Operations Highlights

Transcription

1 Operations Highlights Description Highlights of Operations System Performance. A high-level summary of notable events and update of important operation information not otherwise covered in other Board Agenda items. Notable Events C1 Model Implementation On December 1, 25 the ISO successfully implemented a significant change to the commercial model utilized in the Market Applications, and Operations Process. The new model incorporates five major control area footprint change requests, establishes four new Metered Subsystems and accommodates a pilot program for a Participating Generators located outside the ISO Control Area. The commercial model was modified to incorporate Control Area footprint changes relating the following areas:! The transfer of the California-Oregon Transmission Project (COTP) 5 KV transmission line to the SMUD Control Area.! The transfer of the Modesto Irrigation District (MID) service territory to the SMUD Control Area! Establishes the Turlock Irrigation District (TID) service territory as an independent Control Area! Creates a new Plumas-Sierra Marble Substation intertie between the ISO and the Sierra Pacific Power Control Area.! Creation of a Pseudo Tie between the ISO and SMUD Control Areas incorporating the Calpine Sutter Generator into the ISO. The Pseudo Tie accommodates a pilot program that establishes a market connection between the ISO and SMUD Control Areas. It accommodates the Calpine s Sutter Generation facility, physically connected to the Western 23 KV system located within the SMUD Control Area, to incorporate the Participating Generator within the ISO s Control area. Therefore, allowing Calpine to schedule energy and ancillary services into the ISO s Day Ahead, Hour Ahead and Real Time markets. In addition to the commercial model modifications, the ISO also implemented the necessary application modification to establish Metered Subsystems (MSS) agreements under the ISO Tariff for Anaheim, Vernon. Anaheim and Vernon sought the benefits of the MSS Tariff provisions, which were designed to better address and accommodate Municipal utilities, many which remain vertically integrated, within the ISO Market Design. NTraweek/Operations 1 12/9/5

2 Network Applications In October, the initial rollout of the Network Applications (State Estimator, Contingency Analysis, Dispatcher Load Flow) to the Operating Floor was completed. The Network Applications are a suite of analytical tools, which use available SCADA data and mathematical models to provide visibility of near-real time grid conditions, contingency monitoring, and the ability to perform what-if analyses of the power system. Presently, the Operators are processing outages that impact network connectivity, maintaining the grid topology, and identifying and resolving anomalies between the power system model and available real time data. The rollout of the Network Applications is allowing the Operators to become familiar with the Network Applications and their function and utilization, and the processes for maintaining the functionality of the real time network model. Alhambra Market Desk October marks the successful implementation of a fully functioning Market Desk in the Alhambra Dispatch Center. Folsom transferred five Dispatchers to Alhambra to complete the staffing of the dispatch center. This effort makes the Alhambra Dispatch Center a viable secondary location to perform system dispatch functions that include generation and transmission and for the first time the ISO Markets. System Performance The System Performance chart will be suspended until June 26. The chart compared the summer system performance with the Summer Assessment 1 in 2 forecast. Operations Performance Scorecard The Operations Performance graphs briefly explain the monthly year-to-date (YTD) results for Operations Performance. This section includes: WECC Monetary Sanctions, Control Performance Standards 1 and 2, Operating Transfer Capability Violations, ISO Control Area Frequency and Generation Outage Summary. Definitions of the Performance Standards are included in Appendix A. NTraweek/Operations 2 12/9/5

3 WECC Monetary Sanctions (Figure A) The WECC Monetary Sanctions graph shows the quarterly and YTD number of violations of the WECC s Reliability Management System (RMS) criteria. It also includes letters received as a result of these violations. To date in 25, the ISO has not received RMS monetary sanctions and is on target to zero monetary sanctions for this year. 1 Dollars (Thousands) ISO Qtr Monetary Sanctions ISO YTD Monetary Sanctions Total WECC YTD Monetary Sanctions** YTD ISO % of WECC Monetary Sanctions P4: 4th Quarter '4* P1: 1st Quarter '5 P2: 2nd Quarter '5 P3: 3rd Quarter ' % 79.2% 27.9% 21.1% Figure A Chart begins with 4th Quarter 24 to allow for delay in finalization and receipt of year-end WECC sanction data, and to enable analysis of Performance goals based on a full year. ** The 3rd Quarter data represented is through September 25. October data will be presented for the 4 th Quarter. NTraweek/Operations 3 12/9/5

