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LCRA Transmission board approves nine capital projects totaling about $80 million
Summary
The LCRA Transmission Services Corporation board on Nov. 12 approved nine capital improvement projects — including transmission-line overhauls, transformer additions and protective-relay upgrades — that together carry multi‑million-dollar price tags and staggered completion dates through 2027.
The LCRA Transmission Services Corporation board voted Nov. 12 to approve nine capital improvement projects aimed at improving reliability and adding capacity across its Texas service territory.
Josh Cole, the board presenter for capital projects, said the package includes transmission-line overhauls, substation equipment additions and protection-system upgrades brought forward after scope, design and refined cost estimates. "I've got more than a handful of projects for your consideration today," Cole told the board. He said completed projects will later be presented to the Public Utility Commission of Texas for cost recovery.
The largest single estimate in the packet was a $24.7 million project to add a power transformer at the Hornsby Substation in Travis County to serve forecasted load growth including the Tesla campus southeast of Austin. Other approved items include a 37.9‑mile, 345 kV overhaul between Big Hill and Twin Buttes (Tom Green and Schleicher counties) estimated at $12.8 million, a Colton–Elroy 138 kV line overhaul ($16.6 million), protective relaying upgrades at 15 substations ($6.5 million), and transformer additions at Georgetown South ($6.4 million) and Glasscock ($7.6 million). A Jack Furman substation interconnection to support the Kerrville Public Utility Board was estimated at $2.9 million, and Blewett Substation circuit-breaker additions were estimated at $7.0 million. Cole also described easement-acquisition work for a Lockhart–Mendoza corridor (up to 47 parcels) with easement costs cited around $2.0 million; Cole noted both a packet-listed recommended completion date and an internal note anticipating later work in 2028.
Board discussion was limited to brief procedural comments; a director seconded the motion to approve the package and Chair Cooper called for a voice vote. The motion passed by voice vote; the transcript does not record a roll‑call tally of individual votes.
What happens next: staff will proceed with project delivery according to the scopes and schedules presented and will seek cost recovery from the Public Utility Commission of Texas where applicable. Individual projects will return for any final permitting, real‑estate actions or segmented approvals as required.
