An Act to amend and reenact § 56-594 of the Code of Virginia, relating to net energy metering; standby charge; facility capacity.
HB1255 revises Virginia’s net energy metering law in several ways. It keeps the basic framework that allows eligible customer-generators and eligible agricultural customer-generators to offset their electricity use with on-site renewable generation, but updates the rules governing system size, interconnection, compensation, and utility charges. The bill also clarifies that eligible systems may include battery storage and smart inverters, preserves customer ownership of renewable energy certificates unless they opt to sell them to the utility, and continues to require utilities to offer power purchase agreements for excess generation under Commission-approved terms.
The bill also adjusts capacity limits and utility-specific rules. For residential customers in Phase I and Phase II utility territories, new systems installed after July 1, 2020 are limited relative to expected annual consumption, with Phase I capped at 100 percent and Phase II at 150 percent of expected annual usage. The bill raises the residential standby-charge threshold in Phase II utility territory from more than 15 kilowatts to more than 20 kilowatts of alternating current, while continuing to prohibit standby charges for residential customers of other investor-owned utilities after July 1, 2020. It also preserves special treatment for certain localities in Planning District 8 that may install and credit output from up to 5-megawatt solar or wind facilities on locality-owned sites.
HB1255 affects Code of Virginia § 56-594, the state’s principal net metering statute. It preserves the Commission’s authority to regulate interconnection, metering equipment, contract terms, and cost allocation, while requiring the Commission to conduct a net energy metering proceeding once certain capacity thresholds or dates are reached. In that proceeding, the Commission must evaluate infrastructure costs, customer compensation, avoided costs, cost-shifting, and broader economic, environmental, and resilience impacts, and may raise or remove the statewide net metering cap. The bill also continues the transition for electric cooperatives to a separate small agricultural generator framework under § 56-594.01.
The overall sentiment appears generally supportive but divided. The bill advanced through both chambers with clear majorities, though not unanimously, indicating broad acceptance of the net-metering framework with some reservations. The vote margins suggest the measure was viewed as a policy update rather than a major overhaul, with support likely coming from renewable-energy and customer-choice advocates and opposition concentrated among members concerned about utility cost recovery, rate impacts, and cross-subsidization.
The main points of contention are the same issues that typically surround net metering: how much utilities should be allowed to recover for grid use, whether customer-generators shift costs to nonparticipants, and how compensation should be set for exported electricity and renewable energy certificates. The standby charge provision is another likely flashpoint, because it permits a monthly charge for larger residential systems in Phase II territory while prohibiting such charges for most other investor-owned utility customers. The bill’s changes to capacity limits and the Commission’s future rate-setting authority also suggest ongoing debate over balancing rooftop solar growth with utility revenue stability and fairness to other ratepayers.
HB1255 amends Virginia Code § 56-594 to modify the rules governing net energy metering for residential, nonresidential, agricultural, and certain locality-owned renewable generation systems. It changes standby-charge thresholds, clarifies treatment of battery storage and smart inverters, preserves customer ownership of renewable energy certificates subject to a one-time sale option, and directs the State Corporation Commission to continue regulating interconnection, compensation, and cost allocation. The bill also reinforces the Commission’s authority to revisit the program through a formal proceeding and to adjust or eliminate the statewide cap on net-metered capacity.
The bill appears to have been broadly supported, as shown by favorable committee and floor votes in both chambers, but not without dissent. The vote totals indicate a generally positive reception to updating net metering rules, while the presence of no votes in both the House and Senate suggests some lawmakers remained concerned about utility cost recovery, rate impacts, and the fairness of standby charges and compensation rules.
The most notable disputes likely centered on whether net metering causes cost-shifting to nonparticipating customers, how much utilities should be allowed to recover through standby charges and rate adjustments, and whether the Commission should have broader authority to revise compensation for exported power. The Phase II standby-charge provision is especially sensitive because it singles out larger residential systems for a monthly charge, while other investor-owned utility customers are protected from standby charges. There is also likely tension over the bill’s capacity limits, the treatment of agricultural generators, and the special carve-out for a large locality in Planning District 8.