Approval History Approval Date: 3/27/09 Effective Date: 05/01/18 BPM Owner: Dede Subakti BPM Title: Director, Operations Engineering Services Revision History Version PRR Date Description 36 Minor changes - Update Exhibit A-3 section 6.1.3.5, replaced reference to reliability inbox with CIDI, added availability assessment hours for 2019 35 1030 05/01/2018 PRR 1030 – RSI 1B and RSI 2 34 1029 11/29/2017 Revise Availability Assessment Hours for 2018 33 986 07/01/2017 Update Availability Assessment 32 973 5/08/2017 Update language around under construction units 31 951 2/06/2017 PRR 951 – Updating Acquired Resource section 30 888 10/26/2016 PRR 888 – Reliability Services 29 854 5/25/2016 As a result of appeal on PRR 854, foot-note has been removed. 28 881 12/29/2015 PRR 881 – CPM replacement (competitive solicitation process) 27 868 12/01/2015 PRR 868 Clarify ULR Submission Process and PRR 854 Local capacity counting clarification for Reliability Demand Response Resource (RDRR) and Proxy Demand Resource (PDR) resources 26 853 07/01/2015 PRR 853 – Update Exhibit A-2 25 839 04/01/2015 PRR 839 - Change the name of the application that manages resource adequacy capacity information. 24 776 02/27/2015 PRR 776 - Section 8 outage management system integration: Update Reliability Requirements BPM to support the new outage management system integration and related policy decisions regarding the standard capacity product availability calculations.
Each year by the election date for reserve sharing status set for in Exhibit A-1, SCs for LSEs electing to be a Modified Reserve Sharing LSE must provide the following programmatic resource adequacy related information to ISO: The applicable Reserve Margin for each of the year adopted by the Local Regulatory Authority (Section 40.2.3.1.) A description of the criteria for determining qualifying resource types and the Qualifying Capacity from such resources and any modifications thereto as they are implemented from time to time (Section 40.2.3.2.) Such information shall be provided to the ISO via CIDI. There is no particular template that must be used. However, the information must be complete. In addition to this annual programmatic information, an SC for a Load Serving Entity electing Modified Reserve Sharing LSE status must provide annual and monthly information. The Demand Forecast requirements for Modified Reserve Sharing LSEs are different than those for Reserve Sharing LSEs in several respects. A Modified Reserve Sharing LSE must provide the ISO annual and monthly Resource Adequacy Plans that set forth the following information: Each annual Resource Adequacy Plan must be submitted to the ISO on a schedule and in the reporting format(s) set forth in this Business Practice Manual. The annual Resource Adequacy Plan must, at a minimum, set forth the Local Capacity Area Resources, if any, procured by the Load Serving Entity as described in Tariff Section 40.3. Each monthly Resource Adequacy Plan or the same information as required to be included in the monthly Resource Adequacy Plan, plus any other information the ISO requires as identified in this Business Practice Manual, must be submitted to the ISO at least 45 days in advance of the first day of the month covered by the plan, and in accordance with the schedule and in the reporting format(s) set forth in the Business Practice Manual. The monthly Resource Adequacy Plan must identify all resources, including Local Capacity Area Resources, the Load Serving Entity will rely upon to satisfy the applicable month’s peak hour Demand of the Load Serving Entity as determined by the Demand Forecasts developed in accordance with Tariff Section 40.2.2.3 and applicable Reserve Margin. Resource Adequacy Plans must utilize the Net Qualifying Capacity requirements of Tariff Section 40.4. The Scheduling Coordinator for the Load Serving Entity may submit at any time from 45 days through 11 days in advance of the relevant month, a revision to its monthly
Unit from being available. The BPM for Rules of Conduct Administration describes the process fir the ISO to administer Sanctions. The following table provides a summary of the scheduling and bidding rules for RA Capacity. Summary of Bidding Requirements for Resources Providing RA Capacity Resource Type Bidding Requirements IFM RUC RTM ISO Inserts Required Bids Generating Units Including Pseudo Ties (other than Use-Limited Resources) Economic Bids or are to be submitted for all RA Capacity for all hours of the month the resource is physically available (ISO Tariff 40.6.1). $0/MW RUC Availability Bids are to be submitted for all RA Capacity for all hours of the month the resource is physically available (ISO Tariff 40.6.1). Economic Bids or are to be submitted for any remaining RA Capacity from resources scheduled in IFM or RUC. Economic Bids or Self-Schedules are to be submitted for all RA Capacity from Units not scheduled in IFM (ISO Tariff 40.6.2, 40.6.3). Yes (1) Dynamic, System Resources than Resources) Same bidding requirement as (ISO Tariff 40.6.1). Same bidding requirement as above (ISO Tariff 40.6.1). Same bidding requirement as above (ISO Tariff 40.6.2, 40.6.3, 40.6.5.1). Yes (1) Dynamic, System Resources Same bidding requirement as above (ISO Tariff 40.6.1). Same bidding requirement as above (ISO Tariff 40.6.1). Same bidding requirement as above (ISO Tariff 40.6.2, 40.6.3, 40.6.5.1). Yes (1) Specific
