On January 14, 2025, the United Arab Emirates announced a 5.2-gigawatt solar project backed by 19 gigawatt-hours of battery storage. This technical choice reflects the strategy of certain Gulf States: controlling locally produced electricity to reduce domestic consumption of fossil fuels, which can increase exportable volumes. The MENA region invested 22 billion dollars in renewable energy in 2025, with a pipeline of 202 gigawatts in development—figures that sketch a structural shift, provided the grid keeps pace.
The essentials
- Gulf States are deploying renewables to feed their domestic demand, freeing up their hydrocarbons for export: a dual fossil and solar rent, simultaneous.
- The MENA region invested 22 billion USD in renewables in 2025, with 202 GW in pipeline (Middle East Energy 2026 / Dii Desert Energy MENA Outlook 2026).
- The Emirati project of 5.2 GW solar coupled with 19 GWh of batteries is designed to deliver 1 GW continuously, twenty-four hours a day: storage, combined with the grid, demand response, and other flexibilities, can help make solar production more controllable.
- The major risk is structural curtailment: if storage does not keep pace with renewable deployment, the barrels are not freed up and the transition rent is captured only by actors capable of financing fossil backup.
- The question facing the region at the 2030–2035 horizon is who benefits from the pivot: local economies, industrial consumers, or only state-owned enterprises.
The Gulf produces oil and builds solar panels at the same time
The dominant narrative on energy transition often rests on a contrast: fossil fuel-producing countries resist change, and importing countries push it forward. The Persian Gulf dismantles this scheme through concrete action.
Saudi Arabia, the United Arab Emirates, and Oman rank among the leading renewable energy investors in 2025 in the MENA zone, for several billion dollars. These sums finance projects at industrial scale, designed to durably reshape the domestic electricity mix. The objective includes reducing domestic consumption of liquid fuels and optimizing available hydrocarbons, alongside other goals of economic diversification and decarbonization.
Saudi Arabia today burns several hundred thousand barrels per day to produce its national electricity. A reduction in domestic hydrocarbon consumption can increase the volume potentially available for export. With oil prices oscillating between 70 and 90 dollars in recent periods, domestic energy substitution can boost export potential, subject to prices, quotas, production capacities, and commercial choices. In certain producer countries, renewables can both reduce domestic fossil fuel use and increase export potential.
This logic yields a potential double rent. Solar electricity is produced at nearly zero marginal cost once infrastructure is installed, and reducing domestic fossil fuel consumption can increase volumes available for export. The two revenue streams coexist through coordinated investment decisions between states and national enterprises.
Storage, not installed capacity, changes the game
The Emirati project announced on January 14, 2025 deserves close attention because it illustrates a break in method rather than simply more of the same.
5.2 gigawatts of installed solar capacity represents significant peak power. A solar plant without storage produces electricity when the sun shines and nothing at night or in cloudy weather. Sunshine in Gulf countries ranks among the world’s most intense, but continuous supply poses a problem: consumption peaks occur in the evening, when daytime heat gives way to night-time air conditioning.
The 19 gigawatt-hours of batteries attached to the Emirati project address this issue precisely. They make it possible to store energy produced mid-day and release it in the evening, guaranteeing continuous power of 1 gigawatt, twenty-four hours a day. This is no longer intermittent energy: it is controllable power, comparable to what a thermal plant can offer, but without fuel to burn.
This technical shift carries implications that extend beyond the Emirates. A heavily solar system can reduce the role of fossil plants if it has a sufficient set of storage, grid, demand response, and other flexibilities. Renewable development can reduce domestic fossil fuel use and increase their potential availability for export. Dependence on the electrical grid as a strategic pivot is not unique to the Gulf: it is a universal constraint on transition.
The difference with Europe or France is that Gulf States have an immediate economic interest in solving this constraint. Oil revenues can finance renewable and storage development, potentially freeing hydrocarbons for export. The loop is virtuous for producers, at least in the short term.
202 gigawatts in pipeline, deployment for which the grid will be the true bottleneck
The total MENA pipeline reaches 202 GW, of which 38 GW are under construction, 34 GW in development, 43.7 GW operational, and 87 GW announced or under framework agreement. To give a sense of scale, the total installed electrical capacity in mainland France at end 2025, from all sources combined, is approximately 164.5 gigawatts.
But a project in a pipeline is not a project built. The history of global energy transition shows that the gap between announcements and deployment depends on several variables: grid capacity, financing, permits, supply chains, and project execution.
Curtailment is an important indicator of difficulties in renewable integration, but it does not measure solely grid insufficiency. In Brazil, this phenomenon reached concerning levels in 2025: wind and solar farms in operation, but part of their output is shed because transmission lines cannot carry the electricity to consumption areas. Installed capacity is growing faster than transport infrastructure.
The Gulf is not there yet. But the risk exists, and it is structural. Insufficient deployment of grid and storage risks producing curtailment and reducing effective substitution of fossil fuels. The transition rent, savings on domestic fossil fuel consumption, could be concentrated among well-capitalized actors.
