Discussed the development of the go-live sequence for the program in the next few weeks.
Integrated market readiness into the development plan, focusing on timelines, milestones, and deadlines for issue resolution.
Identified a need to prioritize policy-driven changes that may take up to six months.
Targeted mid-2025 for the initiation of market trials.
Flagged that the discussion on AS proxy offers was not ready for today but planned for the next meeting.
Focused on market readiness and settlements, leaving room for information on demand curves.
Planned a culling process to streamline and prioritize the issues list, currently containing about 20 items.
Developed clarifying NPRRs including a singular RTC (Real-Time Co-optimization) NPRR to capture baseline developments since 2019 and identify gaps found during business requirements.
Shared initial drafts of the NPRR revisions last month, filed with numbers and provided links.
Scheduled to review the NPRR revisions in the next two to three meetings.
Introduced the RTC+B program for understanding and development in future meetings.
Key foundational documents include NPRR1007 through 1013 set in 2019-2020 and supporting documents like operating guide revisions and binding OBDR.
NPRR1204 involves state of charge, 1236 deals with RUC capacity short, and various clarifying NPRRs were discussed.
NPRR1000 related to Dynamically Scheduled Resources is being formally deleted to save testing time.
NPRR1054 removes the Oklaunion exemption settlement calculations transparently.
NPRR1172 includes changes to the RUC clawback.
Implementing sections of NPRR963 that overlap with NPRR1014 for 1014 to work fully, creating an interdependency.
NPRR1058 enables QSEs to update energy offer curves in real-time, going live next week.
Training for RTC+B is planned but not outlined; feedback on critical pieces is welcomed for a future update.
Specifics of RTC+B training are to be developed in the next few weeks. Update will be provided in next month’s meeting.
Clarification on whether the listed NPRRs are exhaustive for the RTC+B scope: Current list is what is known now, but updates will continue as necessary. ERCOT aims to minimize market changes to accommodate this scope.
Questions and Answers:
Participant: Bill Barnes Question: Inquiry about the development and availability of an RTC+B training program for market participants. Response: Training is part of the project, with specifics to be anchored in the next few weeks. A detailed update on training will be provided in next month’s meeting.
Participant: Chris Espinosa Question: Clarification on whether the listed NPRRs are exhaustive for the RTC+B scope. Response: Current list is what is known now, but updates will continue as necessary. ERCOT aims to minimize market changes to accommodate this scope.
Next Steps:
Discussion on NPRRs, simulator update, market submissions, market readiness, and the agenda for the next meeting in September.
3 - Review RTC and ESR Clarifying Revision Requests for Market Questions Dave Maggio/Kenneth Ragsdale
Discussion on revision requests for NPRR1245 and single model changes.
A niche topic related to settlements was identified and presented for NPRR1245.
Magie Shanks presented the DAM Omission Settlement update
While reviewing NPRR1245, an additional necessary edit was discovered.
In section 9.14.10, settlement procedures need to include real-time market clearing prices.
Current language assumes awards for AS are only physical, ignoring real-time reallocations.
Propose changes to settlement section to align with real-time market operations.
Changes will be submitted as comments for consideration at the September PRS.
Presentation included current workflow and proposed changes for ancillary services.
New proposal aligns price calculations between day-ahead and real-time markets.
4 - Issue 3 - RTC Simulator Update verbal update only Raymund Lee
Raymund Lee provided a quick update on the RTC SCED production scale tool.
System-wide limits (RSUF, RSFF, ECRSM) have been formulated.
Implemented logic for NCLRs to self-provide ancillary services, including validation logic.
Core formulation of the problem completed for the first phase.
Development done using small test cases; large scale testing and validation are upcoming.
Intern Luke Gutierrez created a visualization application for tool outputs.
The next steps include testing and validation on larger cases and resolving bugs.
Last meeting discussed the original slides for the simulator scope, confirming it as an ERCOT in-house tool to use ERCOT databases and rerun historical system solutions via RTC.
RTC task force has provided operating days for simulation runs; next phase involves running sample cases and presenting them back to the group.
