The Nordic Power Markets: Where's the Opportunity for Battery Storage?

Key points

• Battery storage in the Nordics is growing fast. Just over 1.25 GW operates across Sweden, Finland, Denmark and Norway, and around 5 GW is expected by 2030.
• The best Nordic bidding zones for batteries are SE3, SE4, DK1, DK2 and Finland. This is due to demand, wind and links to Continental Europe making prices in these zones far more volatile than in the hydro-dominated north. In our 2025 Gridcog model, the same battery earned almost 13 times more from day-ahead trading in DK2 than in NO4.
• Counter-reserve headroom limits how much a battery can bid into FCR. A battery can offer its actual power divided by 1.34 into FCR-N, so the volume it can sell falls as it degrades.
• Batteries pay network charges on both import and export. Fees range from €3000-4000/MW a year in Finland to around €12000/MW in Norway, and Denmark’s are even higher.
• Finland is the most balanced Nordic market for batteries. It combines strong spreads, the lowest grid fees and, like Denmark, already trades aFRR energy through Europe’s PICASSO platform, which Sweden and Norway have not yet joined.
• Gridcog can model a battery across all 12 Nordic bidding zones, its revenue streams and each market’s rules.

On this page

• How are the Nordic power markets set up?
• How does wholesale trading work in the Nordics?
• What ancillary services are available to batteries in the Nordics?
• How do network charges work for Nordic batteries?
• How do contracts work for Nordic batteries?
• So what’s the opportunity for developers?
• Modelling the Nordic markets in Gridcog
• Key takeaways for developers looking at the Nordics
• Frequently asked questions about the Nordic markets

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The Nordics are often talked about as a single power market, and for day-ahead trading that is largely true. Underneath it though, sit four countries, four system operators, twelve bidding zones and two separate synchronous areas, with a hydro-heavy north and a windier, more volatile south. In 2025, average day-ahead prices still ranged from €9/MWh in NO4 to €83/MWh in DK2, resulting from transmission bottlenecks keeping north and south prices apart and interconnectors further pulling the southern zones towards Continental prices.

Battery storage has grown quickly across the region, with just over 1.25 GW now operating and around 5 GW expected by 2030. To understand where that capacity earns its money, it helps to break the market into four parts: wholesale trading, ancillary services, network charges, and contracts.

How are the Nordic power markets set up?

Norway, Sweden, Finland and eastern Denmark form the Nordic synchronous area, meaning they share one grid frequency. Western Denmark (Jutland and Funen), on the other hand, is part of the Continental European system. The two halves of Denmark are only joined by a direct current link under the Great Belt - so they run as two electrically separate systems that happen to share a government.

Each country has one transmission system operator (TSO), and the Nordic region is split into twelve bidding zones drawn around its transmission bottlenecks.

Table 1: The Nordic bidding zones

How does wholesale trading work in the Nordics?

Wholesale trading runs through EPEX SPOT and Nord Pool's day-ahead markets, which moved to 15-minute products on 1 October 2025. Most of the liquidity sits in that day-ahead auction, whilst continuous intraday trading is thin by comparison, and deepest in the southern and eastern zones.

The major reason for this is due to geography. Large hydro reservoirs in the north flatten prices across the day, whilst the south, with most of the demand - plus wind and interconnection to Germany and the Baltics - is far more volatile. In 2025, the average daily spread (the gap between the two most expensive and two cheapest hours) was €107-111/MWh in Denmark, €73-95/MWh in SE3 and SE4, and €79/MWh in Finland. The hydro-heavy zones sat much lower, at €12-54/MWh across Norway and €28-29/MWh in SE1 and SE2.

What ancillary services are available to batteries in the Nordics?

This is where the Nordics get interesting. The Nordic synchronous area is small, and this combined with the region having few spinning generators, causes low inertia compared with Continental Europe. So a given loss of generation moves frequency further and faster. The TSOs have responded with a wider and faster set of products than most of Europe, including a split of frequency containment reserve (FCR) into one product for normal operation and another for disturbances.

