In short
What you will learn
A power purchase agreement (PPA) is a long-term contract to buy electricity from a specific producer at an agreed price, for a fixed period of typically 10 to 15 years. It gives the buyer price certainty and documented renewable supply, and the producer predictable revenue to finance new capacity. The contract fixes a headline price. How much of it survives to your bottom line depends on shape, basis and capture price.
This guide covers the main PPA types, benefits and risks – and what the Nordic market means for the value you actually receive.
• What a PPA is and how it is built
• The main types and who carries shape risk
• Benefits, additionality and why timing matters
• The five risks that decide realised value
• What the Nordic market means for your price
• What to ask a counterparty
What is a power purchase agreement?
A power purchase agreement commits a buyer and a producer to three things: A price, a volume profile and a delivery period of typically 10 to 15 years. Each of those terms decides how market risk is split between the two.
Each element rewards a closer look. The parties are a buyer, often called the offtaker, and a producer, typically the owner of a wind or solar asset. The price can be fixed for the full term or indexed against an agreed reference. Either way, it is set at signature, and that is where the certainty comes from. The volume is rarely a flat number: Most agreements define a profile that follows what the asset actually generates. And the delivery period runs long because the producer's lenders need that revenue visibility before they will finance the plant.
The everyday PPA meaning – a fixed price for renewable power – captures the intent but not the mechanics. What you contract is a claim on a specific asset's production at an agreed price; what you consume is still ordinary electricity from the grid. The two are reconciled commercially, not through a dedicated cable. That reconciliation is where most of the questions in this guide live.
One of them is worth flagging already. The agreed price applies to the hours when the asset produces, and those are not always the hours when your business consumes. The rest of this guide keeps returning to that distinction.
Behind every PPA structure sits one decision that outweighs the labels: Who carries the shape risk, the buyer or the seller. Physical, financial or virtual, pay-as-produced or baseload: The terminology matters less than that single allocation.
How power and money flow differs from type to type, and this section gives you enough to tell them apart.
Types of power purchase agreement
A physical PPA delivers actual electricity. The producer's output reaches you through the grid – either on-site, where the asset sits at your facility, or sleeved, where a third party manages delivery through your supply setup. The corporate PPA (cPPA) most businesses meet first usually belongs to this family.
A financial PPA involves no physical delivery. You keep buying power exactly as you do today, and the contract settles the difference between the agreed price and the market price. A virtual PPA works the same way. It is the label used most often when buyer and asset sit in different markets. These financial structures let you contract renewable production without touching your physical supply, which is why they suit companies with many sites or with consumption spread across countries.
A virtual PPA works the same way as a financial PPA. It is the label used most often when buyer and asset sit in different markets. These financial structures let you contract renewable production without touching your physical supply, which is why they suit companies with many sites or with consumption spread across countries.
The technology behind the asset matters too. Solar concentrates its output around midday, while wind spreads unevenly across seasons and weather systems. The two can also be combined in a hybrid PPA – a 60/40 wind and solar split, for example – to smooth the profile you receive. The profile you buy follows the technology mix, which makes that mix a risk choice, not just a preference.
Not every PPA is built to finance new capacity. A short cPPA is a shorter, bilateral deal struck directly between a buyer and a seller, off-exchange rather than through a market. It secures price and supply for an agreed period, but it rarely brings new capacity to the grid. That is why the Scope 2 section below treats additionality as a question of structure, not of the PPA label.
Pay-as-produced versus baseload or firmed
In a pay-as-produced agreement, you take the asset's output as it comes, hour by hour. When the wind blows hard, you receive a lot; when it drops, you receive little. The profile risk sits with you, and so does the exposure to what those hours are actually worth.
In a baseload or firmed structure, the seller or an aggregator reshapes the delivery into a steady band and carries the profile risk instead. That service is priced in, not given away.
So the question is not which structure looks cheapest on paper, but which risk your organisation is better placed to carry. Where that line is drawn matters more than the type itself. It is what separates two otherwise similar power purchase agreements, and where a PPA starts to differ from the simpler instruments compared in the next section.
The benefits of a power purchase agreement – and why they matter now
A power purchase agreement earns its place over guarantees of origin, a green tariff or pure financial hedging when a buyer needs two things at once: Price certainty and documented renewable supply in a single instrument. Rising Nordic volatility makes that need more pressing, not less.
