While previous hydrogen trials were confined to decommissioned sections of the National Transmission System (NTS), the test at Centrica’s facility in north Lincolnshire marks the UK’s first live demonstration.
After the hydrogen was injected, it was blended with natural gas and delivered to the Brigg Power Station, where it was combusted in gas turbines to produce electricity for the national power grid.
Previously, Centrica and HiiROC partnered to trial hydrogen blending at the Brigg site, utilising hydrogen produced on-site and blended into the station’s own gas feed.
Typically operating for less than three hours a day, the 240MW gas-fired peaking plant balances the UK’s electricity grid during times of high demand.
The milestone follows the UK government’s launch of a consultation on allowing 2% hydrogen in the NTS, designed to evaluate whether and how hydrogen blending should proceed.
“The results of this trial are especially exciting as we push to develop a world-leading hydrogen economy right here in the Humber,” explained Chris O’Shea, Group Chief Executive at Centrica.
“If the government can seize this opportunity, hydrogen can turbocharge economies like the Humber, creating jobs, boosting economic growth, and ensuring communities across the area remain at the heart of the UK’s energy transition.
“Not only does this enhance our energy security, it also ensures we can power the UK when the sun doesn’t shine, and the wind doesn’t blow.”
Both Centrica and National Gas are now urging the government to provide a strategic policy decision for a hydrogen blend of up to 5%.
“This would maximise the potential of blending, support greater investment and market certainty, while requiring minimal additional technical modifications,” Centrica’s statement read.
National Gas’ research has indicated that a 5% mix in the NTS could allow hydrogen producers to de-risk 100% of their offtake by 2028/29, resulting in around 30% de-risking by 2035 as more projects come online. That’s compared with just 10% under a 2% injection.
Higher hydrogen blends are technically feasible, according to analysts and stakeholders.
Penspen’s CEO, Peter O’Sullivan, recently confirmed to H2 View that the majority of Europe’s distribution networks can safely handle up to 20% hydrogen blends.
Other industry voices see value even at 2%. During an H2 View webinar, Lhyfe’s Boris Davis noted that if pipeline infrastructure is delayed, producers need an outlet.
He said a 2% share offers a low-impact bridge, serving more as an “offtaker of last resort” than a decarbonisation tool, while providing certainty for early projects.
However, not all industry voices support the idea. Energy analyst Michael Liebreich dismissed hydrogen blending as “the stupid idea from Stupidville” at an event earlier this year.
He argued that blending destroys the value of green hydrogen by downgrading its heat content.
Analysis: Why hydrogen blending is up for discussion again
Hydrogen blending is back on the agenda. This time, grid decarbonisation isn’t the primary motive. Now, it is viewed as a way to derisk clean hydrogen projects while demand remains low and infrastructure undeveloped.
However, it’s contentious. Regardless of how pragmatic a route it may be, blending faces stark opposition from both physical and financial efficiency hawks and members of the public.
The growth in discussions comes as the UK energy department consults the market on allowing up to 2% hydrogen blends into the National Transmission System (NTS). The consultation, which launched in July, aims to assess whether the benefits of blending outweigh the potential costs for NTS end-users.
While it’s positioned as a way to support climate targets, the department said, “Transmission blending could play a role in managing the risk of hydrogen producers being unable to sell sufficient volumes of hydrogen.”
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