The Emirati project illustrates this approach: coupling 5.2 GW of solar with 19 GWh of storage aims to supply up to 1 GW of renewable power continuously; storage can limit curtailment but does not automatically make all 5.2 GW installed dispatchable.
Who captures the transition rent: the question the figures have not yet settled
22 billion invested, 202 gigawatts in pipeline, flagship projects of several billion each—these figures describe massive deployment. They do not yet say who concretely benefits.
Gulf States are economies where national hydrocarbon enterprises, Saudi Aramco, ADNOC in the Emirates, play a major role in energy revenues. The transition to renewables unfolds within the same institutional framework. Large solar projects are led by public or quasi-public entities: ACWA Power in Saudi Arabia, Masdar in the Emirates. The model is not one of a market open to competition: states retain a central role in renewable development, notably through planning and tender processes.
This deployment remains technically sound: infrastructure is being built, electricity will be produced, and local demand will be met. The distribution of benefits remains uncertain. Residential consumers could benefit from lower electricity prices thanks to cheap solar, and local industries could access competitive energy conducive to their diversification away from hydrocarbons.
The transition rent—savings on domestic consumption and preserved export revenues—could be distributed unevenly depending on institutional structures and financing capacities.
Available data do not yet allow a determination. Gulf countries display ambitious economic diversification targets, Saudi Arabia’s Vision 2030 and UAE Energy Strategy 2050, and cheap domestic energy constitutes a potential lever to attract manufacturing industries and energy-intensive data centers. This causal chain is not yet confirmed by industrial investment flows.
On this point, comparison with Europe is instructive. Decarbonized electricity is not enough to decarbonize an economy: electricity must still be available, accessible, and cheap for industrial uses. The Gulf has the advantage of abundant solar. The question is whether local market structures will allow this advantage to spread.
The 2030 milestones and Gulf strategy
Two scenarios structure the 2030–2035 horizon for the MENA region, and the signals to watch are already identifiable.
In the first, large-scale storage reaches the targeted capacities. Domestic electricity demand in Gulf States is covered by renewables for a growing share. Progress in exports can be compatible with domestic substitution, but must be compared against production data, inventories, and domestic consumption to establish it.
International climate commitments remain under tension, but the Emirates and Saudi Arabia can argue that they have reduced their domestic fossil fuel consumption.
In the second, a significant portion of the renewable pipeline deploys without storage and transmission capacities following at a comparable pace. Curtailment risk rises. Effective substitution of fossil fuels would be reduced. Financers of renewable projects—well-capitalized state enterprises—absorb curtailment losses, while less-capitalized local industrial actors continue paying for their electricity at prices without competitive advantage.
The distinguishing sign between these two trajectories will be measurable before 2030. The curtailment rate in MENA countries that have deployed the most renewables is the first indicator: a high curtailment level would signal that effective substitution is compromised. The second indicator is the volume of fossil barrels actually redirected to export by states that have invested in large-scale storage: its evolution would allow assessment of the effectiveness of domestic substitution.
Two structural conditions would improve the odds of the first scenario, independent of Gulf States’ own decisions. First: condition public financing of MENA renewable projects on binding commitments regarding storage capacities installed simultaneously. Development finance institutions—the World Bank, regional development banks—have the levers to impose this condition. Without it, solar projects can deploy without the storage that makes them useful. Second: create a regional grid-sharing mechanism among MENA countries.
Pooling storage and transmission at regional scale would reduce unit cost for each country and allow less-capitalized states—Morocco, Jordan, Egypt—to benefit from the pivot without financing infrastructure alone. The geopolitics of sovereignty complicates this regional cooperation, but precedents exist for energy infrastructure sharing among countries with divergent interests.
What unfolds in the Gulf between 2025 and 2035 transcends the region. If the Emirati model works—solar coupled with storage, effective domestic substitution, barrels freed—it will become a reference for other hydrocarbon producers seeking to steer their own transition without sacrificing export revenues. If curtailment prevails, it will instead supply the argument that renewables without sufficient grid capacity are an unfulfilled promise, and that fossil dependence persists despite investment. The 6.1 billion of the Emirati project is as much an industrial test as a strategic signal.
Sources
- Middle East Energy 2026 Exhibition / Dii Desert Energy MENA Outlook 2026, MENA renewable investments 2025, 202 GW pipeline, UAE project 5.2 GW solar + 19 GWh batteries (GreenTech Lead, 2026)
- UAE Energy Strategy 2050, government of the United Arab Emirates (official publication, accessible via the UAE Ministry of Energy and Infrastructure portal)
- Dii Desert Energy, MENA Renewable Energy Outlook 2026 (full report, dii-desertenergy.com)
- IRENA, Renewable Power Generation Costs 2024 (annual report, irena.org)
- International Energy Agency (IEA), World Energy Outlook 2025 (iea.org)
