EC pledges quick approval for Germany's gas tender as clean energy lobbies flag grid overhaul risk
Brussels wants to move fast on Germany's 11 GW gas capacity programme, but industry groups warn the network overhaul shifts investment risk onto developers.
The European Commission aims to approve Germany's planned tenders for 11 gigawatts of new gas-fired power capacity "as soon as possible" once Berlin enacts a long-term capacity scheme, a Commission spokesman told Montel on Tuesday (2026-07-14). The statement signals Brussels is ready to clear the way for Germany's dispatchable capacity build, but approval remains conditional on Berlin first establishing the legal framework.6
Germany's need for firm generation is visible in the market. German baseload power traded at €122.88/MWh as of Monday (2026-07-20), reflecting a grid running with thin reserve margins after successive nuclear and coal closures. During the week of 2026-05-18, Germany's available power margin fell to its lowest point that winter as wind generation dropped roughly 25% below the same two months the previous year and colder temperatures pushed demand higher, according to Bloomberg modelling.3
The Commission's support for Germany's gas preference extends into the tender design itself. A requirement that effectively prevents batteries from competing in the planned capacity market auctions — directing capacity payments to gas-fired plants instead — received a nod from Brussels last year, according to a German economy ministry briefing reported by Montel on Friday (2026-07-10). Ministry documents suggest up to 5 GW of capacity could be allocated under terms that disadvantage storage, though the full technical specification was not publicly released.5
Clean energy developers are less comfortable with the parallel policy track. Industry figures told Montel on Thursday (2026-05-21) that the economy ministry's network package, intended to ease transmission bottlenecks, could trigger an abrupt slowdown in renewable investment. "The current network package… shifts investment risk very heavily on t[he developers]," one industry figure said. Grid reform that imposes connection uncertainty on multi-year projects discourages the long-cycle capital those projects require.1
The battery exclusion and the network package together sketch the emerging shape of German power market architecture: gas for dispatchable capacity, private capital for renewables, investors absorbing more grid integration cost than before. Germany has 500 GW-worth of battery storage projects queued for grid connections, more than 20 times current installed capacity, according to The Economist — a pipeline that erodes quickly if connection economics worsen. TenneT, which operates Germany's largest grid alongside Dutch networks, plans to spend €200bn on infrastructure by 2034. Private investors facing less certain terms may not share that patience.4
The Commission also approved a separate measure on Thursday (2026-05-21): Germany's plan to provide up to €3.8bn in electricity cost relief for energy-intensive industrial companies over three years, alongside similar schemes for Bulgaria and Slovenia. The subsidy acknowledges that prevailing German power prices are already pressing on industrial competitiveness, adding another layer to the toolkit Berlin is deploying to manage a costly transition.2
Across Europe, the grid investment burden is large. France's RTE has committed €100bn between 2025 and 2040. Italy's Terna is spending €18bn between 2024 and 2028. ENTSO-E, the European grid regulator, estimates the continent needs €800bn in network upgrades to meet 2050 electrification targets. Germany's capacity market design will shape the balance between gas-backed and market-driven investment in Europe's largest power system, with consequences for wholesale prices well beyond German borders.4
The more immediate variable is legislative timing. The Commission's approval of the 11 GW gas tender stays contingent on Berlin passing the long-term capacity scheme into statute. Until that happens, both the gas programme and the network package reform exist as approved in principle but unexecuted, leaving investment decisions across the renewables, storage and gas supply chains without the certainty that capital deployment requires.6,1