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atural gas continues to play a central role in ASEAN’s energy systems, balancing growing demand with the region’s transition goals. Despite constraints on reserves, production, and trade, the fuel—whether delivered by pipeline or as LNG—remains essential for power generation, industrial use, and export revenues.

 

 

Declining supply, increasing demand

ASEAN’s proven natural gas reserves fell by 0.94 percent in 2023, driven primarily by a 3.79 percent decline in Indonesia’s reserves, underscoring concerns about long-term sustainability. Gas production, which had been declining since 2016 at an average annual rate of 3.02 percent, showed a modest rebound in 2023, rising by 0.84 percent to 19.8 BSCFD. The increase was led by the region’s three main producers—Indonesia (+1.52 percent), Malaysia (+0.77 percent), and Thailand (+0.25 percent).
 

Looking ahead, however, demand growth is expected to far outpace supply. The 8th ASEAN Energy Outlook (AEO8) projects that by 2050, gas consumption could increase by 163 percent under the Baseline Scenario (BAS)1 and by 87.3 percent under the ASEAN Member States (AMS) Target Scenario (ATS)2, driven by strong GDP growth and continued dependence on gas for power generation and industrial activity. 

 

 

A natural gas trade paradox: a dependent LNG importer and a key exporter

Trade dynamics show a shifting balance. Until 2023, ASEAN remained a net gas exporter, with Brunei Darussalam, Indonesia, Malaysia, and Myanmar offsetting the import requirements of Singapore and Thailand. Exports rose to 55.8 Mt from 51 Mt in 2022, yet net exports declined by 13 percent year-on-year and by 66 percent since 2019—a trend indicating that ASEAN is on track to become a net importer by 2027.

 

 

Country-specific developments highligh divergent strategies across ASEAN while underscoring the region’s deep integration with global gas markets. Indonesia has pledged to prioritize domestic gas use to strengthen energy security and support economic growth, though its net exports still declined by 3 percent in 2023. Malaysia remained the region’s largest exporter at 28.91 Mt, with only 12 percent of that volume retained within ASEAN. Indonesia, the second-largest exporter, sent about 30 percent of its exports to regional markets, primarily Singapore. Meanwhile, Thailand’s import dependence rose by 11 percent, and Singapore’s gas trade deficit widened by 2 percent, reflecting both countries’ continued reliance on imports for power generation.
 

Global price trends add another layer of complexity. Although benchmarks such as Henry Hub indicate oversupply and sluggish demand growth in 2024, gas prices across ASEAN remain relatively high due to regulated pricing structures and long-term export commitments. This disconnect leaves the region exposed to external market volatility and growing concerns over domestic affordability.

 

 

ASEAN’s gas sector stands at a crossroads. Rising domestic demand, uneven reserve replenishment, and shrinking net export capacity all point to a growing dependence on LNG in the years ahead. The region has already invested in and built much of the infrastructure needed to secure supply, expand LNG’s role in meeting energy transition goals, and chart decarbonization pathways to ensure long-term sustainability. Yet regional and global challenges to the continued use of natural gas are deepening.

 

 

Regional initiative and national development

The ASEAN Plan of Action on Energy Cooperation (APAEC)—the region’s energy development blueprint—underscores this challenge through the Trans-ASEAN Gas Pipeline (TAGP) initiative, designed to enhance accessibility and connectivity via pipelines and regasification facilities. To date, TAGP links six ASEAN Member States through 13 pipelines totaling 3,631 km and 14 LNG regasification terminals (RGTs) with a combined capacity of 59.6 Mtpa. However, according to the ASEAN Council on Petroleum (ASCOPE), all completed and proposed pipelines remain either domestic or bilateral in scope, with no multilateral links under development. This highlights the persistent gap between regional ambitions and national realities.
 

Amid slower progress in cross-border integration, ASEAN Member States have advanced their own national LNG and gas infrastructure strategies to meet domestic demand and bolster energy security. Indonesia expanded its capacity with the commissioning of the 3.8 MTPA Tangguh LNG Train 3 in October 2023, now targeting 180 cargoes annually—equivalent to about 60 percent of the country’s total gas output. Complementing this, the state-owned enterprise PLN Energi Primer Indonesia (PLN EPI) has signed new MoUs to develop midstream gas and LNG facilities integrated with port infrastructure, enhancing logistical efficiency and strengthening energy independence under the RUPTL 2025–2034 plan.
 

Malaysia, already a leading exporter in the region, operates two regasification terminals in Peninsular Malaysia—at Sungai Udang and Pengerang—with a third planned in Lumut, Perak, to meet rising demand. East Malaysia remains the backbone of the country’s export capacity, with Sarawak maintaining a major LNG supply base and Sabah expanding its floating LNG facilities, which are scheduled to begin operation by 2027.
 

Vietnam is moving rapidly into LNG-to-power development, with plans for six LNG terminals and related projects totaling more than 22,000 MW by 2035. To speed adoption, the government has reduced LNG import tariffs from 5 percent to 2 percent starting in 2025, reflecting its determination to position LNG as part of its clean energy transition strategy.
 

