Virginia solar export compensation
What Virginia pays for exported rooftop solar power, with the source and the date each figure was checked.
Record verified 2026-09-16 · 17 of 17 fields sourced
What does your utility pay?
No single rate — formula based
Legacy annual net metering at retail-value offsets; net excess generation under a requested PPA is paid at the PJM DOMZONE day-ahead annual simple-average LMP. Approved future NEM 2.0 value: $0.05829/kWh.
Dominion Energy Virginia · Virginia
Current customers are protected; Dominion NEM 2.0 is approved for new customers after the future effective date established through revised tariffs.
Source: dominionenergy.com · scc.virginia.gov
Full Dominion Energy Virginia detail →Virginia retains annual net metering, but the compensation for net excess generation depends on the utility and the applicable tariff. Appalachian Power's Rider N.M.S. II is effective November 27, 2025 and pays avoided-cost credits for net excess generation, while Dominion's NEM 2.0 was approved on April 30, 2026 but the current tariff still shows the legacy 12-month net-metering/PJM-LMP structure as of September 16, 2026.
Program details
| Compensation mechanism | Utility-specific annual net metering: generation offsets consumption over a 12-month net-metering period; net excess generation fed to the grid is compensated under the utility's approved avoided-cost/PJM-LMP mechanism. APCo Rider N.M.S. II uses avoided-cost credits; Dominion's approved NEM 2.0 uses a 30-minute export-credit design, but it is not yet the current Dominion tariff. |
|---|---|
| Export rate | No single statewide rate exists. APCo Rider N.M.S. II lists total avoided-cost credits of $0.0566/kWh for residential secondary, $0.0581/kWh for commercial/industrial secondary, $0.0552/kWh for primary, $0.0553/kWh for sub-transmission, and $0.0546/kWh for transmission. Dominion's current tariff uses the PJM DOMZONE day-ahead annual simple-average LMP under a power-purchase agreement; Dominion NEM 2.0's approved net-excess-generation compensation value is $0.05829/kWh for the future tariff. |
| Rate effective | APCo Rider N.M.S. II: November 27, 2025. Dominion NEM 2.0: approved April 30, 2026; the Commission ordered revised tariff language, but the current Dominion terms-and-conditions filing remains effective February 5, 2026 and retains the legacy structure as of the verification date. |
| Credit rollover | Billing-period excess credits carry forward and are applied against later positive usage within the 12-month net-metering period. At the end of the period, only allowable excess generation may carry into the next period under the applicable tariff; APCo's current rider states excess generation is not transferable. |
| Credit expiration | Unused credits are reconciled at the end of each 12-month net-metering period. Excess generation beyond the amount permitted to carry forward is forfeited under the APCo customer materials; Dominion's current tariff pays remaining excess only through a requested power-purchase agreement and otherwise provides no compensation from the Company. |
| Annual true-up | Each successive 12-month net-metering period, beginning with the first meter reading after final interconnection; the annual reconciliation occurs at the customer's net-metering anniversary/period end. |
| Residential system cap | The utility materials identify a maximum residential generator size of 25 kW AC. Separately, Virginia Code limits post-July 1, 2020 Phase I facilities to no more than 100% of expected annual consumption (APCo) and Phase II facilities to no more than 150% (Dominion). |
| Commercial system cap | The utility materials identify a maximum commercial generator size of 3 MW AC. Virginia Code also limits the post-July 1, 2020 annual-output sizing percentage by utility phase: 100% of expected annual consumption for Phase I and 150% for Phase II. |
| Aggregate program cap | 6.0% of the participating investor-owned electric distribution company's adjusted Virginia peak-load forecast for the previous year: 5.0% available to all customers and 1.0% reserved for low-income utility customers. |
| Program status | The 6% aggregate cap remains in the governing regulation; the APCo final order says the cap shall continue. A statewide used-cap percentage or remaining-capacity figure was not published in the documents reviewed, so open/full/closed cannot be asserted as a statewide status. |
| Regulator | Virginia State Corporation Commission (SCC), including its Division of Public Utility Regulation. |
| Docket | APCo: SCC Case No. PUR-2024-00161, final order August 29, 2025. Dominion: SCC Case No. PUR-2025-00079, final order April 30, 2026, under the broader PUR-2024-00047 future-net-metering proceeding. |
| Governing rule | Va. Code § 56-594 and 20 VAC 5-315, Regulations Governing Net Energy Metering; the tariff-level APCo and Dominion terms implement those provisions. |
| Grandfathering | Existing customer-generators are protected from a successor final-order tariff; APCo's Rider N.M.S. II order preserves existing Rider N.M.S. customers and qualifying pre-effective-date applications under the prior tariff for up to 25 years. Dominion's order says current customers may stay on the current tariff or switch to NEM 2.0. |
| Interconnection application | Submit the utility's net-metering interconnection notification/application before construction or installation, obtain utility approval, then resubmit the completed form after installation for final approval and meter exchange. Dominion accepts an online notification form or paper/email submission; APCo directs applicants to PowerClerk and its NMIN package. |
| Interconnection timeline | Residential: the utility has 30 days to determine whether requirements are met, and the customer may interconnect after 31 days absent a waiver. Nonresidential: 60 days for review and 61 days before interconnection absent a waiver. |
| Pending change | Dominion NEM 2.0 is approved but not yet reflected as effective in the current Dominion terms-and-conditions filing as of 2026-09-16. The approved design uses a 30-minute netting interval and a $0.05829/kWh net-excess-generation compensation value; the order requires revised tariff language within 90 days of publication. |
Rates by utility
State rules set the framework. Individual utilities often pay something different, and where they do the utility tariff governs.