Price certainty is the core of the case. A business buying on the spot market rides every swing in its price area. A business with a PPA has replaced a large share of that exposure with a price it can budget, invest and quote against. That certainty is worth most where electricity is a significant cost line and planning horizons are long: Manufacturing, logistics, data-heavy operations. It is worth least where prices can simply be passed through to customers.
The alternatives each solve half the problem. Unbundled certificates document origin, but leave your power price fully exposed. A green tariff bundles supply and documentation, but on the supplier's terms and rarely with a long price horizon. Financial hedging fixes the price, but says nothing about where the power comes from. When you need both a defensible renewable claim and a price you can plan around, the PPA is the instrument built for that combination. Its benefits follow from it: Budget certainty over a horizon no standard tariff matches, and renewable documentation tied to a named asset rather than a certificate pool.
The timing question has sharpened. Our own analysis concluded that Nordic prices could more than double in some price areas (Nordic Energy Market Insights, Mid-Year 2026). A market that can move like that turns an unhedged power budget into a planning risk. Regulation points the same way: the EU's 2024 electricity market design reform explicitly promotes long-term contracts such as PPAs as a way to steady the market for producers and consumers alike.
That volatility cuts both ways. It makes a PPA more attractive, and it makes the question of what your agreement actually covers more decisive, not less. The wider the market swings, the more a well-chosen contract is worth, and the more an ill-understood one can cost. Certainty that looks cheap can be a mirage: Real certainty comes from knowing what the contract does not cover. That is what shape, basis and capture price determine. The risk section below names them one by one, and the Nordic section explains why this market sharpens them.
"In today's volatile market, locking in a share of your electricity costs for the long term through a PPA can make your overall market exposure more manageable. This provides a stronger basis for long-term planning."
Additionality
Additionality and Scope 2 documentation
The environmental value of a power purchase agreement rests on additionality: The new renewable capacity the contract helps finance. That is what separates it from unbundled guarantees of origin in Scope 2 market-based reporting.
When your PPA underwrites the revenue of a plant that would not otherwise have been built, your procurement changes the energy system rather than relabelling it. European Guarantees of Origin document that a megawatt-hour was produced renewably. On their own, they do not finance anything new. Both count under the GHG Protocol Scope 2 Guidance, but the scrutiny behind the numbers is rising. The EU's Corporate Sustainability Reporting Directive (CSRD) raises the bar for what companies must be able to document: It mandates independent third-party audits of reported emissions, so auditors now actively assess whether Guarantee of Origin purchases meet the quality criteria set out in the GHG Protocol's Scope 2 guidance. And the EnergyTag standard for granular, hourly matching is moving the market from annual averages towards matching consumption in the actual hour. That is a structural shift, not any single trader's campaign.
Not every PPA clears that bar. The short cPPA noted under types is the clearest case: It fixes a price without financing anything new, so it is not additional even though it is still a PPA. Additionality is a property of the structure, not the label.
For us, this is a capability we advise on and support, not the reason to sign. Most of the 10.8 TWh portfolio we manage is wind, solar and hydro. So the documentation questions above are ones we answer in practice, not just in principle.
Understanding and managing your exposure
Five risks decide how much of a power purchase agreement's value survives contact with the market: Shape risk, basis risk, cannibalisation of the capture price, counterparty credit risk and the length of the commitment itself.
These five answer the objection that stalls most PPA processes internally: Committing for a decade or more without being able to name the risks you are taking on. Each risk below is described from your side of the contract – what the exposure is, and when it bites.
None of the five is an argument against signing. They are the difference between the price in the contract and the value in your accounts, and every one of them can be measured, negotiated and allocated before you commit.
The risks and considerations buyers should weigh
Shape risk is the mismatch between when the asset produces and when you consume. In a pay-as-produced structure – the axis described under types – that mismatch is yours. The contract delivers value in the asset's hours; your costs arise in your own. The gap between the two profiles has to be bought and sold in the market, at whatever those hours cost.
Basis risk, sometimes called locational risk, arises when the asset sits in a different price area from your consumption. You have fixed a price against one area's market, but you pay another's. As long as the two areas move together, the risk stays quiet. When they drift apart, the difference lands on you, and nothing on the front page of the contract warns you it is coming.
