Thailand's Petroleum Department is pushing forward with a plan to auction exploration rights for 26 offshore and onshore blocks by year's end, a move that signals both the urgency and complexity of the kingdom's energy predicament. Domestic natural gas output has dropped 15% year-on-year in 2025, forcing authorities to confront an uncomfortable reality: aging fields in the Gulf of Thailand and diminishing flows from Myanmar can no longer sustain the country's electricity grid, industrial base, or transport sector without significant reliance on expensive imported fuel.
For residents and businesses accustomed to relatively stable electricity costs, the shift has profound implications. Thailand now imports roughly 40% of its natural gas supply as liquefied natural gas (LNG), with the share projected to climb to 60% by the mid-2030s. That dependency exposes the economy to volatile global spot prices—which spiked to $25 per million BTU in March 2026 amid geopolitical tensions—and complicates long-term budgeting for manufacturers, transport operators, and households alike.
Why This Matters
• Electricity bills: Higher LNG import costs translate directly into fluctuating power tariffs, with the fuel adjustment charge (Ft) rising or falling as global prices shift.
• Industrial competitiveness: Energy-intensive sectors—petrochemicals, cement, steel—face margin pressure when gas prices surge, potentially eroding Thailand's manufacturing edge in ASEAN.
• Revenue impact: Declining domestic production means lower petroleum royalties for the Treasury, narrowing fiscal headroom at a time when infrastructure and climate adaptation demand investment.
• Policy pivot: Draft Power Development Plan 2025 (PDP 2025) targets cutting gas dependence in electricity generation to below 41%, accelerating renewables deployment and possibly introducing small modular nuclear reactors (SMRs) by the early 2030s.
Decline in the Gulf and Myanmar Pipeline
The kingdom's flagship fields—Erawan and Bongkot—have aged beyond their most productive years. PTTEP, the national exploration and production flagship, managed to squeeze out approximately 2,720 million cubic feet per day from the Gulf of Thailand in the first quarter of 2026 by bringing new satellite projects online, including Arthit, the Thai-Malaysian Joint Development Area (B17-01), Contract 4, and G2/61. Yet those gains merely slow the rate of contraction rather than reverse it.
Projected figures paint a stark picture: domestic output is forecast to fall 17.1% from 2025 to 2026, following a 15% drop the previous year. Meanwhile, pipeline imports from Myanmar are set to decline 5.4% in 2026 after tumbling 20.1% in 2025. Key Burmese fields such as Yadana and Zawtika are nearing depletion, and fresh exploration has stalled amid political instability across the border. Although PTTEP has proposed new drilling at Yadana to extend field life, the incremental volumes will not compensate for the underlying trend.
LNG Import Surge and Long-Term Contracts
To bridge the gap, PTT in March 2026 expanded its supply agreement with a United States exporter, lifting the contracted volume from 1 million to 1.3 million tonnes per annum. Deliveries under a separate 20-year, 2-million-tonne-per-year deal with Alaska LNG are scheduled to commence in 2026, offering some insulation from the wild swings of the spot market.
Total LNG imports are expected to climb 8.8% in 2026, reversing an 11.7% contraction in 2025 when robust output from Erawan temporarily reduced the need for expensive cargoes. Over the January–October 2025 period, Thailand took in approximately 8.6 million tonnes of LNG, down roughly 11% year-on-year. Analysts at SCB EIC estimate the average landed price for 2026 at $17.94 per million BTU, though spot cargoes in May reached $18.22 per million BTU—well above the $11 baseline seen before major conflicts disrupted Middle Eastern shipping lanes.
For logistics operators and industrial buyers, the volatility is a planning headache. Trucking LNG to remote facilities remains niche but growing: the Department of Energy Business forecasts 30% growth in LNG trucking volumes this year, from 110,000 tonnes to approximately 155,000 tonnes, as manufacturers seek alternatives to diesel and heavy fuel oil.
Falling Demand and Underutilized Gas Plants
Paradoxically, total gas demand in Thailand is declining—projected to drop 3% in 2026 after a 3.8% fall in 2025. The culprit is a structural shift in the electricity mix: rising renewable capacity, especially solar, plus increased power imports from Laos hydroelectric schemes, have steadily displaced gas-fired generation. Between January and August 2025, gas accounted for 54.8% of electricity production, but that share is expected to fall below 41% under the draft PDP 2025.
The oversupply of gas-fired capacity has become conspicuous. In October 2025, seven privately operated combined-cycle plants ran at utilization rates below 10%. In response, the National Energy Policy Committee (NEPC) ordered the suspension of four stations—three gas-fired—and postponed commissioning of an additional 0.6 GW until 2029. Mothballed plants are slated to return to service only after that date, when anticipated growth in electric-vehicle charging, data centers, and air-conditioning demand may absorb surplus capacity.
This mismatch—falling demand, rising import dependency, and idle domestic infrastructure—underscores the challenge of managing a transition away from fossil fuels without stranding assets or triggering price spikes during supply shocks.
