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Nodal Program Update
Jason Iacobucci
Nodal Program Manager
Technical Advisory Committee
5 August 2010
2 Technical Advisory Committee5 August 2010
Agenda
• Program Status
• Full System Market and Reliability Test Overview
• NMMS Update
• Cut-Over Overview
• Cut-Over Certification – Outage Scheduler & CRR
• Market Readiness
• Follow-Up Discussion
3
Integrated Nodal Timeline – Go-Live December 1, 2010
Technical Advisory Committee5 August 2010
4
2010 Market Trials Timeline – Go-Live December 1, 2010
Technical Advisory Committee5 August 2010
5
2010 Cut Over Timeline – 4 month outlook
5 August 2010 Technical Advisory Committee
6
117 Days to Go-Live
Technical Advisory Committee5 August 2010
Market Trials has been running for 26 weeks Market Quality Testing and Operational Readiness
Achievements within Market Trials: • CRR
• Six monthly CRR auctions and one Balance of the Year auction have been completed and invoiced
• Real Time Markets• Real Time settlements
– Occurring daily for 15 weeks
• DAM / RUC / WRUC• DRUC has been running in conjunction with DAM for 13 weeks• DAM Settlements are being executed• Settlement and extract data has been available since Mid-May• 12 Operational scenarios were successfully run in June• WRUC has been running twice a week for 3 weeks
• Ancillary Services• Procured in every DAM for production quantities• Supplemental AS Market tested as needed
• Full System Market and Reliability Test • 8 hour test occurred on June 17th • 5 hour test occurred on July 21st
• Credit• Credit Module went into effect on May 14th
• Cut-Over• Market Readiness Seminar #5 was held on July 28 th
7
117 Days to Go-Live
Technical Advisory Committee5 August 2010
Market Trials has been running for 26 weeks Upcoming Milestones for Market Trials:
• Full System Market Reliability Tests
• 24 hour test scheduled for the week of August 2nd • Additional Full System Market and Reliability Test – Duration will be based on results of 24-Hour Tests• Week of August 30th, 168 hour Full System Market and Reliability Test• Additional Market Readiness Assessment / Market Simulation will take place, including a multiday test in
early Sept
• DAM/RUC/SASM Scenarios• Planning more operational scenarios for August• DAM will run continuously for 7 consecutive days starting on 8/9/2010 through 8/16/2010
• DRUC, WRUC, and HRUC will run 24x7 all 7 days• Reduce the number of DAMs to create more resource availability to support additional Full System Market
and Reliability Tests
• Market Changes in trials for August / September• NPRR206- Change in Credit Management Collateral calculations for Day-Ahead Market• NPRR202- Posting of ERCOT network model (redacted version for all MPs)• NPRR169- Posting Real-Time Prices after every SCED run• QSEs and TSPs begin maintaining outages for September and post Go-Live
System Cut-Over / Go-Live• Sept/Oct 2010– Network Modeling, Outage Scheduling• November 2010- Go-Live CRR Auction • November 30th DAM• December 1st – First Operating Day
8
Upcoming Dates for Go-Live Sign Off
System (Protocol)
TAC Approval Board of Directors Approval
Congestion Revenue Rights (CRR) August 5th August 17th
Outage Scheduling (OS) August 5th August 17th
Full Nodal Operations October 7th October 19th
5 August 2010
The table below outlines key approval dates for TAC and Board Signoff
Technical Advisory Committee
9
Test Activities CRRRTM DAMOSEMS COMSNMMS CMM REG REPORTS
Functional Stability
System Stability
Business Stability
Go-Live
Functional Completeness
Solution/ Data Completeness
Solution/ Data Quality
FA/SA TEST
INTEGRATION TEST
BUSINESS PROCESS TEST
PERFORMANCE & LOAD TEST
Model Load /Validation Processes
MARKET TEST
UI Performance
Improvements
Contingencies
ICCP Quality
SE Quality
DRUCDAMRTM
HRUCSASM
SCED
Model Baseline
ICCP Point Checkout
Technical Advisory Committee5 August 2010
Business Quality
Integration
1 Day Dual Entry
May Auction
Integrated Credit
Management
Phase 5:Full Functionality
Phase 5:Full
Functionality
RARF
SEM MT 2.1
MT 3.0MT 4.0 MT 5.0
NPRR 206 Integration
10
Nodal Program Risks & Issues
Technical Advisory Committee5 August 2010
Risk/Issue Impacted Milestone
Target Category Probability Severity Status
Network Model ManagementPerformance and availability issues around the NMMS.
Program July 2010
Schedule / Budget
Med High • Working closely with vendor to correct all issues
• Working through issues list with NDSWG and NATF
Market Design AssessmentRisk around the protocol traceability project and the market results as each phase of market trials becomes active.
