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A commercial solar power purchase agreement (PPA) is a contract in which a provider typically develops, owns and operates a solar photovoltaic system while a business buys the electricity it generates at an agreed price for a defined term. In a standard onsite arrangement, the customer buys the system’s output—not the system itself—so it may avoid the upfront cost of purchasing the equipment, but it still takes on contractual, site, utility and counterparty risks.
For businesses and developers in the United States, the key questions are how electricity is delivered, how the rate compares with the customer’s actual utility costs and load, who owns the renewable energy certificates, and what happens if the project underperforms or the contract ends. The details depend on state and local rules, utility arrangements, project design and the signed agreement.
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What is a solar PPA and how does it work?
A solar PPA is an electricity-purchase contract tied to output from a solar project. In the common third-party-owned onsite model, the provider arranges development, financing, design, permitting and construction, and a project company, developer or investor owns and operates the photovoltaic (PV) asset. The customer makes site access available and pays for electricity generated under the agreement. As the U.S. Environmental Protection Agency (EPA) explains, “the host customer buys the services produced by the PV system rather than the PV system itself.”
This structure can let a business obtain solar-generated electricity without buying the system outright. It can also shift specified development and operating responsibilities to the provider. It does not make the electricity free, guarantee savings, or remove the customer’s obligations under the PPA, lease, utility tariff or other project agreements. The allocation of responsibilities and risks is set by the contract.
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Terms often span years rather than months. The EPA describes solar PPA terms generally as ranging from six to 25 years and says onsite customer PPAs commonly run 15 to 20 years. These are general descriptions, not required terms or a prediction for a particular bid. A business should match the proposed term to its expected site tenure, energy needs and plans for the property.
What is the difference between onsite, physical and virtual PPAs?
The main distinction is whether the project is at the customer’s site and how, if at all, its electricity is delivered to the buyer. These structures are not interchangeable: a virtual PPA, in particular, is a financial arrangement rather than a direct supply of solar electricity to a facility.
| Structure | Where the project is | How the arrangement works | Key point for the buyer |
|---|---|---|---|
| Onsite PPA | At the customer’s site | The system supplies electricity behind the customer’s meter, subject to the project and utility arrangements. | Review site access, load and utility terms as well as the electricity price. |
| Offsite physical PPA | At a separate project | Power is sourced from the project and delivered to an agreed grid point under the applicable market structure. | Check delivery arrangements, settlement and market-specific requirements. |
| Virtual or financial PPA | At a separate project | The parties enter a financial arrangement, commonly a contract for differences; the project’s electricity is not directly delivered to the buyer. | Do not treat the contract as a direct reduction in electricity flowing to a particular facility. |
The EPA describes physical PPAs as usually lasting 10 to 20 years. Physical delivery, settlement and utility arrangements depend on the applicable market. The EPA’s overviews of physical PPAs and financial PPAs explain the distinction. A buyer should identify the intended structure before comparing offers: a quoted rate in one structure may not represent the same delivered product or risk as a rate in another.
How should a business compare PPA offers?
Compare the complete contract economics and operating assumptions, not just the headline cents-per-kilowatt-hour rate. The relevant comparison is the offered PPA price against the utility costs the business would otherwise face, in light of when it uses electricity and what the project is expected to generate.
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- Set the buyer’s requirements first. Identify the sites, expected occupancy or tenure, energy needs, sustainability objectives and tolerance for price, output and counterparty risk. For multi-site or leased-property businesses, confirm which locations can support the proposed arrangement and for how long.
- Put the price in context. Ask whether the price is fixed or changes over time, what escalator applies if any, and what charges or settlement obligations sit outside the stated energy rate. Compare the offer with relevant utility costs and the customer’s load profile rather than assuming that one quoted rate proves savings.
- Review term and schedule. Establish the contract start and end dates, the target commercial-operation date and what happens if development or construction is delayed. Confirm that the term fits the customer’s expected use of the site and any lease or occupancy agreement.
- Test the output assumptions. Request the expected generation basis and performance assumptions. Determine what the provider must do if the system produces less than expected, whether there are under-delivery remedies or penalties, and how performance is measured and reported.
- Understand delivery and settlement. For onsite power, confirm how the system connects to the facility and how the arrangement interacts with the utility relationship. For an offsite physical or financial PPA, require a clear description of delivery points, settlement mechanics and the buyer’s obligations under the relevant market structure.
- Allocate site and operating duties. In an onsite PPA, specify access rights and responsibility for maintenance, insurance, repairs and eventual system removal. Make sure the contract addresses how site work, roof or property changes, and access restrictions are handled.
- Review payment, credit and exit provisions. Examine payment timing, credit requirements, default provisions, termination rights and any applicable payment or termination consequences. Ask what rights the customer has if the provider, project owner or project changes.
- Settle environmental-attribute rights. State who owns the renewable energy certificates (RECs), who may sell them, and whether they will be retired for the buyer. Do not assume that buying electricity associated with a solar project gives the customer the right to make renewable-electricity claims.
- Agree on end-of-term choices. Specify whether the customer may renew, purchase the system or require its removal, and how any purchase price will be determined. Do not assume ownership transfers automatically when the PPA expires.
The EPA’s PPA key-components guide from the National Renewable Energy Laboratory and the EPA’s renewable energy contract development best practices provide further context for contract terms and procurement. They are useful frameworks; the actual agreement and local rules govern a specific project.
