Europe keeps adding batteries at pace, with EUPD Research expecting European storage installations to grow about 78% in 2026, led by Germany, Bulgaria, Italy, the UK and Spain (ESS News, 7 September). Yet the first week of September (2 to 9) sent three signals that where those batteries earn, and whether the rules let them, is moving fast: July revenue swung toward Iberia, Poland and southern Italy while the Baltics and much of the north fell, Germany’s capacity mechanism cleared Brussels with batteries still shut out of the first auctions, and Norway showed that grid rules can gate a storage case even where the technology fits. Every figure below links to its source.
1. The revenue map swung south in July, and the Baltics fell
Clean Horizon’s July storage index shows a sharp split across Europe. In Spain, a two-hour battery’s indicative revenue rose to €477,000/MW/year and a four-hour system to €650,000/MW/year, both up about 90% on June, on stronger day-ahead and continuous intraday markets plus wider spreads in the manual restoration reserve (mFRR) (index write-up). Portugal climbed around 50%, France rose 44.9% to €410,000/MW/year on a 64.8% jump in aFRR capacity prices, and southern Italy’s SUD zone reached €450,000/MW/year. Poland stayed on top of the published two-hour values at €581,800/MW/year, up 10%, as intraday revenue rose 75% and offset a 20% fall in the day-ahead spread and lower capacity prices.
On the other side, German revenues fell by between 10% and 16% across durations as day-ahead volatility eased and the upward aFRR reserve price slipped from €15 to €10/MW/h; Belgium dropped 23.8% and Sweden 20%. The Baltics reversed a strong June outright. Estonia’s two-hour index fell 46% to €175,000/MW/year, with aFRR capacity prices down 47% and mFRR down 65%; Latvia fell 24% to €338,000 and Lithuania 30% to €302,000 (pv magazine). Only a month earlier the same three markets had jumped 84%, 31% and 32% (ESS News, June index). The pattern is consistent: revenue now depends on the combination of wholesale and intraday spreads with ancillary income, and where ancillary prices compressed and volatility faded, the floor dropped away (Clean Horizon Storage Index).
If you own or manage batteries in the Baltics or the Nordics, July was a warning shot. Same assets, very different month. Here is what is worth doing now.
First, stop underwriting a project on one market. A stack that leaned on aFRR and mFRR capacity just lost a third to two-thirds of that line in a single month. Second, put wholesale and intraday at the core and treat ancillary as the top-up, not the base. The markets that held up in July were the ones where trading across day-ahead and intraday did the heavy lifting. Third, design for dispatch across borders and services, so a weak month in one product or one price zone is covered by another.
This is the work we do at Fusebox. We integrate and dispatch BESS, PV, EV chargers, HVAC systems and C&I industrial loads on a single platform, and we operate across 15 European markets and 9 TSOs. That spread is what lets an owner move value between products and zones instead of riding one market up and down.
Talk to Fusebox about multi-market dispatch →
2. Germany’s capacity mechanism cleared Brussels, batteries still wait for 2027
On 2 September the European Commission approved Germany’s capacity mechanism under state-aid rules, clearing up to €35.2 billion of support for generation, storage and demand-side flexibility (ESS News). The approval landed days before the first tender’s bid deadline of 8 September. That first long-term auction offers 4.5 GW on 15-year contracts, with at least a third reserved for the “grid-technical north” and local-content rules requiring EU or free-trade-agreement cells and inverters (Enerdata). The maximum price is near €244,000 per MW of de-rated capacity, and winners are due on 3 November (Energy-Storage.news).
Batteries are effectively shut out of this round. The rule requiring at least ten consecutive hours of full output admits gas plants and excludes most storage from the first 9 GW. Environmental lawyers at ClientEarth called the design pro-gas and criticised an approval published so late that there was no window to scrutinise it before bids closed. The opening for storage comes later: duration-neutral auctions of roughly 2 GW are expected from 2027 (Energy-Storage.news).
For anyone building or buying BESS with German exposure, read the near-term capacity payments as gas money, not battery money. The revenue you can bank before then still comes from merchant trading, ancillary services and tolls, and July’s numbers above show how quickly German merchant revenue can swing. Plan the route to market around that volatility now, and position projects for the 2027 duration-neutral round rather than the auction closing this month.
Map your German route to market with Fusebox →
3. Norway shows the grid rules, not the fundamentals, decide the case
A PV Magazine and ESS News feature on 3 September set out why Norway lags its neighbours on batteries. State-owned transmission operator Statnett capped prequalification volumes for balancing resources connected below 110 kV (in practice 66 kV and lower), applied per area and covering FCR and FRR, including aFRR, since most of that network is not in its model (ESS News; pv magazine). That cap lands on the exact segment where a Norwegian storage case was forming: distribution-connected standalone batteries, hybrid solar-plus-storage and aggregated flexibility. Double grid tariffs, paid as a consumer when charging and again as a producer when discharging, remain unresolved.
The fundamentals do not help either. Hydropower supplies around 90% of Norwegian electricity and smooths the price swings batteries feed on, so prequalified battery volumes are tiny (about 13.2 MW in fast frequency reserve and 2 MW each in FCR-N and FCR-D as of mid-2025, against more than 600 MW prequalified for FCR in Sweden). Norway’s largest industrial battery, a 4.9 MW / 12.2 MWh system for regional utility Ren Røros, is due this autumn with commissioning set for October. The analyst quoted said a licensing review and any relaxation of the volume caps could make 2027 and 2028 look different.
For Nordic owners and aggregators, the lesson is blunt: check the prequalification, observability and telemetry rules, and the grid-tariff treatment, before you bank any reserve-market revenue. Where standalone access is capped, co-location and behind-the-meter or aggregated setups can still find a route, and the market you pick matters as much as the hardware you buy. If you want to sanity-check which products and zones are open to your assets, our knowledge bot is a quick first stop (Fusie), and then let’s get specific.
Talk to Fusebox about where your assets can actually earn →
Regulatory and market watch
- Germany, StromVKG: the first long-term capacity auction (4.5 GW, 15-year contracts) closed to bids on 8 September, with winners due on 3 November; duration-neutral auctions of about 2 GW open to batteries are expected from 2027 (Energy-Storage.news, Enerdata).
- Italy, MACSE-2: storage technical qualification is due to Terna by 10 September and the pre-auction guarantee 35 days out, ahead of the 24 November auction for 16 GWh (2029 delivery); Capacity Market 2028 awards before 4 November will trim the MACSE quota (Timera Energy, DLA Piper).
- Baltics, balancing review: Elering, AST and Litgrid plan to submit their annual balancing-services analysis to the Baltic regulators in Q3 2026, which guides whether TSO demand-reduction resources are wound down (Elering, AST).
- EU flexibility: national flexibility needs assessments under the July 2026 methodology feed indicative non-fossil flexibility targets due by January 2027, while the EU network code on demand response is still under review at the Commission (ACER).
- Spain, capacity market: the Commission-approved mechanism (about €900 million a year for ten years, open to generation, storage and demand response) still needs its operational rules, participation conditions and award criteria before the first auctions (Energy-Storage.news).
