Renewable Energy in New Hampshire: The Facts, the Trade-offs, and a Practical Roadmap for the Granite State

By Granite State Report — September 18, 2025

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Executive summary (TL;DR)

New Hampshire’s electricity system is at an inflection point. Renewables already supply a meaningful share of in-state generation—primarily hydro and biomass, with growing contributions from wind and distributed solar. But the mix, policies, and economics are shifting fast across New England and the U.S. At the regional level, ISO-New England expects continued load growth from electrification and a surge of behind-the-meter solar. At the federal level, FERC’s 2024 transmission planning reforms and a raft of IRA-era investments are catalyzing new lines, batteries, and clean generation. Locally, community power aggregation has scaled to dozens of NH towns, even as the state has pared back its Renewable Energy Fund appropriations. Offshore wind in the Gulf of Maine has moved from concept to leases, and Maine’s floating-wind research array is advancing—both with real implications for New Hampshire’s grid and economy.

This report walks through the data and policy signals that matter most for Granite Staters: the current energy mix; what’s changed in law and markets since 2024; where the biggest opportunities and risks are (from biomass to offshore wind to community power); and a pragmatic, fiscally conservative pathway that can lower bills, improve reliability, and cut emissions without overpromising or underdelivering.

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1) Where New Hampshire stands today

The generation mix. In 2023, renewables produced about 18% of New Hampshire’s in-state electricity, including small-scale solar. Most renewable generation came from hydroelectric, biomass, and wind, with solar still relatively modest but growing. New Hampshire also hosts the region’s last two coal plants—Merrimack (Bow) and Schiller (Portsmouth)—both scheduled to retire by 2028 and 2025 respectively. (EIA)

Biomass matters here. Biomass supplied roughly 5% of total NH net generation in 2023 and the sector remains economically and politically salient because it ties to the forest products industry. The 75-MW Burgess BioPower plant in Berlin—one of the nation’s largest stand-alone biomass facilities—has struggled financially (Chapter 11 in 2024) but continues operating through restructuring under lender control proposals in 2025. (EIA)

Wind and solar: small but rising. By September 2024 New Hampshire had five utility-scale wind farms totaling ~212 MW (all on mountain ridges), while solar supplied ~2% of generation—almost entirely from small-scale, customer-sited systems; the first and only utility-scale PV plant is 2.4 MW (2019). (EIA)

Regional context. Across New England, the resource mix remains dominated by natural gas and nuclear, with renewables and imports filling the remainder. ISO-NE’s latest profiles show strong growth in behind-the-meter PV and ongoing demand growth from building and transportation electrification through the 2020s. (ISO New England)

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2) The policy framework shaping NH renewables

Renewable Portfolio Standard (RPS). New Hampshire’s RPS dates to 2007 (RSA 362-F) and requires suppliers (except municipal utilities) to meet a combined obligation roughly equivalent to one-quarter of retail electricity sales by 2025, with carve-outs among four classes that include “new” renewables and eligible thermal technologies (e.g., solar thermal). The state also allows suppliers to use renewable generation from other New England states via Renewable Energy Certificates (RECs). (EIA)

Net metering. New Hampshire requires all utilities selling electricity in the state to offer net metering up to 1 MW for most customer-generators, with municipalities and certain public entities allowed up to 5 MW for group net metering since HB 315 (2021). The 1-MW limit has been criticized as restrictive for large commercial projects, and the PUC left the basic structure unchanged in late 2024. (DSIRE)

Renewable Energy Fund pressure. In July 2025, lawmakers moved to sweep much of the Renewable Energy Fund into the general fund through 2027, effectively halving the available program dollars for projects—creating near-term headwinds for municipalities and businesses expecting REF grants. (New Hampshire Bulletin)

Community power aggregation. At the same time, Community Power Coalition of New Hampshire (CPCNH) has surged—now 60+ communities by 2024 and expanding in 2025. Programs like Portsmouth Community Power are publishing updated rates under CPCNH supply, positioning local aggregation as a counterweight to volatility in standard-offer utility rates. (CPCNH – Community Power NH)

