Approval History Approval Date: 3/27/09 Effective Date: 3/31/09 BPM Owner: Dede Subakti BPM Owner’s Title: Director, Operations Engineering Services Revision History Version Date Description 28 12/29/2015 PRR 881 – CPM replacement (competitive solicitation process) 27 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 07/01/2015 PRR 853 – Update Exhibit A-2 25 04/01/2015 PRR 839 - Change the name of the application that manages resource adequacy capacity information. 24 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. 23 02/10/2015 PRR 803: Annual standard capacity product grandfathering notification process update 22 01/15/2015 PRR 802: Automated Multiple Substitutions per Resource 21 01/01/2015 PRR 787 Use-Limited Resource Process Updates 20 11/14/2014 PRR 786 Flexible RA Capacity 19 08/01/2014 PRR 743 Annual SCP Grandfathering Notification Process 18 04/01/2014 PRR 724 Supporting the Resource Adequacy one-for-many manual substitution policy initiative. 17 10/9/2013 PRR 693 Update Section 4 “Resource Adequacy Capacity” to accurately reflect existing business processes related to the evaluation of RA/Supply Plans and add more granular details related to implementation of the approved Replacement Requirement for Scheduled Generation Outages initiative
16 7/3/2013 PRR 678 Update Reliability Requirement BPM for NQC request form, QC timeline, Interim Deliverability, Exhibit A-3 submittal dates, Import Allocation steps, Capacity Procurement Mechanism 15 11/23/2012 PRR 606 Addition of Replacement Requirements for Scheduled Outages 14 8/9/2012 PRR 555 Replace Transmission Reliability Margin 13 6/1/2012 PRR 554 Remove RDRP Language as entered in PRR 458 12 4/9/2012 PRR 525 Procedure for Exceptional Dispatch CPM Quantity Designation 11 12/2/2011 PRR 487 NRS-RA Generated Bids effective January 1, 2012, PRR 488 Clarity for Substitution timeline effective December 2, 2011 10 9/14/2011 PRR 458 Reliability Demand Response Product (RDRP), for Reliability Demand Response Resources (RDRR) – Tariff effective April 1, 2012 9 8/5/2011 PRR 444 Deliverability of RA Capacity on Interties PRR 447 Annual LCR Process Schedule 8 6/9/2011 PRR 439 Resource Transitions 7 3/31/2011 PRR 382 Revisions for Implementation of Capacity Procurement Mechanism (CPM) PRR 424 Revisions for Risk of Retirement Capacity Procurement Mechanism (CPM) 6 12/28/2010 PRR 315 Additional text for Standard Capacity Product Phase II Enhancements 5 8/30/2010 PRR 283 Removal of the SCP calculation of non-availability charge below Pmin as required in FERC Order ER09-1064. PRR 294 Add Exhibit A-3: Import Capability Posting Step 10 4 7-28-10 PRR 222 Clarification of the conditions under which Resource Adequacy Resources may be considered for temporary or seasonal use-limited status. 3 1-1-10 PRR 89 New for Standard Capacity Product New section to describe most aspects of Standard Capacity Product. 2 11-18-09 PRR 81 Updated Exhibit A-2 Submission dates for RA Plans and Supply Plans for 2010. PRR 90 Update Supply Plan Content rules.
Deliverability is an essential element of any resource adequacy assessment. LSE compliance with resource adequacy procurement obligations will be affected by the ability of their procured supplies to serve Load under peak conditions. Therefore, an effective deliverability study is essential in resource planning so that LSEs are able to ‘count’ their resources to determine if they are satisfying the required Reserve Margins. The deliverability of Generation to the aggregate of Load measures the capability of the transmission system given the dispatch of other proximate Generation resources to deliver power output from a particular Generator to Load in the ISO Control Area during peak Demand conditions. A resource whose output is not fully deliverable will have the capacity that it may offer for resource adequacy purposes reduced. Consequently, ISO has developed a deliverability study to assess deliverability of Generation to serve Load in the ISO Control Area. This deliverability assessment of Generation to the aggregate of load is performed through both annual assessments to measure general system changes and for new Generating Facilities through the Large Generator Interconnection Procedure. ISO performs Deliverability Assessments consistent with the timeline of Generator Interconnection Procedure (GIP). Table 1 outlines the studies to be done in each GIP study cycle: Table 1: Deliverability Assessment Start End Cluster Phase I June October Cluster Phase II January July Annual Full Capacity Deliverability Option1 June August The annual full capacity deliverability option for Generating Facilities previously studied as Energy-Only Deliverability Status starts in 2012. Pursuant to Section 6.5.2 of the Generator Interconnection Procedure (GIP), Appendix Y of the ISO Tariff, ISO will conduct a Deliverability Assessment in the Phase I study to determine: Preliminary Delivery Network Upgrades required to provide the Generating Facility with Full Capacity Deliverability Status. MW of deliverable generation capacity for the group of generators that contribute to the same transmission constraints if the highest cost Delivery Network Upgrade component were removed from the preliminary Delivery Network Upgrade plan. The Interconnection Customer can choose to move forward into the Phase II study either confirming the same deliverability status as in Phase I or changing the deliverability status from
