1. Commercial Operations Subcommittee (COPS) Update to RMS 11/3/2015

2. 2 COPS VOTING Items for TAC o LPGRR055, Extend Load Profile Model Calendar Inputs to 2030  Previously tabled at TAC  Proposed Effective Date: November 1, 2015  Reason for Revision - Administrative  Extends the Load Profile Model calendar-related inputs in Appendix E, Profile Model Spreadsheets, from 2020 to 2030  Calendar inputs include calendar variables, daylight savings variables, sunrise/sunset times and holiday variables  Corresponding changes to calendar-related inputs will be made to the Load Profile Models in the MetrixIDR load forecast and backcast system

3. 3 COPS VOTING Items for TAC o COPMGRR040, Alignment with NPRR719, Removal of Trigger and Requirement to Reduce the Distributed Generation (DG) Registration Threshold COPMGRR040 aligns language with the Nodal Protocols by removing the inclusion of the new proposed threshold for DG registration threshold as defined in Protocol Section 16.5, Registration of a Resource Entity, in the ERCOT Unregistered Distributed Generation Report, which is published on the Market Information System (MIS) Public Area. NPRR719 removes the trigger and requirement to reduce the DG registration threshold from Protocol Section 16.5, eliminating the new proposed threshold for DG registration. IA is less than $5k. COPS requests that TAC table COPMGRR040 until it can be considered with NPRR719.

4. 4 COPS VOTING Items o NPRR719, Removal of Trigger and Requirement to Reduce the Distributed Generation (DG) Registration Threshold  Removes the requirement for ERCOT to reduce the DG registration threshold when the aggregated unregistered installed capacity of DG greater than 50 kW in any one Load Zone reaches 10 MW.  COPS submitted comments revising ERCOT’s comments and ERCOT staff showed support for the revisions. COPS voted to endorse NPRR719 as amended by the 10/7/15 ERCOT comments and as revised by COPS.

5. 5 ERCOT Updates o September 2015 IT Service Metrics  Market Data Transparency IT systems met all SLA targets  Retail API SLA was not met; Find ESI ID at 97.8%; Target 99%  UNIX Production frame failure in Taylor data center and unplanned site failover, 9/20/2015 17:42 to 9/21/2015 05:00 Impacted Report publishing to the MIS, downloading of extracts and reports from MIS and EWS, MIS and ERCOT.com dashboards and displays, MOTE, NMMS, and Find ESI ID  CSWG and MISUG will review the SLA and Market Notice Distribution process and make recommendations for improvement o 3rd Quarter 2015 Settlement Stability Report  See Appendix A  Improvements are being made via NPRR720, Update to Settlement Stability Reporting Requirements

6. 6 ERCOT Updates o Concept Discussion Take advantage of AMS technology to allow AMS meter data, by working with the TDSPs (both Competitive and NOIE), to flow into ERCOT’s registered non-modeled generation aggregation process to eliminate the settlements time delay for these resources  Non-Modeled Registered Generation is <10 MW  Interconnected at 60kV or below  There is an AMS meter installed or available, METERTYPECODE = AMS  A Resource ID (RID) is established Next steps: ERCOT staff will introduce the concept to WMS, and potentially the Metering Working Group ERCOT will work on a draft NPRR (Implementation cost and timeline not known at this time)

7. 7 Communications and Settlements Working Group (CSWG) o Draft NPRR, Balancing Account Data Cuts  The CRR Balancing Account Extract provides a prototype of the CRR Balancing Account Invoice  The prior month’s balance is needed for shadow settlements, CRRBAF (m-1)  CSWG is working on a draft NPRR to include the prior month’s data cut in the Extract, to align the Nodal Protocols with the COPMG and the Balancing Account Extract User Guide

8. 8 Profiling Working Group (PWG) o Unaccounted For Energy (UFE) Allocation Factors should remain ‘As-is’  Per a survey by TDSPs, “high voltage customers and interval data recorders contribute less to UFE on an interval by interval basis”  NIDR 1.0, IDR-Distribution 0.5, and IDR-Transmission 0.1 o Load Profiling Guide (LPG) Review  Protocol Section 18, Load Profiling, edits are complete and under final review  The PWG is now reviewing other sections of the LPG

9. 9 Profiling Working Group (PWG) New Valley Weather Zone Update o ‘Virtual’ Weather Zone is still preferred for ERCOT forecasting purposes o ERCOT staff still evaluating how to distribute the Valley Weather Zone data o PWG agreed that ERCOT’s proposed solution is the best option because it includes minimum system changes and Market Participant impacts

10. 10 Market Information System User Group (MISUG) o Work on the following initiatives continues  Draft NOGRR, Proposed revisions to NOGRR084  Reports to be Automated (16)  Disclosure Data User Guides review and re-write

11. 11 Market Information System User Group (MISUG) o External Web Services (EWS) Modifications Workshop III  Held on September 29, 2015  Discussion for ways to improve ERCOT’s EWS in response to a request from the City of Garland for a more user-friendly and technologically up-to-date approach to data delivery  Survey results revealed high interest in  Subscription service  Notifications of report availability  API  Demonstration of web sockets  “Push” delivery  Appropriate for small data sets