Program August2010
Scope / Budget
Low High • Performing risk assessment associated with four identified issues for August board meeting
Operational ReadinessOperational readiness of the Nodal systems and business processes are an increasing risk at this point in the program
Program September2010
Scope / Schedule/
Budget
Med High • Organizational capability assessments and improvement recommendations are under review by executive management
• The PMO has and will continue to identify critical deficiencies and implement mitigation strategies to ensure delivery
11
Network Model Management System Update
• Improvement in stability since two patches installed on July 2nd and July 22nd – No unscheduled restarts since the July 22nd installation
• Navigation Performance:– Vendor delivered performance patch which is being tested in the
sandbox test environment– Initial results indicate navigation improvements but testing is ongoing
• The plan is to install this week if the patch continues to test well
• Validation Performance: – Programmers are assessing validation and testing potential
improvements
Technical Advisory Committee5 August 2010
Kenneth RagsdaleMarket Trials
Full System Market and Reliability Test Overview
13
5-Hour LFC Test Update
5-Hour LFC Test Update
Time Activity
0800 Hotline call was made by the ERCOT Operator announcing the 1100 start time for the test
0929 ERCOT Operators activated an OC3 for solving congestion in Zonal
1100 Hotline call what made announcing the test was starting and the VDI was issued
1119 First participating QSE confirms switch over to Nodal control
1214 Final participating QSE confirms switch over to Nodal control
1218 Hotline call what made announcing that all participating QSEs on Nodal control
1531 Hotline call what made announcing that participating QSEs were being switched back to Zonal
1535 First participating QSE confirms switch back to Zonal control
1616 Final participating QSE confirms switch back to Zonal control
5 August 2010 Technical Advisory Committee
14
5-Hour LFC Test Update
Constraints Encountered During the Test
Start Constraint Reason10:00 Roanoke Switch OC3 Loss of Roanoke Switch T1 345/138KV
autotransformer overloads West Denton - Fort Worth Substation 138KV - 108% of 218 MVA rating.
12:20 Jack County - Reno OC3 Loss of Jack County - Reno 138KV overloads Wise County - Bridgeport TU 138KV - 105% of 199 MVA rating.
5 August 2010 Technical Advisory Committee
15
5-Hour LFC Test Update
• Completion Criteria:– The rolling CPS1 one minute average score must equal or exceed 100% during
the test period. • Note that CPS1 metric will not apply to periods during testing wherein
system tuning is being performed by either ERCOT or Market Participants– HE12-73, HE13-112, HE14-103, HE15-120, HE16-103
– Zonal Commercially Significant Constraints (CSCs) and Closely Related Elements (CREs) managed below thermal limits. The Zonal CSCs were not activated during the test
– Local Congestion managed below thermal limits. Two local constraints binding during the test
– Stability limits managed below transfer limits No stability limits were activated during the test
– No NERC Disturbance Control Standard (DCS) failure if applicable Not applicable during the test
– No LFC-SCED system issues that result in termination of the test. No issues– Procedural and software fixes have been verified to address lessons learned
from previous rounds of testing There were no shift factors transfer failures during the test.
5 August 2010 Technical Advisory Committee
16
GREDP Performance Summary
• For this analysis; X=5%, Y=5, MW, and Z=10%
• Performance does not appear to have varied drastically from the 8-hour test
Percent of Non-IRR Generation Resources that Met the Protocol Criteria
All Resources 79.74%
Resources Providing Regulation 86.90%
Combined Cycle Resources 93.22%
Coal and Lignite Resources 97.50%
Diesel Resources 100.00%
Gas Steam (Non-Reheat Boiler) Resources 25.00%
Gas Steam (Reheat Boiler) Resources 72.22%
Gas Steam (Supercritical Boiler) Resources 33.33%
Hydro Resources 88.89%
Nuclear Resources 100.00%
Simple Cycle (Greater than 90 MW) Resources 100.00%
Simple Cycle (Less than 90 MW) Resources 34.04%
Percent of IRRs that Met the Protocol Criteria 33.33%
Number of IRRs that had an Interval for which
GREDP was scored9
5 August 2010 Technical Advisory Committee
Nodal Go-Live UpdateReview of Outage Scheduler and CRR Go-Live Items
Kenneth RagsdaleMarket Trials
18
Readiness Methodology
ERCOT will measure readiness by the following categories:• System Readiness – an evaluation of a particular system
needed to support identified market activities• Process Readiness – an evaluation of the Processes and
Procedures necessary to support identified market activities• People Readiness – an evaluation of ERCOT and Market
Participant capabilities to support identified market activities
ERCOT plans to review the Market Readiness Criteria at NATF and subsequently request a vote from TAC per Section 21.12.3, Notice to Market Participants of Effective Date for Nodal Protocol Provisions and Retirement of Zonal Protocol Provision
5 August 2010 Technical Advisory Committee
19
Protocol 21.12.3
21.12.3 Notice to Market Participants of Effective Date for Nodal Protocol Provisions and Retirement of Zonal Protocol Provision
No part of the nodal market design may start operation until all the Market Readiness Criteria for that part of the nodal market design have been met. Certification that all Market Readiness Criteria have been met must be made at least by each of the following: the Technical Advisory Committee (TAC), ERCOT and the ERCOT Board. Upon such certification, ERCOT shall issue two Notices alerting Market Participants to the effective date of Nodal Protocol sections and the retirement of Zonal Protocol sections, as applicable. ERCOT shall issue the first Notice no less than thirty (30) days prior to the effective date or retirement date, as applicable, and the second Notice no less than ten (10) days prior to the effective date or retirement date, as applicable. The Notice shall include:
(1) The Nodal Protocol Sections to become effective; and
(2) The Zonal Protocol Sections to be retired, if any
5 August 2010 Technical Advisory Committee
20
OS and OS UI (12 defects) as of 7-29-10
• All 12 are expected to be fixed in NPROD by 8-13-10.
• 8 of the 12 are market facing.
