cutover daily call 4:30 pm

http://nodal.ercot.com 1

Cutover Daily Call 4:30 PM

November 23, 2010 4:30


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.


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


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)


• 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.


QUESTIONS?


Appendix


Items Covered in 10:30 AM Call



• 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.



• 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)


Simple Cycle (Less than 90 MW)


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%