Notes from the flexibility desk for 23 to 29 July 2026. Two capacity-market moves this week ran in opposite directions. Germany opened its first auction on terms that sideline batteries, while Poland’s capacity contracts kept underwriting new battery construction. Add a sharper forecast on how fast ancillary revenue is thinning, the grid-connection queues that still decide who actually gets built, and another round of platform takeovers, and the week changed the math on where battery revenue comes from and how much of it is safe. Everything below is market news, with figures linked to their sources.

1. Capacity markets are now the gatekeeper, and Germany and Poland point opposite ways

Germany’s Federal Network Agency opened the first auction under its new Electricity Supply Security and Capacity Act (StromVKG). Bids for the first 4.5 GW round are due on 8 September, winners are named on 3 November, and a second 4.5 GW round follows later in the year, per Energy-Storage.news and Enerdata. Contracts run for 15 years, at least a third of the volume is reserved for the “grid-technical north,” and battery cells and inverters must be sourced from the EU or from countries with an EU free-trade deal. The catch for storage is the duration rule: these long-duration rounds ask an asset to sustain output for about ten hours, which the storage industry says effectively rules batteries out of the first 9 GW. The first slot where batteries compete head to head is a 2 GW technology-neutral round in May 2027, per ess-news, and a full capacity market only arrives from 2032.

Poland is the mirror image. Its capacity market, with 17-year contracts, is the backbone of almost every large battery business case there, and this week it kept turning paper into steel. R.Power signed EPC contracts for two four-hour projects, the 300 MW/1,200 MWh Dziegielewo and the 250 MW/1,000 MWh Gdansk site, both backed by capacity contracts with delivery from 2029, per ess-news. EDF Power Solutions and Eurus Energy Europe formed a build joint venture, and Eiffel Investment Group and Ergy took on a 46 MW/184 MWh project at Baczyna that already holds a capacity contract, per Energy-Storage.news. Across four auctions since 2022, Polish batteries have locked in roughly 5 GW of deliverable capacity.

What does this mean for flexibility asset operators? Capacity-market design is now the first thing to check before you model a battery, not the last. Three moves worth making now.

First, read the fine print on duration and local content before you assume your asset qualifies. A rule written for ten-hour plants can quietly exclude a two- or four-hour battery. Second, if you sit in a market like Poland where capacity contracts are on offer, treat them as the floor your financing stands on and bid accordingly. Third, if you sit in a market like Germany where the door is shut for now, build your case on the revenue you can actually earn today (wholesale, balancing, congestion) and keep the capacity-market option open for 2027 and beyond.

This is the work we do every day. Fusebox integrates and dispatches BESS, PV, EV chargers, HVAC systems and C&I industrial loads on a single platform, across 15 European markets and 9 TSOs, so an asset can chase the revenue that is open in its market instead of waiting on one that is not. If you are weighing a capacity-market bid against a merchant plan, let’s pressure-test it together. Talk to Fusebox about your capacity-market strategy →

2. Ancillary-service revenue is thinning fast, so the smart money is pre-selling the stack

The clearest number came from a recent Modo Energy forecast for Poland. It expects a four-hour battery to earn about €366,000 per MW per year in 2027, fall to a €146,000 trough by 2030 as balancing markets saturate, then recover toward €170,000 later in the decade as day-ahead spreads widen, per Modo Energy. The mechanism is simple and familiar: ancillary services make up around 80% of Polish battery revenue in 2026 but under a tenth by 2030 as the fleet passes 8 GW, with the aFRR capacity price sliding from about €46 to €14 per MW per hour. It rhymes with S&P Global’s read that ancillary’s share drops from 75% in 2025 to under 20% after 2032, the same saturation already seen in the UK and Germany.

You can watch developers price that in. The Polish projects moving into construction this week are not betting on frequency response. R.Power paired its Dziegielewo capacity contract with a long-term optimization deal that carries a price floor, per ess-news. Contracts and floors first, merchant upside second.