5 August 2010 Technical Advisory Committee
21
Outage Scheduling – Go Live
System Readiness Planned Completion
Status
Outage Scheduler released to Market Trials 2/01/10 Complete
Outages Scheduler Integrated with DAM, RUC 4/15/10 Complete
Outage Scheduler Qualification Connectivity Qualification (MP20) 4/01/10 Green
Process Readiness
Verify Outage Evaluation System Functionality (EMO3 #1) 6/23/10 Green
Outage Coordination Procedures 7/16/10 Complete
Nodal Protocol Transition Plan Updated for Outage Scheduling 7/29/10 Complete
Outage Scheduling Transition Plan Established 7/08/10 Complete
5 August 2010 Technical Advisory Committee
22
Outage Scheduling – Go Live
People Readiness Planned Completion
Status
ERCOT Staff Support of Market Trials Ongoing Green
ERCOT Staff Trained on System and Processes 09/03/10 Green
Market Participant Training Delivered 7/15/10 NMMS/OS
class added
Overall Readiness
NATF Review7/08/10,
07/29/10 Complete
ERCOT Management Signoff 8/04/10
TAC Approval 8/05/10
BOD Approval 8/17/10
30 Day Market Notice 10/01/10
10 Day Market Notice 10/21/10
5 August 2010 Technical Advisory Committee
23
Outage Scheduling
On July 8th, NATF approved a motion to recommend to TAC that the Outage Scheduling Market Readiness Criteria have been met.
ERCOT Management Sign-off in progress as of 7-29-10. It will be posted once signed.
5 August 2010 Technical Advisory Committee
24 Technical Advisory Committee5 August 2010
• Outage Scheduler with Zonal Outage Transfer
• Delete all Outages and run Zonal to Nodal Transfer Tool Friday, 8/13 (Note that 80% to 85% of the outages are transferred)
• A Market Notice will be sent out once the purge and transfer is complete
• Email MarketTrials@ERCOT.com by 8/9/10,1700 if the transfer is NOT desired
• Resource Outages will not be transferred by the Transfer tool
• The target is to make available for outage transfer validation and outage submissions Monday 8/16, 7:00 am, for the upcoming tests, optional months of October & November and for December and beyond
• Request list of Outages not transferred from MarketTrials@ERCOT.com
• Send email to Market MarketTrials@ERCOT.com confirming outages have been validated by 9/17 for all Outages December and beyond
• First production pull of OS data is scheduled for 10/2 for the first CRR Auction
• TSPs and QSEs are responsible to ensure that the outages in the Nodal Outage Scheduler are correct
• Outages previously approved in zonal will be automatically approved in Nodal
Outage Scheduler Transition Timeline
25
TAC’s Outage Scheduler Certification Approval
WHEREAS, Protocols Section 21.12.3 (Notice to Market Participants of Effective Date for Nodal Protocol Provisions and Retirement of Zonal Protocol Provisions) provides that before a “part of the nodal market design may start operation,” a vote of the Technical Advisory Committee (TAC) is required affirming that the “Market Readiness Criteria for that part of the nodal market design have been met”
WHEREAS, the Section 21.12.3 certification by TAC, Electric Reliability Council of Texas, Inc. (ERCOT) staff, and the ERCOT Board of Directors regarding the satisfaction of “Market Readiness Criteria” for a particular part of the nodal market design will result in ERCOT issuing “two Notices alerting Market Participants to the effective date of Nodal Protocol sections and the retirement of Zonal Protocol sections, as applicable”;
WHEREAS, the Protocols do not define the term “Market Readiness Criteria,” and ERCOT, in conjunction with Market Participants, has developed specific metrics and a Nodal Readiness Scorecard that are used to determine the progress of specific parts of the nodal market design in meeting the criteria necessary for implementing the Nodal Protocols and starting operations;
WHEREAS, the members of TAC recognize that there are issues that remain to be addressed regarding the implementation and operation of the Outage Scheduler before the Texas Nodal Market Implementation Date (TNMID), but that none of those issues should prevent the Outage Scheduler Go-Live on November 1, 2010, which is an integral occurrence in the progress toward meeting the TNMID on schedule;
WHEREAS, TAC has reviewed the market readiness metrics documentation underlying ERCOT staff’s recommendation regarding the Outage Scheduler part of the nodal market design, and has conducted due diligence on ERCOT staff’s conclusion that the Outage Scheduler has satisfied all of the steps necessary to make the declaration of market readiness required by Section 21.12.3, in order to authorize Outage Scheduler Go-Live on November 1, 2010;
THEREFORE be it RESOLVED, that this Resolution shall serve as the TAC certification that all Market Readiness Criteria have been met, for purposes of ERCOT Protocols Section 21.12.3, regarding Outage Scheduler Go-Live on November 1, 2010;
5 August 2010 Technical Advisory Committee
26
CRR Allocation and Auction (5 defects) [as of 7-29-10]
1. Topology Processor (TP) cannot properly consume outage information. With TP version 8 delivered in early July it was identified that the outages were not properly consumed. Working with Siemens and also working on manual work-around.
