Synthetic Natural Gas Market Size & Share Analysis - Growth Trends and Forecast (2027 - 2032)

Market Trends and Insights

Energy Security Mandates and Coal-to-Gas Expansion in Asia

China’s 15th Five-Year Plan for 2026 to 2030 places coal-to-gas within active industrial policy as the country seeks to reduce dependence on imported natural gas. The National Development and Reform Commission approved the Zhundong project in March 2025 for 2 billion cubic meters (bcm) per year of synthetic natural gas output using pressurized coal gasification in Xinjiang.^[1] Changji projects then received environmental approvals in July 2025 for 4 bcm per year of combined capacity, with green hydrogen coupling and carbon capture and storage included in the project designs.^[2] These projects create direct demand for gasification equipment, methanation catalysts, carbon-management systems, and related engineering services. The synthetic natural gas market benefits because project approvals convert an energy-security objective into a defined construction pipeline. The inclusion of hydrogen and carbon capture also indicates that developers are preparing coal-based assets for tighter future emissions requirements.

Pipeline-Injection Policy and Grid-Compatible Synthetic Natural Gas (SNG) Infrastructure

Japan’s Seventh Strategic Energy Plan set a 1% target for e-methane and biogas injection into pipelines by fiscal year 2030.^[3] The plan allows higher costs to be recovered through network tariffs, which gives utilities a route to introduce lower-carbon gas without requiring end users to replace equipment. Japan’s methanation council confirmed in June 2025 that the policy direction supports gas-sector coordination around this target. In Europe, the Renewable Energy Directive III (RED III) requires member states to create the regulatory conditions for renewable fuels and biomethane access, while its transport provisions set a 5.5% combined target for advanced biofuels and renewable fuels of non-biological origin by 2030.^[4] These rules favor grid-compatible gas because it can use existing pipelines, storage, and industrial connections. The synthetic natural gas market also gains from certification systems such as SURE, which support traceability and sustainability compliance for gaseous fuels across national markets.

Transportation Demand for CNG, LNG, and RNG Heavy-Duty Fleets

The 2025 launch of Cummins’ X15N natural gas engine broadened heavy-duty fleet options across Freightliner, Kenworth, and Peterbilt truck platforms. This provides an equipment base that can use renewable natural gas where fueling infrastructure is available. North American producers are increasingly directing renewable gas to transport applications, reinforcing demand for upgrading plants and fuel supply agreements. In Germany, bio-LNG represented 98% of LNG dispensed at fueling stations in the first half of 2025, showing the scale of renewable gas use within that fuel channel. Transportation and mobility therefore links gas production, upgrading, distribution, and vehicle deployment in a single commercial chain. The synthetic natural gas market benefits when fleet adoption raises the value of renewable gas certificates and encourages new feedstock investment.

Biological and Catalytic Methanation Technology Scale-Up

Catalytic methanation remains the most established route because it has been used in large gasification projects and legacy synthetic gas plants. Research published in 2026 by Johnson Matthey Technology Review examined single-atom alloy catalysts for carbon dioxide methanation and reported gains in activity and selectivity. Honeywell completed its acquisition of Johnson Matthey’s Catalyst Technologies business in July 2026, adding the KATALCO portfolio to its process technologies and automation offering. Biological methanation has a smaller installed base but can support projects that combine biogenic carbon dioxide and renewable hydrogen. Hitachi acquired Electrochaea’s worldwide biomethanation patent portfolio in August 2026 after the company’s insolvency, keeping the technology within a larger industrial group. The synthetic natural gas market may therefore see technology ownership consolidate around companies with the engineering capacity and capital needed for full-scale deployment.

High E-Methane Production Costs from Green Hydrogen

E-methane costs remain tied closely to renewable electricity and electrolyzer economics because hydrogen represents a major input. A 2025 peer-reviewed techno-economic study reported levelized substitute natural gas costs of EUR 304 to EUR 376 per megawatt-hour for power-to-gas configurations. This cost position is above conventional gas prices in many markets, so projects need policy support, carbon pricing, contracted offtake, or low-cost electricity. Siemens Energy is expanding electrolyzer manufacturing capacity in Berlin, which may support lower equipment costs as deployments increase. Even so, developers must manage the cost and availability of electricity, carbon dioxide, hydrogen, and financing at the same time. The synthetic natural gas market is likely to see e-methane projects advance first where several of these conditions are available together.

Regulatory Fragmentation and Permitting Complexity Limiting Synthetic Natural Gas (SNG) Scale-Up

Renewable-gas policy is advancing, but implementation differs sharply between countries and jurisdictions. The European Commission began infringement proceedings against 26 of 27 European Union member states that had not transposed the Renewable Energy Directive III (RED III) by the May 2025 deadline. This uneven rollout can delay rules on certification, grid access, and support mechanisms that projects need before financing can close. Producers also face permitting requirements for renewable power, gas upgrading, pipeline interconnection, and carbon dioxide handling. In the United States, proposed measures for renewable natural gas transport support were still subject to the legislative process during 2025, leaving developers to rely mainly on existing incentive programs. The synthetic natural gas market faces slower project conversion when regulations are incomplete or when infrastructure approvals move on different timelines.

*Our forecasts treat driver/restraint impacts as directional, not additive. The impact forecasts reflect baseline growth, mix effects, and variable interactions.

Synthetic Natural Gas Market Segment Analysis

Catalytic methanation accounted for 57.3% of synthetic natural gas market share in 2026. The technology is widely used at the final conversion stage of coal-to-gas systems and benefits from established reactors, catalyst, and operating knowledge. Dakota Gasification’s Great Plains Synfuels Plant processes 18,000 metric tons of lignite per day and produces 170 million standard cubic feet of synthetic natural gas daily. This operating base gives catalytic solutions a practical advantage where projects need reliable large-volume conversion. Catalyst suppliers can also adapt established offerings for carbon dioxide methanation in renewable-gas projects.

