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Glossary · Energy industry & energy transition

Basis risk

Basis risk price hedging Hedging PPA futures market bidding zone electricity price electricity market

Basis risk is the risk that a hedging instrument does not replicate exactly the same price movement as the economic position that is to be hedged. In the electricity market it arises when generation, procurement or consumption depend on a particular price, profile or location, but the price hedge refers to a different reference price, a different market area, a different product or a different time structure.

The "basis" is the difference between the price of the position to be hedged and the price of the hedging instrument used. In the electricity market it is usually expressed in euros per megawatt hour (€/MWh). Whether it is calculated as "position minus hedge" or the other way round is a matter of convention. Contracts and risk reports should therefore always specify which direction of calculation applies. An example: A company procures electricity on the spot market and hedges through a standardised annual product on the forward market. The difference between the actual procurement price during its own consumption hours and the forward price then remains as basis risk. The hedge stabilises the average price, but does not automatically make the actual electricity purchase price-identical to the hedged product.

A numerical example, intended for illustration only: A solar park hedges its revenues through a baseload future at €80/MWh. In the delivery year the average day-ahead price is also €80/MWh. In the hours with solar feed-in, however, the park achieves only €55/MWh on average. The future offsets movements in the average price, but the operator continues to bear the difference of €25/MWh between the baseload price and the solar value itself. This difference is precisely the basis risk.

How standard products on the forward market are structured

Basis risk arises above all from the way the available hedging products are constructed. The most widely used reference contract for Germany is the EEX German Power Future. It is financially settled and refers to the average day-ahead price of EPEX SPOT in the German market area. It is available as a base and peak product with maturities from one day up to one year. In addition, the exchange offers block products for certain hours of the day, for example a block from 12:00 to 16:00, which roughly corresponds to the solar midday peak. Such products can reduce profile deviations, but they do not replicate a specific feed-in or consumption profile exactly.

Price, profile and location

The first cause lies in the time structure. Standard products refer to baseload or peakload over days, months, quarters or years. Actual electricity consumption, by contrast, follows a load profile: industrial plants, data centres, heat pumps, charging infrastructure or commercial businesses do not consume evenly across all hours. If the expensive periods weigh more heavily in actual consumption than in the hedged product, procurement can turn out more expensive than expected despite hedging. Conversely, the result can also turn out cheaper. The risk lies in the deviation, not only in a possible price increase. This time-related basis has become finer: since the delivery day of 1 October 2025, the European day-ahead market coupling (SDAC) forms prices in quarter-hours instead of hours, with the exception of Ireland. Deviations within an hour thereby become visible in the price.

A second cause is the generation profile. Wind and solar plants sell electricity when the wind blows or the sun shines. Their revenue therefore depends not only on the average market price but on the market value of their feed-in profile. If many similar plants feed in at the same time, the price in those periods often falls. The term cannibalisation effect describes this effect. A financial contract based on a monthly or annual average reflects this only incompletely. In a power purchase agreement (PPA), a gap can thus arise between the agreed reference price and the value the plant can actually achieve. This gap is part of the PPA risk.

A third cause is location. In zonal electricity markets, the wholesale price is formed for a bidding zone. Germany does not form a zone of its own; since the separation from Austria in October 2018, it forms the DE/LU bidding zone together with Luxembourg. Within the zone, the same price applies on the wholesale market, even though grid congestion has physically different effects. Other markets, such as some in North America, operate with local or nodal prices. In cross-border contracts, virtual PPAs or procurement across several market areas, the reference market can move differently from the price at the actual delivery or feed-in location. This gives rise to spatial basis risk. Whether the DE/LU zone will be split in future is being discussed at European level. A split would create new spatial basis risks between sub-zones.

Distinction from price risk, volume risk and profile risk

Basis risk must be distinguished from general price risk. Price risk means the uncertainty about how a relevant electricity price will develop. Basis risk arises only when a hedge refers to a price that does not fully match the actual position. A company can thus reduce its price risk and at the same time retain a basis risk.

Volume risk is also something different. It concerns the question of how much electricity is actually generated or consumed. A wind farm can generate less than forecast, an industrial company can change its production, a portfolio of heat pumps can need more electricity because of the weather. Basis risk, by contrast, concerns the price relationship between the hedge and the actual position. In practice, the two often occur together: a wind farm, for example, generates less during a lull and may then have to buy the missing volumes at high prices.

