Southeast Asia (ASEAN) LNG Facilities Database

Latest LNG news

ASEAN + world · latest 40 of the last 7 days · from the daily LNG news reader · generated 2026-08-25 18:17

08-25
Other Woodside’s H1 profit climbs LNG Prime
08-25
Other Uniper and Equinor secure long-term gas supply contract LNG Industry
08-25
Other Knutsen takes delivery of QatarEnergy LNG tanker LNG Prime
08-25
Africa Iran war makes multibillion-dollar Tanzania LNG more attractive, Equinor says Reuters
08-25
Other Hanwha Aerospace forms US LNG unit LNG Prime
08-25
Singapore BW confirms sale of steam LNG carrier LNG Prime
08-24
Other Woodside scraps clean energy target, posts 7% first-half profit rise Reuters
08-24
Other Uniper, Equinor seal long-term gas supply deal LNG Prime
08-24
Other US LNG exports set for endurance test as high gas prices bite Reuters
08-24
Other UK's Burnham urges allies to do 'everything' to support Ukraine's skies Reuters
08-24
Other TotalEnergies profitably moving heavily discounted oil through Strait of Hormuz, says CEO Reuters
08-24
Other TotalEnergies eyes new exploration in Norway, CEO says Reuters
08-24
North America Shell shelves Aphrodite offshore gas project in Trinidad for now Reuters
08-24
Other Santos: GLNG to buy Meridian CSG project LNG Prime
08-24
Europe Norway will drill in Arctic regardless of EU's position, says energy minister Reuters
08-24
Other India’s GAIL plans Kandla LNG bunkering facility LNG Prime
08-24
Other Germany's Uniper signs 15-year gas import deal with Norway's Equinor Reuters
08-24
Other Germany's Uniper says it has filled 70% of its contracted gas storage Reuters
08-24
Other GLNG acquires Meridian CSG project LNG Industry
08-24
Asia GAIL India plans bunkering facility at Kandla Port LNG Industry
08-24
Asia Fewer than 20 ships transit key Strait of Hormuz over weekend, data shows Reuters
08-24
Other Expion in oil and gas move LNG Prime
08-24
Other Ebara Elliott Energy and Doosan Enerbility partner on advanced compressors for the LNG industry LNG Industry
08-24
North America Construction progresses on Woodside’s Louisiana LNG project LNG Prime
08-24
Other Cheniere confirms Corpus Christi LNG plant undergoing maintenance Reuters
08-24
Asia Bangladesh seeks more spot LNG supplies LNG Prime
08-23
Asia Iran says Pakistan's army chief to visit Tehran Reuters
08-21
North America White & Case advises consortium of banks on US financing for LNG-to-power project in the Dominican Republic LNG Industry
08-21
Other TPDC, TAQA Arabia, and Africa50 sign gas sales agreement LNG Industry
08-21
Asia Ships passing through Hormuz hover in single digits, data shows Reuters
08-21
Other New Fortress Energy's finance chief Guinta resigns Reuters
08-21
Other India's Welspun Corp wins record $1.8 billion pipe supply order; shares jump Reuters
08-21
Other GTT receives order for LNG carrier tank designs LNG Industry
08-21
Other First gas from Australia's Beetaloo puts shale ambition to the test Reuters
08-20
Other Suomen Lantakaasu inauagurates bio-LNG production plant in Nurmo LNG Industry
08-20
Other LR supports LNG carrier-to-FSU conversion for Perenco LNG Industry
08-20
Other Energy Watch: Oil squeeze is just getting started Reuters
08-20
Other EU not concerned about gas supply or storage filling, Commission says Reuters
08-20
Other CoreMarine completes decommissioning operations LNG Industry
08-19
Other Summit LNG supplying up to 550 million ft3/d LNG Industry

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	Facility	Type	Status	Country	Cap (Mtpa)	Years	Location	Operator	Imp/Exp
	Bontang LNG (Badak) Badak LNG	Liquefaction (export)	Operating (partial)	Indonesia	25.1	1977	Bontang, East Kalimantan Kalimantan	PT Badak NGL 🇮🇩	Export
Capacity 25.1 design; ~5.7 active (trains G-H) + Train F reactivation planned; 11.5 exported (2021) · 8 trains (A-H) + train I (cancelled) Direction Export Ownership Pertamina (PHE/Pedeve) 70% / VICO Indonesia 20% (Eni 50% - Saka Energi 50%) / TotalEnergies 10% Feed source Badak, Nilam, Samberah, Mutiara fields; Eni Merakes (2021); Eni Kutei Basin hubs: North (Geng North + Gehem) & South (Gendalo + Gandang), dual FID Mar 2026 Serves Exports (Japan, Korea, Taiwan) + domestic Cost — Source source Notes Trains A-D retired, E-F idled, G-H operating, train I cancelled (2009). Production declining since 2006 due to feedstock depletion; 2024 IGU: 2 trains decommissioned, 2 operational. VERIFIED 2026-08-12: Eni dual FIDs (Mar 2026) for North Hub (Geng North, Gehem) and South Hub (Gendalo, Gandang) - up to 2 bscfd gas + 90,000 bpd condensate at plateau, leveraging Jangkrik FPU and Bontang; POD reactivates idle Train F, studies underway for up to 2 more idle trains; Eni secured LNG offtake deals (May 2026). Ownership CORRECTION 2026-08-12: NOT 100% state-owned; historical split Pertamina 55% / Total E&P 10% / VICO 20% / JILCO 15% through 2018; Pertamina agreed Apr 2020 to acquire JILCO 15% (CSPA via PT Pedeve) lifting the group to 70%; VICO BP interest passed to Eni (2021), VICO now Eni 50% - Saka Energi 50%
	Tangguh LNG Tangguh (BP Berau)	Liquefaction (export)	Operating	Indonesia	11.4	2009	Teluk Bintuni, Bintuni Bay, West Papua Papua	BP Berau 🇬🇧	Export
Capacity 11.4 (3 x 3.8) · 3 trains (T1-T3) Direction Export Ownership BP PLC 40.2% / Mitsubishi 13.9% / CNOOC 13.9% / INPEX 10.9% / ING Resources Muturi 7.4% / ENEOS 6.2% / JOGMEC 6.0% / KG Wiriagar 1.4% Feed source Wiriagar, Berau, Muturi fields (Bintuni Bay) Serves Exports + domestic (89 cargoes planned for 2026, +4.7% YoY) Cost $6.2B Source source Notes T1/T2 started 2009 (US$2.5B each); T3 FID 2016, started Oct 2023 (US$1.2B train; $3.74B debt package JBIC/ADB/commercial). VERIFIED 2026-08-12: T3 commercially inaugurated by President (ESDM); UCC project (Ubadari + CCUS, ~15 Mt CO2 phase 1) FID Nov 2024 and designated a national strategic project; groundbreaking also held for blue ammonia and Asap Kido Merah gas field (ESDM). CCUS plan approved by SKK Migas Aug 2021.
