. Hanian Secretary
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
July 24, 2006 March 1, 2007
Jean D. Jewell Secretary
I.P.U.C. No. 1 Original Sheet No. 38.1
Submitted Under Case No. PAC-E-16-01
ISSUED: January 13, 2016 EFFECTIVE: April 15, 2016
ROCKY MOUNTAIN POWER
ELECTRIC SERVICE SCHEDULE NO. 38
STATE OF IDAHO
______________
Qualifying Facility Avoided Cost Procedures
______________
PREFACE:
1. The process outlined in this Schedule is typically applicable to projects already under
development.
2. All submissions, responses and notices required in this Schedule must be done in
electronic or hard copy format. Requests and information may be submitted to the
Company at QFrequests@pacificorp.com .
3. The QF pricing queue referenced in this Schedule is independent of and unrelated to
the interconnection and transmission services queue maintained and administered by
PacifiCorp Transmission Services pursuant to PacifiCorp Transmission Service’s
FERC approved Open Access Transmission Tariff (OATT), as posted on its Open
Access Same-Time Information System (OASIS). The generation interconnection
process is a critical and lengthy process that typically must be well underway before
a power purchase agreement should be requested. QF Developers are strongly
encouraged to gain a clear understanding of the transmission interconnection process
and associated costs and timelines before requesting indicative pricing or a power
purchase agreement under this schedule.
4. The Company must use its reasonable commercial efforts to meet all Company
deadlines specified herein, and shall attempt to make up any Company delays in
meeting subsequent Company deadlines. QF Developer deadlines will be extended to
reflect Company delays beyond Company deadlines specified herein. Under
extenuating circumstances, the Company or a QF Developer may request an extension
of any deadlines from the Commission.
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
March 3, 2016 April 15, 2016
Per O.N. 33474
Jean D. Jewell Secretary
I.P.U.C. No. 1 Original Sheet No. 38.2
Submitted Under Case No. PAC-E-16-01
ISSUED: January 13, 2016 EFFECTIVE: April 15, 2016
ELECTRIC SERVICE SCHEDULE NO. 38 - Continued
PREFACE: (continued)
5. Subject to the specific tariff provisions provided below, the general timelines and
deadlines for actions or responses for Developers and the Company in this tariff are
summarized here for convenience, along with references to the relevant tariff
provisions:
a) Company must provide Developer illustrative, pro forma contract within seven
(7) days of request [Section I.B.1];
b) Developer may request indicative pricing at any time by submitting required
information [Section I.B.2];
c) Company must notify Developer whether request for indicative pricing is
complete within seven (7) days of submission [Section I.B.3];
d) Company must provide indicative pricing within thirty (30) days of notice of
completeness [Section I.B.4];
e) Developer must request draft power purchase agreement and submit required
information within sixty (60) days of receipt of indicative pricing [Section I.B.5];
f) Company must notify Developer whether request for power purchase agreement
and required information is complete within seven (7) days of submission to the
Company [Section I.B.6];
g) Company must provide Developer with draft power purchase agreement within
thirty (30) days of notice of completeness [Section I.B.6];
h) Developer must provide Company with initial comments on and proposed edits
to draft power purchase agreement within thirty (30) days of receipt [Section
I.B.7];
i) Company must respond to Developer’s initial comments and edits within thirty
(30) days of receipt, and commence negotiations over areas of disagreement
[Section I.B.8];
j) Indicative prices must be updated unless a PPA is executed within six (6) months
after indicative pricing was provided by the Company [Section I.B.9];
k) Company must complete all internal reviews and approvals within twenty-one
(21) days after agreement is reached on a proposed final version of a power
purchase agreement [Section I.B.8];
l) PPA must be executed within five (5) months after Developer’s receipt of draft
power purchase agreement [Section I.B.10];
m) Company must submit power purchase agreement to Commission for approval
within seven (7) days of execution [Section I.B.8]; and
n) Company must submit Transmission Service Request within seven (7) days after
execution of purchase power agreement [Section I.B.8].
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
March 3, 2016 April 15, 2016
Per O.N. 33474
Jean D. Jewell Secretary
I.P.U.C. No. 1 Original Sheet No. 38.3
Submitted Under Case No. PAC-E-16-01
ISSUED: January 13, 2016 EFFECTIVE: April 15, 2016
ELECTRIC SERVICE SCHEDULE NO. 38 - Continued
PREFACE: (continued)
6. QF Developers should pay special attention to the fact that, as specified in the
tariff sections that follow, a QF project will typically be removed from the QF
pricing queue, and any indicative or proposed prices or agreements will no longer
be valid, upon occurrence of any of the following events:
a) Failure of the QF Developer to submit to the Company a request for a power
purchase agreement within sixty (60) days of its receipt of indicative pricing, as
specified in Section I.B.5;
b) Failure of the QF Developer to submit written comments and proposals within
thirty (30) days of its receipt of a proposed power purchase agreement, as specified
in Section I.B.7;
c) Failure of the parties to execute a power purchase agreement within five (5)
months after a draft power purchase agreement was provided by the Company to
the QF Developer, as specified in Section I.B.10.e.; or
d) A material change in the point of interconnection, a change in design capacity of
more than 10%, a change in generation technology, or a change of more than
three (3) months in the online date, as specified in Sections I.B.10.a.-d.
7. When a QF project is removed from the QF pricing queue, the developer may
request new indicative pricing and a new agreement by timely following all of the
steps outlined below, in which case it will be placed in the QF pricing queue as a
new project.
AVAILABILITY: To owners of Qualifying Facilities (QFs) in all territory served
by the Company in the state of Idaho.
APPLICATION: To owners of existing or proposed wind or solar QFs with a design
capacity greater than 100 kW, or Seasonal or Non-Seasonal Hydro projects and all other
projects greater than 10 a MW who desire to make sales to the Company and to QFs who are
not able to obtain pricing under the standard published rates. Such owners will be required
to enter into written power purchase and interconnection agreements with the Company
pursuant to the procedures set forth below. Additional or different requirements may apply
to Idaho QFs seeking to make sales to third-parties, or out-of-system QFs seeking to wheel
power to Idaho for sale to the Company.