12. 12 Market Information System User Group (MISUG) Potential EWS System Changes o Subscription service  Report availability  Historical event information o API  Supported and documented .Net and Java platforms  Support for additional platforms is possible o Enhanced UI  Support for smaller shops  Ad hoc requests Next Steps  Make other stakeholders aware and gain support  Consider options for creating a project

13. 13 Appendix A 3 rd Quarter 2015 Settlement Stability Report  8.2(c)(i) Track number of price changes (Slide 12)  8.2(c)(ii) Track number and types of disputes submitted (Slide 13)  8.2(c)(iii) Compliance with timeliness of response to disputes (Slide 14)  8.2(c)(iv) Other Settlement metrics (Slides 15-17)  8.2(c)(v) Availability of ESIID consumption data (Slides 18-23)  8.2(g) Net Allocation to Load (Slide 24)

14. 14 8.2(c)(i) Track number of price changes Notes: Reporting Period: 2015 Q3 Operating Day # of Corrected Settlement Point Prices# of Intervals Affected DASPPRTSPPRTRMPR ORDC Adders DASPPRTSPPRTRMPR ORDC Adders 6/4/2015 -12069824- 22 2 6/6/2015 -7236589212- 6/7/2015 -11457932929- 19 6/8/2015 -150751227540- 25 6/9/2015 -7236589221- 12 6/10/2015 -10854883829- 18 6/11/2015 -8442687424- 14 6/12/2015 -126631031125- 21 6/13/2015 -192961571245- 32 6/14/2015 -361829466- 66 6 6/15/2015 -186931522155- 31 7/31/2015 14--- -- - 8/5/2015 -1211963-- 33 - Notes: Price corrections for OD between 06/04/2015 and 06/23/2015 due to data error (mean and standard deviation). Approved for Resettlement at 8/11/2015 Board. The remaining corrections (6/16-19,6/23) will be executed in Q4. Price corrections for OD 7/31/2015 corrected HE1-14 for PENA_ALL Settlement Point. Price corrections for OD 8/5/2015 were due to a system issue.

15. 15 8.2(c)(ii) Track number and types of disputes submitted YEAR2015 QUARTERQ1-Q3 Row LabelsDeniedGranted Granted w/Exc. Open Total Submitted Congestion Revenue Rights-RTM 134 Energy-DAM 11 Energy-RTM 15924 Emergency Operations- RTM 97117 Ancillary Services- RTM314 Grand Total 29161450

16. 16 8.2(c)(iii) Compliance with timeliness of response to disputes YEAR2015 QUARTERQ1-Q3 Row LabelsFinalTRUE-UP Grand Total Congestion Revenue Rights- RTM100% Energy-DAM100% Energy-RTM100% Emergency Operations-RTM100% Ancillary Services- RTM100% Grand Total100%

17. 17 8.2(c)(iv) Other Settlement metrics NOTE: ERS Final settlement OD data is not represented in graph. Average percent change per year YearFinalTrue Up 20113.65%0.42% 20122.56%0.41% 20132.83%0.34% 20143.18%0.32% 20152.92%0.17%

18. 18 8.2(c)(iv) Other Settlement metrics NOTE: “Total of Charges” represents the sum of statements that are a net charge to the Market Participant (i.e., the amount due to ERCOT) 20112012201320142015 Q1-Q3 AVERAGE $7.06$4.29$5.41$6.46$4.79 MEDIAN $3.85$3.67$5.11$5.66$4.20 MIN $1.81$1.70$2.96$1.96$1.86 MAX $108.69$26.21$19.45$47.93$42.34

19. 19 8.2(c)(iv) Other Settlement metrics NOTE: “Total of Charges” represents the sum of statements that are a net charge to the Market Participant (i.e., the amount due to ERCOT) 20112012201320142015 Q1-Q3 AVERAGE $7.19$5.19$6.61$8.21$6.14 MEDIAN $4.69$4.51$5.97$7.15$5.13 MIN $2.38$2.34$2.98$3.32$2.90 MAX $173.66$63.34$40.52$123.68$33.61

20. 20 8.2(c)(v) Availability of ESIID consumption data

21. 21 8.2(c)(v) Availability of ESIID consumption data

22. 22 8.2(c)(v) Availability of ESIID consumption data

23. 23 8.2(c)(v) Availability of ESIID consumption data

24. 24 8.2(c)(v) Availability of ESIID consumption data

25. 25 8.2(c)(v) Availability of ESIID consumption data Note: Significant reductions due to an overall tightening- up of the process (Checks for quality of the data coming in and feedback being provided to the TDSPs) Result: Less than 500 out of 7M ESI IDs being estimated

26. 26 8.2(g) Net Allocation to Load

27. 27 The next COPS meeting is scheduled for December 9, 2015. Questions?