Eric Goff and Mark Alstrom on behalf of Nextera, Sarah Parsons for Avangrid, and Omar Martino for Invenergy expressed an interest in commenting on Nodal operating guide revision request NOGRR245.
NPRR1197, addressing the optional exclusion of load from netting at ERCOT PD settlement metering facilities, was presented by Colin Martin, vice chair of TAC.
The revision request aims to allow resources to separately meter and settle loads located behind the EPS metering point at the resource's point of interconnection.
The justification for the revision is that netting auxiliary loads can impact the expected performance of the projects, and the proposed language enables a resource to exclude loads from a netting arrangement and settle them with a separate TDSP and load serving entity.
There was one opposing vote from the cooperative segment due to concerns that the revision codifies in the protocols a metering arrangement they had attempted to prohibit in a separate, recently rejected revision request, NPRR1194.
This opposing vote also represents a general objection to how netted loads are treated in protocols in relation to energy storage resources.
ERCOT remains opposed to Comments approved at TAC due to three main reliability concerns: 1) lack of consideration of system reliability when assessing exemptions, 2) potential for indefinite exemptions from ride-through requirements, and 3) timeline of the effective date.
ERCOT would like RMC to remand to TAC to reconsider due to the narrow margin by which NOGRR245 passed.
Eric Goff is solely representing Nextera but sharing the views of the joint commenters
Requesting that RMC approve the TAC recommendation
Emphasized avoidance of retroactive requirements due to chilling effect on investment
Emphasized commercial reasonability as a standard
Sarah Parsons spoke for Avangrid and emphasized regulatory certainty and procedural transparency
Omar Martino for Invenergy spoke, emphasizing the importance of commercial reasonableness and avoiding retroactive requirements for investment decisions
Mark Alstrom for Nextera also spoke in favor of the TAC-approved comments
After robust discussion and questions, NOGRR245 was remanded to TAC with Courtney Hjaltman abstaining and the other three members approving the motion
5 - Recommendation regarding San Antonio South Reliability - Kristi Hobbs
Kristi Hobbs presented the recommendation for an additional reliability project in the San Antonio area, asking for endorsement and designation as critical for reliability
The project involves rebuilding two current 345kV lines, expanding right away, and adding a new substation to increase the region's reliability
The project was recommended unanimously by TAC and designated as critical to the reliability of the ERCOT system
The project is part of a phased approach, with phase one being the CPS South of San Antonio project
It was noted that additional projects may be needed in the future to meet the demands of the state's evolving resource mix
The motion to recommend the project to the board was approved unanimously
Issue with incorrect line series device and transformer ratings identified in January
Implemented a fix on January 30th to ensure correct static ratings for transmission lines
Market notice put out on February 5th
Impact analysis completed on March 12
Three operating days identified for board approval
Issue rooted in new EMs installed in November, now fixed
Motion to approve item 6.1 made and approved
6.2 - Incorrect Constraint Data for GTCs - Woody Rickerson
On February 28th, a routine maintenance process led to the deletion of a constraint in the Market Management System, impacting the real-time market.
The constraint deletion was a result of a downstream production change, which didn't show up in the Energy Management System, leading to market impact.
On March 1st, ERCOT issued a notice for impact analysis, followed by notifying the market on March 18th about the results needed for board review.
Seven counterparties were affected, with the largest impact being $455,000 and an overall impact of $277,000.
The downstream production change process was identified as the root cause, designed to accommodate last-minute system changes, but in this case, an error occurred.
There are approximately 7-8 weekly database loads requiring production changes, which are vulnerable to errors, and their increasing numbers are being monitored.
Recommendations were made to track and control the number of downstream changes and to address them in upcoming meetings.
Motion to approve ERCOT recommendation approved unanimously
Jeff McDonald is the new director of the Independent Market Monitor (IMM) for ERCOT.
He has been focusing on ECRS rule change issues, working collaboratively with PUC and ERCOT staff.
The IMM is also involved in an Ancillary services study, with positive cooperation among all parties.
They are gearing up for more effort in the performance credit mechanism space and preparing the state of the market report, which will be forwarded to the PUC staff for review on May 1st.
There are also less pressing market rule changes that the IMM has been engaged in
Woody Rickerson provided an update on the commercial markets addressing ADERs. He mentioned that there are no new developments in that area and that they continue to work on qualifying it for ECRS.
No new ADERs have been added since the last update.
8.3.1 - Real-Time Co-optimization Update - Matt Mereness
The Real-Time Co-optimization (RTC) involves 75 departments and 150 people, representing a significant operational shift for ERCOT
Progress has been made with technology and security aspects, with regular meetings and code deliveries in progress
Market readiness design issues are being addressed through workshops and engagement with market participants
Key outstanding design issues include RUC capacity shortage and online hydro resources
Discussion on the reshaping of Ancillary service demand curves, with potential policy changes at the PUC level and implications for market trials in May of next year