How can an RFP make proposals easier to compare?
A request for proposals (RFP) can help a business solicit consistent bids by asking every bidder to respond to the same project, delivery, price, output, REC, credit, risk and end-of-term requirements. EPA guidance describes RFPs as a way to solicit and compare PPA bids.
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Use the same response format and evaluation criteria for each proposal, then identify differences and uncertainties that need diligence. An RFP makes bids more comparable, but it does not validate engineering assumptions, settle utility or interconnection questions, determine tax eligibility, or replace legal review. Those checks depend on the site, project and jurisdiction.
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Who owns the RECs, and what can the buyer claim?
The PPA should say who owns the renewable energy certificates associated with the project and whether the buyer receives them for retirement. RECs represent environmental attributes associated with renewable generation. If the provider retains or sells the certificates, the buyer should not assume it can claim the project’s renewable attributes simply because it purchases electricity under the PPA.
Make the REC provisions specific: identify the certificates covered, the party entitled to transfer or sell them, and whether and how they will be retired for the customer. Align any public renewable-electricity claim with the rights documented in the agreement. The EPA’s customer PPA guidance and its PPA materials discuss the importance of the agreement’s environmental-attribute provisions.
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There is no automatic transfer of system ownership simply because the contract term has expired. The agreement may provide for renewal, a purchase option or system removal; if there is a purchase option, the price may be based on fair market value or another stated mechanism. The signed contract controls.
Before signing, determine who must give notice and by when to exercise each option, how a purchase price is established, and who pays for removal and site restoration if the system is not retained. A customer with leased property should also confirm that its lease or other site rights last long enough to cover the PPA and any required removal period. Addressing these issues early can prevent a mismatch between the customer’s property plans and its long-term energy contract.
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How do U.S. federal solar tax credits affect a PPA?
Do not assume that a host customer automatically claims a federal project tax credit or receives a lower PPA rate because a credit is available. Tax incentives generally follow the project owner or another eligible taxpayer, and eligibility depends on the taxpayer, ownership, facility and applicable transition rules.
The IRS says the section 48E Clean Electricity Investment Credit applies to qualifying property placed in service after December 31, 2024. In Notice 2025-42, the IRS describes the 2025 law’s termination of the section 48E and section 45Y credits for applicable solar and wind facilities placed in service after December 31, 2027, when construction begins after July 4, 2026. Those dates do not by themselves determine eligibility for a particular project: the notice’s definitions, transition provisions, taxpayer rules, ownership and other facility-specific requirements matter.
For a live project, review the current IRS Clean Electricity Investment Credit guidance and consult qualified tax counsel. Businesses should ask bidders to explain any tax assumptions embedded in their proposal, but should not rely on a generic PPA description as a promise of tax-credit eligibility or a specific price reduction.
Independent reader supportYour contribution helps us test, update, and keep practical guides available for everyone.What risks remain with a third-party-owned PPA?
A provider’s ownership and operating responsibilities do not erase risks for the customer. The customer can remain exposed to contract performance, payment, site-access, utility and counterparty issues. The precise allocation varies by agreement, so diligence should focus on what the provider has promised, what the customer must do, and the remedy if an obligation is not met.
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- Generation risk: A proposal’s expected output is an assumption to examine, not a guarantee unless the contract makes it one. Clarify measurement, reporting, shortfall remedies and any exclusions.
- Price and load risk: The value of a PPA rate depends on the customer’s actual usage timing and relevant utility costs. Review the rate shape and contract obligations against the facility’s expected load rather than relying on a headline rate.
- Site risk: Construction, access, maintenance and removal all require rights over the property. Coordinate the PPA with lease terms, planned building work and site-control arrangements.
- Utility and market risk: Interconnection, tariffs, delivery points and settlement rules can vary by location and transaction structure. Confirm which party is responsible for each approval and obligation.
- Counterparty and credit risk: The contract should make payment, credit, default, termination and project-change provisions clear. Understand the consequences if either party cannot meet its obligations.
- Environmental-claim risk: A customer may lack REC rights even while purchasing project electricity. Verify ownership, transfer and retirement terms before making claims about renewable electricity.
Solar PPA authorization, utility arrangements, interconnection rules and enforceability vary across jurisdictions and projects. This U.S.-oriented overview is not legal, tax, engineering or investment advice for an individual transaction. A business should have the final proposal and contract reviewed by appropriate legal, engineering, utility and tax professionals.
Frequently Asked Questions
Does a solar PPA guarantee lower electricity bills?
No. Whether the arrangement reduces costs depends on the contract price and shape, the facility’s usage timing, relevant utility costs and any additional obligations. Compare those factors for the specific site instead of treating a quoted energy rate as a savings guarantee.
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Can a PPA cover more than one business location?
A proposal may address multiple sites, but the practical structure and applicable utility or market arrangements depend on the locations and transaction. Ask bidders to identify which sites each offer covers and to state the assumptions and obligations for each one.
Can a business sell its property while an onsite PPA is active?
The agreement may affect a sale through site-access, assignment, termination or other provisions, so a buyer should not assume the contract simply disappears with a property transfer. Review those clauses alongside the property documents before a sale or transfer is planned.
Is a solar PPA the same as a solar lease?
No. In the PPA structure described here, the customer purchases electricity generated by a provider-owned system. The parties’ payment obligations and other terms differ by contract, so compare the actual documents rather than relying on labels alone.