Biological methanation is forecast to grow at a 23.2% CAGR through 2032, the fastest rate among production technologies. The pathway uses microorganisms to convert hydrogen and carbon dioxide to methane, which can fit projects built around biogenic carbon dioxide. Hitachi’s 2026 purchase of Electrochaea’s patents preserved access to the underlying technology after the developer entered insolvency. A 2025 study in Industrial & Engineering Chemistry Research evaluated power-to-gas methanation using a nickel-based catalyst, showing continued work on integrated conversion systems. The synthetic natural gas industry may see biological technology progress through partnerships with larger equipment suppliers and utilities rather than through independent specialist developers.

Coal-based feedstock held 42.7% of synthetic natural gas market revenue in 2026. Its position reflects active coal gasification capacity in China and the continuing role of Sasol’s Secunda operations in South Africa. Sasol confirmed in November 2025 that it plans to supply methane-rich gas from Secunda to external industrial customers from July 2028 through June 2030. Coal-based projects can offer security of supply where local resources and pipeline demand are aligned. However, carbon capture, hydrogen integration, and environmental approval requirements are becoming more important to their long-term viability.

Renewable hydrogen and captured carbon dioxide are forecast to grow at a 25.7% CAGR through 2032, giving it the highest feedstock growth rate. KBR received a front-end engineering and design contract in August 2026 for the Live Oak project in Nebraska, which targets 250 MW of electrolysis and 75,000 tonnes per year of e-methane for export to Japan. The project plans to use biogenic carbon dioxide from ethanol plants, which can reduce reliance on direct air capture. VERBIO produced 1,410 GWh of biomethane in fiscal year 2025/26 as its North American and European assets expanded. These examples show how agricultural, ethanol, and waste-based supply chains can provide inputs for the synthetic natural gas market.

Transportation and mobility accounted for 25.4% revenue share in 2026 and is forecast to expand at a 22.4% CAGR through 2032. The segment uses renewable natural gas, bio-liquefied natural gas (bio-LNG), and synthetic methane in heavy-duty road transport and, increasingly, in maritime fuel pathways. Cummins introduced the X15N natural gas engine in 2025 for Class 8 trucks, allowing fleets to choose a new engine designed for natural gas fuel. Fuel suppliers and station operators can build existing liquefied natural gas (LNG) and compressed natural gas (CNG) systems rather than create a wholly separate distribution network. European transport rules and renewable-fuel targets also support demand for lower-carbon gaseous fuels.

Power and utilities use synthetic gas for grid balancing and seasonal energy storage, especially where variable renewable electricity is increasing. Chemicals and petrochemicals use gas as a feedstock for products such as ammonia and methanol, which makes secure supply commercially important. BASF and Equinor signed a 10-year gas supply agreement in July 2025 for up to 23 TWh per year beginning in October 2025. Oil and gas, manufacturing, and commercial users can also use grid-injected biomethane without replacing all end-use equipment. These diverse uses reduce the synthetic natural gas market’s dependence on a single demand channel.

Geography Analysis

North America

North America held 31.3% of synthetic natural gas market share in 2026. The region has an established renewable natural gas ecosystem supported by landfill, agricultural, and waste feedstocks, together with transport fuel demand and pipeline connections. The American Biogas Council reported USD 2.1 billion in U.S. biogas investment during 2025 and 70 newly commissioned facilities. Dakota Gasification Company’s Great Plains facility continues to demonstrate the role of large-scale coal-based synthetic gas and carbon dioxide management in the region. The Live Oak development in Nebraska introduces an export-focused e-methane model that combines electrolytic hydrogen with biogenic carbon dioxide for Japanese customers. Low Carbon Fuel Standard programs and related clean-fuel rules continue to shape the economics of renewable gas used in transportation. These factors support a broad project base across production, upgrading, transport, and export.

Asia-Pacific

Asia-Pacific is forecast to grow at a 22.8% CAGR through 2032. China’s coal-to-gas program is a central source of regional volume, with recent approvals in Xinjiang covering projects that include carbon capture and green hydrogen integration. Local feedstock availability and the objective of reducing import exposure support project development in China. Japan follows a different route, focused on e-methane and biomethane injection into existing city-gas systems. The Seventh Strategic Energy Plan gives this effort a policy basis through its fiscal year 2030 injection objective. Hitachi’s acquisition of bio methanation intellectual property provides a domestic industrial platform for future deployment. Regulatory influence from METI and gas-network tariff mechanisms may help Japan turn early demonstrations into utility-led projects.

Europe, South America, and the Middle East and Africa

Europe’s synthetic natural gas market is shaped by renewable-gas targets, infrastructure standards, and the need to turn policy into operating projects. Renewable Energy Directive III (RED III) provides the wider renewable-fuel framework, while certification systems such as Sustainable and Renewable Energy (SURE) influence how gaseous fuels demonstrate sustainability compliance. EnviTec reached its 100th EnviThan gas-upgrading facility in 2025 and is investing in biomethane expansion, which illustrates continued activity in the region’s production base. Technip Energies received engineering contracts for the Ecoplanta waste-to-methanol project in Spain during 2025, reinforcing the role of waste conversion technology in Europe’s synthetic-fuel ecosystem. South America offers agricultural residues, and energy diversification needs that can support biomethane development. In the Middle East and Africa, industrial gas demand and established LNG infrastructure remain important, while Sasol’s planned methane-rich gas supply offers a temporary bridge for South African industrial customers. The synthetic natural gas market across these regions does not follow one development path, but each can create demand for feedstock conversion, gas treatment, and carbon-management capability.