China’s National Development and Reform Commission (NDRC) and National Energy Administration (NEA) have recently issued the “15th Five-Year Plan for Coal Industry Development,” setting new rules for mine approvals, capacity allocation and consolidation, cross-regional transportation and reserve mechanisms. The plan is expected to reshape China’s physical and futures coal markets over the next five years.
The plan significantly raises the threshold for new coal mines, limiting future supply elasticity. Shanxi, Inner Mongolia, Shaanxi and Xinjiang outside southern Xinjiang will no longer approve mines below 1.2 Mt/year, while the thresholds are 0.6 Mt/year in Ningxia and 0.3 Mt/year elsewhere. The minimum size for new high-hazard mines will rise to 0.9 Mt/year, with restrictions also placed on small mines operating at depths below 1,000 meters. All new capacity must be included in a national capacity register and fully backed by capacity replacement, while replacement capacity can only be developed in the five major coal bases, leaving little room for expansion in smaller mining regions.
Existing capacity will also face further consolidation. Resource-depleted and high-risk mines in central and eastern China will gradually exit, while smaller mines with weaker safety standards in the southwest and northeast will be phased out faster. Production will consequently become more concentrated in large-scale mines, with large modern mines targeted to account for 87% of national capacity by 2030.
The five major supply bases—Shanxi, western Inner Mongolia, eastern Inner Mongolia, northern Shaanxi and Xinjiang—are expected to account for more than 80% of national coal output by 2030. Most incremental production will come from western Inner Mongolia and Xinjiang, while Shanxi output remains broadly stable and mining intensity in central and eastern regions is tightly controlled.
Transport infrastructure will be expanded accordingly. Southeastern coastal provinces will rely on coal from Shanxi, Shaanxi and western Inner Mongolia alongside imports; the Hunan-Hubei-Jiangxi region will receive more coal via the Haoji and Jiaoliu railways; eastern Inner Mongolia will mainly supply the northeast, while southwest China will gradually increase inflows of Xinjiang coal. Changes in transport capacity will therefore remain an important driver of regional price differentials.
To curb sharp price swings during peak seasons, the plan calls for more than 100 Mt/year of reserve coal capacity by 2030, supplemented by inventories at power plants and producing regions. Reserve capacity can be released during summer and winter peak-demand periods, while stronger oversight of medium- and long-term thermal coal contracts and price-range regulation should limit extreme price spikes.
On the demand side, coal consumption is targeted to peak by 2030 and then enter a high-level plateau. Incremental demand will mainly come from power generation and coal-to-liquids/gas projects, while loose coal consumption and demand for lower-quality coal will continue to decline. High-quality thermal coal and coking coal are expected to retain structural premiums. Meanwhile, coalbed methane production is targeted at 26 Bcm by 2030, potentially marginally reducing industrial coal demand.
Overall, China’s coal market is moving toward a stock-based competitive phase, characterized by tighter supply growth and greater production concentration. Trading opportunities are likely to focus increasingly on high-quality coal from the five major production bases, with capacity releases, Xinjiang coal shipments and reserve deployment remaining key factors to watch.
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