Indonesia Coal Market Size & Share Analysis - Growth Trends and Forecast (2027 - 2032)

Market Trends and Insights

Prolonged PLN-led baseload demand for low-CV thermal coal

PT PLN (Persero), Indonesia's state electricity utility known as PLN, can create additional outlets for low-calorific-value coal through changes in its fleet's fuel capability. In July 2026, PLN said a successful retrofit of Suralaya units 6 and 7 allowed the plants to use low-rank coal at about 4,100-4,300 kcal/kg. The modification widens the usable fuel range at those units, giving lower-calorific coal a route into existing generating equipment. Broader coal deliveries to Indonesian power plants rose from 133.5 million metric tons in 2024 to 141.4 million metric tons in 2025. A joint operation of PT Arutmin Indonesia and PT Darma Henwa Tbk has contracted to supply PLN's Suralaya plants with 1.305 million metric tons of low-rank coal annually from 2009 through 2028.

Surge in coal-fired captive power for nickel & EV-battery smelters

Nickel processing connects coal demand to industrial power requirements alongside the utility system. In 2025, Indonesian nickel processing used more than 81 TWh of captive power, with over 94% generated from coal, according to Ember’s estimate.^[1] Operational captive coal capacity linked to the nickel industry rose from 7.16 GW in 2023 to 15.4 GW in 2025. This larger operating base gives coal suppliers an industrial outlet whose fuel requirements depend on smelter operations, extending demand beyond PLN’s purchasing needs. Suppliers can size contracts around operating smelters' fuel needs, with lower utilization reducing offtake even if no generating units close.

China-plus-One strategy shifting seaborne demand to Indonesia

South Korea was one destination where Indonesian coal shipments grew in 2025, even as shipments to China fell. Indonesian coal shipments to South Korea rose 4.51% from 2024 to 29.1 million metric tons in 2025. Those deliveries represented 5.5% of Indonesia’s total coal exports that year. China was the largest buyer in 2025, receiving 213 million metric tons, down 11.98% from 2024, and accounting for 40.2% of exports versus 42.7% in 2024. The difference in scale makes South Korea a growing complement to China-bound sales, rather than a replacement for them.

Government “Gasification & DME” incentives for low-rank coal

Government support for gasification works through potential feedstock-cost relief, with eligibility determining its practical value. Under Government Regulation No. 25 of 2021 (PP No. 25 of 2021), eligible production-operation license holders may receive a 0% royalty on coal used for domestic value addition, subject to energy-independence and industrial-feedstock considerations. Implementing rates, requirements and procedures require ministerial rules and prior finance-minister approval, while Indonesia’s Ministry of Energy and Mineral Resources (ESDM) said in its 2025 performance report that detailed rules were being prepared. The mining framework includes gasification, with intermediate production under mining licenses and final-product processing subject to industrial licensing. Applied to qualifying coal volumes, the relief can improve conversion economics and support a domestic feedstock outlet. For a conversion developer, qualifying feedstock and implementing approvals must come together before potential royalty savings can underpin a project.

Mandatory Domestic Market Obligation (DMO) price caps

The DMO price cap constrains the economics of supplying PLN when mining costs rise. In June 2026, Indonesia’s USD 70-per-metric-ton cap on DMO coal supplied to PLN reduced producers’ economic incentive to allocate coal domestically as production costs rose.^[2] Stripping ratios at some mines rose to between 10 and 12, raising production costs while the price PLN pays stayed capped. The constraint is most acute for the mines with the higher stripping burden. Higher utility fuel needs cannot restore miners' cost recovery when additional regulated deliveries retain the same price ceiling.

Proposed accelerated coal-plant retirement under JETP funding

Accelerated retirement proposals constrain the duration of coal demand even before they produce a completed plant closure. Under Indonesia's Just Energy Transition Partnership (JETP), the PT SMI technical-assistance program was approved in January 2024 to support financing for accelerated retirement of PLN-owned coal plants, with the Asian Development Bank as implementing partner. In December 2025, Indonesia's coordinating economic minister said the government had dropped the Cirebon-1 plan and would seek an older coal plant for early retirement. For suppliers serving those plants, the proposed mechanism introduces a potential earlier endpoint to an otherwise continuing fuel requirement. Unlike a temporary dispatch reduction, retirement would remove the buyer's recurring fuel requirement. Plant-specific supply infrastructure can face a shorter repayment window if retirement advances.

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

Indonesia Coal Market Segment Analysis

Sub-bituminous coal accounted for a 47.15% share of the Indonesia coal market size in 2026, making it the largest segment. PT Arutmin Indonesia, a PT Bumi Resources Tbk subsidiary, produced 8.2 million metric tons of sub-bituminous eco-coal at its Kintap mine in 2025. Arutmin’s sub-bituminous eco-coal has very low sulfur and ash content and is used in domestic and overseas steam power plants. Arutmin's Asamasam site in South Kalimantan has capacity of up to 8 million metric tons of sub-bituminous coal annually, giving the operator another substantial site in this grade.

Bituminous and coking coal is forecast to be the fastest-growing segment, with a CAGR of 7.3% over 2027-2032. PT Alamtri Minerals Indonesia Tbk, an Alamtri Resources subsidiary, reported FY2025 total coal output of 7.41 million metric tons, up 12% from FY2024, mostly metallurgical with the remainder low-calorific coal.^[3] In 4Q2025, it completed the first 39-kilometer phase of a chip-seal hauling-road upgrade linked to its subsidiary PT Maruwai Coal’s hard-coking-coal operations. Designed to support safe all-weather navigation, the upgrade addresses the link between mine output and dependable haulage. Because the upgrade is targeted to cover the entire hauling road surface, the 39-kilometer first phase leaves further work on Maruwai's haul route.