Cannibalisation of the capture price has the least intuitive name and the largest bearing on this guide's core point. The capture price is what a given asset actually earns per megawatt-hour, compared with the average market price.
As the share of wind and solar grows, their output increasingly coincides. In hours of high simultaneous production, Nordic hourly prices can fall towards zero or below. The capture price therefore tends to fall precisely in the hours when production – and delivery against your PPA – is highest. For a pay-as-produced buyer, that is how a sound contract price quietly erodes into weaker realised value.
Counterparty credit risk is the plain question of whether the party on the other side will still perform in year twelve. A PPA is only as strong as the balance sheet behind it. The scrutiny is mutual: Producers and their lenders will weigh your creditworthiness with the same care you should apply to theirs.
The length of the commitment is a risk in its own right, not just a feature. A tenor of 10 to 15 years outlasts most corporate strategies, several budget cycles and possibly your current management team. Two questions matter: What flexibility the contract gives you if your consumption changes, and on what terms you could exit or renegotiate. Both are far cheaper to ask before signature than after.
How the PPA process works
The PPA process follows a fixed order: Needs assessment, RFQ, indicative offers, due diligence, negotiation, signature. A buyer who knows the sequence can prepare for each stage before it arrives.
If you have wondered how power purchase agreements work in practice once the decision is taken, the honest answer is that the outcome is largely determined early – before any producer has been contacted, and long before anyone talks price.
The stages are standard; the preparation is not. Buyers who arrive at the RFQ with the needs assessment genuinely done set the terms of the comparison instead of receiving them.
NEEDS ASSESSMENT: Define what you are buying and why: Volume, horizon, risk appetite and documentation requirements. The structure discussion from the types section belongs here, not at the negotiation table.
RFQ: Put the need to the market in a form producers can price: A request for quotation specifying profile, tenor and structure, so that the offers you receive are comparable.
INDICATIVE OFFERS: Producers and intermediaries respond with indicative pricing. Read these as the start of the conversation: They show where the market is, not what you will sign.
DUE DILIGENCE AND TERM SHEET: The serious stage. The asset, the counterparty and the assumptions behind the price are verified, and the commercial skeleton is fixed in a term sheet.
NEGOTIATION: The remaining risk allocation is settled clause by clause: Who carries what, under which conditions and at what price.
SIGNATURE: The agreement takes effect and moves from paper into the market, where delivery, settlement and balancing begin.
Who are the parties in a power purchase agreement?
A power purchase agreement runs on four parties, not two. The buyer takes the power and the producer generates it. But a balance responsible party settles each delivery against the market, and the financier's bankability requirements shape the terms in the background.
Understanding who holds which role in your specific deal is groundwork for the counterparty questions at the end of this guide.
Buyer/offtaker
The buyer, or offtaker, is the party this guide is written for: The company that commits to the price and receives the power or its financial equivalent. Your consumption profile, credit standing and documentation needs shape what the other three parties can offer.
Producer
The producer owns and operates the asset. For the producer, the PPA is financing as much as sales: A signed long-term agreement is often the document that makes the project bankable at all.
Balance responsible party
The balance responsible party, or BRP, is the least visible of the four, and the one most buyers meet last. Power delivery must be forecast, nominated and settled against the market continuously, and any deviation between forecast and actual production has a cost. The BRP is the market participant who takes on that responsibility for the delivery. Every PPA has one somewhere in the chain, whether the buyer sees it or not.
Financier
The financier rarely signs the PPA, but shapes it anyway. Lenders' bankability requirements reach into tenor, price structure and termination clauses. That is why some terms that look odd from where the buyer sits make sense the moment you read them as credit protection.
PPAs and the Nordic market: Route to market, BRP and balancing
The Nordic power market is where a power purchase agreement stops being generic. It is fragmented into separate bidding zones, with a widening north-south price divide and falling capture rates for wind and solar. Those are the very conditions that decide how much of a headline price a buyer actually receives.
Start with the map. The region trades power not as one market but as separate bidding zones on Nord Pool: NO1 to NO5 in Norway, SE1 to SE4 in Sweden, and so on. When transmission between zones is constrained, their prices part ways. This is where the basis risk described under risks is born. A power purchase agreement priced against one zone and consumed in another inherits every divergence between the two.