For the BESS and C&I asset owners. If your model still leans on frequency markets, stress-test it now, since those markets are shallow and filling fast. Betting on a single service isn’t a strategy; building a real revenue stack is: ancillary reserve running in the background, wholesale and intraday layered on top, and congestion payments captured whenever the grid pays for them, all dispatched automatically rather than chased by hand. That mix is what holds revenue together as any one market thins. Want to see how the layers fit for your asset? Explore the numbers with our knowledge bot, or better, let’s map your revenue stack together →

3. Grid connection, not hardware, is the real limit, and flexible contracts are the way in

Two markets put hard numbers on the queue this week. Westnetz, Germany’s largest distribution operator, said it is now sitting on roughly 116 GW of battery connection requests against a network peak load of about 12 GW, and rolled out a flexible connection agreement that lets a battery share a renewable plant’s connection and use spare capacity rather than wait for a network upgrade, per ess-news. The Dutch picture is similar in shape. TenneT is carrying a connection queue near 38 GW against a national peak around 19 GW, and is leaning on flexible connection contracts (the ATR85 and time-bound variants) that can cut transmission fees by up to 65% for batteries that agree to stay off the grid at peak, per reporting on the Vopak-backed Sequoia project, a 200 MW/800 MWh battery that hands the operator real-time dispatch rights.

Poland is trying to clear its own logjam by law. The UC84 Grid Act, in force from around October, puts milestone deadlines and collateral on the roughly 90 GW of storage sitting in a 240 GW connection queue, forcing stalled “zombie” projects to progress or forfeit their rights, per Modo Energy. The theme across all three is the same: a connection is worth more than a project, and flexibility on when you draw and inject is what earns you one.

The theme across all three: a connection is worth more than a project, and flexibility on when you draw and inject is what earns you one. If you’re trying to connect an asset in a congested zone, the fastest route is rarely more copper — it’s agreeing to be flexible. Co-locate with a solar or wind site and share the connection. Take the flexible or time-bound contract and shape your charging around the peak. Show the operator you’ll move when the grid needs it, and you connect years sooner and cheaper. That behaviour only pays off if it’s automated. Talk to Fusebox about connecting faster in a congested grid →

4. Big capital keeps buying European storage platforms

The consolidation wave rolled on. Zenobe, which calls itself the largest owner and operator of transmission-connected batteries in Europe with 3.3 GWh in operation or construction, bought Bavaria-based developer SDP Energie for a 1.75 GW German transmission-level pipeline, per Energy-Storage.news and Energy Global. Zenobe was blunt about the plan: buy more transmission-scale projects and partner with offtakers looking for flexibility services. Its timing is no accident, with German build activity climbing since regulators fixed 4 August 2029 as the date projects must be online to keep the grid-fee exemption. Days earlier, Alpiq followed its Harmony Energy takeover with a 1.2 GWh project at home in Switzerland, per Energy-Storage.news, and Brookfield agreed to buy developer Aypa Power from Blackstone at an enterprise value of about US$7 billion, per Energy-Storage.news, a reminder of the cheque sizes now moving into storage.

For portfolio managers eyeing a deal, a pipeline is only worth what it can earn once it is dispatched. Grid position, market access and a credible optimization plan are what separate a 1.75 GW headline from a bankable one. Before you sign, make sure the assets can actually stack revenue across the markets they sit in. We run assets across 15 European markets and 9 TSOs, so we can tell you quickly whether a target’s revenue story holds. Bring us in before your next storage acquisition →

Regulatory and market watch

• Germany, capacity market. First-round bids are due 8 September 2026, winners are named on 3 November, and the second-round bid deadline is set to be announced on 10 November; the scheme is still subject to EU state-aid clearance. Energy-Storage.news
• Germany, battery grid-fee window. To keep the storage grid-fee exemption, projects need an investment decision before the new AgNES grid-fee system takes effect (not before 1 January 2027) and must be grid-connected before 4 August 2029. ess-news
• Poland, UC84 Grid Act. Provisions take effect around October 2026, adding collateral and a 30-month building-permit deadline (with a one-time 24-month extension at PLN 60/kW) that will force stalled connection rights to progress or lapse. Modo Energy
• Baltics, balancing review. Elering, AST and Litgrid are due to submit their annual balancing-services analysis to Baltic regulators this quarter, including whether market-based aFRR is now deep enough to retire TSO demand-reduction resources (Energy Cells’ 40 MW in Lithuania runs to end-2026; the AST battery in Latvia to November 2028). Elering

Market news, not investment advice. Every figure links to its source.