Twenty questions, answered properly

As a sample planning range for this territory, budget roughly $1.90 to $2.60 per watt DC installed for a straightforward rooftop array, $2.20 to $3.00 for ground-mount with civil works, and $3.40 to $4.60 for carports where you are also buying a steel structure. Storage is priced separately against its kW and kWh ratings. These are illustrative figures for a demonstration site, not a quotation.

Our modelled commercial paybacks typically fall between five and nine years once the federal tax credit and accelerated depreciation are applied, with demand-charge savings included where storage is part of the system. The spread is wide because payback depends on your tariff, your load shape and your tax position far more than on the equipment. These are sample figures.

The federal investment tax credit for commercial solar has been at a 30 percent base rate for projects meeting prevailing wage and apprenticeship requirements, with adders available for domestic content and certain locations. Rates, adders and eligibility change with legislation and guidance. Treat every figure on this site as a sample and confirm your position with a licensed tax professional.

Commercial solar has historically been eligible for accelerated depreciation under MACRS, with bonus depreciation available in varying amounts depending on the year. For a taxpaying entity that can be worth a substantial share of system cost in present value. It is worth nothing to an entity with no tax liability, which is why public agencies and non-profits usually look at a power purchase agreement instead.

Yes. Equipment loans, C-PACE assessments attached to the property, operating leases and power purchase agreements all exist for commercial solar. Each puts the tax benefits, the ownership and the balance sheet treatment in a different place. Our financing page lays out the five structures side by side.

In this part of the Valley a well-oriented fixed-tilt array typically models around 1,550 to 1,700 kWh per installed kW DC per year, before soiling losses. A 1 MW DC array therefore models at roughly 1,600 MWh a year. Tilt, azimuth, shading, soiling and inverter clipping all move that figure, which is why we model your specific geometry rather than quoting a rule of thumb. Sample figures.

kW DC is the sum of the module nameplate ratings. kW AC is what the inverters can deliver to the building. We commonly design at a DC to AC ratio around 1.2, meaning a 1,200 kW DC array behind 1,000 kW AC of inverter. That slightly oversizes the array, which fills more of the inverter's capacity through the shoulder hours at the cost of a small amount of clipping at midday.

They work, but less well as they get hotter. Modules have a negative temperature coefficient, typically around minus 0.29 to minus 0.35 percent of power per degree Celsius above the rating condition. On a 42 degree Bakersfield afternoon the cells are considerably hotter than ambient, and output is measurably below nameplate. Good ventilation behind the modules, which carports and ground-mount provide naturally, helps.

Modules carry production warranties commonly running 25 to 30 years, with a first-year degradation figure and an annual rate thereafter. Inverters are the shorter-lived component: plan for replacement somewhere around year 12 to 15 and budget for it rather than being surprised by it. Racking, if correctly specified for the environment, outlasts both.

Output falls but does not stop. Diffuse light still generates, typically in the range of 10 to 30 percent of clear-sky output depending on cloud density. Valley winters bring tule fog, which is the genuine seasonal low point for production here and is modelled explicitly rather than averaged away.

From signed contract to permission to operate, a straightforward rooftop project typically runs 26 to 34 weeks. Ground-mount with medium-voltage work and a utility study can run 40 to 60 weeks. Construction is rarely the long pole. The interconnection process usually is.

Rule 21 is the California tariff governing how generating facilities connect to the distribution system of the investor-owned utilities. It sets the application process, the fast-track screens, the supplemental review path and the study process. Our interconnection page walks through all eight stages with typical week ranges.

Almost always. We phase the work around your operating hours and, for seasonal businesses, around your campaign. Electrical tie-in needs a shutdown window, usually a single day, scheduled well in advance and frequently at a weekend.

We do. Building and electrical permits with the city or county, the Rule 21 application with the utility, and any additional agency review for public and school sites. You sign, we file, and we report on every queue monthly.

It is rarely a flat no. It is usually a condition: an export limit, a smaller AC rating, a power factor setting or protective relaying. We model the effect of each condition on your production and economics before accepting it, and we tell you if the conditioned project no longer makes sense.

Mechanically, very little. There are no moving parts on a fixed-tilt system. What it needs is monitoring that can see a fault, washing scheduled against measured soiling, an annual thermal scan, periodic IV curve traces and torque checks on terminations. Ground-mounts add vegetation control. Trackers add a genuine mechanical maintenance line.

Without string-level monitoring, often you would not, for months. A single dead string on a 400 kW array is a small enough share of monthly output to hide inside normal weather variation. With daily weather-corrected expected-versus-actual comparison at string level, it shows up the same day.

Yes. We commission a performance baseline, register the equipment serial numbers, take over monitoring and alerting, and put the site on our service calendar. Where the existing monitoring only reports whole-system output we usually recommend an upgrade, because you cannot manage what you cannot see.

A production guarantee commits that the system will deliver at least a stated percentage of modelled annual kWh, adjusted for actual weather, with a remedy if it falls short. The weather adjustment is the essential part: without it, a cloudy year looks identical to a failure and neither party can tell them apart.

Ballasted arrays are removed in sections and reinstalled. It is real cost and no added generation, which is exactly why we assess membrane life before designing. If the roof has under eight years left we will recommend reroofing first, even though it delays the project.