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Cutover Daily Call 4:30 PM. November 23, 2010 4:30. Antitrust Admonition. ANTITRUST ADMONITION - PowerPoint PPT Presentation
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http://nodal.ercot.com 1
Cutover Daily Call 4:30 PM
November 23, 2010 4:30
http://nodal.ercot.com 2
Antitrust Admonition
ANTITRUST ADMONITION
ERCOT strictly prohibits Market Participants and their employees who are participating in ERCOT activities from using their participation in ERCOT activities as a forum for engaging in practices or communications that violate the antitrust laws. The ERCOT Board has approved guidelines for members of ERCOT Committees, Subcommittees and Working Groups to be reviewed and followed by each Market Participant attending ERCOT meetings. If you have not received a copy of these Guidelines, copies are available at the Client Relations desk. Please remember your ongoing obligation to comply with all applicable laws, including the antitrust laws.
DISCLAIMER
All presentations and materials submitted by Market Participants or any other Entity to ERCOT staff for this meeting are received and posted with the acknowledgement that the information will be considered public in accordance with the ERCOT Websites Content Management Operating Procedure.
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Daily Call – 4:30 8 Days Until Go-Live
• General Updates / Reminder– FAQ: The Zonal data that is not required past 12/1, does this include
Zonal Telemetry?A: Zonal telemetry is not required past 12/1. Please note that, as with all Zonal data requirements, ERCOT may extend this need based on Nodal System conditions. This will be communicated via Hotline, Market Call and Market Notice if required.
– WGR during EMBP Activation and W2N is active• WGRs may receive special instructions to hold their last base point (depending on
whether the IROL is active)• ERCOT expects that this instruction will come as a hotline call• For purposes of calculating GREDP, ERCOT does not consider the 5-minute clock
intervals during which Emergency Base Points have been issued (see NP 8.1.1.4.1 (6)(b))
FAQ
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Trade confirmation
Documentation:• Market Submission Validation Rules on the MIS, Day-Ahead market page
• Market Manager User Guide: http://nodal.ercot.com/readiness/markettrials/connectivity/keydocs/Market_Manager_User_Guide_06.doc
FAQ (cont’d)
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• QSEs receive systematic notifications from ERCOT when their counterparty confirms the trade by submitting the matching trade. The timestamp of this notification can be compared to the RUC timestamp to understand whether or not the trade should be included in the snapshot.
• Notifications can also be queried after the fact via web services or via Market Manager (Notices tab).
– A word of caution is that this notification only says that a trade is confirmed between Buyer1 and Seller1 at SettlementPoint1, it doesn’t include the delivery hours or the quantity details. A trade query can be done after the notification is received to confirm the hours/details.
• Similarly, QSEs can capture the timestamp of the acknowledgement for the trade that is received when they submit the matching trade that confirms the transaction.
• Note that if the counterparty structures the xml in such a way as to submit each hour separately, a trade confirmation notification will be sent for each hour of the trade. If the xml is structure to submit the trade as a block of time, only one notification will be sent.
• Example – 24 hour trade. If the counterparty submits each hour separately, you receive 24 identical notifications. If the counterpart submits the trade as hours 1-24 within the xml, you receive 1 notification.
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QUESTIONS?
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Appendix
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Items Covered in 10:30 AM Call
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Daily Call – 10:30 8 Days Until Go-Live
• General Updates / Reminder– ERCOT will remove the Market Trials posting Settlement Points and
MP Short Names (as of 10/21/2010) today• That was a manual posting available only until the automated posting was available on
MIS• Settlement Points List and Electrical Buses Mapping information may be found under
the MIS Operating Day System Conditions portlet• MP short names can be found at
Landing Page: http://www.ercot.com/mktparticipants/ Direct Link: List of Market Participants in ERCOT Region
– FAQ: Why a combined cycle resource was not awarded in the DAM, or why DAM transitioned the combined cycle down to a lower configuration at the end of the day. A: The DAM engine studies a 24 hour period, and must respect the resource constraints within that period. DAM must make sure that a resource is capable of shutdown by the last hour of the day/award, so the last hour awarded to a combined cycle resource will be from a shutdown-capable configuration. If no configuration is offered into the DAM that is capable of being shut down directly (this is a RARF parameter), then DAM will not award the resource at all. Similarly, if no configuration is offered into the DAM that is capable of being started up directly, DAM will not award the resource unless it is initially online at the end of the current day.
