HomeMy WebLinkAbout20230124Attachment 9 to Bayer.pdf OREGON
SCHEDULE 106
DEMAND RESPONSE PROGRAMS Page 1
P.U.C. OR No. 36
Original Sheet No. 106-1
Issued March 28, 2022 Effective for service on and after May 06, 2022
Matthew McVee, Vice President, Regulatory Policy and Operations Advice No. 22-004
AVAILABLE:
In all territory served by Company in the State of Oregon.
APPLICABLE:
All Customers served by the Company in the State of Oregon taking service under the Company’s Delivery
Service Schedules listed on Schedule 291 – System Benefits Charge are eligible to participate in demand
response programs subject to criteria listed on the program section of the Company website.
PURPOSE:
To manage electric loads through one or more Company-dispatched demand response control system(s).
PROGRAM DESCRIPTIONS:
One or more detailed program descriptions can be found on the demand response section of the
Company’s website (https://www.pacificpower.net/savings-energy-choices.html). Each program will have
separate area on the website.
CUSTOMER PARTICIPATION:
Customer participation in each program is voluntary and is initiated by following the participation
procedures listed on the program website.
PROGRAM ADMINISTRATOR:
Qualified person or entity hired by the Company to administer one or more demand response Program(s).
PROVISIONS OF SERVICE:
1. Incentive amounts, participation requirements and procedures will be listed on the demand
response website.
2. Incentive delivery may vary by program and may include cash payments and/or bill credits.
3. Incentives may be offered year-round or for selected time periods.
4. Incentive amounts, participation requirements, and procedures may be changed to enhance
program cost effectiveness, improve participation, reflect quality assurance findings or market
information.
5. All changes will occur with a minimum of 45-day notice and be prominently displayed as a change
on the demand response section of the Company’s website.
6. Company and/or Program Administrator will employ a variety of quality assurance techniques
during the delivery of the program. They may differ by program and may include, but are not limited
to, site inspections, phone surveys, and confirmation of Customer eligibility.
7. The Company may verify or evaluate the demand response impacts at Customer sites. Verification
or evaluation may include, but are not limited to, telephone survey, site visit, billing analysis, pre-
and post-installation of monitoring equipment as necessary to quantify demand response impacts.
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 Commission, including future applicable amendments, will be considered as forming a part of and
incorporated in said Agreement.
First Revision of Sheet No. 114.1
P.S.C.U. No. 51 Canceling Original Sheet No. 114.1
(continued)
Issued by authority of Report and Order of the Public Service Commission of Utah in Advice No. 22-035-T09
FILED: June 6, 2022 EFFECTIVE: July 6, 2022
ROCKY MOUNTAIN POWER
ELECTRIC SERVICE SCHEDULE NO. 114
STATE OF UTAH
______________
Load Management Program
______________
APPLICABLE: This tariff is applicable to eligible Customers who have premises located
in designated areas. Customers served by the Company in the state of Utah taking service under the
Company’s electric service schedules listed on Schedule 193 – DSM Cost Adjustment located within
the designated areas are eligible to participate in a Load Management Program (Program).
PURPOSE: To manage electric loads through a Company-dispatched Direct Load Control
System (System).
PROGRAM DESCRIPTION: Detailed descriptions of Program(s) can be found on the
Company website at www.wattsmart.com.
The Company shall have the right to dispatch System(s) according to the following criteria:
Load
Control
Program
Dispatch
Period
Available
Dispatch
Hours
Maximum
Dispatch
Hours
Dispatch Days Dispatch Duration
Cool
Keeper
May 1
through
September 30
2:00pm to
9:00pm
Mountain Time
100 hours per
Program Year
Monday through
Friday, excluding
holida s
Events will be limited to four
hours per day
Wattsmart
Batteries
January 1
through
December 31
12:00am to
11:59pm
Mountain Time
N/A Monday through
Sunday
Events may be held multiple
times per day up to two full
atter dut c cles
Wattsmart
Business
January 1
through
December 31
12:00am to
11:59pm
Mountain Time
65 hours per
Program Year
Monday through
Sunday
Events will be limited to four
hours per day
In the event of a system emergency, Rocky Mountain Power may, at its discretion, expand the
dispatch criteria beyond the parameters listed. Emergency events may be used to satisfy requirements
of the North American Electric Reliability Corporation (NERC) standard BAL-002-WECC-2 for
Contingency Reserve Obligation (CRO) and may be deployed when the utility is experiencing a
qualifying event as defined by the Northwest Power Pool.