Federal transmission rules (FERC Order 1920/1920-A). In 2024, FERC finalized Order No. 1920 requiring regional planners to use long-term scenarios (reflecting state policies) to identify transmission needs and to allocate costs more predictably. This is a big deal for New England’s ability to move offshore wind, Quebec hydro imports, and onshore renewables to load—New Hampshire included. (Federal Energy Regulatory Commission)

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3) The national tide: why it matters even for a small state

Record clean generation & storage build-out. U.S. wind and solar output jumped in 2024—solar up ~25% and wind up ~8% year-over-year—as new projects entered service. Utility-scale battery storage capacity exceeded 26 GW by end-2024 (up 10+ GW in one year), and 2025 is on track for another record. These national shifts lower wholesale prices at certain hours and improve the economics of importing clean power into New England. (EIA)

Renewables’ growing share of U.S. electricity. Best-available compilations from EIA-based datasets indicate renewables generated roughly 24% of U.S. electricity in 2024, with wind+solar contributing ~17%—a new high. That momentum shapes equipment costs, power markets, and investor appetite in every region. (Electrek)

Jobs and investment. Clean-energy employment rose again in 2023–2024, accounting for more than half of new energy-sector jobs and totaling ~3.5–4.1 million broadly defined “advanced energy/clean energy” positions, according to DOE’s USEER and nonprofit sector tracking. Those gains underpin workforce programs NH can tap, especially around construction trades, grid modernization, and heat pump/HVAC. (The Department of Energy’s Energy.gov)

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4) The near-term opportunity set for NH

4.1 Community power + local procurement

Community power aggregation has become the fastest-growing energy initiative in the state, offering portfolio flexibility (e.g., hedging with fixed-price blocks, layering in RECs, piloting demand response) and local governance. As CPCNH scales, it could aggregate long-term PPAs for small hydro, landfill gas, or solar+storage in-state while also using regional contracts (e.g., offshore wind, hydro imports) to diversify supply and stabilize rates. Key levers: standardized procurement docs for towns, securitization of long-term contracts, and shared risk management. (CPCNH – Community Power NH)

4.2 Distributed solar and storage

With net metering at 1 MW for most customers and up to 5 MW for municipal group net metering, the sweet spot is school districts, water/wastewater, and municipal campuses pairing PV with batteries to shave demand charges and provide resilience. The state interconnected ~52 MW of new PV in 2023, pointing to steady—if not spectacular—growth that could accelerate with better interconnection timelines and standardized host-customer agreements. (New Hampshire Municipal Association)

Pairing behind-the-meter batteries with PV is no longer exotic—the U.S. added ~10 GW of utility-scale storage in 2024 alone, with costs falling and performance improving. Municipalities can leverage 5-MW projects under HB 315 to combine solar+storage for peak shaving and public safety power (shelters, comms). (EIA)

4.3 Onshore wind on ridgelines (incremental)

New Hampshire’s existing wind fleet (~212 MW) shows the state can responsibly site and operate projects, but the most accessible ridgelines are largely built. Incremental additions are possible where interconnection and wildlife/sightline impacts are manageable, but large expansions are unlikely without new transmission or repowering older sites with higher-capacity turbines. (EIA)

4.4 Small hydro and dam modernization

Hydropower is already a pillar of NH renewables. Modernization (fish passage, automation, runner upgrades) can squeeze more megawatt-hours from existing dams with minimal new impacts. While plant-level data are diffuse, EIA’s state profiles confirm hydro’s central role; focused procurement by CPCNH or utilities could keep these assets operating and grid-supportive. (EIA)

4.5 Biomass: tighten the value proposition

Burgess BioPower’s financial distress underscores a key reality: dispatchable renewable capacity has system value, but rate structures and REC markets must reflect that value transparently. For biomass to be part of the mix post-2025, reforms could include performance-based incentives tied to capacity contributions during winter peaks and verified forest health metrics—versus blanket subsidies. (Business NH Magazine)

