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Low-Carbon Hydrogen in Oil & Gas: Where the Market Actually Stands in 2026
The investment numbers look encouraging, but the project pipeline doesn't. This article covers what the IEA's latest data actually shows about low-carbon hydrogen production, why Shell and Equinor cancelled their flagship blue hydrogen projects in the same month, what the EU's November 2025 Delegated Act changed for project developers, and where that leaves oil and gas operators trying to make decisions now.
Low-Carbon Hydrogen Production Gap: IEA Data on Investment vs. Output in 2025
Capital spending on low-emissions hydrogen reached $4.3 billion in 2024 – an 80% increase from 2023. Based on projects reaching final investment decisions, the IEA projected another 80% rise in 2025 to nearly $8 billion.
That momentum is real, but production hasn't followed. In 2024, low-emissions hydrogen accounted for less than 1% of global output: roughly 0.8 million tonnes out of almost 100 million tonnes consumed worldwide. The other 99% came from coal and unabated natural gas.
The pipeline of announced projects tells the sharper story – the IEA estimated 37 Mtpa of low-carbon hydrogen by 2030 in its September 2025 review, down from 49 Mtpa the previous year. By June 2026, that figure had fallen further to 27 Mtpa as cancellations accumulated and project timelines extended beyond 2030. Of those 27 Mt, only around 6 Mt is regarded as having strong potential to be operational by 2030, down from 10 Mt nine months earlier.
In the IEA's Net Zero Emissions by 2050 Scenario, new applications of hydrogen need to represent roughly 40% of global demand by 2030. Today they account for less than 0.1%.
Blue Hydrogen vs Green Hydrogen: LCOH Comparison for Oil and Gas Operators in 2026
Gray hydrogen from unabated steam methane reforming costs $1.50-2.50 per kilogram. Adding CCS for blue hydrogen raises that to $2.00-3.50/kg, with natural gas accounting for 50-65% of production cost. Blue is still cheaper than green in most markets, but its economics track gas prices closely, which creates exposure in project finance structures built for a 20-year horizon.
Green hydrogen from electrolysis runs $3-6/kg at scale in 2026. In high-renewable-resource regions (MENA solar, northwest China, parts of Chile) projects are already reaching $2.00-2.50/kg. Electrolyzer CAPEX fell from roughly $1,500/kW in 2020 to $700-1,000/kW today, and overall costs have dropped about 45% over that period. The direction is clear – the timeline for cost parity in most markets still points to the late 2020s at the earliest.
For O&G operators in gas-rich regions with established CO₂ storage access, blue hydrogen offers a near-term cost advantage and lower capex relative to electrolysis. For those operating in or supplying to European markets, the regulatory picture adds complexity that the November 2025 Delegated Act now makes legally explicit.
EU Low-Carbon Hydrogen Delegated Act 2025: GHG Threshold and What It Means for Projects
Commission Delegated Regulation 2025/2359, published in the Official Journal of the EU on 21 November 2025, established the first legally binding EU-wide definition of low-carbon hydrogen. A production pathway qualifies if it achieves at least 70% GHG savings against a fossil fuel comparator of 94 gCO₂e/MJ – equivalent to a maximum of 3.38 kg CO₂e per kilogram of hydrogen, measured across the full lifecycle.
Full lifecycle accounting covers upstream methane emissions, CO₂ capture rate and storage permanence, transport and storage infrastructure efficiency and grid electricity carbon intensity for electrolysis. For blue hydrogen using standard SMR at 85-90% capture, clearance depends heavily on upstream methane leakage in the supply chain. Autothermal reforming at capture rates above 93% provides more headroom.
The Act creates no financial incentives and sets no production targets. Its function is to end ambiguity: a pathway is either certifiably low-carbon under EU law or it is not. For developers seeking long-term offtake with EU industrial buyers, or building towards the import compliance requirements under the Gas Package, that regulatory certainty reduces one category of project risk. The offtake question is a different matter.
Explore DECARBON 2027 Business Programme
Why BP, Shell and Equinor Cancelled Their Blue Hydrogen Projects
Companies most often cited as low-carbon hydrogen leaders spent 2024 and 2025 cancelling their flagship projects.
