| PGRR073 |
Related to NPRR956, Designation of Providers of Transmission Additions |
This Planning Guide Revision Request (PGRR) aligns the Planning Guide with NPRR956. NPRR956 revises the Protocols to align with section 37.056 of the Texas Utilities Code, as amended by SB1938 86(R), which became effective on May 16, 2019. The NPRR imports SB1938’s language regarding project responsibility and clarifies that ERCOT does not designate providers of recommended Transmission Facility additions, but simply identifies the owners of the existing Transmission Facilities to which those additions will interconnect. Consistent with the NPRR, this PGRR proposes that ERCOT’s report to the Public Utility Commission of Texas (PUCT) regarding a recommended Transmission Facility addition will identify the owners of the existing Transmission Facilities to which the addition will interconnect. |
07/02/2019 |
ERCOT |
No |
3.1.6 |
Pending |
|
| PGRR105 |
Deliverability Criteria for DC Tie Imports |
This Planning Guide Revision Request (PGRR) adds Direct Current Tie (DC Tie) Resources to the list of Resources for which the minimum deliverability condition applies. |
04/17/2023 |
Rainbow Energy Marketing Corporation |
No |
4.1.1.1, 4.1.1.7 |
Pending |
|
| PGRR106 |
Clarify Projects Included in Transmission Project Information and Tracking (TPIT) Report |
This Planning Guide Revision Request (PGRR) clarifies what transmission projects are included in the Transmission Project Information and Tracking (TPIT) report. |
04/19/2023 |
ERCOT |
No |
2.2, 6.4 |
Pending |
|
| PGRR107 |
Related to NPRR1180, Inclusion of Forecasted Load in Planning Analyses |
This Planning Guide Revision Request (PGRR) aligns the Planning Guide with NPRR1180. PGRR107 revises the Planning Guide to address recent amendments to P.U.C. SUBST. R. 25.101, Certification Criteria, which became effective on December 20, 2022. Specifically, PGRR107 incorporates the requirement in P.U.C. SUBST. R. 25.101(b)(3)(A)(ii)(II) for any review conducted by ERCOT to incorporate the historical Load, forecasted Load growth, and additional Load seeking interconnection, in ERCOT’s analysis. PGRR107 also requires a Regional Planning Group (RPG) project submitter to provide such information to ERCOT, when available, for inclusion in ERCOT’s planning analyses. |
05/11/2023 |
Oncor |
No |
3.1.2.1, 3.1.3, 3.1.4.1, 3.1.4.2, 3.1.7, 4.1.1.1 |
Pending |
|
| PGRR111 |
Related to NPRR1191, Registration, Interconnection, and Operation of Customers with Large Loads; Information Required of Customers with Loads 25 MW or Greater |
This Planning Guide Revision Request (PGRR) creates a new process for studying the reliability impacts of all Large Loads (those 75MW or more) that will be interconnected within 24 months. As with the Full Interconnection Study (FIS) required for proposed Generation Resources, this PGRR requires a Large Load Interconnection Study (LLIS) for each new Large Load meeting applicability requirements that is proposed to interconnect to the ERCOT System. Like the FIS, the LLIS will consist of a similar suite of studies conducted by one or more affected Transmission Service Providers (TSP). This PGRR describes these studies in detail and establishes timelines for the review of these studies and the completion of other steps in the interconnection process. This PGRR requires a Customer proposing to interconnect such a Load—referred to as a “Large Load Interconnecting Entity”—to initiate such a request through ERCOT’s Resource Integration and Ongoing Operations (RIOO) system, which will leverage the efficiency of this existing tool to enable ERCOT and affected TSPs to submit, review, and confirm completion of the studies that are needed. This PGRR also requires some Large Loads to be evaluated as part of the existing quarterly stability assessment. This PGRR also adds additional Reliability Performance Criteria for the inclusion of Large Loads in planning studies. |
08/01/2023 |
ERCOT |
No |
2.1, 4.1.1.2, 5.2.10 (new), 5.3.5, 6.1, 6.6 (new), 6.6.1 (new), 6.6.2 (new), 6.6.3 (new), 6.6.4 (new), 7.1, 9 (new), 9.1 (new), 9.2 (new), 9.2.1 (new), 9.2.2 (new), 9.2.3 (new), 9.2.4 (new), 9.3 (new), 9.3.1 (new), 9.3.2 (new), 9.3.3 (new), 9.3.4 (new), 9.3.4.1 (new), 9.3.4.2 (new), 9.3.4.3 (new), 9.4 (new), 9.5 (new), 9.5.1 (new), 9.5.2 (new), 9.5.3 (new), 9.6 (new) |
Pending |
|
| PGRR112 |
Dynamic Data Model and Full Interconnection Study (FIS) Deadline for Quarterly Stability Assessment |
This Planning Guide Revision Request (PGRR) establishes requirements for Interconnecting Entities (IEs) to submit dynamic data models and for Transmission Service Providers (TSPs) to submit final Full Interconnection Studies (FISs) for approval at least 30 Business Days prior to the quarterly stability assessment deadline. Projects will not be qualified for the quarterly stability assessment if dynamic data models and final FISs are submitted less than 30 Business Days prior to the deadline. |
09/20/2023 |
ERCOT |
No |
5.3.2.5 and 5.3.5 |
Pending |
|
| PGRR113 |
Related to NPRR1198, Congestion Mitigation Using Topology Reconfigurations |
This Planning Guide Revision Request (PGRR) revises the Planning Guide to provide that ERCOT will first consider transmission needs without Constraint Management Plan (CMP) actions in its Regional Transmission Plan studies, and will then only model a CMP in the Regional Transmission Plan in certain limited circumstances. A CMP will not be planned to resolve a planning criteria performance deficiency unless it is expected that system conditions will change such that the CMP will no longer be needed within the next five years. |
11/14/2023 |
ERCOT |
No |
3.1.4.1.1 and 4.1.1.2 |
Pending |
|
| PGRR114 |
Related to NPRR1212, Clarification of Distribution Service Provider’s Obligation to Provide an ESI ID |
This Planning Guide Revision Request (PGRR) modifies Section 5.5 to clarify that, before ERCOT approves Initial Energization for a project that will consume Load other than Wholesale Storage Load (WSL) and that is not behind a Non-Opt-In Entity (NOIE) tie meter, the Distribution Service Provider (DSP) must provide ERCOT with Electric Service Identifier(s) (ESI ID(s)) for the project and these ESI ID(s) must be established in the ERCOT Settlement system in a state that allows for the Load to be properly settled to the appropriate Qualified Scheduling Entity (QSE). |
11/22/2023 |
ERCOT |
No |
5.5 |
Pending |
|