Thailand Oil And Gas Market Size & Share Analysis - Growth Trends And Forecast (2025 - 2030)

This growth stems from resilient domestic gas demand for power generation, rising petrochemical feedstock needs in the Eastern Economic Corridor, and continuous capital allocation to sustain production from mature offshore fields. The 25th petroleum bidding round further buoys robust upstream spending, accelerates LNG terminal development, and offers supportive fiscal terms that enhance project economics. Decommissioning activity and digital‐enabled maintenance remain bright spots, while fuel-price caps and emissions-related trade rules temper downstream profitability. Operators are therefore balancing cost discipline, carbon-reduction initiatives, and selective frontier exploration to safeguard energy security and corporate returns. Collectively, these dynamics keep the Thailand oil and gas market firmly on a mid-single-digit growth trajectory through the decade.

EGAT’s current Power Development Plan calls for 15 GW of additional gas-fired capacity by 2030, a 40% step-up from 2024 levels.^{[1]EGAT, “Power Development Plan (PDP2024),” egat.co.th} Long-term supply contracts between independent power producers and PTTEP underpin a stable offtake for new upstream projects. Demand is concentrated in the Eastern Economic Corridor, where power and petrochemical requirements overlap, ensuring minimum load factors for new plants. Pipeline expansions from the Gulf of Thailand to Chonburi and Rayong have therefore gained priority approvals. Consequently, upstream investors view the Thailand oil and gas market as insulated from near-term demand volatility, encouraging a healthy drilling program pipeline.

The 25th bidding round, with nine onshore blocks and improved fiscal terms, marks the first licensing window since 2018. Royalty rates have been lowered by one percentage point for exploration phases, while local-content rules are relaxed until field development commences. This fiscal reset arrives as Brent prices hover above USD 80/bbl, lifting netbacks for frontier drilling. International majors have pre-qualified teams focusing on shallow-water gas prospects that could enter production before 2030. Successful awards would counterbalance a 5% annual decline in legacy fields and reinforce the Thailand oil and gas market’s upstream-led growth narrative.

PTTGC’s USD 1.2 billion ethane cracker expansion adds 1 million tpa of ethylene capacity by 2026, while Dow Chemical’s USD 800 million polyethylene unit strengthens value-chain integration.^{[2]PTT Global Chemical, “Ethane Cracker Expansion Fact Sheet,” pttgcgroup.com} These projects increase domestic demand for NGL and lean gas, providing a back-of-the-envelope level of offtake security for Gulf of Thailand gas producers. The complex’s adjacency to deep-water berths lowers export logistics costs, enhancing Thailand’s regional competitiveness. New storage, such as Vopak’s 60,000 m³ ethane tank, improves feedstock optionality and supports turn-key contract opportunities for midstream players. Collectively, these assets anchor downstream profitability despite national pump-price controls.

The 7.5 mtpa Nong Fab terminal entered service in 2024, granting Thailand access to global spot LNG and mitigating pipeline supply risks from Myanmar. A 5 mtpa third terminal in Chonburi is undergoing FEED review, with a target FID by late 2025. Regas capacity raises system flexibility, enabling seasonal import arbitrage and safeguarding power plants during upstream maintenance shutdowns. Thailand also eyes re-export opportunities via interconnected pipelines to Laos and Cambodia, potentially creating an ASEAN trading hub. These moves enhance the resilience of the Thailand oil and gas market while widening revenue pools along the gas value chain.

Output from Erawan, once 25% of the national gas supply, is declining 15% per year due to a drop in reservoir pressure and rising water cut.^{[3]PTTEP, “Field Decline Management Report,” pttep.com} Bongkot shows parallel exhaustion trends, despite secondary recovery schemes. Chevron has allocated USD 2 billion for infill drilling, but geological limits cap incremental gains. The shortfall forces higher LNG imports, which squeeze the balance of payments and elevate power tariffs. Urgent replacement barrels and molecules therefore dominate operator capital budgets in the Thailand oil and gas market, crowding out discretionary exploration spend elsewhere.

The EU’s Carbon Border Adjustment Mechanism enters its monitoring phase in 2026, exposing Thai refiners shipping diesel and jet fuel to Europe to prospective carbon tariffs. Bangchak has begun ISO 14001 deployments, yet full Scope-1 emission cuts require multi-year furnace upgrades and renewable power PPAs. Added compliance costs could erode netbacks by USD 1/bbl for European-bound cargoes, thereby challenging the expansion economics of export-oriented capacity. This policy headwind nudges refiners toward higher-value petrochemicals and Asian demand centers, reshaping downstream flow patterns within the Thailand oil and gas market.