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No single energy source can reliably replace natural-gas export revenue. The most credible approach is a portfolio: renewable hydrogen and derivatives such as ammonia, methanol and e-kerosene; renewable electricity traded through functioning interconnectors; and critical minerals backed by domestic refining and manufacturing. Each can create export income, but none is a proven one-for-one substitute for a particular country’s gas receipts.
The practical question is therefore not which fuel replaces gas, but which combination can reproduce fiscal income, foreign exchange and industrial activity while limiting new dependencies.
Why replacing gas revenue is harder than replacing gas energy
Natural-gas exports generate several income streams at once: sales by producers, royalties and taxes for the state, dividends from national companies, port and pipeline fees, and foreign currency for the wider economy. A replacement must be judged against all of those functions, not merely against the amount of energy delivered to a customer.
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No published source establishes that any candidate will match a named country’s natural-gas receipts. Outcomes depend on the quality and cost of the resource, project finance, policy stability, access to buyers, infrastructure and the share owned domestically.
1. Renewable hydrogen and its derivatives
Why hydrogen is the closest commodity analogue
Renewable hydrogen is made by splitting water with electricity generated from renewable sources. It can be sold directly or converted into products that are easier to handle and have established industrial uses. The main derivatives identified by the International Renewable Energy Agency (IRENA) and the World Trade Organization (WTO) are ammonia, methanol and e-kerosene. Their 2024 analysis says renewable hydrogen and hydrogen-derived commodities are expected to play an important role in the transition to low-carbon energy and projects that they could account for up to 14% of final energy consumption by 2050.
Ammonia already moves through global fertilizer markets and can also serve as a hydrogen carrier or marine fuel. Methanol is a chemical feedstock and can be used in shipping and synthetic-fuel pathways. E-kerosene targets aviation, where direct electrification is difficult. These products give a renewable-rich country several outlets instead of forcing every project to sell pure hydrogen.
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- Large, low-cost renewable generation with enough operating hours to keep electrolyzers productive.
- Electrolyzers, water-treatment equipment, compression and storage.
- Conversion plants for ammonia, methanol or synthetic aviation fuel when a derivative is more economical to transport.
- Port facilities, specialized tanks, loading systems and safety procedures for export.
- Certification that proves the electricity source, emissions intensity, water accounting and chain of custody accepted by the destination market.
- Long-term offtake contracts or demand aggregation so lenders can finance projects.
Why revenue is not immediate
Hydrogen trade remains at an early stage. The International Energy Agency (IEA) reported in 2024 that, if every announced project proceeds, export-oriented projects could reach 16 million tonnes per year of hydrogen equivalent by 2030—about one-third of projected low-emissions hydrogen production. That figure is a pipeline scenario, not committed output. Current international trade is minimal, and infrastructure, certification and the coordination of multiple buyers remain material constraints.
Projects can therefore spend years in permitting and construction before producing export income. A government that budgets future royalties as though all announced capacity will be built risks repeating the volatility of a commodity boom.
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2. Renewable-electricity exports
When electrons are the best export
Cross-border electricity can be efficient because it avoids the conversion losses and equipment required to turn power into a molecule. A country with abundant wind, solar or hydropower next to a stable regional market may sell through a high-voltage interconnector, bilateral power-purchase agreement or regional electricity exchange.
This model works only when geography and institutions line up. Interconnectors require coordinated grid planning, permits in several jurisdictions, congestion rules, settlement systems and agreement on balancing responsibility. Buyers also need confidence that the exporting grid can deliver during the hours specified in a contract.
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Electricity cannot be economically shipped across oceans in the same way as LNG. A remote renewable resource without a nearby buyer or transmission corridor will usually need to be converted into hydrogen derivatives or used in domestic industry. Seasonal output, curtailment and weather variability must be managed with storage, firm generation, flexible demand or contracts that explicitly define delivery risk.
Electricity exports can provide earlier revenue than a new hydrogen economy when an interconnector already exists or is under construction. Where no such link is feasible, they are a long-term infrastructure project rather than a quick substitute.
3. Critical minerals and mineral-based industry
Why minerals belong in a revenue strategy
Critical minerals are not an energy source, but they can replace part of the export value and industrial activity formerly associated with gas. Copper, lithium, cobalt, graphite and rare earths are used in power networks, batteries, electric vehicles and renewable-energy equipment. As UN Secretary-General António Guterres put it, “A world powered by renewables is a world hungry for critical minerals.”
Processing determines how much value stays home
Mining and exporting ore is the lowest-value part of the chain. A UN Trade and Development article published in 2025, using 2022 trade data, reported $6 billion in processed cobalt exports compared with $167 million in unprocessed cobalt exports. The comparison illustrates the value of refining and processing; it does not guarantee that every country can reproduce those figures or that processing will be profitable at local scale.
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Higher-value strategies include concentrating and refining ore, producing precursor chemicals or cathode materials, fabricating components, and supplying equipment and services to the clean-energy industry. Each additional step requires reliable power, water, technical skills, environmental controls, finance and access to customers.
The concentration problem
Minerals can replace one dependency with another. The IEA reported in 2025 that the average share held by the top three producers of copper, lithium, cobalt, graphite and rare earths reached 86% in 2024, up from about 82% in 2020. A new exporter that relies on one mineral or one foreign refinery remains exposed to price shocks, export controls and geopolitical pressure.
Governments should diversify products and buyers, publish contracts, require credible environmental and labor standards, and invest in recycling. Domestic capability matters, but forcing uneconomic processing through quotas can destroy value; projects need transparent tests of power cost, logistics and market demand.