2. HUB PNODES mismatch between TP and DSV model database. Defect resolved and currently being retested.
3. Incorrect Load Zone Designation from TP. (Possible data issue. Continue to investigate with Siemens.)
4. Resource Nodes missing from output file produced by TP. (Possible data issue. Continue to investigate with Siemens.)
5. Islanding in PSSE network model. (Possible data issue. Continue to investigate with Siemens.)
5 August 2010 Technical Advisory Committee
27
CRR Allocation and Auction – Go Live
System Readiness Planned Completion
Status
CRR System released to Market Trials 2/01/10 Complete
CRR Integrated in Market Trials 5/01/10 Complete
CRR Account Holder Connectivity Qualification MP 15 (B) 9/17/10 Red**
Operation of CRR Auctions and Allocations (CRR3) Ongoing Green
Verify CRR Auction Invoices (CO8) Ongoing Green
Process Readiness
CRR Procedures 6/25/10 Complete
Nodal Protocol Transition Plan Updated for CRR 7/29/10 Complete
TCR to CRR Transition Plan (CRR4) 9/29/09 Complete
** Red due to MPs registering but not working to get qualified. (inflated denominator)
5 August 2010 Technical Advisory Committee
28
CRR Allocation and Auction – Go Live
People Readiness Planned Completion
Status
ERCOT Staff Support of Market Trials Ongoing Green
ERCOT Staff Trained on System and Processes 06/25/10 Complete
Market Participant Training Delivered 07/15/09 Complete
Overall Readiness
ERCOT Management Signoff 08/04/10
NATF Review 07/08/10, 07/29/10
TAC Approval 08/05/10
BOD Approval 08/17/10
30 Day Market Notice 09/13/10
10 Day Market Notice 10/03/10
5 August 2010 Technical Advisory Committee
29
CRR Allocation and Auction – Go Live (as of 7-29-10)
Scheduled to be reviewed again at 8-3-10 NATF meeting.
ERCOT Management Sign-off is in progress as of 7-29-10. It will be posted once signed.
5 August 2010 Technical Advisory Committee
30
TAC’s Congestion Revenue Rights Certification Approval
WHEREAS, Protocols Section 21.12.3 (Notice to Market Participants of Effective Date for Nodal Protocol Provisions and Retirement of Zonal Protocol Provisions) provides that before a “part of the nodal market design may start operation,” a vote of the Technical Advisory Committee (TAC) is required affirming that the “Market Readiness Criteria for that part of the nodal market design have been met”
WHEREAS, the Section 21.12.3 certification by TAC, Electric Reliability Council of Texas, Inc. (ERCOT) staff, and the ERCOT Board of Directors regarding the satisfaction of “Market Readiness Criteria” for a particular part of the nodal market design will result in ERCOT issuing “two Notices alerting Market Participants to the effective date of Nodal Protocol sections and the retirement of Zonal Protocol sections, as applicable”;
WHEREAS, the Protocols do not define the term “Market Readiness Criteria,” and ERCOT, in conjunction with Market Participants, has developed specific metrics and a Nodal Readiness Scorecard that are used to determine the progress of specific parts of the nodal market design in meeting the criteria necessary for implementing the Nodal Protocols and starting operations;
WHEREAS, the members of TAC recognize that there are issues that remain to be addressed regarding the implementation and operation of the Congestion Revenue Rights before the Texas Nodal Market Implementation Date (TNMID), but that none of those issues should prevent the Congestion Revenue Rights Go-Live on October 13, 2010, which is an integral occurrence in the progress toward meeting the TNMID on schedule;
WHEREAS, TAC has reviewed the market readiness metrics documentation underlying ERCOT staff’s recommendation regarding the Congestion Revenue Rights part of the nodal market design, and has conducted due diligence on ERCOT staff’s conclusion that the Congestion Revenue Rights has satisfied all of the steps necessary to make the declaration of market readiness required by Section 21.12.3, in order to authorize Congestion Revenue Rights Go-Live on October 13, 2010;
THEREFORE be it RESOLVED, that this Resolution shall serve as the TAC certification that all Market Readiness Criteria have been met, for purposes of ERCOT Protocols Section 21.12.3, regarding Congestion Revenue Rights Go-Live on October 13, 2010;
5 August 2010 Technical Advisory Committee
Brandon McElfreshReadiness & Transformation
Market Readiness
32
Reminder – Nodal Registration Cutoff – QSEs and CRRAHs
Technical Advisory Committee
• Scope• What is the cutoff date for QSEs and CRRAHs to begin registration for Nodal Go-Live (based on ERCOT
resource availability)?• Registration must begin by these dates to be qualified for Nodal Go-Live
• August 13th, 2010• QSEs with Resources with a new WAN connection *• CRRAHs (to be qualified for the 10/13 PCRR nomination and for the 11/11 December 2010 CRR Auction) *
~
