| 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 |
|
| 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 |
|
| 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 |
|
| NPRR1197 |
Optional Exclusion of Load from Netting at ERCOT-Polled Settlement (EPS) Metering Facilities which Include Resources |
This Nodal Protocol Revision Request (NPRR) adds the ability for Resources to separately meter and settle 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), adds EAP as a type of Constraint Management Plan (CMP) suitable for managing congestion that is resolvable by Security-Constrained Economic Dispatch (SCED), and removes language limiting the application of EAPs to congestion issues for which there exists no feasible SCED. The related NOGRR258 proposes changes that add language to allow the use of EAPs to address congestion that is resolvable by SCED, 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, 3.10.7.4 and 6.5.1.1 |
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 |
|
| 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 |
|
| 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 |
|
| 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 |
|
| 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 |
|
| NPRR1215 |
Clarifications to the Day-Ahead Market (DAM) Energy-Only Offer Calculation |
This Nodal Protocol Revision Request (NPRR) clarifies that the Day-Ahead Market (DAM) Energy-Only Offer credit exposure calculation zeros out negative values, with any zeroed out values being included in the calculation of the dpth percentile difference. This clarification aligns with how ERCOT has been performing the calculation since Nodal Go-Live. |
01/23/2024 |
ERCOT |
No |
4.4.10 |
Pending |
|
| NPRR1216 |
Implementation of Emergency Pricing Program |
This Nodal Protocol Revision Request (NPRR) aligns the Protocols with the Public Utility Commission of Texas (PUCT) Order amending 16 Texas Administrative Code (TAC) § 25.509 in Project No. 54585 (54585 Order), which establishes an Emergency Pricing Program (EPP) for the wholesale electric market as required by Public Utility Regulatory Act (PURA) § 39.160. |
01/23/2024 |
ERCOT |
No |
2.1, 2.2, 4.4.9.3.3, 4.4.11, 4.4.12, 6.8, 6.8.1, 6.8.2, 6.8.3 (delete), 6.8.3.1 (delete), 6.8.3.1.1 (delete), 6.8.3.2 (delete), 6.8.4, and 9.5.3 |
Pending |
|
| NPRR1217 |
Remove Verbal Dispatch Instruction (VDI) Requirement for Deployment and Recall of Load Resources and Emergency Response Service (ERS) Resources |
This Nodal Protocol Revision Request (NPRR) removes the requirement for Load Resources and Emergency Response Service (ERS) Resources to be deployed using a Verbal Dispatch Instruction (VDI) from ERCOT and updates a reference in paragraph (3)(a) of Section 6.5.9.4.1 to be consistent with changes made in NPRR1176, Update to EEA Trigger Levels. |
02/28/2024 |
ERCOT |
No |
2.1, 3.14.3.1, 6.5.9.4.1, 6.5.9.4.2, and 8.1.3.3.3 |
Pending |
|
| NPRR1218 |
REC Program Changes Per P.U.C. SUBST. R. 25.173, Renewable Energy Credit Program |
This Nodal Protocol Revision Request (NPRR) updates Section 14, State of Texas Renewable Energy Credit Trading Program, to comply with P.U.C. SUBST. R. 25.173, Renewable Energy Credit Program. This includes an update of the Renewable Portfolio Standard (RPS) requirement to pertain to only solar renewable energy. |
03/05/2024 |
ERCOT |
No |
1.1, 1.3.1.1, 2.1, 2.2, 14.1, 14.2, 14.3.2, 14.5.2, 14.5.3, 14.6.1, 14.6.2, 14.8, 14.9, 14.9.1, 14.9.2, 14.9.3, 14.9.3.1, 14.9.4, 14.9.5, 14.10.1, 14.10.2, 14.13 |
Pending |
|
| NPRR1219 |
Methodology Revisions and New Definitions for the Report on Capacity, Demand and Reserves in the ERCOT Region (CDR) |
This Nodal Protocol Revision Request (NPRR) changes the methodologies for preparation of the Report on Capacity, Demand, and Reserves in the ERCOT Region (“CDR”) and incorporates a report release schedule. Other changes include new definitions to support the methodology changes and revisions to address outdated terms and add clarity to the methodology descriptions. Finally, Section 16.5.4, Maintaining and Updating Resource Entity Information, is updated to require Switchable Generation Resource (SWGR) owners to provide information on unavailable SWGR units for all seasons rather than just for the summer and winter. A revised SWGR data reporting form will be posted to the ERCOT website. |
