| 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 |
|
| 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 RTRDPA price signals under Real-Time Co-optimization (RTC); limit Resource payment to the actual “indifference payment” (consistent with its definition), thereby reducing associated uplift by eliminating the future need for RTRDPA payments to Resources that exacerbate constraints and eliminating payments to available capacity not requiring an indifference payment; eliminate any future need for the Ancillary Service Imbalance Payments or Charges (ASIP/C) type of indifference payment associated with RTRDPA, thereby reducing the risk associated with providing Ancillary Services; provide Resources an indifference payment under RTC to eliminate the potentially large incentive to ignore Base Point instructions that would likely cause serious reliability issues; 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 |
2.1, 3.2.5, 3.5.2.1, 3.5.2.2, 3.5.2.3, 3.5.2.4, 3.5.2.5, 3.5.2.6, 3.5.2.7, 4.4.11, 5.5.2, 5.7.1.3, 5.7.1.4, 6.3.2, 6.5.7.3, 6.5.7.3.1, 6.5.9.2, 6.6.1.1, 6.6.1.2, 6.6.1.6, 6.6.1.7 (delete), 6.6.3.1, 6.6.3.6, 6.6.3.8, 6.6.6.3, 6.6.6.10, 6.7.5, 6.7.6, 6.9 (new), 6.9.1 (new), 6.9.2 (new), and 9.5.3 |
Pending |
|
| NPRR1255 |
Introduction of Mitigation of ESRs |
This Nodal Protocol Revision Request (NPRR) introduces Mitigated Offer Cap (MOC) curves below the System-Wide Offer Cap (SWCAP) for Energy Storage Resources (ESRs) when the Resource, through its Qualified Scheduling Entity (QSE), has the potential to exploit market power, as evaluated in the Security-Constrained Economic Dispatch (SCED) Constraint Competitiveness Test (CCT) process. |
10/02/2024 |
ERCOT |
No |
3.8.5, 4.4.9.4.1 |
Pending |
|
| NPRR1272 |
Voltage Support at Private Use Networks |
This Nodal Protocol Revision Request (NPRR) clarifies that Section 3.15 should be applied to require ERCOT to independently evaluate the Reactive Power requirements of Generation Resources excluding the effects of co-located retail load. As such, any Generation Resources that meet the requirements of the Protocols as standalone Generation Resources shall not have additional Reactive Power requirements imposed as a result of co-locating with load. Further, the language clarifies that the onsite load must also comply with the power factor requirements for retail Customers in the applicable tariff for retail delivery service. |
02/05/2025 |
Occidental Chemical Corporation |
No |
3.15 |
Pending |
|
| NPRR1278 |
Establishing Advanced Grid Support Service as an Ancillary Service |
This Nodal Protocol Revision Request (NPRR) creates an Advanced Grid Support Service (AGSS), which will incent Inverter-Based Resources (IBRs), particularly Energy Storage Resources (ESRs), to provide valuable stability support to the ERCOT grid and will do so more quickly and efficiently than a mandate, as qualifications are clearly stated, without punitive and unclear compliance mechanisms, which may slow technology growth altogether. This NPRR defines Resource capabilities and provides for compensation based on an annual bidding process, similar to Black Start Service (BSS). |
03/30/2025 |
Joint Sponsors |
No |
2.1, 2.2, 3.14, 3.14.6 (new), 6.6.15 (new), 6.6.15.1 (new) 6.6.15.5 (new), 8.1.1.2.1.8 (new), 16.20 (new), 22Q (new), and 22R (new) |
Pending |
|
| NPRR1286 |
Establish Multi-Value Criteria for Resiliency-Related Transmission Project Evaluation |
This Nodal Protocol Revision Request (NPRR) establishes new planning criteria to address the process for determining whether a project that addresses a resiliency issue provides sufficient benefit balanced with economic savings or reliability benefits, in accordance with 16 Texas Administrative Code (TAC) § 25.101(b)(3)(A)(iii). Cleanups are also included in Section 3.11.2 to address the inconsistent use of terminology and delete certain obsolete language. |