Shell and Equinor abandoned their Norwegian blue hydrogen plans in September 2024. The proposed project involved producing blue hydrogen from Norwegian gas, capturing the CO₂ offshore and exporting via a new subsea pipeline to German power plants. Equinor's stated reason: "We are not able to make this kind of investment when we don't have long-term agreements and the markets in place."1 Shell cited identical reasoning for closing the Aukra Hydrogen Hub. By February 2026, Equinor had dropped its H2M Eemshaven project in the Netherlands and paused all new CCS investment.
BP cancelled 18 hydrogen projects in 2024, closed HyGreen Teesside in March 2025, and shut the 1.2 GW H2Teesside blue hydrogen project in December 2025. By 2027, low-carbon energy accounts for roughly 6% of BP's annual capex: $8.90 in oil and gas for every $1 in low-carbon technology.
Across all three companies, the cancellations share one characteristic: missing demand. Industrial buyers have not committed to hydrogen contracts at prices that justify new infrastructure. The IEA's Breakthrough Agenda 2025 identifies this as the central structural barrier – developers cannot secure creditworthy offtake agreements that allow projects to reach FID.
Gray Hydrogen and EU Regulation: Why Unabated Production Is No Longer Viable
Gray hydrogen produces 9-12 kg of CO₂ per kilogram of output. It sits outside EU low-carbon certification by definition. EU ETS carbon pricing adds a per-tonne cost to unabated production in European markets that has grown substantially since 2020 and now makes the cost gap between gray and blue hydrogen meaningfully smaller than it was five years ago.
For O&G operators supplying European industrial customers, gray hydrogen is increasingly a contract liability. The question is what certification pathway, timeline and offtake structure the market will accept. The November 2025 Delegated Act has narrowed the available answers.
Discussing Low-Carbon Hydrogen at DECARBON 2027: Berlin, 15-16 February
The open questions this market leaves in 2026 are operational: what CCS configuration clears the Delegated Act threshold in practice, how to structure a blue hydrogen project with a credible pathway to green feed later, what bankable offtake looks like when buyers are cautious, how operators in US markets are adjusting after the IRA policy reversals.
DECARBON 2027 addresses these in sessions built around projects that have reached FID or operational status. The hydrogen and CCUS programme tracks bring upstream, midstream and downstream operators together with EPCs, technology providers and regulators across two days in Berlin. The offtake question is on the agenda precisely because the market hasn't resolved it yet.
FAQ
What is DECARBON 2027?
DECARBON 2027 is the Oil & Gas Decarbonisation Congress – a closed-door B2B event bringing together senior operators, EPCs and technology providers from across the global oil and gas value chain. The programme covers CCUS, low-carbon hydrogen, methane abatement, energy efficiency, regulatory compliance and digital tools for net-zero.
When and where does DECARBON 2027 take place?
DECARBON 2027 takes place on 15-16 February 2027 in Berlin, Germany. The two-day programme includes sessions, a technology exhibition and structured B2B meetings.
Who attends DECARBON 2027?
DECARBON 2027 is attended by C-level executives, sustainability leads, technical experts and operational decision-makers from major oil and gas operators, upstream producers, midstream companies and refiners, alongside the technology, EPC and service companies supporting the sector's energy transition. The Congress operates on a closed-door model, with participants selected to maintain a focused professional environment of end-users, solution providers and licensors.
How do companies participate in DECARBON 2027?
Companies participate in DECARBON 2027 as delegates, sponsors, exhibitors or speakers. Participation details are available on request.
Is low-carbon hydrogen production on track to meet 2030 climate targets?
Low-carbon hydrogen production is not on track to meet 2030 climate targets. The IEA's June 2026 assessment finds that only around 6 million tonnes per year has strong potential to be operational by 2030 – down from 10 Mt estimated nine months earlier – against a pipeline of 27 Mtpa of announced projects. In the IEA's Net Zero Emissions by 2050 Scenario, new hydrogen applications need to represent roughly 40% of global demand by 2030, but today they account for less than 0.1%.
What does the EU Delegated Act require for hydrogen to be classified as low-carbon?
The EU Low-Carbon Hydrogen Delegated Act (Regulation 2025/2359), published in November 2025, requires hydrogen to achieve at least 70% greenhouse gas savings compared to a fossil fuel comparator – equivalent to a maximum of 3.38 kg CO₂e per kilogram of hydrogen across the full lifecycle. The methodology covers upstream methane emissions, CO₂ capture rate, storage permanence and, for grid-connected electrolysis, the carbon intensity of the electricity supply. Production that does not meet this threshold cannot be certified as low-carbon under EU law.