Scheduling Coordinators representing Resource Adequacy Capacity procured by Resource Sharing LSEs must make the Resource Adequacy Capacity listed in the Scheduling Coordinator’s monthly Supply Plan available to the ISO in a manner consistent with the specific availability obligations of different types of resources according to the scheduling and bidding rules described in the following sections. In addition, ISO Tariff Section 37.2.4 provides for Sanctions in the event that a Market Participant does not place or keep a Resource Adequacy Resource online in a manner consistent with a DAM or RUC commitment or Real-Time Dispatch Instruction, whether through a submitted Bid or Default Energy Bid, unless a Outage prevents the Generating 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 (other than Use-Limited 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) Dynamic, 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 Yes (1)
described in unit’s RA Capacity from Eligible Intermittent Resources is not required to be offered into the DAM. (ISO Tariff 40.6.4.3.1, 40.6.4.3.4). RA Capacity from Eligible Intermittent Resources is not required to be offered into the DAM. (ISO Tariff 40.6.4.3.1). the use-limitations described in unit’s Energy Bids or Self-Schedules are to be submitted for all RA Capacity from Units not scheduled in IFM, consistent with the described in unit’s Use-Plan (ISO Tariff 40.6.2, 40.6.3, 40.6.4.3.1). Hydro, Pumping Load, and Use-Limited Resources Economic Bids or are to be submitted for RA Capacity that the market participant expects to be available Plan (ISO Tariff 40.6.4.3.2). No RUC Availability Bids required (ISO Tariff 40.6.4.3.2). Economic Bids or are to be submitted for RA Capacity that the market participant expects to be available (ISO Tariff 40.6.4.3.2). 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 these markets. ISO will not insert bids for these resources in the event that required amounts of RA capacity are not offered into the respective markets. An exception is that the ISO will insert Economic bids into the IFM and/or RTM in the event that there is a RUC Availability Bid or RUC Schedule for a resource without a corresponding Economic Bid or Self-Schedule. limitations
Extremely Long-Start Resources (other than Use-Limited Resources) Same as above. Same as above. Once committed by Day Ahead 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 above, 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 economically dispatched. ISO Tariff Sections 40.10.6.1(e) IFM: No RUC: Optimized at $0/MW-hour RTM: No Resources For resources not flagged as regulation energy management: Submit Economic Bids for Energy (includes positive and negative generation) for the full Flexible RA Capacity MW. Submit Economic Bids for Ancillary Services that are not flagged as Contingency Only for the full Flexible RA Capacity MW certified to provide Ancillary Services. Where Economic Bids are required, resource must submit in at least the required hours for the resource’s committed Flexible RA Capacity categories. For resources flagged as regulation energy Submit Economic Bids for regulation up and ISO will optimize using $0/MW-hour RUC Availability Bids for all Flexible RA Capacity that is not reflected in an IFM Schedule in only the required hours for the resource’s committed Flexible RA Capacity categories. ISO Tariff Sections 40.10.6.1(a) & 40.10.6.1(f)(1) Must submit Bids for Regulation Up and Regulation Down from 05:00 to 22:00 seven days a week. Shall not submit Bids for Energy or other Ancillary Services. IFM: No RUC: Optimized usng RTM: No
down that are not flagged as Contingency Only for the full Flexible RA Capacity MW certified to provide Ancillary Services. Availability Requirement ISO Tariff Section 40.10.6.1(b) During the period of the applicable must-offer obligation, a Flexible RA Capacity Resource must be operationally available except for limitations specified in the Master File, legal or regulatory prohibitions or as otherwise required by this CAISO Tariff or by Good Utility Practice. Participation in RUC ISO Tariff Section 40.10.6.1(d) ISO will optimize flexible capacity participating in RUC using $0/MW-hour for all Flexible RA Capacity that is not reflected in an IFM Schedule in only the required hours for the resource’s committed Flexible RA Capacity categories. In determining the amount of capacity that will be optimized in RUC at $0/MW-hour, the ISO will assume maximum overlap of RA Capacity and Flexible RA Capacity on the given hour. For example, a resource with 100 MW of RA Capacity and 150 MW of Category 1 Flexible RA Capacity that is awarded an IFM of 100 MW in HE13 will automatically be optimized in RUC using $0/MW-hour for the additional 50 MW of Category 1 Flexible RA Capacity. Failure to Bid ISO Tariff Section 40.10.6.2 If the Scheduling Coordinator for a resource supplying Flexible RA Capacity fails to submit bids as required in ISO Tariff Section 40.10.6, the ISO will not insert Generated Bids for any Flexible RA Capacity for which the resource did not submit bids. If the SC fails to submit bids and the resource subsequently receives an Exception Dispatch instruction, the instruction shall not be an Exception Dispatch CPM designation under ISO Tariff Section 43.2.5.