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Daily Call – 10:30 8 Days Until Go-Live
• General Updates / Reminder– Listener URLs
• ERCOT continues to receive several requests for Listener URL updates• ERCOT is asking that all remaining updates to Listener URLs be submitted by EOB
tomorrow (11/24/2010) to [email protected]
– Data Access Frequency (Dashboards, Extracts, Reports, etc)• All MPs need to review the frequency of which they are downloading / programmatically
accessing data from ERCOT systems• ERCOT Support Teams are finding several MPs that are accessing reports at an
unreasonable frequency• For example, some Daily Reports (generated once in a 24-hour period) are being hit
150,000+ times / daily by some QSEs• This will assist ERCOT in gauging post Go-Live performance and sizing / scaling of
systems going forward to support reasonable data access behavior• If there are questions on the frequency of a particular report, MPs can access the
ERCOT Market Information List (EMIL), currently posted at: (Under Key Documents): http://nodal.ercot.com/readiness/reports/index.html
Follow-Up: November Full System Reliability and Market Test Results Generation Resource Energy Deployment Performance (GREDP)
•Measure of how well resources follow dispatch instructions
•Non-Wind, Non-DSR Generators and DSR Portfolios must have a GREDP less than 8% or 8 MW for 85% of the intervals in which GREDP was scored
Percent of Non-WGRs Generation Resources that Met the Protocol
Criteria
Average Percent of Total Generation During the Test by
Fuel Type
All Resources 90.97% NA
Resources Providing Regulation 92.31% NA
Combined Cycle Resources 87.18% 27.30%
Coal and Lignite Resources 94.44% 41.02%
Diesel Resources 100.00% 0.03%
Gas Steam (Non-Reheat Boiler)
Resources100.00% 0.00%
Gas Steam (Reheat Boiler) Resources 85.71% 0.92%
Gas Steam (Supercritical Boiler)
ResourcesNA 0.00%
Hydro Resources 75.00% 0.08%
Nuclear Resources 100.00% 12.21%
Simple Cycle (Greater than 90 MW)
Resources92.31% 1.52%
Simple Cycle (Less than 90 MW)
Resources88.89% 0.75%
Percent of DSR Portfolios that Met the Protocol Criteria
All DSRs 0.00%
DSRs Providing Regulation NA
Non-WGRs/ Non-DSRs
DSRs
Follow-Up: November Full System Reliability and Market Test Results
Generation Resource Energy Deployment Performance (GREDP)
•Measure of how well resources follow dispatch instructions
•Wind Generators must have a GREDP less than 10% or the output must be less than their expected output for 95% of the intervals in which GREDP was scored
•Wind Generators are only scored during curtailment
Percent of WGRs that Met the Protocol Criteria 20.51%
Number of WGRs that had an Interval for which GREDP was scored 39
Average Percent of Total Generation During the Test from WGRs 16.16%
WGRs
Follow-UP: Example - Scoring GREDP for IRRs
• For this example, assume no exclusions were active and that LSL = AEGR = ARI = 0 for the WGR
Interval
Ending
QSE Res.Fuel Type
Res. Status
ATG ABPSCED HSL
SCED BP
ATG – Expected MW
GREDP (%)
Was Interval Passed?
Number of Intervals Scored
Percent of Intervals Passed
13:05:00 QABC UNIT1 WIND ON 123.5 120.5 125. 125. 8 50%
13:10:00 QABC UNIT1 WIND ON 131. 127. 130. 129.
13:15:00 QABC UNIT1 WIND ON 125. 109.5 135. 90. 15.5 14.155 N
13:20:00 QABC UNIT1 WIND ON 100. 90. 135 90 10 11.111 N
13:25:00 QABC UNIT1 WIND ON 95. 90. 130. 90. 5 5.5556 Y
13:30:00 QABC UNIT1 WIND ON 70. 65. 125. 40. 5 7.6923 Y
13:35:00 QABC UNIT1 WIND ON 35. 40. 125. 40. -5 12.5 Y
13:40:00 QABC UNIT1 WIND ON 25. 20. 130 0 5 25 N
13:45:00 QABC UNIT1 WIND ON 10. 0. 135 0. 10 N
13:50:00 QABC UNIT1 WIND ON 0 0. 135. 0. 0 0 Y
• Wind must have a GREDP less than 10%:
GREDP (%) = ABS[((ATG – AEGR)/(ABP + ARI)) – 1.0]*100
ATG <= Expected MW = AEGR + ABP + ARI
• OR output must be less than expected output:
# of Intervals passed: 4
(4÷8)*100=
50%