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
March 3, 2016 April 15, 2016
Per O.N. 33474
Jean D. Jewell Secretary
I.P.U.C. No. 1 Original Sheet No. 38.4
Submitted Under Case No. PAC-E-16-01
ISSUED: January 13, 2016 EFFECTIVE: April 15, 2016
ELECTRIC SERVICE SCHEDULE NO. 38 – Continued
I. Process For Negotiating Power Purchase Agreements
A. Communications
Unless otherwise directed by the Company, all communications to
the Company regarding QF power purchase agreements should be
directed in writing as follows:
Rocky Mountain Power
Manager - QF Contracts
825 NE Multnomah St, Suite 600
Portland, Oregon 97232
QFrequests@pacificorp.com
The Company will respond to all such communications in a timely manner. If
the Company is unable to respond on the basis of incomplete or missing
information from the QF owner, the Company shall indicate what additional
information is required. Thereafter, the Company will respond in a timely
manner following receipt of all required information.
B. Procedures
1. Request for Pro Forma Contract. The Company shall provide a QF
Developer with a pro forma power purchase agreement within seven (7)
days of its receipt of a request for the same. The pro forma document
provided (i) does not constitute an offer to enter into an agreement, (ii) may
include general proposed terms and conditions, and (iii) will not include
pricing or project specific information. Anyone who desires to enter into
a power purchase agreement with the Company must proceed in
accordance with this Schedule to request indicative pricing under Section
I.B.2, to request a proposed power purchase agreement under Section
I.B.5, and to negotiate and execute a power purchase agreement that is
executed by the Company and approved by the Commission.
2. Request for Indicative Pricing. To obtain indicative pricing with respect
to a proposed project, a QF Developer must provide to the Company the
following general project information:
a) A general description of the QF project and the QF Developer,
including email address and other contact information;
b) generation technology and other related technology applicable to the
site and for solar projects specify fixed ground mount or solar
tracking;
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
March 3, 2016 April 15, 2016
Per O.N. 33474
Jean D. Jewell Secretary
I.P.U.C. No. 1 Original Sheet No. 38.5
Submitted Under Case No. PAC-E-16-01
ISSUED: January 13, 2016 EFFECTIVE: April 15, 2016
ELECTRIC SERVICE SCHEDULE NO. 38 – Continued
I. B. Procedures (continued)
c) design capacity (MW), station service requirements, and net amount of
power to be delivered to the Company's electric system;
d) quantity and timing of monthly power deliveries (including project’s
ability to respond to dispatch orders from the Company) and an hourly
generation profile (12X24 profile minimum, 8760 preferred) in Excel
or other spreadsheet format with all formulae intact, and the expected
generation degradation per year and whether the degradation rate is
calculated against the first year or against the prior year, or a forecast
of annual generation for each contract year over the life of the
requested contract term;
e) proposed site location and electrical interconnection point;
f) proposed on-line date and outstanding permitting requirements;
g) demonstration of ability to obtain QF status (FERC Form 556);
h) fuel type(s) and source(s);
i) plans for fuel and transportation agreements (Motive force plans);
j) proposed length of contract term;
k) status of transmission interconnection arrangements including
interconnection queue number; and
l) other information promptly and reasonably requested by the Company.
3. Notice of Completeness and Queue Position. Within seven (7) days of its
receipt of a request for indicative pricing and supporting materials as specified
above, the Company shall confirm its receipt of the same and notify the QF
Developer whether the submission is substantially complete or if additional
information is required. The Company shall not be obligated to provide
indicative pricing until all information described in Paragraph I.B.2 has been
received from the QF Developer. Indicative pricing will be determined in light
of other QF projects in the QF pricing queue ahead of the project, and using
inputs and procedures as approved by the Commission. A QF will be added
to the QF pricing queue as of the date the Company has confirmed receipt of
all project information required in Paragraph I.B.2 and will retain its priority
position in the QF pricing queue for purposes of subsequent requests for
indicative pricing unless and until removed from the QF pricing queue as
provided herein. The Company will notify the QF Developer of the date its
project was added to the QF pricing queue. Once a QF Project has been added
to the QF pricing queue, in the event additional clarifying information is
reasonably required by the Company in order to calculate indicative prices, the
deadlines in Section I.B.4 shall be extended
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
March 3, 2016 April 15, 2016
Per O.N. 33474
Jean D. Jewell Secretary
I.P.U.C. No. 1 Original Sheet No. 38.6
Submitted Under Case No. PAC-E-16-01
ISSUED: January 13, 2016 EFFECTIVE: April 15, 2016
ELECTRIC SERVICE SCHEDULE NO. 38 – Continued
on a day for day basis until the requested clarifying information has been
provided.
I. B. Procedures (continued)
4. Indicative Pricing. Within thirty (30) days following the date a QF project was
added to the QF pricing queue under Section I.B.3, the Company shall provide the
QF Developer with indicative pricing, which may include other indicative terms
and conditions, tailored to the individual characteristics of the proposed project.
An indicative pricing proposal provided by the Company may be used by the QF
Developer to make determinations regarding project planning, financing and
feasibility. However, such prices are indicative only and may be subject to change
by the Company as specified herein or by the Commission. Prices and other terms
and conditions are only final and binding to the extent contained in a power
purchase agreement executed by both parties and approved by the Commission.
The Commission may approve, reject or conditionally approve a power purchase
agreement and may at any time make changes to this Schedule, QF pricing
methods and inputs, or terms and conditions applicable to QF pricing and power
purchase agreements.
5. Request for Draft Power Purchase Agreement. If a QF Developer desires to
precede forward with the project it must, within sixty (60) days of its receipt of
indicative pricing, request that the Company prepare and submit for the
Developer’s review a proposed power purchase agreement. Absent timely
submittal of such request, the project will be removed from the QF pricing queue
and the indicative prices will no longer be valid. In connection with its request for
a power purchase agreement, the Developer must provide the Company with the
following additional project information:
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
March 3, 2016 April 15, 2016
Per O.N. 33474
Jean D. Jewell Secretary
I.P.U.C. No. 1 Original Sheet No. 38.7
Submitted Under Case No. PAC-E-16-01
ISSUED: January 13, 2016 EFFECTIVE: April 15, 2016
ELECTRIC SERVICE SCHEDULE NO. 38 - Continued
I. B. Procedures (continued)
a) any available updates to the information specified in Paragraph I.B.2;
b) evidence of adequate control of proposed site;
c) identification of and timelines for obtaining any necessary governmental
permits, approvals or authorizations;
d) assurance of fuel supply or motive force;
e) anticipated timelines for completion of key project milestones;
f) evidence that any necessary interconnection studies are underway and that
the necessary interconnection arrangements can timely be completed in
accordance with Part II sufficient for the project to reach energization by
the proposed on-line date;
g) information describing the developer/owner of the proposed project,
including name, address, and ownership organization chart; and
h) other information promptly and reasonably requested by the Company.