	Donggi-Senoro LNG DSLNG	Liquefaction (export)	Operating	Indonesia	2.0	2015	Luwuk, Banggai Regency, Central Sulawesi Sulawesi	PT Donggi-Senoro LNG 🇯🇵	Export
Capacity 2.0 · 1 train Direction Export Ownership Mitsubishi 45% / Pertamina 29% / KOGAS 15% / Medco Energi 11% Feed source Senoro-Toili and Matindok fields Serves Exports (Japan, South Korea) Cost $2.9B Source source Notes Started June 2015; first cargo delivered to Arun terminal Aug 2015. JV formed Dec 2007, FID Jan 2011.
	Arun LNG (export trains) Arun T1-T6	Liquefaction (export)	Retired	Indonesia	12.5	1978–2014	Lhokseumawe, Aceh Sumatra	Perta Arun Gas (PAG) 🇮🇩	Export
Capacity 12.5 (6 trains) · 6 trains (T1-T6) Direction Export Ownership Historical: Pertamina 55% / ExxonMobil 30% / JILCO 15% Feed source Arun field (depleted) Serves Exports (Japan, Korea, Taiwan) - ceased Cost — Source source Notes Closed 2014 from feed-gas depletion; site converted to import terminal (2015). Trains T2/T3/T4/T5 formally retired 2012-2013. Could be revived if South Andaman Sea gas discoveries materialise (2024 speculation).
	Abadi LNG (Masela) Masela LNG Project	Liquefaction (export)	Under construction	Indonesia	9.5	—	Masela Block, Arafura Sea (Maluku) Maluku	INPEX Masela 🇯🇵	Export
Capacity 9.5 · 1 terminal (2-train scale) Direction Export Ownership INPEX 65% / Pertamina 20% / Petronas 15% Feed source Abadi gas field (deepwater, Masela Block) Serves Exports + min 2 Mtpa domestic (PLN, Pupuk Indonesia MOUs) Cost $20.0B Source source Notes Construction launched 16 Jul 2026 (groundbreaking). VERIFIED 2026-08-12: FID target end-2026 (ANTARA, VOI) vs 2027 (GEM, still 'proposed'); INPEX confirms FID prep (permits, land, LNG marketing, financing) proceeding; investment cited Rp332 trillion (~US$20.9B); first LNG expected 2029-2030. ~US$14B project financing planned (ECAs ~$5B, intl banks $6B, Indonesian banks $3B; Mizuho advisor). CCS component; Shell exited 2023. Environmental approval Feb 2026.
	Sengkang LNG EWC Sengkang	Liquefaction (export)	Shelved	Indonesia	2.0	2023	South Sulawesi coast (near Sengkang contract area) Sulawesi	PT South Sulawesi LNG 🇬🇧	Export
Capacity 2.0 (4 x 0.5 modular) · 4 trains (T1 + T2-T4) Direction Export Ownership Energy World Corporation (100%) Feed source Sengkang gas field Serves 315 MW gas power plant + export Cost — Source source Notes Construction ~80% complete by Nov 2018, then stalled (land dispute). Identical progress language in annual reports for 8+ years; GEM classifies shelved as of Jul 2024. Most output was reserved for domestic use.
	Madura FLNG Madura Floating LNG	FLNG (liquefaction)	Shelved	Indonesia	1.3	—	Madura gas field, offshore East Java Java	Bumi Armada / Pertamina International Shipping / Davenergy Mulia Perkasa (proposed JV) 🇲🇾	Export
Capacity ~1.3 est (no published capacity; Madura Strait PSC 3M project gas scale) · 1 FLNG vessel Direction Export Ownership Proposed JV Feed source Madura gas field Serves Export Cost — Source source Notes Non-binding agreement Sep 2023; ABS design approval Oct 2023. No updates in 2+ years - inferred shelved (Aug 2025). CAPACITY ESTIMATE: no published figure; ~1.3 Mtpa derived from Madura Strait PSC gas scale.
	Arun LNG Hub / Import Terminal Arun LNG Receiving Terminal	Regasification (import)	Operating	Indonesia	3.0	2015	Lhokseumawe, Aceh Sumatra	PT Perta Arun Gas 🇮🇩	Both
Capacity 3.0 · Onshore terminal (ex-liquefaction site) Direction Both Ownership Pertamina 70% / Government of Aceh 30% Feed source LNG imports (Donggi-Senoro, Tangguh, spot) Serves Aceh/Sumatra grid; regional re-export hub Cost — Source source Notes Indonesia's top re-export hub: 2025 activity = 27 unloadings + 11 reloadings + 11 GUCD (1.499M m3 unloaded, 34.81M MMBtu). VERIFIED 2026-08-12: revitalized LNG storage tank began operations Jan 2026 (Petromindo); Arun LNG Storage & Regasification Terminal construction underway (ESDM groundbreaking). TotalEnergies terminal-use agreement 2022. Truck loading since 2020. Two extra tanks MoU with Natuna Eton Energy (2020).
