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December 2, 2004 Congestion Causes and Effects. Presented to WMS January 14, 2005 Beth Garza. Issue Statement.
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December 2, 2004 CongestionCauses and Effects Presented to WMS January 14, 2005 Beth Garza
Issue Statement Transmission Outages on Dec 2 & 3 lowered the NE-N CSC limit to a level where TCRs became very valuable and payments to TCR holders exceeded congestion payments by over $6 M which was uplifted through BENA
Topics to Cover • Day Ahead Info • Prices • Transmission Outages • BENA/Uplift effects • TCR Auction vs. Day Ahead Limit • Pre-controlling CSC limits
Transmission Limits to Be Monitored For: Thursday 12/02/2004 The maximum total loading on the following Zonal and Local Constraint monitored elements should be maintained. Local constraints will be resolved with Real Time Contingency Analysis Above Zonal limitations are based on the following:
Transmission Limits to Be Monitored For: Thursday 12/02/2004 REVISED[1] The maximum total loading on the following Zonal and Local Constraint monitored elements should be maintained. Local constraints will be resolved with Real Time Contingency Analysis [1] Revision was made to reflect a change in online units from the day-ahead study.
Zonal Shift Factors for NE-N CSC The most effective combination to relieve NE-N congestion is to Balance Down in the NE / Up in the North. • 41.31% impact NE +35.8% North -5.51% West +0.23% Hou -4.44% South -3.76%
Shadow price and Northeast MCPE calculation for December 2 / 05:15 Once Down Balancing in the Northeast is exhausted, the system looks to other zones Shadow Price Power balance is maintained while reducing flow on NE-N CSC MCPE for the Northeast is now determined from its relation to these costs MCPEz – MPCE NE = SP*(SFNE – SFz) MCPEz – SP*(SFNE – SFz) = MCPENE = $2241
Aggregated Balancing Energy Down BidsNortheast Zone - December 2, 2004
Possible reasons for discrepancy between the Monthly TCR calculation and the Daily CSC limits calculation: • Monthly TCR calculation occurs 45 days in advance • TSPs only required to submit outages 3 days in advance • There were several line-ratings changes that occurred in November not considered in the monthly calculation • No generator outages are considered in the monthly calculation • No dynamic ratings are used in the monthly calculation • Operations case vs. SSWG case • Generators not adjusted individually in monthly calculation • Overloads on lines with PTDF’s of less than 4.0% are ignored • Settlement Adjustment consideration differences
December NE – N TCR Calculation with Actual Transmission Outages Line Outages: • December TCR study included 33 line outages. • 130 line and transformer outages actually occurred on December 2. • Using a 5-day outage criteria, there were 67 line and transformer outages on December 2. Variables considered: • Line Outages (All, 5-Day window) • Updated Ratings (with and without the 11/12/2004 update) • Normally, the limiting contingency is chosen by MUST. One case using the 5-day window outages was run using the contingency chosen by operations.
Transmission Limits to Be Monitored For: Wednesday 12/01/2004 The maximum total loading on the following Zonal and Local Constraint monitored elements should be maintained. Local constraints will be resolved with Real Time Contingency Analysis Above Zonal limitations are based on the following:
Transmission Limits to Be Monitored For: Friday 12/03/2004 The maximum total loading on the following Zonal and Local Constraint monitored elements should be maintained. Local constraints will be resolved with Real Time Contingency Analysis Above Zonal limitations are based on the following:
Transmission Limits to Be Monitored For: Saturday 12/04/2004 The maximum total loading on the following Zonal and Local Constraint monitored elements should be maintained. Local constraints will be resolved with Real Time Contingency Analysis Above Zonal limitations are based on the following:
Northeast DBES Bids December 2, 2004
