Maryland’s Solar Gap Is Forcing Smarter Deployment

A few weeks ago, we wrote about Maryland’s Affordable Solar Act and the push to bring 4 GW of solar online by 2035. Targets matter, but they are only part of the story. The real question is how Maryland actually builds that capacity within its regulatory and geographic constraints.

Regional Pressure Meets State Mandates

PJM Interconnection forecasts roughly 85 GW of peak demand growth over the next 15 years, driven by data centers, electrification, and broader load expansion. Much of that growth sits outside Maryland, but the grid impact is regional. As PJM tightens, reliable in-state generation becomes more valuable for a state that imports a significant share of its electricity.

At the same time, Maryland’s Renewable Portfolio Standard requires 50% renewable electricity by 2030, with the solar carve-out rising to 14.5% by 2028. The challenge is not ambition. It is timing. Policy requirements are moving faster than large-scale solar projects can realistically be permitted and built.

Why Large Projects Face Friction

Maryland is densely populated, and as projects scale, approvals become more complex. Once a project exceeds roughly 2 MW, it must go through a state-level review called a Certificate of Public Convenience and Necessity (CPCN). That process adds environmental and community review, a non-refundable deposit equal to 1% of project cost, and longer development timelines.

Crossing that 2 MW threshold materially changes execution risk. Developers respond accordingly. Instead of pursuing large greenfield projects with higher siting exposure, development is clustering around smaller distributed and community solar systems that can move through administrative approval and avoid regulatory cliffs.

Incentives Shape Deployment

State policy reinforces this shift. The Brighter Tomorrow Act introduced a 150% SREC compliance multiplier for eligible sub-5 MW projects. For a 2 MW community solar project, that can mean roughly $80,000 to $90,000 in incremental annual revenue, depending on SREC pricing. The structure rewards smaller, in-state projects that can move more predictably.

Community solar adds complexity, including a requirement that at least 40% of output serve low- and moderate-income subscribers. The state offsets that with LMI incentives, SREC multipliers, tax relief, and subscription stability. The framework is deliberate. It aligns financial returns with projects that are more likely to clear regulatory hurdles.

Reliability Over Scale

In 2024, Maryland recorded the highest Alternative Compliance Payments in program history, reflecting utilities’ inability to procure enough SRECs to meet the escalating solar carve-out. The Brighter Tomorrow Act was enacted in response to that structural gap. Supply has not kept pace with mandate, and mandates continue to rise.

Maryland’s system appears to be choosing reliability over size. In a land-constrained state facing tightening regional grid conditions, distributed and community solar are emerging as the clearest path to adding in-state generation. Hitting 4 GW is not just about ambition. It is about aligning incentives with what can actually get built on time. Maryland may not scale through mega-projects. It may scale through disciplined, distributed deployment.