6. Notice of Completeness and Draft PPA. Within seven (7) days of its receipt of
a request for a power purchase agreement and the information specified in Section
I.B.5, the Company shall confirm its receipt of the same and notify the Developer
whether any additional information is needed. The Company shall provide the
Developer with a proposed power purchase agreement within thirty (30) days
following the date of the Company’s notice that the information required in
Paragraph I.B.5 has been received and is substantially complete. The proposed
power purchase agreement shall contain a comprehensive set of proposed terms
and conditions, including specific pricing based on the indicative pricing provided,
as adjusted if necessary in light of specifics of the project. The proposed power
purchase agreement will also specify project specific data and exhibits that must
be provided by the QF Developer prior to final approval or execution of the PPA.
The proposal submitted by the Company shall serve as the basis for subsequent
negotiations.
7. Developer’s Initial Comments and Edits. Within thirty (30) days of receiving a
proposed power purchase agreement, the QF Developer shall prepare and deliver
to the Company an initial set of written comments and proposals, failing which
the Project will be removed from the QF pricing queue and the proposed
agreement and prices will no longer be valid.
8. Company’s Response and Responsibilities. If the QF Developer’s proposals are
not acceptable, the Company shall commence negotiations on all outstanding areas
of disagreement, and:
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
March 3, 2016 April 15, 2016
Per O.N. 33474
Jean D. Jewell Secretary
I.P.U.C. No. 1 Original Sheet No. 38.8
Submitted Under Case No. PAC-E-16-01
ISSUED: January 13, 2016 EFFECTIVE: April 15, 2016
ELECTRIC SERVICE SCHEDULE NO. 38 - Continued
I. B. Procedures (continued)
a) shall respond to the developer’s initial comments and proposals within thirty
(30) days, and thereafter respond timely to subsequent comments and
proposals;
b) will not unreasonably delay negotiations and will respond in good faith to any
additions, deletions or modifications to the draft power purchase agreement
that are proposed by the QF Developer;
c) may request to visit the site of the proposed project if such a visit has not
previously occurred;
d) may request additional information from the Developer if reasonably
necessary to finalize the terms of the power purchase agreement and satisfy
the Company's due diligence with respect to the Project; and
e) shall submit to PacifiCorp Transmission Services a request for network
transmission service relating to the project within seven (7) days after
execution of a power purchase agreement, or otherwise as early as
practicable based on the applicable PacifiCorp Transmission Services tariff;
f) shall complete credit, legal, upper management and any other required
internal reviews of proposed terms and conditions within twenty-one (21)
days after agreement was reached on a proposed final version of a power
purchase agreement; and
g) shall submit a fully executed power purchase agreement to the Commission
for approval within seven (7) days of execution.
9. Required Pricing Update. The prices in the proposed power purchase agreement
provided by the Company under Section I.B.6 shall be recalculated by the
Company using the most recent available pricing inputs and methods approved by
the Commission, but without a change in the QF project’s pricing queue priority,
if the QF Developer and the Company have not executed a power purchase
agreement within six months after indicative pricing was provided by the
Company under Section I.B.4, except to the extent delays are caused by Company
actions or inactions, which may include delays in obtaining legal, credit or upper
management approval by the Company.
10. Removal from QF Pricing Queue. In addition to the circumstances described in
I.B.5 and I.B.7, at any time during the process outlined in I.B.3 through I.B.9, the
Company shall remove a QF project from the QF pricing queue, and any
associated indicative prices, proposed prices or proposed agreement previously
provided will no longer be valid, if any of the following occurs with respect to a
QF project:
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
March 3, 2016 April 15, 2016
Per O.N. 33474
Jean D. Jewell Secretary
I.P.U.C. No. 1 Original Sheet No. 38.9
Submitted Under Case No. PAC-E-16-01
ISSUED: January 13, 2016 EFFECTIVE: April 15, 2016
ELECTRIC SERVICE SCHEDULE NO. 38 - Continued
I. B. Procedures (continued)
a) A material change in the point of interconnection;
b) A change in design capacity of 10% or more of the original specified
design capacity;
c) A change in generation technology (i.e. solar, wind, thermal), including a
change between fixed tilt and tracking solar projects. Changes in the
quantity and timing of monthly power deliveries will not cause removal
from the QF pricing queue so long as the basic generation technology and
design capacity have not changed;
d) A change in the online date specified in the information provided under
Section I.B.2.f of more than three months earlier or later; or
e) A PPA has not been executed by both parties within five (5) months after
the draft PPA was provided by the Company to the Developer, except to
the extent delays are caused by Company actions or inactions.
11. Standard PPA Terms. Absent Commission approval to the contrary for good
cause shown, a power purchase agreement executed under this Schedule shall
include the following terms and conditions, among others:
a) The scheduled commercial operation date must not be greater than thirty
(30) months after the execution date of the power purchase agreement;
b) The QF Developer must sign a System Impact Study Agreement with
PacifiCorp Transmission (refer to Section 42.2 or Section 51.4 of
PacifiCorp’s OATT) within 120 days of the date a Commission Order
approving the agreement has become final and non-appealable; and
c) The QF Developer must provide 100% of the project development security
within 30 days of the date a Commission Order approving the PPA has
become final and non-appealable.
II. Process for Negotiating Interconnection Agreements
In addition to negotiating a power purchase agreement, QFs intending to make sales to the
Company are also required to enter into an interconnection agreement that governs the
physical interconnection of the project to the Company's transmission or distribution system.
The Company's obligation to make purchases from a QF is conditioned upon all necessary
interconnection arrangements being consummated.
It is recommended that the owner initiate its request for interconnection as early in the
planning process as possible, to ensure that necessary interconnection arrangements proceed
in a timely manner on a parallel track with negotiation of the power purchase agreement.
Interconnection agreements (both transmission and distribution level voltages) are handled
by the Company's power delivery function, PacifiCorp Transmission Services.
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
March 3, 2016 April 15, 2016
Per O.N. 33474
Jean D. Jewell Secretary
I.P.U.C. No. 1 Original Sheet No. 38.10
Submitted Under Case No. PAC-E-16-01
ISSUED: January 13, 2016 EFFECTIVE: April 15, 2016
ELECTRIC SERVICE SCHEDULE NO. 38 - Continued
II. Process for Negotiating Interconnection Agreements (continued)
A. Communications
Initial communications regarding interconnection agreements should be directed to
the Company in writing as follows:
PacifiCorp Transmission Services
Interconnection Requests
825 NE Multnomah St, Suite 1600
Portland, Oregon 97232
QFrequests@pacificorp.com
B. Procedures
Generally, the interconnection process involves (1) initiating a request for
interconnection, (2) completion of studies to determine the system impacts associated
with the interconnection and the design, cost, and schedules for constructing any
necessary interconnection facilities, (3) execution of an interconnection agreement.