4 Control Performance Standards 1 & 2 (Figure B) The Control Performance Standards graph shows the number of monthly and YTD system disturbances through Control Performance Standard 1 (CPS1) and Control Performance Standard 2 (CPS). The CPS 2 Target Goal is to attain a score of at least 9% for 11 of 12 months during the calendar year. Our cumulative results are on track to meet the Stretch objective of attaining a score of at least 9% 12 of 12 months. The CPS2 WECC minimum operating criteria and ISO goal is indicated on the figure below as the CPS2 minimum requirement. The WECC minimum requirement for CPS1 is 1% as indicated on the figure. 2% 19% 18% 17% 16% 15% 14% 13% 12% 11% 1% 9% 8% Jan Feb Mar Apr May Jun July Aug Sept Oct Nov Dec '5 CPS '5 CPS '4 CSP '4 CPS CPS1 Min. Req CPS2 Min. Req 9% 9% 9% 9% 9% 9% 9% 9% 9% 9% 9% 9% Figure B NTraweek/Operations 4 12/9/5

5 Operating Transfer Capability Violations (OTC) (Figure C) The Operating Transfer Capability graph reports the number of monthly, YTD OTC Violations, and their duration. OTC violations are one category of the four-category corporate goal to meet or exceed NERC operating standards. The ISO s cumulative results for 25 are zero OTC violations, which contributes to the ISO meeting the corporate Stretch objective not to exceed three violations in combined four categories. 14 Number of Violations Jan Feb Mar Apr May Jun July Aug Sept Oct Nov Dec '5 Violations '5 YTD Violations '4 YTD Violations '4 Violations Figure C NTraweek/Operations 5 12/9/5

6 ISO Control Area Frequency (Figure D) The Control Area Frequency graph reports monthly and YTD totals of qualifying disturbances that represent the number of contingencies that meet Disturbance Control Standard (DCS) criteria. DCS violations are one category of the four category corporate goal to meet or exceed WECC and NERC operating standards. To date, the ISO has had zero DCS violations, which contributes to the ISO meeting the Stretch objective of the corporate goal. Number of Disturbances Jan Feb Mar Apr May June July Aug Sept Oct Nov Dec Inside ISO ' Outside ISO ' Inside ISO ' Outside ISO ' '5 YTD Total '4 YTD Total Figure D NTraweek/Operations 6 12/9/5

7 Generations Outage Summary (Figure E) The Outage Summary graph shows the number forced, scheduled, and cancelled generation and transmission outages. The graph also indicates the number of Restricted Maintenance Operations (RMO), which was previously referred to as No Touch Days. RMO accommodates additional transmission or other maintenance on the grid. Outage Summary 35 3 Number of Outages Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec 5 Forced Scheduled Cancelled RMO RMO Forced Scheduled Cancelled Figure E NTraweek/Operations 7 12/9/5

8 Real Time Bias (Figure F) Operations has a 25 annual goal that targets an average bias of 4% and a stretch goal of 2% or less of manual intervention. The following is the monthly average percent bias from January through October 25. The real time bias number has continued to trend downward slightly for the months of September and October. Please note: The Corporate goals differ from the Operations goal. The Corporate Target goal is 5%, while the Stretch is 1%. Real Time Bias Average % 4% Target 2% Stretch Percent Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec 25 Figure F NTraweek/Operations 8 12/9/5

