How a consultant establishes which document a REAP project actually needs, builds an energy production forecast that survives review, and tests an incentive stack that may not hold — in a programme where most applications do not require a full feasibility study at all.
The first question is whether a feasibility study is required
Most consultants approaching the Rural Energy for America Program quote a feasibility study. For the majority of REAP applications, that is the wrong product.
REAP uses tiered technical documentation scaled to total project cost, with different requirements applying below $80,000, between $80,000 and $200,000, and above $200,000. A full feasibility study is required only where the lender or the Agency determines one is necessary.
The practical consequence is that a small on-farm energy efficiency project — a grain dryer replacement, a lighting retrofit, an irrigation efficiency upgrade — needs a technical report prepared to the programme's specification, not a multi-week feasibility engagement. Quoting a $15,000 study against a $120,000 project is quoting a product the programme does not ask for and the economics cannot support.
Establishing the correct tier is therefore the first billable act of a competent REAP engagement, and it frequently reduces the scope rather than expanding it. A consultant who leads with that has usually earned the client's trust for the work that follows.
Where a full feasibility study genuinely is required — larger projects, novel technology, complex offtake arrangements, or where a lender requires it irrespective of the regulatory floor — the analysis differs from commercial feasibility work in ways set out below.
What the technical report has to establish
Whatever the tier, the analytical core of a REAP submission is the same, and it is an engineering question before it is a financial one.
For a renewable energy system
- The resource available at the site, established independently rather than by the equipment vendor
- The system as specified, with capacity, configuration and expected performance
- The energy production forecast, in physical units — kilowatt hours, therms, MMBtu — with the basis for the estimate stated
- Degradation and availability assumptions over the equipment life
- Interconnection arrangements and any utility constraints
For an energy efficiency improvement
- Baseline energy consumption, measured rather than estimated
- The proposed measure and its engineering basis
- Projected savings in physical units
- The measurement and verification approach
In both cases, the evidence has to be independent. A production estimate supplied by the party selling the equipment is not independent evidence, and reviewers know it.
Note that USDA's Energy Audit and Renewable Energy Development Assistance grant programmes are not funded in 2026, so applicants requiring an energy assessment should expect to procure and pay for it privately. That cost belongs in the project budget rather than in a hope of grant support.
Historical energy usage is now the load-bearing document
An August 2025 policy directive changed what REAP applications need to demonstrate, and the change is more consequential than the headline eligibility restrictions it is usually reported alongside.
Under that guidance, REAP loan guarantees became unavailable — and grants deprioritised — for projects including:
- Ground-mounted solar photovoltaic systems larger than 50 kW
- Ground-mounted solar photovoltaic systems that cannot document historical energy usage
- Ground-mounted solar photovoltaic systems sited on certified cropland
- Solar photovoltaic systems incorporating components from a country designated as a foreign adversary under 15 CFR 791.4
The second of those is the one that reshapes the consultant's work. Documented historical energy usage converts REAP from a programme that finances generation capacity into one that finances the offsetting of demonstrated consumption.
In practice this means the analysis must establish, from metered data across a full seasonal cycle, what the operation actually uses — and then demonstrate that the proposed system is sized to that load rather than to available roof or ground area, or to what the equipment vendor would like to sell.
Assembling a full year of metered consumption data takes time. It is the single most important piece of documentation in the current REAP environment and it cannot be produced retrospectively.
Right-sizing is now an analytical requirement, not a scoring preference. A system materially larger than documented load will attract scrutiny it would not have attracted three years ago, and the study should address the relationship between load and capacity explicitly rather than leaving a reviewer to infer it.
The revenue model is production multiplied by price, and both halves need evidence
REAP financial analysis has a distinctive structure that separates it from most commercial feasibility work.
Revenue is a physical quantity multiplied by a price. Neither can be assumed.
The production forecast comes from the technical analysis above and should be supported by independent resource assessment. For solar, that means irradiance data and system modelling rather than a vendor's nameplate multiplied by a generic capacity factor. For anaerobic digestion, feedstock volume and composition. For biomass, fuel supply and heat content.
The price requires its own evidence:
- Where the energy offsets purchased power, the price is the avoided utility rate — which requires the actual tariff, including demand charges, time-of-use structure and any standby charges applicable after interconnection
- Where energy is exported, the price is the applicable export or net metering rate, which varies enormously by state and utility and has been revised downward in many jurisdictions
- Where the project sells under contract, the contract governs, and its term relative to the loan term matters
Avoided cost analysis is where efficiency projects live, and it is frequently more robust than generation revenue because the saving is realised against a known tariff rather than an uncertain market.