Power generation represented a 56.16% Indonesia coal market share in 2026 and was the largest segment. ESDM estimated in July 2026 that PLN required 154 million metric tons of coal that year for its power plants. ESDM had separately assigned 212 million metric tons to mining companies with approved work plans. The assignment exceeds PLN's estimated requirement, so designated supply does not guarantee sales for each assigned ton. On October 16, 2026, ESDM said the allocation for PLN's 2026 power-plant needs was secure through year-end.

Iron, steel, and metallurgy is forecast to be the fastest-growing segment, with a CAGR of 8.1% over 2027-2032. Domestic buyers accounted for 31% of Alamtri subsidiary PT Alamtri Minerals Indonesia Tbk’s FY2025 metallurgical-coal sales volume, driven by strong demand from Indonesian coke producers. That buyer relationship connects mining sales to domestic coke production, creating a metallurgical outlet alongside export demand. Cement industries provided another distinct industrial use, consuming 8.78 million metric tons of coal in Indonesia in 2025.

Geography Analysis

East Kalimantan Coal Market

East Kalimantan held 38% of Indonesia's proven coal reserve base in 2026. PT Kaltim Prima Coal, a Bumi Resources subsidiary, mined 53.5 million metric tons at Sangatta and Bengalon in 2025, down 2.7% from 2024. The decline came from Sangatta, which mined 42.3 million metric tons in 2025 against 44.2 million in 2024, while Bengalon rose to 11.2 million from 10.8 million. Sangatta's larger output and decline make its performance the main determinant of Kaltim Prima Coal's supply from East Kalimantan.

Sumatra’s production story is illustrated by South Sumatra, where coal output reached 120.7 million metric tons in 2025, up from 113.3 million in 2024. Central Kalimantan is illustrated by PT Pada Idi's high-energy thermal-coal operation at Luwe Hulu. In Central Kalimantan, Pada Idi serves domestic and international markets and moves stockpiled coal to its port over a 1-kilometer overland conveyor. South Sumatra's 7.4-million-metric-ton output rise in 2025 shows provincial supply expansion, whereas Pada Idi illustrates single-mine logistics for high-energy thermal coal, with a 1-kilometer overland conveyor linking stockpile to port.

North Maluku’s role is as an industrial coal-use destination, illustrated by the 4.54 GW of operational captive coal-power capacity linked to Indonesia Weda Bay Industrial Park (IWIP) in the 2025 inventory. North Maluku’s IWIP-linked capacity serves nickel processing and uses domestic coal, connecting the destination to fuel requirements outside the utility system. On Obi Island, the PT Halmahera Persada Lygend smelter power complex at Kawasi has at least 1,630 MW of capacity for domestic-coal captive generation, although some units are not operating. For potential suppliers, the distinction between installed capacity and active units affects the volume of fuel that can become recurring demand. Returning idle units to service could create additional fuel demand at Obi without adding new generating capacity.

Regulatory Framework and Outlook

The comparison covers selected jurisdictions from the perspective of coal producers seeking production areas and viable dispatch routes. Government Regulation 39/2025 (PP 39/2025), in force since September 11, 2025, permits specified eligible entities to seek priority coal areas through the central government's OSS licensing system after ministerial verification and approval. Eligible categories include cooperatives, small and medium businesses, businesses owned by religious community organizations, and specified state-owned, regional-owned or private businesses for higher-education access or downstream value addition. East Kalimantan Governor Regulation 43/2013 (Pergub 43/2013), in force since July 18, 2013, constrains public-road coal haulage, so priority access alone cannot secure dispatch.

Indonesia's Medium rating reflects the exclusion of producers outside the eligible categories from priority access, while No change reflects PP 39/2025's operation since September 11, 2025. East Kalimantan’s Low rating reflects the public-road restriction for bulk coal, which makes a compliant haul route central to dispatch feasibility. Packaged coal intended for household use has an exception, subject to road-class tonnage limits. Continuing road-use conditions and assigned oversight through the integrated team support continuity of the provincial haulage constraint.

Value Chain Stages

The value chain compares mine production, inland rail movement and maritime dispatch, separating coal-sales earnings from transport-service revenue. PT Kereta Api Indonesia (KAI) transported 41.61 million metric tons of coal by rail in South Sumatra and Lampung during January-September 2026. That volume makes rail a substantial route for South Sumatra and Lampung coal, so producers there depend on freight slots as well as mine output.

KAI identified tracks, signaling, terminals, maintenance facilities and committed cargo as requirements for productive freight capacity. Under a 2026 plan, Bukit Asam is to develop loading and unloading terminals and supporting infrastructure, while KAI is to provide rolling stock and electric signaling. The complementary responsibilities illustrate why usable freight capacity depends on coordinated readiness across a route, making isolated equipment additions an incomplete basis for expanding shipments.

Key Opportunities for Market Participants

These opportunities compare initial utility supply, subsequent-year delivery scale and coal-to-methanol feedstock demand. PT Lestari Banten Energi invited mine owners and relevant license holders to qualify for planned supply of 1.2 million metric tons in 2027 and 1.8 million annually afterward, with submissions due October 30, 2026. The minimum contract term is 2 years, with extensions subject to agreement, remaining mine reserves and the validity of the PLN power-purchase agreement.

The clearest near-term opening is the utility’s defined procurement schedule, because its buyer, annual need and qualification date are specified. The methanol project offers a separate route for the designed low-calorific feedstock, with coal sales dependent on construction and contracting progress. This separates an actionable supply process from a project-development outlet, keeping each opportunity tied to the stage at which coal can actually be purchased.