Beaver City considers bond to fund meter-structure upgrade and new substation as EV charging strains capacity

Beaver City staff presented plans this session to add a new meter structure and later build a substation to relieve immediate capacity constraints caused in part by electric vehicle fast chargers. Dave, the power department presenter, told council members the town’s existing meter equipment is rated to about 100 amps while the system has seen peaks around 140 amps and that Rocky Mountain Power has discouraged new connections until capacity is increased.

Why it matters: Council members said the problem is now pressing because several high-capacity fast‑charging installations — including Tesla, Rivian, Iona and Electrify stations — draw large, concentrated loads. “Tesla on the South End is 3,000 amp service, which pulls more energy than the entire town just on that one service,” Dave said, describing how a single fast‑charging pad can create system‑wide peaks.

What officials discussed: Staff estimated the meter‑structure work “a little over $1,000,000” while bond parameters under discussion would allow borrowing up to $4,000,000 as a not‑to‑exceed cap to cover contingency and related costs. Council members and staff also flagged major equipment costs: modern breakers with bypasses are now required where older fuse links were used, and Dave said those breaker assemblies can cost roughly $400,000 apiece.

Council members weighed timing and risk. One council member asked whether the city should “bite the bullet” and buy multiple breakers now to avoid higher future prices and long lead times; Dave cautioned that lead times can be several months. The council scheduled a presentation by the city’s financial advisor, Marcus Keller, to review bond parameters and help assess whether to include contingency for additional breakers.

Rates, impact fees and billing: Staff explained the city has created a separate EV rate category and an impact‑fee approach that charges very large services an upfront fee to reflect the capacity they reserve. Dave described the methodology behind the impact fee study — 15‑minute readings across all meters for a year, then averaging by breaker size — and said large 3,000‑amp services face upfront impact fees “just under $500,000” in the city’s calculation. He also described demand charges that apply retroactively to the monthly peak and noted those fees are intended to ensure the city recovers the cost of capacity spikes.

Market rules and operations: The council also discussed a broader operational change tied to a day‑ahead market (EDAM) requirement taking effect May 1, which will require the city to purchase power day‑ahead and to provide hour‑by‑hour plant communications. Staff said they are evaluating telemetry options (including Starlink) so the city’s plants can report hourly status and to help avoid unanticipated shortfalls on holidays or during large events.

What’s next: The council will hear Marcus Keller’s bond presentation and a technical briefing from an Eaton representative on the substation cost and design later in the meeting. No formal financing vote occurred at this session; council members asked staff to refine cost estimates and procurement timing so they can decide whether to authorize bonding and whether to buy additional breakers now or stage purchases.