Virginia Clean Economy Act: Solar Energy Implications

The Virginia Clean Economy Act (VCEA), enacted in 2020 as Virginia Code § 56-585.1 et seq., is the legislative framework that mandates the commonwealth's transition to 100% carbon-free electricity by 2050. This page examines how the VCEA's renewable portfolio standards, capacity mandates, and utility procurement requirements directly shape solar energy development at residential, commercial, and utility scales across Virginia. Understanding the VCEA's mechanics is essential for anyone navigating solar project timelines, utility interconnection, or compliance obligations in the state.

• Definition and Scope
• Core Mechanics or Structure
• Causal Relationships or Drivers
• Classification Boundaries
• Tradeoffs and Tensions
• Common Misconceptions
• Checklist or Steps
• Reference Table or Matrix

Definition and Scope

The Virginia Clean Economy Act is codified primarily at Virginia Code § 56-585.1 and administered by the Virginia State Corporation Commission (SCC). The law establishes a mandatory renewable portfolio standard (RPS) for the two largest investor-owned utilities in Virginia — Dominion Energy Virginia and Appalachian Power Company — requiring each to achieve progressively higher percentages of electricity sales from renewable sources on a fixed schedule terminating at 100% by 2050.

The VCEA's scope is explicitly limited to investor-owned electric utilities subject to SCC jurisdiction. Electric cooperatives and municipal utilities are not bound by the same mandatory RPS schedule under the VCEA, though they may participate voluntarily or face separate state-level guidance. Federal installations, off-reservation federal land, and out-of-state generating facilities interconnected to the PJM grid fall outside the VCEA's direct compliance obligations, even if their output is counted toward Virginia's renewable goals through renewable energy certificates (RECs).

The geographic coverage is the Commonwealth of Virginia. Matters governed by federal law — including Federal Energy Regulatory Commission (FERC) transmission tariffs, PJM Interconnection rules, and IRS tax credit eligibility — operate in parallel but are not covered by this page. For a broader look at how Virginia solar projects are structured before engaging VCEA-specific rules, the conceptual overview of Virginia solar energy systems provides foundational context.

Core Mechanics or Structure

Renewable Portfolio Standard Schedule

Under the VCEA, Dominion Energy Virginia must meet an RPS of 30% renewable energy by 2030, scaling to 100% by 2045. Appalachian Power must reach 100% by 2050. These percentages are measured against total Virginia retail electric sales, not installed capacity. Each percentage point of retail sales represents hundreds of megawatts of renewable generation at current load levels.

Offshore Wind and Solar Carve-Outs

The VCEA creates specific capacity targets for solar and onshore wind. Dominion Energy Virginia is directed to build or procure 16,100 megawatts of solar and onshore wind by 2035 (Virginia Code § 56-585.1:11). Of this, the act reserves 200 megawatts for small agricultural and small community solar projects, and sets aside a minimum 3% of the solar and wind portfolio for low-income community solar programs. These carve-outs create dedicated procurement channels separate from general utility-scale competitive solicitations.

Renewable Energy Certificates

RECs are the accounting instrument for VCEA compliance. One REC represents 1 megawatt-hour of electricity generated from a qualifying renewable source. Virginia-domiciled solar projects produce Virginia RECs (VARECs or SRECs depending on context). The SCC oversees REC retirement and tracks compliance through annual filings. Solar system owners who retain their RECs can sell them into the SREC market in Virginia, creating a secondary revenue stream tied directly to VCEA compliance demand.

Energy Storage Mandate

The VCEA requires Dominion Energy Virginia to develop at least 2,700 megawatts of energy storage capacity by 2035. This mandate accelerates demand for co-located battery systems, including residential and commercial storage installations. The mechanics of storage integration are explored in detail at solar energy storage batteries in Virginia.

Causal Relationships or Drivers

The VCEA's capacity targets function as demand signals that propagate through the solar supply chain in measurable ways.

