| NPRR956 |
Designation of Providers of Transmission Additions |
This Nodal Protocol Revision Request (NPRR) modifies Section 3.11.4.8 to align with section 37.056 of the Texas Utilities Code, as amended by SB1938 86(R), which became effective on May 16, 2019. As amended, section 37.056 authorizes the Public Utility Commission of Texas (PUCT) to grant a Certificate of Convenience and Necessity (CCN) only to a Transmission Service Provider (TSP) that owns the Facilities to which a proposed Transmission Facility addition will interconnect, or to the lawful designee of such a TSP. If more than one TSP owns Facilities to which a proposed addition will interconnect, the PUCT may issue a CCN to each such TSP to construct the needed Facilities in “separate and discrete equal parts,” unless the TSPs agree to a different allocation of responsibility. SB1938’s allocation of project responsibility based on ownership of the Facilities to which an addition interconnects is consistent with the Protocols’ longstanding assignment of responsibility based on ownership of the Facility endpoints. For the sake of consistency, however, ERCOT proposes to revise Section 3.11.4.8 to more closely comport with the language of the statute. ERCOT notes that revised Section 3.11.4.8 applies not only to those projects requiring a CCN, but also to other Tier 1 projects that may not require a CCN and therefore do not come within the coverage of section 37.056. This is consistent with the Protocols’ existing allocation rules, which have long assigned responsibility for all Tier 1 and 2 projects. ERCOT proposes to incorporate section 37.056’s assignment rules into a new paragraph (2). ERCOT proposes to modify paragraph (1) to recognize that ERCOT’s role, upon completing an independent review, is simply to identify the owners of the existing facilities, rather than to formally designate transmission providers. ERCOT also proposes to remove language from paragraph (1) which contemplates that ERCOT may determine project responsibility in the event of a disagreement between TSPs and may assign responsibility to a new TSP when the originally assigned TSP has not diligently pursued the project. Both of these provisions are inconsistent with SB1938, which contemplates no such role for ERCOT. ERCOT also proposes new paragraph (3), which would establish an explicit mandate that the TSP diligenty pursue the project. Although such a mandate is already implicit in provisions that establish the designation of providers, ERCOT suggests that stating this more explicitly will provide greater transparency that responsibility for a project entails a duty to pursue the completion of that project. ERCOT notes that “TSP” as used in the Protocols includes Municipally Owned Utilities (MOUs) and Electric Cooperatives (ECs). Finally, ERCOT proposes revisions to Section 3.11.4.9, Regional Planning Group Acceptance and ERCOT Endorsement, to provide that ERCOT will issue a Market Notice instead of sending an acceptance letter or endorsement letter, following Regional Planning Group (RPG) acceptance of Tier 3 projects, and ERCOT’s endorsement of Tier 1 and Tier 2 projects. This change will ensure that all TSPs (and other Market Participants) receive documentation showing completion of the ERCOT review process. ERCOT notes that because SB1938 is already effective, ERCOT must comply with the amended statute irrespective of the status of this NPRR. Thus, to the limited extent ERCOT’s existing Protocols conflict with the statute, ERCOT is already precluded from complying with those provisions. ERCOT is currently developing independent review reports for several projects and will ensure that its processes comport with the amended statute as it develops those reports over the next few months. |
07/02/2019 |
ERCOT |
No |
3.11.4.1, 3.11.4.8, 3.11.4.9 |
Pending |
|
| NPRR1070 |
Planning Criteria for GTC Exit Solutions |
This Nodal Protocol Revision Request (NPRR) will improve ERCOT planning modeling assumptions to more accurately reflect operations of the ERCOT market and include indirect benefits as allowed by the Public Utility Commission of Texas (PUCT) when evaluating exit alternatives for Generic Transmission Constraints (GTCs). |