Table 2: Nordic ancillary services open to batteries

Minimum bids vary by TSO; FFR ranges from 0.3 MW in Denmark to 1.0 MW in Norway and Finland.

*mFRR has a feature that suits batteries particularly well, since energy bids can be submitted voluntarily without holding a capacity contract. A battery can therefore offer its spare headroom into the balancing energy market hour by hour and only be paid when activated.

Counter-reserve headroom

A most interesting rule applies to FCR-N and FCR-D. Because a battery has a limited amount of energy stored, the TSOs require it to hold back capacity in the opposite direction (known as counter-reserve headroom), which both caps how much power it can bid and fixes the state of charge (SoC) window it has to stay within.

In short, a battery can bid its actual power divided by 1.34 into FCR-N, and divided by 1.2 when offering FCR-D up and down at the same time. Offering only one direction of FCR-D allows the full power to be bid. Taking a 1 MW / 2 MWh battery as the example:

Table 3: Counter-reserve headroom for a 1 MW / 2 MWh battery

One detail that is easy to miss is that the calculation uses actual power rather than nameplate, so it is net of losses and degradation. Therefore, the volume a battery can sell into FCR falls every year as the asset ages. In Gridcog, losses and degradation schedules can be set on the battery, and the maximum registered capacity as well as headroom and footroom requirements on each market service can be configured. So, Gridcog can accurately reflect this rule.

Western Denmark plays by Continental rules

DK1 has none of the Nordic FCR-N/FCR-D split. That is because DK1 is joined to Germany by AC lines, so it shares the Continental grid’s frequency. It uses the Continental set of FCR, aFRR and mFRR, with FCR bought in four-hour blocks, a 15-minute endurance requirement and no payment for activated energy (much like FCR-D). mFRR capacity in DK1 has historically been procured upwards only, although both directions can be offered in the energy market through voluntary bids.

Where is ancillary value moving?

Most of Sweden’s first batteries were built to earn from FCR-D, and it shows how quickly a reserve market can fill up. Prequalified capacity grew from under 10 MW to around 600 MW between early 2023 and late 2024, against total demand of under 550 MW, and by February 2025 FCR-D was averaging below €3/MW per hour.

Batteries have since moved into mFRR, helped by the automated Nordic mFRR energy activation market that went live on 4 March 2025 with 15-minute imbalance settlement. Swedish battery mFRR prequalification rose from 120 MW to nearly 600 MW in the first quarter of 2025 alone. aFRR looks like the next opening, with Finland already trading aFRR energy through the European PICASSO platform, and Sweden not expected to join until late 2027.

How do network charges work for Nordic batteries?

Network charges in the Nordics follow a common theme. Storage pays on both import and export in all four countries, although the level varies a lot:

• Finland is the cheapest. Fingrid's 2026 storage fees are €94.75/MW per month in each direction plus around €1-2/MWh on throughput, which works out at roughly €3000-4000/MW a year for a battery cycling daily.
• Sweden comes in at around €6000/MW a year.
• Norway is around €12000/MW a year.
• Denmark is the most expensive, with its capacity fee at around three times Finland's.

In Sweden, a site only pays the tariff for the level it connects at (transmission, regional or distribution). In Denmark, distribution tariffs are added on top of Energinet's transmission tariffs, although agreeing to a flexible connection can reduce the transmission capacity charge.

How do contracts work for Nordic batteries?

Merchant structures still dominate, but tolls have started to appear. For example, in September 2026, Centrica and Delta Capacity signed a partial tolling agreement for the 125 MW / 300 MWh Karppio project in Finland, securing part of the revenue whilst keeping merchant upside (more on these structures in our offtake agreements explainer).

So what’s the opportunity for developers?

The southern and eastern zones (SE3, SE4, DK1, DK2 and Finland) are where batteries make the most money, because that’s where spreads are widest and flexible reserves are currently low.

Denmark has the best spreads, but getting connected is hard. Energinet’s queue reached around 60GW against peak demand of roughly 7GW, forcing a three-month pause on new connection agreements in 2026. Finland is the most balanced option, with good spreads, the lowest grid fees, access to PICASSO and the region’s first tolling deals. Sweden has the biggest fleet and solid margins in SE3 and SE4. Norway is least attractive, largely due to its hydro. Its hydro keeps the system flexible, but leaves little price movement for a battery to trade.

