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Effects of Certain Market Participant Actions on SCED

Effects of Certain Market Participant Actions on SCED. ERCOT Feb 2 nd , 2010. Objective. Increase awareness of the effects of certain Market Participant (MP) actions on Real Time Market (RTM) results

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Effects of Certain Market Participant Actions on SCED

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  1. Effects of Certain Market Participant Actions on SCED ERCOT Feb 2nd, 2010

  2. Objective • Increase awareness of the effects of certain Market Participant (MP) actions on Real Time Market (RTM) results • Encourage MPs to manage these MP actions so as to get meaningful RTM results during Market Trials (MT) • Provide a check list for MPs to analyze their data before contacting ERCOT • Discuss possible issues with Market Design

  3. $/MWh LMP1 LMP2 LMP3 LDL MW3 MW2 HDL MW1 MW Normal SCED Result

  4. Resources Not Setting LMP • Emergency Base Points are deployed • Resources are Ramp limited. • Telemetry inconsistency issues • Resource is starting up • After Ancillary Service is recalled and Resource is dispatched near HASL • Ramp capacity being reserved for Resource Regulation Responsibility

  5. Very High/ Very Low LMP • Prices could be greater than System Wide Offer Capor lower than System Wide Offer Floor • LMP = System Lambda – Sum (Shift Factor * Shadow Price) • Power Balance Penalty • i.e. 3001 $/MWh for the violated MW from 0MW to 9999.999MW, and 5000$/MWh for the violated MW from 10000MW to 100000MW • Maximum Shadow Price for Transmission Constraints • Base Case:  $5,000/MW • Post Contingency • 345 kV:  $4,500/MW • 138 kV:  $3,500/MW • 69 kV:  $2,800/MW

  6. Special Cases • ONRR • if RRS deployment >0 • Base Point = Current MW • Else • Base Point = 0 • ONTEST • Base Point = Current MW

  7. MP Actions -Inconsistent Telemetry • SCED expects telemetered HSL, LSL, Ancillary Service Resource Responsibility, Ancillary Service Schedule, MW, Resource Status, Combined Cycle configuration number and DSR Output Schedule to be consistent among themselves • ERCOT fixes the Resources at its current telemetered MW if the values are not consistent.

  8. MP Action -Inconsistent Telemetry • Resource Status =OFF, OUT, OFFNS, EMR and telemetered net MW>0 MW • Resource Status = ON and telemetered net MW<0 • Resource Status quality is bad • Resource Status quality is good, but the value is not a valid Resource Status Code • Telemetered Resource Responsibility or Schedule <0 for any Ancillary Service • Calculated LDL >HASL • Calculated HDL<LASL • HSL<LSL, • HSL <=0 • LSL <0 • HSL <= Reg-Up Resource Responsibility + Responsive Resource Responsibility + Non-Spin Resource Responsibility • (HSL-LSL) < SUM (AS Responsibilities) • Invalid Combined Cycle Plant configuration • MW < 0.9 *LSL

  9. MP Action -Inconsistent Telemetry -Effect on Real Time Market • Under Generation • Wrong Resource Status telemetry • Wrong Ancillary Service Schedule telemetry • Change in Ancillary Service Resource Responsibility • Ancillary Service recall • Higher LMP • Price Fluctuation

  10. MP Action -Significant Capacity on Output Schedule • LMPs will be at System Wide Offer Cap with small increase in load.

  11. MP Action -Lack of EOC for Wind Resources Prices will be $ -250 even if only a small amount of Wind generation is dispatched down to resolve constraints

  12. Market Design Issues • Ramp Rate needed for providing Regulation Resource Responsibility is reserved when SCED Up Ramp Rate is calculated. This makes part of available physical capacity un-available to SCED. • Output Schedule is not adjusted for RRS deployment. Hence RRS energy from Resources on Output Schedule is not deployed as part of Base Points from SCED, unless the LMP is at System Wide Offer Cap. I.e. RRS energy from Resources on Output Schedules can only be deployed at the System Wide Offer Cap. • The artificial drop in price when EILS is deployed during EEA prevents scarcity prices from being communicated consistently to Market Participants • SCED Base Points lags behind Load Forecast and uses up regulation since SCED considers current generation as demand instead of 5 minutes look ahead forecast load. Current implementation has extra terms in the “generation to be dispatched” calculation to consider short term load forecast, non-confirming load changes and frequency deviation.

  13. Questions

  14. Calculations • LASL = Min {HSL, LSLTELEM + RDSTELEM} • HASL = Max (LASL, (HSLTELEM – (RRSTELEM + RUSTELEM+ NSRSTELEM))) • SURAMP = RAMPRATE – (RUSTELEM / 5) • SDRAMP = NORMRAMP – (RDSTELEM / 5) • HDL = Min (POWERTELEM + (SURAMP * 5), HASL) • LDL = Min {Max (POWERTELEM - (SDRAMP * 5), LASL),HSL}

  15. HASL LASL HDL LDL BP HSL HASL HDL MW LDL LASL LSL Range of values

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