The QF project owner is responsible for all interconnection costs assessed by the
Company on a nondiscriminatory basis.
For interconnections greater than twenty (20) megawatts, the Company will process
the interconnection application through PacifiCorp Transmission Services generally
following the procedures for studying the generation interconnection described in the
Company’s Open Access Transmission Tariff, PacifiCorp FERC Electric Tariff, Fifth
Revised Volume No. 11 Pro Forma Open Access Transmission Tariff (OATT), as the
same may be changed or updated, on file with the Federal Energy Regulatory
Commission (FERC). A copy of the OATT is available on-line at
http//www.oasis.pacificorp.com.
The Company’s interconnection forms and agreements, are provided electronically at the
following address: http://www.pacificorp.com/tran/ts/gip/qf.html
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
March 3, 2016 April 15, 2016
Per O.N. 33474
Jean D. Jewell Secretary
I.P.U.C. No. 1 Original Sheet No. 38.11
Submitted Under Case No. PAC-E-16-01
ISSUED: January 13, 2016 EFFECTIVE: April 15, 2016
ELECTRIC SERVICE SCHEDULE NO. 38 - Continued
III. Process for Filing a Complaint with the Commission on Contract Terms
The Commission has both informal and formal dispute resolution processes which can
be reviewed on the Commission website at the following
address: http://www.puc.idaho.gov/forms/consumerassistance
These processes are available for any matter as to which the Commission has
jurisdiction, which may include (i) QF PPA contracts, (ii) small QF interconnection
agreements (less than 20 MW), and (iii) large QF interconnection agreements (more
than 20 MW), so long as all of the QF output is sold exclusively to the Company. To
the extent any portion of the QF output is sold to anyone other than the Company, a
QF generation interconnection may be subject to FERC jurisdiction. Nothing in this
Schedule will affect the jurisdiction of the Commission or FERC, and all parties will
retain any and all rights they may have under any applicable state or federal statutes
or regulations.
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
March 3, 2016 April 15, 2016
Per O.N. 33474
Jean D. Jewell Secretary
ROCKY MOUNTAIN
POWER
A DIVISION OF PACIFICORP
I.P.U.C.No.1 Fourth Revisiou of Sheet No.70.1
Canceling Third Revision of Sheet No.70.1
ROCKY MOUNTAIN POWER
ELECTRIC SERVICE SCHEDULE NO.70
STATE OF IDAHO
Renewable Energy
Rider -Optional
AVAILABILITY:In all territory served by the Company in the state ofIdaho.
APPLICATION:To Customers receiving service under the Company's Electric Service
Schedules.
ADMINISTRATION:Funds received from Customers under this Schedule will cover program
costs and match Renewable Energy purchases to Block purchases.Funds not spent after covering program
costs and matching Renewable Energy purchases may be used to fund Qualifying Initiatives as defined
below.
BLOCK:1 Block equals 100 kWh ofRenewable Energy.
CHARGE PER BLOCK:$1.95 per month
MONTHLY BILL:The Monthly Bill shall be the number of Blocks the Customer has agreed to
purchase multiplied by the Charge per Block.The Monthly Bill is in addition to all other charges contained
in Customer's applicable tariff schedule.This rider's Monthly Bill shall be applied to the Customer's billing
regardless ofactual energy consumption.
RENEWABLE ENERGY:Renewable Energy includes bundled power or Renewable Energy
Credits (RECs)derived from the following fuels:
•wind;
•solar
•geothermal energy;
•certified low impact hydroelectric;
•hydrogen derived from photovoltaic electrolysis or a non-hydrocarbon derivation process;
•pipeline or irrigation canal hydroelectric systems;
•wave or tidal action;and
(Continued)
Submitted Under Advice Letter No.12-02
ISSUED:October 2,2012 EFFECTIVE:November 2,2012
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Oct. 9, 2012 Nov. 2, 2012
Jean D. Jewell Secretary
ROCKY MOUNTAIN
POWER 7 A DIVISION OF PACIFICORP
I.P.U.C. No. 1 First Revision of Sheet No. 70.2
Canceling Original Sheet No. 70.2
ELECTRIC SERVICE SCHEDULE NO. 70 - CONTINUED
RENEWABLE ENERGY: (continued)
low emissions biomass based on digester methane gas from landfills, sewage treatment
plants or animal waste and biomass energy based on solid organic fuels from wood, forest or
field residues or dedicated crops that do not include wood pieces that have been treated with
chemical preservatives such as creosote, pentachlorophenol or copper chrome arsenic.
Renewable Energy Credits (also known as Tradable Renewable Energy Credits, Renewable Energy
Certificates, Green Tags or Carbon Credits) represent all of the regional and global environmental and
emissions benefits associated with one unit of output from a qualifying renewable electricity generating
resource. In some markets, the credits are certified by an independent third party and include a serial number
for tracking purposes.
Offering must consist of 100% new Renewable Energy.
New Renewable Energy is (1) placed in operation (generating electricity) on or after January 28,
2000; (2) repowered on or after January 28, 2000 such that 80% of the fair market value of the project
derives from new generation equipment installed as part of the repowering, or (3) a separable improvement
to or enhancement of an operating existing facility that was first placed in operation prior to January 28,
2000, such that the proposed incremental generation is contractually available for sale and metered
separately than existing generation at the facility. Any enhancement of a fuel source that increases
generation at an existing facility, without the construction of a new or repowered, separately metered
generating unit, is not eligible to participate.
Preference will be given to resources within Pacific Power & Light Company and Rocky Mountain
Power service territories.
Renewable Energy purchases made to match Customer Block purchases are in addition to
investments associated with the Company's Integrated Resource Plan, and are not considered for purposes of
any Renewable Portfolio Standard requirements. Renewable Energy generated in response to any federal or
state statutory requirement to construct or contract for the Renewable Energy is not eligible.
(Continued)
Submitted Under Advice Letter No. 07-04
ISSUED: March 26,2007 EFFECTIVE: May 1,2007
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
April 23, 2007 May 1, 2007
Jean D. Jewell Secretary
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
April 6, 2009 April 12, 2009
Jean D. Jewell Secretary
ROCKY MOUNTAIN
POWER 7 A DIVISION OF PAClFlCORP
I.P.U.C. No. 1 Original Sheet No. 70.4
ELECTRIC SERVICE SCHEDULE NO. 70 - CONTINUED
SPECIAL CONDITIONS: (continued)
4. To ensure that all costs and benefits of this program are isolated to the participants
of this program, all funds collected under this program will be separately identified
and tracked. On the effective date of this Schedule, the Company will establish a
regulatory liability for all funds collected and will debit the regulatory liability as
funds are spent. The Company will endeavor to match spending to collection within
each calendar year.