• October 1st, 2010• QSE with Resources using a Nodal qualified service provider *• QSEs without Resources *• Sub-QSEs using a Nodal qualified parent QSE *
• Mechanics• Qualification will follow the Nodal production qualification process and all testing will be done in the MOTE
environment• MPs that want to begin registration past these
deadlines will be examined on a case-by-case basis• Nodal Metric MP22 will measure progress of
new entrants
* QSE Application or CRRAH Application must be submitted, which includes Credit Application
~ Doesn’t include NOIE Allocation Eligibility Form, which must be submitted by 6/30 for CRRAHs eligible for PCRRs
QSERs (new wan),CRRAHs
QSERs (existing wan),Sub-QSERs,
QSEs w/o Resources
5 August 2010
33
Next 60-days of Nodal Classes/Workshops
Course Start Date Location
Basic Training Program August 10 Calpine (Houston)
NPRR206 E-Factors Workshop August 10 Hilton Austin Airport (Austin)
ERCOT Nodal 101 August 10 ERCOT Met Center (Austin)
Basic Training Program August 10 Calpine (Houston)
Network Model/Outage Scheduler Workshop (new)
August 10 ERCOT (Taylor)
Load Serving Entity 201 August 16 Reliant Energy (Houston)
Market Settlements 301 August 17 City of Garland Fire Administration Building (Dallas)
Network Model/Outage Scheduler Workshop (new)
August 18 ERCOT (Taylor)
GCPA Retail Workshop August 19 Centerpoint (Houston)
5 August 2010
Enrollment at: http://nodal.ercot.com/training/courses/index.html
Technical Advisory Committee
34
Next 60-days of Nodal Classes/Workshops - continued
Course Start Date Location
NOIE QSE Operations August 20 City of Garland Fire Administration Building (Dallas)
Congestion Revenue Rights August 24 University of Delaware (Newark, DE)
Generation 201 August 25 University of Delaware (Newark, DE)
Congestion Revenue Rights August 31 ERCOT Met Center (Austin)
Generation 201 September 1 Hilton Austin Airport (Austin)
Economics of LMP September 13 ERCOT Met Center (Austin)
ERCOT 101 for Wind Generation September 13 Optim Energy (Dallas)
ERCOT Nodal 101 September 14 StarTex Power (Houston)
Generation 101 September 15 Hilton Austin Airport (Austin)
Basic Training Program September 20 LCRA (Austin)
Load Serving Entity 201 September 27 ERCOT Met Center (Austin)
Enrollment at: http://nodal.ercot.com/training/courses/index.html
5 August 2010 Technical Advisory Committee
35
RED/AMBER Metrics Summary
ERCOT Metrics
Market Participant Metrics
Metric NameCurrent Score
Applies to
Weight Green % Yellow % Red %Not
Scored %Primary Criteria Notes
Market Participant MetricsMP15(B) CRR Connectivity Qualification
Red CRRAHsEven
weighting94.2% 0.0% 0.0% 5.8%
Successful submission CRR transactions
66/74 CRRAHs qualified. Greater than
5% RED.
MP16 DAM Participation
Amber QSEsEven
Weighting78.6% 6.6% 12.6% 1.1%
Participation in 50% of the Day-Ahead Market
runs
143/182 QSEs w/o Resources
Metric NameCurrent Score
Applies to
Weight Green % Yellow % Red %Not
Scored %Primary Criteria Notes
ERCOT Metrics
EMO9(A) State Estimator Convergence
Amber ERCOT N/A N/A 95.44 N/A N/A
State Estimator converges 97% of runs during a monthly test
period.
95.44% Convergence for State Estimator for
the month of May.
EMO9(B) RTCA Modeling Differences
Red ERCOT N/A N/A N/A 84.33% N/A95% of load tap setting
values matched between Zonal/Nodal
84.33% Match for transformer tap settings.
1430 transformers in Nodal.
Technical Advisory Committee5 August 2010
36
Questions ?
5 August 2010 Technical Advisory Committee
37
Appendix
5 August 2010 Technical Advisory Committee
38
Nodal Program Risks & Issues: Definitions
5 August 2010
Definitions for Category, Probability and Severity of Risks & Issues:
• Category– Scope : Will require a scope change– Schedule: Will require a schedule change– Budget: Will require a budget change
• Probability– High : Probability to occur is ≥ 90%; perceived impact would require a Change
Request over the next 1-3 months– Medium: Probability to occur is between 31 – 89%; perceived impact would
require a Change Request over the next 4 -10 months– Low: Probability to occur is ≤ 30 %; not expected to require a Change Request
• Severity – High: Milestone impact, or budget impact >$250,000 – Medium: Milestone impact - but expected to be mitigated, or budget impact
between $0 - $250,000 – Low: No milestone impact, or no budget impact
Technical Advisory Committee
39
60 Day Outlook : August Market Activities
Functional Area Real-Time Market
Congestion Revenue Rights
Day-Ahead Market
Reliability Unit Commitment
Outage Scheduler
COMS/Settlements
Network Modeling
Nodal Reports
Credit
Full Integration
Targeted Activities for August 2010• August is reserved for focusing on any
issues or scenarios encountered in the first 3 months of Phase 5
• Real time submission continue• ERCOT executes August Monthly CRR
Auction• SASM executed as needed
Jan Feb Mar Apr May June July Aug
5 August 2010 Technical Advisory Committee
40
DAM/RUC/SASM Operational Scenarios