05/21/2025 |
ERCOT |
No |
3.11.2 |
Pending |
|
| NPRR1292 |
Granular Product Type for CRR TOU |
This Nodal Protocol Revision Request (NPRR) creates the granular Congestion Revenue Right (CRR) Time Of Use (TOU) blocks to align with the current resource mix and improve auction speed and efficiency. Currently, CRRs are traded as weekday/weekend peak and off-peak, with no opportunity to further shape hedges. More granular CRR TOU blocks will divide weekday/weekend peak between solar and non-solar hours, providing a more targeted hedging product. |
07/22/2025 |
Vistra |
No |
7.3, 7.5.5.3, and 16.11.4.5 |
Pending |
|
| NPRR1295 |
GTC Exit Solutions |
This Nodal Protocol Revision Request (NPRR) establishes new planning criteria to address the process for improving Generic Transmission Limits (GTLs) or resolving Generic Transmission Constraints (GTCs) when evaluating GTC exit solutions. |
08/19/2025 |
Joint Sponsors |
No |
3.11.2 |
Pending |
|
| NPRR1296 |
Residential Demand Response Program |
This Nodal Protocol Revision Request (NPRR) implements a Residential Demand Response (RDR) Program for Retail Electric Providers (REPs) and Non-Opt-In Entities (NOIEs). |
08/26/2025 |
ERCOT |
No |
2.1, 2.2, 3.6.1, 3.7.1.2, 3.14.3.1, 3.14.3.4, 3.14.4, 3.26 (new), 3.26.1 (new), 3.26.2 (new), 3.26.3 (new), 3.26.4 (new), 3.26.5 (new), 6.9 (new), 6.9.1 (new), 6.9.2 (new), 6.9.3 (new), 8.1.4 (new), 8.1.4.1 (new), 8.1.4.2 (new), 8.1.4.3 (new), 8.1.4.4 (new), 9.5.3, 9.5.13 (new), and 22O |
Pending |
|
| NPRR1301 |
Align Protocols to Constraint Activation Procedure |
This Nodal Protocol Revision Request (NPRR) aligns the Protocols to ERCOT’s Transmission Security and Operating Procedure for constraint activation. |
09/12/2025 |
LCRA |
No |
22P |
Pending |
|
| NPRR1310 |
Dispatchable Reliability Reserve Service Plus Energy Storage Resource Participation and Release Factor |
This Nodal Protocol Revision Request (NPRR) develops Dispatchable Reliability Reserve Service (DRRS) as a new Ancillary Service. |
11/20/2025 |
ERCOT |
Yes |
2.1, 2.2, 3.2.3, 3.9.1, 3.17.5 (new), 3.18, 4.4.7.1, 4.4.7.2, 4.4.7.3, 4.4.12, 4.5.1, 4.6.2.3, 4.6.2.3.1, 4.6.4.1.6 (new), 4.6.4.2.6 (new), 5.5.2, 5.6.2, 5.7.1, 5.7.1.1, 5.7.1.2, 5.7.1.3, 5.7.1.4, 5.7.2, 5.7.4.1.1, 6.1, 6.5.7.3, 6.5.7.3.1, 6.5.7.5, 6.5.7.6.2.5 (new), 6.6.1.6, 6.6.9.1, 6.6.12.1, 6.7.1, 6.7.2.7 (new), 6.7.2.7, 6.7.2.8, 6.7.3, 8.1.1.2.1.8 (new), 8.1.1.3.5 (new), 8.1.1.4.5 (new), 9.2.3, 9.14.10, 9.19.1, 16.11.4.3.1, and 16.11.4.3.2 |
Pending |
|
| NPRR1312 |
Revisions to the Standard Form Agreement (SFA) |
This Nodal Protocol Revision Request (NPRR) amends the Standard Form Market Participant Agreement (“SFA”) for several reasons (see Justification for Revision below) and transfers certain sections of the SFA to the Protocols. Specifically, this NPRR: • Clarifies the definition of the ERCOT Protocols; • Establishes a new section regarding Notice, and modernizes the Notice language; • Transfers Breach and Default language from the SFA to the Protocols; • Amends the definition of a Force Majeure Event; • Amends sections in the SFA to conform with the Texas Supreme Court’s rulings in CPS Energy v. ERCOT; and • Amends the Standard Form Black Start Agreement and Standard Form Must Run Agreement to algin with revisions to the SFA by eliminating any duplicative language. |
11/26/2025 |
ERCOT |
No |
1.1, 1.7, 1.8 (new), 1.10 (new), 2.1, 16.2.6.1, 16.20 (new), 16.20.1 (new), 16.20.2 (new), 16.21 (new), 16.3, 20.1, 20.6, 22A, 22B, 22D, and 22E |
Pending |
|
| NPRR1317 |
Creation of Non-Settled Generator (NSG) and Clarification of the Types, Usage, and Registration of Distributed Generation |
