One solar system, one roof, twenty meters. Multi-tenant properties — apartment buildings, mixed-use projects, strip retail, small office — are where California’s solar billing rules get genuinely complicated, because the electricity is generated at one point and consumed behind many. The rules governing this arrangement were rewritten in late 2023, challenged in the Legislature in 2024, and litigated through mid-2026. They are now, for practical purposes, settled — and an owner who understands them can still build projects that pencil.
From VNEM to net billing: how the rules changed
For roughly a decade, California’s Virtual Net Energy Metering (VNEM) tariff and its cousin, NEM Aggregation (NEMA), made multi-tenant solar straightforward: a property owner installed one system, and the utility allocated its output as retail-value bill credits across the property’s meters — tenant units, common areas, EV chargers — according to percentages the owner set. Solar generated on-site and consumed on-site was, economically, treated as if each meter had its own array.
That ended with CPUC Decision D.23-11-068, adopted November 16, 2023. For interconnection applications submitted after February 14, 2024, new multi-tenant projects at PG&E, SCE, and SDG&E take service on the Virtual Net Billing Tariff (VNBT) — the multi-meter analog of the NEM 3.0 framework we covered in NEM 3.0 realities. The decision’s most consequential change was the treatment of self-consumption across meters: a nonresidential multi-meter property can no longer net solar generated on one meter against consumption on another. Power that crosses a meter boundary is treated as a grid export, credited at avoided-cost rates — and the tenant who consumes it buys it back from the utility at full retail. The California Solar & Storage Association estimated the loss of on-site netting cut energy-cost savings for affected multi-meter customers by roughly 75%.
The Legislature tried to reverse this. SB 1374 (Becker), which would have restored self-consumption crediting for schools, farms, and multi-meter properties, passed the Senate 28–7 and cleared both houses with large majorities — and Governor Newsom vetoed it in September 2024, citing cost-shift concerns. The courts have now closed the other avenue: after the California Supreme Court ordered a re-examination in August 2025, the First District Court of Appeal upheld the net billing framework in March 2026, and in June 2026 the Supreme Court declined to revisit that ruling. The policy fights will continue, but an owner underwriting a project today should assume the current rules are the rules.
If you already have VNEM or NEMA
Systems with interconnection applications submitted before April 14, 2023 keep their legacy tariff for 20 years from interconnection. Applications submitted between April 15, 2023 and February 14, 2024 received a shorter 9-year legacy period. Either way, do not casually modify or re-apply for interconnection on a legacy system without checking how the change affects legacy status — that grandfathering is one of the most valuable intangible assets on the property.
How the Virtual Net Billing Tariff actually works
VNBT has three moving parts: a generator account (the meter the system is physically interconnected behind), a set of benefiting accounts (the other meters on the property that receive credits), and an allocation schedule (the owner-designated percentage of exports assigned to each benefiting account). The property must be a single premises or a set of contiguous parcels, and all accounts must be served by the same utility.
The billing logic works like this. Energy the generator account consumes in real time behind its own meter is self-consumption at full retail value — unchanged from any behind-the-meter system. Energy exported to the grid is metered in intervals and credited using the utility’s hourly Energy Export Credit rates, derived from the CPUC’s Avoided Cost Calculator. These are not one number: PG&E’s schedule alone contains 576 distinct hourly values by month, hour, and weekday/weekend. Averaged across the year, export values have run roughly 3–4 cents per kWh for the three investor-owned utilities in 2025–2026, against retail rates north of 30 cents — though a small number of late-summer evening hours carry export values many multiples higher, which is precisely the window batteries are designed to hit.
Each benefiting account then receives its allocated share of the export credit. If the system exports 10,000 kWh in a month and a tenant’s account is allocated 10%, that tenant’s bill reflects credits for 1,000 kWh, valued hour by hour at the export rates in effect when the energy actually flowed.
