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Oak Ridge electric department unveils $28 million substation and infrastructure plan as load projections climb
Summary
City electric officials presented a multi‑phase long‑range plan that lists roughly $28 million in major substation and transformer projects plus an estimated $14 million for conductor/pole work to address aging equipment and projected load growth over the next decade.
Oak Ridge electric department leaders and consultants told the City Council that the city’s power system faces significant investment needs to meet projected load growth and replace aging equipment, and they recommended immediate planning and procurement steps to avoid long lead times for transformers.
City Electric Director David Cross (presenting) introduced JD Bush of Patterson & Dewar Engineers, who said the city’s baseline peak system load (about 100 megawatts) could grow by roughly 60% based on projects already in progress or under negotiation. That growth, Bush said, would nearly double peak demand within about 10 years if all identified developments proceed; adding the Arano facility alone could contribute an additional roughly 40 megawatts.
Why it matters: Rapid load growth coupled with decades‑old substation transformers and overhead conductors creates operational and reliability risk. City staff said major substation transformer replacements, distribution upgrades and copper replacement will be required and carry long procurement lead times.
Plan highlights and timing: - Cost and phasing: Consultants presented three phases (2025–2027, 2028–2030 and 2031–2034) with about $28 million of major substation projects (transformer replacement and substation refurbishments) and an additional roughly $14 million estimated for conductor (formerly copper) and pole replacement programs. - Substations: Several substations have units installed in the 1960s and 1970s; Bush recommended grouping full replacements (rather than piecemeal work) at each substation to gain efficiency and uniform design. - Transmission and TVA coordination: Officials said most planned projects can be handled on existing substation footprints, but very large customers such as the proposed Arano plant will require close coordination with the Tennessee Valley Authority for transmission and capacity decisions. - Lead times and procurement: Staff warned that power transformers can have lead times up to three years and that design, bidding and procurement should begin now for phase‑2 work to avoid multi‑year delays. - Reliability and resilience projects: Shorter‑term projects include adding switchgear and sectionalizing points in new developments (for example, the Preserve) to improve outage isolation and reduce customer disruption; officials said one specific switchgear project could be completed in a few months once funding and equipment are ready. - Copper replacement and safety: Electric staff explained that some overhead copper conductors date back 60 years and that safety rules require de‑energized handling for old copper — increasing outage time and work complexity. The department plans to replace number‑6 copper with modern aluminum conductors to extend service life and improve safety for linemen. - AMI pilot and SCADA: Staff said an advanced metering infrastructure (AMI) pilot is planned for August with a full meter rollout expected over two to three years; SCADA (supervisory control and data acquisition) improvements were also recommended to better monitor and operate the system.
Councilors asked about project prioritization, aesthetic siting of equipment in neighborhoods and the cost impacts on ratepayers. Officials said they will follow a financial planning process and work with a TVA consultant to align phasing and financing to minimize customer rate shock.
Ending: Consultants and staff urged council to begin design and procurement for near‑term substation projects because of long equipment lead times and to pursue a steady program of conductor and pole replacement to improve reliability.