4.6 Offshore wind: the Gulf of Maine and NH’s stakes

In October 2024, the federal government auctioned Gulf of Maine leases, with two provisional winners across four lease areas and $21.9 million in winning bids. Invenergy picked up two leases totaling ~215,000 acres. Separately, Maine’s 144-MW floating “Research Array” (MeRA) is advancing after BOEM’s environmental review, with the state planning a floating wind port and 3-GW policy target—developments that could anchor a regional floating-wind supply chain benefiting NH ports and manufacturers. (Bureau of Ocean Energy Management)

Closer to market, Vineyard Wind 1 (MA) delivered its first power in January 2024 and was supplying 68 MW from five turbines by February 2024; despite setbacks (blade issues in mid-2024), the project is progressing toward full operations in 2025, marking the first commercial-scale U.S. offshore wind plant to put power onto the New England grid. For NH, that matters in wholesale markets and regional REC supply even before Gulf of Maine projects deliver. (Offshore Wind Business)

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5) The grid piece: transmission, imports, and reliability

Why transmission is the hidden keystone. Adding renewables without the wires to move power where and when it’s needed is a recipe for curtailment and higher costs. FERC Order 1920/1920-A pushes planners (including ISO-NE and utilities) to run multi-decade scenarios, incorporate state policy inputs, and design cost-allocation methods that withstand legal scrutiny. Expect more cross-border solutions (Québec hydro, Maine corridor) and on-system upgrades that enable batteries and offshore wind to serve winter peaks. (Federal Energy Regulatory Commission)

NECEC (Maine corridor). The New England Clean Energy Connect line—importing 1,200 MW of Quebec hydro into Maine/Massachusetts—has survived multiple legal challenges and continued construction in 2025, though contingent conservation requirements and appeals persisted mid-year. If completed, NECEC could lower regional wholesale prices and emissions, indirectly benefiting NH ratepayers. (WMTW)

ISO-NE markets and winter reliability. Regional fuels constraints in cold snaps remain the grid’s most acute risk, with gas pipeline limits and heating demand stressing supply. In that context, dispatchable renewables (hydro releases, biomass, storage) and transmission are not abstractions; they are how we keep the lights on when the wind slacks and solar sets at 4:30 p.m. in January. ISO-NE’s 2025 state/region profiles and 2024 markets report emphasize the role of demand resources, PV growth, and market enhancements. (ISO New England)

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6) Affordability: what helps (and what doesn’t)

Community aggregation continues to offer rate stability and customer choice. Several CPCNH members reported competitive supply rates over the last year relative to utility default service, aided by flexible procurement and timing. Local control doesn’t guarantee the lowest possible price each month—but it can mitigate volatility across a multi-year horizon. (CPCNH – Community Power NH)

Grid investments, if well-planned, can save money by reducing congestion and enabling lower-cost clean power to reach load. Poorly targeted or delayed projects can do the opposite. Order 1920’s scenario-planning requirements aim to avoid “build and hope” and align wires with realistic resource portfolios and load forecasts. (Federal Energy Regulatory Commission)

State incentives matter at the margins. The 2025 REF sweep will likely delay or downsize some municipal and commercial projects unless replaced by cheaper financing or federal dollars. On the flip side, federal tax credits and rebates (IRA-era) continue to lower capital costs for PV, storage, and efficiency—though the exact NH rebate program rollouts vary over time. The overarching takeaway: program design and stability are as important as raw dollars. (New Hampshire Bulletin)

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7) Siting and public acceptance

Ridge-line wind and transmission corridors are the two flashpoints. The 2021 Maine referendum against NECEC and subsequent court battles show how process, trust, and environmental mitigation determine outcomes as much as engineering does. The Gulf of Maine auction had some leases unbid—a cautionary sign about economics, stakeholder dynamics, and supply chain timing. NH policymakers and developers should front-load fisheries, wildlife, and view-shed engagement for any future projects. (Ballotpedia)

Biomass debates blend economics, forest health, and carbon accounting. If policymakers want firm, renewable, winter-peaking capacity, they should articulate clear performance metrics and transparent rate impacts, not indefinite subsidies. Burgess’s restructuring provides a window to re-base expectations. (Business NH Magazine)

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8) How New Hampshire can lower bills, cut emissions, and boost reliability—at once

Here’s a practical, no-regrets playbook, sequenced for cost-effectiveness and reliability.

