Net Metering in Virginia: Rules and Compensation Structures

Net metering in Virginia governs how residential and commercial solar customers receive credit for surplus electricity delivered to the utility grid. The rules establish the rate at which that credit is calculated, the capacity limits triggering eligibility, and the administrative obligations for both utilities and system owners. Understanding these mechanics is essential for accurately projecting the financial return on any grid-tied solar installation in the Commonwealth.

• Definition and scope
• Core mechanics or structure
• Causal relationships or drivers
• Classification boundaries
• Tradeoffs and tensions
• Common misconceptions
• Checklist or steps (non-advisory)
• Reference table or matrix

Definition and scope

Net metering is a billing arrangement authorized under Virginia Code § 56-594 that requires investor-owned utilities to credit eligible customer-generators for surplus electricity fed into the distribution grid. The credit offsets the customer's consumption charges in subsequent billing periods rather than being paid as cash on a monthly basis.

Virginia's State Corporation Commission (SCC) exercises primary jurisdiction over net metering tariffs, interconnection procedures, and dispute resolution for the state's investor-owned utilities — principally Dominion Energy Virginia and Appalachian Power Company (APCo). The SCC's authority derives from Title 56 of the Code of Virginia, and its administrative rules are elaborated through case orders issued under relevant docket proceedings.

Scope limitations: This page addresses Virginia's state-level net metering framework as it applies to residential and small commercial customers served by investor-owned utilities regulated by the SCC. It does not cover net metering arrangements administered by rural electric cooperatives, municipal utilities, or federal power authorities operating within Virginia, whose rules vary and fall outside SCC tariff jurisdiction. Federal interconnection standards set by the Federal Energy Regulatory Commission (FERC) under Order 2222 and related rulemakings provide an upstream layer of authority but are not addressed in detail here.

Core mechanics or structure

A net metering system uses a bidirectional meter — or two separate meters — to record electricity consumed from the grid and electricity exported to the grid in separate registers. The billing calculation computes the net difference between consumption and export over a defined billing period, typically one month.

Credit rate: Under the framework established by Virginia's Clean Economy Act (enacted in 2020), the default compensation rate for net excess generation (NEG) credits is the full retail rate for electricity. Credits accumulate as a dollar-denominated or kilowatt-hour balance applied against future bills.

Annual true-up: Accumulated NEG credits roll forward month to month. At the end of each 12-month anniversary period, any remaining credit balance is either carried forward under utility-specific tariff provisions or, depending on tariff design, compensated at an avoided-cost rate. The SCC has historically required utilities to publish the applicable avoided-cost rate in approved tariff filings.

Capacity thresholds: Virginia Code § 56-594 establishes a system size cap tied to the customer's expected annual electricity consumption, generally set at 100% of that consumption in kilowatt-hours. As of the SCC's most recent tariff approvals, Dominion Energy Virginia's net metering program accepts residential systems up to 20 kilowatts (kW) AC and non-residential systems up to 1 megawatt (MW) AC under standard net metering (Virginia Code § 56-594). APCo maintains comparable thresholds under its SCC-approved tariff.

For a technical overview of how grid-tied systems interact with utility infrastructure, see How Virginia Solar Energy Systems Work.

Causal relationships or drivers

Several legislative and market forces have shaped Virginia's net metering structure.

Virginia Clean Economy Act (VCEA): The VCEA, codified at Virginia Code § 56-585.1 et seq., directed the SCC to expand net metering access, raise aggregate program capacity limits, and study potential successor tariff structures. The Act set a statewide aggregate net metering capacity target that scales with each utility's peak demand. The VCEA also accelerated Dominion's integrated resource planning obligations, which indirectly influence interconnection queue processing times.

Aggregate capacity caps: Virginia law had historically imposed a 1% of the utility's adjusted Virginia peak-load forecast as a cap on aggregate net metering participation. The VCEA revised this ceiling upward, requiring the SCC to evaluate and potentially eliminate caps as penetration levels grow (Virginia Code § 56-594.01).

Interconnection standards: Net metering eligibility is conditioned on completing an interconnection application reviewed under the utility's SCC-approved interconnection procedures. These procedures incorporate IEEE Standard 1547-2018 (Standard for Interconnection and Interoperability of Distributed Energy Resources with Associated Electric Power Systems Interfaces) as a technical baseline. For Dominion-specific processes, the Dominion Energy solar interconnection framework governs application timelines and technical screening.

Rate design pressures: Utility arguments that net metering creates a cross-subsidy — whereby non-solar customers bear a higher share of fixed infrastructure costs — have driven SCC proceedings examining demand charges, standby charges, and alternative compensation structures.

Classification boundaries

Net metering in Virginia applies across distinct customer and system categories, each carrying different administrative requirements.

Residential vs. non-residential: Residential customers face a 20 kW AC system cap. Non-residential customers may qualify for standard net metering up to 1 MW AC, with larger projects potentially subject to alternative interconnection tracks rather than simplified net metering tariffs.

Technology eligibility: Virginia's net metering statute covers solar photovoltaic, wind, combined heat and power, and certain other eligible generating technologies. Standalone battery storage systems — not paired with solar generation — do not qualify as eligible generating facilities under current statute.

Paired storage: When battery storage is paired with a solar system, only the solar-generated electricity qualifies for net metering credit. Electricity stored from the grid and later exported may be subject to separate billing treatment. The solar energy storage and batteries page addresses how storage pairing affects metering registration.