	Nusantara Regas Satu (West Java FSRU) Regas Satu FSRU	FSRU (import)	Operating	Indonesia	3.0	2012	Jakarta Bay, 15 km offshore West Java Java	PT Nusantara Regas 🇮🇩	Import
Capacity 3.0 (design 3.8 / 500 MMSCFD) · 1 FSRU (ex-KHANNUR, ~125,000 m3) Direction Import Ownership Pertamina 60% / PGN 40% (vessel ex-Golar LNG Partners KHANNUR, now New Fortress Energy) Feed source LNG imports Serves West Java power plants and industry via pipeline Cost — Source source Notes Indonesia's first LNG receiving/regasification terminal (May 2012); reached full 3 Mtpa in 2016.
	Lampung FSRU Lampung LNG (PGN)	FSRU (import)	Operating	Indonesia	2.7	2014	Labuhan Maringgai, Lampung (21 km offshore, SW Sumatra) Sumatra	PT Perusahaan Gas Negara (PGN) 🇮🇩	Import
Capacity 2.7 (max send-out 360 MMSCFD) · 1 FSRU (170,000 m3) Direction Import Ownership PGN (Pertamina gas subholding); vessel Hoegh LNG PGN FSRU Lampung (170,132 cbm, 20-yr charter) Feed source LNG imports Serves South Sumatra / western Java gas supply Cost — Source source Notes Started Jul 2014. Early proposal was 'Medan FLNG' (North Sumatra), relocated. PGN planned to develop into regional gas hub (2020).
	Jawa Satu FSRU (Cilamaya) Jawa-1 FSRU	FSRU (import)	Operating	Indonesia	2.4	2021	Cilamaya, West Java Java	PT Jawa Satu Regas 🇮🇩	Import
Capacity 2.4 · 1 FSRU Direction Import Ownership Pertamina 26% / Marubeni 20% / MOL 19% / Sojitz 10% / Humpuss 25% Feed source LNG imports (ship-to-ship transfer) Serves PLTGU Jawa-1 power station (1,760 MW) - Asia's first FSRU gas-to-power project Cost $350M Source source Notes First cargo Apr 2021; power plant commercial operations Apr 2024 (MOL FSRU commercial start 29 Mar 2024). Project ~US$1.8B incl. plant; ADB/JBIC/NEXI financing. FSRU cost ~US$300-400M.
	Tanjung Benoa FSRU (Bali LNG) Karunia Dewata FSRU	FSRU (import, small-scale)	Operating	Indonesia	0.35	2016	Tanjung Benoa, Badung, Bali Bali	PT Pelindo Energi Logistik 🇮🇩	Import
Capacity 0.35 · 1 FSRU (Karunia Dewata; replaced 2016 Gas Entec FRU) Direction Import Ownership PT Pelindo Energi Logistik (Pelindo group); vessel Karunia Dewata owned by Jaya Samudra Karunia (JSK) Feed source LNG imports Serves 200 MW Benoa power plant Cost — Source source Notes World's first small-scale floating regasification unit (Mar 2016, 50 mcfd); FSRU Karunia Dewata delivered Nov 2018.
	Teluk Lamong LNG Terminal PGN Teluk Lamong	Regasification (import, small-scale)	Under construction	Indonesia	0.3	—	Teluk Lamong port, Surabaya, East Java Java	PGN (with state port companies) 🇮🇩	Import
Capacity Phase 1: 40 MMSCFD (~0.3 Mtpa) · Small-scale regas unit Direction Import Ownership PGN Feed source LNG imports Serves East Java LNG distribution Cost — Source source Notes First phase expected end-2019 (Reuters 2019), repeatedly delayed; GEM lists as in-construction (Oct 2025). VERIFIED 2026-08-12: Phase 2 planned by PT Lamong Nusantara Gas (US$40M terminal, East Java); part of PGN small-scale strategy incl. LNG-by-rail trial with KAI (2021).
	Sulawesi-Maluku Mini-LNG Terminals (PLN EPI) Ternate / Kendari / Bau-Bau / Pomalaa / Gorontalo / Ambon LNG	Regasification (import, small-scale)	Under construction	Indonesia	1.0	—	Six sites: Ternate (North Maluku), Kendari, Bau-Bau, Pomalaa (Southeast Sulawesi), Gorontalo, Ambon (Maluku) Sulawesi/Maluku	PLN EPI with private consortia (Sulawesi-Maluku: AGP Indonesia Utama, Suasa Benua Sukses, KPM Oil & Gas) 🇮🇩	Import
Capacity Small-scale (6 terminals; ~151 BBtud program gas demand ≈ 1.0 Mtpa; phase 1 gasifies 10 power plants, 660 MW) · 6 mini-LNG receiving terminals + regas units Direction Import Ownership PLN EPI + private SPC (AG&P-affiliated) Feed source LNG imports (Bontang/Tangguh supply) Serves Nickel smelters (coal-to-LNG RKEF switch) + PLN gas/diesel power plants in eastern Indonesia Cost — Source source Notes Bappenas Nickel Industry Decarbonization Roadmap names six mini-LNG terminals targeting operations by 2026 (Ternate, Kendari, Bau-Bau, Pomalaa, Gorontalo, Ambon). VERIFIED 2026-08-12: AG&P LNG 20-yr contract (Apr 2024) for Sulawesi-Maluku cluster import terminals serving 7 power plants (1,510 MW); PLN EPI SPC signed 31 Dec 2024 with AGP Indonesia Utama, Suasa Benua Sukses, KPM Oil & Gas to gasify 10 plants (660 MW) at the six sites; part of PLN EPI program converting 20 diesel plants (2,278 MW) across six clusters (Sulawesi-Maluku, Nusa Tenggara, Kalimantan, North Papua, South Papua, Nias) needing ~151 BBtud (~18 LNG cargoes/yr); consortia secured for 4 clusters as of Apr 2025 (Nias: Berkat Samudra Gemilang; Nusa Tenggara: Prima Osean Nusantara/Enviromate/APCA/KOGAS; North Papua: Pertamina International Shipping/PGN LNG/Enviromate/APCA); Sumatra and South Papua clusters still in planning.
