- Bituminous coal drives growth despite longer-term renewable energy transition
- Elevated LNG prices improve coal’s competitiveness
South Korea’s coal imports rose sharply in July 2026 as peak summer electricity demand strengthened requirements for thermal fuels, highlighting how coal remains an important source of system flexibility even as the country gradually shifts its generation mix towards nuclear, gas and renewables.
Total coal-product imports reached 12.54 mnt in July, up 22% from 10.24 mnt in June. The increase was overwhelmingly driven by bituminous coal, imports of which jumped 27% m-o-m to 12.04 mnt.
The July increase also reinforced a much stronger year-to-date trend. South Korea imported 70.2 mnt of coal products during January-July 2026, up 19% from 58.9 mnt in the corresponding period last year.
Bituminous coal dominates import recovery
The composition of imports is particularly significant.
Bituminous coal accounted for approximately 96% of South Korea’s July coal-product imports, rising by around 2.55 mnt from June.
During January-July, bituminous imports increased by more than 11.3 mnt y-o-y to 66.3 mnt, effectively explaining the entire increase in South Korea’s aggregate coal imports.
This contrasts sharply with anthracite, where imports declined 24% y-o-y to 1.82 mnt, while petcoke imports fell 12% to 0.28 mnt.
The data therefore do not point towards indiscriminate growth across coal products. Instead, South Korea has increased its reliance specifically on bituminous coal, a category encompassing the country’s principal thermal and metallurgical coal requirements.
Summer power demand brings thermal coal back into focus
The July import surge coincided with strong summer electricity requirements.
South Korea’s thermal coal arrivals were estimated at around 8.54 mnt in July, a multi-month high, as utilities across North Asia increased purchases to meet peak summer electricity demand. Regional thermal coal economics were also supported by elevated LNG prices, improving coal’s competitiveness as a power-generation fuel.
Korea Power Exchange data confirm the scale of the summer power requirement. On 28 July, electricity demand was around 87.8 GW at 20:55, while available generating capacity stood at 106.6 GW.
Coal remained heavily utilised during this period. KPX data show coal generation running around 30 GW during overnight periods in the final week of July, alongside approximately 22 GW of nuclear generation. On 30 July at midnight, for example, coal output was 30.77 GW, nuclear 22.00 GW and gas 14.68 GW.
This helps explain why coal imports accelerated despite South Korea’s longer-term plans to reduce coal dependence.
Generation mix is changing, but coal still provides flexibility
South Korea is nevertheless undergoing a structural transformation of its generating fleet.
The country’s 2026 capacity trajectory envisages around 37.6 GW of coal capacity, compared with 40.2 GW in 2023, while renewable capacity rises to 44.8 GW from 32.8 GW. LNG capacity is projected at 52.4 GW and nuclear at 28.9 GW.
On installed capacity alone, renewables are therefore already becoming considerably larger than coal.
But capacity and actual generation tell different stories.
KPX’s real-time data show that during high-demand summer periods, coal continues to provide a large block of dependable generation. Nuclear similarly operates at high and relatively stable output, while gas provides additional flexibility as demand changes.
The July coal-import surge consequently illustrates an important feature of South Korea’s transition: declining structural dependence on coal does not necessarily produce a linear decline in coal imports.
Weather, nuclear availability, renewable output, LNG prices and inventory requirements can still produce periods of aggressive coal restocking.
Outlook
South Korea’s July coal trade highlights the tension between energy transition and energy security.
The country is steadily reducing coal’s importance in its installed generation fleet while expanding nuclear, LNG and renewable capacity. Yet during periods of strong summer demand, coal remains capable of returning quickly to the centre of the fuel mix.
The 21% y-o-y rise in bituminous coal imports during January-July is therefore significant. Rather than signalling a reversal of South Korea’s energy transition, it demonstrates that the path towards lower coal dependence is unlikely to be linear.
As renewables expand, South Korea’s future coal-import requirements could increasingly become seasonal and opportunistic — rising when power demand, fuel economics or generation availability favour coal, but trending lower structurally as alternative capacity expands.
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