China is building the world's only large-scale coal-to-gas (CTG) industry as a strategic buffer against energy supply shocks, with no other country having developed synthetic gas from coal at any meaningful scale. The United States once operated a single commercial facility — the Great Plains Synfuels Plant in North Dakota — but abundant shale gas and environmental concerns deterred further build-out, leaving China alone in pursuing the technology at gigawatt scale. According to Rystad Energy, China's CTG capacity is on track to reach 9.4 billion cubic meters (Bcm) per year by the end of 2026 and grow to 28 Bcm per year by 2030 — equivalent to more than four times Austria's entire annual gas demand, though still a modest share of China's own gas consumption, which exceeded 390 Bcm in 2023.

The country's 15th Five-Year Plan, covering 2026 to 2030, strengthens CTG's role in its domestic supply architecture, signaling a shift from deliberation to active execution. The plan aligns with Beijing's broader push to reduce exposure to imported fuel after global LNG prices spiked to record highs in 2022 following Russia's invasion of Ukraine, a shock that reinforced the strategic case for domestically producible alternatives.

China's coal-to-gas program is a direct expression of its energy security doctrine. In a world where LNG supply chains and pipeline routes are increasingly affected by geopolitics, China is investing in molecules it can produce, store and move without reference to any foreign supplier.

— Wei Xiong, Vice President, Gas & LNG Markets, Rystad Energy

Xinjiang Emerges as CTG Hub

China's Xinjiang province has become the undisputed center for CTG expansion, driven by mine-mouth coal prices that averaged just 214 yuan, or approximately $30 per tonne, between April 2025 and May 2026 — less than 40% of the equivalent price in Inner Mongolia. This cost advantage translates directly into delivered gas prices: Xinjiang-produced CTG reaches East China at $9.1–$9.6 per million British thermal units (MMBtu), generally below China's average liquefied natural gas (LNG) import price.

Existing CTG plants are operating at over 90% utilization, reflecting both strong demand and the cost competitiveness of domestically produced synthetic gas compared to imported alternatives. Approximately 20 Bcm per year of CTG capacity is currently under development, with the majority located in Xinjiang. Project approval timelines in the region have compressed dramatically, from three years or more to under 12 months in several recent cases.

Balancing Energy Security with Environmental Requirements

The Chinese government is working to support CTG development for energy security purposes while simultaneously imposing project-specific carbon and environmental requirements. This dual-track approach reflects a tension at the heart of Beijing's climate policy: China has pledged to peak carbon emissions before 2030 and achieve carbon neutrality by 2060, yet coal gasification is inherently more carbon-intensive than burning natural gas directly, placing CTG expansion in direct tension with those commitments. New projects are adapting to these conditions. The CHN Energy Zhundong development, for example, is a 2 Bcm per year facility scheduled to begin gas production in 2027. It has been designed with electrolytic hydrogen integration, wastewater recycling, and 550,000 tonnes per year of planned carbon capture capacity.

China already has a well-established market for utilization-based carbon capture projects with practical end-use applications, though the market for permanent storage-based carbon capture remains limited.

If the economics of decarbonized CTG will prove bankable over the long term remains an open question, but for now the global security imperative is diminishing hesitation.

— Eryu Wang, Carbon Capture, Utilization and Storage (CCUS) Analyst, Rystad Energy

Remaining Challenges

Water availability, environmental compliance, and carbon emissions continue to pose real headwinds. China has not yet established a uniform nationwide decarbonization standard for new CTG projects. Some integrated facilities require substantial upfront capital and may intensify water pressures in northwestern China, particularly because reported water consumption applies to the entire CTG complex rather than carbon capture operations alone. Additionally, if captured CO2 is destined for geological storage within China, the commercial viability of carbon capture could face further limitations.

Implications for Global LNG Markets

As CTG capacity expands despite these challenges, the impact on China's LNG demand — and consequently on global LNG prices and long-term supply contracting — will become increasingly significant for producers from Australia to Qatar to the United States. China was the world's largest LNG importer in 2023, and even a single-digit percentage reduction in import growth from domestic substitution could shift the supply-demand balance that underpins long-term LNG contracting decisions and terminal investment timelines worldwide.

CTG is one of China's many hedges against a world where LNG supply is finite and politically sensitive. At 28 Bcm per year by 2030 it remains a supplemental source, not a replacement for imports, but its steady growth means every LNG exporter targeting China should model it as a structural dampener on demand, not a footnote.

— Wei Xiong, Vice President, Gas & LNG Markets, Rystad Energy

Source: Rystad Energy via OilPrice.com