Table 4: The four markets at a glance

Average daily gap between the two most expensive and two cheapest hourly day-ahead prices, calendar 2025 (ENTSO-E).

Modelling the Nordic markets in Gridcog

Modelling a battery across different zones, revenue streams and market rules is a key part of the pre-investment phase, and is exactly what Gridcog is built to handle.

To show how much location matters, I built a project in Gridcog with the same 1 MW/2 MWh co-optimised battery in each of the twelve bidding zones, run against 2025 day-ahead prices with wholesale trading as the only revenue stream.

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‍Figure 1: Day-ahead wholesale earnings for a 1 MW / 2 MWh co-optimised battery across the twelve Nordic bidding zones, 2025

The results follow the north-south divide closely. On a per MW basis, DK2 comes out on top at €76,100, followed by DK1 at €70,500 and SE4 at €66,900, with Finland and SE3 at around €51,000-53,000. The two southern Norwegian zones earn roughly €32,000, whilst the hydro-dominated zones (NO3, NO4, NO5, SE1 and SE2) fall between €5,900 and €18,600. In other words, identical equipment earns almost thirteen times as much in DK2 as it does in NO4.

For more detailed analysis of network charges, contracts and ancillary revenue stacking whilst abiding by market rules, here is an example I modelled at a site at Sege in SE4. The two scenarios analysed over fifteen years are:

1. The introduction of 50 MW of south-facing solar;
2. The same solar, co-located with a 25 MW / 50 MWh co-optimised battery energy storage system (BESS).

Most of the Nordic reserve rules are already pre-set by our Industry team following extensive benchmarking in Gridcog, with energy duration requirements and bid rounding set in the market library item, and degradation and losses in the battery asset.

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‍Figure 2: Sege site (SE4) cashflows over fifteen years - "50 MW solar" does not recover its hardware cost; "+ 25 MW / 2 h BESS" turns the site’s cashflows positive

The Gridcog project used 2025 historic market prices, with no discount rate applied. The solar-only system finished €6.8m down over the period, because its revenue fell short of €35.5m in hardware (capex and opex). Co-locating with the BESS added a further €19.9m in wholesale earnings and €22.5m from ancillary services, which more than covered the extra hardware costs and network charges, leaving the site with a positive cashflow of €9.8m.

Key takeaways for developers looking at the Nordics

Location has a major impact. The same battery earns almost thirteen times more from day-ahead trading in DK2 than in NO4, and the balancing market follows the same north-south divide.

Market saturation shows that reserve revenue has a shelf life. FCR-D went from Sweden's most lucrative battery market to a saturated one in under two years, so value is shifting to mFRR, aFRR and arbitrage. This is a similar pattern to what has already been observed in more mature markets, such as GB, Australia and Germany.

Market rules impact the outcome. Counter-reserve headroom, degradation-adjusted bid volumes, voluntary mFRR bidding and double network charging all move the result, which is why they need to be built into the model from the start.

Get in touch if you are interested in modelling battery storage across the Nordic markets.

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Frequently asked questions about the Nordic markets

Sources

1. Nord Pool, ‘Market Coupling Steering Committee confirms go-live of 15-minute MTU in SDAC’, 12 September 2025
2. Statnett, ‘Confirmation of mFRR EAM go-live March 4th 2025’, 2025
3. Fingrid, ‘Automatic frequency restoration reserve energy markets: business context’, accessed 12 October 2026
4. Global Transmission, ‘Sweden revises timetable for joining Europe’s PICASSO aFRR balancing platform’, accessed 12 October 2026
5. Fingrid, ‘Main grid service fees 2026’, 2026
6. Centrica, ‘Centrica Energy and Delta Capacity sign partial tolling agreement for 125 MW / 300 MWh Karppio BESS project in Finland’, September 2026
7. RaboResearch (Rabobank), ‘Backup power for Europe – part 8: Ranking BESS market attractivity in the Nordics’, 16 July 2026