Vermont Clean Energy Guide

Vermont wears the cleanest generation crown in the country, and it is worth reading the fine print. The state leads every other on the renewable share of its in-state electricity, close to 100% since 2015, yet it generates only a sliver of what it burns and imports roughly 80% of its supply, most of it Canadian hydropower. This is a small, legacy-hydro market where the real story is not a solar-and-wind buildout but a wind moratorium, a distributed grid, and utilities scrambling to serve new load with renewables.

A Clean Grid That Runs on Imports and Legacy Hydro

The headline is real but partial. Vermont has the largest share of in-state electricity net generation from renewables of any state, near 100% every year since 2015, and its in-state fleet is essentially fossil-free, with a CO2 emissions rate of 8 lbs/MWh, ranked 51st and cleanest in the nation. But look at the fuel mix and you see a legacy portfolio, not a modern buildout: in 2023 in-state generation broke down to roughly 57% hydroelectric, 17% biomass, 16% wind, and 10% solar, on a total of about 2,085 GWh.

That number matters because Vermont consumed far more than it made. Total in-state net generation in 2024 was about 2.26 million MWh against retail sales of about 5.46 million MWh, and imports, overwhelmingly hydropower from Quebec, fill the gap. Net summer generating capacity across all fuels is just 864 MW. For a utility-scale audience, the takeaway is blunt: Vermont is not a place to chase gigawatts of greenfield generation. It is a small, high-price New England market (18.41 cents/kWh all-sector average in 2024) where the growth levers are storage, distributed solar, and utility-run programs rather than sprawling merchant plants.

Act 179: A 100% Renewable Mandate Passed Over a Veto

Vermont's policy backbone is a binding Renewable Energy Standard, and in 2024 the legislature gave it real teeth. H.289, enacted as Act 179 of 2024, was the first major update to the RES since its 2015 creation. It passed on June 17, 2024 over Governor Phil Scott's veto (Senate 21-8, House 102-43), took effect July 1, 2024, and set new generation requirements starting January 1, 2025. The design goal is unambiguous: get to 100% renewable, not merely carbon-free, electricity, making Vermont the third state to require that of all in-state providers.

The timeline splits by utility size. Green Mountain Power and Vermont Electric Cooperative, the large providers with 75,000-plus customers, must hit 100% renewable by 2030; every other utility not already there must reach it by 2035. Underneath sits a five-tier structure: Tier I (total renewable) starts at 63% in 2025 and steps up roughly 4% every three years to 100%; Tier II (distributed generation) climbs from 5.8% toward about 20%; Tier III (energy transformation) rises from 7.33% in 2025 to 12% by 2032; Tier IV (new renewable) requires large providers to hit 4% by 2027, 10% by 2030, 15% by 2032, and 20% by 2035; and Tier V (load-growth renewable) forces utilities already at 100% to serve new load growth with new renewables, moving from 50% in 2025 to 100% by 2028.

One provision deserves developer attention: Act 179 doubled the in-state share of renewable obligations from 10% to 20%. Analyses projected roughly 600 MW more in-state solar than the prior law would have driven, plus about twice that in new regional renewables, much of it regional wind sited outside Vermont's borders. In other words, the mandate is real demand, but a good chunk of it is designed to be met over the fence in the broader ISO-NE footprint.

The Surrounding Climate Framework

The RES does not stand alone. The 2020 Global Warming Solutions Act sets binding, litigable emissions targets: 26% below 2005 by 2025, 40% below 1990 by 2030, and 80% below by 2050. The 2022 Comprehensive Energy Plan targets 100% carbon-free electricity with at least 75% renewable by 2032, with the next CEP update due in 2028. Vermont is also a member of the Regional Greenhouse Gas Initiative, the Northeast power-sector cap-and-trade program.

Incentives Lean on Federal Credits

Vermont runs no standalone state ITC or PTC. Support flows through Efficiency Vermont rebates, the Clean Energy Development Fund, net metering, and aggressive utility programs, notably Green Mountain Power's bring-your-own-device battery incentives (rebates up to $10,500, or a $55-a-month Powerwall lease). Project economics still rest heavily on federal credits, the IRA-era ITC/PTC and their Clean Electricity successors, which makes the federal tax-credit phaseout debate consequential even in a small market like this one. On net metering, systems up to 500 kW are allowed and there is no aggregate cap, but off-site/group net metering closed to new applications at the end of 2024 (with a one-year extension for low-income multifamily systems through January 1, 2026). The 2025 Senate Bill S.50 nudged the expedited-interconnection threshold up from 15 kW to 25 kW and let customers keep or transfer their renewable energy credits.

The Projects: Small by National Standards, and Nothing New in Wind

Vermont has no traditional utility-scale plant above 50 MW. Its fleet is a handful of ridgeline wind farms built more than a decade ago, one notable solar array, and a fast-growing battery footprint. The wind is essentially frozen in time: about 149 MW across five farms, all pre-dating the 2017 sound rules.

• Kingdom Community Wind (Lowell, Orleans County): Vermont's largest wind farm at 63 MW, 21 turbines on the Lowell Mountain ridge, owned by Green Mountain Power and Vermont Electric Cooperative and online since 2012.
• Sheffield Wind (Caledonia County): 40 MW, originally built by First Wind and later owned by TerraForm Power.
• Deerfield Wind (Bennington County): 30 MW, 15 turbines from Avangrid Renewables in the Green Mountain National Forest, online 2017 and the only U.S. wind project sited in a national forest at the time.
• Georgia Mountain Community Wind (Georgia/Milton): 10 MW, four turbines, a privately held community project online since 2012.
• Coolidge Solar 1 (Ludlow, Windsor County): Vermont's largest single solar array at 20 MW, developed by NextEra Energy and online at the end of 2018.