5 August 2010 Technical Advisory Committee
41
DAM/RUC/SASM Operational Scenarios
5 August 2010 Technical Advisory Committee
42
ACTIVE NODAL METRICSMetric # Metrics Name Category ERCOT QSERs QSEs TSPs CRRAHs REs
MO4 Verify SCED Execution Quality RT Green N/A N/A N/A N/A N/AMO5 Generate LMPs for 6 months RT Green N/A N/A N/A N/A N/ACRR3 (ERCOT) Operation of CRR Auctions and Allocations CRR Green N/A N/A N/A N/A N/AMO9 Generate Day-Ahead LMPs DAM Green N/A N/A N/A N/A N/AMO10 DRUC Execution DAM Green N/A N/A N/A N/A N/ACO8 Verify CRR Auction Invoices COMS Green N/A N/A N/A N/A N/AEMO9(A) State Estimator Convergence NM Amber N/A N/A N/A N/A N/AEMO9(B) RTCA Modeling Differences NM Red N/A N/A N/A N/A N/AEMO10 Anomalous/Auto-Disabled Telemeted Points NM Green N/A N/A N/A N/A N/AE1 ERCOT Internal Training READ Green N/A N/A N/A N/A N/AE9 Develop Nodal Procedures READ Green N/A N/A N/A N/A N/AMP3 Market Submissions Connectivity Qualification CONN Green Green Green N/A N/A N/AMP15B CRR Connectivity Qualification CONN Red N/A N/A N/A Red N/AMP20 Outage Scheduler Connectivity Qualification CONN Green Green N/A Green N/A N/AEMO6 Individual LFC Testing RT N/A Green N/A N/A N/A N/AMP15A Real-Time Market Daily Participation RT N/A Green N/A N/A N/A N/AEMO6 Individual LFC Testing RT N/A Green N/A N/A N/A N/ACRR3 Operation of CRR Auctions and Allocations CRR N/A N/A N/A N/A Green N/AMP16 DAM Participation DAM N/A Green Amber N/A N/A N/AMP20 Outage Scheduler Connectivity Qualification OS N/A Green N/A Green N/A N/AN2 Telemetry/ICCP System Failover NM N/A Green N/A N/A N/A N/AMP6(SE) Telemetry Compliance 3.10.7.5 NM N/A Green N/A N/A N/A N/AMP6(SCED) Telemetry Compliance 3.10.7.5 NM N/A Green N/A N/A N/A N/AMP6 (TSP) Telemetry Compliance 3.10.7.5 NM N/A N/A N/A Green N/A N/AMP14B Participation in NOMCR Trials NM N/A N/A N/A Green N/A N/AMP14C Network Model Validation NM N/A N/A N/A Green N/A N/AMP11 Resource Registration RES N/A N/A N/A N/A N/A Green
Active Nodal Metrics
Technical Advisory Committee5 August 2010
43
Metrics RoadmapPURPLE
ORANGE
Timing and Design Confirmed
Timing subject to change, design in progress
MP15A
MP16
MP20
MP3
MP6
MP11 MP14C
E9
E1
N2 EMO9(B)
CRR3
EMO6
MO4 MO5
CO1
CO2
CO3
CO4
CO5
CO6 CO7
CO8 CO9
C10
E7
E11
E12
C1-C10
EMO13
MO7
CRR4
E5
IMM1
R0
R2
R3
MP15B
MP3
N1
E3
E10
R1
MP22
EMO9(D)
MO9
MO8MO3MO10
EMO10 EMO9(C) EMO7EMO9(A)
New Metric
MP23
EMO2
EMO8
Technical Advisory Committee5 August 2010
44
CRR Metrics
Metric NameCurrent Score
Applies to
Weight Green % Yellow % Red %Not
Scored %Primary Criteria Notes
Market Participant MetricsMP15(B) CRR Connectivity Qualification
Red CRRAHsEven
weighting90.7% 0.0% 9.3% 0.0%
Successful submission CRR transactions
68/75 CRRAHs qualified. Greater than
5% RED.
CRR3 Operation of CRR Auctions and
AllocationsGreen CRRAHs
Even weighting
87.8% 0% 12.2% 0.0%
Participation in at least 1of the last 2 auctions or allocations. > 80%
total participating
58/66 CRRAHs with adequate participation in June or July auction or
allocationERCOT Metrics
CRR3 Operation of CRR Auctions and
Allocations
Green ERCOT N/A N/A N/A N/A N/A
Auction results distributed to
participants per schedule in CRR
Handbook
6/21 2010 June Monthly Auction results posted to
market.
TBD ERCOT N/A 100% 0% 0% 0%
Allocated Revenue Rights in statistical
sample = 100% accurate
Source – Sink prices = CRR Clearing prices for
obligations for BOY auction. ERCOT working on similar
validation process for options.
CO8 Verify CRR Auction Invoices
GreenERCOT N/A 100% 0% 0% 0%
CRR Auction Result for MP(n) – CRR Auction
Invoices for MP(n) = 0$
S&B validated invoices reflected awards for each CRRAH in the
March, April, May, June, and July auctions, .
GreenERCOT N/A 100% 0% 0% 0%
System Generated CRR Auction Invoices
not posted = 0
6/22 July CRR auction invoices submitted to all 48 CRRAHs who participated
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Real-Time Metrics
Metric NameCurrent Score
Applies to
Weight Green % Yellow % Red %Not
Scored %Primary Criteria Notes
Market Participant MetricsMP3 Market Submissions Connectivity Qualification
Green QSERsGeneration Ratio Share
99.0% 1.0% 0.0% 0.0% Successful submission of RT and DAM
transactions
79/81 QSERS qualified
Green QSEsEven
weighting98.9% 1.1% 0.0% 0.0% 178/182 QSEs qualified.
EMO6 Individual LFC Testing
Green QSERsGeneration Ratio Share
96.9% 0% 0% 3.1%
80% of system-wide generation has
completed individual QSE tests for LFC
70/73 QSERs completed their individual LFC test or provided attestation
MP15-A Real-time Market Participation
Green QSERsGeneration Ratio Share
100.0% 0.0% 0.0% 0.0%Weekly average of
daily SCED submissions
79/79 QSERs above 95% weekly average for
SCED submissions. ERCOT Metrics
MO3 Verify SASM Green ERCOT N/A 100% N/A N/A N/A
Multiple SASMs are successfully executed during Market Trials
and the 168 hour test.
