How the UAE Splits GCC Green Hydrogen Investment Between Masdar and ADNOC

Investigation | Read time: 12 minutes

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Abu Dhabi is running two separate strategies inside its GCC green hydrogen investment program, and each one answers to a different investor.

Masdar puts capital into overseas renewable projects, from a €1 billion Spanish electrolyzer to wind ventures across the UK, Germany, and Montenegro.

ADNOC keeps its capital closer to home, funding blue hydrogen, carbon capture, and efficiency upgrades that protect near-term cash flow. Board members and fund directors tracking the UAE’s hydrogen ambitions as one story are tracking the wrong story.

It is two stories, running in parallel, and this piece breaks down what each one means for GCC investors, industrial buyers, and the SMEs supplying them.

Masdar and ADNOC Split Abu Dhabi’s Clean Energy Capital

The UAE National Hydrogen Strategy 2050 sets a production target of 1.4 million tonnes per annum of low-carbon hydrogen by 2031, split between 1.0 million tonnes of green hydrogen and 0.4 million tonnes of blue hydrogen [5]. The strategy projects total national production reaching 15 million tonnes per annum by 2050 [5]. But domestic market models put local UAE industrial demand at 2.1 million tonnes per annum by 2031 [7]. Local factories, refineries, and steel mills will absorb early domestic hydrogen volumes well before Abu Dhabi has meaningful export capacity left over [5].

That gap between production ambition and domestic demand explains why Abu Dhabi executes its hydrogen strategy through two separate corporate entities instead of one [4].

Masdar manages a clean energy portfolio exceeding 65 gigawatts and targets 100 gigawatts of global renewable capacity by 2030 [9]. It puts capital into mature international markets with established regulatory backing. In March 2026, Masdar and Spanish energy firm Moeve reached a final investment decision, the point at which a project’s financing is locked and construction can begin, on Phase 1 of the Andalusian Green Hydrogen Valley in Spain [10]. The partners committed more than €1 billion to build a 300 megawatt electrolyzer that will produce 45,000 tonnes of green hydrogen annually, backed by a €304 million grant from the Spanish government [10]. Masdar also acquired 50 percent of US renewable operator Terra-Gen and formed wind joint ventures in Montenegro, Germany, and the UK [9].

ADNOC, meanwhile, directs its capital toward domestic decarbonization. It is expanding crude oil production capacity toward 5 million barrels per day by 2027 while holding upstream carbon intensity at 7 kg of CO2 equivalent per barrel of oil equivalent, a measure of how much carbon the company emits per unit of oil produced [4]. ADNOC funds efficiency projects like Project Wave, which supplies treated seawater to onshore operations to protect freshwater aquifers, and it is expanding carbon capture facilities at Al Reyadah [4].

This division lets Abu Dhabi chase overseas clean energy market share through Masdar while protecting domestic cash flow and industrial stability through ADNOC [4].

Entity	Mandate	Target	Capital Focus
Masdar	Overseas clean power and technology export	100 GW by 2030 [9]	International hydrogen joint ventures, utility solar, offshore wind [9]
ADNOC	Domestic hydrocarbon efficiency	5 Mbpd oil capacity by 2027 at 7 kg CO2e/boe [4]	Blue ammonia, carbon capture, Project Wave [4]

Low Power Prices Give Gulf Hydrogen Projects a Cost Edge

Global hydrogen consumption reached 99.5 million tonnes in 2024, but low-carbon hydrogen still accounts for barely 1 percent of that total, with fossil-based production supplying the rest [2]. High capital costs, expensive transport, unclear regulation, and buyers unwilling to pay a green premium have delayed hydrogen projects worldwide.

Developers had advanced only 20 gigawatts of electrolyzer capacity to final investment decision status by 2025, a fraction of announced global capacity, putting projected low-emission hydrogen supply at just 4.2 million tonnes by 2030 [3].

GCC developers operate under different economics. Sun-rich Gulf locations routinely secure solar power purchase agreements, long-term contracts that lock in electricity prices, between $0.012 and $0.022 per kilowatt-hour [1]. Since renewable electricity makes up 50 to 70 percent of the cost of producing green hydrogen, these low power prices compress production costs significantly [1].

