Deep dive: Community solar & shared renewables — the fastest-moving subsegments to watch

Community solar capacity in the United States surpassed 10 GW in early 2026, a 40% increase from the 7.1 GW operating at the end of 2024, according to the Solar Energy Industries Association (SEIA, 2026). More than 6 million households now participate in shared solar programs, and 22 states plus Washington, D.C. have enacted enabling legislation. But behind those headline figures, the sector is splitting into subsegments that are growing at dramatically different rates. Understanding which subsegments are accelerating, which are stalling, and where capital is flowing next is essential for procurement teams evaluating community solar as a component of corporate renewable energy strategy.

Why It Matters

Community solar exists to solve a structural problem: roughly 50% of US households and businesses cannot install on-site solar due to renting, shading, roof condition, or building type. Shared renewables allow these customers to subscribe to a portion of a larger off-site solar facility and receive credits on their utility bills. For procurement professionals, community solar offers a pathway to renewable energy sourcing that requires no capital expenditure, no on-site construction, and no long-term asset management obligations.

The market is maturing rapidly. The Inflation Reduction Act (IRA) established a 20% adder for community solar projects located in low-income communities and a 10% adder for projects sited on brownfields or in energy communities, making the effective investment tax credit as high as 60% for qualifying installations (US Department of Energy, 2025). These incentives are reshaping the economics of community solar and concentrating developer activity in specific subsegments where returns are highest.

At the same time, regulatory frameworks vary widely across states. Some markets like New York and Illinois have mature programs with standardized interconnection and billing credit mechanisms, while emerging markets in states like New Mexico, Delaware, and Virginia are just beginning to build programmatic infrastructure. For procurement teams, selecting the right community solar subsegment in the right geography is the difference between a straightforward clean energy procurement and a multi-year administrative burden.

Key Concepts

Community solar and shared renewables encompass several distinct models, each with different risk profiles, subscriber economics, and growth trajectories.

Virtual net metering (VNM) allows subscribers to receive bill credits proportional to their share of a community solar facility's output. The subscriber never takes physical delivery of electricity; instead, the utility calculates the production from the subscriber's allocated share and applies credits at a defined rate. VNM is the dominant model in states like Massachusetts, New York, and Minnesota.

Community choice aggregation (CCA) enables local governments to procure electricity on behalf of residents and businesses within their jurisdictions while the incumbent utility continues to deliver power. CCAs in California, Illinois, and New Jersey increasingly incorporate community solar into their procurement portfolios, creating large-volume off-take agreements that reduce subscriber acquisition costs.

Low-income community solar (LICS) targets households earning below 80% of area median income, providing guaranteed bill savings with no upfront cost or credit check requirements. The IRA's 20% adder and state-level carve-outs in New York, Illinois, Colorado, and New Jersey have created a distinct subsegment with its own financing structures, subscriber management platforms, and policy frameworks.

Commercial and industrial (C&I) community solar serves businesses, municipalities, and institutions that subscribe to larger allocations, typically 100 kW to 2 MW. This subsegment offers simpler subscriber management (fewer accounts per project) and more predictable off-take, but requires tailored contract structures and credit evaluation.

Subsegment Performance and Momentum

Subsegment	Growth Rate (2024-2026)	Avg. Project Size	Subscriber Savings	Capital Flowing	Policy Tailwind
Low-income community solar	65% CAGR	2-5 MW AC	15-25% bill reduction	$4.2B deployed	Strong (IRA + state carve-outs)
C&I community solar	45% CAGR	3-10 MW AC	10-20% bill reduction	$2.8B deployed	Moderate
CCA-integrated solar	55% CAGR	5-20 MW AC	5-15% bill reduction	$1.9B deployed	Strong (state CCA expansion)
Residential VNM	20% CAGR	1-5 MW AC	5-15% bill reduction	$3.1B deployed	Moderate
Agrivoltaic community solar	80% CAGR	2-7 MW AC	10-15% bill reduction	$600M deployed	Emerging
Battery-paired community solar	70% CAGR	2-5 MW AC + 1-4 MWh	8-18% bill reduction	$1.1B deployed	Strong (storage incentives)

What's Working

Low-income community solar is the fastest-growing subsegment by absolute capacity additions. New York's expanded NY-Sun program allocated $350 million specifically for low-income community solar between 2024 and 2026, resulting in 1.2 GW of new project applications in 2025 alone (NYSERDA, 2025). The Illinois Solar for All program, funded by the Climate and Equitable Jobs Act, has enrolled over 85,000 low-income households since 2023, with average annual bill savings of $420 per household. The combination of IRA adders and state incentives has pushed developer internal rates of return for LICS projects to 12 to 16%, compared to 8 to 11% for standard community solar, attracting mainstream infrastructure investors including BlackRock, Brookfield, and Goldman Sachs Renewable Power.