ELECTRIC SERVICE REGULATIONS: Service under this Schedule will be in
accordance with the terms of the Electric Service Agreement between the Customer and the
Company. The Electric Service Regulations of the Company on file with and approved by the
Idaho Public Utilities Commission, including future applicable amendments, will be considered as
forming a part of and incorporated in said Agreement.
Submitted Under Advice Letter No. 07-04
ISSUED: March 26,2007 EFFECTIVE: May 1,2007
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
April 23, 2007 May 1, 2007
Jean D. Jewell Secretary
ROCKY MOUNTAIN
POWER
A DIVISION OF PACIFICORP
I.P.V.C.No.1 Third Revision of Sheet No.73.1
Canceling Second Revision of Sheet No.73.1
ROCKY MOUNTAIN POWER
ELECTRIC SERVICE SCHEDULE NO.73
STATE OF IDAHO
Renewable Energy
Rider -Optional
Bulk Purchase Option
AVAILABILITY:In all territory served by the Company in the state of Idaho.
APPLICATION:To Customers receiving service under The Company's non-residential
Electric Service Schedules.
ADMINISTRATION:Funds received from Customers under this Schedule will cover
program costs and match Renewable Energy purchases to Block purchases.Funds not spent after
covering program costs and matching Renewable Energy purchases to Block purchases may be used
to fund Qualifying Initiatives as defined below.
BLOCK:1 Block equals 100 kWh of Renewable Energy.This program requires a
minimum purchase of 121.2 megawatt-hours (121,200 kWh or 1,212 Blocks)per year.For the
purpose of qualifying for this Schedule,Customers with multiple sites can sum their Block
purchases across all Pacific Power &Light Company and Rocky Mountain Power service territories
to meet the minimum purchase requirement.
CHARGE PER BLOCK:
Plus
$0.70 per month per 100 kWh block
$1,500.00 per year fixed charge
For Purchase commitments over two years in length or large purchases over 75,000 MWh
per year,individually negotiated arrangements may be available,pursuant to the execution of a
written contract.
CHARGE:The Charge can be billed either monthly,twice yearly or annually and shall be
the number of Blocks the Customer has agreed to purchase multiplied by the Charge per Block,plus
the $1,500 yearly fixed charge divided between the customer's billing choice (monthly,twice yearly
or annually)and added to the Customer's standard bill.The Charge is in addition to all other
charges contained in Customer's applicable tariff schedule.This rider's Charge shall be applied to
the Customer's billing regardless of actual energy consumption.
(continued)
Submitted Under Advice Letter No.12-02
FILED:October 2,2012 EFFECTIVE:November 2,2012
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Oct. 9, 2012 Nov. 2, 2012
Jean D. Jewell Secretary
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Feb. 09, 2010 Feb. 12, 2010
Jean D. Jewell Secretary
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Aug. 9, 2007 Aug. 27, 2007
Jean D. Jewell Secretary
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
April 6, 2009 April 12, 2009
Jean D. Jewell Secretary
ROCKY MOUNTAINPOWER
A DIVISION OF PACIFICORP
Ninth Revision of Sheet No.94.1
f.P.U.C.No.1 Canceling Eighth Revision of Sheet No.94.1
ROCKY MOUNTAIN POWER
ELECTRIC SERVICE SCHEDULE NO.94
STATE OF IDAHO
Energy Cost Adjustment
AVAILABILITY:At any point on the Company's interconnected system.
APPLICATION:This Schedule shall be applicable to all retail tariff Customers taking service under
the Company's electric service schedules.
ENERGY COST ADJUSTMENT:The Energy Cost Adjustment is calculated to collect the
accumulated difference between total Company Base Net Power Cost and total Company Actual Net Power Cost
calculated on a cents per kWh basis.
MONTHLY BILL:In addition to the Monthly Charges contained in the Customer's applicable
schedule,all monthly bills shall have applied the following cents per kilowatt-hourrate by delivery voltage.
Delivery Voltage
Secondary Primary Transmission
Schedule 1 0.316¢per kWh
Schedule 6 0.316¢per kWh 0.302¢per kWh
Schedule 6A 0.316¢per kWh 0.302¢per kWh
Schedule 7 0.316¢per kWh
Schedule 7A 0.316¢per kWh
Schedule 9 0.292¢per kWh
Schedule 10 0.316¢per kWh
Schedule 11 0.316¢per kWh
Schedule 12 0.316¢per kWh
Schedule 19 0.316¢per kWh
Schedule 23 0.316¢per kWh 0.302¢per kWh
Schedule 23A 0.316¢per kWh 0.302¢per kWh
Schedule 24 0.316¢per kWh 0.302¢per kWh
Schedule 35 0.316¢per kWh 0.302¢per kWh
Schedule 35A 0.316¢per kWh 0.302¢per kWh
Schedule 36 0.316¢per kWh
Schedule 400 0.292¢per kWh
Schedule 401 0.292¢per kWh
Submitted Under Case No.PAC-E-19-04
ISSUED:April 3,2019 EFFECTIVE:June 1,2019
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
May 31, 2019 June 1, 2019
Per O.N. 34352
Diane M. Hanian Secretary
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Aug. 28, 2006 Sept. 15, 2006
Jean D. Jewell Secretary
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Aug. 28, 2006 Sept. 15, 2006
Jean D. Jewell Secretary
First Revision of Sheet No. 135.1
I.P.U.C. No. 1 Canceling Original Sheet No. 135.1
Submitted Under Case No. PAC-E-16-07
FILED: February 29, 2016 EFFECTIVE: May 1, 2016
ROCKY MOUNTAIN POWER
ELECTRIC SERVICE SCHEDULE NO. 135
STATE OF IDAHO
______________
Net Metering Service
______________
AVAILABILITY: At any point on the Company's interconnected system.
APPLICATION: On a first-come, first-served basis to any customer that owns and operates an
Eligible Generating Plant that is located on the Customer’s premises, on the Customer’s side of the Point of
Delivery, is interconnected and operates in parallel with the Company’s existing transmission and
distribution facilities and is intended primarily to offset part or all of the Customer’s own electrical
requirements.