03/05/2024 |
ERCOT |
No |
2.1, 2.2, 3.2.6 (new), 3.2.6, 3.2.6.1 (delete), 3.2.6.2 (new), 3.2.6.2 (delete), 3.2.6.2.1 (delete), 3.2.6.2.2 (delete), 3.2.6.3 (new), 3.2.6.4 (new), and 16.5.4 |
Pending |
|
| NPRR1220 |
Market Restart Approval Process Modifications |
This Nodal Protocol Revision Request (NPRR) modifies the Market Restart process. The proposed process requires Technical Advisory Committee (TAC) and ERCOT Board approval, with an alternative mechanism to ERCOT Board approval where circumstances require it. |
03/20/2024 |
ERCOT |
No |
25.3 |
Pending |
|
| NPRR1221 |
Related to NOGRR262, Provisions for Operator Controlled Manual Load Shed |
This Nodal Protocol Revision Request (NPRR) aligns provisions regarding manual and automatic firm Load shed; clarifies the proper use and interplay of Under-Voltage Load Shed (UVLS), Under-Frequency Load Shed (UFLS), and manual Load shed; and addresses reliability concerns ERCOT has identified regarding the extent of Transmission Operators’ (TOs’) manual Load shed capabilities. |
03/20/2024 |
ERCOT |
No |
6.5.9.4.2 |
Pending |
|
| NPRR1222 |
Public Utility Commission of Texas Approval of the Methodology for Determining Ancillary Service Requirements |
This Nodal Protocol Revision Request (NPRR), consistent with ERCOT discussions with the Public Utility Commission of Texas (PUCT), elevates final approval of the Other Binding Document titled, “ERCOT Methodologies for Determining Minimum Ancillary Service Requirements”, from the ERCOT Board of Directors to the PUCT. |
03/20/2024 |
ERCOT |
No |
3.16 |
Pending |
|
| NPRR1223 |
Addition of TA Contact Information Into TDSP Application Form |
This Nodal Protocol Revision Request (NPRR) updates Form J to require Transmission and/or Distribution Service Providers (TDSPs) to provide contact information to ERCOT. |
03/21/2024 |
ERCOT |
No |
23J |
Pending |
|
| NPRR1224 |
ECRS Manual Deployment Triggers |
This NPRR introduces a trigger that ERCOT may use to manually release ERCOT Contingency Reserve Service (ECRS) from Security-Constrained Economic Dispatch (SCED)-dispatchable Resources when the system power balance constraint is consistently violated and the MW amount of the power balance violation is at least 30 MW for ten consecutive minutes. |
03/27/2024 |
ERCOT |
Yes |
6.5.7.6.2.4 |
Pending |
|
| NPRR1225 |
Exclusion of Lubbock Load from Securitization Charges |
This Nodal Protocol Revision Request (NPRR) updates the Protocols to align with the Public Utility Commission of Texas’s (PUCT’s) decisions in PUCT Docket No. 56119, Petition of Electric Reliability Council of Texas, Inc. for Expedited Declaratory Order Regarding Public Utility Regulatory Act Chapter 39, Subchapter N; and Docket No. 56122, Petition of Electric Reliability Council of Texas, Inc. for Expedited Declaratory Order Regarding Public Utility Regulatory Act Chapter 39, Subchapter M. To comply with the PUCT’s declaratory orders, ERCOT changed its Settlement systems to implement the PUCT-ordered exclusions to be effective on or before March 4, 2024, the day on which the transfer of Lubbock Power and Light (LP&L) retail Customers to Retail Electric Providers (REPs) began. This NPRR reflects in the Protocols those exclusions. |
04/11/2024 |
ERCOT |
No |
26.2, 27.3, and 27.5.4 |
Pending |
|
| NPRR1226 |
Demand Response Monitor |
This Nodal Protocol Revision Request (NPRR) creates a Demand Response Monitor to assist Market Participants and ERCOT Operators in making judgements of near-future capacity needs. The Monitor will detect a response by selected Load responses attributable to: Locational Marginal Prices (LMPs); 4-Coincident Peak (4-CP); Near 4-CP; Conservation Alerts; and other ERCOT actions. |
04/23/2024 |
ERCOT Steel Mills |
No |
2.1, 2.2, and 6.5.7.1.13 |
Pending |
|