9 Market Services Highlights Description Highlights of the Market Services system status, activities, and anomalies relating to Market applications and systems. It is intended that additional graphs will be added to the Market Services Highlights as deemed relevant. System Status Core Market Systems availability times are reported quarterly. The Corporate goals for system availability are: Threshold of 99.8%, Target of 99.9% and Stretch of 99.99%. Market Application Scheduling Infrastructure (SI) Scheduling Application (SA) Real Time Market Application (RTMA) Automated Dispatch System (ADS) Interchange Transaction System (BITS) OASIS (Information System) Vitria (Integration Software) % Availability Q1 % Availability Q2 % Availability Q % 99.96% 99.97% 1% 1% 99.99% 99.9% 99.92% 99.9% 99.96% 1% 99.99% 1% 1% 1% 1% 1% 1% 99.93% 1% 1% NTraweek/Operations 9 12/9/5

10 Settlements Reliability Must Run (RMR) (Figure G) The following graph shows the monthly and annual cost of Reliability Must Run resources. The graph also indicates cumulative gross costs and the 25 annual cost estimate. Dollars (Millions) Annual Cost Estimate Jan Feb Mar Apr May Jun July Aug* Sep* Oct* Nov Dec 24 Monthly Cost Gross Monthly Cost Gross Cumulative Cost Gross Cumulative Cost Gross Estimated Annual Cost** 84. Figure G *The August through October 25 figures are based on Generator estimated preliminary invoice amounts. There is a 12-day lag between preliminary and adjusted final invoices. **The 25 Annual RMR Cost Estimate is based on a forecast of both fixed and variable cost payments. NTraweek/Operations 1 12/9/5

11 Settlements Neutrality (Figure H) The graph below shows the monthly settlement neutrality amounts. July 25 estimate was high due to the addition of the Settlements Adjustment Project (Rerun for Jan 22-Jun 24). Neutrality Dollars (Millions) (1) (2) Jan Feb M ar Apr M ay Jun July Aug Sept* Oct Nov Dec 24 M onthly Amount M onthly Amount Figure H Neutrality number includes both the Neutrality Adjustment (CT-11, CT-141) & Existing Contract Charge/Adjustment (CT-121) *Amounts estimated for September 25. There is a 75-day time lag before actual Neutrality data becomes available. NTraweek/Operations 11 12/9/5

12 Operations Support Highlights Description Highlights of the operational compliance for Regulation, Ancillary Services, Rescinded Payments, and Settlement Dispute Trend. Regulation Performance Monitoring (Figure I) Operations Support monitors suppliers of Regulation to ensure that the Regulation capacity scheduled in the ISO markets is available in real-time. In July and August 25, 97 percent of scheduled Regulation was available and capable of performing. The ISO rescinded $222,572 in Regulation payments in July and $122,26 in August. The following graph compares the monthly amount of unavailable Regulation capacity (MW) for August 24 through August 25, with the 24 monthly average. The regulation non-performance increase in August was due in most part to a single Scheduling Coordinator s non-compliance. 25 Regulation Non-Compliance August 24 - August 25 Non-Compliance MW Aug-4 Sep-4 Oct-4 Nov-4 Dec-4 Jan-5 Feb-5 Mar-5 Apr-5 May-5 Jun-5 Jul-5 Aug-5 MW/Month 24 Monthly MW Average Figure I Please note: There is a 75-day time lag before actual data becomes available. NTraweek/Operations 12 12/9/5

13 No Pay Capacity (Figure J) Suppliers of Ancillary Services are monitored by the No Pay software to ensure that Ancillary Service capacity awarded in the ISO markets is available in real-time. The following graph compares the monthly totals of noncompliant Ancillary Service capacity (MW) from No Pay for twelve months with the monthly average from 24. The ISO rescinded $936,251 in Ancillary Service payments in July and $462,691 in August. The July and August increase in No-Pay was due to large capacity awards to fast ramping units that failed to comply in real time with the ramp rates bid in at the time of the capacity awards. 9 8 MW/month No Pay Capacity August 24 - August Average Monthly Non-Compliance MW Aug-4 Sep-4 Oct-4 Nov-4 Dec-4 Jan-5 Feb-5 Month Mar-5 Apr-5 May-5 Jun-5 Jul-5 Aug-5 Figure J Please note: There is a 75-day time lag before actual data becomes available. NTraweek/Operations 13 12/9/5