	East Java Mini LNG Terminals Gresik Mini LNG	Regasification (import, mini)	Proposed	Indonesia	1.5	—	Gresik, East Java Java	Pertamina 🇮🇩	Import
Capacity 1.5 · Mini terminal Direction Import Ownership Pertamina Feed source LNG imports Serves East Java industry / power Cost — Source source Notes Reported by BloombergNEF Q4-2020 project database (Jan 2021); no confirmed updates since.
	Central Java Mini LNG (Cilacap) Cilacap Mini LNG	Regasification (import, mini)	Proposed	Indonesia	0.84	—	Cilacap refinery, Central Java Java	Pertamina 🇮🇩	Import
Capacity 0.84 · Mini terminal Direction Import Ownership Pertamina Feed source LNG imports Serves Cilacap refinery + local demand Cost — Source source Notes Announced May 2021 as small-scale facility at Cilacap refinery; no confirmed construction updates.
	Central Java FSRU (Cilacap) Cilacap FSRU	FSRU (import)	Cancelled	Indonesia	1.4	—	Cilacap, Central Java Java	Pertamina 🇮🇩	Import
Capacity 1.4 (200 MMSCFD; tender sought up to 1.6) · 1 FSRU (25-yr BOOT) Direction Import Ownership Pertamina 100% Feed source LNG imports Serves Central Java power/industry Cost — Source source Notes WHY CANCELLED: tender opened 2016 (Indonesia's 3rd FSRU; 25-yr BOOT, up to 1.6 Mtpa; Aug 2019 spec 200 MMSCFD / ~1.4 Mtpa) but never reached FID or construction; superseded by the smaller Central Java Mini LNG plan at the Cilacap refinery (announced May 2021, 0.84 Mtpa), which serves the same location with far lower capex; no development updates in 4+ years - inferred cancelled 2024 (GEM).
	Bojonegara LNG Receiving Terminal Bojonegara LNG	Regasification (import)	Cancelled	Indonesia	7.0	—	Bojonegara, Banten (west of Jakarta) Java	Pertamina 🇮🇩	Import
Capacity GEM total 7 Mtpa (phase 1 500 MMSCFD → phase 2 1,000 MMSCFD) · Onshore receiving terminal Direction Import Ownership Pertamina Feed source LNG imports Serves Western Java gas demand Cost — Source source Notes WHY CANCELLED (Riviera, Jul 2018): Pertamina halted the US$800M project citing slack gas demand in West Java - abundant cheap coal and slow gas infrastructure development made demand forecasts optimistic; the site sat roughly halfway between the two existing FSRUs (PGN Lampung and Nusantara Regas Jakarta Bay), only ~250 km apart, so a second land-based receiving terminal was judged redundant. JV partner was Kalla Group unit Bumi Sarana Migas (BSM; HOA Apr 2015: 4 Mtpa, operations planned 2019, pushed to 2020); JBIC was to finance, Tokyo Gas to design (2 x 160,000 m3 tanks). Pertamina left the door open: a rebound in power-sector gas demand could prompt a feasibility review.
	Porong LNG (FSRU) Porong FSRU	FSRU (import, small-scale)	Proposed (stale)	Indonesia	0.5	—	Porong, East Java Java	State plan (Pertamina/PLN) 🇮🇩	Import
Capacity no published capacity; est. ~0.5 Mtpa small-scale FSRU (≥0.3 per AFEO map inclusion) · FSRU / small-scale Direction Import Ownership State plan Feed source LNG imports Serves East Java power clusters Cost — Source source Notes Listed in Indonesia 35-GW integrated LNG infrastructure plan (AFEO, 2018). No public updates since - status unverified. CAPACITY ESTIMATE: no published figure; est. ~0.5 Mtpa small-scale FSRU.
	Nunukan LNG Nunukan LNG	Regasification (import, small-scale)	Proposed (stale)	Indonesia	0.5	—	Nunukan, North Kalimantan Kalimantan	State plan (Pertamina/PLN) 🇮🇩	Import
Capacity small-scale; related WK Nunukan mini-LNG production plan ~60 MMSCFD (PGN/KMJ) ≈ 0.5 Mtpa · Small-scale Direction Import Ownership State plan Feed source LNG imports Serves North Kalimantan power clusters Cost — Source source Notes Listed in Indonesia 35-GW integrated LNG infrastructure plan (AFEO, 2018). No public updates since - status unverified. CAPACITY ESTIMATE: no published terminal figure; ~0.5 Mtpa aligned to WK Nunukan mini-LNG production scale (~60 MMSCFD, PGN/KMJ).
	East Dara FLNG East Dara Floating LNG	FLNG (liquefaction)	Proposed (stale)	Indonesia	0.8	—	East Dara field (offshore) Offshore	State plan 🇮🇩	Export
Capacity FLNG concept sized for 110 MMSCFD plateau (BPE preliminary POD) ≈ 0.8 Mtpa · FLNG vessel Direction Export Ownership State plan Feed source East Dara gas field Serves Export / domestic Cost — Source source Notes Listed in Indonesia 35-GW integrated LNG infrastructure plan (AFEO, 2018). No public updates since - status unverified. CAPACITY: leased FLNG sized for 110 MMSCFD plateau, 18-yr life (Black Platinum preliminary POD, 2016) ≈ 0.8 Mtpa.
