The Opportunity:

Two of the world's most intractable decarbonization challenges — the fossil gas dependence of the global fertilizer industry and the prohibitive cost of carbon capture from energy generation — share a common solution. A single green hydrogen infrastructure, built around water electrolysis, can address both simultaneously, creating a rare convergence of positive climate impact and commercial advantage.

Water electrolysis splits water into hydrogen and oxygen in a fixed ratio. Today, the hydrogen from electrolysis is used as a petrochemical feedstock (but which can easily be used in ammonia synthesis for fertilizer). The oxygen — eight kilograms for every kilogram of hydrogen produced — is simply vented as waste. We at CO2 Norway argue that the hydrogen should be used in production of green ammonia for fertilizer to displace use of fossil gas. And that this should be integrated with use of the biproduct pure oxygen in oxyfuel combustion of biogas and fossil gas. This can eliminate the single greatest cost barrier to carbon capture and storage (CCS): the expensive separation of CO₂ from nitrogen-diluted flue gas resulting from combustion in air. Treating these two outputs as an integrated system, rather than a primary product and a waste stream, changes the investment economics for both.

The Business Case

A stacked, diversified revenue model

An integrated green hydrogen–ammonia–oxyfuel project captures value across multiple revenue streams that no standalone facility can access:

  • Green ammonia sales: Fertilizer commands a large, predictable global market of ~185 million tonnes per year. Green ammonia can be used locally or enter existing shipping, storage, and distribution infrastructure directly, avoiding the liquefaction and carrier-conversion challenges that hamper direct distribution of hydrogen from centralized production facilities to users across regions.
  • Carbon removal credits: Oxyfuel combustion of biogas with pure oxygen biproduct from electrolysis— bioenergy with carbon capture and storage (BECCS) — generates not only power and heat but also verifiable negative-emissions credits. Biogenic CO₂, once captured and sequestered, constitutes genuine atmospheric removal, a category that commands premium pricing in voluntary and regulated carbon markets and is central to mitigating global warming.
  • Eliminated capital cost of air separation: Replacing an air separation unit (ASU) with electrolytic, pure oxygen removes a major capital and operating cost from the oxyfuel facility. The oxygen is a co-product of electrolysis already paid for by hydrogen revenues; its marginal cost to the combustion facility is substantially below industrial oxygen pricing.
  • Shared infrastructure savings: Grid connections, water treatment and pre-heating, compression systems, heat recovery, and control infrastructure can be shared across the electrolyser, ammonia synthesis, biogas energy, and CO₂ compression units — reducing per-unit capital costs relative to the sum of independent installations.

Cost-reduction dynamics

Post-combustion carbon capture from conventional power plants costs an estimated $100–170 per tonne of CO₂, rendering it uneconomic in most markets without strong policy support. Oxyfuel combustion with electrolytic oxygen replaces the expensive separation step with straightforward cooling and condensation, at an estimated cost below $15 per tonne captured CO₂. This is possible because the flue gas from oxyfuel consists of water vapor and CO2 only. Oxyfuel enables a a structural cost reduction of one order of magnitude, not an incremental improvement, and compares even more favourably against direct air capture, which currently costs $400–1,000 per tonne.

On the hydrogen side, oxygen revenue reduces the effective net cost of green hydrogen production. As electrolyser and renewable electricity costs continue their well-documented learning-curve declines, and as carbon pricing and global fossil gas supply unreliability and price volatility increasingly penalise grey hydrogen, the competitive position of green ammonia will become unassailable. The integrated green hydrogen-fertilizer-oxyfuel energy system accelerates this crossover.

Market Scale and Strategic Timing

Global ammonia production consumes approximately 30–35 million tonnes of hydrogen annually, making it the world's largest single hydrogen end-market after petroleum refining. The grey ammonia problem — approximately 450–500 million tonnes of CO₂-equivalent emitted each year by steam methane reforming for fertilizer production alone — represents 1–1.5% of total global greenhouse gas emissions from a single feedstock. This is a replacement market of known, large, and stable size.

The energy crises of 2022 and 2026 exposed the geopolitical and food-security risks of fossil-dependent fertilizer supply chains in concrete terms. Price volatility, supply curtailments, and resulting fertilizer shortages demonstrate that the true cost of grey ammonia — including supply risk — is not fully priced. Investors who move early to establish integrated green hydrogen–ammonia–BECCS infrastructure will be positioned to supply a market under structural pressure to transition.

Climate and Regulatory Tailwinds

The integrated system is the only approach that simultaneously severs fertilizer production from fossil fuels and enables cost-effective carbon removal from bioenergy. These are complementary outputs of a single physical system, not competing priorities.

As regulatory frameworks increase costs of carbon emissions from industrial processes, carbon removal credits gain increasing value in both voluntary and compliance markets. A project delivering both green fertilizer and negative emissions is positioned to benefit from multiple, reinforcing policy tailwinds — green hydrogen incentives, carbon removal premiums, and agricultural decarbonisation mandates — rather than depending on a single regulatory lever.

The Investment Proposition

The commercial logic for the integrated system is straightforward: both the green ammonia industry and the oxyfuel carbon-capture industry have been analysed and financed as standalone projects, each absorbing costs that the other could eliminate. The green hydrogen–ammonia–oxyfuel integration does not require new chemistry or unproven technology. Alkaline and PEM electrolysers, Haber-Bosch ammonia synthesis, anaerobic digestion, and oxyfuel combustion with CO₂ capture are all technically mature. What is new is their combination into a single synergetic system.

Project development should target sites with favourable overlap of low-cost renewable electricity, available organic waste or agricultural residue streams, regional fertilizer demand, and accessible CO₂ storage geology. Agricultural regions in the Americas, Northern Europe, the Middle East, and Australasia frequently satisfy several of these conditions simultaneously.

The infrastructure decisions being made now will define the food and energy systems of the next fifty years. This paper calls for project developers, investors, and policymakers to build the analytical frameworks, financing structures, and enabling policy incentives that allow these complementary processes to be planned and operated as the single optimised system their chemistry demands — before the window for establishing first-mover advantage closes.