03/05/2021 |
EDF Renewables / Pattern Energy |
No |
3.11.2 |
Pending |
|
| NPRR1162 |
Single Agent Designation for a QSE and its Sub-QSEs for Voice Communications over the ERCOT WAN |
This Nodal Protocol Revision Request (NPRR) amends Section 16.2.1 to require each Qualified Scheduling Entity (QSE) and its Subordinate QSEs to have only one primary and one alternate voice circuit for the purpose of operational voice communications with ERCOT over the ERCOT Wide Area Network (WAN), including, without limitation, receiving and discussing Dispatch Instructions, and amends Section 23, Form F, to reflect the changes made in Section 16.2.1. |
02/10/2023 |
ERCOT |
No |
16.2.1 and 23F |
Pending |
|
| NPRR1170 |
Capturing Natural Gas Delivery Information for Natural Gas Generation Resources |
This Nodal Protocol Revision Request (NPRR) requires Qualified Scheduling Entities (QSEs) to provide information related to the delivery of natural gas to Generation Resources being offered into the market. This required information is deemed to be Protected Information. |
03/29/2023 |
ERCOT |
No |
1.3.1.1 and 4.3 |
Pending |
|
| NPRR1172 |
Fuel Adder Definition, Mitigated Offer Caps, and RUC Clawback |
This Nodal Protocol Revision Request (NPRR) creates a definition for Fuel Adder to provide clarity for which costs are included as routine and predictable versus which costs are exceptional. This NPRR also removes the Mitigated Offer Cap (MOC) multipliers, and creates a 100% clawback for Reliability Unit Commitment (RUC). |
04/11/2023 |
Consumers |
No |
2.1, 3.14.1.2, 3.14.1.20, 4.4.9.4.1, 5.6.1.1, 5.6.1.2, 5.7.2, 6.6.6.2, 6.6.6.9, 6.6.12.1, 9.14.7, 9.14.9, and 25.5.2 |
Pending |
|
| NPRR1179 |
Fuel Purchase Requirements for Resources Submitting RUC Fuel Costs |
This Nodal Protocol Revision Request (NPRR) ensures that Qualified Scheduling Entities (QSEs) representing Generation Resources that have an executed and enforceable transportation contract and file a Settlement dispute to recover their actual fuel costs incurred when instructed to operate due to a RUC, procure fuel economically. This NPRR also adds an adjustment to the RUC Guarantee to reflect the cost difference between the actual fuel consumed by the Resource to start and operate during the RUC-Committed Intervals and the fuel burn calculated based on Verifiable Cost parameters. Finally, the NPRR clarifies that fuel costs may also include penalties for fuel delivery outside of RUC-Committed Intervals in accordance with the ratable delivery obligations and costs as specified in the enforceable transportation agreement. |
05/04/2023 |
ERCOT |
Yes |
9.14.7 |
Pending |
|
| NPRR1180 |
Inclusion of Forecasted Load in Planning Analyses |
This Nodal Protocol Revision Request (NPRR) revises the Protocols to address recent amendments to P.U.C. SUBST. R. 25.101, Certification Criteria, which became effective on December 20, 2022. Specifically, NPRR1180 incorporates the requirement in P.U.C. SUBST. R. 25.101(b)(3)(A)(ii)(II) for any reliability-driven transmission project review conducted by ERCOT to incorporate the historical Load, forecasted Load growth, and additional Load seeking interconnection, in the ERCOT independent review. NPRR1180 also requires a Regional Planning Group (RPG) project submitter to provide such information to ERCOT, when available, for inclusion in ERCOT’s project analysis. |
05/11/2023 |
Oncor |
No |
3.11.4.1, 3.11.4.6, 3.11.4.7, 3.11.4.9 |
Pending |
|
| NPRR1181 |
Submission of Coal and Lignite Inventory Notifications |
This Nodal Protocol Revision Request (NPRR) creates a new requirement for Qualified Scheduling Entities (QSEs) representing coal or lignite Generation Resources to submit to ERCOT a Seasonal declaration of coal and lignite inventory levels. The NPRR also adds requirements for the QSEs to notify ERCOT when coal or lignite inventory drops below target and critical levels. |
05/16/2023 |
ERCOT |
No |
1.3.1.1, 3.24 and 22P |
Pending |
|
| NPRR1186 |
Improvements Prior to the RTC+B Project for Better ESR State of Charge Awareness, Accounting, and Monitoring |