On installed base, SEIA pegged Vermont at 439 MW of solar in early 2025, ranked 41st nationally and dead last, 50th, for projected five-year growth at a forecast 98 MW (EIA reported roughly 333 MW as of September 2024; the gap is methodology, blending utility-scale and distributed PV). Storage is where the momentum is. Green Mountain Power's battery fleet reached 68.5 MW as of August 2024 across six utility-scale sites (Georgia, Springfield, Bethel, Middlebury, Bristol, Barre) plus thousands of behind-the-meter residential Powerwalls.

The GlobalFoundries Battery Is the Real Marquee Project

The most significant thing under construction is not a solar farm but a battery. Lightshift Energy is building a 16 MW / 52 MWh lithium-ion system at GlobalFoundries' Fab 9 semiconductor plant in Essex Junction, financed via KeyBanc Capital Markets and expected online in early 2026. It will be Vermont's largest battery project, used for peak shaving at the fab, and it is paired with a 5 MW on-site solar array required under GlobalFoundries' utility agreement. That single industrial customer, not a merchant developer, is driving the largest new clean-energy asset in the state, which tells you a lot about where this market is headed.

Siting: A State Board, Not County Zoning, and a Wind Wall

Vermont's permitting regime is distinctive and, for wind, decisive. The Vermont Public Utility Commission permits utility-scale generation and transmission statewide under 30 V.S.A. Section 248 by issuing a Certificate of Public Good. This is a state-board process that preempts local zoning, so opposition does not play out as county moratoria; it plays out as interventions before the PUC. Applicants must give municipalities and regional planning commissions at least 45 days' notice before filing, and under Act 174 of 2016 towns with energy-compliant plans earn substantial deference in Section 248 review. Public input, notably, is more limited than under the state's separate Act 250 land-use process.

Then there is the wall. PUC Rule 5.700, effective November 22, 2017, sets wind-turbine sound limits of 42 dBA daytime and 39 dBA nighttime plus a setback of 10 times turbine height, meaning a 500-foot turbine must sit 5,000 feet from the nearest residence. Renewable Energy Vermont stated that none of the state's existing wind projects could meet the standard, and no new commercial ridgeline wind has been permitted since. It is a de facto moratorium in everything but name, and it explains why Vermont's wind capacity has been flat for years while every other technology grows.

Solar siting fights are smaller and more local, typically over farmland, open space, and viewsheds rather than formal bans. In Lowell (Orleans County), Northland Solar's proposed roughly 5 MW, 44-acre array on a community hayfield split a town of about 800 people, with the select board, local school, and cemetery formally intervening against it at the PUC ahead of an expected 2025 ruling. That local texture, plus statewide project data, is what our Vermont opposition tracker follows; nationally, Columbia's Sabin Center counted at least 498 contested renewable projects across 49 states at the end of 2024, up 32% year over year, and Vermont's own Public Service commissioner has described the familiar dynamic of communities backing solar in principle but not within sight.

Demand: Flat for Decades, Now Bending Upward

Vermont's electricity demand has historically been small and flat, but two forces are pushing peak demand up, and VELCO's 2024 Long-Range Transmission Plan warns that the resulting growth may strain reliability. The first is a single semiconductor plant. The PUC granted GlobalFoundries a Certificate of Public Good to create GF Power LLC, a self-managed utility for its Essex Junction fab (about 2,000 employees and more than 600,000 wafers a year). GF Power will procure most of its power directly from ISO-NE starting around October 2026, must meet the same renewable standards as other utilities, and anchors the 5 MW solar array and 16 MW / 52 MWh battery noted above. A private chipmaker becoming its own regulated utility is not a common demand driver, and it is now one of the biggest in the state.

The second is electrification. Heat pumps, EVs, and the 2024 building energy stretch code (with solar-ready and EV-ready requirements) are steadily electrifying end uses, while Green Mountain Power's 2030 Zero Outages Initiative layers on line hardening, microgrids, and storage. Crucially, RES Tier V forces utilities that are already at 100% renewable, GMP and VEC, to meet that new load growth with new renewables rather than leaning on the existing hydro base. Vermont also requires regulated electric and gas utilities to file a least-cost integrated plan every three years, and transmission operators to file a 10-year Transmission System Plan on the same cadence, so the demand response here is planned and utility-led rather than market-driven.

Frequently Asked Questions

Outlook: A Mandate Meets a Moratorium

Vermont is the country's cleanest generator and one of its least likely to host a large greenfield project. That tension defines the outlook. Act 179's 100%-by-2030 mandate for GMP and VEC is genuine demand, and its doubled 20% in-state carve-out will push new solar, but Rule 5.700 has taken the state's best onshore wind resource off the table indefinitely, and there is no utility-scale solar above 50 MW to build on. The practical path forward runs through distributed solar, aggressive storage, and regional renewables procured across ISO-NE rather than sited on Vermont ridgelines.

For developers and utility watchers, the signals to track are concrete: whether GMP and VEC actually hit their RES tiers on schedule, how GF Power's transition to direct ISO-NE procurement plays out after October 2026, and whether the Lightshift battery model at GlobalFoundries gets replicated at other large loads. Federal tax-credit economics still underpin nearly every project here, so the national phaseout debate matters locally. And with off-site net metering now closed to new applicants, the distributed-solar engine that made Vermont a per-capita leader will have to find its next gear. The mandate is ambitious; the buildout will be small, storage-heavy, and, on the wind side, largely imported.