Between 19 and 26 August 2026, the market kept paying for control rather than raw capacity. A virtual battery in Germany reached its full contracted power, a Swiss utility bought an operating German battery outright, a Danish trading house took over running a co-located project in Denmark, and Austria said it will steer subsidy money toward storage instead of more panels. Every number below links to its source.
Aggregation turned scattered batteries into one product you can dispatch
Vattenfall and Terralayr finished commissioning what they describe as the industry’s first multi-asset capacity toll for batteries, giving Vattenfall 55MW of dispatchable storage drawn from eight separate battery sites across Germany and pooled into a single virtual battery through Terralayr’s LAYR platform (ESS News, 20 August). The build was staged over the year, starting at 5MW in January and adding tranches in June and July until it reached the full 55MW under a seven-year contract (Startupticker, 19 August). Vattenfall can use the capacity across wholesale markets and both primary and secondary reserve, meaning FCR and aFRR, and if one battery is unavailable or curtailed under a flexible grid-connection agreement, the platform moves the dispatch to the others. The offtaker gets flexibility without owning hardware or carrying the operating role, and the arrangement stays off its balance sheet.
The same week, from the other end of the model, Sunrun agreed to feed capacity from a portion of its thousands of residential solar-and-storage systems into Voltus’s Bring Your Own Capacity programme for AI data centres, covering the PJM and MISO regions (Energy-Storage.news, 24 August). Voltus recently signed a similar three-year deal with Google to bring 100MW of distributed resources into a virtual power plant. Different assets, same idea: pool many small or scattered resources, present them to the market as one controllable block, and get paid for flexibility rather than for steel in the ground.
What this means if you own flexible assets. The value is shifting from who holds the megawatts to who can control and route them. Three things are worth doing now. First, stop treating your battery as a single asset with a single contract, because a portfolio that can cover for one site’s downtime is worth more than the sum of its parts. Second, ask what your assets earn across several markets at once, not just in one reserve product, since the FCR and aFRR pools saturate while wholesale and balancing together still hold depth. Third, if you do not run a trading desk, treat aggregation as the way in, because you can reach the same markets a utility does without the capital outlay or the operating burden.
This is the part we do. Fusebox integrates and dispatches BESS, PV, EV chargers, HVAC systems, and C&I industrial loads from a single platform, and we operate across 15 European markets and 9 TSOs. If you want your assets working across energy and reserve markets at the same time, let’s talk. Talk to Fusebox about multi-market dispatch →
Capital and trading desks keep locking up the batteries that already run
Money kept moving into batteries that are already operating. Alpiq bought the company behind the 103.5MW/238MWh battery at Bollingstedt in Schleswig-Holstein outright, a plant that has been running since 2025, extending a relationship with developer Eco Stor that began with a five-year tolling deal on a nearby twin site (ESS News, 25 August; pv magazine Deutschland). Eco Stor, which keeps operating the plant, called the purchase a signal of how mature the German storage market and international investor appetite have become. In Denmark, developer BeGreen handed optimisation of its Ingerslev Å solar-plus-storage site to trading house Danske Commodities, which now acts as balancing responsible party for the 48MW of solar and balancing service provider for the new 20MW/40MWh battery, and already runs the country’s largest battery, the 200MWh Kvosted project (Energy-Storage.news, 20 August). One detail from that deal is worth keeping in mind: in Denmark standalone batteries are treated as consumers and pay extra grid charges, while batteries co-located with solar do not, which is why most large projects there sit next to panels.
Why the rush toward contracted, optimised revenue? Because pure merchant arbitrage is getting thinner as fleets grow. BloombergNEF reported that realised battery arbitrage spreads in Australia fell 84% in the second quarter of 2026, as more renewables and more batteries compressed the price gaps that trading relies on (ESS News, 20 August). Europe is not Australia, but the direction of travel is a useful warning.
What this means for BESS owners and portfolio managers. Ownership is being separated from operation. The buyers in these deals are paying for assets that already run and already earn, and the value they add sits in the trading and optimisation on top. If your battery leans on one or two revenue streams, you are leaving money on the table as arbitrage alone gets thinner. Bring the whole stack into play, across wholesale, intraday, and balancing, and make the co-location and grid-connection rules work for you rather than against you. Not sure where your assets stand today? Our knowledge bot can handle the first round of questions. When you want to go deeper, bring your portfolio to Fusebox →
Austria points subsidy money at storage, not more panels
Austria set out plans to rewire its renewable subsidies around storage and flexibility rather than more generation (pv magazine, 21 August). The Ministry of Economy and Energy said broad support for small standard PV systems will be phased out from 2027 and redirected toward battery storage, energy management systems, and smart storage, with retrofitting existing solar arrays with batteries becoming eligible and the old first-come-first-served scramble scrapped (ESS News, 21 August). A study for the ministry found that up to 8GW of market-oriented storage by 2030 would be economically useful and could shave up to €2/MWh off wholesale prices that year. Austria has only about 3.2GWh of battery storage installed today, mostly small systems, alongside 6.2GW of pumped hydro. The last funding round ran out of money in 33 seconds, and the third and final call under the current rules opens in October. The regulator E-Control is drafting a new grid-fee framework and criteria for system-serving storage, which the industry wants kept broad enough not to slow the ramp-up.
What this means if you run C&I sites or PV in Austria and nearby markets. The policy signal is blunt: midday solar is cheap, evening power is not, and storage is how you move value between the two. If you operate PV or flexible loads, the coming rules reward pairing them with storage and an energy-management system that can actually shift consumption, not just measure it. Watch the E-Control grid-fee draft closely, because how system-serving storage gets defined will decide what your asset is allowed to earn. Want to map what a storage-plus-EMS setup could do across your sites before the rules land? Let’s plan your flexibility setup with Fusebox →
Regulatory and market watch
- Austria: the redesigned EAG subsidy framework is due to take effect in 2027, the third funding call under the current rules opens in October, and E-Control’s grid-fee and system-serving-storage draft is open for debate (pv magazine).
- Italy: for the second MACSE storage auction on 24 November, qualification data must reach Terna by 10 September and the pre-auction financial guarantee is due by 20 October, with the round targeting 16GWh (Timera Energy).
- Baltics: Litgrid, AST and Elering are due to submit their annual balancing-services review to regulators this quarter, including whether market-based storage can replace the TSOs’ demand-reduction reserves (Elering).
- Germany: grid-fee, grid-connection, FCA and capacity-market questions still hang over Europe’s biggest storage market, keeping year-end 2026 project timing in focus (Energy-Storage.news, 19 August).
- Nordics: watch the coming changes to bid submission in the Nordic aFRR and mFRR capacity markets and the aFRR energy-activation market go-live in Sweden and Norway, both of which change how reserves are offered (Nordic Balancing Model).