Utility Procurement → Project Pipeline

Dominion's 16,100 MW mandate creates recurring competitive solicitations for power purchase agreements (PPAs). Each solicitation cycle opens procurement windows that drive utility-scale solar development, particularly on agricultural and formerly industrial land parcels. This connects directly to the growth in agricultural solar installations in Virginia and utility-scale solar projects in Virginia.

RPS Compliance Costs → Rate Cases

When utilities incur costs meeting VCEA mandates — through capital expenditure on owned generation or PPA costs for third-party projects — those costs flow into SCC-reviewed rate cases. The SCC retains authority to disallow "unreasonable" costs, creating a regulatory check on compliance spending. This tension between mandate speed and affordability is a live feature of Virginia utility regulation.

Low-Income Carve-Outs → Access Programs

The 3% low-income carve-out has prompted Dominion to develop structured community solar programs with income-qualifying subscription tiers. The operational details of these programs are covered at low-income solar access in Virginia and community solar programs in Virginia.

REC Demand → SREC Prices

Utility compliance demand for RECs sets a floor on SREC market prices. When compliance obligations tighten as the RPS percentage steps up each year, REC demand rises, which theoretically supports SREC prices. However, the relationship is not linear — surplus REC banking and out-of-state REC imports can suppress prices even when the RPS percentage climbs.

Classification Boundaries

The VCEA distinguishes among solar project categories in ways that affect permitting, procurement eligibility, and incentive access.

Utility-Scale vs. Distributed Generation

Projects above 1 megawatt AC interconnecting at transmission or subtransmission voltage are classified as utility-scale and subject to full SCC project approval under Virginia Code § 56-580. Projects below 1 MW interconnecting at distribution voltage are classified as distributed generation (DG) and subject to the net metering statute and SCC net metering rules.

Small Agricultural Solar

The 200 MW carve-out for small agricultural and small community solar defines "small agricultural" as projects 1 MW or smaller sited on agricultural land. These projects qualify for streamlined SCC review and dedicated procurement slots, making them categorically distinct from general competitive utility procurement.

Community Solar

Community solar programs under the VCEA allow customers to subscribe to shares of a solar facility without direct rooftop installation. Subscription sizes, billing credit mechanisms, and income qualification thresholds are defined by SCC order, not by individual utility tariff. The full regulatory framework is documented at the regulatory context for Virginia solar energy systems.

Tradeoffs and Tensions

Speed vs. Grid Reliability

The VCEA's fixed statutory deadlines constrain how quickly the SCC can pace project approvals. PJM interconnection queues — which routinely take 3 to 5 years for large projects — operate on federal timelines outside the SCC's control. This creates a structural risk that statutory capacity targets and actual grid-ready MW diverge.

Utility Ownership vs. Third-Party Development

The VCEA generally favors utility ownership of generation assets, which supports regulatory cost recovery but limits the share of capacity built by independent power producers. Consumer advocates and independent developers have argued before the SCC that utility ownership preferences reduce competitive pressure and raise long-term consumer costs.

Distributed Solar vs. Centralized Utility Build

The 16,100 MW mandate is primarily a utility procurement mandate, not a distributed solar mandate. Rooftop solar at the residential level contributes to overall renewable generation but does not count directly toward utility VCEA compliance unless the utility purchases the associated RECs. Homeowners who sell or assign their RECs to the utility receive no separate VCEA "credit" — the benefit flows to the utility's RPS compliance account, not to any homeowner incentive program.

Property Rights and Visual Impacts

Large-scale solar development enabled by VCEA mandates has prompted local land-use conflict in rural Virginia counties. Some Virginia counties have enacted restrictive zoning ordinances to limit solar farm siting. The interaction between state-level VCEA policy and local zoning authority is examined at local zoning and land use for solar in Virginia.