5 - Issue 9 - Explanation of Market Submission Interface Changes Nathan Smith
Discussion on moving from "AS responsibility" to "AS capability" to represent a resource's total AS capacity available by AS type. Changes in COP allowing negative values for ESRs to account for charging and discharging states.
Explanation of new "AS only offers" for the day-ahead market.
Introduction of ESR energy bid offer curve for RTC+B, DAM, RUC, and SCED, allowing negative megawatt quantities for charging states.
Detailed discussion on resource-specific as offers and their applications in DAM, SASM, RUC, and SCED.
Modifications to the market manager submission UI, including new sub-tabs and drop-down options for DAMs.
Addition of three new parameters for ESRs: minimum state of charge, max state of charge, and round trip efficiency.
Changes to reports: removal of DAM AS insufficiency report and the SASM reports
Replacing DAM AS obligation with DAM Advisory AS Obligations. Adding DAM Final AS obligations report and DAM AS-only Offer Awards report
Discussion on training needs: preference for modular training units with voice-over narration over comprehensive all-day events.
Suggestion to incorporate a bulletin board or FAQ system for addressing participant questions asynchronously.
Matt Mereness explained market submissions and system setup timelines, including the planned go-live in May 2025.
July-August will involve SCED testing and telemetry checkout.
Control room tests will simulate real dispatch scenarios for 2 to 4 hours.
Luminant provided comments and noted the need for short technical workshops at each phase.
Clarifications on QSE attestation and request for at least ten business days advance notice for open or closed loop tests were discussed.
Discussion included avoiding settlement impacts during closed loop tests and allowing QSEs to test their systems during such tests.
Comments from Luminant suggested the need for more detailed internal testing, especially related to non-spin reserves.
ERCOT explained that closed loop tests aim to ensure reliability without financial settlements, suggesting disputes could be raised if financially harmed.
Monica Jha from Vistra expressed concerns about testing non-spin reserves during closed loop testing.
Dave Maggio from ERCOT clarified concerns and suggested further offline discussions to address them.
It was noted that QSE-specific functionalities might need separate testing closer to go-live.
Acknowledge ERCOT's interface specifications as of June 29, 2024.
Acknowledge goal to prepare for market trials as early as May 2025.
Intent was to gauge awareness of deadlines, not to commit to readiness
Scorecard status: Out of 106 entries, only one company (LCRA) is missing.
Yellow status for some in-progress PCs lacking resources but will need to build for both current and RTC systems.
LCRA flagged for modifying attestations, specifically omitting engagement for May 2025 market trials due to uncertainty.
Purpose of attestation emphasized as market readiness awareness.
Update on EMIL-related reports: New data products will be added and modifications shown in a report inventory.
Approximately 50 reports will be added, modified, or deleted.
7 - Issue 18 - Placeholder for MPs Discussion of AS Demand Curves
AS Demand Curves not discussed
7.1 - Indifference Payment Required under RTC to avoid Incentive Incompatibility - Shams Siddiqi
Shams Siddiqi introduced the issue of indifference payment related to RTC design, initially thought to be resolved through NPRR1214.
RTC doesn't provide indifference payment related to Reliability Deployment Price Adder (RDPA) causing incentive incompatibility for resources.
Resources might chase higher RDPA prices instead of following their base points, leading to reliability concerns.
Currently, all resources with available capacity are paid the real-time RDPA ancillary service imbalance amount, creating unnecessary large payments.
Proposed indifference payment based on 0.5*ΔLMP*ΔMW between pricing run and dispatch run deltas to reduce incentives to chase prices
Implementation of NPRR1214 is suggested to be in phases, starting with a grid-wide indifference payment, then introducing locational price signals.
Recommends a further refinement to address AS award differences between the SCED pricing run and dispatch run
In their latest NPRR1214 comments, ERCOT proposed deferring the consideration of NPRR1214 until after RTC implementation, raising concerns about potential severe scarcity events.
Discussion included the need for tools to simulate RDPA price adders and look at the risk of not addressing the indifference payment issue.