This NPRR clarifies the term “Distributed Generation” (DG) and, introduces the categories of “Distributed Generation,” which include: Unregistered Distributed Generator; Distribution Generation Resource; Settlement Only Distribution Energy Storage System; Settlement Only Distribution Generator; and Non-Settled Distribution Generator. This NPRR also clarifies the Resource registration process for Resource Entities. Additionally, this NPRR updates DG interconnection, registration, and reporting requirements to ensure consistency throughout the ERCOT System as it relates to DG. |
12/19/2025 |
ERCOT |
No |
1.6, 1.6.5, 2.1, 2.2, 3.1.4.3, 3.1.5.1, 3.6.2, 3.8.1, 3.8.7, 3.8.9, 3.10.7.2, 3.14.1, 3.14.1.8, 3.14.1.9, 3.14.1.10, 3.14.1.19, 3.14.4.1, 3.15, 6.5.5.2, 10.2.2, 10.2.3, 10.3.2.1, 16.5, 16.5.1, 16.5.1.1, 16.5.2, 16.5.3, 23C, and 23U (new) |
Pending |
|
| NPRR1319 |
Clarification to Seasonal Mothball Evaluation Process |
This Nodal Protocol Revision Request (NPRR) clarifies ERCOT’s next steps after a Generation Resource proposal to be placed on seasonal mothball status has been evaluated. The current language in some cases requires ERCOT to prepare and post a Must-Run Alternative (MRA) “Request for Proposal” (RFP). Given that a request to seasonally mothball a Resource can be submitted as little as 90 days before the season begins, if ERCOT studies indicate a reliability concern of the seasonal mothball request, in most cases there is not enough time to effectively go through the MRA process and receive operational alternatives in a timely manner. This NPRR clarifies that ERCOT may, but is not required to, go through the MRA RFP process when it receives notice to place a unit on seasonal mothball status. |
12/29/2025 |
ERCOT |
No |
3.14.1.2, 3.14.1.2.1 (new), 3.14.1.2.1, and 22E |
Pending |
|
| NPRR1320 |
Reserve Margin Reporting and Miscellaneous Changes for the Report on Capacity, Demand, and Reserves in the ERCOT Region (CDR) |
This Nodal Protocol Revision Request (NPRR) formalizes reporting of alternative Planning Reserve Margin (PRM) forecasts in the Report on Capacity, Demand, and Reserves in the ERCOT Region (CDR). The current Protocol language requires estimating only “expected” future PRMs by risk period, season, and year. Reliance on single point forecasts fails to recognize key uncertainties that can yield a range of potential PRM outcomes, thereby downplaying the extent of risks to resource adequacy. In recognition of this shortcoming, ERCOT has in past CDRs included alternative PRM scenarios as supplemental information. This NPRR would require a range of PRM scenarios to be included in future CDRs. Formally requiring the reporting of a range of PRM scenarios, as opposed to singling out one potential future, reflects a best practice for resource adequacy risk assessment and promotes appropriate messaging regarding potential resource adequacy futures. |
01/27/2026 |
ERCOT |
No |
1.3.1.2, 3.2.6.1, 3.2.6.2, 3.2.6.4, and 3.14.1.1 |
Pending |
|
| NPRR1326 |
Add Energy Storage Resource (ESR) State of Charge (SOC) Information to the Ancillary Services Capacity Monitor |
This Nodal Protocol Revision Request (NPRR) adds State of Charge (SOC) information for Energy Storage Resources (ESRs) in the ERCOT region to the Ancillary Services Capacity Monitor. |
03/06/2026 |
Reliant Energy Retail Solutions |
No |
6.5.7.5 |
Pending |
|
| NPRR1328 |
Establishment of Generation Firming Program |