Self-Schedules are to be submitted for all RA Capacity from Units not scheduled in IFM. Distributed Energy Resources Same as resources type for grid connected resource Same as resources type for grid connected resource Same as resources type for grid connected resource Same as resource type for grid connected resource Non-generator resource Economic Bids or are to be submitted for all RA Capacity for all hours of the month the resource is physically available. $0/MW RUC Availability Bids are to be submitted for all RA Capacity for all of the month the resource is physically available. Economic Bids or are to be submitted for any remaining RA Capacity from resources scheduled in IFM or RUC. Economic Bids or Self-Schedules are to be submitted for all RA Capacity not scheduled in IFM. Yes (1) Non-generator resource (REM) Economic Bids or are to be submitted for all RA Capacity for regulation for all of the month the resource is physically available. $0/MW RUC Availability Bids are to be submitted for all RA Capacity for all hours of the month the resource is physically available. Economic Bids or are to be submitted for any remaining RA Capacity from resources scheduled in IFM or RUC. Economic Bids or Self-Schedules are to be submitted for all RA Capacity not scheduled in IFM. Yes (1) Proxy Demand Resource Economic Bids or are to be submitted for RA Capacity that the market participant expects to be available per supply plan. $0/MW RUC Availability Bids are to be submitted for all and medium start RA Capacity for all hours of the month the resource is physically available. No RUC Availability Bids required for long-start RA Capacity. Economic Bids or are to be submitted for any remaining RA Capacity from resources scheduled in IFM or RUC. Economic Bids or Self-Schedules are to be submitted for all RA Capacity from Units not scheduled in IFM. No (2) Notes in table: ISO will insert Economic Bids and RUC Availability Bids into DAM and RTM if required amounts of RA Capacity are not offered into markets. ISO will not insert bids for resources in the event that required amounts of RA capacity are not offered into the respective markets. An exception is that the ISO will Start Start
submitted Energy Bids. ISO Tariff Sections 40.10.6.1(f)(1), 40.6.3, and 40.6.2. Long Start Generating Resources (other than Use-Limited Resources) Same as Same as above. Long Start Units not committed in the Day-Ahead Market or RUC will be released from any further obligation to submit Bids for the relevant Operating Day. Scheduling Coordinators for Long Start Units are not precluded from self-committing the unit after the Market and submitting a for Wheeling-Out in the RTM, unless precluded by terms of their contracts. ISO Tariff Sections 40.10.6.1(f)(2) and 40.6.7. IFM: No RUC: Optimized at $0/MW-hour RTM: No Extremely Long-Start Resources (other than Use-Limited Resources) Same as above. Same as above. Once committed by Day Market under ELC process, it will be subject to section 40.10.6 for RTM availability. IFM: No RUC: Optimized at $0/MW-hour RTM: No Use-Limited Resources Same as above, consistent with its use-limitations. ISO Tariff Section 40.10.6.1(e) Same as consistent with its use-limitations. ISO Tariff Section 40.10.6.1(e) Consistent with its use limitations: Submit Economic Bids for Energy for the full Flexible RA Capacity MW. Where Economic Bids are required, resource must submit bids for the Trading Hours that it is capable of being IFM: No RUC: Optimized at $0/MW-hour RTM: No Schedule
Capacity Technical Study ISO Tariff Section 40.3.1, ISO Technical Study ISO, on an annual publishes a technical study that determines the minimum amount of Local Capacity Area Resources that must be available to ISO within each Local Capacity Area identified in the study. ISO collaborates with the CPUC, LRAs within the ISO Control Area, and other Market Participants as applicable to establish the parameters, assumptions, and other criteria to be utilized in the technical study. The objective of the Local Capacity Area Resources Study is to specifically identify areas within the ISO Controlled Grid that have local reliability problems and to determine the generation capacity in MW that is required to mitigate these problems. The Local Capacity Technical Study will be conducted in accordance with the schedule set forth in Exhibit A. This schedule ensures both the required collaboration in the determination of study parameters and assumptions as well as consideration by the CPUC and other Local Regulatory Authorities prior to annual procurement cycles. The ISO is responsible for maintaining the integrity of the interconnected transmission grid in a manner consistent with prevailing Applicable Reliability Criteria (ARC), primarily consisting of reliability standards established by NERC and WECC. While the ISO develops and promulgates the ACR, in consultation with its Participating Transmission Owners (“PTOs”) and other market participants, as specified in ISO Transmission Control Agreement Section 5.1.5, the collaborative Local Capacity Technical Study