8.1 Lean into community power as the organizing platform

1. Standardize long-term PPAs across CPCNH towns for small hydro, landfill gas, solar+storage, and—when available—offshore wind REC strips. Aggregation increases deal flow and bargaining power. (Community Power NH)
2. Create a pooled resilience portfolio: 5-MW municipal solar+storage sites (HB 315) prioritized for school gyms and public safety facilities to provide islandable backup during winter storms. (New Hampshire Municipal Association)
3. Expand demand flexibility through opt-in managed EV charging and commercial battery dispatch programs—these are fast to stand up and reduce peak procurement costs.

8.2 Target “invisible megawatts”

1. Weatherization and heat pumps: Electrification is coming; make it cheaper to heat by reducing load first. Coordinate with utilities to braid federal rebates/tax credits into turnkey packages for oil-heated homes (a large share in NH). (EIA)
2. Commercial retro-commissioning: Low-cost O&M changes can cut 5–15% of building consumption and improve comfort without major capex.

8.3 Optimize the existing fleet before building new

1. Hydro upgrades: Support modernization of small hydro with streamlined permitting and REC contracts that reflect grid services (ramping, black start). (EIA)
2. Biomass performance contracts: If retained in the mix, tie support explicitly to winter capacity value, verified emissions controls, and forest management standards—with periodic re-bidding. (Business NH Magazine)

8.4 Prepare for offshore wind—on our terms

1. Supply-chain positioning: Even with lease auctions in the Gulf of Maine completed and MeRA advancing, project timelines stretch years. Use this window to pursue port upgrades, manufacturing, and workforce partnerships so NH captures jobs without taking on premature project risk. (Bureau of Ocean Energy Management)
2. Priority on grid readiness: Coordinate with ISO-NE and Eversource/Unitil/Liberty on off-ramps and grid interconnections that allow NH to import offshore wind energy reliably when it materializes. Order 1920 planning is the right venue. (Federal Energy Regulatory Commission)

8.5 Back smart wires, not just more wires

1. Support ISO-NE’s long-term planning with NH’s explicit policy goals (reliability, rate stability, emissions). Push for cost-allocation that reflects beneficiary pays, guarding NH customers from paying for lines that don’t help them. (Federal Energy Regulatory Commission)
2. Champion NECEC completion coupled with environmental offsets that withstand scrutiny; imports can lower winter prices and emissions across the region. (WMTW)

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9) What to watch in 2025–2027

• REF funding gap: The REF sweep could slow municipal/commercial projects unless CPCNH or federal programs fill the financing gap. Track PUC dockets and budget adjustments. (New Hampshire Bulletin)
• Gulf of Maine next steps: Post-auction development plans and any offtake solicitations from MA/ME (and potentially NH involvement via REC purchases) will clarify timelines and local business opportunities. (Bureau of Ocean Energy Management)
• Vineyard Wind 1 full operations: As it ramps toward full COD in 2025, expect more data on capacity factors and grid impacts—useful proxies for Gulf of Maine economics. (Reuters)
• Transmission planning under Order 1920: Watch ISO-NE’s long-term studies and cost-allocation proposals. New England will need more transfer capability—to move offshore wind and imports, and to relieve winter constraints. (Federal Energy Regulatory Commission)
• Battery storage in New England: The U.S. storage boom reduces curtailment and enhances reliability. Expect more solar+storage PPAs and stand-alone batteries at substations. (EIA)

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10) Frequently asked questions (grounded answers)

Q: “Isn’t renewable energy the reason bills went up?”
A: In New England, the largest driver of price spikes has been natural-gas supply constraints in winter (and global fuel volatility), not wind or solar per se. Renewables can lower average prices in specific hours (especially mid-day with solar) but require transmission and storage to deliver the full benefit. Order 1920 aims to plan those investments coherently. (Federal Energy Regulatory Commission)

