No single energy source is likely to replace natural-gas export revenue on its own. The most credible strategy is a portfolio: renewable hydrogen and derivatives such as ammonia, methanol and e-kerosene; renewable-electricity exports where cross-border transmission is practical; and critical minerals tied to domestic refining, processing and manufacturing. Green industrial products can add another layer of value.
These options differ sharply in maturity, infrastructure, geography, price risk and the share of value retained at home. Hydrogen derivatives most closely resemble liquefied natural gas (LNG) as shipborne commodities, but their trade is still small. Minerals can generate far more value after processing, yet concentrated supply chains create a different dependency. Electricity exports can be efficient, but only countries connected to durable regional markets can use them at scale.
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Why replacing gas-export revenue is harder than replacing gas energy
Natural-gas exports generate more than a fuel sale. They combine a globally traded commodity, port or pipeline infrastructure, long-term contracts, tax and royalty payments, foreign-exchange earnings, local jobs and a network of suppliers. A substitute therefore has to be evaluated on revenue, not only on whether it can produce low-carbon energy.
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1Fix the driver behind crashes, sound loss and screen glitches2Repair Windows errors before they cause bigger problems3Scan for outdated or missing drivers - takes under a minuteThree tests matter. First, can the product reach overseas buyers by ship, pipeline or interconnector? Second, can the exporting country capture processing, manufacturing and service income rather than selling an unprocessed resource? Third, can public finances withstand the new product’s construction period and price cycles?
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No published source establishes that any one substitute can match a particular country’s natural-gas receipts. Results depend on resource quality, project finance, policy, infrastructure, market access and domestic ownership. A country replacing a large gas industry may need several export lines operating at once, with transitional gas revenue funding the build-out.
The main candidates at a glance
| Candidate | How it reaches buyers | Current maturity | Main advantages | Main constraints |
|---|---|---|---|---|
| Renewable hydrogen and derivatives | Derivatives such as ammonia, methanol and e-kerosene can be shipped; hydrogen itself may require pipelines, liquefaction or specialized carriers. | Early-stage international trade. If every announced project proceeds, export-oriented projects could reach 16 million tonnes per year of hydrogen-equivalent by 2030. | Closest commodity analogue to LNG; can serve shipping, aviation, chemicals and other hard-to-abate sectors. | High-cost production, new terminals and storage, certification, uncertain demand and limited current trade. |
| Renewable electricity | High-voltage cross-border transmission and regional interconnectors. | Technically mature where grids and markets already connect. | Direct use avoids conversion losses and can support stable regional sales. | Geographically constrained; requires transmission, market rules and political reliability. |
| Critical minerals | Bulk mineral exports, refined materials, chemicals, components and manufactured products. | Established mining trade, but processing and clean-energy manufacturing capacity vary widely. | Potentially high value addition and demand from batteries, grids and renewable equipment. | Producer concentration, environmental impacts, volatile prices and governance risk. |
| Clean-energy industrial products | Exported equipment, materials and energy-intensive products made with renewable power. | Varies by product and industrial capability. | Moves value capture beyond raw resources and can create skilled jobs. | Needs reliable low-cost power, technology, capital, standards and access to buyers. |
Renewable hydrogen and its derivatives
Why hydrogen is the closest LNG analogue
Renewable hydrogen is made with electricity from renewable sources, usually by electrolyzing water. It can be used directly in chemicals, steel and some transport applications, or converted into molecules that are easier to store and ship. Ammonia is already traded globally as a fertilizer input; methanol has established chemical and shipping uses; and e-kerosene is intended for lower-carbon aviation fuel.
IRENA and the World Trade Organization said in 2024 that renewable hydrogen and hydrogen-derived commodities are expected to play an important role in the transition to low-carbon energy. Their analysis projects that renewable hydrogen and derivatives could account for up to 14% of final energy consumption by 2050. That is a long-term scenario, not a present-day market share or a guarantee of export revenue.
What the 2030 pipeline actually shows
The International Energy Agency reported in 2024 that, if all announced projects proceed, export-oriented projects could reach 16 million tonnes per year of hydrogen-equivalent by 2030—about one-third of projected low-emissions hydrogen production. “If all announced projects proceed” is important: announcements still require final investment decisions, financing, construction, buyers and operating performance.
Current international hydrogen trade remains minimal. The limiting factors are not just electrolyzer capacity. Exporters also need water and renewable generation, conversion plants, dedicated storage, port equipment, compatible ships, safety systems, carbon-intensity certification and buyers willing to sign contracts. Importing jurisdictions are still developing rules for what qualifies as renewable or low-emissions hydrogen.