	Kayan LNG (mini) PT Kayan LNG Nusantara (KLN)	Liquefaction (mini)	Operating	Indonesia	0.2	2023	Tanjung Keramat, Tanah Lia, Tana Tidung Regency, North Kalimantan Kalimantan	PT Kayan LNG Nusantara 🇮🇩	Domestic
Capacity 25 MMSCFD design ≈ 0.2 Mtpa (first mini-LNG module in Indonesia); 22 MMSCFD contracted feed · 1 skid-mounted mini plant (train 1) Direction Domestic Ownership Kayan Patria Pratama Group (holding) Feed source Simenggaris block (JOB Pertamina-Medco E&P Simenggaris: PHE Simenggaris + Medco E&P Simenggaris); 22 MMSCFD contracted, actual supply 14-15.5 MMSCFD (2024) Serves PLN Tarakan power plant (first LNG regas in Tarakan); PGN Group retail LNG (3-5 BBTUD) for Kalimantan/eastern Indonesia Cost — Source source Notes Indonesia's first mini LNG plant, inaugurated 30 Apr 2023 (ESDM). VERIFIED 2026-08-12: constructed Jan 2020-Nov 2023 by ENN Natural Gas / Xindi Energy Engineering (skid-mounted technology; phase I completed per ENN HK listing disclosure Jun 2025); first LNG cargo sail-away Nov 2023; supplies PLN Tarakan regasification (first LNG regasification success in Tarakan, ~Oct 2025, Petromindo) and PGN Group retail market (3-5 BBTUD PJB LNG); requested increased feed (2024) as actual 14-15.5 MMSCFD fell short of the 22 MMSCFD contracted with JOB Pertamina-Medco E&P Simenggaris.
	SAG Mini LNG Plant (Tuban) PT Sumber Aneka Gas Mini LNG	Liquefaction (mini)	Operating	Indonesia	0.06	2026	Tuban, East Java Java	PT Sumber Aneka Gas 🇮🇩	Domestic
Capacity max LNG production 55,300 t/yr ≈ 0.06 Mtpa (ESDM 2026); multi-product: LNG, CNG, LPG 9,800 t/yr, condensate 19,600 bbl/yr, liquid CO2 21,000 t/yr · 1 mini plant Direction Domestic Ownership PT Sumber Aneka Gas (SAG) Feed source Sumber Field (PT Pertamina Hulu Energi Tuban) Serves East Java domestic gas/LNG distribution Cost — Source source Notes VERIFIED 2026-08-12: inaugurated by Energy Minister Bahlil Lahadalia (MEMR) 26 Jun 2026 as part of domestic gas optimization push (ESDM official).
	HUMI Mini LNG Plant (Bojonegoro) OTSI / Hutama Metana Perkasa Mini LNG	Liquefaction (mini)	Under construction	Indonesia	0.04	—	Bojonegoro, East Java Java	PT OTS Internasional (OTSI), unit PT Hutama Metana Perkasa 🇮🇩	Domestic
Capacity 5 MMSCFD processing capacity ≈ 0.04 Mtpa (HUMI 2026) · 1 mini plant Direction Domestic Ownership PT Humpuss Maritim Internasional Tbk (HUMI) Feed source East Java gas sources Serves Domestic small-scale LNG supply Cost — Source source Notes VERIFIED 2026-08-12: groundbreaking 12 Mar 2026 (LNG Prime, HUMI) - small-scale LNG processing facility supporting national energy security.
	Bintulu LNG Terminal Malaysia LNG (MLNG) / Petronas Bintulu LNG Complex / PETRONAS LNG Complex (PLC)	Liquefaction (export)	Operating	Malaysia	28.8	1983	Bintulu, Sarawak Borneo	Petronas (Petronas LNG / MLNG) 🇲🇾	Export
Capacity ~30 Mtpa per Petronas (GEM train sum: Satu 8.4 + Dua 9.6 + Tiga 7.2 + Train 9 3.6 = 28.8) · 9 trains (MLNG Satu 3, MLNG Dua 3, MLNG Tiga 2, Train 9 1) Direction Export Ownership Per train: MLNG Satu Petronas 90% / Mitsubishi 5% / State of Sarawak 5%; MLNG Dua Petronas 80% / Mitsubishi 10% / Sarawak 10%; MLNG Tiga Petronas 60% / Sarawak 25% / PTT 10% / Diamond Gas (Mitsubishi) 5%; Train 9 Petronas 70% / Sarawak 10% / ENEOS 10% / PTT 10% Feed source Offshore Sarawak gas (Central Luconia fields, Petronas Carigali) plus Sabah gas via Sabah-Sarawak Gas Pipeline (SSGP); new Jerun field supply began ~2025-26 Serves Japan, South Korea, China, Taiwan; domestic Peninsular Malaysia via regasification terminals Cost — Source source Notes Petronas' 9-train Bintulu complex comprises MLNG Satu (3x2.7 Mtpa, first LNG Jan 1983), MLNG Dua (3x3.2 Mtpa, 1995), MLNG Tiga (2x3.6 Mtpa, 2003) and Train 9 (3.6 Mtpa, commissioned 2016, commercial 2017); GEM splits these into four terminal pages (Satu Malaysia Terminal, Dua Malaysia LNG Terminal, Tiga Malaysia LNG Terminal, Malaysia LNG Terminal Train 9). MLNG Dua was shut from Oct 2022 (SSGP pipeline leak) and brought back online May 2024; Petronas confirmed Bintulu's first Jerun-field gas supply in early 2026 (LNG Prime). VERIFIED 2026-08-12 - complex operating with all 9 trains, per GEM (pages last updated Aug 2026) and Petronas 'nearly 30 Mtpa' capacity statement; Dua recovered from the 2022-24 outage.
