German parliament clears 11 GW hydrogen-ready power plant tenders as EU competition scrutiny eases
Berlin's capacity market law passed its lower house on Thursday (2026-07-09), opening tenders for 11 GW of gas-fired plants that will reshape German power pricing.
Germany's parliament approved a law on Thursday (2026-07-09) clearing the way for tenders of 11 GW of gas-fired, hydrogen-ready power plants as part of a new capacity market designed to replace coal and nuclear output with dispatchable generation. The measure cleared the lower house by voice vote and now moves to the upper chamber, where approval is widely expected given the cross-party support the framework has attracted.6
European power traders are pricing the consequence. German power front-month stood at €155.51/MWh early Thursday (2026-09-03), with the Cal+1 contract at €123.12/MWh — levels that embed expectations of tight supply well before the new plants come online.6
The parliamentary vote caps a year of legislative groundwork. A German economy ministry official said on Tuesday (2026-05-19) that a raft of energy legislation would come up for vote in the following days and weeks, though he ruled out any "180 degree course corrections" to Berlin's energy strategy. The power plant law is the most consequential of that batch, setting up a capacity mechanism that pays gas plants for availability rather than just output.1
Brussels had already cleared the path. The European Commission approved Germany's plan on Thursday (2026-05-21) to provide up to EUR 3.8bn in subsidies to lower electricity costs for energy-intensive companies over three years, alongside Bulgarian and Slovenian schemes. That decision came alongside separate state aid clearance for EUR 1.3bn ($1.51bn) in German support for renewable hydrogen projects, aimed at bidders that failed to win in earlier auctions.2,3
The hydrogen money is flowing to specific projects. European Energy has been awarded up to EUR 228m ($265.85m) under Germany's hydrogen auction framework linked to the European Hydrogen Bank, one of three projects selected for support, contributing to Danish production capacity feeding German offtakers.4
The subsidy approvals and the plant tender law form two halves of the same industrial strategy. Berlin compensates energy-intensive manufacturers for carbon costs embedded in power prices while simultaneously building the generating capacity to keep those prices competitive once coal exits. The Commission's approval of expanded carbon cost compensation on Wednesday (2026-07-08) granted 20 additional sectors access to the subsidy scheme, widening the safety net beneath German industry.5
The capacity market design will test how much gas demand Germany's power sector actually generates. New plants will be hydrogen-ready, but fuel switching to green hydrogen at scale depends on electrolyser buildout and import infrastructure that does not yet exist. In the interim, those turbines burn natural gas, adding demand pressure to European gas balances already trading with ICE Endex TTF front-month at €73.67/MWh.6,4
State aid calculus in Brussels has shifted. Approving both the industrial subsidy top-ups and the hydrogen support within weeks signals that the Commission accepts Germany's argument that electrification of industry requires bridging mechanisms, not just carbon pricing. Other member states with heavier industrial bases are paying close attention to that interpretation of competition rules.2,3
But the physical picture is more complicated than the futures curve suggests. German power Cal+1 at €123.12/MWh reflects a market already positioned for tighter balances, yet generation from the new gas fleet will not arrive until tenders are awarded, plants constructed, and grid connections completed — a process that typically runs three to four years from award.6
The upper house vote is the next concrete hurdle. If the law clears as expected, the first tenders for gas-fired capacity could open before year-end, and auction results will give the market its first read on bid pricing for availability payments. Those outcomes will set the floor for what German industry pays for reliable power through the coal phase-out.6
Underneath the capacity mechanism sits the hydrogen credibility question. If green hydrogen fails to reach competitive cost by the late 2020s, the hydrogen-ready plants will simply run on natural gas for longer, embedding higher fuel demand into German power prices and pulling additional European gas volumes toward the German market. Bid prices in the first tender round will reveal how developers are pricing that uncertainty.4