Utah regulators hear experts on 'advanced transmission technologies' to unlock grid capacity

The Utah Public Service Commission on Thursday hosted a technical briefing on advanced transmission technologies — a suite of software and hardware tools proponents say can increase capacity on existing transmission lines and shorten timelines for bringing new generation online.

Jenny Netherton, an officer with the Pew Charitable Trusts’ energy modernization program, opened the session by noting the Utah Legislature’s recent passage of HB 212 and urging commissioners and staff to consider the new tools as they implement the law. “We’re hopeful that this helps to inform your efforts and work as you implement the provisions of this bill,” Netherton said.

The briefing brought together industry consultants, nonprofit experts and utility representatives to explain three broad categories of technologies under discussion: grid‑enhancing software and controls (topology optimization and advanced power‑flow control), dynamic line ratings (DLR, which use sensors or fiber to measure real‑time line capacity), and higher‑performance conductors such as carbon‑composite core wires and, in limited cases abroad, superconductors.

Why it matters: supporters said these options can often be deployed faster and at lower upfront cost than new transmission lines. Julie Seltier of the WATT Coalition, which represents grid‑enhancing technology manufacturers, summarized the argument visually: “I like to think about the grid as a highway where there’s a lane that’s there, but we can’t use it,” she said, adding that topology optimization and other tools can unlock existing capacity.

Presenters described typical benefits and limits. DLR installations are characterized as relatively fast (often cited as deployable in about 1 to 3 years) and able to capture additional capacity when ambient cooling (wind) is present; one presenter summarized the rule of thumb that roughly a 2‑feet‑per‑second breeze can raise carrying capacity by about 20 percent in some conditions. Grid‑enhancing controls (large substation devices and software) and topology optimization can reroute flows and reduce congestion, in some case unlocking hundreds of megawatts where alternative paths exist. High‑performance conductors can yield firm increases in line capacity—presenters cited reconductoring that can double capacity in some situations—but carrying conductors at very high temperatures raises tradeoffs of higher electrical losses and possible lifecycle considerations.

Utility experience: Rocky Mountain Power and PacifiCorp staff described past and ongoing deployments. Wesley (PacifiCorp) said PacifiCorp has installed several DLR systems and advanced conductors across its system and continues to evaluate newer sensor technologies. “The ATP is not a new concept. We have been installing things like DLR since 2012,” Wesley said. Rocky Mountain Power representatives said they have used DLR and other grid‑enhancing devices in targeted locations and are evaluating newer generations of the technology.

Research and case studies: independent consultants and GridLab noted studies in other regions that modeled portfolios of these tools and found rapid paybacks in some interconnection or congestion cases. Jay Casper, a power engineer and consultant, described a multi‑tool study in the Plains that modeled roughly 50 DLR and related deployments and estimated production‑cost savings large enough to justify the lower capital cost compared with building new lines in that case.

Barriers and limitations: presenters and utility staff repeatedly emphasized situational limits and institutional barriers. DLR is most useful where ambient conditions vary along a line and where operations can safely use real‑time ratings; advanced power‑flow devices and topology changes require operators and planning teams to adopt new procedures. Several speakers stressed that incentives and planning rules historically have not rewarded utilities for extracting efficiency from existing assets, creating an adoption barrier. Presenters also cautioned that some high‑performance conductors are best used for occasional emergency ratings rather than continuous operation because continuous high‑temperature operation increases losses and may affect lifecycle economics.

Legislative and regulatory context: speakers referenced HB 212 (the Utah law encouraging evaluation of advanced transmission technologies), FERC direction on ambient‑adjusted ratings and planning (discussed as FERC Order 881 in the briefing), and federal programs such as DOE grid‑improvement grants. Commissioners asked staff to follow up on the current status of DOE grant negotiations that attendees mentioned.

No formal votes or regulatory actions were taken at the briefing. The session was structured as a technical exchange and question‑and‑answer forum to inform commission staff and commissioners as they implement HB 212.

The commission closed the meeting after a final round of questions about equipment lifespan, deployment timetables and the potential to use federal wildfire mitigation or grid grants to offset costs. Staff said they would provide follow‑up information on grant status and on technical details requested during the discussion.