Battery-paired community solar is creating new value streams. Projects that co-locate 2 to 4 hours of battery storage with community solar arrays can capture time-of-use arbitrage, provide grid services, and offer subscribers enhanced bill savings by shifting generation to peak pricing periods. Nexamp's 15 MW solar plus 60 MWh storage project in Massachusetts demonstrated a 35% increase in subscriber bill credit value compared to a solar-only equivalent during summer 2025, with storage enabling credit generation during evening peak hours when solar production would normally be zero (Nexamp, 2025). The IRA's standalone storage investment tax credit, effective from 2025, further improves economics by allowing the storage component to claim its own 30 to 50% tax credit independent of the solar array.

CCA-integrated procurement is scaling subscriber acquisition. Marin Clean Energy (MCE), one of California's largest CCAs, contracted for 120 MW of community solar capacity across 18 projects in 2025, automatically enrolling 45,000 residential and small commercial accounts without individual subscriber acquisition. This approach eliminates the $200 to $400 per subscriber customer acquisition cost that burdens traditional community solar developers and compresses project development timelines by 6 to 12 months. Sonoma Clean Power, East Bay Community Energy, and Peninsula Clean Energy have adopted similar models, creating a pipeline of over 300 MW of CCA-integrated community solar in California alone (CalCCA, 2026).

Agrivoltaic community solar is opening new siting opportunities. Projects that combine solar generation with continued agricultural use, typically sheep grazing, pollinator habitat, or shade-tolerant crop production, are gaining traction in states where farmland conversion restrictions have historically blocked utility-scale solar development. Silicon Ranch's Regenerative Energy platform has deployed 1.2 GW of agrivoltaic projects across 12 states, with community solar applications in Minnesota, Oregon, and Virginia demonstrating that dual-use designs can satisfy both agricultural preservation requirements and renewable energy mandates (Silicon Ranch, 2025).

What's Not Working

Residential subscriber churn remains stubbornly high in mature markets. The average annual subscriber churn rate across the community solar industry is 12 to 18%, driven by customer moves, billing confusion, dissatisfaction with savings levels, and aggressive competitor solicitation. In New York, the state's largest community solar market, churn rates reached 22% in 2025 for projects relying on door-to-door and telemarketing subscriber acquisition channels (NYSERDA, 2025). Each subscriber replacement costs $250 to $500 in acquisition expense and creates 30 to 60 days of unsubscribed capacity during which the developer receives no revenue. Projects that fall below 90% subscription levels risk triggering loan covenant violations.

Interconnection delays are choking project pipelines. Community solar projects in states with congested distribution grids face interconnection study timelines of 18 to 36 months, with upgrade cost allocations that can exceed $500,000 per MW. In Massachusetts, over 2.5 GW of community solar projects were stuck in interconnection queues as of mid-2025, with Eversource Energy and National Grid processing applications at rates far below submission volumes. Developers report that interconnection uncertainty adds 15 to 25% to project development costs through extended carry of pre-development capital.

Billing credit mechanisms are under political pressure. Net metering successor tariffs in California (NEM 3.0), which reduced export compensation by 70 to 80% for behind-the-meter systems, have created uncertainty about the long-term value of community solar billing credits. While most community solar programs operate under separate tariff structures, the broader political environment of declining export compensation rates signals risk for subscriber economics. Minnesota's community solar garden program, one of the oldest in the country, underwent its third rate structure revision in 2025, reducing the applicable retail rate from the full residential rate to a lower "value of solar" rate that decreased subscriber savings by approximately 20% (Minnesota PUC, 2025).

Low-income subscriber verification creates administrative friction. Qualifying low-income subscribers requires income verification documentation that many households find burdensome or invasive. Programs that use categorical eligibility (participation in SNAP, LIHEAP, Medicaid, or public housing) streamline enrollment, but data-sharing agreements between state agencies and solar developers take 12 to 24 months to negotiate and implement. Developers in Colorado and New Jersey report that 30 to 40% of initial low-income subscriber applications are abandoned before income verification is completed.

