and related policy decisions regarding the standard capacity product availability calculations. 23 803 02/10/2015 PRR 803: Annual standard capacity product grandfathering notification process update 22 802 01/15/2015 PRR 802: Automated Multiple Substitutions per Resource 21 787 01/01/2015 PRR 787 Use-Limited Resource Process Updates 20 786 11/14/2014 PRR 786 Flexible RA Capacity 19 743 08/01/2014 PRR 743 Annual SCP Grandfathering Notification Process 18 724 04/01/2014 PRR 724 Supporting the Resource Adequacy manual substitution policy initiative. 17 693 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 16 678 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 15 606 11/23/2012 PRR 606 Addition of Replacement Requirements for Scheduled Outages 14 555 8/9/2012 PRR 555 Replace Transmission Reliability Margin 13 554 6/1/2012 PRR 554 Remove RDRP Language as entered in PRR 458 12 525 4/9/2012 PRR 525 Procedure for Exceptional Dispatch CPM Quantity Designation 11 487 12/2/2011 PRR 487 NRS-RA Generated Bids effective January 1, 2012, PRR 488 Clarity for Substitution timeline effective December 2, 2011 10 458 9/14/2011 PRR 458 Reliability Demand Response Product (RDRP), for Reliability Demand Response Resources (RDRR) – Tariff effective 1, 2012 9 444 8/5/2011 PRR 444 Deliverability of RA Capacity on Interties PRR 447 Annual LCR Process Schedule 8 439 6/9/2011 PRR 439 Resource Transitions many
For all LSEs, Resource Adequacy Plans must meet the following standards: Annual Resource Adequacy Plans Shall be submitted by the date set forth in Exhibit A-2 for each Load Serving Entity served by the Scheduling Coordinator. Shall identify the resources that the LSE is relying upon to serve its load and meet its Tariff obligations. LSEs are permitted to include resources under construction in their annual resource adequacy plans Shall identify the flexible RA capacity resources and categories of flexible capacity that the LSE is relying upon to meet its flexible capacity needs. Must not demonstrate RA in excess of the Net Qualifying Capacity of each Resource Adequacy resource. Shall identify whether local RA capacity is Listed Local or System capacity. For deficiencies in TAC Area Resource procurement, the ISO will provide notification to the SC for the LSE. The notification will advise the SC for the LSE that it has thirty (30) days to submit a revised Resource Adequacy Plan showing Capacity Area Resources or be subject to the potential cost implications of the deficiency detailed in ISO Tariff Section 40. Based on the RA data submitted by load serving entities the ISO identifies individual and collective capacity deficiencies in the several Local Capacity Areas. A deficiency occurs when the aggregate portfolio of Resource Adequacy Resources that has been procured, including RMR resources, fails to satisfy the adopted reliability criteria in a Local Capacity Area. The ISO Tariff provides an opportunity for LSEs to cure individual or collective deficiencies before the ISO may engage in any backstop procurement. Deficient LSEs may procure additional capacity from any resource with a local attribute in their TAC Area. However, to the extent that the aggregate LSE showings do not comprise the right mix of resources that meet the Local Capacity Requirement and ISO effectiveness criteria, a deficiency may exist that would cause the ISO to procure individual and/or collective backstop capacity. Monthly Resource Adequacy Plans Shall be submitted to the ISO at least 45 days prior to the compliance month covered by the plan and in accordance with the submittal schedule for monthly Resource Adequacy Plans located on the Reliability Requirements website.
Start 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 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, 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
Start (ISO Tariff 40.6.4.3.1, 40.6.4.3.4). into the DAM. (ISO Tariff 40.6.4.3.1). 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). Participating load that is pumping load submit Economic Bids for Energy and/or a Submission to Ancillary Services in the Market for its Resource Adequacy Capacity that is certified to provide Non-Spinning Reserve Ancillary Service No RUC Availability Bids required but any such bids submitted must be $0/MW RUC Availability Bids (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). Participating load that is pumping load shall submit Economic Bids in the Real-Time Market for its Reserve Capacity that receives an Ancillary Service Award in the Market No (2) Reliability must take generation (RMT) 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). No RUC Availability Bids required but any such bids submitted must be $0/MW RUC Availability Bids (ISO Tariff 40.6.4.3.2). 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). No (2) Distributed Energy Resources (Single resource Type) 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 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 Yes (1) limitations Ahead Ahead
Winter – November 1 through March 31 Availability Assessment Hours: 4pm – 9pm (HE17 – HE21) 2018 Flexible Resource Adequacy Availability Assessment and must offer obligation hours Flexible RA Capacity Type Category Designation Required Bidding Hours Required Bidding Days January – April October – December Base Ramping Category 1 05:00am to 10:00pm (HE6-HE22) All days Peak Ramping Category 2 2:00pm to 7:00pm All days Ramping Category 3 2:00pm to 7:00pm Non-Holiday Weekdays* May – September Base Ramping Category 1 05:00am to 10:00pm (HE6-HE22) All days Peak Ramping Category 2 3:00pm to 8:00pm All days Super-Peak Ramping Category 3 3:00pm to 8:00pm Non-Holiday Weekdays* 2019 System and Local Resource Adequacy Availability Assessment Hours Analysis employed for 2019 going forward: Top 5% of load hours using average hourly load Summer – April 1 through October 31 Availability Assessment 4pm – 9pm (HE17 – HE21) Winter – November 1 through March 31 Availability Assessment Hours: 4pm – 9pm (HE17 – HE21) 2019 Flexible Resource Adequacy Availability Assessment and must offer obligation hours