SASMs successfully run on 4/28, 4/30, 5/4, 5/6, 5/7, 5/12, 5/14, 6/9, and
6/10. No issues reported.
MO4 Verify SCED Execution Quality
Green ERCOT N/A 100% 0% 0% 0%
All successful SCED executions passed the post-execution price
validations.
6/1 - 6/14 period - 4,035 Price Validation runs with no rule violations
MO5 Generate 6 Months of LMPs
Green ERCOT N/A 98.1%. 0% 1.9% 0%
95% of SCED executions completed with LMPs posted on
MIS.
6/1 - 6/14 period, 3,971 out of 4,031 SCED runs
with LMPs posted.
CO5 Verify RTM Settlement
Statements/CO6 Verify RTM Settlement
Invoices
Green ERCOT N/A 100% 0% 0% 0%
System Generated RT Statement Dollars-
Independently Generated RT
Calculation Dollars =$0
6660 RTM Statements;1609 RTM InvoicesAll validated $$ =
system generated (with some rounding differences)
Green ERCOT N/A 100% 0% 0% 0%System Generated RT Statements/Invoices
not posted = 0
6660 RTM Statements;1609 RTM InvoicesAll posted on time
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Day-Ahead Market Metrics
Metric NameCurrent Score
Applies to
Weight Green % Yellow % Red %Not
Scored %Primary Criteria Notes
Market Participant Metrics
MP16 DAM Participation
Green QSERsGeneration Ratio Share
99.0% 1.0% 0.0% 0.0% Participation in 50% of the Day-Ahead Market
runs
78/79 QSEs with Resources
Amber QSEsEven
Weighting78.6% 6.6% 12.6% 1.1%
143/182 QSEs w/o Resources
CO10 Credit Calculations
6/30/2010QSERs, QSEs
Gen Ratio Share, Even Weighting
N/A N/A N/A N/A<= 25% of MPs credit limits inconsistent with
protocolsTo be determined
ERCOT Metrics
MO8 Verify DAM Execution Quality
Report in Progress
ERCOT N/A N/A N/A N/A RedDAM executions pass
the post-execution price validations
Report in progress
MO9 Generate DAM LMPs
Green ERCOT N/A N/A N/A N/A N/A95 percent DAM
execution as evidenced by DAM LMP postings
6/1 – 6/14 – 7/7 DAM runs execute(doesn’t
measure quality)
MO10 DRUC Execution
Green ERCOT N/A N/A N/A N/A N/A95 percent DRUC
execution
6/1 – 6/14 - 7 out of 7 DRUC runs executed
(doesn’t measure quality)
CO3 Verify DAM Settlement
Statements/CO7 Verify DAM Invoices
Green ERCOT N/A 100% 0% 0% 0%
System Generated RT Statement Dollars-
Independently Generated RT
Calculation Dollars =$0
4715 DAM Statements and Invoices
All validated $$ = system generated (with
some rounding differences)
Green ERCOT N/A 100% 0% 0% 0%System Generated RT Statements/Invoices
not posted = 0
4715 DAM Statements and Invoices
All posted on time
CO10 Credit Calculations
6/30/2010ERCOT N/A N/A N/A N/A N/A
ERCOT performs credit calcs for a stat. sample
of MPsTo be determined
1. MP16 – Metric is based on a 2 week rolling average (6/7 – 6/18 – 9 runs).2. MP16 – 97% Load participating.
Technical Advisory Committee5 August 2010
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Metric NameCurrent Score
Applies to
Weight Green % Yellow % Red %Not
Scored %Primary Criteria Notes
Market Participant Metrics
MP14-C TSP Model Validation
Green TSPsOwnership Ratio Share
99.9% .1% 0.0% 0.0%Network Model data
validated by TSP
24/28 TSPs have submitted model
validation e-mail to ERCOT.
MP6 Telemetry Compliance with Nodal
Protocols 3.10.7.5
Green QSERsGeneration Ratio Share
100% 0.0% 0.0% 0.0%Expected State
Estimator telemetry submitted.
78/78 complete. 3502 total SE points provided
Green QSERsGeneration Ratio Share
100% 0.0% 0.0% 0.0%Expected SCED
telemetry submitted.78/78 complete. 7629 SCED points provided
Green TSPsOwnership Ratio Share
99.3% 0.0% 0.0% .7%Expected TSP
telemetry per ICCP Handbook submitted
14/17 TSPs above 98% threshold for GREEN. 143 points outstanding
N2 Telemetry ICCP System Failover
Green/White only
QSERsGeneration Ratio Share
68.9% 0% 0% 31.1%
ICCP Failover test completed successfully prior to the 8-hour LFC
test.
37/78 QSERs completed ICCP telemetry failover
test.
MP18 Mapping of Resources and Loads
in Private Use Networks
6/30/2010 QSERsGeneration Ratio Share
N/A N/A N/A N/A
# of QSE(n) PUN Points Provided / # of QSE(n) PUN Points
Expected
306 points across 7 QSEs with Resources. 15 points still assigned
to TSP.MP21 WGRs ICCP
Meteorological Telemetry
6/30/2010REs (only
WGRs)
Registered MW Capacity Ratio Share
N/A N/A N/A N/AWGRs must meet
reasonability tests for MET ICCP
To be determined
MP23 Telemetry Quality (MP to ICCP
server)
6/30/2010 TSPsOwnership Ratio Share N/A N/A N/A N/A
# of TSP(n) Suspect/Bad points
provided / # of TSP(n) points total
1077 Suspect/Bad points (98.3% good
quality).