This NPRR is the first of two NPRRs that ERCOT has prepared to improve the awareness, accounting, and monitoring of the State of Charge (SOC) for an ESR. This particular NPRR is for the interim period which is described as the time period before the RTC+B project goes live. The target go-live date for the RTC+B project is expected to be several years away and the language and changes in this first NPRR are aimed to strategically improve SOC awareness, accounting, and monitoring with minimal system changes so that the improvements can be in place while the RTC+B project is completed. This NPRR does NOT specify that ERCOT manage the SOC for an ESR. It specifies existing and new information to be provided by the QSE so that ERCOT can better understand each ESR’s current energy capability and expected energy capability in future hours. Grey-boxed language related to DC-Coupled Resources was not revised with this NPRR. |
06/22/2023 |
ERCOT |
Yes |
2.1, 2.2, 3.8.1, 3.9.1, 4.5.1, 5.5.2, 6.3.2, 6.4.9.2.2, 6.5.5.2, 6.5.7.2, and 8.1 |
Pending |
|
| NPRR1188 |
Implement Nodal Dispatch and Energy Settlement for Controllable Load Resources |
This Nodal Protocol Revision Request (NPRR) changes the dispatch and pricing of Controllable Load Resources (CLRs) in response to items in Phase 1 of Public Utility Commission of Texas’ (PUCT’s) market design blueprint related to demand response and increasing the “...utilization of load resources for grid reliability”. Specifically, this NPRR is focused on the blueprint language discussing the pursuit of “…market modifications and technical measures to improve transparency of price signals for load resources, such as changing demand response pricing from zonal to locational marginal pricing (LMP)”. To address the above directive from the PUCT, this NPRR changes the market participation model for CLRs that are not Aggregate Load Resources (ALRs) such that they are dispatched at a nodal shift factor and settled for their energy consumption at a nodal price. |
06/27/2023 |
ERCOT |
No |
1.3.1.1, 2.1, 2.2, 3.2.5, 3.6.1, 3.9.1, 4.2.4, 4.4.7.2, 4.4.9.8, 4.4.9.8.1, 4.4.9.8.2, 4.4.10, 4.5.1, 4.5.3, 4.6.2.2, 4.6.2.3.2, 6.3.1, 6.4.3, 6.4.3.1, 6.4.3.1.1, 6.4.3.1.2, 6.5.7.3, 6.5.7.3.1, 6.5.7.4, 6.5.7.5, 6.5.7.6.2.3, 6.6.1.2, 6.6.1.4, 6.6.3.1, 6.6.3.2, 6.6.5.1, 6.6.5.6, 7.9.1.3, 7.9.3.1, 8.1.1.1, 8.1.1.4.3, 9.14.10, 9.19.1, 10.2.2, 10.2.3, 10.3.2.3, 11.1.6, 16.11.4.1, 16.11.4.3.2, and 26.2 |
Pending |
|
| NPRR1190 |
High Dispatch Limit Override Provision for Increased NOIE Load Costs |
This Nodal Protocol Revision Request (NPRR) adds a provision for recovery of a demonstrable financial loss arising from a manual High Dispatch Limit (HDL) override to reduce real power output, in the case when that output is intended to meet NOIE load obligations. |
07/26/2023 |
Joint Sponsors |
No |
3.8.1 and 6.6.3.6 |
Pending |
|
| NPRR1191 |
Registration, Interconnection, and Operation of Customers with Large Loads; Information Required of Customers with Loads 25 MW or Greater |
This Nodal Protocol Revision Request (NPRR) and the related PGRR, NOGRR, and RRGRR establish registration, interconnection, and operational requirements for Customers with “Large Loads”—defined in this NPRR to refer to Facilities with an aggregate peak power Demand of 75 MW or more. ERCOT proposes these requirements based upon its experience with the interim large Load interconnection process implemented on March 25, 2022, analysis of operational events, and the discussion of various issues concerning Large Loads explored by the Large Flexible Load Task Force (LFLTF). Although the primary focus of this NPRR is Loads that are 75 MW or larger, this NPRR also requires a Customer with an aggregate peak Demand of 25 MW or more at a site behind one or more common Points of Interconnection (POIs) or Service Delivery Points to provide ERCOT with information and Load parameter data that is specified in the accompanying RRGRR. |
08/01/2023 |
ERCOT |
No |
2.1, 2.2, 3.1.1, 3.1.5.11, 3.2.6.2.1, 3.3.2, 3.15, 3.15.3, 3.22, 3.22.1, 3.22.1.1, 3.22.1.2, 3.22.1.3, 3.22.1.4 (new), 3.22.1.4, 3.22.2, 3.22.3, 6.5.7.3.1, 6.5.7.12 (new), 6.5.9.4.1, 16.20 (new), 16.20.1 (new), 23R (new), ERCOT Fee Schedule |
Pending |
|
| NPRR1192 |
Move OBD to Section 22 – Requirements for Aggregate Load Resource Participation in the ERCOT Markets |
