Renewables, storage and local incentives: industry and counties describe roles, limits and community impacts

Three presenters — Amanda Smith of AES, Ricky Seguin of Inner West Energy Alliance and Lincoln Shirts of the Utah Association of Counties — briefed legislators on the role renewables and storage can play in meeting projected load growth and supporting community economic development.

Amanda Smith said renewables are part of an "all-of-the-above" strategy and noted solar can be developed quickly (24–36 months) and paired with battery storage to add flexibility. "Solar still [is] super competitive compared to gas," Smith said, referencing industry levelized-cost studies without tax incentives. She described community benefits from renewable projects, including local hiring, training and impact payments negotiated with counties. AES described existing Utah assets (Clover Creek solar, central Utah wind) and said some customer demand—for example data centers—drives behind‑the‑meter, colocated generation options.

Ricky Seguin, representing about 60 regional developers, said renewables and storage complement other generation types by providing resource diversity and price stability and can be brought to market faster than many thermal or advanced-nuclear options. "Renewables and storage are regularly built together now," Seguin said, adding that paired projects often yield a more valuable product than either resource alone. He emphasized keeping Utah "open for business" to attract projects and investment.

Lincoln Shirts explained how county taxation and Community Reinvestment Areas (CRAs) work in Utah. He said most of the tangible value of solar projects is treated as tangible personal property under state assessment rules, which does not create local new‑growth tax revenue unless the project is placed in a CRA and a community benefit agreement is negotiated. Shirts said counties negotiate CRA-based community benefit agreements to capture and reinvest project revenue locally (roads, emergency services, infrastructure) and that many counties lack in-house technical expertise to evaluate complex power‑purchase agreements and queue/ transmission cost questions.

Lawmakers asked about transmission costs, development timelines, land use and the impact of recent federal changes in tax incentives. Amanda Smith and Ricky Seguin said supply-chain and transformer lead times (15–48 months) and turbine lead times (multiple years) mean renewables and storage can often be deployed faster than some thermal options. Lincoln Shirts urged state–local coordination to provide counties technical support and recommended a partnership model rather than centralizing all authority at the state level.

Ending: Presenters asked lawmakers to consider how to preserve market choice, ensure timely transmission upgrades, and provide counties technical help so local communities can evaluate incentives and negotiate community benefit agreements.