6/30/2010 QSERsGeneration Ratio Share
N/A N/A N/A N/A
# of QSER(n) Suspect/Bad points
provides / # of QSER(n) points total
277 Suspect/Bad points (98% good quality)
Network Modeling Metrics
1. MP6 does not include 405 QSE CB and DSC points from TSP outreach. ERCOT is determining whether these rollback into the QSER MP6 measurement.
Technical Advisory Committee5 August 2010
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Network Model Metrics
Network Modeling Metrics
Metric NameCurrent Score
Applies to
Weight Green % Yellow % Red %Not
Scored %Primary Criteria Notes
ERCOT MetricsEMO9(A) State
Estimator Standards Performance
Amber ERCOT N/A N/A N/A N/A N/AState Estimator
converges 97% during monthly test period
95.44% Convergence for State Estimator for
the month of May.
EMO9(B) RTCA Modeling Differences
Green ERCOT N/A 96.8% N/A N/A N/A95% of impedance
values matched between Zonal/Nodal
97.9% match for impedances for lines
and transformers. 6718 lines and transformers in
Nodal.
Green ERCOT N/A 96.8% N/A N/A N/A95% of dynamic line
ratings matched between Zonal/Nodal
97.5% match for ratings for lines. 5288 lines in
Nodal.
Red ERCOT N/A N/A N/A 84.33 N/A95% of load tap setting
values matched between Zonal/Nodal
84.3% Match for transformer tap settings.
1430 xfrms in Nodal.
EMO10 Anomalous / Auto-Disabled
Telemetered PointsGreen ERCOT N/A 1.91% N/A N/A N/A
The % of Anomalous and Auto-Disabled
Measurements < 2% of Total Measurements
April Nodal 2.58%May Nodal 1.92%June Nodal 1.91%
EMO9(C) RTCA CSC Comparison
7/14/2010 ERCOT N/A N/A N/A N/A N/ACSC Pre-contingency SE Flows within 5% (Hourly snapshot)
Measurement establishes baseline flows on Commercial lines to indicate the
significance of Psuedo modeling and multi-
section lines on the SE flows.
EMO9(D) Validate Zonal and Nodal Security Analysis
Results
9/8/2010 ERCOT N/A N/A N/A N/A N/A
90% of active constraints in Zonal
RTCA are also detected in Nodal
RTCA
To be determined
Technical Advisory Committee5 August 2010
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Other Readiness Metrics
Metric NameCurrent Score
Applies to
Weight Green % Yellow % Red % Not Scored % Primary Criteria Notes
Market Participant MetricsMP20 Outage
Scheduler Connectivity Qualification
Green QSERsGeneration Ratio Share
98.9% 0.0% 0.0% 1.1% Successful submission of OS
transactions
78/79 QSERS qualified.
Green TSPsOwnership Ratio Share
99.7% 0% 0% .3% 20/23 TSPs qualified.
MP11 Resource Registration
Green REsRegistered
MW Capacity Ratio Share
99.6% 0.0% .4% 0.0%
Decision Making Authority form submitted, and
GENMAP validated
154/157 Resources completed.
CO2 Verify Dispute Process
7/14/2010QSERs, QSEs
Generation Ratio Share,
Even Weighting
N/A N/A N/A N/A
>=1 dispute submit per MP. # of unprocessed
disputes by 168 = 0
To be determined
ERCOT Metrics
E1 ERCOT Staff Completes Training
Green ERCOT N/A 100% N/A N/A N/A
Training plans must be adhered
to for highly impacted
departments
15 out of 15 highly impacted departments are up to date with their
training plans.
E9 Develop Nodal Procedures
Green ERCOT N/A 100% N/A N/A N/A
Procedures developed 1
month prior an exercised in the
appropriate Market Trials Phase
All MT4 and MT5 are developed and the MT4 procedures exercised as scheduled in MT4.
EMO3 Verify Outage Evaluation System
FunctionalityGreen ERCOT N/A N/A N/A N/A N/A
A test of the Outage
Management Process is completed
OS to OE integration tested throughout Market Trials and
reviewed at 6/23 NATF
Technical Advisory Committee5 August 2010
50
Participant Readiness Touch Points
20102010
Meetings
Training
Outreach
Market trials
SeptemberAugustJuly
• NATF 7/8
• MRS #5 168 Hour Test (Tentative)
• Dispute & Reports Metrics
• Standby site visits
• Weekly Trials calls• 48 hr system-wide
LFC test• Verifiable costs
loaded into N-Prod
• Nodal 101• Transmission 101• Generation 101, 201• Basic Training
Program• NOIE QSE Operations• Settlements 301
• Weekly Trials calls• Prepare for 168 hr
test
• NATF 8/19
• Nodal 101• Transmission 101• Generation 101, 201• Basic Training
Program• NOIE QSE Operations• Settlements 301
• Standby site visits
• Weekly Trials calls• Execute 168 hr test
• NATF 9/14
• Nodal 101• Transmission 101• Generation 101, 201• NOIE QSE Operations• Settlements 301• MMS & MIS GUI
(Online only)
• Standby site visits
October
• Preparation for Nodal Go-Live
• NATF 10/5
• TBD
• TBD
Technical Advisory Committee5 August 2010
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