Two facilities can install identical equipment and end up with completely different financial outcomes. The difference usually isn't the hardware. It's the structure underneath it — who owns the asset, who claims the tax benefits, and how the payments are shaped over the life of the system.
Most commercial energy projects are financed through one of three broad structures, or a variation on them. They are not interchangeable, and the best one depends less on the project than on the owner.
The three structures, in cash-flow terms
Direct ownership means the facility buys the system outright or finances it with a loan. The owner takes on the upfront capital cost, or debt service in place of it, and in exchange captures everything the asset produces: the avoided utility cost, any performance upside, and the tax benefits. Cash flow is negative early and improves as the system pays back, then stays positive for the remaining service life.
A lease shifts the shape of that curve. Instead of a large upfront outlay, the facility makes fixed periodic payments for the use of the equipment. Depending on how the lease is written, the lessor may retain ownership for tax purposes, which means the incentives flow to them rather than to the facility — usually reflected in a lower payment. Capital lease and operating lease treatment differ materially in accounting terms, and that distinction is worth settling before the structure is chosen rather than after.
A power purchase agreement is not a way of financing equipment at all. It's a contract to buy the output. A third party owns, installs, and maintains the system on the facility's site, and the facility pays a per-kilowatt-hour rate for the electricity it produces, typically over 15 to 25 years. There is often no upfront capital cost. The facility also does not own the asset, does not claim the incentives, and does not capture the upside if energy prices rise faster than the contract escalator.
Ownership buys the upside and the obligations together. A PPA trades the upside away in exchange for someone else carrying the capital, the performance risk, and the maintenance.
Energy-as-a-service and C-PACE structures are variations on the same underlying question. The vocabulary changes; the tradeoff between upfront capital, retained upside, and who bears performance risk does not.
What actually separates them
Three variables do most of the work in distinguishing one structure from another.
Who can use the tax benefits
Federal investment tax credits and accelerated depreciation are worth a substantial share of a project's value — but only to an entity with sufficient tax liability to absorb them. A profitable operating company may capture full value through ownership. A non-profit, a municipality, or an entity in a loss position generally cannot, which is often what makes a third-party PPA or lease the more economical route rather than simply the easier one.
What the capital is worth elsewhere
Ownership produces the strongest lifetime economics in most models, but it consumes capital that has other uses. If the facility's internal hurdle rate for capital exceeds the project's return, a structure that preserves that capital can be the correct decision even when it shows a lower headline savings figure.
Who carries performance risk
Under ownership, underperformance is the owner's problem — and so is maintenance, warranty administration, and eventual replacement. Under a well-written PPA, the facility pays only for delivered output, which transfers that risk to the provider. The value of that transfer depends heavily on the specific contract language, not on the structure's label.
Where the comparison usually goes wrong
The most common error is comparing structures on a single number. A PPA rate quoted in cents per kilowatt-hour and an ownership case quoted as a payback period are not comparable figures, and lining them up side by side tends to flatter whichever one the person presenting it is selling.
A defensible comparison holds the assumptions constant across all three: the same production estimate, the same utility rate escalation, the same term, the same treatment of maintenance and replacement costs, and the same discount rate applied to the resulting cash flows. Escalators deserve particular attention — a PPA with a fixed annual escalator can look inexpensive in year one and expensive in year fifteen if the assumed utility rate increase never materializes.
End-of-term treatment is the other frequently overlooked variable. What happens at the end of a lease or PPA — purchase option, renewal terms, removal obligations, who owns a system with useful life remaining — can shift the total picture materially, and those terms are set at signing.
The questions that decide it
For a specific facility, the structure question usually resolves into a short list:
- Does the entity have the tax position to use the incentives itself, or would they be stranded?
- What return does capital earn in the facility's next-best alternative use?
- How long does the organization expect to occupy or hold the property, relative to the contract term?
- Does an operating-expense treatment matter for internal approval, covenants, or reporting?
- Under a third-party structure, who is responsible for performance shortfalls, maintenance, and removal — and what does the contract actually say?
- What are the purchase, renewal, and termination terms at end of term?
Answering these usually narrows the field to one or two viable structures before any modeling is done. Not every structure is available or appropriate for every project; suitability depends on jurisdiction, asset type, and ownership structure. Tax and accounting treatment should be confirmed with the facility's own tax and legal advisors.
Where this fits into a broader energy strategy
Financing structure is one decision inside a larger sequence. The load analysis comes first, because it determines what the asset needs to do — a system sized against unexamined demand-charge exposure will be financed correctly and specified wrongly. The supply contract behind the meter matters too, since procurement and on-site generation interact. Worked examples of how these pieces combine are set out in the industrial and hospitality engagement economics.
TEK Energy is an independent energy advisory and systems integrator. We do not manufacture equipment, and we are not a financing counterparty. We model the structures side by side against a facility's actual data and objectives, identify which ones are genuinely available, and then structure and oversee whatever the numbers support. See how independent evaluation works.