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Board reviews emergency plans after 61-year-old White Rock transformer failed
Summary
A 1964 White Rock substation transformer failed Aug. 8; staff presented three emergency options — tie to LANL with voltage regulators, rent a mobile substation, or buy/refurbish a larger transformer — and estimated combined near-term costs could reach roughly $1 million for a replacement plus tie-in work.
A 61‑year‑old transformer at the White Rock substation failed in the early hours of Aug. 8, and Los Alamos Department of Public Utilities staff told the Board of Public Utilities on Sept. 3 they are pursuing multiple emergency options to keep the town powered while securing a longer‑term replacement.
“On August 8, that transformer failed at 03:20 AM,” said Dennis, the staff presenter, describing a failure that generated significant heat inside the tank and required an immediate crew response. Staff restored service by about 6 a.m. and collected oil samples for laboratory analysis to help identify the failure mechanism.
Why it matters: White Rock is effectively an electrical island for the county with two substation transformers and limited alternate feeds. If the second transformer fails before a replacement is secured, residents risk prolonged outages unless a temporary feed or mobile substation can be arranged.
What staff proposed: Dennis described three emergency alternatives. Option 1 is to tie into Los Alamos National Laboratory’s (LANL) 13,200‑V line and step the voltage down with auto‑transformer voltage regulators and safety switches; staff noted regulators can be procured in roughly four weeks and LANL has agreed to collaborate. “We can put voltage regulators on the line and step the voltage down … and that’s what we’re going to plan to do,” Dennis said.
Option 2 is to secure a mobile substation from a neighboring utility (PNM) or a rental supplier; staff warned deployment typically takes about a day and can be expensive to operate. Option 3 is to buy or refurbish a replacement power transformer. Staff reported bids for rebuilt units that meet requirements and said refurbished transformers often carry stronger warranties than new units being produced offshore. Board members and staff discussed upsizing the unit to 7.5 MVA or larger to meet future load growth identified in the electrification study.
Costs and timing: Staff estimated the tie‑in work and regulator procurement at tens of thousands of dollars (LANL estimated about $75,000 for line work and staff cited roughly $70,000 for regulators and associated platform work). Replacement transformer and foundation work — including procurement, refurbishment, delivery and installation — were estimated in the hundreds of thousands; staff said refurbished replacements currently under consideration were in the $400,000–$600,000 range and total project costs could approach $1,000,000 after site, foundation and commissioning costs.
Board concerns and next steps: Board members pressed on whether the failed unit had prior indicators; Dennis said a 2024 oil test did not signal imminent failure. The staff will pursue the LANL tie, seek mutual‑aid access to mobile substations, continue procurement for replacement transformers (refurbish favored), and report back to the board with vendor details and schedules. If the LANL tie is available, staff said it intends to keep that as a permanent or semi‑permanent backup arrangement where feasible.
The board did not take a final vote at the meeting; staff said follow‑up procurement and agreements would be presented as needed in subsequent meetings.