	Petronas FLNG Satu PFLNG Satu / PFLNG 1 / Malaysia FLNG Terminal 1	FLNG (liquefaction)	Operating	Malaysia	1.2	2017	Kebabangan (KBB) cluster, offshore Sabah (South China Sea); originally Kanowit field offshore Sarawak	Petronas 🇲🇾	Export
Capacity 1.2 Mtpa Direction Export Ownership Petronas 100% Feed source Kanowit field (offshore Sarawak) 2016-19; Kebabangan (KBB) cluster offshore Sabah since 2019 Serves LNG exports (Japan/Korea buyers) and domestic market Cost — Source source Notes World's first floating LNG vessel, built by DSME (Okpo), delivered May 2016; first LNG production Dec 2016 at Kanowit and first cargo April 2017, making it the world's first operational FLNG. Relocated in 2019 (world's first FLNG relocation) to the Kebabangan (KBB) cluster offshore Sabah where it remains. VERIFIED 2026-08-12 - GEM lists Satu FLNG Terminal as operating, 1.2 Mtpa, operating year 2017, 100% Petronas (page updated Aug 2026); no relocation or retirement reported as of mid-2026.
	Petronas FLNG Dua PFLNG Dua / PFLNG 2 / Rotan FLNG Project / Sabah FLNG Terminal	FLNG (liquefaction)	Operating	Malaysia	1.5	2021	Rotan gas field, deepwater offshore Sabah (South China Sea)	Petronas 🇲🇾	Export
Capacity 1.5 Mtpa Direction Export Ownership Petronas 100% Feed source Rotan field, deepwater (about 1,300-1,500 m water depth) offshore Sabah Serves LNG exports (domestic and international buyers) Cost — Source source Notes Petronas' second FLNG, built by Samsung Heavy Industries; FID taken Feb 2014 and the vessel was originally targeted for 2018-2020 start-up. Started LNG production in February 2021 at the Rotan field, making it the world's first deepwater FLNG. VERIFIED 2026-08-12 - GEM lists Dua FLNG Terminal as operating, 1.5 Mtpa, operating year 2021, 100% Petronas (page updated Jul 2026); no status change reported as of mid-2026.
	Petronas FLNG Tiga PFLNG Tiga / PFLNG 3 / Tiga FLNG Terminal	FLNG (liquefaction)	Under construction	Malaysia	2.0	—	Near-shore waters of Sabah (construction site onshore Sabah) Borneo	Petronas 🇲🇾	Export
Capacity 2.0 Mtpa · 2 trains Direction Export Ownership Petronas 60%; SMJ Sdn Bhd (Sabah state) 25% (stake bought Nov 2025); PTT 10%; Mitsubishi 5% Feed source Sabah gas resources (near-shore FLNG fed from Sabah fields; GEM notes facility powered by a nearby gas-fired power station) Serves LNG exports Cost $2.0B Source source Notes Petronas' third FLNG (minimum 2 Mtpa, two trains), developed near-shore in Sabah with JGC Corp and Samsung Heavy Industries as EPC contractors; FEED awarded Dec 2021, FID Dec 2022, construction groundbreaking April 2024, commercial operations targeted for H2 2027. Cost reported around US$2 billion (GEM: US$2.02bn); Petronas sought a US$1bn+ loan in 2025 and SMJ bought a 25% stake in Nov 2025. VERIFIED 2026-08-12 - GEM lists Tiga FLNG Terminal as in construction with 2027 target (page updated Jul 2026), corroborated by The Star (Apr 2024 groundbreaking) and TradingView/Reuters (Nov 2025 SMJ stake).
	Sungai Udang Regasification Terminal RGTSU / Melaka FSRU / Regasification Terminal Sungai Udang / Malacca FLNG	FSRU (import)	Operating	Malaysia	3.8	2013	Sungai Udang Port, Melaka (offshore jetty) Peninsular Malaysia	Petronas Gas Berhad (Regas Terminal Sungai Udang) 🇲🇾	Import
Capacity 500 mmscfd regasification (PGB) Direction Import Ownership Petronas 100% (via Petronas Gas Berhad) Feed source Imported LNG (domestic and third-party TPA cargoes since 2018) Serves Peninsular Malaysia gas grid (PGU) - power plants and industry; small-scale LNG bunkering Cost — Source source Notes Malaysia's first LNG import terminal, commissioned in 2013 (FID 2012), using MISC FSUs Tenaga Satu and Tenaga Empat with regasification on an island jetty - the world's first LNG regasification unit on an island jetty. PGB began commercial operation in Q2 2013 and opened the terminal to third-party access in 2018 (first third-party cargo). VERIFIED 2026-08-12 - GEM lists Melaka FSRU as operating, 3.8 Mtpa, operating year 2013, 100% Petronas (page updated Oct 2025); PGB confirms 500 mmscfd capacity and continuing operation.
	Pengerang Regasification Terminal RGTP / Pengerang Johor LNG Terminal / Pengerang LNG Terminal	Regasification (import)	Operating	Malaysia	3.5	2017	Pengerang, Johor Peninsular Malaysia	Petronas Gas Berhad (via Pengerang LNG (Two) Sdn Bhd) 🇲🇾	Import
Capacity 490 mmscfd regasification (PGB) Direction Import Ownership Petronas 65%; Dialog Group 25%; Government of Johor 10% Feed source Imported LNG (incl. third-party TPA cargoes); also LNG transshipment/bunkering services Serves Pengerang Integrated Complex (PIC/RAPID), Pengerang cogeneration plant and PGU grid; LNG transshipment hub Cost $594M Source source Notes Onshore regasification terminal proposed 2011, construction from 2014, first commercial cargo November 2017 (commissioning cargoes Sep-Oct 2017); deepwater jetty enables large LNG carriers and bulk-breaking/building for crude, products and LNG. MISC converted LNG carrier Puteri Delima Satu into an FSU for the terminal (commercially operational Q2 2025, 20-year term) for LNG transshipment. VERIFIED 2026-08-12 - GEM lists Pengerang Johor LNG Terminal as operating, 3.5 Mtpa, cost US$594m, owners Petronas 65%/Dialog 25%/Johor 10% (page updated Aug 2026); MARC (Sep 2024) confirms PLNG2 regas supply to PIC since 2017.