Incentive stacking, and the discipline of modelling without it
This is where REAP financial analysis most often overreaches, and where a consultant adds the most protective value.
Renewable projects commonly layer multiple revenue and subsidy sources: federal tax credits, state incentives, renewable energy credits, utility rebates, accelerated depreciation, and the REAP support itself. Stacked together, marginal projects become attractive.
The analysis must reconcile with and without the layers that are not contractually committed.
A project that covers its debt service only when speculative incentive revenue is included at favourable values does not cover. That is not a conservative view; it is the correct one, and recent experience in adjacent renewable sectors — where credit values moved sharply and projects underwritten at peak pricing struggled — makes the point empirically.
The practical structure is a base case built on contracted and legislated revenue only, with incentive layers shown separately as upside, each identified as executed, applied for, or assumed.
Note also a hard constraint: under section 22002(c) of the Inflation Reduction Act, the Secretary may not enter into a loan agreement that may result in disbursement after 30 September 2031, or a grant with an outlay after that date. Projects with long construction timelines should be modelled against that ceiling.
The programme's current state, and what it does to the capital stack
Any REAP analysis prepared now has to reflect where the programme actually is.
Grant awards are paused. The Rural Business Cooperative Service announced on 31 March 2026 that it intends to update the regulations at 7 CFR Part 4280 Subpart B to comply with Executive Order 14315, and that REAP will make no further grant awards until the amended regulations take effect. The funding notice published in October 2024 was rescinded effective 15 April 2026. Applicants without a fully executed Financial Assistance Agreement will need to reapply once a replacement notice is published.
Guaranteed loans remain open, on a continuous application cycle, at up to 75% of total eligible project costs with an 80% guarantee to the lender, a maximum of $25 million, terms to 40 years, and an initial guarantee fee of 1% of the guaranteed amount.
Applications for biodigester and controlled environment agriculture projects have been paused separately, on stewardship grounds relating to delinquency performance in those sectors. That is a credit-driven action rather than a policy one, which means a project in either category needs to strengthen its creditworthiness case rather than its compliance case.
What this means for the model: a project structured on a combined grant and guaranteed loan cannot currently be assembled as designed. The capital stack has to be rebuilt around the loan plus equity.
The useful discipline is to model at zero grant. If the project works without grant support, proceed through the loan path and treat any future award as upside. If it only works at a 50% grant, the project needs rethinking irrespective of programme timing — a project requiring half its cost to be donated is thinly conceived, and saying so is more useful to the client than waiting for a window to reopen.
Where a full feasibility study is genuinely required
For larger or more complex projects, the analysis extends beyond the technical report into full feasibility scope. The distinguishing features remain:
Technical feasibility carries unusual weight, because the question is whether the system will produce what is claimed at the scale proposed. Where technology is novel or unproven at commercial scale, this becomes the central question rather than a verification step.
Feedstock or fuel supply, for conversion projects. Volume, composition, seasonality, competing demand, price history, and — critically — whether supply is contracted or assumed.
Offtake, where output is sold rather than self-consumed. Executed contracts, letters of intent, and assumptions should be distinguished from one another.
Coverage computed on USDA's definition, which under Part 5001 for guaranteed loans is EBITDA less reasonably expected replacement capital expenditures over total borrower debt service. Renewable energy equipment has finite life — inverters in particular — and an unfunded replacement reserve reduces the coverage ratio the lender will compute.
Sensitivity on production shortfall, price movement, and the removal of uncommitted incentive revenue.
What the reviewer is reading for
Is the production forecast independent? A vendor estimate is not evidence.
Is the system sized to documented load? With metered consumption data across a full cycle, not an estimate.
Does the project clear the eligibility conditions? Particularly the ground-mounted solar restrictions and the component-origin requirement, which are binary and checked early.
Does it work without the speculative revenue? Base case on committed sources only.
Is the right document being submitted? A full feasibility study on a project that needed a tiered technical report is not a stronger application — it is an expensive one, and it signals that the preparer did not know the programme.
REAP is a genuinely useful programme in a period of regulatory transition, and the loan stream continues to operate while the grant stream is rewritten. The consultant's contribution is establishing which document is required, building an energy analysis that a technically literate reviewer will accept, and being honest about whether the project stands up when the incentives that made it look attractive are removed from the base case.
Prepared by feasibility-study-consultant.com. REAP is undergoing regulatory revision and programme terms, eligibility conditions and documentation requirements are changing; verify current detail against USDA's published notices before relying on any point here. Last updated: July 30, 2026.