This Nodal Protocol Revision Request (NPRR) incorporates the new Generation Firming Program requirements, as required by Public Utility Regulatory Act (PURA) § 39.1592 and the Public Utility Commission of Texas’ (PUCT) rule adopted in 16 Texas Administrative Code § 25.65. The obligation to participate in the Generation Firming Program applies to all Generation Resources with an original Standard Generation Interconnection Agreement (SGIA) executed on or after January 1, 2027, beginning one year after the Generation Resource’s Resource Commissioning Date. Such Generation Resources are required to operate, or be available to operate, at or above the Generation Resource’s Seasonal Average Generation Capability during the Low Operation Reserve Hours in each Firming Season. Generation Resources can satisfy this obligation either through their own performance or via a Firming Transfer with another eligible Resource. This NPRR provides details on the administration of the Generation Firming Program, including definitions, timing requirements, processes for submitting Firming Transfers to ERCOT, specific calculations for measuring performance and applying exemptions, and associated market-facing reporting. |
04/02/2026 |
ERCOT |
Yes |
1.3.1.1, 2.1, 2.2, 9.5.3, 23V (new), 28 (new), 28.1 (new), 28.2 (new), 28.2.1 (new), 28.2.2 (new), 28.3 (new), 28.3.1 (new), 28.3.2 (new), 28.4 (new), 28.5 (new), 28.5.1 (new), 28.5.2 (new), 28.6 (new), 28.7 (new), 28.8 (new), 28.9 (new), 28.10 (new) |
Pending |
|
| NPRR1329 |
Resource Entity Requirements for Self-Limiting Facilities |
This Nodal Protocol Revision Request (NPRR) establishes a framework whereby two Resource Entities and their associated Qualified Scheduling Entities (QSEs) may jointly share the responsibility for managing the injection and withdrawal limits at a Point of Interconnection (POI) and formalizes the responsible QSE functions through an attestation process that is deemed acceptable to ERCOT. |
04/13/2026 |
NextEra |
No |
3.8.7 |
Pending |
|
| NPRR1331 |
Unannounced Generation Capacity Testing |
This Nodal Protocol Revision Request (NPRR) aligns the allowed timeframe for “Combined Cycle Generators” during an unannounced generation capacity test with their observed performance. |
05/08/2026 |
Constellation |
No |
8.1.1.2 |
Pending |
|
| NPRR1332 |
Related to PGRR146, Rename Quarterly Stability Assessment and Modify the Assessment Schedule |
This Nodal Protocol Revision Request (NPRR) renames the stability assessment from quarterly stability assessment to qualifying stability assessment. |
05/20/2026 |
ERCOT |
No |
3.10.7.6 |
Pending |
|
| NPRR1333 |
Establish an Incentive Program for Advanced Grid Support |
This Nodal Protocol Revision Request (NPRR) establishes a one-time advanced grid support incentive program to encourage Inverter-Based Resources (IBRs) that would not otherwise be required to provide advanced grid support to implement advanced grid support within 18 months of receiving the award notification. |
05/26/2026 |
ERCOT |
No |
3.26 (new) and 23V (new) |
Pending |
|
| NPRR1334 |
Revision to Cybersecurity Incident Notification |
This Nodal Protocol Revision Request (NPRR) expands the scope of Cybersecurity Incidents and requires a Market Participant to notify ERCOT upon determination of a Cybersecurity Incident on: (1) The Market Participant’s vendor’s computer network or system that interfaces with the ERCOT Wide Area Network (WAN), the Market Information System (MIS), or any other ERCOT computer network or system; or (2) The Market Participant’s or its vendor’s computer network or system that could foreseeably jeopardize the Market Participant’s reliable operation under the Protocols, an Other Binding Document, or Agreement. |
05/26/2026 |
ERCOT |
No |
2.1 and 16.18 |
Pending |
|
| NPRR1335 |
Implementation of PUCT Changes to Firm Fuel Supply Service for Phase 3 |
This Nodal Protocol Revision Request (NPRR) aligns the Protocols with the Public Utility Commission of Texas’ (PUCT's) recent adoption of a rule to govern Firm Fuel Supply Service (FFSS): 16 Texas Administrative Code (TAC) § 25.520. |