The ISO will insert bids for RA capacity for which the resource did not submit bids, but will not insert bids into the day-ahead market or the real-time market for Flexible RA Capacity for which the resource did not submit bids, Table : Summary of Bidding Requirements for Flexible RA Capacity Resources Resource Type Bidding Requirements IFM RUC RTM ISO Inserts Required Bids Start or Medium Start Generating Units (other than Resources) Submit Economic Bids for Energy 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. ISO Tariff Sections 40.10.6.1(a) & 40.10.6.1(f)(1) Participation of all available flexible RA capacity resources is required. 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) All Flexible RA Capacity MW that does not have an IFM Schedule or a RUC for a given Trading Hour must submit to the RTM for that Trading hour: (a) Energy Bids for the full amount of the Flexible RA Capacity MW, including capacity for which it has submitted Ancillary Services Bids or Submissions to Self-Provide Ancillary Services; and (b) Ancillary Services Bids and Submissions to Self-Provide Ancillary Services for the full amount of the available Ancillary Resource Adequacy Capacity and for each Ancillary Service for the resource is certified, including capacity for which it has IFM: No RUC: Optimized at $0/MW-hour RTM: No
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 above. 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 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 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 IFM: No RUC: Optimized at $0/MW-hour RTM: No Schedule
N has a Pmax of 1,000 MW, and an RA obligation of 500 MW Tie ID A refers to a single Intertie The process for reporting NRS-RA resource and transmission outages at an intertie after January 1, 2012 is as follows: Case: Intertie Status: Resource Status: Bid Value: Outage: Impact: 1 Available Available 250 MW (M), 500 MW (N) None None 2a Derated Available 250 MW (M), 500 MW (N) None (* ISO knows Intertie is out) None 2b Fully Derated (Open Tie) Available ISO does not require a bid to be submitted None (* ISO knows Intertie is out) None 3 Available Out (assume Resource N is out) 250 MW (M) Resource tie ID outage (A) – submitted within OMS Unit substitution required. If it is a maintenance outage then substitution not required Outage Correction Process For events where a Scheduling Coordinator submitted a Forced Outage or an Ambient Derate Due to Temperature Outage for a resource but subsequently discovered that the correct category for reporting the outage was “Ambient Outage not due to temperature”, the ISO has an Outage Correction Process. The CIRA tool has functionality that allows an SC to submit a request to correct the reported outage category. The ISO will accept outage correction requests only within five (5) business days after the SC reported the outage in the outage management system. Outage correction requests received after
If a resource has an RA Capacity or CPM Capacity obligation that pre-existed the resource’s Exceptional Dispatch CPM Designation and, during the term of the resource’s Exceptional Dispatch CPM designation, the amount of the resource’s RA Capacity or CPM Capacity is reduced, the ISO will increase the CPM designation by the amount, if any, necessary to ensure that the sum of Exceptional Dispatch CPM designation quantity and any remaining RA Capacity is not less than PMin. If capacity that receives an Exceptional Dispatch CPM Designation becomes RA Capacity or receives a monthly CPM designation or Significant Event Designation or receives an RMR Contract as of a certain date, then the Exceptional Dispatch CPM designation shall be reduced by the amount of the new RA Capacity, CPM Significant Event designation, or RMR Contract from that date through the rest of the 30-day term. Examples of different CPM scenarios: Tariff Section 43.2.5.2.4 Change is RA, RMA or CPM Status Example of CPM with Increasing RA Example CPM with increasing monthly RA amounts Pmax: Limit of CPM NQC: Not used in CPM Pmin: RA is above Pmin Month A: CPM Dispatch Level: Total output of facility including 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: Increasing monthly RA Incremental CPM Month B: CPM Dispatch Level – (Month B RA, or other Contracts) Month B CPM Days: 30 – Month A Days Tariff Section 43.2.5.2.4 Change is RA, RMA or CPM Stutus
Incremental CPM Month B: Pmin – (Month B RA, or other Contracts) Month B CPM Days: 30 – Month A CPM Days Tariff Section 43.2.5.2.3 Subsequent Exceptional Dispatch Example of Second CPM occurring in the first month Example of Second CPM occurring in the first month Pmax: Limit of CPM NQC: Not used in CPM Pmin: RA is above Pmin Month A: CPM all the same rules apply Second CPM Month A Incremental CPM: Second CPM Dispatch Level – (Any Existing CPM, Month A RA, or other Contracts) Second CPM Month A Retroactive Days: Date Second CPM was called – First CPM Start Date Second CPM A Days: End of first CPM Date – Date Second CPM was called Month B: First CPM all the same rules apply, all three cases above establish Month B CPM Level Second CPM Month B Incremental CPM: To determine the Second CPM Dispatch Level follow the same rules as the first CPM Dispatch level – (Any Existing CPM, Month A RA, or other Contracts) Second CPM B Days: End of First CPM Date – First of Month B Tariff Section 43.2.5.2.3 Subsequent Exceptional Dispatch