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TAC Update: NPRR Approvals, Revision Requests, and ERCOT Updates

This update covers recent NPRR approvals, revision requests, and ERCOT updates discussed in the TAC meeting on January 26, 2017. It includes information on changes to reporting requirements, credit exposure calculations, and auction offers. It also provides updates on ERCOT's reliability unit commitment reporting and forecast adequacy of the system administration fee.

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TAC Update: NPRR Approvals, Revision Requests, and ERCOT Updates

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  1. January 26, 2017TACUpdate to COPS Michelle Trenary March 8, 2017

  2. TAC and Subcommittee Leadership • Technical Advisory Committee (TAC) Chair: Adrianne Brandt, CPS Energy Vice Chair: Bob Helton, Dynegy, Inc. • Protocol Revision Subcommittee (PRS) Chair: Martha Henson, Oncor Electric Delivery Vice Chair: Diana Coleman, OPUC • Reliability and Operations Subcommittee (ROS) Chair: Alan Bern, Oncor Electric Delivery Vice Chair: Boone Staples, Tenaska Power Services • Retail Market Subcommittee (RMS) Chair: Kathy Scott, CenterPoint Energy Vice Chair: Rebecca Reed Zerwas, Reliant Energy Retail Services • Wholesale Market Subcommittee (WMS) Chair: Jeremy Carpenter, Tenaska Power Services Vice Chair: David Kee, CPS Energy 2

  3. PRS Update • NPRR794, Relocation of Unregistered Distributed Generation (DG) Reporting Requirements, Effective Date: March 1, 2017 Approved • NPRR800, Revisions to Credit Exposure Calculations to Use Electricity Futures Market Prices, URGENT, Effective Date: Upon system implementation, Priority 2017, Rank 1561 Approved • NPRR805, Clarification for Multi-Month Congestion Revenue Right (CRR) Auction Offers, Effective Date: March 1, 2017 Approved • NPRR806, Clarification for Designation of Capacity of Refund Pre-Assigned Congestion Revenue Rights (PCRRs), Effective Date: January 1, 2017Approved 3

  4. Revision Requests Previously Tabled by TAC • COPMGRR044, Alignment with NPRR794, Relocation of Unregistered Distributed Generation (DG) Reporting Requirements, Effective Date: March 1, 2017 Approved via email vote 2/23/2017 • Appeal of NOGRR149, Revision of Definition of Transmission OperatorTabled until the August TAC meeting; With monthly written updates and an in-person update in May 4

  5. ROS Update • NOGRR165, Emergency Operations Plans as Required by NERC Reliability Standards, Effective Date: February 1, 2017 Approved • PGRR052, Stability Assessment for Interconnecting Generation, Effective Date: Upon system implementation, but no earlier than August 1, 2017, Priority 2017, Rank 2000 Tabled pending consideration of NPRR809 • PGRR053, Addition of Proposed Generation Resources to the Planning Models, Effective Date: March 1, 2017 Approved 5

  6. ERCOT Update • ERCOT Revisions to “Setting the Shadow Price Caps and Power Balance Penalties in Security Constrained Economic Dispatch” Other Binding Document (OBD) Approved • Forecast Adequacy of the Budgeted System Administration Fee • The ERCOT System Administration Fee is forecast to be adequate for 2016-2019 • Under-Frequency Load Shedding (UFLS) Survey Workshop • Held 2/20/2917 to look at ways to better handle Load Resources in the survey 6

  7. ERCOT Update • Annual Reliability Unit Commitment (RUC) Reporting Requirement 7

  8. ERCOT Update 2016 RUC Statistics • Of the 1,514 instructed RUC resource-hours in 2016, 1,481 (97.8%) were for congestion and 33 (2.2%) were for capacity • There were no resource-hours of commitment for ancillary service shortages, voltage/reactive support, system inertia or for anticipation of extreme cold weather/startup failures • 478 resource-hours were successfully bought back through use of the ONOPTOUT Resource status option • 170.1 resource-hours were dispatched above the Resource’s Low Dispatchable Limit (LDL) when the Resource was not opted-out • Inconsistencies between settlement treatment and the triggering of the Real-Time Reliability Deployment Price Adder (RTRDPA) were again observed; This will be resolved with the implementation of NPRR744, RUC Trigger for the Reliability Deployment Price Adder and Alignment with RUC Settlement, later in 2017 • 17% of the instructed RUC resource-hours were settled as ONRUC, but the Resource did not telemeter ONRUC • 0.3% of the instructed RUC resource-hours were settled as ONOPTOUT, but the Resource telemetered ONRUC • The total RUC make-whole amount was $1.2 million and these payments were fully covered by capacity-short charges for all months in 2015 and 2016 8

  9. Questions? 14

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