05/26/2026 |
ERCOT |
No |
1.3.1.2, 2.1, 3.14, 3.14.5, 6.6.14.1, 6.6.14.2, 8.1.1.2.1.6, and 22F (new) |
Pending |
|
| NPRR1336 |
Language Clean-up for NPRR1188 Implementation |
This Nodal Protocol Revision Request (NPRR) corrects language related to the implementation of NPRR1188, Implement Nodal Dispatch and Energy Settlement for Controllable Load Resources. Specific changes include: aligning language with Real-Time Co-optimization plus Batteries (RTC+B) implementation, replacing Updated Desired Base Points with Updated Desired Set Points (UDSPs), in Section 6.5.7.4; correcting a Controllable Load Resource (CLR) meter price formula in Section 6.6.3.1; clarifying the consideration of Unaccounted For Energy (UFE) in bill determinants in Section 6.6.3.1; aligning MEBR variable definitions across Section 6.6.7.1; clarifying the Settlement of calculated auxiliary Load for an Energy Storage Resource (ESR) that is not separately measured in paragraph (5) of Section 11.1.6; and other updates. |
05/26/2026 |
ERCOT |
No |
6.5.7.4, 6.6.3.1, 6.6.7.1, 11.1.6 |
Pending |
|
| NPRR1337 |
ERS Enhancements |
This Nodal Protocol Revision Request (NPRR) implements an Alternate Baseline Test to determine if an Emergency Response Service (ERS) Resource can qualify to have its performance based on the alternate baseline and changes the availability performance metric from a Qualified Scheduling Entity (QSE) Portfolio Factor combining all ERS Time Periods to having an individual QSE Portfolio Factor for each ERS Time Period. |
05/26/2026 |
ERCOT |
No |
6.6.11.1, 8.1.3.1.1, 8.1.3.1.3, 8.1.3.1.3.1, 8.1.3.1.3.3, 8.1.3.1.4, 8.1.3.2, and 8.1.3.3.1 |
Pending |
|
| NPRR1338 |
Restructure Long-Term Auction Sequence Auctions to Six Monthly Optimizations |
This Nodal Protocol Revision Request (NPRR) restructures the Long-Term Auction Sequence auctions, currently structured as three time-of-use optimizations, to six single-month optimizations. |
05/29/2026 |
ERCOT |
No |
7.5.2.1 and 7.5.2.3 |
Pending |
|
| NPRR1339 |
Protocol Clean Up and Alignment with RTC+B Implementation |
This Nodal Protocol Revision Request (NPRR) corrects misalignment of Protocol language with the Real-Time Co-optimization plus Batteries (RTC+B) implementation. The proposed changes are summarized below: 1. Corrects the duration requirement of ERCOT Contingency Reserve Service (ECRS). NPRR1282, Ancillary Service Duration under Real-Time Co-Optimization, set the duration requirement for ECRS to one hour, but certain sections were inadvertently omitted from NPRR1282 and still reflect the previous two-hour duration. This NPRR corrects those references to align with the as-built one-hour duration for ECRS. 2. Removes Fast-Responding Regulation Service (FRRS) reference in Section 4.4.7.3, Ancillary Service Trades, since FRRS was deleted with the RTC+B implementation. 3. Removes the requirement for Energy Storage Resources (ESRs) to telemeter the next Operating Hour Ancillary Service Responsibilities, which is no longer applicable following the removal of Ancillary Service Responsibilities under RTC+B. 4. Removes references to Ancillary Service Responsibility and Ancillary Service Schedule, as well language that is no longer applicable under RTC+B, in several sections. Replaces the Ancillary Service Responsibilities with Ancillary Service awards wherever applicable. |
05/29/2026 |
ERCOT |
No |
2.1, 3.9, 3.17.4, 4.4.7.3, 6.3.2, 6.5.7.6.2.3, 8.1.1.2.1.1, 8.1.1.2.1.2, and 8.1.1.3 |
Pending |
|
| NPRR1340 |
Dispatchable Reliability Reserve Service Ancillary Service with Energy Storage Resource Participation |
