1. Technical Advisory Committee
Presentation to the
ERCOT Board of Directors
April 22, 2009

2. TAC Report Summary 5 PRRs for Board approval 1 NPRR for Board approval
1 SCR for Board approval
Report: 2 CREs approved
Report: 2 COPMGRRs approved
Report: SCR approved
Report: 2009 TAC Goals
Report: Wind Metrics Development
Report: Unfunded Projects List
Update: PRR 791
Update: Stakeholder Engagement in Nodal Program

3. Protocol Revision Requests
PRR 768 TDSP Energy Storage Reliability - URGENT
PRR 789 Removal of Grey Box Language Related to Dynamics Load Profiling Due to Unfunded Projects
PRR 790 Load Profile ID Annual Validation Change Request
PRR 803 Revised Implementation Approach for PRR 601 – URGENT
PRR 804 Revisions to Section 21 Appeals Process – URGENT

4. PRR 768 – TDSP Energy Storage for Reliability -- URGENT
Purpose
(AEP)
Clarifies that electricity flows from TSP-owned battery storage will be treated as substation equipment and that measurement of such flows is not required for settlement; this clarification will be limited to ERCOT Board endorsed TSP reliability projects
Benefit
Provides additional technology to address reliability needs
Market Impact
N/A
System Change No
Assumptions
TAC Vote
TAC recommended approval with 2 opposing votes (electric cooperative segment) and 1 abstention (independent generator segment); all Market Segments were present
Effective Date
May 1, 2009

5. PRR 768 – TDSP Energy Storage for Reliability -- URGENTNo
Impact
Impact
Description
Item Reviewed
Budget
Staffing
Computer Systems
Business Functions
Grid Operations
Credit Monitoring/
Liability

6. PRR 789 – Removal of Grey Box Language Related to Lagged Dynamics Load Profiling Due to Unfunded Projects
Purpose
(Direct Energy for Profiling WG)
Removes grey-box language related to the use of lagged dynamic samples for new profiles.
Benefit
Administrative clean-up.
Market Impact
N/A
System Change No
Assumptions
TAC Vote
TAC unanimously recommended approval; all Market Segments were present.
Effective Date
May 1, 2009

7. PRR 789 – Removal of Grey Box Language Related to Lagged Dynamics Load Profiling Due to Unfunded Projects No
Impact
Impact
Description
Item Reviewed
Budget
Staffing
Computer Systems
Business Functions
Grid Operations
Credit Monitoring/
Liability

8. PRR 790 – Load Profile ID Annual Validation Change Request
Purpose
(Direct Energy for Profiling WG)
Allows for changes in the Annual Validation process timeline due to extreme events.
Benefit
Allows Market Participants to utilize their resources to handle emergency situations.
Market Impact
N/A
System Change No
Assumptions
TAC Vote
TAC unanimously recommended approval; all Market Segments were present
Effective Date
May 1, 2009

9. PRR 790 – Load Profile ID Annual Validation Change RequestNo
Impact
Impact
Description
Item Reviewed
Budget
Staffing
Computer Systems
Business Functions
Grid Operations
Credit Monitoring/
Liability

10. PRR 803 – Revised Implementation Approach for PRR 601 -- URGENT
Purpose
(ERCOT)
Changes the BES ramping period from 10 minutes to 14 minutes
Benefit
Improve dispatch efficiency by better ramp rate utilization
Market Impact
Ramping over 14 minutes will allow more BES to be deployed and may tend to reduce Regulation Service deployments
System Change
Yes
$100K to $250K
Assumptions
Impacts EMMS, EDW, Market Database and Lodestar
TAC Vote
TAC unanimously recommended approval with a “2 - High” priority and rank of 39.1; all Market Segments were present
Effective Date
Not later than 6 months after approval; earlier than 6 months after approval only if all affected market participants have successfully tested new ramping capability

11. PRR 803 – Revised Implementation Approach for PRR 601 -- URGENTNo
Impact
Impact
Description
Item Reviewed
Budget
$100K to $250K
Staffing
EMMS, EDW, Market Database and
Lodestar
Computer Systems
Business Functions
Grid Operations
Credit Monitoring/
Liability

12. PRR 804 – Revisions to Section 21 Appeals Process -- URGENT
Purpose
(ERCOT)
Provides that if a motion to approve a revision request fails, the revision request shall be deemed rejected by the body considering it and subject to appeal, unless at the same meeting that body votes to remand, refer or reconsider the revision request
Benefit
Further defines an “appealable event”
Market Impact
N/A
System Change No
Assumptions
TAC Vote
TAC unanimously recommended approval as amended by ERCOT comments; all Market Segments were present
Effective Date
May 1, 2009

13. PRR 804 – Revisions to Section 21 Appeals Process -- URGENTNo
Impact
Impact
Description
Item Reviewed
Budget
Staffing
Computer Systems
Business Functions
Grid Operations
Credit Monitoring/
Liability

14. Nodal Protocol Revision Request
NPRR 149 Change the Name of Emergency Electric Curtailment Plan (EECP) to Energy Emergency Alert (EEA)

