Modeling Work GroupDiscussion Points on ProposedModeling of Operating Reserves andCombined Heat & Power (CHP) December 14, 2011 Web Meeting
Agenda • Welcome, Introductions (Tom Miller) • Proposed Operating Reserve Modifications for TEPPC Dataset • Reserve Modeling Issues • Operating Reserve Definitions • Proposed Reserve Modeling Concept • WECC-Wide Modeling of Operating Reserves • Composite Hourly Reserve Requirement • Modeling Technique For PROMOD • Spinning and Non-Spin Generators • TAS December 15th Meeting, Status and Next Steps • E3’s Proposed Modeling Updates to CHP in the TEPPC Base Case (WECC Staff- Heidi Pacini) Comments, Suggestions and Concerns Needed
Reserve Modeling Issues • The reserve modeling in Promod is not implemented at the same granularity as much of the other data. • Only a “spinning” reserve requirement has been specified in the dataset. • The “fixed” hydro does not contribute to operating reserves in Promod. • Increases in the amount of variable generation, such as wind and solar, are expected to impact the required level of reserves and/or the unit commitment decisions.
Operating Reserve Definitions • Operating Reserve (spinning and non-spinning): That capability above firm system demand required to provide for regulation, load forecasting error, equipment forced and scheduled outages and local area protection (NERC). • Regulating Reserve (or Frequency Response Reserve): An amount of reserve responsive to Automatic Generation Control (AGC), which is sufficient to provide normal regulating margin (NERC). • Operating Reserve Margin The amount of unused available capability of an electric power system at peak-load for a utility system as a percentage of total capability (EIA). • “Flexibility Reserves”: additional reserves required to manage the variability and uncertainty associated with variable generation resources like wind and solar (NREL).
Proposed Reserve Modeling Overview • A: Base Operating Reserves (Spin and Regulation) requirement of 4% of load will be calculated for each hour for each sub-region. • Non-spin Reserves not explicitly modeled; simplified assumption is that there is sufficient short-start resources available (e.g. GT’s) • B: Flexibility Reserves as calculation will be derived from the variability of renewable generation (will not include load variability) in each of the TEPPC sub-regions • C: Total Composite Reserve Requirement (A+B): will be sum of Base reserves plus Flexibility reserves, which will be modeled in PROMOD using the transaction methodology.
WECC-Wide Modeling of Reserves • New calculation will be based on dataset for the TEPPC 2022 case. • Use current TEPPC topology with reserves defined at the sub-region level. • Sub-region reserves not adjusted for energy imbalance markets or dynamic scheduling. • Pumping loads do not require any reserves. • Proposal will be implemented, wholly or partially, in either the 2022 PC1 common case or a sensitivity case.
Composite Hourly Reserve Requirement • Reserve granularity is increased from a weekly requirement to a daily requirement with an hourly adjustment for load following and variable generation • Load regulation reserves to follow the fluctuation of the load. • Flexibility reserves to follow the fluctuation of the wind and solar output. • The reserve requirement will continue to be specified at the TEPPC sub-region level with a 4% basis.
Modeling Technique for PROMOD • Combination of three inputs simulates an hourly reserve requirement • Hourly reserves requirement: can be implemented by inserting a Model purchase that contributes to reserves • Model sale that cancels the purchase as depicted
Spinning and Non-Spin Generators Table 1 - Spinning & Non-Spinning Generation Note: fixed scheduled hydro does not contribute to reserve requirements
Status and Next Steps • Present Overview and Proposal to TAS December 15th • Data Coordination for Flexibility Reserve Calculation (NREL/WECC) • Renewables By CREZ • WECC Topology • Calculation of Flexibility Reserves (Jack King) • Composite Reserve Modeling (WECC Staff) • Perform PROMOD Run and Validation (Staff and WG’s) • Present Results and Recommendation to TAS regarding using reserve modeling as Sensitivity or Common Case assumptions
Modeling of CHP in TEPPC 2022 Common Case • Background: • In the process of developing assumptions for the 2022 High DSM/DG TEPPC study case LBNL and E3 pointed out that the TEPPC datasets do not appear to capture much of the existing CHP capacity in the Western Interconnection. • This issue t was flagged as a cross-cutting issue that should be addressed in the 2022 Common Case. • Review E3’s investigation into the representation and modeling of existing cogeneration in the TEPPC 2022 Common Case. • Review E3 proposal to improve the TEPPC dataset. • The E3 proposal has also been posted to the meeting page for Thursday’s TAS call and added to the TAS agenda.