A power purchase agreement (PPA) priced at €70/MWh may appear to offer a renewable project a straightforward revenue hedge. But the headline price alone does not show how much risk the contract removes. In Southeast European markets, PPAs with the same nominal price can produce materially different cash flows because their terms differ.
Contract structures shape the risk profile
A pay-as-produced PPA typically settles electricity based on the plant’s actual generation. It can remove substantial market-price risk, but the agreement still needs to set out how it treats curtailment, negative prices, imbalances and volumes that cannot be delivered.
A baseload PPA creates a different exposure by requiring the generator to deliver a relatively constant volume, regardless of actual renewable production. If output falls below that committed profile, the generator may need to buy replacement electricity from the market. The price risk remains, but takes a different form.
Shaped and fixed-volume agreements bring other variations. Floors and caps can offer partial protection while preserving some upside, and contracts may combine merchant pricing with guaranteed minimum revenues. AleaSoft says a PPA’s contribution to project stability depends on its agreed price, contracted volume, delivery profile and duration, as well as the obligations each party assumes.
For lenders, those obligations need to be translated into their cash-flow consequences. Negative-price provisions are increasingly important: a contract might suspend payments when wholesale prices remain negative for a defined period, continue paying the generator, or require the producer to stop operating. Each arrangement creates a different exposure, even when the headline PPA price is identical.
Operational and counterparty risks
Curtailment terms also matter. If a transmission system operator restricts production, lenders and project parties need to know whether the buyer pays for deemed generation and whether compensation covers only certain forms of curtailment. They also need to establish who bears the risk when the plant is technically available but cannot export.
These provisions can determine whether a project retains its debt-service capacity during periods of grid stress. Balancing responsibility is another source of variation: a generator that remains financially responsible for deviations between forecast and delivered production may face significant imbalance costs. A PPA in which the buyer or an aggregator absorbs that exposure has a fundamentally different economic value.
Counterparty credit needs to be assessed separately from electricity-market protection. A 15-year contract is useful only if the buyer can continue to meet its obligations. Lenders therefore need to assess guarantees, credit support, termination rights and replacement mechanisms alongside the power price.
Termination compensation warrants particular scrutiny. If the buyer defaults halfway through the financing period, lenders need to know whether they receive enough protection to refinance the project or replace the offtaker. A weak termination structure can leave a supposedly contracted project exposed to the merchant market when the original PPA fails.
Remaining merchant exposure and bankability
Merchant tail risk presents a different challenge. A 10-year PPA financing a project with a 15- or 18-year debt life leaves part of the loan exposed to market prices after the contract expires. Even if the debt matures before the PPA, the asset’s residual value may depend on the assumptions used for the post-contract period.
For that reason, PPA bankability should be assessed as a matrix rather than a single figure. The relevant questions include what volume is protected, during which hours, and against which market risks. Parties also need to establish who pays for imbalance, who bears curtailment, and what happens during negative prices.
The assessment should also cover what happens if the buyer fails and how much merchant exposure remains. A headline price answers none of these questions. As volatility increases and renewable penetration rises in Southeast European markets, the PPA’s commercial structure will matter as much as its negotiated €/MWh.
The strongest contract will not necessarily be the one with the highest quoted price. It will be the one that continues to protect project cash flow when the electricity system behaves differently from the base case.