Power Purchase Agreement Template

In plain language: Identifies the generator and offtaker as legal entities, states the purpose of the agreement, and defines every capitalized term used throughout the contract.

Common mistake: Using trade names instead of registered legal entity names. If the contracting entity does not match the project company holding the generation license or interconnection agreement, lenders may reject the PPA as unbankable.

In plain language: Sets the contract start and end date, defines the commercial operation date milestone, and lists the conditions — permits, interconnection approval, financing close — that must be met before the delivery obligation activates.

Common mistake: No longstop date on COD. Without one, the offtaker is indefinitely exposed to a project that never reaches commercial operation — a position project finance lenders and utilities consistently reject.

In plain language: States the price per MWh — fixed, indexed, or escalating — the payment calculation methodology, invoicing frequency, and the due date for payments.

Common mistake: Omitting an escalation mechanism entirely on a 20-year fixed price. Inflation over a 20-year term can erode the generator's economics to the point of project distress — which then triggers termination provisions that expose the offtaker to replacement cost risk.

In plain language: Defines how electricity volume is measured, who owns and maintains the meters, the settlement methodology for imbalances, and whether the generator has a firm or as-available delivery obligation.

Common mistake: Defining delivery as 'firm' for a variable renewable asset with no storage. Firm delivery from an intermittent source requires backup procurement or storage — without that, the generator faces perpetual shortfall penalties it cannot operationally avoid.

In plain language: Addresses who can order a reduction in output, under what circumstances, and whether the offtaker owes payment for curtailed energy that the generator was ready and able to produce.

Common mistake: Allowing unlimited offtaker curtailment without deemed energy payment. Lenders stress-test revenue against curtailment scenarios — unlimited free curtailment rights make a project unfinanceable by eliminating revenue certainty.

In plain language: Allocates ownership of RECs or equivalent green certificates generated by the facility and confirms that environmental claims (e.g., carbon-free energy matching) belong to the party receiving the certificates.

Common mistake: Failing to address REC ownership at all. When REC ownership is ambiguous, the offtaker cannot make verified renewable energy claims for sustainability reporting, and the generator may inadvertently double-count the same attributes.

In plain language: Requires one or both parties to post collateral — typically a letter of credit, parent company guarantee, or cash deposit — sized to cover a defined number of months of payment or performance exposure.

Common mistake: Accepting a parent guarantee from an entity with no audited financials or unrated credit. Lenders require credit support from a counterparty whose financial strength can actually be verified — an unrated subsidiary guarantee provides no bankable security.

In plain language: Defines events beyond a party's reasonable control that excuse performance, states the notice and mitigation obligations, and limits the duration for which force majeure can suspend obligations before either party may terminate.

Common mistake: Including grid curtailment or market price changes as force majeure events. These are foreseeable commercial risks that should be addressed in the curtailment and price clauses — elevating them to force majeure eliminates the compensation mechanism and creates an uninsurable gap.

In plain language: Lists events of default for each party, cure periods, and the remedies available to the non-defaulting party — including termination and a liquidated-damages calculation for early contract exit.

Common mistake: No termination payment formula for generator default. Without one, the offtaker's only remedy is cover damages — replacing a 20-year contract in a changed market — which are speculative and expensive to prove in litigation.

In plain language: Specifies the applicable law, the dispute resolution process (negotiation, mediation, then arbitration or court), the seat and rules for arbitration, and whether interim injunctive relief is preserved.

Common mistake: Choosing a governing law with no nexus to the project location or the parties' home jurisdictions. Energy regulatory requirements are jurisdiction-specific — a governing law that conflicts with the site's local electricity law creates unresolvable ambiguity on issues like interconnection disputes and curtailment obligations.

A Power Purchase Agreement is a long-term contract between an electricity generator and an offtaker that defines the price, volume, and conditions under which generated electricity is bought and sold. PPAs are the foundational commercial document for renewable energy projects — they provide the revenue certainty that allows developers to raise project finance and give buyers price stability and verifiable green-energy credentials for sustainability reporting.

Most utility-scale renewable energy PPAs run 15 to 25 years, calibrated to match the useful life of the generating asset and the tenor of the project debt. Corporate PPAs tend to be shorter — 10 to 15 years — to align with corporate planning horizons and budget cycles. Behind-the-meter and community solar agreements typically run 10 to 20 years depending on the host's lease term.

A physical PPA involves actual delivery of electricity from the generator to the offtaker at a defined delivery point — the buyer receives the power and the associated renewable attributes. A virtual PPA (VPPA) is a financial contract: the generator sells power into the wholesale market, and the parties settle the difference between the contract price and the market price. VPPAs are common for corporate buyers who are not in the same grid region as the generating asset. Both transfer RECs to the buyer.

The three main structures are fixed price, indexed price, and escalating fixed price. A fixed price provides revenue certainty for the generator and cost certainty for the buyer. An indexed price ties payments to a published market benchmark such as the day-ahead LMP at a named hub, exposing both parties to market movements. An escalating fixed price starts at a defined rate and increases by a fixed percentage annually, balancing predictability with inflation protection. Many PPAs combine a fixed floor with a market-linked upside.

Renewable Energy Certificates — also called RECs in North America, Guarantees of Origin (GOs) in Europe, or I-RECs internationally — are tradeable instruments that represent the environmental attributes of one MWh of renewable generation. Ownership of RECs determines who can make verified renewable energy claims for ESG reporting, RE100 commitments, or regulatory compliance. Most PPAs assign RECs to the offtaker simultaneously with delivery of electricity, but this must be stated explicitly — ambiguity creates double-counting risk.

Deemed energy is the notional volume of electricity a generator would have produced but was prevented from producing by an offtaker-instructed curtailment or an offtaker-caused grid constraint. In most bankable PPAs, the offtaker owes payment at the contract price for deemed energy, even though no electricity was actually delivered. This provision protects the generator's revenue and is a prerequisite for project lenders who model debt service against curtailment scenarios.

Market practice for utility-scale PPAs is for the offtaker to post a letter of credit or parent guarantee sized at three to six months of estimated contract payments. For non-investment-grade or unrated offtakers, six to twelve months is more common. The credit support instrument must come from a financial institution or corporate parent rated at least A- by a major rating agency. Some PPAs also require the generator to post performance security during the construction period.

In the United States, utility-scale PPAs between independent power producers and utilities may require FERC authorization under the Federal Power Act, and state public utility commissions often have review rights. In Canada, provincial energy boards typically oversee utility PPAs. In the EU, electricity market regulations and state aid rules can apply to government-backed offtakers. Behind-the-meter and corporate PPAs generally face lighter regulatory requirements but should be reviewed for local licensing and retail supply rules.

If the generator misses the target COD, most PPAs allow a grace period — typically three to six months — before the offtaker's delay remedies activate. If the longstop date is reached without COD, the offtaker may terminate the agreement and recover any posted credit support or agreed break fee. Developers typically manage COD risk through liquidated damages provisions in the engineering, procurement, and construction (EPC) contract, which are sized to cover PPA delay damages.

Yes, for any project-financed or utility-scale PPA. These are complex, long-term contracts with significant financial exposure — lenders will require a legal opinion on enforceability, regulatory compliance, and lender step-in rights as a condition of financial close. A template provides a strong structural starting point and reduces drafting time, but review by an energy lawyer with jurisdiction-specific experience is essential before any PPA is executed. For small behind-the-meter or community solar arrangements, a lighter review may suffice.