At the same time, the capital cost of PEM electrolyzers, the equipment that splits water into hydrogen using electricity, fell more than 50 percent between 2018 and 2025, with manufacturers projecting a further 60 to 70 percent drop by 2030 as factory output scales [1].

Gulf developers also have supply chain flexibility that Western developers lack. Trade barriers restrict European and North American projects from importing lower-cost equipment, but Middle Eastern sponsors can source Chinese electrolysers without penalty [2].

That flexibility lowers capital cost per megawatt and lets GCC sovereign entities advance large projects while Western developers struggle to reach financial close [2].

Oman and Saudi Arabia Lock In Off-Take Before They Build

Oman and Saudi Arabia take different paths to the same goal: securing buyers before construction finishes.

Oman created Hydrogen Oman (Hydrom) as an independent central authority under Energy Development Oman to handle master planning, land allocation, and developer auctions [14]. Hydrom has allocated 50,000 square kilometers of land across Duqm, Dhofar, and Al Jazir, capable of supporting 180 gigawatts of renewable capacity [16]. The country targets 1.0 to 1.38 million tonnes of green hydrogen per year by 2030, scaling to 8.5 million tonnes by 2050 [16].

Those targets are already converting into signed contracts. In April 2024, Hydrom signed an $11 billion agreement with EDF Group and partners to build two green hydrogen projects in Dhofar, targeting 178,000 tonnes per year by 2030 using 4.5 gigawatts of combined solar and wind capacity [3]. The POSCO-ENGIE consortium secured a separate block, committing to 5 gigawatts of renewable capacity to produce 200,000 tonnes of green hydrogen annually for conversion into 1.2 million tonnes of green ammonia for export [14].

A third consortium, combining Shell, OQ, EnerTech, and InterContinental Energy, is targeting an initial 150,000 tonnes per year, with plans to expand to 25 gigawatts of renewables [14]. Oman backed these projects with grid investment, commissioning the 1 gigawatt Manah I and II solar plants in January 2025 and building a 400 kV transmission line linking inland solar sites to coastal industrial ports [15].

Saudi Arabia took a narrower, faster path through the NEOM Green Hydrogen Company at Oxagon [17]. A dedicated 4 gigawatt solar and wind complex, built from 5.6 million solar panels and 250 wind turbines across 300 square kilometers, powers the facility, which began energisation with completion on track for mid-2026 and commercial output starting in 2027 [17].

NEOM eliminated market risk entirely by signing a 30-year exclusive off-take agreement with Air Products for 100 percent of its output, 1.2 million tonnes of green ammonia annually, securing debt service regardless of spot price swings [17].

Bahrain Refits Existing Assets Instead of Building New Ones

Bahrain is taking a third approach entirely. Rather than build new megaprojects, Bapco Energies is upgrading what already exists [18]. Working under a national target to cut emissions 30 percent by 2035 and reach net zero by 2060, Bahrain has allocated $500 million toward hydrogen technology [19].

Bapco’s near-term focus is the Bapco Modernization Program, aimed at cutting operational energy intensity 6 percent by 2025 [19]. To work around Bahrain’s limited land for renewable generation, Bapco signed an agreement with Masdar in May 2024 to study developing 2 gigawatts of offshore wind capacity [22].

Country	Lead Agency	2030-31 Target	Off-Take Strategy
Oman	Hydrom (EDO) [14]	1.0-1.38 Mtpa green hydrogen [16]	Competitive auctions and domestic industry [15]
Saudi Arabia	NEOM Green Hydrogen Company [17]	1.2 Mtpa green ammonia [17]	30-year exclusive contract with Air Products [17]
Bahrain	Bapco Energies [18]	0.10 Mtpa hydrogen capacity [21]	Refinery refit and grid integration [19]
UAE	Masdar and ADNOC [4]	1.4 Mtpa, 1.0 green and 0.4 blue [5]	Domestic absorption plus overseas equity [5]

Heavy Industry Absorbs Hydrogen While Export Deals Stall

Whether a hydrogen project gets financed usually comes down to one question: who is buying the output? Globally, green ammonia makes up 28.7 percent of hydrogen applications and is growing at a projected 41.5 percent annually, while direct industrial use holds a 41.2 percent share [1].

