I. How the credit reaches your bill
Community solar in New York runs through a program the Public Service Commission calls Community Distributed Generation, or CDG (shared solar projects whose output is split among subscribers who get bill credits). You do not own a panel. You subscribe to a share of a local array, usually one in your own utility's territory, and each month the electricity it sends to the grid earns credits that land on your delivery bill.
Those credits are priced by something called the Value Stack, or VDER (the Value of Distributed Energy Resources, the formula that replaced simple net metering for these projects). Instead of crediting every kilowatt-hour at the retail rate, the Value Stack pays more when and where the power is worth more to the grid, and less when it is not. It is fairer in theory. It is also harder to explain to a subscriber, which is part of why the mailers stay vague.
II. Why projects chase the same substations
A solar developer cannot just pick a sunny field. The array has to connect to a distribution feeder (the medium-voltage line that carries power down a road) with room to take the extra energy, and it has to sit near a substation that can handle the flow back up the system. In rural upstate, the good spots are limited: flat, cleared land near a three-phase line and a substation with headroom. Dairy farms fit the description, which is why so many arrays now share fields with cows.
Everyone reads the same maps. National Grid, NYSEG, and RG&E each publish a hosting capacity map (a public map showing roughly how much new generation each part of the grid can absorb), and developers cluster their applications on the same green spots. When a dozen projects target one substation, the first few fit and the rest do not, at least not without upgrades that no single project wants to pay for alone.
III. The backlog, honestly
When more projects want to connect than a feeder can hold, the utility studies what it would cost to upgrade the wires, the transformers, or the substation itself. Those studies take time, the cost estimates can run high, and the bill often gets split among the projects waiting in line through a cost-sharing process. If one developer drops out, the math shifts for everyone behind them, and the queue reshuffles. Projects that looked ready can stall for a year or more, at last public report.
New York knows this is the bottleneck. The state has set a goal of roughly 10 gigawatts of distributed solar by 2030, and community solar is a big share of how it plans to get there, but the interconnection queue is where the schedule slips. Whether a given project near you comes online next spring or the spring after depends less on sunshine than on whether the substation down the road gets its upgrade funded and scheduled. It depends, and anyone who tells you otherwise is selling something.
IV. Worth watching this month
1. Whether the utilities post updated hosting capacity maps this fall, since the green spots move as projects connect and others drop out (routine, but the clearest early read on where new arrays can still fit).
2. The Public Service Commission's ongoing interconnection proceedings at dps.ny.gov, where the rules for cost-sharing and study timelines get revised, usually in slow increments.
3. NYSERDA's NY-Sun dashboard, which reports installed and pipeline community solar capacity and is the plainest public sign of whether growth is speeding up or stalling.
4. Any notice from your own community solar provider about a project delay, which is common and rarely means your credits are at risk.
5. NYISO's fall planning reports, which matter less for community solar directly but flag the upstate transmission constraints that shape where larger clean energy projects can land.