This Nodal Protocol Revision Request (NPRR) adds Energy Storage Resource (ESR) participation to the Dispatchable Reliability Reserve Service (DRRS) Ancillary Service. In addition to eligible Off-Line Generation Resources and On-Line Generation Resources, this provides the framework for ESRs to provide DRRS. ESR participation in DRRS would only be permitted using the discharge capability, not the charging capability (i.e., positive High Sustained Limit (HSL)). |
05/29/2026 |
ERCOT |
No |
3.17.5 (new), 3.18, 4.5.1, 5.7.4.1.1, 6.5.7.3, and 6.5.7.5 |
Pending |
|
| NPRR1341 |
Related to LPGRR077, Profile Decision Tree Excel-to-Word Conversion |
This Nodal Protocol Revision Request (NPRR) relocates select terms from Load Profiling Guide Section 19.1, Definitions, to Protocol Section 2.1, Definitions, removes the term ‘Time of Use Schedule (TOUS)’, and updates section references related to the Profile Decision Tree. |
06/23/2026 |
ERCOT |
No |
2.1, 2.2, 11.4.2, 11.4.4.2, 11.4.4.3, 18.4.2 |
Pending |
|
| NPRR1342 |
Mitigated Offer Caps for Contract for Capacity Resources |
This Nodal Protocol Revision Request (NPRR) creates a new process for determining the Mitigated Offer Cap (MOC) for Contract for Capacity (C4C) Resources procured through Section 6.5.1.1, ERCOT Control Area Authority. This NPRR proposes using market design principles to allow the C4C Resource to be Dispatched but still be above other Resources that solve the same constraint. This NPRR uses the “last-in-line” principle from NPRR826, Mitigated Offer Caps for RMR Resources, to set the MOC for C4C Resources and minimize their effect on market competition. This NPRR sets clear requirements for using this method. If those requirements aren't fulfilled, mitigation of the C4C Resource is determined by cost. The C4C MOC methodology in this NPRR will only be applied to an active constraint when all of the following three conditions are true: 1) The C4C Resource has an unloading Shift Factor more than 2% on the Transmission Facility; 2) The C4C Resource has a greater than 5% unloading impact* on the Transmission Facility; and 3) At least one other non-C4C Resource has a 5% or more unloading Shift Factor on the Transmission Facility. Unloading impact is reduction of flow on the Transmission Facility and is used in ERCOT’s evaluation of whether the unit would be an effective C4C Resource. The MOC methodology in this NPRR is similar to the NPRR826 approach and works as follows to create the line: 1) Identify all non-Reliability Must-Run (RMR) and non-C4C Resources that have a greater than 5%* unloading Shift Factor on the Transmission Facility; 2) Collect the highest energy offer point (mitigated if applicable) for each Resource in step 1 and convert to a Shadow Price equivalent; 3) Select the highest value from step 2 and ensure it is less than the Shadow Price cap for the constraint by $1; 4) Add $0.01 to the value from step 3, multiply by the Shift Factor of the C4C Resource to convert back to an energy offer equivalent, and set as the C4C MOC; and 5) If there are multiple constraints, use the lowest value from step 4. Finally, if possible, ERCOT should implement this NPRR with NPRR826, stop manual MOC calculations for RMR and C4C, and remove related Protocol language. |
06/30/2026 |
ERCOT |
No |
2.1, 2.2, 4.4.9.4.3 |
Pending |
|
| NPRR1343 |
Introduction of PTP Obligation Bid Fee in DAM |
This Nodal Protocol Revision Request (NPRR) proposes the introduction of a bid fee for each inefficient hourly Point-to-Point (PTP) Obligation bid in the Day-Ahead Market (DAM). The fee will be assessed per inefficient PTP hourly bid and will be modifiable. Changes to the fee will be recommended by WMS, approved by TAC, and communicated to Market Participants in advance of the DAM run in which the change will take effect. |
06/30/2026 |
ERCOT |
No |
4.6.3., 7.9.3.1, 9.2.3, and 16.11.4.3.1 |
Pending |
|