ERCOT To Seek Up To 3,000 MW of Generation or Demand Response Capacity for Winter 2023-24 Reliability, RMR

October 2, 2023

Email This Story
Copyright 2010-23 EnergyChoiceMatters.com
Reporting by Paul Ring • ring@energychoicematters.com

The following story is brought free of charge to readers by VertexOne, the exclusive EDI provider of EnergyChoiceMatters.com

ERCOT said in a market notice that, "In accordance with Paragraph (4) of ERCOT Protocols § 6.5.1.1, ERCOT Control Area Authority, ERCOT has identified a need to procure capacity to meet Load and reserve requirements during the winter 2023-24 Peak Load Season."

"This reliability need is informed by several factors, including significant peak Load growth since last winter, recent and proposed retirements of dispatchable Generation Resources (see the lists of Generation Resources below), which have reduced the share of the overall Resource mix represented by dispatchable Generation Resources, and recent extreme winter weather events, including Winter Storm Elliott in December 2022, Winter Storm Uri in February 2021, and the 2018 and 2011 winter storms, each of which resulted in abnormally high demand during winter weather," ERCOT said in a market notice

"Based upon probabilistic analysis, ERCOT has determined that if the ERCOT Region experienced a winter storm during the 2023-24 winter Peak Load Season comparable to Winter Storm Elliott in December 2022, the risk of entering into an Energy Emergency Alert (EEA) during the highest-risk hour (Hour Ending 8 a.m.) would be approximately 19.9%. This would exceed the 10% probability level that constitutes an 'elevated' risk under the standard ERCOT has employed for purposes of its studies conducted in support of NERC’s winter resource adequacy assessments. While ERCOT is not projecting that EEA conditions are likely to occur, ERCOT nevertheless finds this elevated risk of EEA unacceptable. ERCOT has determined that approximately 3,000 MW of additional capacity would be needed to reduce the probability of EEA below this 10% elevated-risk threshold. A summary of ERCOT’s analysis is attached to this Market Notice," ERCOT said in a market notice

"Accordingly, ERCOT intends to seek additional capacity in accordance with ERCOT Protocols § 6.5.1.1(4), which recognizes ERCOT’s 'authority to prevent an anticipated Emergency Condition relating to serving Load in the current or next Season by procuring existing capacity that may be used to maintain ERCOT System reliability in a manner not otherwise delineated in the[] Protocols and the Operating Guides,'" ERCOT said in a market notice

"Based on the risk identified in ERCOT’s analysis, ERCOT intends to issue a request for proposals (RFP) to procure up to 3,000 MW of generation or Demand response capacity for the winter 2023-24 Peak Load Season (December 2023 through February 2024)," ERCOT said in a market notice

ERCOT has released an RFP and governing documents. ERCOT intends to issue an amended RFP and Governing Document by October 23, 2023 following submission of any comments. . Proposals are due Monday, November 6, 2023

"ERCOT will seek capacity from eligible Generation Resources and providers of Demand response that ERCOT deems acceptable for providing the needed capacity. These eligible providers are further identified below. While offers from Generation Resources must comport with the format of the Reliability Must-Run (RMR) Agreement, offers may include a proposed Incentive Factor that reflects the revenues the unit owner determines would be necessary to bring the unit back to operation for the winter Peak Load Season. As such, the Incentive Factor is not necessarily limited to 10%. Providers of eligible Demand response will be eligible to submit offers based on similar principles that are not necessarily constrained by cost," ERCOT said in the notice

ERCOT identified dispatchable Generation Resources as potentially eligible to offer capacity in response to the RFP as including Mothballed Dispatchable Generation Resources (as of December 1, 2023); Seasonally Mothballed Dispatchable Generation Resources (as of December 1, 2023); Dispatchable Generation Resources that have decommissioned since December 1, 2020; and Dispatchable Generation Resources currently in the interconnection queue for which commercial operations could feasibly be accelerated to occur on or between December 1, 2023 and January 9, 2024 while meeting all requirements under ERCOT Protocols and Operating Guides

A listing of the eligible units in the four categories listed above can be found in ERCOT's market notice

Only the active Resource Entity for any of the identified Generation Resources listed in categories 1-4 here (or the Resource Entity’s Qualified Scheduling Entity) or the owner of any of the such-identified decommissioned Generation Resources is eligible to submit the offer on behalf of the Generation Resource.

ERCOT identifies the following potential sources of Demand response that ERCOT considers acceptable for providing the capacity that ERCOT seeks to procure:

1. Customers with peak Demand response capability exceeding one MW that was not price-responsive during the 2022-23 winter Peak Load Season.

2. Aggregations of Customer sites with peak Demand response capability that was not price-responsive during the 2022-23 winter Peak Load Season, including sites with unregistered dispatchable generation that may offset load or inject power into the distribution system, if each aggregation exceeds one MW of peak Demand response.

A Customer or an aggregation of Customer sites will not be considered price-responsive if their Load (including the injection potential associated with any co-located unregistered generation) was observed during at least 90% of the 25 highest-priced intervals in the 2022-23 winter Peak Load Season during the hours for which the Load is being offered.

ERCOT deployments of Demand response will be limited to no more than six hours per deployment with a maximum of three deployments during the Contract Period. When submitting offers to provide Demand response, Customers may choose one or more of the following time periods during which their capacity must be available for deployment:

a. during all hours of every day during the Contract Period,

b. only during Hour Ending 0500 through Hour Ending 1000 of every day during the Contract Period (i.e. the morning hours),

c. only during Hour Ending 1800 through Hour Ending 2300 of every day during the Contract Period (i.e. the evening hours), or

d. Only during both the morning and evening hours of every day during the Contract Period.

ERCOT reserves the right to determine what amounts of Demand response capacity to procure for each of these time periods.

Customers designated as critical Loads are not eligible to provide capacity under this procurement.

Sources of Demand response may be offered by any Entity that has been explicitly authorized in writing by the Customer to provide the Demand response. As described in the RFP and the Governing Document, an Entity must submit a list of the Electric Service Identifiers (ESI IDs) that constitute the Demand response source.

ERCOT will issue a Market Notice on November 23, 2023 identifying the Entities receiving awards along with the relevant MW quantities and prices awarded.

ADVERTISEMENT

ADVERTISEMENT
NEW Jobs on RetailEnergyJobs.com:
• NEW! -- Natural Gas Senior Scheduler -- Retail Supplier
• NEW! -- Pricing Analyst - Retail Power
• NEW! -- Electricity Pricing Analyst -- Retail Supplier
• NEW! -- Business Development Manager -- Retail Supplier
• NEW! -- Call Center Manager -- Retail Supplier
• Senior Billing Subject Matter - (Remote) -- Retail Supplier

HOME

Copyright 2010-23 Energy Choice Matters.  If you wish to share this story, please email or post the website link; unauthorized copying, retransmission, or republication prohibited.