Gulf Hydrogen Ambitions Tested as NEOM Project, UAE Strategy Race to Lock In Asian Offtakers

Gulf states are doubling down on plans to become major exporters of low‑carbon hydrogen and its derivatives by the early 2030s, but analysts warn that cost overruns, infrastructure bottlenecks and hesitant buyers in Europe and Asia could delay commercial scale. Saudi Arabia’s flagship NEOM hydrogen project, widely billed as the world’s largest, is scheduled to begin production in December 2026, while the UAE has unveiled an expanded national hydrogen strategy targeting 1.4 million tonnes of green hydrogen output annually by 2031 and 15 million tonnes by 2050.

A recent policy paper on Gulf energy transitions notes that Oman, Saudi Arabia, the UAE and Qatar—in that order—have made the most progress on planning low‑carbon hydrogen industries, though each faces different constraints. Saudi Arabia enjoys abundant solar and wind resources along the Red Sea coast and is backing NEOM with significant state support, but faces questions over long‑term offtake prices and transport costs for ammonia shipments to Europe, Japan and South Korea. Oman has attracted consortia for coastal hydrogen and green‑ammonia plants but must balance fiscal capacity with other infrastructure needs.​

The UAE’s hydrogen blueprint is among the most detailed. By 2031 it plans to develop two hydrogen production hubs, expanding to five hubs by 2050, while raising renewables’ share of domestic power generation to 30 percent by the early 2030s. Officials say the goal is for the UAE to capture up to 25 percent of key global hydrogen markets by 2030, leveraging existing oil and gas export infrastructure, trading expertise and sovereign wealth fund capital.​

Japan and South Korea—early movers in hydrogen strategies and potential anchor buyers for Gulf projects—have so far been cautious about locking in large, multi‑decade volumes at premium prices. Utilities and heavy‑industry players in both countries are grappling with domestic grid decarbonisation, nuclear restarts and competing renewable options, making them reluctant to sign the kind of long‑term, take‑or‑pay contracts that would de‑risk giga‑scale hydrogen investments.​

European demand has been similarly tentative. While Brussels and Berlin have signalled political support for importing low‑carbon hydrogen, actual tendered volumes remain modest, and price benchmarks for green versus blue and grey hydrogen are still evolving. That leaves Gulf exporters in a “chicken‑and‑egg” bind: they need scale to push down costs and prove reliability, but financiers and buyers want clearer economics before committing.​

Despite these hurdles, S&P Global and regional think‑tanks argue that hydrogen remains a strategic hedge for Gulf producers as global fossil demand plateaus over coming decades. Large‑scale projects like NEOM, UAE’s hubs and Oman’s consortia are expected to attract blended finance packages from export‑credit agencies, multilateral lenders and Asian and European commercial banks willing to treat early deals as quasi‑infrastructure with upside.​

Within domestic power systems, Gulf states are also experimenting with hydrogen‑ready gas turbines and industrial offtake for steel, cement and petrochemicals, which could absorb part of initial output if export markets lag. Japan and South Korea are watching closely, seeing in the Gulf not just a fuel supplier but an R&D test bed for co‑firing, storage and transport technologies.​

For investors, the 2026–2030 period is likely to separate flagship, state‑backed projects with credible offtake pathways from more speculative announcements aimed at signalling rather than delivery. Equity and debt providers will scrutinise contract structures, regulatory support and integration with existing energy systems before committing to multi‑billion‑dollar exposures that could span 20–30 years.