	Pengerang RGT2 (Phase 2) Pengerang LNG (Two) / RGT-2 / Pengerang Phase 2 expansion	Regasification (import)	Operating	Malaysia	3.5	2025	Pengerang Integrated Complex, Pengerang, Johor Peninsular Malaysia	Petronas Gas Berhad (Pengerang LNG (Two) Sdn Bhd) 🇲🇾	Import
Capacity 2 x 200,000 m3 LNG tanks; FSU Puteri Delima Satu (170,000 m3) Direction Import Ownership Petronas Gas Berhad 65%; Dialog Group 25%; Government of Johor 10% (PLNG2SB) Feed source Imported LNG; FSU used for LNG transshipment by the Petronas group Serves RAPID/PIC, Pengerang cogeneration plant and PGU grid; LNG transshipment Cost — Source source Notes Phase 2 (RGT2) of the Pengerang regasification complex, developed by Pengerang LNG (Two) Sdn Bhd (PLNG2SB, PGB subsidiary): two 200,000 m3 LNG tanks (roof-raising completed 2021) plus jetty modification for MISC FSU 'Puteri Delima Satu', which became commercially operational in Q2 2025 under a 20-year contract. PGB's Integrated Report 2025 lists completion of the LNG storage expansion at Regasification Terminal Pengerang as a 2025 highlight. VERIFIED 2026-08-12 - storage/FSU phase operating per MISC (Q2 2025 commercial FSU) and PGB IR2025; GEM's Pengerang page (Aug 2026) notes the FSU expected operational H1 2025; full RGT2 regasification send-out has not been separately announced in press.
	Kemaman LNG Terminal RGT Kemaman / E&H Energy Kemaman LNG import terminal	Regasification (import)	Proposed	Malaysia	3.6	—	Kemaman, Terengganu Peninsular Malaysia	E&H Energy Sdn Bhd 🇲🇾	Import
Capacity terminal capacity not disclosed; 3.6 Mtpa LNG supply deal signed with Amigo LNG (Mexico) — used as design anchor Direction Import Ownership E&H Energy Sdn Bhd 100% Feed source Imported LNG (Amigo LNG/FLNG Mexico, 20-year supply deal starting Q3 2027) Serves East-coast Peninsular Malaysia industry, power plants and data centres (via PGU pipeline, virtual pipeline trucks or East Coast Rail Link) Cost — Source source Notes Independent multi-user LNG import/regasification terminal proposed by E&H Energy (reported Feb 2025); FID was targeted for end-2025, and in 2026 the Terengganu state government said the project was on track and awaiting the Letter to Proceed targeted for Q2 2026. Operations are now expected in Q4 2029, with supply from Mexico's Amigo FLNG Terminal (3.6 Mtpa contract). VERIFIED 2026-08-12 - GEM lists Kemaman LNG Terminal as proposed, 100% E&H Energy (page updated Aug 2026); feasibility questioned by some analysts citing lack of demand guarantees, but project remains active, not shelved.
	Lumut LNG Terminal RGT-3 / Lumut FSRU / Petronas Gas third LNG import terminal	FSRU (import)	Proposed	Malaysia	3.8	—	Lumut, Perak (Manjung) Peninsular Malaysia	Petronas Gas Berhad 🇲🇾	Import
Capacity 500 mmscfd regasification ≈ 3.8 Mtpa; 170,000 m3 FSRU storage (MISC FSRU being built by Samsung Heavy Industries) Direction Import Ownership Petronas Gas Berhad (Petronas) with TNB unit Integrax - partnership pact signed June 2026 Feed source Imported LNG via FSRU (Malaysia's first FSRU-based import terminal) Serves Northern Peninsular Malaysia (gas demand equivalent to ~3.5 GW of power generation) via PGU pipeline Cost — Source source Notes Malaysia's third regasification terminal (RGT-3), mandated to Petronas Gas by the Ministry of Economy; concept announced June 2025 at Energy Asia and confirmed as an FSRU project in Lumut, Perak. Petronas Gas and TNB's Integrax signed a partnership pact in June 2026, and MISC's FSRU (Samsung Heavy Industries hull, GTT tanks) is being fabricated; commercial operations targeted for Q2 2029. VERIFIED 2026-08-12 - GEM lists Lumut LNG Terminal as proposed, proposal year 2025 (page updated Jun 2026), corroborated by Petromindo (May 2026) and LNG Prime (May 2026 jetty deal); pre-FID, under active development, not shelved.
	RGT Yan LNG Terminal Yan Kedah FSRU / Pulau Bunting LNG terminal / Gas Malaysia-Tokyo Gas-VTTI FSRU	FSRU (import)	Proposed	Malaysia	6.0	—	Offshore west of Pulau Bunting, Yan, Kedah Peninsular Malaysia	Gas Malaysia Berhad (with Tokyo Gas and VTTI) 🇲🇾	Import
Capacity up to 6 Mtpa via FSRU; cost up to US$765m (Gas Malaysia project scope) Direction Import Ownership Gas Malaysia 70%; Tokyo Gas 15%; VTTI 15% (JDA June 2026); original developers MMC Group and SKS Corp (Pulau Bunting Integrated Development) Feed source Imported LNG via offshore FSRU Serves Pulau Bunting 1.6 GW power station and northern Peninsular Malaysia industry Cost $765M Source source Notes LNG regasification terminal within the RM14.4bn Pulau Bunting Integrated Development (MMC Group and SKS Corp, launched Sept 2022) in Yan, Kedah. Gas Malaysia signed a Joint Development Agreement with Tokyo Gas and VTTI (70:15:15) in June 2026 for an FSRU-based terminal with up to 6 Mtpa capacity; a US$765m facility was reported approved in March 2026 and Technip Energies secured an engineering contract in August 2026. VERIFIED 2026-08-12 - GEM lists RGT Yan LNG Terminal as proposed (page updated Aug 2026), corroborated by Forbes (Mar 2026 approval), Gas Malaysia (Jun 2026 JDA) and LNG Prime (Aug 2026 Technip Energies contract); actively progressing toward FID.
