SRECs Explained (2026): How to Earn Income From Your Solar Power

By SolarCostData Data Desk · Reviewed September 2026 · Corrections log

Of all the ways solar can pay you back, SRECs are the least understood — partly because they’re genuinely complicated, and partly because the ground has shifted a lot in the last few years. Here’s the honest 2026 version, including the states where this actually matters, roughly what a certificate is worth, and how the money actually reaches your bank account.

What an SREC is

Some states require their utilities to source a specific slice of power from solar — a “solar carve-out” inside the state’s Renewable Portfolio Standard. To prove they’ve hit that target, utilities buy SRECs : one certificate for every megawatt-hour (1,000 kWh) a solar system generates. If you own solar in one of those states, your system mints SRECs as it produces — a typical home system throws off roughly 8 to 12 a year — and you sell them, usually through an aggregator like Flett Exchange, SRECTrade, or Sol Systems.

The crucial point: that money is separate from what you save on your electric bill. Your panels cut your bill and generate certificates you can sell. It’s the closest thing residential solar has to a paycheck.

What sets the price: the compliance ceiling

SREC prices aren’t pulled out of thin air, and understanding why they move helps you judge whether a state’s market is worth counting on. Every carve-out program has a backstop called the Solar Alternative Compliance Payment (SACP) — a fine a utility pays for each SREC it fails to buy. That fine is the ceiling. No rational utility pays more for a certificate than the penalty it avoids, so SREC prices trade below the SACP, and how far below depends on supply and demand.

When a state’s solar carve-out grows faster than installations can keep up, SRECs get scarce, demand presses against the ceiling, and prices stay high. That’s exactly the situation in Washington DC, where an aggressive carve-out and limited rooftop space keep the market chronically undersupplied — which is why DC certificates trade in the hundreds while a state with abundant supply trades in the single digits. When installations outrun the target, the opposite happens: certificates flood the market and prices collapse, which is what hollowed out Pennsylvania and Ohio years ago. The lesson is that a high price today is a signal about scarcity, and scarcity can end when a state adds capacity — so don’t assume today’s number holds for the full life of your system.

SREC prices by state in 2026

This is where most explainers wave their hands and say “it varies.” It does, but you can put real numbers on it, and the differences are enormous:

Two things jump out. First, DC is in a league of its own — a certificate there is worth ten times one in Pennsylvania. Second, and more importantly, the pure traded-SREC model is fading. New Jersey, Massachusetts, and Illinois — three of the historically biggest markets — have all shifted new systems onto fixed-payment successor programs (SuSI , SMART, and Illinois Shines respectively). Those pay less than a hot SREC market at its peak, but they trade that upside for predictability: you know the per-MWh rate up front, often locked for 10–15 years, instead of riding a volatile market. New Jersey’s own rate illustrates the direction of travel — the residential incentive stepped down during 2026 by BPU order of 21 May 2026 (roughly $85/MWh for earlier registrations, dropping toward $77/MWh for later ones), and once you register, your rate is fixed for the full 15 years regardless of what happens after.

The chart below puts every market on one dollars-per-certificate scale, and it makes both points at once: how far DC floats above everyone else, and how the fixed programs trade that upside for a rate you can plan on.

Two very different cash-flow shapes

Not all SREC-style income arrives the same way, and the shape matters as much as the size when you’re planning around it.

• Ongoing traded income (DC, Maryland). Your system mints certificates as it produces, and you sell them periodically — monthly, quarterly, or on a schedule your aggregator runs. The income is a stream that continues for as long as the market and your certificates’ eligibility last, but each sale happens at whatever the market is paying that day.
• Ongoing fixed income (New Jersey SuSI). Same drip of certificates, but at a rate locked at registration. You trade the chance of a price spike for 15 years of numbers you can actually put in a spreadsheet.
• Upfront lump sum (Illinois Shines). Illinois is the outlier. Rather than paying you over time, the program pays your REC value as a lump sum shortly after the system is verified (delivered upfront or over a short window, depending on system size). That’s a very different thing to budget around — it behaves more like an instant rebate that lowers your net install cost than like a paycheck, and there’s no ongoing SREC income to plan on afterward.

Knowing which shape your state uses tells you whether SREC income belongs in the “reduces my upfront cost” column or the “adds to my yearly savings” column of your analysis.

What it adds up to: a worked example

Say you install a 7–8 kW system that produces around 10 MWh in its first year — so it mints roughly 10 SRECs annually. Here’s what that same production is worth depending on where the roof sits:

That table is the whole story of why location dominates. In DC, SREC income alone can approach the size of a household’s entire remaining electric bill after solar — a genuinely large lever. In New Jersey it’s a dependable few hundred to eight hundred dollars a year you can bank on. For a Baltimore-area rooftop , Maryland’s ~$50 certificates add roughly $500 a year on top of the bill savings priced on that page. In Pennsylvania it’s rounding error. None of these are guaranteed for the full life of the system except New Jersey’s fixed rate, so treat the DC and Maryland figures as this-year snapshots, not 15-year promises.