Regional Context: Indonesia, Vietnam, Malaysia
Thailand is not alone. Across Southeast Asia, mature basins are entering decline, forcing governments to choose between doubling down on hydrocarbons or pivoting harder toward renewables.
Indonesia aims to auction 60 upstream blocks over the next two to three years and has set production targets of 1 million barrels per day of oil and 1.005 billion cubic feet per day of gas by 2030. The government is also exploring carbon capture, utilization, and storage (CCUS) and blue hydrogen to decarbonize existing gas infrastructure. Without fresh finds, analysts warn Indonesia could face domestic shortages by 2033.
Vietnam planned an ambitious rollout of 22.5 GW of LNG-fired capacity by 2030, but financing gaps, policy gridlock, and geopolitical risk have stalled multiple projects. State-owned PV Gas is investing $3.8 billion (2026–2030) in terminals and regasification facilities, yet one major conglomerate, Vingroup, proposed scrapping a large LNG plant in favor of renewable megaprojects. The revised National Power Development Plan (PDP8) now targets 75% renewable share by 2050, excluding large hydro, with a sixfold increase in solar capacity by 2030.
Malaysia has seen Peninsular output halve over the past decade, though reserves in Sabah and Sarawak keep the country a net exporter until the early 2040s. Sarawak remains a major LNG exporter, while the Peninsula will rely increasingly on imports. Kuala Lumpur is also exploring nuclear power, aiming for a first reactor by 2031.
For Thailand, these regional case studies underscore a common playbook: auction more acreage, secure long-term LNG contracts, accelerate renewables, and pilot low-carbon technologies such as CCUS and hydrogen.
Policy Reforms and the Path to Carbon Neutrality
The Ministry of Energy has outlined a multi-pronged strategy to shore up supply and reduce emissions:
Accelerate upstream licensing: Round 25 onshore and Round 26 combined onshore-offshore auctions are designed to attract exploration capital. Projected investment stands at ฿2.5 billion, with potential reserves of 20.7 trillion cubic feet if discoveries reach commercial threshold.
Extend joint development areas: Negotiations to renew the Thai-Malaysia JDA, which expires in 2029, are underway. Talks with Cambodia over the Overlapping Claims Area (OCA) in the Gulf, which stalled in mid-2025 due to border tensions, remain critical to unlocking new reserves.
Diversify LNG suppliers: Beyond North America, PTT is in discussions with producers in the Middle East, Australia, and Africa to avoid over-reliance on any single source.
Maximize value from raw gas: Authorities are directing more wet gas to separation plants that extract liquefied petroleum gas (LPG) and petrochemical feedstock before routing residual methane to power stations, capturing higher-margin products.
Reduce gas in power generation: Some studies recommend slashing the gas share to below 20% by 2050 to meet carbon neutrality by 2050 and net-zero by 2065. This implies a massive build-out of solar, wind, battery storage, and possibly nuclear.
The draft PDP 2025 envisages renewables exceeding 50% of installed capacity, with provisions for small modular reactors and energy-storage systems to provide baseload stability as intermittent solar and wind displace dispatchable gas plants.
Impact on Expats and Investors
For expatriates managing household budgets, the immediate consequence is less predictable electricity bills. The fuel tariff (Ft) adjusts quarterly based on generation costs; when spot LNG prices spike, so does the Ft surcharge. Long-term residents may notice sharper seasonal swings, particularly if drought curtails Lao hydro imports or extreme heat pushes air-conditioning demand beyond forecast.
Foreign manufacturers evaluating Thailand as a production hub should factor in energy-cost uncertainty. While the government has pledged to prioritize industrial allocations during shortages, any sustained price divergence from Vietnam or Malaysia could erode competitiveness in energy-intensive sectors. On the upside, accelerated renewable deployment may eventually lower marginal costs and enhance Thailand's green credentials for export markets imposing carbon border adjustments.
Investors in infrastructure—particularly solar developers, battery-storage projects, and LNG terminals—stand to benefit from policy tailwinds. The Energy Regulatory Commission is finalizing rules for direct power purchase agreements (DPPAs), allowing large industrial users to contract directly with renewable generators, bypassing the state utility and potentially locking in lower rates.
What Comes Next
Thailand's energy transition is unfolding in real time, balancing the inertia of a gas-dependent grid against accelerating climate commitments and fiscal realities. Domestic production will continue its decline unless exploration yields commercial discoveries—a process that typically requires five to seven years from license award to first gas. In the interim, LNG imports will fill the gap, exposing the economy to global price volatility and geopolitical risk.
The government's bet is that renewables, storage, and demand-side efficiency can absorb the slack faster than conventional wisdom suggests, rendering new gas infrastructure partially redundant before assets fully depreciate. Whether that gamble pays off depends on execution: timely auctions, swift permitting for solar farms, grid upgrades to handle variable generation, and political consensus around potentially unpopular tariff reforms.
For now, residents should expect a bumpier ride on electricity costs, manufacturers should stress-test energy budgets against wider price bands, and policymakers must navigate the narrow path between energy security and decarbonization—knowing that missteps in either direction carry economic and environmental consequences that will reverberate for decades.
