Presented data shows the effective resource hours through the RUC process for all days in 2025, highlighting RUC activity for congestion, particularly in February and March.
From January 1 to April 23 there were 220 HRUC commitments for congestion, mainly in South Texas GTCs (72%), and the Valley Export (9%).
71% of HRUC commitments for congestion occurred when the high ancillary service margin (HASL margin) was negative.
Negative HASL margin indicates not enough system-wide capacity to meet load forecasts, resulting in RUC recommendations to resolve capacity shortages.
RUC decisions often address both capacity and network constraint violations simultaneously, using an optimization model to select the lowest cost solutions.
The need for real-time co-optimization with the RUC engine was discussed, suggesting improvements in recommendations and unit commitments.
Proposed scenarios illustrate cost evaluations in RUC decision-making, with choices influenced by both power balance and network constraints.
Shift factors, both single reference and load distributed, play a critical role in RUC decision-making processes, influencing how constraints are managed.
Behavior of the RUC engine in managing South Texas export constraints was discussed, highlighting the complexity and frequency of RUC operations.
Stakeholder inquiries addressed factors such as negative HASL margins, specific RUC incidents, and the impacts of congestion on capacity decisions.
Clarification on RUC's simultaneous handling of power balance and congestion, using full SCED schedule to optimize resource commitments.
No shift factor cutoff is utilized in the RUC process, and RUC does not prioritize constraints in the same manner SCED does.
Discussions on potential improvements with real-time co-optimization and SOC (State of Charge) impacts on ancillary services procurement.
Discussion on improving the self-commitment process in relation to RUC by identifying a misalignment in opt-out timelines.
Current rules require opting out of RUC two hours prior to the unit startup time, which does not align with operational practices as most RUC instructions are issued with a lead time of two hours or less.
The February RUC report indicates that 83% of RUCs are initiated close to the RUC window, limiting resources' ability to opt out.
A suggested revision is to allow resources to opt out up to the moment they need to start their unit, increasing flexibility for self-commitment.
Discussion on the history and rationale behind the current two-hour cushion for opting out, with a focus on stakeholder compromise to improve alignment with QSE decision making.
Questions raised about the impact of removing the two-hour cushion on operators' actions and its potential effects on the economics and efficiency of the market.
Feedback from stakeholders suggests that the current opt-out window affects both generation and consumer load, with a preference for more dynamic market conditions to ensure better alignment with real-time market movements.
Consensus that allowing more flexibility in opting out would benefit both resources and consumers by freeing up capacity that is otherwise restricted by RUC commitments.
The group is considering proposing a modification to remove the two-hour opt-out buffer, with plans to submit an NPRR if there are no significant concerns from stakeholders.
Presentation on planned outage capacity limits in the MDRPOC by TCPA.
The discussion centered around SB3, passed after the winter storm Uri, granting ERCOT broad discretion to review and approve or deny planned outage requests.
The need for a flexible process allowing ERCOT to manage planned outages with less forced outages, enhancing reliability.
Real-time price signals and competitive market principles should guide the scheduling and movement of planned outages.
Challenges in resource availability, skilled labor shortages, and the adverse impacts of restricting outage periods too narrowly.
Recommendations included transforming MDRPOC as an informational tool, earlier approvals for longer outages, prioritizing major turbine inspections, including ESR capacity, and allowing outage capacity transfers within a QSE.
Debate over the lack of certainty in scheduling outages affecting maintenance requirements and the possibility to spread risk through setting minimum amounts during shoulder seasons.
Discussion emphasized long-term reliability concerns, with the need for maintenance on increasingly aging dispatchable fleet facilities.
Several stakeholders acknowledged the importance of market signals in prompting timely rescheduling of outages.
Fred Huang from ERCOT provided insights into the MDRPOC process and the potential for some methodological changes, with future notices and NPRRs addressing exemptions for TEF units.
Concluded with suggestions on the next steps and a continued dialogue on implementing changes to the MDRPOC process.
Magie Shanks presented on improved methodology for enhanced emergency settlement during price correction events.
The recent analysis of price corrections from August 12 to September 11 showed higher payments through emergency settlement.
The current methodology was found to have room for enhancement, specifically in identifying eligible resources for make-whole payments during price correction events.
The methodology change impacts only resources eligible for the emergency settlement payment.
The previous method assessed all generation resources for emergency operations settlement without determining actual dispatch impact during price correction.
New step added: Resources whose base points remained unchanged between actual SCED and recalculated optimization identified as price takers and ineligible for emergency settlements.
An example provided of a resource with ‘ONTEST’ status, which would not qualify for emergency payments under new methodology due to unchanged base points.
A market notice was sent out regarding a past price correction error where two operating days originally considered for resettlement no longer qualify.
Participants acknowledged the clarification of protocols and discussions on enhancing language clarity in protocol to prevent misunderstandings.