How to sell SRECs — in NJ, MD, PA, DC or anywhere else

Once your system is minting certificates, you have to turn them into cash, and the mechanics are the same in every market (in New Jersey the “sale” is really SuSI program registration, since the rate is fixed). There are essentially two paths:

• Spot sales. You sell each certificate at the current market price through an aggregator. You capture upside if prices rise, but you’re exposed if they fall. This suits a rich, tight market like DC where prices have held up.
• Fixed-price contracts. An aggregator or broker buys your future SRECs at a set price for a multi-year term. You give up the upside for certainty — useful if you want to lock SREC income into a loan-payoff plan, or if you’re nervous the market could soften as your state adds solar.

Either way, expect the aggregator to take a fee or a cut of the sale price, to require an approved production meter, and to handle registration paperwork. Compare a couple of them before committing — terms, fees, and payout speed vary — and don’t let a broker sign you into a long fixed contract at a soft price just because it feels safe.

Why the shift matters for your decision

The old SREC pitch — “prices could spike and you’ll cash in” — is mostly gone in the states that moved to fixed programs. That’s not necessarily bad news. A guaranteed $80/MWh for 15 years, as New Jersey’s SuSI offers, is something you can actually put in a payback calculation with confidence, which a floating SREC never was. If you’re in DC or Maryland, you’re still exposed to market swings and should treat the income as a range, not a line item.

Either way, the discipline is the same: model your base payback without any SREC income first, using the savings calculator and your state’s row in the payback-by-state ranking , then add certificate income as upside. That way a soft SREC market never turns a good decision into a bad one. Registration also has deadlines and paperwork in most programs, so if you’re in an SREC state, sort out enrollment when the system is installed — not years later, when you may have missed eligibility windows or let early certificates expire.

The watch-outs nobody mentions in the sales pitch

A few things routinely surprise homeowners after the fact:

• Certificates expire. DC’s have a five-year life, and other markets cap eligibility too. Sitting on them hoping for a spike can mean watching them lapse worthless.
• It’s usually taxable income. Unlike bill savings, SREC revenue is generally reportable income. Set some aside, especially in a high-income DC market.
• The rate can be reset — except where it’s fixed. Traded markets move with supply; only fixed programs (SuSI, SMART, Illinois Shines) lock your number. Don’t build a 15-year plan on a spot price.
• Leased systems usually don’t pay you. If your panels are third-party owned through a lease or PPA, the owner typically keeps the SRECs. Certificate income is another reason ownership beats leasing — see the lease-vs-buy breakdown .

The bottom line

SRECs are a real, sometimes substantial income stream — but a deeply local one. In DC they can move the needle hard; in Maryland they’re a useful bonus; in a fixed-program state like New Jersey they’re a dependable add-on; in Illinois they arrive as an upfront lump that lowers your install cost; and in the ~40 states with no market, they simply don’t exist. Check whether your state has a program at all in the incentives-by-state comparison , model your payback without the SREC income first, and confirm current rules on the public DSIRE database before you build them into your numbers.

SRECs and successor incentives are market and policy instruments, not guarantees. Prices, program rates, and enrollment deadlines change — verify your state’s current terms before counting on the income.

Sources

• State and utility programs — DSIRE program index , Database of State Incentives for Renewables & Efficiency, NC Clean Energy Technology Center.
• Electricity rates — U.S. Energy Information Administration, average price by state .

Figures on this page are estimates built from the sources above, not quotes. State and utility programs change and are often budget-limited — verify current terms on DSIRE and with your own utility before relying on them. Nothing here is tax, legal or financial advice.

Frequently asked questions

Sources: U.S. Energy Information Administration (EIA) electricity rates · DSIRE incentive records · public IRS/OBBBA guidance. Figures are modeled estimates, not quotes or tax advice. See our methodology.

Where to go next

• Incentives by state — Whether your state has a certificate market at all. Roughly 40 do not, and no amount of production changes that.
• Lease vs. buy — On a third-party-owned system the certificates belong to the lessor. Ownership is what keeps this income.
• Payback by state — Build the baseline payback first, with no certificate income in it, then add SRECs as upside.
• Net metering explained — Export credits and certificates are two separate payments for the same kilowatt-hour. Do not count either twice.
• 2026 savings calculator — Models bill savings alone, so a soft certificate market can never flip a decision that was already sound.