Key Players

Established companies: Nexamp (largest US community solar developer with 3.5 GW pipeline), Summit Ridge Energy (backed by GIP, focused on mid-Atlantic and Midwest markets), Clearway Energy (community solar portfolio exceeding 1 GW), National Grid Renewables (community solar development across 10 states), US Solar (Minnesota-headquartered developer with focus on low-income programs)

Startups and growth-stage: Arcadia (subscriber management platform serving 600+ community solar projects), Solstice (low-income community solar enrollment specialist using EnergyScore qualification), Perch Energy (digital-first subscriber acquisition and management), PowerMarket (CCA-integrated community solar origination platform)

Investors and financiers: BlackRock Climate Infrastructure (committed $2B+ to community solar portfolios), Goldman Sachs Renewable Power (tax equity and project finance), Brookfield Renewable Partners (portfolio acquisitions in Northeast and Midwest), Generate Capital (infrastructure-as-a-service model for community solar), US Bank (leading community solar tax equity provider)

Action Checklist

• Evaluate state-level community solar programs in jurisdictions where your facilities or employees are located, prioritizing states with established billing credit mechanisms and low interconnection backlogs
• Request proposals from at least three community solar developers, comparing subscriber savings guarantees, contract terms, churn replacement provisions, and IRA adder eligibility
• Prioritize battery-paired community solar projects that can deliver peak-period credits, particularly in markets with time-of-use rate structures
• Assess low-income community solar programs for ESG reporting benefits and potential alignment with corporate social impact commitments
• Review interconnection timelines in target markets before committing to specific projects; favor projects with completed interconnection agreements over those still in queue
• Negotiate contract provisions that protect against billing credit rate changes, including floor pricing mechanisms or indexed escalators
• Consider CCA-integrated community solar where available, as these programs typically offer lower administrative burden and more stable subscriber economics

FAQ

Q: How does community solar differ from a virtual power purchase agreement (VPPA)? A: Community solar delivers direct utility bill credits to subscribers, reducing their retail electricity costs without requiring the subscriber to manage wholesale market exposure. VPPAs are financial hedges where the buyer receives renewable energy certificates (RECs) and a settlement payment based on the difference between the contract strike price and wholesale market prices. Community solar is simpler to implement, requires no energy market expertise, and provides immediate, visible bill savings, but is limited to states with enabling legislation and typically covers smaller load percentages than VPPAs.

Q: What subscriber savings levels should procurement teams expect? A: Guaranteed savings in mature markets typically range from 5 to 20% of the subscriber's applicable utility rate. The exact savings depend on the billing credit rate structure, the developer's discount to retail rates, and whether the project benefits from IRA adders or state incentives. Battery-paired projects in time-of-use markets can deliver savings at the higher end of this range. Procurement teams should require a minimum guaranteed savings floor in their subscription agreements and model sensitivity to potential billing credit rate changes.

Q: What are the main risks in a community solar subscription? A: The primary risks include billing credit rate reductions by regulators, project underperformance due to weather or equipment issues, developer insolvency, and interconnection delays that push commercial operation dates beyond contracted timelines. Mitigants include selecting developers with strong balance sheets or investment-grade sponsors, requiring performance guarantees backed by liquidated damages, and negotiating early termination rights triggered by sustained underperformance or regulatory changes that reduce savings below a specified threshold.

Q: How do IRA incentives affect community solar project economics? A: The IRA provides a base 30% investment tax credit for community solar projects, with additional adders of 10% for projects under 5 MW AC located in low-income communities, 10% for projects that reserve at least 50% of output for low-income subscribers, and 10% for projects on brownfields or in energy communities. A fully qualifying low-income community solar project on a brownfield site can access a combined 60% tax credit, dramatically improving developer returns and enabling deeper subscriber discounts. These adders are available through at least 2032, providing long-term policy certainty for project development.

Sources

• Solar Energy Industries Association. (2026). US Community Solar Market Outlook 2026. Washington, DC: SEIA.
• US Department of Energy. (2025). Inflation Reduction Act: Community Solar Tax Credit Guidance and Adder Eligibility Requirements. Washington, DC: DOE.
• NYSERDA. (2025). NY-Sun Community Solar Program: Annual Performance and Market Report. Albany, NY: New York State Energy Research and Development Authority.
• Nexamp. (2025). Community Solar Plus Storage: Performance Results and Subscriber Value Analysis. Boston, MA: Nexamp Inc.
• CalCCA. (2026). Community Choice Aggregation and Community Solar: Integrated Procurement Trends in California. San Francisco, CA: California Community Choice Association.
• Silicon Ranch. (2025). Regenerative Energy Platform: Agrivoltaic Community Solar Project Performance and Agricultural Outcomes. Nashville, TN: Silicon Ranch Corporation.
• Minnesota Public Utilities Commission. (2025). Community Solar Garden Program: Rate Structure Revision and Value of Solar Tariff Update. St. Paul, MN: MPUC.