The residential exception that shapes system design
Buried in D.23-11-068 is the distinction that now drives multifamily project economics: residential benefiting accounts receive 15-minute unit-level netting; nonresidential benefiting accounts receive none. In practice, a residential tenant’s allocated generation first offsets that unit’s consumption within the same 15-minute interval at the tenant’s full retail rate, and only the remainder is settled at export values. A commercial benefiting account — a retail suite, an office tenant, a common-area house meter that isn’t the generator account — gets avoided-cost credits on everything. Same roof, same electrons, very different value.
| Feature | Legacy VNEM / NEMA | Virtual Net Billing Tariff (current) |
|---|---|---|
| Credit basis | Retail-rate credits allocated across meters | Hourly avoided-cost export credits (ACC-based) |
| Cross-meter self-consumption | Netted at retail for all account types | Residential accounts: 15-minute netting. Nonresidential: none |
| Availability | Closed to new applicants (except SOMAH/MASH) | All new multi-tenant applications since Feb 15, 2024 |
| Legacy protection | 20 years (pre-4/14/23 applications); 9 years (4/15/23–2/14/24) | Subject to future CPUC review |
| Storage pairing | Optional; modest value | Effectively required for strong economics |
The legal framework: what you can (and cannot) bill a tenant
The tariff determines what the utility credits. A separate body of law determines what you, the property owner, may charge tenants for energy — and this is where well-intentioned solar projects create legal exposure. Three structures cover nearly every California multi-tenant arrangement.
1. Utility-administered VNBT credits
The cleanest structure: each tenant keeps a direct utility relationship, and solar credits land on the tenant’s own utility bill per the allocation schedule. You never sell electricity to anyone, so utility-resale law is never triggered. The trade-off is that the value lands on the tenant’s bill, not yours — so the owner recovers the investment indirectly, through a solar rent premium, a green lease clause, or simply a more competitive, lower-operating-cost unit. This works, but only if the lease is written to capture it deliberately rather than hoping the amenity pays for itself. The same ownership-structure questions we walk through in roof lease vs. owner-operated apply here with more force, because the beneficiary and the payer are different parties.
2. Master-meter or submetered resale
If the property is master-metered and you bill tenants for their usage, California Public Utilities Code Section 739.5 controls: the master-meter customer must charge each tenant the same rate the tenant would pay if served directly by the utility. There is no legal path to a markup — the statute is explicit that a residential landlord cannot profit on resold electricity, solar-generated or otherwise. Relatedly, Section 218 keeps an owner who generates power on-site and supplies it to tenants on the same premises from being regulated as an “electrical corporation” — you do not become a public utility by selling your own solar power to your own tenants — but that exemption governs your regulatory status, not your pricing freedom on residential master-metered accounts. Any submeter used as the basis for billing must also be a revenue-grade device that complies with California’s weights-and-measures requirements, subject to county sealer inspection, and billing statements must transparently show usage, rates, and the basis of the charge.
3. Rent- or CAM-inclusive recovery
Commercial leases allow more flexibility than residential law does. On a triple-net or modified-gross commercial property, owners commonly recover a solar investment through common-area maintenance charges or an amortized capital line item, or structure a direct energy-services agreement with the tenant — subject to the lease’s operating-expense definitions and audit rights, which is a drafting exercise, not a tariff question. Many owners avoid per-kWh energy sales entirely and simply fold the benefit into the rent structure. The discipline that matters: whichever structure you choose, the lease, the meter data, and the billing statements have to tell the same story, because that is exactly what a tenant dispute or an AB 802 benchmarking data request will test.
The trap to avoid
Installing solar on a master-metered residential property and quietly billing tenants a “solar rate” above the utility-equivalent rate. Section 739.5 makes the overcharge recoverable, and utility billing-dispute processes and small-claims courts see these cases regularly. If the pro forma only pencils by marking up tenant electricity, it does not pencil.
Metering, data, and settlement infrastructure
Multi-tenant solar billing is, at bottom, a data problem. Under VNBT the value of every kilowatt-hour depends on when it flowed, which meter it flowed through, and what account type sits behind that meter. Getting the accounting right requires infrastructure that most single-tenant projects never need.
Metering. The utility’s revenue meters handle the tariff side, but any owner-billed arrangement needs certified, revenue-grade submeters with current transformers sized to the panel, delivering interval data — not monthly reads. Fifteen-minute granularity is the minimum that matches how the tariff itself settles residential netting.
Allocation management. Allocation percentages are filed with the utility, and changes are restricted — utilities process allocation updates on limited schedules, not on demand. Vacancy, turnover, and seasonal load shifts therefore need to be modeled before you file, because an allocation tuned to last year’s occupancy quietly leaks value all year.
