Community Solar Programs: How Shared Solar Works in the US

Community solar programs allow households and businesses without suitable rooftops to access solar-generated electricity by subscribing to a share of a larger, off-site solar array. This page covers how these programs are structured, the regulatory frameworks that govern them, how credits flow to subscribers, and the key differences between program types. Understanding community solar is essential for anyone evaluating solar financing options or state solar incentives who cannot or does not wish to install panels on their own property.

Definition and scope

Community solar — also called shared solar or solar gardens — refers to grid-connected solar generation facilities whose output is allocated among multiple subscribers rather than a single property owner. The National Renewable Energy Laboratory (NREL) defines community solar as any solar project or purchasing program, within a utility service territory, that allows customers to buy or lease a portion of the energy produced.

In the United States, community solar operates under a patchwork of state statutes and utility commission rules rather than a single federal standard. The Federal Energy Regulatory Commission (FERC) governs wholesale electricity markets and interstate transmission but leaves retail community solar program rules to individual state public utility commissions (PUCs). As of 2023, 43 states plus the District of Columbia had at least one active community solar project, according to the NREL Community Solar Market Trends report.

Eligible participants typically include residential customers, small businesses, nonprofits, and government entities. Low-to-moderate income (LMI) carve-outs are embedded in the statutory frameworks of states including Minnesota, New York, and Illinois, reserving a defined percentage of project capacity — often 30% or more — for qualifying households.

How it works

The operational model follows a structured chain from generation to bill credit:

1. Project development — A developer or utility constructs a ground-mount or rooftop solar array, typically ranging from 500 kilowatts (kW) to 5 megawatts (MW), sized to the subscriber base the local utility commission permits.
2. Utility interconnection — The project applies for grid interconnection under the utility's tariff, a process governed by state commission rules and, where applicable, FERC Order 2023 for larger projects. See solar interconnection process for the technical stages.
3. Subscriber enrollment — Customers sign a subscription agreement for a defined share of the array's output, measured in kilowatt-hours (kWh) or kilowatts of capacity.
4. Generation and metering — The array generates electricity metered at the project site. A third-party administrator or the utility tracks each subscriber's proportional share of monthly output.
5. Bill credit allocation — The utility applies a per-kWh credit to each subscriber's electricity bill. Credit rates are set by the state commission — Minnesota's Value of Solar Tariff, for example, set a 2014 base rate calculated from avoided-cost components including fuel, transmission, and carbon value.
6. True-up or carry-forward — Unused credits typically carry forward monthly, though annual expiration rules vary by state program.

The credit mechanism differs fundamentally from net metering, where a customer's own system offsets their bill. Community solar credits originate from a separate facility and are applied as a bill reduction rather than a meter offset, meaning subscribers remain full retail customers of their utility.

Common scenarios

Utility-sponsored programs are administered directly by investor-owned utilities or rural electric cooperatives. Subscribers pay a fixed monthly fee or a per-kWh rate set by the utility tariff. These programs carry low subscriber risk but typically limit subscription terms to 12–36 months.

Third-party or independent developer programs are built and operated by private companies. Subscribers sign contracts ranging from 1 year to 25 years, with credit rates that may be fixed, indexed, or discounted relative to the retail rate. Long-term contracts require careful review of early-termination provisions and credit portability if a subscriber moves.

Municipal and cooperative programs serve members of electric cooperatives or municipal utilities, which are not regulated by state PUCs in the same manner as investor-owned utilities. The rules for these programs derive from cooperative bylaws and, in some cases, Rural Utilities Service (RUS) guidelines under the U.S. Department of Agriculture.

Low-income community solar programs pair subscription discounts with income verification. Illinois's Path to 100 legislation, enacted under the Climate and Equitable Jobs Act (Public Act 102-0662), established a requirement that 50% of new community solar capacity serve LMI customers.

For comparison, on-site residential solar energy systems require the homeowner to manage permits and approvals, equipment selection, and maintenance. Community solar subscribers transfer those responsibilities to the project operator entirely.

Decision boundaries

Several structural factors determine whether a community solar subscription is appropriate for a given situation:

• Utility eligibility — Community solar is only available where the local utility operates an approved program or accepts virtual net metering credits from a qualifying project. Not all utilities in all 43 active states offer programs in every service territory.
• Credit rate vs. retail rate — If the bill credit rate is lower than the subscriber's retail electricity rate, the economic benefit is reduced. Subscribers should compare the credit rate disclosed in the subscription agreement against their current utility rate schedule.
• Subscription size — Most programs limit subscriptions to 100% to 120% of a customer's prior 12-month average electricity consumption, preventing over-subscription that generates uncompensated excess credits.
• Contract portability — Subscribers who relocate outside the utility's service territory may be unable to transfer their subscription. Termination fees in third-party agreements can range from $0 to several hundred dollars depending on contract structure.
• LMI qualification — Households meeting income thresholds under program-specific definitions (often at or below 80% of area median income) may access discounted subscription rates or priority enrollment in carve-out capacity tranches.

Community solar sits within a broader spectrum of solar access options. Understanding grid-tied solar systems, solar battery storage systems, and solar system costs provides context for comparing community solar against direct ownership.

References

• NREL Community Solar Market Trends — National Renewable Energy Laboratory overview and market data
• FERC Order 2023 — Federal Energy Regulatory Commission interconnection reform rule
• Illinois Climate and Equitable Jobs Act, Public Act 102-0662 — Statutory basis for Illinois community solar LMI requirements
• U.S. Department of Agriculture Rural Utilities Service — RUS guidelines relevant to cooperative solar programs
• Minnesota Public Utilities Commission – Value of Solar — Minnesota rate methodology for community solar credits