NEM 3.0 and Commercial Solar in California: What Actually Changed

NEM 3.0 — California’s new Net Billing Tariff — went live on April 15, 2023. The headlines at launch were grim: solar export rates cut by 75%. Solar industry in freefall. The economics of rooftop solar destroyed.

That framing was mostly wrong, especially for commercial buildings. Here’s what actually changed, who it affects, and what the math looks like today.

What NEM 3.0 Actually Did

Under NEM 2.0, excess solar you exported to the grid was credited at the full retail electricity rate — whatever you’d pay to buy that power back. In SoCal, that meant export credits of $0.25–$0.35/kWh.

Under NEM 3.0, export credits are now based on the “Avoided Cost Calculator” (ACC) rate — what the utility would have paid to generate or procure that electricity from another source. That rate averages around $0.04–$0.08/kWh. Same solar production. Roughly one-fifth the export credit.

The CPUC approved NEM 3.0 in December 2022, and the California IOUs — SCE, PG&E, and SDG&E — moved all new interconnection applications to the new tariff starting April 15, 2023.

What didn’t change: the value of solar electricity you consume on-site. When your panels produce power and your building uses it directly, you’re avoiding buying that electricity from the utility at full retail rates. That offset still works at $0.20–$0.38/kWh depending on your rate schedule. NEM 3.0 only affects what happens to electricity you can’t use and push back to the grid.

Commercial Buildings Are Less Exposed Than Residential

The NEM 3.0 pain lands hardest on residential solar customers — particularly those who sized their systems to zero out their annual utility bill with heavy evening exports. For a household that pushes most of its solar production to the grid during the day and pulls it back at night, the export rate cut is a direct hit.

Commercial buildings operate differently.

Manufacturing facilities, warehouses, office buildings, retail centers, and industrial properties run their loads during the same hours the sun is producing. HVAC, compressed air, lighting, refrigeration, process equipment — most of it runs 8am to 6pm. A well-sized commercial solar system in SoCal has a natural self-consumption rate of 70–90% for most business types.

That means 70–90% of your solar production is valued at full retail rates you’re avoiding — not at the reduced export rate. NEM 3.0 affects the 10–30% that would otherwise be exported. The impact on overall system economics is real but not catastrophic.

For a 300 kW system at a warehouse in Riverside that runs 8am–5pm five days a week, the difference between NEM 2.0 and NEM 3.0 export compensation might be $3,000–$6,000 per year — material, but not the difference between a viable and non-viable project.

Battery Storage Changes the Math

The bigger shift NEM 3.0 created is in how battery storage integrates with commercial solar.

Under NEM 2.0, storage made sense for backup power and demand charge management. Exporting excess solar at retail rates was almost as good as storing it — you got full value either way.

Under NEM 3.0, storing excess production and discharging it during peak TOU windows is dramatically more valuable than exporting it. Instead of earning $0.06/kWh for exported power, you’re offsetting $0.32–$0.38/kWh peak rates when SCE’s TOU periods kick in during evening hours.

That spread — $0.06 export credit vs. $0.35 peak offset — is what makes battery storage a standard recommendation on commercial solar projects now, not an optional add-on.

The use case is strongest for businesses with significant evening demand: cold storage facilities that run refrigeration overnight, multi-tenant properties with evening occupancy, manufacturers running second shifts. But the demand charge angle applies broadly.

Demand charge reduction. SCE commercial rate schedules often have demand charges of $12–$20 per kW per month on your peak 15-minute interval. A 100 kW battery system that shaves your peak demand by 60–80 kW is worth $720–$1,600 per month in demand charge reduction alone — independent of energy arbitrage and independent of what NEM version you’re on. That math existed before NEM 3.0 and it still holds.

If You’re Already on NEM 2.0: The Grandfathering Window

Customers who completed interconnection under NEM 2.0 before April 15, 2023 are grandfathered for 20 years from their original interconnection date. If you installed in 2021, you’re on NEM 2.0 export rates until approximately 2041.

That’s a meaningful asset. If you’re expanding or adding a second meter on an existing property, those new installations go on NEM 3.0. But your original system keeps its rate structure.

One caveat: some system expansions or roof-level reconfigurations can trigger a new interconnection application, which means new NEM 3.0 treatment. If you’re on NEM 2.0 and planning modifications, confirm the interconnection implications with your installer before proceeding.

Running the Numbers Under NEM 3.0

Here’s a realistic scenario for a 300 kW rooftop system at a commercial property in Southern California:

System specs:

• Installed cost: ~$800,000 (before incentives)
• Annual production: ~480,000 kWh
• On-site consumption: ~390,000 kWh (81% self-consumption)
• Export: ~90,000 kWh

Incentives:

• 30% ITC: -$240,000
• MACRS 5-year depreciation benefit (est.): -$130,000–$160,000
• Net effective cost after incentives: ~$400,000–$430,000

Annual savings:

• On-site consumption offset at $0.22/kWh blended: ~$86,000
• Export credits at $0.06/kWh (NEM 3.0): ~$5,400
• Total annual savings: ~$91,000

Payback: roughly 4.5–5 years on net effective cost

That’s a solid return. Under NEM 2.0, the export credit would have been closer to $22,500 instead of $5,400 — a $17,000 annual difference. Meaningful, but it takes the payback from ~4 years to ~4.5–5 years, not from viable to unviable.

Add a 150 kWh battery system (est. $120,000–$150,000 before incentives) targeting demand charge reduction and peak TOU shifting, and the combined system economics typically improve despite the higher capital cost — because demand charge savings are additive and substantial.

What This Means When You’re Evaluating Commercial Solar Today

Don’t let NEM 3.0 be the reason you don’t go solar. For commercial buildings with normal daytime operating profiles, the self-consumption rate limits the damage from lower export rates. The ITC and MACRS depreciation structure is unchanged. California utility rates are among the highest in the country and still rising.

Do right-size the system. Oversizing for maximum export made more sense under NEM 2.0. Under NEM 3.0, sizing to match your daytime load profile is the right starting point. A system that produces what you consume on-site captures full retail value. Excess production above that has limited upside.

Battery storage deserves a serious look. It’s no longer a backup-power accessory — it’s a demand management and energy arbitrage tool that directly improves commercial solar ROI under NEM 3.0. Get quotes for solar-only and solar-plus-storage side by side before deciding.

Verify your existing system’s NEM status. If you have solar already, confirm with your utility which tariff you’re on. If you’re grandfathered on NEM 2.0, that’s worth knowing — it affects how you think about modifications, expansions, and any new installations at adjacent properties.

The policy change was real. The end of commercial solar in California wasn’t.

Ready to See What the Numbers Look Like for Your Building?

We’ll run a NEM 3.0-accurate analysis using your actual utility data — consumption profile, demand charges, TOU schedule — and show you exactly where the economics land.

Schedule a consultation or call us at (949) 877-8008.

Related reading:

• Commercial Solar Cost in California: What to Budget in 2026
• Commercial Solar PPA vs Purchase vs Lease: What Actually Makes Sense for California Businesses
• FEOC Requirements for Commercial Solar: What California Businesses Must Know