Q: “Offshore wind failed in some states—why would it work here?”
A: It’s true that rising rates and supply chain issues forced contract re-sets in 2023–2024. But Vineyard Wind is putting electrons on the New England grid today, and the Gulf of Maine is moving forward with floating technology tuned for deep waters. The economics depend on long-term contracts, inflation trends, and transmission—none of which are static. (Offshore Wind Business)

Q: “Do we need biomass?”
A: That’s a policy choice. Biomass provides dispatchable, winter-relevant capacity and supports forestry jobs, but it must compete on cost and emissions with batteries, hydro imports, and demand response. If retained, make support conditional and time-bounded. (EIA)

Q: “Can community power really keep rates lower?”
A: Not every month, but over multi-year horizons, portfolio flexibility lets aggregations hedge better, procure at opportune times, and offer customer options (green, basic, fixed). Multiple NH communities report competitive offerings vs. standard-offer service. (CPCNH – Community Power NH)

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11) A pragmatic, bipartisan compact for NH energy

Here’s a program both ratepayers and climate hawks can live with:

1. Keep community power growing as the vehicle for local choice and prudent hedging.
2. Back targeted, least-cost efficiency and heat pumps for oil-heated homes—focus where the math is best. (EIA)
3. Pilot 5-MW municipal solar+storage at critical facilities in every county by 2027. (New Hampshire Municipal Association)
4. Modernize small hydro and preserve output via long-term RECs tied to verifiable grid services. (EIA)
5. Resolve biomass with transparent, performance-based contracts—or a clear off-ramp. (Business NH Magazine)
6. Shape transmission, don’t just pay for it: demand scenarios that reflect NH realities, support NECEC completion with adequate mitigation, and prepare interconnections for offshore wind imports. (Federal Energy Regulatory Commission)
7. Position NH firms for Gulf of Maine supply-chain roles (fabrication, mooring systems, electrical systems) and workforce training while larger projects mature. (Bureau of Ocean Energy Management)

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12) Bottom line

New Hampshire doesn’t need a silver bullet. It needs a portfolio: community-led procurement, cheap efficiency, targeted distributed resources, upgraded legacy hydro, hard-nosed treatment of biomass, and smart participation in regional wind and transmission. That set of moves is not ideological; it’s least-regrets. It reduces exposure to volatile fuels, it keeps the heat on in February, and it creates durable jobs in construction, electrical trades, and advanced manufacturing.

The energy transition is happening with or without us. If we choose to shape it—using real data, transparent trade-offs, and local control—New Hampshire can keep what Granite Staters value most: reliability, affordability, and independence.

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Sources (selected)

• U.S. EIA state profile & analysis: NH generation shares, coal retirements, biomass, wind, solar, heating fuels. (EIA)
• ISO-New England resource mix and state/regional profiles: load and PV forecasts, markets. (ISO New England)
• NH Department of Energy: RPS classes, 2025 RPS presentation; 2024 Renewable Energy Fund trends. (New Hampshire Energy)
• DSIRE (N.C. Clean Energy Technology Center): RPS overview; net metering rules. (DSIRE)
• Legislative & policy news: REF sweep (New Hampshire Bulletin); net-metering update (Concord Monitor). (New Hampshire Bulletin)
• Community Power (CPCNH): expansion and municipal rate updates. (CPCNH – Community Power NH)
• Offshore wind: BOEM Gulf of Maine auction/leases; Maine research array environmental review; Reuters & MA/Developer releases on Vineyard Wind 1 milestones. (Bureau of Ocean Energy Management)
• Transmission: FERC Order 1920 & 1920-A explainers. (Federal Energy Regulatory Commission)
• U.S. build-out: EIA on 2024 wind/solar and 2024–2025 battery storage; U.S. renewables’ 2024 share. (EIA)
• Burgess BioPower financial status. (Business NH Magazine)

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Have a correction, data point, or local project we should investigate? Email granitestatereport@gmail.com and we’ll review the evidence and update this report.