15. NPRR 149– Change the Name of Emergency Electric Curtailment Plan (EECP) to Energy Emergency Alert (EEA)
Purpose
(ERCOT)
Companion of PRR 775; changes EECP to EEA; changes the defined term “Alert” to “Watch”
Benefit
Reduce confusion when ERCOT communicates statuses or reports on recent events
Market Impact
System Change
Yes
<$50K
Assumptions
Impacts EMS
TAC Vote
TAC unanimously recommended approval; all Market Segments were present
Effective Date
ERCOT believes NPRR 149 is needed for “go-live”; effective upon Nodal implementation; no impact to schedule

16. NPRR 149– Change the Name of Emergency Electric Curtailment Plan (EECP) to Energy Emergency Alert (EEA) No
Impact
Impact
Description
Item Reviewed
Budget
<$50K
Staffing
EMS
Computer Systems
Business Functions
Grid Operations
Credit Monitoring/
Liability

17. System Change Request
SCR 754 Replace Delivery of WGRPP Forecasts Formerly “WGRPP Forecasts Posted on Zonal TML”
Provides secure and programmatic means to supply WGR QSEs with ERCOT wind power forecast
WGR QSE forecasts currently sent by , which has caused delays and errors
WGR QSE-specific forecast required for ERCOT capacity adequacy studies
ERCOT will utilize existing XML User Interface
Project cost/timeline: $50-100k; 3 months
TAC unanimously recommended approval; all market segments were present

18. Report: ERCOT CREs approved
On March 20, ERCOT requested the addition of 3 North to Houston Closely Related Elements (CREs)
Gibbons Creek-Singleton #2
Singleton-Roans Prairie
Singleton-Tomball
ERCOT requested the addition because the new Singleton substation split an existing CRE
TAC unanimously approved the ERCOT request through an vote

19. Commercial Operations Market Guide Revision Requests
COPMGRR 009 Planned Schedule Release and Planned Maintenance Outage Notifications
Updates language describing ERCOT planned systems outages
Unanimously approved by TAC; all market segments were present
COPMGRR 010 Creating Section 12, Renewable Energy Credits
Adds REC program language to improve information availability, impacts on REC program
Unanimously approved by TAC; all market participants were present

20. Report: SCR Approved
SCR 753 Transmission Outage Notice Detail Enhancements
Increases transmission outage transparency to all market participants by making available information already stored in ERCOT databases
No system project required, no FTEs required
Minor programmatic changes to be absorbed by existing Staff and O&M budgets of affected departments

21. Report: 2009 TAC Goals
Oversee stakeholder engagement in the ERCOT nodal market implementation program and ensure the activities of TAC and its subgroups are properly focused on delivering the nodal project by its intended Go-Live date; that Market Participant Readiness is communicated to the Board of Directors; and that post-Go-Live issues are properly framed and ready to be addressed after nodal market open.
Develop a renewable technologies integration plan which captures the benefits of new energy resources while addressing the challenges such resources pose and economically maintaining system reliability.

22. Report: 2009 TAC Goals
Improve the transparency of the identification and analysis of transmission congestion, including out of merit dispatch, its communication to TAC, and the basis by which solutions are proposed, evaluated and implemented with the goal of maximizing market driven solutions.
Oversee the development of advanced metering settlement, transaction, and procedural activities and assure appropriate revisions to the protocols and guides are made to reflect changes supporting successful implementation of advanced metering.  

23. Report: Wind Metrics
Review of recently approved performance requirements and related performance metrics
Use of AWS Truewind forecast for Day Ahead and intra-day capacity adequacy studies (PRR 763)
Metric: pass/fail
Low-Voltage Ride Through Requirement for new wind units (OGRR 208) and study for applicability to existing units (Study due June 2010)
LSL as % of HSL (PRR 773)
metric: pass/fail
Deleted Resource Plan performance metric for intervals affected by PRR 763 (PRR 777) metric: removed in certain intervals

24. Report: Wind Metrics Ramp Rate limitation for new wind units (PRR 771)
Metric: pass/fail
Ramp Rate limitation for existing wind units (PRR 778)
WGR QSE scheduling metric (PRR 793)
WGR QSE meteorological data telemetry requirement (PRR 794)

25. Report: Wind Metrics Proposed metrics in process
QSE Day Ahead Metric (PRR 800)
Real Time Production Potential (PRR 811)
Development of new and revised WGR and WGR QSE requirements and performance measures will be an ongoing task for some time
RTWG issues development
“governor-like” response
Metrics development is part of draft Texas Renewables Integration Plan
PUCT requested additional detail on issues prioritization and target dates for completion of tasks

26. Report: Unfunded Projects List
Protocols Sec requires quarterly report to the ERCOT Board regarding projects on the “Unfunded Projects List”
There are no Unfunded Projects at this time

27. Update: PRR 791
TAC considered the action and discussion on PRRs 776 and 791 at the March Board meeting
A motion to table PRR 791 pending action by the PUCT carried unanimously; all market segments were present

28. Update: Stakeholder Engagement in Nodal Project
TAC is engaged in productive and focused discussions with ERCOT Staff on best role for stakeholders to support nodal implementation and assure market participant readiness
Key issues
focus on market readiness activities
productive engagement with ERCOT Staff
coordination with ERCOT efforts
visibility and input into ERCOT decision-making process
transparency of relevant information to all market participants