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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.