process also examines the appropriate application of such ACR. Moreover, the collaborative Local Capacity Technical Study process provides the CPUC and other Local Regulatory Authorities with the opportunity to address the appropriate level of service reliability to end-use customers for whom their respective resource adequacy rules apply, as well as the roles of energy efficiency, demand response, and new generation technologies in assuring resource adequacy. In this regard, the CPUC, other Local Regulatory Authorities, and other Market Participants can offer non-generation capacity options to meet the ACR. However, non-generation capacity options chosen to meet the ACR, such as automatic load shedding schemes or operating procedures implementing manual load shedding options, must be operationally feasible, as determined by the ISO as grid operator. Greater detail on the Local Capacity Technical Study Criteria, Methodology and Assumptions can be found in the latest LCR Manual at: Greater detail on the latest Local Capacity Technical Study Reports on LCR needs can be found at:
Example of CPM with Decreasing RA above Pmin Example of CPM with Decreasing RA above Pmin Pmax: of CPM NQC: Not used in CPM Pmin: RA is Pmin A: CPM Dispatch Incremental CPM Month A: CPM Dispatch Level – (Month A RA, or other Contracts) Month A CPM Days: End of Month Date – Start of CPM Date Month B: Decreasing RA above Pmin Incremental CPM Month B: same Incremental CPM as from Month A Month B CPM Days: 30 – Month A CPM Days Tariff Section 43.2.5.2.4 Change is RA, RMA or CPM Stutus Example of CPM with decreasing RA below Pmin, or Zero RA Example of CPM with decreasing RA below Pmin, or Zero RA Pmax: Limit of CPM NQC: Not used in CPM Pmin: RA is below Pmin Month A: CPM Dispatch Level: Incremental CPM Month A: CPM Dispatch Level – (Month A RA, or other Contracts) Month A CPM Days: End of Month Date – Start of CPM Date Month B: Decreasing RA below Pmin, or Zero RA
Annual Information Submittal Date Annual Resource Adequacy Plans, Programmatic Information and Supply Plans The last business day of October Monthly Information: Resource Adequacy Plans, Demand Forecasts and Supply Plans Month Submittal Date All As posted on the Reliability Requirements website. Exhibit A-3: Import Capability Posting and Submittal Dates Exhibit A-3 provides the posting and submittal dates related to the Available Import Capability Process. Only those steps of the Available Import Capability Process that have postings or submittals are shown in the exhibit. Item Posting Date Submittal Date Frequency Market Notice requesting Import Commitment Data and contact person 1st week in June Annual LSE to submit Data requested 2 weeks after previous Market Notice Annual Step 1: Posting of Maximum Import Capability on Interties 1st of July or next business day if 1st falls on a weekend Annual Step 6: Posting of Assigned and Unassigned Capability 9th of July or next business day if 9th falls on a weekend Step 7: Notification of LSE Assignment Information 9th of July or next business Annual
day if 9th falls on a weekend Step 8: Transfer of Import Capability 18th of July, or next business day if 18th falls on a weekend Annual Step 9: Request to assign Remaining Import Capability 19th of July, or next business day if 19th falls on a weekend Annual Step 10: ISO Notification of Initial Remaining Import Capability Assignments and Unassigned Capability 26th of July, or next business day if 26th falls on a weekend. The ISO will begin accepting requests for Step 11 at the date and time indicated in the market notice published after Step 10. Annual Step 11: Secondary request to assign Remaining Import Capability 1st of August, or next business day if 1st falls on a weekend. The ISO will begin accepting requests for Step 11 at the date and time indicated in the market notice published after Step 10. Annual Step 12: Posting of Assigned and Unassigned aggregate Import Capability 8th of August or next business day if 8th on a weekend. The Annual
Stakeholder Meeting Draft Study Results ISO/All 2nd Week March Propose New Operating Procedures All Late March Review and Validate New Operating Procedures and Publish Revised Study ISO Early April Stakeholder Meeting on Revised Study ISO/All 2nd Week in April Receive Comments on All 3rd Week in April Publish Study Report ISO 1st Week in May; No later than end of June Draft LSE Local Allocations LSEs (sum of next year’s TAC local resource needs / sum of current year’s TAC local resource needs) x current year LSEs local allocation for its load in that TAC Updated CEC load forecast CEC No than end of June local allocations ISO/LRA 2nd-3rd week of July Final procurement showing LSEs The last business day of October Market Notice and Report with individual and potential collective deficiencies ISO Twenty-one (21) Calendar days after the Final Procurement Showing Additional procurement showings LSEs Thirty (30) Calendar days the date the Market Notice is issued. ISO backstop (as needed) ISO As needed, following the expiration of the thirty (30) calendar day period for an LSE to show additional procurement has been made to correct an RA deficiency. Exhibit A-6: Flexible Capacity Needs Assessment Schedule Task Entity Date