This Nodal Protocol Revision Request (NPRR) incorporates the Other Binding Document “Requirements for Aggregate Load Resource Participation in the ERCOT Markets” into the Protocols. |
08/08/2023 |
ERCOT |
No |
6.5.7.6.2.3, 8.1.1.2, 10.9, and 22 Attachment O (new) |
Pending |
|
| NPRR1193 |
Related to SMOGRR027, Move OBD to Settlement Metering Operating Guide – EPS Metering Design Proposal |
This Nodal Protocol Revision Request (NPRR) changes the referenced location of the EPS Design Proposal Form, as it is moving from the Other Binding Document List into the Settlement Metering Operating Guide (SMOG). |
08/09/2023 |
ERCOT |
No |
10.4.2 |
Pending |
|
| NPRR1194 |
Wholesale Storage Load Auxiliary Netting |
This Nodal Protocol Revision Request (NPRR) corrects current Protocol language that incorrectly allows netting of auxiliary Loads at storage facilities that avail themselves of Wholesale Storage Load (WSL) treatment. |
08/16/2023 |
STEC |
No |
10.2.4, 10.3.2.3, 11.1.6 |
Pending |
|
| NPRR1195 |
Resource Entity Metering Facilities Maintenance |
This Nodal Protocol Revision Request (NPRR) assigns ERCOT-Polled Settlement (EPS) Metering Facilities maintenance and repair responsibilities to the owner of the Metering Facilities when such is not owned by a Transmission and/or Distribution Service Provider (TDSP). |
08/17/2023 |
STEC |
No |
10.8.1.1, 10.8.1.2, and 10.9.1 |
Pending |
|
| NPRR1196 |
Correction of NCLR Ancillary Service Failed Quantity Calculations under NPRR1149 |
This Nodal Protocol Revision Request (NPRR) makes corrections and updates to equations used to determine Ancillary Service Failed Quantity calculations for Load Resources other than Controllable Load Resources (“NCLRs”) which were developed under NPRR1149, Implementation of Systematic Ancillary Service Failed Quantity Charges. Specific Protocol changes include: updates to the calculation of Ancillary Service Failed Quantities to account for the allowances and restrictions on Ancillary Services that NCLRs can and cannot carry simultaneously with the implementation of ERCOT Contingency Reserve Service (ECRS); updates to specify the snapshot components to be used for the “Telemetered Ancillary Service for the NCLRs As Calculated” variable; and inclusion of an additional non-zero check to be added for the “Telemetered ECRS Responsibility for the Resource As Calculated” variable. |
08/24/2023 |
ERCOT |
No |
6.7.3 |
Pending |
|
| NPRR1197 |
Energy Storage Resource (ESR) Non-Charging Load(s) Optional Exclusion from EPS Netting Arrangement |
This Nodal Protocol Revision Request (NPRR) adds the ability for an Energy Storage Resource (ESR) to separately meter and settle non-charging Load(s) located behind the EPS metering point at the Resource’s POI. |
08/31/2023 |
Engie |
No |
10.3.2.3 and 11.1.6 |
Pending |
|
| NPRR1198 |
Congestion Mitigation Using Topology Reconfigurations |
This Nodal Protocol Revision Request (NPRR) defines Extended Action Plan (EAP), revises the defined term Remedial Action Plan (RAP), adds EAP and RAP as types of Constraint Management Plan (CMP) suitable for the market use of the ERCOT Transmission Grid, and removes language limiting the application of these CMPs to congestion issues for which there exists no feasible Security-Constrained Economic Dispatch (SCED) solution. The related NOGRR258 proposes changes that add language to allow the use of RAPs and EAPs to facilitate the market use of the ERCOT Transmission Grid, adds guardrails to ensure that topology reconfiguration requests meet basic reliability and economic criteria, and defines the process for submission, review, and approval of EAPs. This NPRR and NOGRR258 leverage ERCOT’s existing CMP process to quickly mitigate critical transmission congestion impacts by establishing a scalable process for topology reconfiguration requests that is transparent, predictable, equitable, workable, reliable, and compatible with existing planning processes. ERCOT already leverages topology optimization in the CMP processes. Since NPRR529, Congestion Management Plan was introduced in 2013 with the limitations that this NPRR proposes to revise, the power industry has evolved and there have been technological improvements that make transmission topology reconfigurations a powerful option to mitigate congestion beyond just use cases for which there is no feasible SCED solution. |