Common Misconceptions

Misconception: The VCEA guarantees 100% renewable electricity for all Virginia customers by 2050.
Correction: The VCEA mandates that Dominion Energy Virginia reach 100% carbon-free electric supply by 2045 for its regulated Virginia service territory. Electric cooperatives, municipal utilities, and customers who have opted into competitive retail supply arrangements are not directly covered by the same mandate.

Misconception: Installing rooftop solar automatically contributes to VCEA compliance.
Correction: Rooftop solar contributes to VCEA compliance only if the associated RECs are transferred to Dominion or another VCEA-regulated utility. If the homeowner retains the RECs (as is common in net metering arrangements where no explicit REC transfer occurs), those RECs do not count toward utility RPS compliance.

Misconception: The VCEA sets retail electricity rates.
Correction: The VCEA does not set rates. It sets renewable energy procurement mandates. Rates are determined through SCC rate cases, which review whether compliance costs were prudently incurred. The SCC can — and has — modified or deferred utility cost recovery even when the underlying investment was VCEA-mandated.

Misconception: Community solar and rooftop solar are treated identically under the VCEA.
Correction: They are structurally different. Community solar subscriptions are billed through a separate tariff structure with subscription caps set by SCC order. Rooftop solar is governed by net metering rules. The billing credit mechanisms, capacity limits, and income-tier eligibility differ materially between the two pathways.

Checklist or Steps

The following sequence describes the phases a solar project developer or utility analyst encounters when assessing VCEA alignment for a proposed solar project in Virginia.

1. Determine project size and interconnection voltage — Projects above 1 MW AC connecting to transmission typically require SCC project approval under § 56-580; projects below 1 MW at distribution voltage follow net metering and interconnection tariff rules.
2. Classify the project type — Identify whether the project is utility-owned, third-party PPA, community solar, small agricultural, or distributed rooftop. Each classification triggers different procurement and regulatory pathways.
3. Identify applicable SCC dockets — Review active Dominion or Appalachian Power solicitation dockets at the SCC (scc.virginia.gov) for open procurement windows matching the project's size and type.
4. Assess REC ownership and transfer terms — Determine whether RECs will be retained by the project owner, assigned to the utility, or sold on the open SREC market. This determination affects both project economics and utility VCEA compliance accounting.
5. Confirm local zoning classification — Verify that the project site's local zoning permits solar energy facilities at the proposed scale. Some Virginia counties require conditional use permits or special use permits for ground-mount solar above a specified acreage threshold.
6. Obtain SCC interconnection approval — File an interconnection application under the applicable utility's SCC-approved interconnection tariff. For Dominion, see Dominion Energy solar interconnection in Virginia; for Appalachian Power, see Appalachian Power solar interconnection in Virginia.
7. Obtain local building and electrical permits — Residential and commercial DG projects require local building permits and electrical inspections. Permitting concepts are detailed at the permitting and inspection concepts page.
8. Register generating unit with PJM GATS — Projects generating RECs for VCEA compliance tracking must be registered in PJM's Generation Attribute Tracking System (GATS) to produce certified RECs.
9. File annual production and REC retirement records — Utilities filing annual RPS compliance reports with the SCC must reconcile REC retirements against Virginia retail sales. Project owners supplying RECs should maintain documentation of GATS transfers.

Reference Table or Matrix

VCEA Solar Provisions: Key Parameters

For a full orientation to the Virginia solar landscape, including system types and financing structures, the Virginia Solar Authority home provides navigational access to the full reference library covering residential, commercial, and utility-scale solar topics across the commonwealth.

References

• Virginia Code § 56-585.1 — Virginia Clean Economy Act
• Virginia Code § 56-585.1:11 — Renewable Energy Portfolio Standard
• Virginia State Corporation Commission (SCC)
• Federal Energy Regulatory Commission (FERC)
• PJM Interconnection — Generation Attribute Tracking System (GATS)
• Virginia Code § 56-580 — Electric Utility Facility Approval
• Virginia Legislative Information System — Title 56