DEFINITIONS:
Net Metering: The difference between the electricity supplied by the Company and the electricity
generated by an eligible Customer and fed back to the electric grid over the applicable billing period.
Eligible Generating Plant: A facility that uses energy derived from the sun, wind, water, biomass
or fuel cell technology to generate electricity. An Eligible Generating Plant may not have a generating
capacity of more than twenty-five (25) kilowatts for customers taking service on Schedules 1, 36, 23 or 23A
or one hundred (100) kilowatts for all other customers. To qualify, a Customer must maintain its retail
electric service account for the loads served at the Point of Delivery adjacent to the Generation
Interconnection Point as active and in good standing.
Generation Interconnection Point: The point where the conductors installed to allow receipt of
Customer’s generation connect to the Company’s facilities adjacent to the Customer’s Point of Delivery.
MONTHLY BILL: The Electric Service Charge shall be computed in accordance with the charges
for the Monthly Bill in the applicable standard service tariff subject to the following Special Conditions.
(continued)
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
May 9, 2016 May 1, 2016
Per O.N. 33511
Jean D. Jewell Secretary
I.P.U.C. No. 1 First Revision Sheet No. 135.2
Submitted Under Advice Letter No. 16-05
FILED: June 23, 2016 EFFECTIVE: July 31, 2016
ELECTRIC SERVICE SCHEDULE NO. 135 - Continued
SPECIAL CONDITIONS:
1. If the energy supplied by the Company exceeds the energy generated by the Customer and delivered to
the Company, the Customer shall be billed for the appropriate Power and other non-energy charges and
the prices specified in the Energy Rate section of the Monthly Billing of the applicable standard service
tariff shall be applied to the net positive balance owed to the Company.
2. If the energy generated by the Customer and delivered to the Company exceeds the energy supplied by
the Company, the Customer shall be billed for the appropriate Power and other non-energy charges and:
a. Customers taking retail service under Schedules 1, 36, 23 or 23A shall be financially credited for
such net energy at the Customer’s standard service schedule retail rate.
b. Customers taking retail service under all other Schedules shall be financially credited for such net
energy at the Net Metering Rate Credit specified in Special Condition #3.
3. Net Metering Rate Credit equals 85 percent of the monthly weighted average of the daily on-peak and
off-peak Mid-Columbia Intercontinental Exchange Electricity Price Index (Mid-C ICE Index) prices for
non-firm energy. This rate is calculated based upon the previous calendar month’s data. If the Mid-C
ICE Index prices are not reported for a particular day or days, the average of the immediately preceding
and following reporting periods or days will be used.
4. Net energy and the Net Metering Rate Credit for Customers taking service under any Time-of-Day
Schedule will be calculated separately for on-peak and off-peak usage.
5. The Customer shall execute an interconnection agreement with the Company prior to interconnection of
the Eligible Generating Plant with the Company's system. The Customer shall provide the
interconnection on Customer’s side of the meter. The Customer is responsible for all costs associated
with the Eligible Generating Plant and interconnection facilities, including additional metering
necessary for service under this schedule. At Customer’s expense, the Company shall make reasonable
modifications to the Company’s system necessary to accommodate the Customer’s facility. The
payment for such modifications is due in advance of construction. The Customer shall provide at the
Customer’s expense all equipment that is necessary to meet applicable local, state and national
standards regarding electrical and fire safety, power quality, and interconnection requirements
established by the National Electrical Code, the Institute of Electrical and Electronics Engineers,
American National Standards Institute, and Underwriters Laboratories.
(continued)
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
July 18, 2016 July 31, 2016
Jean D. Jewell Secretary
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Aug. 28, 2006 Sept. 15, 2006
Jean D. Jewell Secretary
‘ROCKY MOUNTAIN
POWER
A OVISON OF PACFICOAP
I.P.U.C.No.I Original Sheet No.140.1
ROCKY MOUNTAIN POWER
ELECTRIC SERVICE SCHEDULE NO.140
STATE OF IDAHO
Non-Residential Energy Efficiency
PURPOSE:Service under this Schedule is intended to maximize the efficient utilization of
the electricity requirements of new and existing loads in Non-residential Facilities through the
installation of Energy Efficiency Measures and energy management protocols.Service under this
Schedule is subject to funding availability.
APPLICABLE:To service under the Company’s General Service Schedules 6,6A,7,7A,9,
10,12,19,23.23A,24,35 and 35A in all territory served by the Company in the State of Idaho.This
Schedule is applicable to new and existing Non-residential Facilities and dairy barns served under the
Company’s residential rate schedules.
CUSTOMER PARTICIPATION:Customer participation is voluntary and is initiated by
following the participation procedures on the Idaho energy efficiency program section of the
Company website,and available to customers without online access upon request.The Company
shall have the right to qualify participants,at its discretion,based on criteria the Company considers
necessary to ensure the effective operation of the measures and utility system.Criteria may include.
but will not be limited to cost effectiveness.
DESCRIPTION:Ongoing program to provide incentives for a variety of equipment and
operational improvements intended for and located in Non-residential Facilities.Periodic program
changes will be made to encourage customer participation in the program and to insure or enhance
program cost-effectiveness as defined by the Company.
QUALIFYING MEASURE:Measures which when installed in an eligible facility result in
verifiable electric energy efficiency improvement compared to existing equipment or baseline
equipment as defined by the Company.The baseline will be determined with reference to existing
equipment,applicable state or federal energy codes,industry standard practice and other relevant
factors.
QUALIFYING ENERGY MANAGEMENT:
Operational improvements which when implemented in an eligible facility result in verifiable electric
energy savings compared to standard operations as determined by the Company.
(Continued)
Submitted Under Case No.PAC-E-14-08
ISSUED:November 18,2014 EFFECTIVE:November 1,2014
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Dec. 1, 2014 Nov. 13, 2014
Per O.N. 33178
Jean D. Jewell Secretary
wROCKY MOUNTAIN
‘POWER
A DIVISION OF PACFCORP
LP.U.C.No.1 Original Sheet No.140.2
ELECTRICAL SERVICE SCHEDULE NO.140 (Continued)
PROVISIONS OF SERVICE:
(I)Qualifying equipment or services,incentive amounts and other terms and conditions will
be listed on the Idaho energy efficiency program section of the Company website.and
are available to customers without online access upon request.Program changes may be
made by the Company with at least 45 days advanced notice.Such changes will be
prominently displayed on the Idaho energy efficiency program section of the Company
website and include a minimum 45 days for processing prior offers.