Community solar: Community solar subscribers receive bill credits through a separate virtual net metering or community solar credit mechanism, not through traditional net metering. These arrangements are governed by Virginia Code § 56-594.01 and separate SCC orders. See community solar programs in Virginia for that framework.

Tradeoffs and tensions

Virginia's net metering framework sits at the intersection of competing policy interests, producing structural tensions that the SCC continues to adjudicate.

Full retail credit vs. avoided cost: Compensating exported solar at the full retail rate benefits customer-generators but arguably exceeds the value of a marginal kilowatt-hour to the grid. Utility cost-of-service studies submitted to the SCC have argued that net metering at retail rates shifts fixed distribution costs to non-participating customers. Solar advocates counter that distributed generation provides locational grid benefits — reduced line losses, deferred distribution upgrades — that retail-rate compensation undervalues.

Fixed charge proposals: Utilities have periodically proposed minimum fixed charges or demand charges for net metering customers to recover infrastructure costs independent of net energy consumption. These proposals have met resistance at the SCC on grounds that they could undermine the economic case for residential solar adoption before the VCEA's renewable energy targets are met.

Interconnection queue delays: As solar adoption accelerated under VCEA incentives, interconnection application backlogs at Dominion have extended processing timelines, creating a gap between system installation and billing enrollment. Delays in interconnection approval defer the start of credit accumulation. The regulatory context for Virginia solar energy systems page covers SCC oversight of interconnection process timelines.

Successor tariff risk: Virginia law contemplates that the SCC may approve net metering successor tariffs once program participation reaches defined thresholds. A successor tariff could alter compensation rates for new applicants, introducing uncertainty for systems installed near a threshold transition point.

Common misconceptions

Misconception: Net metering credits are paid as cash monthly.
Credits accumulated under Virginia's net metering tariff offset charges on future bills. They do not convert to a direct cash payment at the end of each billing cycle. The annual true-up mechanism determines what, if any, residual compensation applies at year-end.

Misconception: Any size solar system qualifies for net metering.
Virginia's statute and SCC-approved tariffs impose both individual system size caps (20 kW residential, 1 MW non-residential under standard net metering) and aggregate program caps. Systems exceeding individual size thresholds may require alternative interconnection agreements rather than standard net metering enrollment.

Misconception: Exporting electricity earns the same rate as buying it.
The credit rate for net excess generation exported to the grid equals the retail rate during the billing period, but the treatment of any end-of-year surplus balance may differ — utilities may compensate residual balances at avoided-cost rates, which are lower than retail rates.

Misconception: Battery storage systems automatically qualify for net metering.
Standalone battery storage does not qualify as an eligible generating technology under Virginia Code § 56-594. Eligibility requires a paired renewable or qualifying generating facility.

Misconception: Net metering rules are uniform across all Virginia utilities.
SCC-regulated investor-owned utilities follow the statutory framework, but each utility's specific tariff terms — including avoided-cost rates, true-up dates, and interconnection fees — differ and are approved separately through SCC docket proceedings.

Checklist or steps (non-advisory)

The following sequence describes the stages a Virginia customer-generator moves through when enrolling in net metering under a standard investor-owned utility tariff:

1. Confirm system eligibility: Verify that the proposed generating technology and system size (kW AC nameplate) fall within the applicable utility's net metering size thresholds.
2. Submit interconnection application: File the appropriate interconnection application with the serving utility (Dominion or APCo) along with required technical documentation — single-line diagram, equipment specification sheets, and site plan — in accordance with the utility's SCC-approved interconnection procedures.
3. Receive technical review determination: The utility completes a simplified or detailed interconnection study depending on system size and local circuit conditions. IEEE 1547-2018 technical screens apply at this stage.
4. Obtain interconnection approval: Upon technical approval, the utility issues an interconnection agreement that the customer executes before energization.
5. Complete local permitting and inspection: Electrical and building permits are obtained from the applicable Virginia locality, and the Authority Having Jurisdiction (AHJ) performs inspections verifying NEC Article 690 compliance under NFPA 70 (2023 edition). See the permitting and inspection concepts page for AHJ-specific requirements.
6. Schedule utility meter installation: The utility installs a bidirectional meter or configures the existing meter for net metering data collection.
7. Enroll in net metering billing tariff: The utility activates net metering billing, establishing the 12-month anniversary date for annual true-up calculations.
8. Monitor credit accumulation: Track monthly NEG credit balances against projected consumption to verify billing accuracy under the tariff.

Reference table or matrix

For the broader landscape of financial incentives that interact with net metering economics, the Virginia solar incentives and tax credits and SREC market in Virginia pages provide complementary detail. System owners considering the Virginia solar landscape as a starting point can access the home page for a structured overview of all major topic areas.

References

• Virginia Code § 56-594 — Net Energy Metering
• Virginia Code § 56-594.01 — Net Energy Metering; Shared Solar
• Virginia State Corporation Commission (SCC)
• Virginia Clean Economy Act (Virginia Code § 56-585.1 et seq.)
• IEEE Standard 1547-2018 — Interconnection and Interoperability of Distributed Energy Resources
• Federal Energy Regulatory Commission (FERC) Order 2222
• Dominion Energy Virginia — SCC Tariff Filings
• Appalachian Power Company — SCC Tariff and Interconnection Information
• National Electrical Code (NEC) Article 690 — Solar Photovoltaic (PV) Systems, NFPA 70 (2023 edition)