First Revision of Sheet No. 114.2
P.S.C.U. No. 51 Canceling Original Sheet No. 114.2
ELECTRIC SERVICE SCHEDULE NO. 114 - Continued
Issued by authority of Report and Order of the Public Service Commission of Utah in Advice No. 22-035-T09
FILED: June 6, 2022 EFFECTIVE: July 6, 2022
CUSTOMER PARTICIPATION: Participating premises are considered Program
participants for the duration of the Program(s). Customers may cancel their participation in the
Program(s) at any time, subject to applicable terms and conditions. The Company or its Program
contractors shall have the right to qualify program participants, at their sole discretion based on criteria
the Company or Program contractors consider necessary to ensure the effective operation of the
Program(s) and utility System. Program details can be viewed on the Company’s website at
www.wattsmart.com.
Table 1 – Cool Keeper Incentives
Load Management Program Participating Equipment Maximum Incentive
“up to”
Cool Keeper Air Conditioners Level 1 $40 annuall
Air Conditioners Level 2 $80 annuall
Table 2 – Wattsmart Batteries Incentives
Load Management
Program
Participating
Equipment
Maximum Incentive “up to”
Enrollment
Incentive1
Annual Participation
Incentive During
Commitment Term2
Annual Participation
Incentive3
Wattsmart Batteries
Residential Batteries $150/kW x Annual
Commitment Ter $15/kW $50/kW
Commercial
Batteries
$150/kW x Annual
Commitment Ter $15/kW $50/kW
Custom Custom
1. Enrollment Incentives are capped at 70% of battery equipment costs and available to new battery purchases
only.
2. Annual Participation Incentives will be capped to not exceed monthly bill amounts.
3. Applicable to new batteries after the commitment term or existing batteries where the enrollment incentive and
commitment term is not applicable. Annual Participation Incentives will be capped to not exceed monthly bill
amounts.
Table 3 – Wattsmart Business Demand Response Incentives
Load Management
Program Participating Equipment Functionality Maximum incentive
“up to”
Wattsmart Business
Demand Response
Real Time Dispatch $125/kW Advanced Notice Dispatch
Real Time and Advanced Notice Dispatch $190/kW
Program contractors may provide additional consideration, at no additional cost to the Company
or its customers, to encourage enrollment in a Program. Such consideration may include but is not
limited to gift cards or other efforts used to increase Customer interest in a Program.
(continued)
P.S.C.U. No. 51 Original Sheet No. 114.3
ELECTRIC SERVICE SCHEDULE NO. 114 - Continued
Issued by authority of Report and Order of the Public Service Commission of Utah in Advice No. 22-035-T09
FILED: June 6, 2022 EFFECTIVE: July 6, 2022
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 Public Service Commission of the
State of Utah, including future applicable amendments, will be considered as forming a part of and
incorporated in said Agreement.
WN U-76
Original Sheet No. 106.1
Schedule 106
DEMAND RESPONSE PROGRAMS
(continued)
Issued: July 21, 2022 Effective: August 26, 2022
Advice No. 22-03
Issued By PacifiCorp d/b/a Pacific Power & Light Company
By: _________________________ Matthew McVee Title: Vice President, Regulation
AVAILABLE:
In all territory served by Company in the State of Washington.
APPLICABLE:
All Customers served by the Company in the State of Washington taking service under the Company’s
Delivery Service Schedules listed on Schedule 191 – System Benefits Charge are eligible to participate in
demand response programs subject to criteria listed on the program section of the Company website.
PURPOSE:
To manage electric loads through one or more Company-dispatched demand response control system(s).
PROGRAM DESCRIPTIONS:
One or more detailed program descriptions can be found on the demand response section of the
Company’s website (https://www.pacificpower.net/savings-energy-choices.html). Each program will have
separate area on the website.
CUSTOMER PARTICIPATION:
Customer participation in each program is voluntary and is initiated by following the participation procedures
listed on the program website.
PROGRAM ADMINISTRATOR:
Qualified person or entity hired by the Company to administer one or more demand response Program(s).
PROVISIONS OF SERVICE:
1. Incentive amounts, participation requirements and procedures will be listed on the demand response
website.
2. Incentive delivery may vary by program and may include cash payments and/or bill credits.
3. Incentives may be offered year-round or for selected time periods.
4. Incentive amounts, participation requirements, and procedures may be changed to enhance
program cost effectiveness, improve participation, reflect quality assurance findings or market
information.
5. All changes will occur with a minimum of 45-day notice and be prominently displayed as a change
on the demand response section of the Company’s website.
6. Company and/or Program Administrator will employ a variety of quality assurance techniques during
the delivery of the program. They may differ by program and may include, but are not limited to, site
inspections, phone surveys, and confirmation of Customer eligibility.
7. The Company may verify or evaluate the demand response impacts at Customer sites. Verification
or evaluation may include, but are not limited to, telephone survey, site visit, billing analysis, pre-
and post-installation of monitoring equipment as necessary to quantify demand response impacts.
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 Commission, including future applicable amendments, will be considered as forming a part of and
incorporated in said Agreement.