Daily Availability 7 days per week, all days per month 7 days per week, all days per month All non-holiday weekdays per month Daily Start-Up Capability The resource must be able to provide the minimum of (i) two Start-Ups per day for every day of the month or sixty Start-Ups per month, or (ii) the number of Start-Ups allowed by its operational limits, including minimum up and minimum down time At least one start per day At least one start per day Other Limitations No monthly or annual limitations on number of starts or energy limits that translate to less than the daily requirements No monthly or annual limitations on number of starts or energy limits that translate to less than the daily requirements Must be capable of responding to at least 5 dispatches per month during the five-hour period of the must offer obligation Qualifying for Multiple Categories A resource that meets the qualifications of the Flexible Capacity Category for Base Ramping resources also qualifies as a Peak Ramping resource. A resource that meets the qualifications of the Flexible Capacity Category for Base Ramping resources or Peak Ramping resources also qualifies as a Super-Peak Ramping resource Use-Limited Resources Use-limited resources may be qualified as Base Ramping, Peak Ramping, or Super Peak Ramping if they meet the qualifications of that category of Flexible RA Capacity. For a complete list of the qualifications, please review ISO Tariff Sections 40.10.3.2 through 40.10.3.4. Combining Use-Limited Resources If the resource is a Use-Limited Resource that individually does not meet the requirements of being a Base Ramping Resource, it may be combined with another resource so that the combination of the two resources meet the applicable criteria. The Flexible RA Capacity amount for the combined resource must be less than or equal to the lowest of the component EFC values.
(1) month if the deficiency is in the monthly Resource Adequacy Plan. The term of the designation cannot extend into a subsequent Resource Adequacy Compliance Year. CPM Significant Events ISO Tariff Sections 43.2.4 and 43.3.5 Under ISO Tariff Section 43.2.4, the ISO has the authority to designate CPM Capacity to provide service on a prospective basis following a CPM Significant Event, to the extent necessary to maintain compliance with Reliability Criteria and taking into account the expected duration of the CPM Significant Event. An “CPM Significant Event” is defined as: A substantial event, or a combination of events, that is determined by the ISO to either result in a material difference from what was assumed in the resource adequacy program for purposes of determining the Resource Adequacy Capacity requirements, or produce a material change in system conditions or in ISO Controlled Grid operations, that causes, or threatens to cause, a failure to meet Reliability Criteria absent the recurring use of a non-Resource Adequacy Resource(s) on a prospective basis. Examples of “CPM Significant Events” include, but are not limited to, the following: Loss of a facility, for any cause, that affects its capability, including but not limited to: Loss of a local RA resource after annual LSE RA showing, Lack of RA resources causing a shortage of capacity to meet required operating reserves (accumulated total, including ongoing scheduled and forced outages) after monthly LSE RA showing, or Loss of a facility, ISO Controlled or not, that affects the deliverability of RA, Reliability Must-Run Contract (“RMR”) or other resource available to the ISO, or affects the operation of the grid; Grid study error, forecast changes, incorrect assumptions, bad data, or modeling inaccuracies, including, but not limited to: An official change in the adopted Load forecast by the CEC after it has been used in RA showings by LSEs, Error in load distribution factors, Voltage or reactive resource modeling errors or resource changes, Errors relative to deliverability of RA resources to load, or
Attachment A: Reliability Requirements Information Submittal Timelines Exhibit A-1: Summary of Resource Adequacy Information Submittal Timelines Exhibit A-1 represents a summary of the submittal dates for resource adequacy information. Item Submittal Date Frequency Deliverability Study January April July October Quarterly or as dictated by Good Utility Practice Local Capacity Process See Exhibit A-4 Annual Local Regulatory Authority submits Qualifying Capacity Criteria & Qualifying Capacity Calculation results to ISO Due June 1 Annual Net Qualifying Capacity draft list posting Second week in August Annual Effective Flexible Capacity draft list posting Second week in August Annual Scheduling Coordinator Corrections to draft NQC list Due 3 weeks after posting of draft NQC list Annual Scheduling Coordinator Corrections to Draft EFC List September 1 Annual Final NQC List Posting TBD Annual Final EFC List Posting TBD Annual SC requests changes to Final NQC List Prior to the first of the month 2 months prior to the target compliance month. Monthly ISO updates final NQC list 15th of each month Monthly