Profile risk is closely related, but narrower in scope. It describes the deviation between an actual time-based feed-in or consumption profile and a standardised price or delivery profile. Profile risk is a form of basis risk as soon as it results in a difference between the hedged price and the actual price. Basis risk additionally covers spatial, product-related and index-related deviations.

Not every open risk after hedging is a basis risk. The credit risk of a counterparty, regulatory changes, technical outages or a balancing group deviation belong to other risk categories. They can interact economically with a hedging strategy, but they do not describe the difference between the reference price and the actual electricity position.

Why basis risk matters in the electricity system

Physically, a megawatt hour is a specific quantity of energy. Economically, it has a different value depending on the time, location and system situation. As the share of weather-dependent generation grows, this becomes more pronounced: price profiles and market values shift, and flexibility gains in importance. Hedges tailored to average prices or standard bands then fit the actual cash flows less naturally.

For electricity consumers, basis risk determines how reliably a procurement strategy stabilises costs. An annual future can reduce budget risks. A company with strongly fluctuating consumption nevertheless remains exposed to the price in the periods in which it actually draws electricity. Flexible consumers can use this deliberately: those who shift production, storage or charging processes to cheaper periods change their own basis relative to standard products. Basis risk is thus directly linked to flexibility, load management and operational processes.

For generators, basis risk is important above all for renewable plants and long-term contracts. A solar park can conclude a PPA based on a monthly market price, but its revenues depend on the prices during the actual solar hours. If solar power often achieves low or even negative prices, the monthly index reflects the plant's value only inadequately. Conversely, a contract with quarter-hourly or hourly settlement entails other burdens, such as higher requirements for forecasting, accounting and operational control.

For traders and utilities, basis risk is part of portfolio management. They combine forward products, spot procurement, customer loads, own generation, storage and balancing energy. The more the actual load and feed-in profiles deviate from the tradable standard products, the more risk management depends on forecasts, flexibility options and internal valuation models.

Typical misinterpretations

  • Hedging does not mean complete certainty. A hedge smooths cash flows and limits extreme price movements, but replaces the actual price reference with a contractual reference. If this reference does not match the position, a difference remains open. It can be small or large, stable or strongly fluctuating, depending on the choice of product, market area, load and generation profile and the liquidity of the instruments.

  • The average price is not the economic value. Two portfolios with the same annual consumption in megawatt hours can have very different procurement costs if their loads fall in different periods. Likewise, two power plants with the same annual generation can achieve different revenues.

  • Basis risk is not proof of poor contract design. It often cannot be avoided entirely, because suitable products are lacking or would be too expensive. Standard products are liquid precisely because they simplify. The more precisely a contract replicates an actual profile, the more individual and less tradable it becomes. This results in a trade-off between accuracy on the one hand and tradability and cost on the other.

Institutional and economic context

Basis risk is closely linked to the design of the electricity market. Bidding zones, balancing groups, forward products, reference indices and PPA standards determine which prices are visible and tradable. If there are only a few liquid products, many actual positions have to be hedged through approximations. The basis risk then does not disappear, but is borne in the contract, in the portfolio or in a company's balance sheet.

Grid infrastructure and regulation also play a role. Grid congestion within a zone means that the zonal wholesale price does not fully express local scarcity. The costs of redispatch then appear elsewhere in the system, for example in grid charges. A price index can thus be market-relevant without containing all physical scarcity signals. In markets with local prices, the basis risk tends to lie between individual nodes. In zonal markets, it tends to lie between the reference price, physical feed-in, consumption profile and regulated cost components.

Basis risk is therefore not a peripheral topic for finance departments. It influences investment decisions, PPA valuations, the calculation of industrial electricity costs, the financing of renewable plants and the valuation of storage. A storage unit can reduce basis risk if it shifts withdrawal or feed-in in time. But it can also create new price relationships, for example between the intraday market, the day-ahead market, balancing energy and contractual delivery obligations.

In short: hedging in the electricity market is always a translation of an actual electricity position, which is finely resolved in time and often tied to a location, into a tradable price product. How well this translation succeeds determines which risk is actually reduced and which remains as basis risk.

Sources

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Edited by eCMS on 11.11.2026 15:12

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