(2)Company may elect to offer energy efficiency measure (“EEM”)incentives through
different channels and at different points in the sales process other than individual
Energy Efficiency Incentive Offer Letter(s)prior to EEM purchase.The differences will
depend on EEM and will be consistent for all EEMs of similar type.
(3)Incentives may be offered year-round or for selected time periods.
(4)Equipment or services receiving an incentive under this program are not eligible for
incentives under other Company programs.
(5)Company will employ a variety of quality assurance techniques during the delivery of
the program.They will differ by measure and may include pre-and post-installation
inspections,phone surveys,and confirmation of Owner/Customer and equipment
eligibility.
(6)Company may verify or evaluate the energy savings of installed measures.This
verification may include a telephone survey,site visit,review of facility operation
characteristics,and pre-and post-installation of monitoring equipment as necessary to
quantify actual energy savings.
(7)Energy Project Manager co-funding is available according to the terms posted on the
Idaho energy efficiency program section of the Company website.
(8)Incentives will not be made available for fuel switching by Owner/Customer.
MINIMUM EQUIPMENT EFFICIENCY:
Retrofit energy efficiency projects must meet minimum equipment efficiency levels and
equipment eligibility requirements of qualifying equipment that are listed on the Idaho
energy efficiency program section of the Company website.
(Continued)
Submitted Under Case No.PAC-E-14-08
ISSUED:November 18,2014 EFFECTIVE:November .1,2014
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Dec. 1, 2014 Nov. 13, 2014
Per O.N. 33178
Jean D. Jewell Secretary
ROCKY MOUNTAIN
POWER
A DIVISION OF PACFICORP
LP.U.C.No.1 Original Sheet No.140.3
ELECTRICAL SERVICE SCHEDULE NO.140 (Continued)
ELECTRIC SERVICE REGULATIONS:Service under this Schedule will be in
accordance with the terms of the Electric Service Agreement between the Customer and the
Company.The Electric Service Regulations of the Company on file with and approved by
the Idaho Public Utilities Commission,including future applicable amendments,will be
considered as forming a part of and incorporated in said Agreement.
Submitted Under Case No.PAC-E-14-08
ISSUED:November 18,2014 EFFECTIVE:November2’,2014
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Dec. 1, 2014 Nov. 13, 2014
Per O.N. 33178
Jean D. Jewell Secretary
Sixth Revision of Sheet No. 191
I.P.U.C. No. 1 Canceling Fifth Revision of Sheet No. 191
Submitted Under Case No. PAC-E-16-02
ISSUED: January 19, 2016 EFFECTIVE: April 1, 2016
ROCKY MOUNTAIN POWER
ELECTRIC SERVICE SCHEDULE NO. 191
STATE OF IDAHO
______________
Customer Efficiency Services Rate Adjustment
______________
PURPOSE: The Customer Efficiency Services Rate Adjustment is designed to recover the costs
incurred by the Company associated with Commission-approved demand-side management expenditures.
APPLICATION: This Schedule shall be applicable to all retail tariff Customers taking service
under the Company’s electric service schedules.
MONTHLY BILL: In addition to the Monthly Charges contained in the Customer's applicable
schedule, all monthly bills shall have the following percentage increases applied prior to the application of
electric service Schedule 34.
Schedule 1 2.70%
Schedule 6 2.70%
Schedule 6A 2.70%
Schedule 7 2.70%
Schedule 7A 2.70%
Schedule 9 2.70%
Schedule 10 2.70%
Schedule 11 2.70%
Schedule 12 – Street Lighting 2.70%
Schedule 12 – Traffic Signal 2.70%
Schedule 19 2.70%
Schedule 23 2.70%
Schedule 23A 2.70%
Schedule 24 2.70%
Schedule 35 2.70%
Schedule 35A 2.70%
Schedule 36 2.70%
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
March 31, 2016 April 1, 2016
Per O.N. 33491
Jean D. Jewell Secretary
First Revision of Sheet No. 197.1
I.P.U.C. No. 1 Canceling Original Sheet No. 197.1
ROCKY MOUNTAIN POWER
ELECTRIC SERVICE SCHEDULE NO. 197
STATE OF IDAHO
______________
Federal Tax Act Adjustment
______________
APPLICATION: This Schedule shall be applicable to all retail tariff Customers taking service under
the Company’s electric service schedules.
MONTHLY BILL: In addition to the Monthly Charges contained in the Customer's applicable
schedule, all monthly bills shall have applied the following cents per kilowatt-hour rate.
Submitted Under Case No. GNR-U-18-01
ISSUED: March 5, 2019 EFFECTIVE: June 1, 2019
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
May 3, 2019 June 1, 2019
Per O.N. 34331
Diane M. Hanian Secretary
First Revision of Sheet No. 300.1
I.P.U.C. No. 1 Canceling Original Sheet No. 300.1
Submitted Under Advice No. 15-01
ISSUED: April 23, 2015 EFFECTIVE: May 18, 2015
ROCKY MOUNTAIN POWER
ELECTRIC SERVICE SCHEDULE NO. 300
STATE OF IDAHO
_____________
Regulation Charges
______________
AVAILABILITY: In all service territory served by the Company in the State of Idaho.
APPLICATION: For all customers utilizing the services of the Company as defined and described
in the Electric Service Regulations.
SERVICE CHARGES:
Sheet No. Description Charge
3R.1 Service Connection Charge:
Normal Office Hours No Charge
Monday through Friday except holidays
4:00 P.M. to 7:00 P.M. $50.00
Weekends and holidays*
8:00 A.M. to 4:00 P.M. $50.00 *Charge assessed if connection is requested and completed on the following holidays:
7R.1 Meter Test for Accuracy
Once in twelve months No charge
Two or more times in twelve months Actual Cost
7R.2 Fee paid to mobile home operators
who sub-meter tenants $1.15 per month per occupied space
8R.1 Late Payment Charge: 1% of delinquent balance per month
8R.2 Returned Check Charge: $20.00
(continued)
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
May 11, 2015 May 18, 2015
Jean D. Jewell Secretary
I.P.U.C. No. 1 Fifth Revision of Sheet No. 300.2
Canceling Fourth Revision of Sheet No. 300.2
Submitted Under Advice No. 15-01
ISSUED: April 23, 2015 EFFECTIVE: May 18, 2015
ELECTRIC SERVICE SCHEDULE NO. 300 - Continued
Sheet No. Description Charge
9R.2 Security Deposit for New Service:
Residential and Small Commercial Up to one sixth of estimated annual
billings.
Industrial and Large Commercial Up to two months peak billings.
10R.8 Reconnection Charges:
Monday through Friday except holidays.
