A virtual power purchase agreement (VPPA) is a financial contract between a corporation and a renewable energy developer where the buyer never receives physical electricity but instead locks in a fixed price for the energy’s financial value and receives the project’s renewable energy certificates (RECs). It’s the most popular way large companies support new wind and solar projects without rewiring their own power supply. Since 2016, corporate PPAs have driven 108 gigawatts of installed renewable capacity, and VPPAs make up the majority of those deals.
How a VPPA Works
A VPPA is structured as a “contract for differences,” which means the buyer and the renewable energy developer agree on a fixed price per megawatt-hour. The developer builds and operates a wind or solar project, then sells the electricity it generates into the wholesale market at whatever the market price happens to be. The financial settlement between buyer and developer is based on the gap between that market price and the agreed-upon fixed price.
If the wholesale market price is higher than the fixed price, the developer pays the buyer the difference. If the market price falls below the fixed price, the buyer pays the developer the difference. This swap of a fixed cash flow for a variable one is the core of the deal. Alongside those payments, the developer transfers RECs to the buyer, which are certificates proving that a specific amount of electricity was generated from a renewable source.
The buyer never takes ownership of the actual electrons. The renewable project could be hundreds of miles away, connected to a completely different part of the grid. The buyer continues purchasing electricity from its local utility the same way it always has. Nothing changes about how power flows to its buildings or data centers.
Why Companies Use VPPAs
The biggest draw is that a VPPA lets a company claim renewable energy use and reduce its reported Scope 2 carbon emissions (the emissions tied to purchased electricity) without physically connecting to a renewable project. When the buyer retires the RECs it receives, those certificates serve as proof that an equivalent amount of clean energy was added to the grid on the company’s behalf.
VPPAs also provide price predictability. By locking in a fixed rate for 10 to 20 years, a buyer can hedge against rising wholesale electricity costs. If market prices climb, the settlement payments from the developer offset some of the buyer’s retail electricity expenses. Big tech companies building power-hungry data centers for artificial intelligence workloads and large retailers like Walmart are among the most active corporate buyers.
For the developer, a VPPA provides the long-term revenue certainty needed to secure financing and actually build the project. Banks and investors are far more willing to fund a solar farm when a creditworthy corporation has committed to buying its output for a decade or more.
How a VPPA Differs From a Physical PPA
In a physical PPA, the developer delivers electricity to a point near the buyer’s location, and the buyer takes legal title to the energy. This requires the buyer and the project to be in the same electricity market or grid region, and the buyer often has to navigate complex utility tariffs and interconnection rules.
A VPPA removes all of that. Because it’s purely financial, the project can sit in any wholesale market in the country. The buyer doesn’t need to coordinate with its utility beyond paying its normal electric bill. This geographic flexibility is a major reason VPPAs have become the dominant structure for corporate renewable energy procurement. For PPAs signed after 2015, 69 percent of corporate deals have terms shorter than 15 years, reflecting a preference for more manageable commitment windows compared to the 20- to 30-year utility contracts that were standard in earlier years.
Financial Risks to Understand
Basis Risk
Most VPPAs settle financially at a regional “hub” price, but the project sells its actual electricity at a local “node” price. These two prices don’t always move together. When hub prices spike above node prices, the project can face steep losses because it owes the buyer a settlement based on the higher hub price while earning the lower node price from selling power. In one extreme example, an electricity hub saw prices reach $9,000 per megawatt-hour while node prices at a nearby project were only $1,000 per megawatt-hour. A 300-megawatt project in that situation would have lost $2.4 million in a single hour.
This matters to the buyer, too. When the project faces those losses, it may curtail (scale back) its electricity output to limit financial damage. Less generation means fewer RECs delivered to the buyer, undermining the environmental goals that motivated the deal in the first place.
Negative Pricing Risk
During periods of low demand, wholesale power prices can drop below zero. When that happens under a typical VPPA, the floating price is treated as zero, so the buyer pays the full fixed price with no offset from market revenues. To guard against this, many contracts include a price floor. Solar VPPAs commonly set the floor at $0, while wind projects sometimes set a negative floor tied to the value of production tax credits the developer receives.
Construction and Delay Risk
Because VPPAs are often signed before a project is built, there’s a risk the project won’t reach commercial operation on time. Contracts typically require a guaranteed commercial operation date, and the developer pays delay damages on a dollar-per-megawatt basis for each day it misses that deadline. Developers also post security in the form of a parent guarantee, letter of credit, surety bond, or cash to protect the buyer during the contract term.
What a VPPA Looks Like in Practice
A typical deal starts with a company deciding it wants to offset a certain portion of its electricity consumption with renewables. It issues a request for proposals to developers, evaluates project quality and pricing, and negotiates a contract that specifies the fixed price, the settlement hub, the contract length, the REC transfer process, and protections against the risks described above.
Once the project is built and generating power, monthly or quarterly settlement statements flow between the two parties. In months when the market price exceeds the fixed price, the buyer receives a payment. In months when it falls short, the buyer makes a payment. Separately, the developer transfers RECs, which the buyer can retire to count toward its sustainability commitments.
The buyer’s utility bill stays the same throughout. The VPPA is an entirely separate financial relationship layered on top of the company’s existing electricity supply. From the perspective of day-to-day operations, nothing about how the company’s facilities receive power changes at all.