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Rocky Mountain Power to triple Mountain Green substation capacity; work to run through 2026
Summary
Rocky Mountain Power told the Morgan County Commission it will replace the Mountain Green substation with a larger 30 MVA facility and add two distribution circuits to improve reliability; construction is expected to complete around May 2026.
Rocky Mountain Power representatives told the Morgan County Commission on March 18 that the utility will replace the aging Mountain Green substation and increase its transformer from 10 MVA to 30 MVA to meet growing summer peak demand.
Logan Taggart, Rocky Mountain Power regional business manager, presented project details: the upgrade will be built on the existing substation property and add two dedicated distribution circuits (north and south) with individual breakers, reduced single‑point failures and improved reliability for communities served from Mountain Green. The new switchgear and breakers will be housed in modern metal enclosures and the plan includes a 10‑foot perimeter concrete wall; the company said the wall also helps mitigate sound from transformers.
Taggart said a large transformer delivery is already staged nearby but long‑lead equipment remains; the company provided an estimated substantial completion date of May 2026. Rocky Mountain Power said its modeling shows the current substation will reach capacity in summer without upgrades and that the upgrades are needed to serve continued growth. The project will also involve reconductoring an older transmission line through Weber Canyon, replacing many poles and increasing average pole height by about 10 feet to meet current standards. Company staff said undergrounding transmission would be technically possible but cost‑prohibitive for ratepayers.
Commissioners and county staff pressed the company on local voltage‑drop complaints and summer voltage regulation on the Island Road line feeding Porterville. Taggart said the substation upgrades could help by allowing load shifting but that distribution upgrades and conductor sizes also affect summer voltage problems; Rocky Mountain Power said it will continue to sample loads with recording voltmeters and may install additional regulators or capacitors as needed.
Rocky Mountain Power said transmission upgrades will require coordination with UDOT for interchange work where lines cross planned road projects; the utility also noted wildfire safety practices in higher risk mapped areas that could affect operations in summer. The company said costs for the transmission/installation are recovered through the utility rate base, not charged to a single neighborhood.
No formal county action was required at the March 18 presentation. Commissioners thanked Rocky Mountain Power for the update and said they expect continued coordination as construction approaches.
