Presentation on theme: "Operating Reserves Task Force"— Presentation transcript:
1Operating Reserves Task Force Erik Ela and Michael Milligan, NRELJuly 18, 2012MIC Meeting
2Proposal to WECC OCThe VGS is proposing the creation of a task force to analyze the benefits and tradeoffs of different operating reserve calculation methodsThe task force would fall under the OC reporting structure, with VGS SMEs prepared to participateThe task force would use tools and expertise from NREL
3Task Force ObjectivesStep 1: Review of current and proposed methods for reserve requirements (continuation of VGS initiative)Step 2: Use requirements in simulation models and compare ACE and cost metrics among all methodsStep 3: Look through data results to see what influences needsStep 4: Determine if new reserve requirement method is appropriate for recommendation
4FESTIV Flexible Energy Scheduling Tool for Integration of VG SCUC, SCED, and AGC sub-modelsModels at high resolutionTypically AGC, the highest resolution is at 2-6 secondsModels multiple time frames with communication between sub-modelsMultiple chances of forecast error and forecast correctionInterval length, interval update frequency, process time and optimization horizon configurableFlexible operating structuresAll modeling timing parameters, how reserves are used, AGC mode of operation, etc.Deployment of operating reserves modeledDefinitions defined by userReserves are held in one sub-model and used in anotherCan measure effectiveness of operating reserves in terms of both costs and reliability
5Operating Reserves and VG “Operating Reserves and Variable Generation”Erik Ela, Michael Milligan, and Brendan KirbyAugust 2011:What are the operating reserves standards and policies in practice?What types of operating reserve methods are being proposed in research?How does variable generation change the need?
6Definitions (for this presentation) Operating Reserves: Capacity above or below that which is scheduled and used to maintain the active power balance of the system during operationsUpward and downward response at all time scalesFor multitude of reasons:Maintain frequency at nominal level (60 Hz in U.S.)Reduce Area Control Error (ACE) to zeroAssist neighboring balancing authorityReduce over flow of transmission lines and transformersManage Voltage (mostly done with reactive power)Etc.Reactive Power Reserves: Reactive Power capacity to facilitate voltage control (not discussed here)Planning Reserves: Long term capacity to ensure system adequacy (not discussed here)
7Operating Reserve Categorization Non-eventEventRegulating ReserveFollowing ReserveContingency ReserveRamping ReserveAutomaticWithin optimal dispatchManualPart of optimal dispatchInstantaneousNon-InstantaneousprimarysecondarytertiarysecondarytertiaryStabilize FrequencyReplace primary and secondaryReplace secondaryReturn Frequency to nominal and/or ACE to zeroCorrect the current ACECorrect the anticipated ACEReturn Frequency to nominal and/or ACE to zero
8Regulation Reserve in North America RegionRequirement DefinitionPJMBased on 1% of the peak load during peak hours and 1% of the valley peak during off-peak hours.NYISOSet requirement based on weekday/weekend, hour of day, and season.ERCOTBased on 98.8th percentile of regulation reserve utilized in previous 30 days and same month of previous year and adjusted by installed wind penetrations (described further below)CAISOUse a requirement floor of 350-MW up and down regulating reserves which can be adjusted based on load forecast, must-run instructions, previous CPS performance, and interchange and generation schedule changes.MISORequirement made once a day based on conditions and before the day-ahead market closes.ISO-NEBased on month, hour of day, weekday/sat/sun.
9Future methods with consideration of high penetration of Variable Generation
10Wind Integration Study Summaries NYISO/NYSERDA 2005 (10% capacity):No additional contingency reserves.Regulating reserves require slight increase based on keeping 3 sigma of variability.Minnesota 2006 (25% energy):Regulating reserves based on geometric addition of load and wind variability, with wind variability based on 100 MW wind farms. Used 5 sigma.Load following reserve based on 2 sigma of five minute changes in net load.Operating reserve margin (comb. of load following and ramping reserve) based on hourly forecast errors and was a dynamic requirement based on the hourly forecast.
11Wind Integration Study Summaries California ISO 2007 (20% capacity):Detailed observation of CAISO scheduling time lines including ED initiation, completion, and basepoint interval.Used “swinging door” algorithm to calculate regulating reserves and load following reserves which quantifies needs of capacity, ramp rate, and ramp duration.Study showed that persistence forecast errors can impact regulating reserves.All Island Grid Study 2008 (multiple scenarios):Spinning Reserve based on largest contingency and additional contribution from wind.Replacement reserve (can be provided by offline units with startup times less than 60 minutes) was calculated by tool that looked at probabilistic distributions of wind and load forecasts. This was based on how the thousands of scenarios for wind and load were reduced to the 5 or 6 used in the simulation that the 90th percentile should be met.
12EWITS Methods Reserve demand as a function of Predicted operating levels (wind, load)
13Questions? Next Steps… Questions? Erik.Ela@nrel.gov
14European comparison N America (NERC) Europe (ENTSOE) Regulating ReserveNERC does not provide for explicit quantitative requirements. Reserve is only used for normal conditions. NERC enforces compliance with Control Performance Standards CPS1 and CPS2. It. The CPS drive the requirements for each BA which are mostly based on time of day and season.Secondary reserve requirement is explicitly based on statistical equation and mostly comes from load variability. However, secondary reserve is used for both contingencies and normal variations. There are no compliance measures.Following ReserveNo requirementsContingency Reserve (Primary)No requirement. In discussions. Only a frequency bias requirement as part of ACE equation of 1% peak load.Primary Control (3000 MW) split between TSOs based on load share. Full Response at 200 mHz. 20 mHz maximum insensitivity.Contingency Reserve (Secondary)Disturbance Control Standard DCS must recover from contingency in 15 minutes. Enough to recover largest contingency. Many regions require at least 50% to be online/spinning.Similar requirement to DCS. Return ACE to zero within 15 minutes. Split between primary secondary and tertiary. Sum of secondary and tertiary should be at least as large as largest contingencyContingency Reserve (Tertiary)No quantifiable requirement but contingency reserve must be replaced within 105 minutes following contingency.No requirementRamping Reserve