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Which derivative may reach revenue first?
- Ammonia: Existing fertilizer trade and shipping practices provide a starting point, although new demand from power generation or maritime fuel still needs to scale.
- Methanol: Existing chemical markets can absorb supply, while low-emissions methanol is being considered for shipping and industrial uses.
- E-kerosene: Aviation creates a potentially valuable market, but production requires renewable hydrogen plus a carbon source and must meet fuel standards.
- Hydrogen itself: Direct exports may work where pipelines connect neighboring markets or where specialized maritime infrastructure is justified.
Derivatives improve transportability, but conversion adds capital cost and energy losses. A country should compare the value of each molecule with the renewable electricity that could instead be sold domestically or through an interconnector.
Renewable-electricity exports
When electricity is the efficient choice
Direct electricity exports avoid the conversion steps required to make hydrogen or synthetic fuels. Countries with exceptional solar, wind or hydropower resources can sell power to nearby markets through high-voltage lines, balancing services and regional electricity exchanges. Long-term contracts can provide a steadier revenue profile than spot fuel sales when market rules are credible.
The geographic limitation
Electricity cannot be shipped economically like LNG. Cross-border trade requires physical transmission capacity, compatible grid codes, dispatch coordination, congestion management and a stable regional market. A remote renewable-rich country may have excellent generation potential but no practical electricity-export route.
Transmission projects also take years to permit and build, cross multiple jurisdictions and can become politically contentious. Where an interconnector is unavailable or too small, converting power into ammonia, methanol, e-kerosene or another product may make the energy transportable by ship. Conversion, however, sacrifices efficiency and adds equipment that must be financed and certified.
Critical minerals: value comes from processing, not just mining
The case for domestic value addition
Energy-transition technologies require minerals for batteries, electric grids, wind turbines and other equipment. Mining can create export income, but refining, chemical conversion, precursor production, component manufacturing and recycling generally retain more value and create a broader industrial base.
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A UN Trade and Development article published in 2025, using 2022 data, illustrated the difference with cobalt: processed cobalt exports were valued at $6 billion, compared with $167 million for unprocessed cobalt exports. That comparison demonstrates the potential of value addition; it does not prove that every country can reproduce those results or replace gas receipts with cobalt.
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The concentration and dependency risk
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. Concentration can expose an exporter to buyer pressure, supply disruptions and sudden price changes—risks that may resemble fossil-fuel dependence in a different form.
A mineral strategy therefore needs transparent contracts, competitive licensing, environmental safeguards, revenue-management rules, recycling and domestic technical capability. Governments should avoid replacing one single-commodity dependency with another. Processing plants also require dependable electricity, water, transport and skilled labor; without those inputs, ore may still leave the country with little additional value captured locally.
Clean-energy industries as a fourth revenue layer
Green hydrogen, green ammonia and green methanol can be exported as commodities, but renewable power can also support domestic industries that sell finished or semi-finished goods. Examples include processed mineral chemicals, battery materials, low-emissions metals and equipment used in renewable-energy systems.
IMF analysis identifies green hydrogen, green ammonia and methanol, and clean-energy industries as diversification options while warning that hydrogen should be treated as one part of a broader strategy. Industrial exports can create more jobs and supplier activity than raw energy sales, but they expose the country to technology competition, product standards and changing trade policy. Reliable power prices and predictable regulation are prerequisites.
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How the options compare on the decisions that affect revenue
| Decision factor | Hydrogen derivatives | Electricity exports | Processed minerals | Clean-energy industries |
|---|---|---|---|---|
| Exportability | Shipborne molecules are possible; infrastructure is still developing. | Efficient only across practical interconnectors. | Highly transportable in bulk, with additional value from refining. | Products are shipped through existing logistics, but specifications vary. |
| Technology maturity | Production technology exists; international trade systems are early-stage. | Mature where regional grids are integrated. | Mining is mature; advanced refining and manufacturing are uneven. | Depends on the product, industrial base and technology access. |
| Certification need | High: buyers need proof of emissions intensity and production origin. | Grid accounting and guarantees of origin may be required. | Traceability and environmental standards increasingly affect market access. | Product and carbon standards can determine eligibility. |
| Speed to revenue | Potentially slower because projects need coordinated infrastructure and buyers. | Faster where spare interconnector capacity already exists. | Mining can begin sooner than complex refining, but permitting and construction remain material. | Usually follows investment in power, plants, skills and customer qualification. |
| Price volatility | Future markets and policy support are uncertain; no source establishes a stable benchmark. | Depends on regional prices, congestion and weather. | Commodity prices can swing sharply and affect royalties. | Margins depend on technology costs, global competition and trade rules. |
| Domestic value capture | Electrolyzers, conversion plants, ports and services can be localized. | Mostly power-generation and transmission income unless paired with industry. | Potentially high when refining, chemicals and manufacturing are domestic. | Potentially high, but requires skills, capital and intellectual property. |
| Resource pressures | Requires renewable land and water plus substantial electricity. | Requires generation sites and transmission corridors. | Requires land, water, energy and environmental management at mine and plant sites. | Requires industrial land, power, water and logistics. |
| Geopolitical exposure | Depends on importing-country standards, shipping routes and equipment supply. | High dependence on neighboring grid partners. | High where production or refining is concentrated among a few countries. | Exposed to technology suppliers, trade measures and customer concentration. |
A practical portfolio sequence for an exporting country
1. Measure the revenue gap
Separate gas income into government royalties and taxes, company profits, foreign-exchange earnings, wages and supplier purchases. A replacement that raises export value but lowers public receipts may not solve a budget problem. Conversely, a project with modest royalties may still diversify jobs and the balance of payments.
