During the meeting, several updates and discussions took place regarding various projects and topics related to the transmission system. Here is a detailed summary of the updates and discussions:
Dominion Energy has identified a need to replace 79 existing transmission towers that carry 230 kV Line Number 272 (Dooms – Grottoes). The need for replacement is based on a complex end of life criteria. The 11.5 mile long line consists of CORTEN X-Series lattice-type towers that were constructed in 1967. These towers have inherent corrosion problems causing continuous deterioration to the steel members and have reached the end of their useful life. They are amongst the weakest and most problematic CORTEN lattice towers on the system and are a high priority for replacement. A proposed solution was presented to replace approximately 11.5 miles of power lines with weathering CORTEN lattice-type towers. The plan includes replacing steel monopoles and installing a new conductor with a normal summer rating of 1573 VA to meet current 230 kV standards. The estimated project cost for this replacement is $34 million, and it is conceptual, with a projected in-service date of December 31, 2027.
A scope change was proposed for the Otter Creek to Cornerstone 500 kV line project, suggesting upgrades to the 500 kV double circuit structures to accommodate future needs and avoid wreck and rebuild scenarios. The incremental cost for this scope change is $19.5 million, bringing the total project cost to $102.8 million. The project aims to reinforce the corridor between the Peach Bottom area and the Cornerstone substation.
PJM operations requested flexibility in switching 765 kV reactors at Baker, Broadford and Jefferson stations for addressing the operational performance issues. Currently, these reactors are tied directly to the line, necessitating a line outage to switch them on and off. The proposed solution is to add four 765 breakers at these substations. The estimated cost for these breaker installations is approximately $61 million, with a required in-service date of June 1, 2027.
The reliability analysis update focused on the 2023 RTEP Window 2 and the 2024 RTEP Window 1. The 2023 RTEP Window 2 received 21 proposals from six entities, which consisted of 15 upgrades and 6 greenfield projects. These proposals addressed load growth in the Columbus, Ohio area, the PSEG footprint around Hinchmen, and end-of-life 500 kV line within the Dominion footprint, with estimated costs ranging from $0.45 million to $229 million. The evaluation and selection process for the 2023 RTEP Window 2 is ongoing. The 2024 RTEP Window 1 is being refined, with work on accurate modeling and requesting analysis results. The window is targeted to open in July, with a 60-day duration.
Participants raised questions about the models used for future planning, specifically inquiring about a draft seven-to-eight-year RTP base case study. The PJM team clarified that the current focus is on the five-year model, with plans to build the seven-to-eight-year case on top of it. The team aims to streamline the process and provide benchmark solutions for different scenarios. Additionally, there was a question about whether the SAA 2.0 problem statement will be part of the June TEAC meeting. The team responded that it is possible but not guaranteed.
Overall, the meeting covered updates on proposed solutions for power line replacements, the need for flexibility in reactor switching, reliability analysis updates, and a scope change for a PPL project. Participants engaged in discussions and raised questions about future planning models and the integration of solutions between the five-year and eight-year timeframes.