8:00 A.M. to 4:00 P.M. $25.00
4:00 P.M. to 7:00 P.M. $50.00
Weekends and holidays*
8:00 A.M. to 4:00 P.M. $50.00
*Charge assessed if reconnection is requested and completed on the following holidays:
10R.8 Tampering Unauthorized Reconnection Charge: $75.00
10R.8 Field Visit Charge: $20.00
11R.1 Taxes
Type of Amount of Date Ordinance
Municipality Tax or Fee Ordinance No. Tax or Fee Adopted
City of Arco Franchise No. 2007-B 3.0% July 23, 2007
City of Ammon Franchise No. 501 3.0% May 19, 2011
City of Bloomington Franchise No. 2012-01 10.0% May 10, 2012
City of Dubois Franchise No. 268 10.0% March 7, 2012
City of Firth Franchise No. 159 1.0% March 14, 2000
City of Franklin Franchise No. 2004-811 3.0% September 23, 2004
City of Iona Franchise No. 40 3.0% June 22, 1989
City of Lewisville Franchise No. 2011-2 2.0% September 14, 2011
City of McCammon Franchise No. 462 3.0% September 7, 2011
City of Mud Lake Franchise No. 60904 2.0% June 9, 2004
City of Paris Franchise No. 338 3.0% November 2, 1998
City of Preston Franchise No. 2005-4 3.0% August 8, 2005
(Continued)
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
May 11, 2015 May 18, 2015
Jean D. Jewell Secretary
Second Revision of Sheet No. 300.3
I.P.U.C. No. 1 Canceling First Revision of Sheet No. 300.3
ELECTRIC SERVICE SCHEDULE NO. 300 - Continued
Type of Amount of Date Ordinance
Municipality Tax or Fee Ordinance No. Tax or Fee Adopted
City of Rexburg Franchise No. 929 6.0% December 8, 2004
City of Rigby Franchise No. 453 3.0% May 21, 1996
City of Ririe Franchise No. 104 3.0% December 31, 1990
City of St. Anthony Franchise No. 20011-10 1.0% September 22, 2011
City of Shelley Franchise No. 375 3.0% October 1, 1995
City of Spencer Franchise No. 2008-1 2.0% June 20, 2008
City of Sugar City Franchise No. 204 3.0% June 13, 1996
Sheet No. Description Charge
12R.1 Minimum Engineering Costs $200
12R.3 Facilities Charges on Facilities less than 46,000 Volts
Facilities Installed at Customer's Expense 0.60% per month
Facilities Installed at Company's Expense 1.30% per month
Facilities Charges on Facilities at and above 46,000 Volts
Facilities Installed at Customer's Expense 0.20% per month
Facilities Installed at Company's Expense 0.90% per month
12R. 13 Temporary Service Charge:
Service Drop and Meter only Single phase: $ 85.00
(Charge is for connection and Three phase: $115.00
disconnection)
12R.15 Contract Administration Allowance $250
25R.1 Customer Guarantee Credit 1:
Restoring Supply After an Outage $50.00
For each additional 12 hours $25.00
25R.2 Customer Guarantee Credit 2:
Appointments $50.00
25R.2 Customer Guarantee Credit 3:
Switching on Power $50.00
25R.2 Customer Guarantee Credit 4:
Estimates for New Supply $50.00
(continued)
Submitted Under Case No. PAC-E-16-13
ISSUED: October 3, 2016 EFFECTIVE: February 28, 2017
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Feb. 24, 2017 Feb. 28, 2017
Per O.N. 33721
Diane M. Hanian Secretary
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Aug. 28, 2006 Sept. 15, 2006
Jean D. Jewell Secretary
‘ROCKY MOUNTAIN
POWER
A OIVISON OF PAOFICORP
Eleventh Revision of Sheet No.400.1
I.P.U.C.No.1 Canceling Tenth Revision of Sheet No. 400.1
ROCKY MOUNTAIN POWER
ELECTRIC SERVICE SCHEDULE NO.400
STATE OF IDAHO
Special Contract
PURPOSE:The purpose of this Schedule is to describe generally the terms and conditions
provided by the Company pursuant to a Special Contract approved by the Idaho Public Utility
Commission,
Availaijt’
This schedule is available for firm and interruptible retail service of electric power and energy
delivered for all service required on the Customer’s premises by customers contracting for not less
than 150,000 kW as of May 18,2006 and as provided in the Electric Service Agreement between
the two parties.
Monthly Charge
Firm Poer and Ener:
Firm Energy Charge:33.908 mills per kilowatt hour
Customer Charge:$1,586.00 per Billing Period
Firm Demand Charge:$15.91 per kW
Interruptible Power and Energy:
Interruptible Energy Charge:33.908 mills per kilowatt hour
Interruptible Demand Charge:Firm Demand charge minus Interruptible Credit
Excess KVAR:$0.96/KVAR
Replacement Energy:
Adlusted Index Price multiplied by Replacement hnergy,
Tariff Rates: The Commission approved rates applicable to the Special Contract Customer,including,but
not limited to,customer charges.demand charges,energy charges.surcharges,and credits,as specified in
Idaho Electric Service Schedule No.400 or its successor.
Submitted Under Case No.PAC-E-I6l2
ISSUED:November 11.2016 EFFECTIVE:January 1,2017
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Dec. 14, 2016 Jan. 1, 2017
Per O.N. 33668
Diane M. Hanian Secretary
Eleventh Revision of Sheet No. 401.1
I.P.U.C. No. 1 Canceling Tenth Revision of Sheet No. 401.1
ROCKY MOUNTAIN POWER
ELECTRIC SERVICE SCHEDULE NO. 401
STATE OF IDAHO
______________
Special Contract
______________
PURPOSE: The purpose of this Schedule is to describe generally the terms and conditions
provided by the Company pursuant to a Special Contract approved by the Idaho Public Utility
Commission.
Availability
This schedule is available for firm retail service of electric power and energy delivered for the
operations of Itafos Conda LLC’s facilities located at Soda Springs, Idaho, as provided in the Power
Supply Agreement between the two parties.
Monthly Charge
Tariff Rates: The Commission approved rates applicable to Itafos Conda LLC, including, but not
limited to, customer charges, demand charges, energy charges, surcharges, and credits, as specified
in Idaho Electric Service Schedule No. 401 or its successor.
Submitted Under Advice No. 18-01
ISSUED: January 12, 2018 EFFECTIVE: February 1, 2018
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Jan. 29, 2018 Feb. 1, 2018
Diane M. Hanian Secretary