The divergence is neither theoretical nor small. In early 2026, prices in NO4 in northern Norway ran roughly 700% above the year before. The Nordic hydro balance showed a deficit of around 32 TWh going into spring, the weakest level in 10 years (both from our Nordic Energy Market Insights, Mid-Year 2026). A hydro-dependent system with a thin buffer amplifies every dry month and every cold spell, and it does so unevenly across zones.
Falling capture rates are the second Nordic condition. Renewable capacity keeps growing, and its output across the region is weather-correlated. The pattern named in the risk section – prices lowest when renewable production is highest – is a structural feature of this market, not an edge case. The practical consequence for a buyer: Two agreements with identical contract prices can deliver clearly different value, depending on zone, technology and profile.
What happens after signature gets far less attention than the price on the page, and it matters just as much. Every delivery against a Nordic PPA must be forecast, nominated, settled and balanced. In the industry's shorthand, that is the route to market. Forecasts miss, wind over- or under-delivers, and every deviation is settled at the imbalance price of the affected zone. We know this layer from the inside. Mind Energy is a registered balance responsible party (BRP) in every Nordic country, and we balance and settle deliveries continuously, price area by price area. We do so across two financially separate business areas: Market Trading, where we trade for our own account, and Customer Business, where we act for our customers.
To be clear about what that means for you: This is not a service on offer in this guide. A corporate buyer does not appoint us as their BRP. It is the vantage point the guide is written from, and the reason we treat capture prices and balancing as operational facts rather than theory.
Choosing a PPA counterparty
Choosing a power purchase agreement counterparty comes down to the questions behind the offer: Who carries the shape and balancing risk, how transparent the price mechanism is, and how solid the counterparty will remain over a 10 to 15 year commitment.
Put your questions in writing, and put them to every counterparty on the shortlist. Written answers are easier to compare than meetings. Five belong on the list every time, however the pattern in the five is deliberate.
Every question is about what happens after signature, because that is where the difference between contract price and received value is made. A counterparty who answers all five in plain terms, without reaching for a disclaimer or a brochure, has told you most of what you need to know.
What buyers should ask
Ask the counterparty to show you where the risk sits for your specific profile: Pay-as-produced or firmed, who handles route to market after signature, and who pays when forecast and actual delivery diverge. The Nordic section above is why this question comes first.
Creditworthiness and bankability matter on both sides of the table. Ask what stands behind the counterparty's commitments over the full tenor, and expect them to examine yours with equal care.
You should be able to see which components make up the price, what is indexed against what, and which market assumptions the offer rests on. An offer that cannot be decomposed cannot be compared.
A counterparty with one product will recommend that product. Test every recommendation against the pay-as-produced versus firmed axis from the types section, and against your own appetite for risk.
If additionality and hourly matching matter to your reporting, ask for the documentation trail up front rather than at the first audit.
"When choosing a cPPA counterparty, transparency is essential. You should understand how the agreement is structured, which risks you are taking on and how it will work in practice over its full lifetime. That transparency is what builds the trust you need in a long-term partnership."
Frequently asked questions about PPAs
A PPA is an agreement to buy electricity from a specific producer at a price you both fix in advance, for a period long enough to matter – usually a decade or more. The producer gets predictable income; you get a known price and documented renewable supply.
Buyer and producer agree price, volume profile and period up front. The producer's electricity is then delivered through the grid, or the contract is settled financially, depending on the structure chosen. Getting to signature follows a fixed sequence, from needs assessment and RFQ through due diligence to negotiation.
A buyer and a producer sign it, but two more parties shape it: A balance responsible party settles the actual delivery against the market, and the producer's financier influences tenor and terms through its bankability requirements.
A physical PPA delivers electricity through the grid to your supply setup. A virtual PPA (vPPA) is settled as a financial contract against the market price, while your physical supply continues untouched – which is why buyers with sites in several markets often choose the virtual route.
Typically 10 to 15 years. The length is not arbitrary: The producer's lenders need long-term revenue visibility before they finance a new asset, so the tenor that feels demanding on your side is what makes the project fundable on theirs.
Three stand out: Price certainty on a horizon that ordinary supply contracts do not offer, renewable supply documented against a named asset, and, where the structure is right, a contribution to new capacity being built. How much of each benefit you realise depends on your price area, your consumption profile and the structure you choose.