The Philippines has quickly positioned itself as a potential LNG import hub, with eight projects under development that could give the country Southeast Asia’s largest LNG import capacity—reaching 30.2 Mtpa. LNG imports are projected to increase more than fivefold between 2025 and 2029, replacing output from the declining Malampaya gas field. An estimated USD 5.4 billion in investment will be required to develop the necessary terminals and supporting infrastructure.
 

Singapore is likewise reinforcing its position as a regional LNG trading and distribution hub. Its second LNG terminal on Jurong Island—featuring a 200,000 m³ FSRU with a 5 Mtpa regasification capacity—is scheduled for completion by 2030. In parallel, a new LNG truck-loading facility is under construction to expand last-mile distribution and strengthen industrial supply chains.

 

 

 

How natural gas narrowed from every direction

Despite its status as a bridge fuel, natural gas occupies a precarious position. Policymakers continue to rely on it for cleaner power generation and short-term energy security, yet its transitional label makes investors cautious. As global capital increasingly flows toward renewables, ASEAN risks being caught in the middle—too dependent on gas to move away from it, yet unable to fully justify the scale of investment required to sustain it. Affordability adds another layer of fragility.
 

Affordability adds another layer of fragility

A market-driven system exposes ASEAN to price spikes, volatility, and the disproportionate influence of major suppliers. Both consumers and governments remain exposed, with the poorest bearing the brunt when global shocks occur. Rather than delivering stability, this environment risks producing unpredictable swings that erode confidence and hinder long-term planning.
 

Geopolitics sharpens these risks. Disputes over contested reserves such as East Natuna and the South China Sea keep significant resources stranded, while ASEAN members remain divided between prioritizing domestic supply and pursuing export revenues. This lack of alignment undermines collective action and delays progress on flagship initiatives like the TAGP. Without greater unity and a coherent regional strategy, ASEAN’s gas sector risks becoming not a pillar of energy security, but a casualty of competing interests and unresolved disputes.
 

Adding to these domestic and regional constraints is the complacency of the global community. Advanced economies urge ASEAN to accelerate its energy transition even as they continue importing LNG—a pattern that reinforces Southeast Asia’s role as a supplier in global gas markets. The region’s exports bind it to external demand cycles, and recent cargo diversions have shown how shifts abroad can quickly reverberate at home. This imbalance is deepened by the lack of meaningful financing and technology transfer, leaving ASEAN with few tools to decarbonize while bearing much of the responsibility for global energy supply.
 

While domestic regulations and export policies can cushion short-term volatility, the region cannot fully insulate itself from global gas dynamics. Import costs, competition for spot cargoes, and shifting benchmark linkages continue to transmit price shocks into national systems. This double bind leaves ASEAN caught between surging domestic demand and external pressures—risking a future in which the region bears the costs of the energy transition but lacks the means to manage it effectively.

 

 

Not only regional reconditioning, but also global re-understanding

ASEAN Member States should move beyond treating natural gas financing as a defensive necessity and instead position it as a strategic enabler of renewable integration. By embedding gas investments within broader decarbonization pathways—such as pairing LNG terminals with hydrogen-ready infrastructure, developing carbon capture pilot projects, or introducing methane-abatement measures across the gas value chain—policymakers can make the sector more attractive to blended finance and climate-aligned capital.
 

For the global community—especially multilateral banks and climate funds—this requires rethinking rigid exclusions on natural gas. Penalizing ASEAN for its pragmatic reliance on gas, while subsidizing transition efforts in the Global North, risks entrenching global inequities. A “just gas transition” framework, with clearly defined and time-bound exit pathways, should be part of the international agenda.
 

ASEAN should move beyond reactive subsidy measures and instead invest in regional price-stabilization mechanisms—such as pooled procurement, shared LNG stockpiles, or an ASEAN-led price index to lessen dependence on distant benchmarks like Henry Hub or JKM. Such measures would shift leverage away from external suppliers and enhance the region’s collective bargaining power.
 

Globally, major producers and trading hubs must begin recognizing Southeast Asia as more than a passive price-taker. Transparency in LNG contracts and mechanisms to contain excessive volatility should be viewed as integral components of the global energy security framework—not merely as regional concerns.
 

Rather than allowing maritime disputes and fragmented priorities to stall cooperation, ASEAN should leverage its collective weight in global LNG flows. Coordinated messaging—linking progress on the TAGP and the development of an integrated regional gas market to broader trade and investment frameworks—would make clear that external powers have as much at stake in regional stability as ASEAN itself.
 

The global community must also stop viewing South China Sea disputes solely as territorial flashpoints—they are critical energy chokepoints. The contested waters contain vast untapped oil and gas reserves and serve as shipping routes for roughly one-third of global energy trade. Any escalation would disrupt exploration and production while undermining the stability of both regional and global energy markets. Proactive multilateral frameworks for joint resource development and conflict de-escalation are essential; without them, the integrity of global LNG trade could face serious structural risks.
 

Ultimately, while the obstacles to expanding LNG’s role in ASEAN are numerous, one thing is clear: LNG can serve as a stable bridge toward a secure and sustainable regional energy mix—but only if ASEAN chooses to cross it.