How the main options compare
| Option | Export form | Technology and trade maturity | Infrastructure and certification | Domestic value capture | Main constraints | Likely speed to material revenue |
|---|---|---|---|---|---|---|
| Renewable hydrogen | Shipborne molecule or pipeline where geography permits | Commercial equipment exists, but international trade is early-stage | Renewable power, electrolyzers, water systems, storage, ports and emissions certification | High if production and conversion equipment are built locally | High capital cost, uncertain demand, water and land needs, certification differences | Medium to long term |
| Ammonia, methanol and e-kerosene | Shipborne derivatives with existing or adapted chemical logistics | Industrial markets exist; renewable pathways are scaling | Conversion plants, feedstock, ports, safety systems and buyer-specific standards | High when conversion and downstream chemicals remain domestic | Electricity cost, competing fossil-based products, policy and fuel standards | Medium to long term |
| Renewable electricity | High-voltage interconnector | Mature generation; cross-border trade depends on regional systems | Interconnectors, grid balancing, market rules and firm-delivery contracts | Moderate to high through generation and grid services | Geographic limits, congestion, permitting and weather variability | Shorter where interconnection already exists; otherwise long term |
| Critical minerals | Ore, concentrate, refined material or manufactured component | Mining is established; refining and advanced manufacturing vary by mineral | Mines, processing plants, power, water, transport, environmental permits and traceability | Low for ore exports; potentially high for refining and manufacturing | Resource depletion, price cycles, environmental impacts and producer concentration | Short to medium term for existing mines; longer for integrated chains |
The table compares structural characteristics, not guaranteed returns. “Short” or “medium” describes the time needed to reach material revenue relative to building an entirely new export system; no source provides a universal timetable.
A portfolio approach is safer than a hydrogen-only bet
IMF analysis identifies green hydrogen, green ammonia and methanol, and clean-energy industries as diversification options while warning governments to treat hydrogen as one part of a broader strategy. A balanced portfolio can combine assets with different failure modes:
- Near-term cash flow: expand renewable generation for domestic industry and pursue electricity sales where an interconnector and regional market already exist.
- Medium-term molecules: develop ammonia, methanol or other derivatives next to the best renewable resources, using staged projects tied to signed offtake.
- Industrial depth: refine minerals and manufacture selected clean-energy inputs instead of exporting only ore.
- Long-term resilience: build technical services, equipment maintenance, recycling and energy-efficiency businesses that earn revenue even when commodity prices fall.
Portfolio design should avoid counting the same renewable power twice. Electricity committed to an interconnector cannot also feed an electrolyzer or a domestic refinery unless additional generation is built. Resource, grid and water plans must therefore be integrated before export contracts are signed.
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Step 1: Establish the gas baseline
Measure annual export sales, taxes, royalties, national-company dividends, foreign-exchange contribution, local jobs and public spending funded by gas. Separate recurring income from one-time signing bonuses and temporary price gains. This prevents a new sector with high sales but low public revenue from being mistaken for a replacement.
Step 2: Map the physical advantage
For hydrogen, assess renewable-quality profiles, water availability, electrolyzer load factors, port access and distance to buyers. For electricity, identify neighboring systems, interconnector routes and seasonal complementarity. For minerals, quantify reserves, ore quality, power and water requirements, transport costs and feasible processing stages.
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Step 3: Secure market access before construction
Require credible buyers, bankable contracts and clear product specifications. Hydrogen derivatives need agreement on emissions accounting and certification. Electricity projects need transmission rights and balancing rules. Mineral projects need transparent sales terms and more than one potential buyer where possible.
Step 4: Set domestic-value requirements that can be met
Use competitive incentives for refining, component manufacturing, local engineering and workforce training. Publish contracts and fiscal terms. Independent audits should verify production volumes, emissions, water use and the share of value retained domestically.
Step 5: Protect the public budget
Base spending on conservative price and volume assumptions. Save windfall income in a stabilization mechanism, cap exposure to one commodity and publish stress tests for low prices, delayed projects and exchange-rate changes. Gas revenue should be replaced gradually as new sectors demonstrate dependable cash flow.
Environmental, social and geopolitical safeguards
Renewable projects require land, transmission corridors and often substantial water infrastructure. Electrolysis can compete with communities or ecosystems for water if projects are placed in arid regions. Mining and refining can create pollution, tailings and labor risks. Environmental approvals, water accounting, rehabilitation bonds and community benefit agreements are economic safeguards as well as ethical requirements: a delayed or canceled project cannot provide dependable export revenue.
Concentration deserves the same attention as emissions. A country that exports one mineral to one dominant buyer, or one derivative through one port, has recreated a single-point failure. Diversified customers, strategic inventories, recycling and regional processing partnerships reduce that exposure.
Which countries are best positioned?
Renewable-electricity exporters need nearby markets and political agreement on grids. Hydrogen and derivative exporters need exceptional renewable resources, water solutions, ports and buyers willing to pay for certified low-emissions products. Mineral exporters need deposits plus reliable power, transport, governance and the ability to move beyond ore.
Countries lacking one of these advantages should not imitate a neighbor’s model. They may earn more by supplying equipment, engineering, processing services or recycled materials to a regional value chain than by building an uneconomic export terminal.
What success should be measured against
A credible replacement program tracks more than export tonnage. Useful indicators include net public revenue per unit of resource, domestic value added, number and diversity of buyers, project completion rates, local employment, emissions intensity, water use, recycling rates and the share of foreign inputs. Comparing those indicators with the gas baseline reveals whether diversification is actually improving fiscal resilience.
The central test is durability: can the sector continue paying taxes, wages and suppliers through a low-price year, a delayed project and a geopolitical disruption? If not, it is an additional export opportunity, not yet a replacement for gas revenue.
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