Settlement. Someone has to reconcile the utility’s hourly export credits against tenant allocations, apply Section 739.5-compliant rates where the owner bills directly, and produce statements a tenant (or an auditor) can follow. This is the problem Symmetric Energy’s Integrated Energy Settlement System was built to solve: it meters tenant consumption at the interval level, applies utility-equivalent rates automatically, reconciles against the property’s actual utility credits, and generates transparent tenant statements — so the compliance burden sits with the system rather than with the property manager’s spreadsheet. We have been settling multi-tenant energy since before the VNBT existed, and the rule change has made disciplined settlement more valuable, not less.
Storage dispatch data. If a battery is shifting exports into high-value hours — and under VNBT it should be — the dispatch logic needs the same interval data feed, plus the export-rate calendar, to decide when discharging to the grid beats serving on-site load. A battery on a static schedule leaves a meaningful share of its value uncaptured.
What still pencils in 2026
The economics of multi-tenant solar did not die in 2024; they reorganized around four design principles.
First, interconnect behind the biggest load you control. The generator account still self-consumes at retail in real time, so the system belongs behind the meter with the largest, most coincident daytime load — often the house meter carrying elevators, HVAC, pumps, and corridor lighting. Every kilowatt-hour consumed there without touching the grid is worth roughly ten times its export value. For many commercial multi-tenant properties, the honest 2026 answer is to size the system primarily to that common-area load rather than chase low-value credits across tenant meters.
Second, allocate exports to residential accounts wherever the property mix allows. The 15-minute residential netting rule means a kilowatt-hour allocated to an occupied apartment during a sunny afternoon offsets retail-priced consumption, while the same kilowatt-hour allocated to a commercial suite earns pennies. On mixed-use properties, this asymmetry should drive the allocation schedule.
Third, treat storage as part of the base design. With average export values in the low single-digit cents but evening-peak export windows worth many times that, a battery converts midday surplus into peak-hour value — and stacks with demand-charge management on the commercial meters. It is the same conclusion we reach in the ROI case for commercial batteries: under net billing economics, solar-plus-storage is the default architecture, and solar-only is the special case.
Fourth, check the program and provider overlays before finalizing anything. Qualifying affordable multifamily properties can still access retail-style VNEM crediting through the SOMAH program, with incentives up to $3.50 per AC watt for tenant-serving capacity and $1.19 for common areas, funded at up to $100 million annually — materially better economics than VNBT, for properties that qualify. (Note that SOMAH paused new integrated-storage incentive additions in PG&E territory in May 2026, though solar applications continue.) And if the property is served by a community choice aggregator — MCE here in Marin, or any of the dozens statewide — the CCA sets its own generation-side crediting policy on top of the utility’s delivery charges, which can shift project value and belongs in the pro forma, not in a footnote.
Practical takeaways for owners
If you are evaluating solar on a multi-tenant California property in 2026, this sequence will keep the project on solid technical and legal ground:
- Confirm your tariff status first. If the property has an existing VNEM or NEMA system, establish its legacy expiration date before touching anything. If it is a new project, model VNBT — not the VNEM economics in a pre-2023 sales proposal.
- Put the generator account behind your largest coincident load and size for self-consumption before counting a single export credit.
- Choose your legal billing structure deliberately — utility-administered credits, 739.5-compliant resale, or rent/CAM recovery — and make the lease language match it before installation, not after.
- Specify revenue-grade, interval-capable submetering wherever the owner bills tenants, and confirm county weights-and-measures compliance.
- Model the allocation schedule against realistic occupancy, favor residential benefiting accounts, and remember allocation changes are infrequent by design.
- Screen for SOMAH eligibility and CCA service before finalizing the financial model — either one can change the answer.
- Pair storage and dispatch it against the export-rate calendar, not a static schedule.
None of this restores the simple arithmetic of the VNEM era. But the owners doing well under the current rules are not the ones waiting for Sacramento to fix them — they are the ones who redesigned around self-consumption, residential netting, and storage, and put the billing infrastructure in place to capture what the tariff still offers.
Symmetric Energy is a California licensed contractor, CSLB #1107653. This article is general information, not legal or tax advice. Tariff terms and utility program rules change; confirm current requirements with your utility, CCA, and counsel before structuring tenant billing arrangements.