In the Gulf, three channels are absorbing hydrogen output directly. Steelmakers in Oman are building facilities to replace fossil gas with hydrogen in iron production. Vulcan Green Steel and Jindal Shadeed are constructing a $3 billion green steel plant in Duqm, and Vale and Essar Group have signed supply agreements for iron ore pellets suited to hydrogen-based steelmaking [2]. Existing chemical plants offer a second channel.

In Salalah, Oman, the $1 billion SalalaH2 project is integrating 400 megawatts of electrolysers, powered by 1 gigawatt of solar and wind capacity, directly into OQ’s operating ammonia facility, replacing fossil gas feedstock [16]. A third channel is contracted export, the model NEOM used to lock in Air Products for its entire output [17].

Projects without firm buyers stall. Egypt shows what that looks like in practice. Between 2021 and 2024, Egypt signed non-binding memorandums of understanding worth $83 billion in hydrogen project announcements. By late 2025, developers had converted only 13 percent of those announcements into binding contracts, held back by high capital costs and the absence of guaranteed buyers [13].

Scatec’s 100 megawatt Egyptian facility reached operational exports in January 2026, but only after it secured explicit European purchasing contracts first [13].

The lesson for GCC developers is direct: land and sunlight are not enough. Buyers have to be locked in before capital moves.

Local Suppliers Find Margin in the Hydrogen Supply Chain

Primary electrolyzer plants routinely exceed $1 billion, which puts direct equity ownership out of reach for most small and medium enterprises [10]. But that has not shut SMEs out of the sector. It has pushed them toward specialized subcontracts where margins are strong and competition is thinner.

Four service niches stand out. Water electrolysers need high-purity deionized water, and local water engineering firms are winning contracts to design and service reverse osmosis and desalination systems [4]. Desert solar farms lose efficiency to dust, so local firms supplying automated robotic panel cleaning, thermal inspection drones, and protective coatings are building recurring service revenue [9]. Primary EPC contractors, the firms responsible for engineering, procurement, and construction on a project, are hiring local civil engineering companies for ground preparation, high-voltage cabling, and substation work [9]. And local software providers are supplying energy management, emissions tracking, and compliance reporting tools to plant operators [4].

National In-Country Value programs are the main mechanism connecting local suppliers to sovereign project spending. ADNOC’s ICV framework scores primary contractors on local procurement, local manufacturing spend, and national workforce employment, and contractors winning sovereign contracts must direct subcontracts to qualified local suppliers to meet that obligation [4]. Dubai SME’s digital empowerment programs add another entry point, giving local entrepreneurs the digital tools to compete for industrial subcontracts [6].

What This Means for GCC Business Leaders

Four moves separate the companies capturing value in this sector from the ones watching from the sidelines.

• Prioritize binding domestic off-take over speculative exports. Secure purchasing commitments from local steel mills and chemical refineries before deploying equity into generation assets [7]. Egypt’s stalled MoUs are the cautionary case.
• Audit ICV alignment before bidding. SMEs should review local procurement metrics, national hiring, and regional supplier partnerships against sovereign ICV criteria before pursuing EPC subcontracts [4].
• Target technical service niches, not equity. Water pre-treatment, robotic solar maintenance, and carbon accounting software carry lower capital requirements and strong recurring revenue [4].
• Run a dual-track model, not a single bet. Combine near-term operational efficiency and low-carbon refits with longer-term hydrogen positions, the same structure Abu Dhabi itself is running at the sovereign level [4].

The pattern across all four Gulf states is the same, even though the mechanisms differ. Saudi Arabia proved that gigawatt-scale facilities reach completion when backed by exclusive off-take agreements [17].

Oman proved that central planning and competitive auctions attract foreign capital at scale [16]. Bahrain proved that targeted refits can move the needle without a megaproject budget [19]. None of these three needed the UAE’s balance sheet or its dual-track structure.

That is the point business leaders should take from this sector: the Gulf’s hydrogen advantage is not just cheap solar power and open land, it is a set of national models built to fit each country’s actual financial position, and the model matters more than the ambition behind it.

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