CCGT

In the European power markets briefing series, CCGT sits at the nexus of the gas-storage and carbon stories. At TTF EUR 47/MWh and EUA EUR 75/tonne (May 2026 levels), CCGT short-run marginal cost reaches approximately EUR 129/MWh, above German day-ahead clearing of EUR 106.35 — producing a negative clean spark spread and pushing German gas plant off-merit. This dynamic is the proximate reason commercial gas-injection economics broke in May 2026: running a CCGT to inject gas into storage destroys value at these relative prices, concentrating the storage burden on mandate-driven operators. The carbon component alone (EUR 34-39/MWh) is the share cited by German chemical and industrial consumers as central to the EUR 62-68/MWh power-cost floor driving curtailment decisions. Germany's planned 12 GW hydrogen-ready capacity is an attempt to preserve CCGT-style flexibility while building a route out of the EUA cost exposure.

A Combined-Cycle Gas Turbine (CCGT) plant generates electricity by running a gas turbine on natural gas combustion, then capturing the exhaust heat in a heat-recovery steam generator (HRSG) to drive a second steam turbine. This two-stage recovery lifts efficiency to 55-62% — significantly higher than the 35-40% of a simple-cycle open-frame gas turbine — and reduces fuel consumption and carbon emissions per MWh of output. CCGTs typically reach full output within 30-60 minutes, faster than coal or nuclear but slower than open-cycle gas turbines used for peak shaving. Their combination of efficiency, dispatchability, and moderate capital cost made them the dominant new-build thermal technology in European power systems through the 2000s and 2010s.

In electricity merit-order terms, CCGTs typically sit mid-stack: they operate more cheaply than older open-cycle gas plant or oil-fired capacity, but are undercut by nuclear, hydro, and renewables on marginal cost. On high-demand days with low wind and high industrial load, the last CCGT running is often the market price-setter — the 'marginal unit' whose short-run marginal cost clears the Day-ahead market. That cost has two principal components: the gas fuel input (indexed to TTF or NBP) and the carbon cost of emissions (priced via EU Allowances under the EU ETS at approximately 0.52 tonnes CO2/MWh for a modern CCGT). The clean spark spread — the margin after fuel and carbon — is the key profitability signal for CCGT operators.

Energy transition planning in Europe gives CCGTs a dual role: as the dispatchable backbone supporting intermittent renewables in the near term, and as a potential hydrogen-burning asset in the longer term once green hydrogen costs fall sufficiently. Germany's government approved a 12 GW hydrogen-ready gas capacity tender in 2024, explicitly specifying plant designs capable of co-firing or switching to hydrogen. The economics of that transition depend critically on whether hydrogen can undercut CCGT marginal cost at scale.