14 Summary of Payments Rescinded (Figure K) The following graph summarizes the settlement adjustments for August 24 through August 25 under the No Pay and the Regulation Performance Monitoring programs. The total value of rescinded payments was approximately $1,158,832 for July and $584,897 for August. $1,4, $1,2, $1,, $8, $6, $4, $2, $- Aug-4 Summary of Payments Rescinded August 24 - August 25 Sep-4 Oct-4 Nov-4 Dec-4 Jan-5 Feb-5 Mar-5 Apr-5 May-5 Jun-5 Jul-5 Regulation No Pay Capacity No Pay Energy Figure K Aug-5 Please note: There is a 75-day time lag before actual data becomes available. NTraweek/Operations 14 12/9/5

15 Dispute Trend (Figure L) The graph below shows the volume of disputes from February 1999 through October 25. It also shows the running average of disputes over a seven year time period, which incorporates a peak volume in April 22 of 217 disputes. Closed Dispute History Dispute Accepted Dispute Denied Running Average 25 Dispute Volume Decline as Mkt Prepares for 1-Min Settlements 1-Min Settlement Disputes Begin Energy Crisis Disputes Begin CERS Policy Disputes Gear up Last Month of CERS Policy Disputes Feb-99 May-99 Aug-99 Nov-99 Feb- May- Aug- Nov- Feb-1 May-1 Aug-1 Nov-1 Feb-2 PG&E Shadow Calc Starts May-2 Figure L Aug-2 Nov-2 Feb-3 May-3 Aug-3 Nov-3 Feb-4 May-4 Aug-4 Nov-4 Feb-5 May-5 Aug-5 Month Received NTraweek/Operations 15 12/9/5

16 Appendix A Definitions The following are definitions of the items and or systems covered in the Operations Performance Scorecard section of this report: Operations Performance Scorecard: WECC Monetary Sanctions (Figure A)- Measures through WECC s Reliability Management System (RMS) criteria. The RMS criteria include items such as Operating Reserve (OR), Operational Transfer Capability (OTC), Disturbance Control Standard (DCS), System Operator certification, and compliance with the WECC Unscheduled Flow Reduction Procedure. The ISO s goal is to have zero monetary sanctions per quarter. Control Performance Standards 1 & 2. (Figure B)- Control Performance Standard 1 (CPS1) is intended to provide a control area with a frequency sensitive evaluation of how well it is meeting its demand requirements. CPS1 is a statistical measure of Area Control Error (ACE) variability. Control Performance Standard 2 (CPS2) is a statistical measure of ACE magnitude. It is designed to limit a Control Area s unscheduled (or inadvertent) power flows that could result from large ACE values. Operating Transfer Capability Violations (Figure C)- OTC Violations are defined as those transmission path overloads that exceed WECC allowable time limits for stability rated (2 min.) and thermally rated (3 min.) paths. ISO Control Area Frequency (Figure D)- The ISO Control Area Frequency figures report internal and external system disturbances and include violations of the Disturbance Control Standard (DCS) resulting from ISO Control Area internal disturbances, such as loss of a large generating unit or transmission line. WECC allowable time limit for disturbance recovery is 15 minutes. Per WECC criteria, qualifying disturbances are defined as those greater than 35% of our maximum generation loss from our most severe single contingency. The California ISO s most severe single generation contingency is a nuclear unit with maximum generation output 112 MW, 35% of which is the 392 MW threshold used herein. Real Time Bias (Figure F)- The number entered manually by the ISO operator into Real Time Market application (RTMA) to adjust for the energy deviation between RTMA and the Energy Management System (EMS). NTraweek/Operations 16 12/9/5