Hunt Energy Network recommends pursuing NPRR1214 to implement the indifference payment with RTC implementation, or pursuing a new urgent NPRR to do the same.
8 - Heads-up on Topics for September RTCBTF Meeting Matt Mereness
Topics for September meeting include
Consolidation of list of issues to prioritize most important issues.
Further discussion of the scope of the RTC program.
Update on simulator.
Addressing the load frequency control tests during the market trails plan.
Development of RTC+B training
AS demand curves, which may potentially be discussed at board meeting next week
AS proxy parameters addressing how to set proxy offer prices
Planned a detailed process involving multiple meetings for setting proxy offer prices.
Sought feedback on data or analysis needed to inform proxy offer prices.
Education on the proxy process and its complexities planned.
Addressed clarifications and questions from attendees regarding proxy offers and related protocols.
9 - Issue 8- Mapping of Bill Determinants to Extracts and Reporting for developing Shadow Settlement Magie Shanks
Main goal is to outline the settlement changes under RTC+B.
New charge type for Ancillary Service Only Offers in DAM Settlement Statement.
Day-Ahead Congestion Revenue Rights:
New category for ESRs in pricing for settlement points.
Cost and Pricing Changes:
Energy Offer Curve Cost Caps:
New category for ESRs, affecting DAM and Real-Time Market (RTM) settlements.
ESRs excluded from DAAIEC, impacting Make-Whole Payments.
Real-Time Market (RTM) Changes:
Real-Time HDLO Energy Payment:
ESRs qualify for payment if directed to reduce power.
Set-Point Deviation:
Renamed from Base-Point Deviation; ESR-specific calculations for over/under performance.
Voltage Support Service Payments:
Updates include ESRs, with new intermediate calculations for ESRs.
Emergency Operations Payment:
Includes ESRs, adjusting for their charging side in emergency events.
Switchable Generation Make-Whole Payment:
Updated to include RT Ancillary Service (AS) Revenues.
Real-Time Ancillary Service Settlement:
New charges and payments based on AS Imbalance, AS Only Offers, and AS Trade Overages.
Real-Time Derated AS Capability Charge:
New charge type allocated on LRS basis for RT Derated payments.
Market Suspension and RUC Changes:
Market Suspension Payment:
Includes ESR considerations, allowing submission of actual O&M rates.
Market Suspension Charge:
ESR load removed from LRS allocation for Market Suspension Charges.
RUC Make-Whole Payments and Clawback Charges:
ESRs excluded from RUCMW payments and RUC Clawback Charges.
Includes RT AS revenues in RUC Guarantee calculations.
RUC Decommitment Payment:
ESRs excluded from related Clawback Charges.
RUC Capacity Short:
ESRs included in QSE’s capacity calculation and shortfall determination.
Settlement Statements and Miscellaneous Invoices:
Some charges related to DAM omissions will appear on miscellaneous invoices rather than on settlement statements.
No structural changes will be made to settlement statements; however, new or removed line items will be added.
Extracts will remain the same, but they will reflect new or removed bill determinants.
Handling of Removed Settlement Charges:
Removed settlement charges will still appear on statements for final or true-up settlements, but new charge types will be updated for new operating days.
ESR Price Categories:
ESRs previously included under the “Other” category are now assigned their own category, maintaining the same minimum and maximum prices (negative $20 and $100, respectively).
Any changes to these prices would require a new NPRR.
Settlement Changes for RTC and Non-RTC Related NPRRs:
NPRRs not directly related to RTC or ESR will still be bundled and released with the RTC project.
Market trials are built to the current scope, and any new NPRRs impacting RTC will be adapted as needed.
Market Trials and Settlement Data:
Settlement changes will go live with the RTC+B project, not during market trials, as shadow settlements won't be visible during trials.
There is a plan to release generic, non-QSE-specific settlement data at the beginning of next year to help market participants understand the impact of the changes.
Clarifications on Settlement and NPRR Errors:
Future NPRRs flagged in the issues list are intended to correct errors in the language, not to change the functionality.
Generic statements and extracts will be shared with market participants to illustrate what post-RTC settlement artifacts will look like.
