Indonesia Thermal Power Market Size, Share & Forecast, By Fuel Type, Plant Technology & Ownership Model, 2025-2032

The Indonesia Thermal Power Market was worth USD 26,000 million in 2025. The estimate covers generator-level value associated with coal, natural gas, and oil or diesel thermal electricity from PLN, generation subsidiaries, IPPs, private power utilities, and licensed own-use generators. ESDM's ownership-based 2025 dataset indicates approximately 415.9 TWh of thermal generation, with coal-fired steam plants accounting for the largest share. The estimate excludes renewable generation, transmission and distribution revenue, fuel mining revenue, and unrelated EPC activity to prevent scope inflation and double-counting.

The market is projected to reach USD 36,341 million by 2032, representing a 4.90% CAGR for 2025-2032. Growth is slower than the 6.93% historical CAGR because renewable generation and storage increasingly capture incremental capacity additions. Absolute thermal output still rises as electricity consumption, industrial processing, captive generation, and balancing requirements expand. The value forecast also assumes increasing contributions from flexible gas generation, higher-efficiency technologies, environmental controls, maintenance services, and carbon-compliance expenditure rather than simple replication of the existing coal fleet.

The principal profit-pool shift is from incremental conventional coal capacity toward combined-cycle gas, operating-efficiency services, environmental retrofits, and industrial captive solutions. The current PLN planning framework contains 10.3 GW of gas additions compared with 6.3 GW of coal additions through 2034. Gas plants can increasingly monetize ramping, system balancing, and lower relative carbon intensity, while existing coal plants must compete through heat-rate improvement, high availability, co-firing capability, and low-cost fuel procurement. Captive industrial operators create an additional modernization market outside traditional PLN dispatch.

The largest structural risk is declining thermal share as renewable energy, storage, and carbon regulation scale simultaneously. Renewables and storage represent 52.9 GW, or 76%, of planned generation and storage additions under the current PLN framework. Carbon trading is also expanding across the thermal fleet, with the 2025 Phase Two framework covering approximately 454 generating units representing 153 companies and 61.40 GW. Operators with high heat rates, poor availability, weak fuel security, or limited environmental-control capability therefore face increasing dispatch, compliance, and refinancing pressure.

Indonesia is the largest market in the report's selected peer benchmark, ahead of Vietnam, Thailand, Malaysia, and the Philippines. Standardized 2025 datasets show Indonesia generating more electricity than these peers, while fossil generation remains a high share of its mix. Vietnam offers faster modeled thermal growth because electricity demand is expanding rapidly, whereas Thailand and Malaysia are comparatively mature. Indonesia's combination of domestic coal supply, large-scale industrial demand, substantial captive generation, and a deep utility and IPP asset base gives it the strongest overall thermal revenue pool within this comparison.

Industrial electrification is the strongest demand-side support because manufacturing, mineral processing, smelting, and industrial estates require high-load-factor electricity and dependable supply. Indonesia's electricity consumption per capita reached 1,584 kWh in 2025, while PLN industrial customer sales were approximately 95.1 TWh before accounting for a substantial captive-generation segment. Thermal generation remains especially important where large industrial loads cannot yet rely entirely on variable renewable supply. Growing grid interconnection and storage reduce thermal share but do not eliminate the need for firm dispatchable capacity.

Combined-cycle gas turbine technology has the strongest incremental positioning because it can provide dispatchable capacity, faster ramping, and lower direct emissions intensity than conventional coal generation. The current planning framework assigns 10.3 GW to new gas capacity, and the 1,760 MW Jawa Satu Power project demonstrates the integrated LNG-to-power model already operating at scale. Ultra-supercritical coal technology and efficiency retrofits remain relevant for existing baseload assets, but new value creation increasingly centers on flexible generation that complements solar, wind, hydro, storage, and stronger inter-island transmission.