Straight answers for the property-level NOI case.

We review your tariff structure, historical load and demand profile, available roof or ground space, interconnection capacity, and site type. Qualification depends on the specifics of your utility territory and facility, and is confirmed through a site-level review rather than a blanket rule.

The load shape decides, not the property label. We look for one owner-paid commercial meter, a spiky load — HVAC banks, pumps, elevators, refrigeration, EV charging — a 20–500 kW system band, and a live, verified program in the property's state. In practice that spans multifamily and community properties (garden apartments, BTR, HOA and condo associations), municipal and district facilities (fire, ambulance and water districts, town buildings), faith, school and non-profit facilities, and demand-heavy commercial such as hotels, senior living, self-storage, light industrial and cold storage. Single-family homes and sites without an owner-paid meter are out of scope.

We model savings from your utility bill data and rate schedule, using your actual demand and usage intervals where available. Modeled figures are project-specific estimates, not published averages, and are documented as part of the proposal for your site.

Production and savings figures shown before construction are projections based on your site data and modeling assumptions, not guarantees. Any performance guarantee, if included, is defined in the specific terms of your project agreement — we don't promise a result outside of what's written into that agreement.

No. Storage can be deployed on its own for demand management, resilience, or program participation. Whether a standalone battery, standalone generation, or a combined system makes sense depends on your load profile and objectives, and is assessed per site.

It means the project is structured so the property owner is not required to fund the upfront cost of equipment and installation. The specific financing structure, payment mechanics, and any conditions are defined in the project agreement.

Ownership depends on the structure selected for your project — a third-party-owned arrangement, a lease, or direct ownership are all possible paths. The agreement for your project specifies which structure applies and how ownership transfers, if at all.

Payment structure and timing are defined per project agreement and depend on the financing and program structure in place at your site. We document the applicable mechanism in writing before you sign.

Transfer provisions — including whether the agreement assigns to a new owner and under what conditions — are set out in the project agreement. We review this with you and prospective buyers as part of any transaction.

Term length varies by financing structure and project type and is stated in the agreement for your site. We'll walk through term, renewal, and any early-termination provisions before you commit.

Our team and installer partners manage engineering design, permitting submissions, and the utility interconnection application on your behalf, coordinating with your facilities team as needed.

Interconnection and permitting timelines are set by your utility and local authority having jurisdiction, and vary by territory, queue position, and system size. We track status and share updates as the application moves through review — we don't set or promise a fixed timeline.

Maintenance responsibility and warranty coverage depend on the ownership structure and are specified in the project agreement and manufacturer warranty documents for the installed equipment.

System behavior during a grid outage depends on the equipment configuration installed at your site (for example, whether battery storage includes outage-ready configuration). This is defined in the system design and agreement for your project, not assumed by default.

Production, dispatch, and savings data are reported through the monitoring and reporting arrangement defined for your project, at a cadence set out in the agreement.

Applicable programs — net metering, demand-response, capacity, or other utility and state programs — depend on your location, utility territory, and system configuration. We identify which programs apply to your site as part of the assessment.

Utility and state program rules can change, and review cadence is set by the administering utility or agency, not by us. We monitor the programs relevant to your site and flag changes that affect your project.

In many cases, yes — federal elective-pay ('direct pay') rules allow certain tax-exempt and governmental owners to receive the value of eligible credits as a payment rather than a tax offset. Eligibility depends on the entity, the project and current rules; we flag the possibility during underwriting and your counsel confirms it. This is general information, not tax advice.

Federal tax treatment depends on your organization's tax position, the ownership structure selected, and current law, which can change. This is not tax or legal advice — please consult your own tax and legal advisors to evaluate how incentives apply to your situation.

An onsite energy project can change the operating-expense line through avoided utility spend, and in qualifying cases add contracted or program income. Both are property-specific and depend on the site's tariff, load, and the agreement structure — neither is guaranteed, and the effect on NOI is modeled per property, not promised as a fixed outcome.

Avoided utility expense (from usage and demand-charge changes) is separate from contracted or program income (such as incentive payments or net-metering credits). We document each as its own line in the property model rather than combining them into a single savings number.

Whether an operating-expense reduction accrues to the owner, flows through to tenants via expense recoveries, or is split depends on the specific lease structure at the property. This has to be reviewed lease by lease — it is not something a general model can determine.

Financing and debt service sit below the NOI line, not inside it. Project financing can change what a project costs the ownership entity, but debt service and financing proceeds are not part of property NOI and are evaluated separately from the operating-expense and income analysis.

Resilience — such as backup power during an outage — is a property and tenant benefit that is distinct from the NOI case. It depends on the specific equipment configuration installed and is evaluated on its own terms, not folded into a savings or income figure.

Production, dispatch behavior, and future program payments remain estimates that are refined by measured performance over time. Once an energy asset is operating, monitoring and reporting replace assumptions with actuals, but future-period figures stay modeled rather than guaranteed.