08/31/2023 |
EDF Renewables, Inc. |
No |
2 and 6.5.1.1 |
Pending |
|
| NPRR1199 |
Implementation of Lone Star Infrastructure Protection Act (LSIPA) Requirements |
This Nodal Protocol Revision Request (NPRR) revises the Protocols to reflect new requirements added to the LSIPA as part of Senate Bill (SB) 2013 during the 88th regular legislative session. Specifically, this NPRR makes the following changes to the Protocols: adds definitions of “Critical Electric Grid Equipment,” “Critical Electric Grid Services,” “Lone Star Infrastructure Protection Act (LSIPA) Designated Company,” and “Lone Star Infrastructure Protection Act (LSIPA) Designated Country” to Section 2.1; adds paragraph (5) to Section 16.1.3, reflecting ERCOT’s statutory authorization, established in SB 2013, to immediately suspend or terminate a Market Participant’s registration or access to any of ERCOT’s systems if ERCOT has a reasonable suspicion that the Entity meets any of the criteria described by Section 2274.0102(a)(2), Government Code, as added by Chapter 975 (S.B. 2116), Acts of the 87th Legislature, Regular Session, 2021; adds Section 16.1.4, establishing new reporting and attestation requirements for Critical Electric Grid Equipment and Critical Electric Grid Services procurements by Market Participants and entities that seek to register as Market Participants; amends Section 23 to add Form R, which shall be used by Market Participants and applicants for Market Participant registration to comply with the reporting and attestation requirements in Section 16.1.4; updates Section 16.1.3 and Section 23, Form Q using the new defined terms, where appropriate; and amends Section 1.3.2.1 to provide that certain information submitted on Form R shall constitute ERCOT Critical Energy Infrastructure Information (ECEII) under the Protocols. |
09/06/2023 |
ERCOT |
No |
1.3.2.1, 2.1, 2.2, 16.1.3, 16.1.4 (new), 23Q, and 23R (new) |
Pending |
|
| NPRR1200 |
Utilization of Calculated Values for Non-WSL for ESRs |
This Nodal Protocol Revision Request (NPRR) permits Energy Storage Resources (ESRs) with unmetered non-Wholesale Storage Load (WSL) from system protection equipment such as current-limiting reactors to utilize calculated auxiliary Load values when the non-WSL from the protective equipment is less than 15 kWh per charge cycle. |
09/14/2023 |
NextEra Energy |
No |
10.2.4 |
Pending |
|
| NPRR1201 |
Limitations on Resettlement Timeline and Default Uplift Exposure Adjustments |
This Nodal Protocol Revision Request (NPRR) reduces exposures for both ERCOT and Market Participants for resettlements and Default Uplift Invoices for historical Operating Days. This NPRR limits timeline for resettlement due to errors that are discovered, and a Market Notice of the error is provided to Market Participants, within one year after the Operating Day. This limit does not apply to resettlement due to an Alternative Dispute Resolution, a Procedure for Return of Settlement Funds, or a resettlement directed by the Board of Directors to address unusual circumstances; and adjusts the Maximum MWh Activity formula in Section 9.19.1 to only consider Congestion Revenue Rights (CRRs) owned during the Operating Days of the reference month, and to not consider CRRs that may have been bought or sold for the month, but are no longer owned on the given Operating Days of the reference month. |
09/20/2023 |
ERCOT |
No |
9.2.5, 9.5.6, and 9.19.1 |
Pending |
|
| NPRR1202 |
Refundable Deposits for Large Load Interconnection Studies |
This Nodal Protocol Revision Request (NPRR) directs ERCOT to charge refundable deposits to Entities that request a Large Load Interconnection Study (LLIS). |
09/22/2023 |
Lancium |
Pending |
2.1, 3.24 (new), and ERCOT Fee Schedule |
Pending |
|
| NPRR1204 |
Considerations of State of Charge with Real-Time Co-Optimization Implementation |
This Nodal Protocol Revision Request (NPRR) implements the State of Charge (SOC) concepts necessary for awareness, accounting, and monitoring of SOC for ESRs within the RTC+B implementation and allow the design to evolve from the interim solutions being proposed under NPRR1186. |