| Dominion Energy Virginia | Legacy annual net metering at retail-value offsets; net excess generation under a requested PPA is paid at the PJM DOMZONE day-ahead annual simple-average LMP. Approved future NEM 2.0 value: $0.05829/kWh. Current terms-and-conditions filing effective 2026-02-05; NEM 2.0 approved 2026-04-30 but not current as of 2026-09-16. Current customers are protected; Dominion NEM 2.0 is approved for new customers after the future effective date established through revised tariffs. |
|---|---|
| Appalachian Power (Virginia) | Rider N.M.S. II total avoided-cost credit: $0.0566/kWh residential secondary; $0.0581/kWh commercial/industrial secondary; $0.0552/kWh primary; $0.0553/kWh sub-transmission; $0.0546/kWh transmission. 2025-11-27 Annual 12-month netting remains; generation not fed back to the grid offsets usage at the applicable retail rate, while net excess generation fed to the grid receives the avoided-cost credit. Existing Rider N.M.S. customers and qualifying pre-effective-date applications are grandfathered. |
Sources read for this record
Keep reading
- Every state we track
- How these figures are sourced and dated
- Alabama — Rate PAE 2026 payment options are time-of-day: 5.17¢/kWh weekday 10 a.
- Arizona — Set per utility, not statewide. APS: $0.05554/kWh. TEP: $0.0513/kWh, w
- California — No single statewide export rate. Compensation is set by the CPUC Avoid
- Colorado — No single statewide dollar export rate. Under ordinary net metering, m
- Connecticut — Netting export rate is a formula, not a single statewide dollar figure
- Florida — No single statewide dollar-per-kWh export rate. Monthly net exports ar
- Georgia — 3.2188¢/kWh solar avoided cost for 2026, plus 4¢/kWh adder for RNR-Ins
- Hawaii — Hawaiian Electric Smart Renewable Energy Export rates for 2024-2026, i
- Illinois — No single statewide dollar-per-kWh rate. For new residential and small
- Indiana — Utility-specific EDG rates, not one statewide rate; the verified utili
- Louisiana — Avoided-cost export rates effective in 2026 are $0.0386407/kWh for Ent
- Maryland — No single statewide export price: for the annual-accrual option, net e
- Massachusetts — No single statewide dollar-per-kWh rate. For ordinary qualifying solar
- Michigan — Utility- and rate-schedule-specific, not one statewide flat rate. DTE'
- Minnesota — There is no single statewide dollar export rate. Xcel's latest posted
- Missouri — Utility-specific avoided-fuel-cost/cogeneration rate, not a single sta
- Nevada — Tier 4 exports are credited at 75% of the applicable retail rate; Nort
- New Jersey — One-for-one retail-rate credit against delivered electricity during th
- New York — No single statewide $/kWh rate. The Value Stack is calculated from uti
- North Carolina — No single statewide export rate exists. For the current DEC NMB and RS
- Ohio — No single statewide dollar rate. Under the standard utility tariff, ex
- Oregon — Full retail rate for each rate component on the bill that uses kWh as
- Pennsylvania — No single statewide dollar rate: full retail kWh rate for monthly offs
- South Carolina — No single statewide export rate exists. Santee Cooper's DG-25 rider li
- Tennessee — NESolar Connect publishes seasonal base rates of $0.07363/kWh summer,
- Texas — No statewide rate. Published municipal examples include Austin Energy
- Utah — Schedule 137: 4.855 cents/kWh for exports in June through September; 4
- Washington — Applicable retail energy rate / kWh credit under the customer's utilit
- Wisconsin — Utility-specific. 2026 examples are WEPCO CGS-NM residential/secondary