2. Match each resource to its nearest market
Map renewable-resource quality, water availability, ports, pipelines, transmission corridors and neighboring demand. Electricity should be prioritized where interconnection is realistic. Shipborne derivatives make more sense for remote resources, provided ports, certification and buyers can be secured.
3. Secure an anchor customer before building
Large hydrogen, mineral-processing and industrial projects need contracts, not only memoranda of understanding. Buyers should specify product standards, emissions accounting, delivery terms and adjustment clauses. Public support should be tied to milestones such as financing, construction and verified production.
4. Build domestic processing in stages
Start with capabilities that the country can operate reliably—such as mineral concentration, refining, chemical conversion, equipment maintenance or port services—then move toward more complex manufacturing. Local-content targets that cannot be met may delay projects; skills training and supplier development should precede them.
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Resource revenues should be governed by transparent contracts, fiscal rules and stabilization mechanisms. Conservative price assumptions are essential because neither future hydrogen prices nor mineral prices are established as a guaranteed replacement for gas receipts. Public borrowing should be matched to projects with credible offtake and cash-flow plans.
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6. Diversify buyers, technologies and ownership
Multiple customers reduce bargaining risk. Recycling and substitution reduce exposure to minerals whose production is concentrated. Domestic or diversified ownership can keep more profits at home, but governments must still publish beneficial ownership, tax terms and environmental obligations to maintain public trust.
What can derail a replacement strategy?
- Announced capacity mistaken for operating capacity: Hydrogen project announcements may never reach final investment decision or production.
- Missing certification: A molecule sold as renewable may be excluded from a buyer’s market if emissions accounting rules differ.
- Infrastructure built before demand: Ports, pipelines and transmission lines can become stranded assets without firm customers.
- Raw-material dependence: Mineral exports without refining leave much of the potential value abroad.
- Local bottlenecks: Water, land, permitting, grid connection and skilled labor can delay otherwise well-funded projects.
- Fiscal overconfidence: Treating a long-term scenario—such as hydrogen reaching up to 14% of final energy consumption by 2050—as a near-term budget forecast creates a gap if adoption is slower.
- Concentration replacing concentration: Depending on one mineral, one buyer or one technology recreates the vulnerability that gas diversification is meant to reduce.
Which countries are best positioned?
There is no universal winner. A renewable-rich country near major demand centers may combine electricity exports with hydrogen derivatives. A country with deposits and existing chemical or metallurgical expertise may capture more value through refining and manufacturing. A country with a remote coastline and abundant renewable power may favor shipborne ammonia or methanol, while one surrounded by integrated grids may earn revenue sooner from electricity.
The strongest position combines several advantages: low-cost renewable generation, usable water supplies, ports or interconnectors, transparent regulation, access to finance, credible certification and a workforce able to operate industrial facilities. Lacking any one of these does not make diversification impossible, but it changes the product mix and the time required to earn revenue.
Bottom line for public and household finances
Renewable hydrogen derivatives are the closest replacement for LNG as an internationally traded energy commodity, but they are not yet a mature or guaranteed revenue stream. Renewable electricity can be efficient and relatively direct where transmission and regional markets exist. Critical minerals offer large value-addition opportunities only when countries move beyond ore exports, and their concentrated supply chains create substantial governance and price risks.
The financially safer approach is staged diversification: use existing energy income to develop projects with real buyers, add domestic processing and manufacturing, publish the fiscal terms, and spread risk across molecules, electricity, minerals and industrial goods. That portfolio approach is more resilient than betting a national budget on a single hydrogen forecast or mineral boom.
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