10/10/2023 |
ERCOT |
Yes |
2.1, 3.2.5, 3.7.1.3, 3.9.1, 5.5.2, 5.8, 6.3.2, 6.4.9.1.1, 6.5.7.3, and 6.5.7.5 |
Pending |
|
| NPRR1205 |
Revisions to Credit Qualification Requirements of Banks and Insurance Companies |
This Nodal Protocol Revision Request (NPRR) strengthens ERCOT’s market entry eligibility and continued participation requirements for ERCOT Counter-Parties (i.e., Qualified Scheduling Entities (QSEs) and Congestion Revenue Right (CRR) Account Holders). Specific changes include strengthening and clarifying minimum credit quality qualifications for: Banks, which issue letters of credit on behalf of Market Participants to ERCOT; and Insurance companies, which issue surety bonds on behalf of Market Participants to ERCOT. |
10/24/2023 |
ERCOT |
No |
16.11.3 |
Pending |
|
| NPRR1206 |
Revisions to QSE Operations and Termination Requirements, and Elimination of Providing Certain Market Participant Principal Information |
This Nodal Protocol Revision Request (NPRR) clarifies the types of Qualified Scheduling Entities (QSEs) required to have a Hotline and a 24-hour, seven-day-per-week (24x7) control or operations center. This NPRR also reconciles: (1) the deadline by which QSEs representing Resource Entities that own or control Resources must provide notice that they are terminating their representation; and (2) the deadline for Resource Entities that own or control Resources to change QSEs by proposing a 45-day timeline by which a QSE representing a Resource must give notice of the effective Termination Date, and clarifies that the Resource Entity’s change in QSE designation takes 45 days to become effective in the Network Operations Model. In addition, this NPRR also eliminates the requirement to provide certain unnecessary Market Participant Principal information. Finally, this NPRR proposes the deletion of duplicative language concerning the authority of a registered Data Agent-Only QSE, and further phases out acceptance of paper checks and the use of communication via fax. |
10/25/2023 |
ERCOT |
No |
2.1, 16.2.1, 16.2.1.2, 16.2.3.2, 16.2.3.3, 16.3.4, 16.5.1.1, 16.5.3, 16.5.4, 16.8.3.1, 23 Form A, 23 Form B, 23 Form E, 23 Form G, 23 Form I, 23 Form J, 23 Form M |
Pending |
|
| NPRR1207 |
Incidental Disclosure of Protected Information and ECEII During ERCOT Control Room Tours |
This Nodal Protocol Revision Request (NPRR) would permit the incidental disclosure of Protected Information and ERCOT Critical Energy Infrastructure Information (ECEII) as part of a tour or overlook viewing of the ERCOT control room provided to eligible persons who, prior to accessing the control room, have signed nondisclosure agreements (“NDAs”) and complied with screening and other requirements provided in a policy adopted by ERCOT security. The policy will include a prohibition on taking photographs and recordings of Protected Information and ECEII. This NPRR would also exempt ERCOT from the requirement to provide notice of disclosure when ECEII or Protected Information is incidentally disclosed as part of a Control Room tour or overlook viewing, consistent with the conditions described above. This exception does not apply to a person who is a director, officer, employee, agent, representative, contractor, or consultant of a Market Participant that is registered with ERCOT as a Resource Entity, Qualified Scheduling Entity (QSE), Load Serving Entity (LSE), or Congestion Revenue Right (CRR) Account Holder. |
11/01/2023 |
ERCOT |
No |
1.3.5 and 1.3.6 |
Pending |
|
| NPRR1208 |
Creation of Invoice Report |
This Nodal Protocol Revision Request (NPRR) creates a new daily report, the ERCOT Invoice Report, which lists the ERCOT Invoices issued for the current day and day prior at a Counter-Party level. |
11/06/2023 |
Reliant Energy |
No |
9.20 (new) |
Pending |
|
| NPRR1209 |
Board Priority – State Of Charge Ancillary Service Failed Quantity Allocations under NPRR1149 |
