Community solar allows utility customers to subscribe to a share of a shared solar array and receive credits on their electric bill — no rooftop required. The developer builds the array, the utility applies bill credits, and subscribers pay a discounted rate for their allocation. Fifteen states plus DC have active community solar programs, with New York, Illinois, Massachusetts, Minnesota, Colorado, Maryland, and New Jersey leading in installed capacity.
A single community solar project touches state energy law, utility interconnection queues, local land use permitting, IRS tax equity rules, and subscriber marketing — all on overlapping timelines. A Gantt chart is the only practical way to manage a process where one delayed deliverable (an interconnection study result, a subscriber milestone) can cascade into months of cost overrun.
Phase 1: Market Selection and Site Control (Months 1–6)
State program analysis (Weeks 1–4). Not all community solar programs are equally developer-friendly. Key variables: program capacity caps (some states run oversubscribed queues), the bill credit rate methodology (avoided cost vs. retail rate — retail rates produce better subscriber economics), and LMI (Low-to-Moderate Income) subscriber requirements. Most active states require 30–51% of subscribed capacity to serve LMI households. Plot the state regulatory calendar: most program allocations open on fixed dates and close when oversubscribed, so missing the window costs a full cycle.
Site selection (Weeks 3–8). Community solar arrays are typically 1–5 MW AC, sized to utility distribution interconnection limits (anything larger triggers costlier transmission-level studies). Site criteria: agricultural or lightly developed land within 1–3 miles of an existing distribution substation (reduces interconnection cost and queue complexity), flat or south-facing terrain, and minimum 5–10 acres per MW. Wetland mapping and soil surveys run concurrently with site identification — a parcel with jurisdictional wetlands triggers US Army Corps of Engineers Section 404 review, which can add 6–12 months.
Site control (Weeks 6–12). Negotiate an option-to-lease agreement with the landowner. Solar lease rates in agricultural states run $500–$1,500/acre/year. The option period should cover the full permitting timeline (24–36 months minimum) with extension rights — a deal that closes before permits are in hand gives the landowner termination leverage at the worst moment.
Preliminary interconnection screening (Weeks 4–10). File a pre-application with the utility under the SGIP (Small Generator Interconnection Procedure). The pre-application report (typically $500–$2,000 fee, returned in 20 business days) identifies whether the targeted point of interconnection has available capacity for the proposed load. A negative result means either a more expensive interconnection upgrade or a new site — the earlier this is known, the better.
Phase 2: Development and Permitting (Months 4–24)
Interconnection application (Months 4–8, outcome: Months 16–36). The interconnection application and queue position is the single biggest risk variable in community solar development. FERC Order 2023 (2023) reformed the interconnection process, but queues at many ISOs and RTOs remain 18–36 months long. File as early as possible. The application triggers a cluster study (Months 6–12) and then a facility study (Months 12–24), culminating in an Interconnection Agreement (IA). The IA defines the cost responsibility for any required network upgrades — a figure that can range from zero to several million dollars and determine project viability.
State regulatory registration (Months 4–10). Most community solar states require project registration with the state public utility commission (PUC) or energy office before construction. The registration confirms compliance with program rules, LMI requirements, and subscriber protections. Registration timelines vary from 30 days (Minnesota) to 6 months (New York).
Local permitting (Months 6–14). Ground-mounted solar in agricultural zones requires a conditional use permit (CUP) or special use permit (SUP) in most jurisdictions. Community opposition to solar on farmland is increasing — agricultural preservation advocates argue against removing productive acres from production. Mitigations: agrivoltaic design (sheep grazing under panels), pollinator habitat plantings, and setbacks from property lines and roads. Environmental review: Phase I ESA, SHPO (State Historic Preservation Office) consultation, and FAA obstruction evaluation if any structure exceeds 200 feet AGL.
Engineering and design (Months 8–16). Single-axis tracker systems (NEXTracker, Array Technologies, GameChange Solar) are standard for utility-scale ground-mount — they improve energy yield 15–25% vs. fixed tilt. Panel selection (bifacial modules add 5–10% yield premium), inverter specification (string vs. central), and SCADA (Supervisory Control and Data Acquisition) design all occur during this phase. The interconnection utility will require protection relay settings and an anti-islanding scheme that meets IEEE 1547-2018.
Phase 3: Financing and Construction (Months 18–30)
Tax equity financing (Months 14–22). The federal Investment Tax Credit (ITC) under IRA Section 13102 provides a 30% base credit on qualified project costs, with adders for domestic content (+10%), energy communities (+10%), and low-income benefit (+10–20%). Tax equity investors (banks, insurance companies) monetize these credits in a partnership flip or inverted lease structure. Tax equity underwriting requires a finalized interconnection agreement, executed engineering contracts, and a majority of subscribers under contract — which creates a chicken-and-egg dynamic: you need subscribers to close financing, but subscribers need a project to sign up for.
Debt financing (Months 18–24). Construction loan from a lender experienced in community solar (KeyBank, Live Oak Bank, Clēnera). The construction loan converts to a term loan at COD (Commercial Operation Date). Lenders will require long-term subscriber agreements representing 80–90% of project capacity.
Construction (Months 22–30). EPC (Engineering, Procurement, Construction) contract with a solar contractor experienced in ground-mount utility-scale installations. Critical path: pile driving (geotechnical report determines pile type — helical vs. driven steel), racking installation, panel mounting, electrical BOS (balance of system), inverter installation, and utility revenue meter installation. Utility witness testing and SCADA commissioning conclude construction.
Phase 4: Subscriber Enrollment (Months 12–34, overlapping)
Subscriber acquisition timeline. Begin subscriber outreach before construction, not after. Most programs require proof of subscriber commitments before the interconnection agreement is executed. LMI subscriber recruitment is the hardest component: it requires community outreach in multiple languages, income verification (utility program administrators often handle this), and simplified enrollment for populations that may not have stable internet access or banking relationships.
Subscription management platform. Platforms like Arcadia Power, Clean Energy Collective (now Omnidian), or SunCentral handle subscription agreements, billing integration with the utility, and subscriber communications. Ensure the platform integrates with your specific utility's billing system — each utility has different EDI (Electronic Data Interchange) requirements for community solar credit pass-through.
Commercial operation and ongoing management. At COD, notify all subscribers, confirm utility bill credit start dates, and activate monitoring. Project performance monitoring (production vs. P50 forecast), subscriber churn management (typical annual churn: 5–15%), and replacement subscriber enrollment are ongoing operational functions. Build these into the Gantt as repeating tasks from COD onward.
Building the Gantt
A community solar Gantt should have four swim lanes: Regulatory & Interconnection, Development & Permitting, Financing & Construction, and Subscriber & Commercial. Color-code the interconnection queue timeline in red — it is the constraint everything else must work around. Set milestones at: pre-application result, interconnection application filed, cluster study complete, facility study complete, IA executed, local permit approved, tax equity LOI, construction start, COD, and 90% subscriber enrollment. Review the Gantt with your interconnection attorney and PUC counsel at least monthly — regulatory timelines shift, and a static Gantt becomes misleading quickly.