This NPRR makes updates to language introduced by NPRR1149, Implementation of Systematic Ancillary Service Failed Quantity Charges, by providing the equations and the priority order to be used to consider Energy Storage Resource (ESR) Real-Time State of Charge (SOC) data when determining Ancillary Service Failed Quantity Charges for a Qualified Scheduling Entity (QSE) after each Operating Day. Under this NPRR, SOC insufficiencies will be reflected in adjustments to the telemetered Ancillary Service Resource Responsibilities for the ESR. These adjusted values will then be used in Ancillary Service failed quantity calculations for a QSE’s portfolio when performing the after-the-fact analysis. The adjusted Ancillary Service Resource Responsibilities for a QSE’s ESRs due to SOC insufficiency will be calculated separately for ‘Up’ and ‘Down’ Ancillary Services by the Energy Management System (EMS). These calculations will be used by the Market Management System (MMS) to allocate failed quantity charges at the QSE level for individual Ancillary Services. |
11/08/2023 |
ERCOT |
Yes |
6.7.3 |
Pending |
|
| NPRR1210 |
Next Start Resource Test and Load-Carrying Test Frequency |
This Nodal Protocol Revision Request (NPRR) changes the frequency of the Next Start Resource Test and the Load-Carrying Test respectively from once every five years to once every four calendar years. |
11/15/2023 |
ERCOT |
No |
8.1.1.2.1.5 |
Pending |
|
| NPRR1211 |
Move OBD to Section 22 – Methodology for Setting Maximum Shadow Prices for Network and Power Balance Constraints |
This Nodal Protocol Revision Request (NPRR) incorporates the Other Binding Document “Methodology for Setting Maximum Shadow Prices for Network and Power Balance Constraints” into the Protocols. |
11/20/2023 |
ERCOT |
No |
4.5.1, 6.4.9.2.2, 6.5.7.1.11, and 22Q (new) |
Pending |
|
| NPRR1212 |
Clarification of Distribution Service Provider’s Obligation to Provide an ESI ID |
This Nodal Protocol Revision Request (NPRR) revises Section 10.3.2 to clarify the obligation of a Distribution Service Provider (DSP) to provide ERCOT with an Electric Service Identifier (ESI ID) for a Resource site that consumes Load other than Wholesale Storage Load (WSL) and that is not behind a Non-Opt-In Entity (NOIE) tie meter. |
11/22/2023 |
ERCOT |
No |
2.1, 10.3.2, 10.3.2.1, 10.3.2.1.2, 10.3.2.1.3 |
Pending |
|
| NPRR1213 |
Allow DGRs and DESRs on Circuits Subject to Load Shed to Provide ECRS |
This Nodal Protocol Revision Request (NPRR) amends requirements for Distribution Generation Resources (DGRs) and Distribution Energy Storage Resources (DESRs) that are seeking qualification to provide ERCOT Contingency Reserve Service (ECRS), as follows: • Paragraph (1)(c) of Section 3.8.6 allows for DGRs and DESRs on circuits subject to disconnection during Load shed events to provide ECRS; and • Section 3.16 recognizes that ERCOT will establish limits on ECRS, which may be provided by DGRs/DESRs on circuits subject to disconnection during Load shed events. |
11/28/2023 |
Enchanted Rock |
No |
3.8.6 and 3.16 |
Pending |
|
| NPRR1214 |
Reliability Deployment Price Adder Fix to Provide Locational Price Signals, Reduce Uplift and Risk |
This Nodal Protocol Revision Request (NPRR) revises the Real-Time On-Line Reliability Deployment Price Adder (RTRDPA) to: send appropriate locational price signals to avoid counterproductive Load and Resource responses to current RTRDPA price signals; limit Resource payment to the actual “indifference payment” (consistent with its definition), thereby reducing associated uplift by eliminating current RTRDPA payments to Resources that exacerbate constraints and eliminating payments to available capacity not requiring an indifference payment; eliminate Ancillary Service Imbalance Payments or Charges (ASIP/C) associated with RTRDPA, thereby reducing the risk associated with providing Ancillary Services; provide Resources an indifference payment under Real-Time Co-optimization (RTC) to eliminate the potentially large incentive to ignore Base Point instructions; and provide a stronger locational price signal around Resources committed by the Reliability Unit Commitment (RUC) process or other reliability actions for congestion, thereby reducing RUC Make-Whole Payment-related charges and uplifts and appropriately compensating impacted Qualified Scheduling Entities (QSEs). |
12/07/2023 |
Joint Sponsors |
No |
6.5.7.3.1, 6.7.5, 6.7.6, 6.9 (new), 6.9.1 (new), and 6.9.2 (new) |
Pending |
|