	Brunei LNG Terminal BLNG / Lumut LNG / Brunei LNG Sdn Bhd plant	Liquefaction (export)	Operating	Brunei	7.2	1972	Lumut, Belait District Borneo	Brunei LNG Sdn Bhd 🇧🇳	Export
Capacity 5 trains x 1.4 Mtpa nominal; up to ~7.7 Mtpa output capability per BLNG Direction Export Ownership Government of Brunei 50%; Shell Overseas Trading Ltd 25%; Mitsubishi Corp 25% (no other shareholders - 'Chengdong' stake unverified/nonexistent) Feed source Offshore Brunei gas from Brunei Shell Petroleum (BSP) fields and the Block B Joint Venture (BBJV); future Kelidang (CA-2) deepwater backfill project (~390 mmscfd, ~2030) will supply new feedstock Serves Japan and South Korea (most shipments); also China and regional buyers Cost — Source source Notes One of the world's oldest LNG plants (Asia-Pacific's first), producing since late 1972 with first exports to Japan in 1973; GEM records operating year 1973, capacity 7.2 Mtpa. The plant underwent a B$500m rejuvenation programme in 1993; BLNG states current output capability of up to 7.7 Mtpa. Ownership is Government of Brunei 50%, Shell 25%, Mitsubishi 25%; the proposed Kelidang (CA-2) gas development (Petronas Carigali Brunei 45%, Shell 20%, others) is being developed to supply new feedstock from ~2030, extending plant life - no new Brunei LNG train, FLNG or terminal project is active. VERIFIED 2026-08-12 - GEM lists Brunei LNG Terminal as operating, 7.2 Mtpa, operating year 1973 (page updated Aug 2026); BLNG site confirms up to 7.7 Mtpa output; plant suffered unplanned downtime in June 2025 (tender canceled, normalization phase) but remained operating into 2026.
	Map Ta Phut LNG Terminal 1 Map Ta Phut LNG Terminal; Rayong LNG Terminal	Regasification (import)	Operating	Thailand	11.5	2011	Map Ta Phut, Rayong	PTT LNG Co Ltd 🇹🇭	Import
Capacity 10 Mtpa base (2017) + 1.5 Mtpa expansion (2019) Direction Import Ownership PTT LNG Co Ltd (100%), parent PTT PCL Feed source Qatar, Malaysia Serves Thailand national gas grid / power sector Cost $930M Source source Notes Onshore regasification terminal commissioned 2011 at 5 Mtpa (US$930m), expanded to 10 Mtpa in 2017 and +1.5 Mtpa in 2019, total 11.5 Mtpa, owned and operated by PTT LNG Co Ltd (PTT PCL 100%); most imported gas comes from Qatar and Malaysia. PTT tested LNG reloading at the terminal in 2020 and the first reloaded/small-scale cargo left in January 2021. VERIFIED 2026-08-12: GEM wiki (updated 2026-08-12) lists the 10 Mtpa base unit and the 1.5 Mtpa expansion (US$28m) both as operating with total terminal capacity 11.5 Mtpa.
	Map Ta Phut LNG Terminal 2 (Nong Fab) Nong Fab LNG Terminal; Map Ta Phut LNG Terminal 2	Regasification (import)	Operating	Thailand	7.5	2023	Map Ta Phut (Nong Fab), Rayong	PE LNG Co Ltd 🇹🇭	Import
Capacity 7.5 Mtpa Direction Import Ownership PE LNG Co Ltd — EGAT 50% / PTT PCL 50% Feed source — Serves Thailand gas grid (EGAT power generation) Cost $1.1B Source source Notes Second Thai LNG import terminal at Nong Fab, adjacent to Terminal 1 in Rayong; 7.5 Mtpa capacity built at ~US$1,116.5m (THB 38.5bn) by the PE LNG Co Ltd joint venture of EGAT (50%) and PTT (50%). Received its first commissioning cargo in June 2022 and entered operation in 2023. VERIFIED 2026-08-12: GEM wiki (updated 2026-08-11) lists the terminal as operating with 7.5 Mtpa capacity and 2023 as operating year; Bangkok Post (Oct 2025) confirms the PTT-EGAT Nong Fab terminal is in service at 7.5 Mtpa.
	Map Ta Phut LNG Terminal 3 MTP3; Gulf MTP LNG Terminal; Map Ta Phut Industrial Port Development Phase 3	Regasification (import)	Proposed	Thailand	10.8	—	Map Ta Phut, Rayong	Gulf MTP LNG Terminal Co Ltd (GMTP) 🇹🇭	Import
Capacity Phase I 5 Mtpa + Phase II 5.8 Mtpa (planned) Direction Import Ownership Gulf MTP LNG Terminal Co Ltd — Gulf Energy Development PCL 70% / PTT PCL 30% Feed source — Serves Thailand gas grid (Gulf Energy gas business) Cost $1.8B Source source Notes Thailand's third LNG import terminal (MTP3), part of the Map Ta Phut Industrial Port Phase 3 PPP; planned 10.8 Mtpa in two phases (5 + 5.8 Mtpa) at up to US$1.83bn (THB 60bn). FID taken in 2025; EPCC contract for the superstructure was signed with the POSCO E&C-CAZ consortium in July 2025, with construction scheduled to start Q4 2025 and commercial operations targeted Q1 2029. VERIFIED 2026-08-12: GEM wiki (updated 2026-08-12) still classifies the terminal as proposed (construction year listed 2025); no 2026 news confirming an actual construction start was found, so status is kept as proposed.
	MCV LNG Terminal Thanlyin LNG Terminal; Thilawa LNG Terminal; Thilawa LNG	FSRU (import)	Operating (partial)	Myanmar	0.4	2020	Thilawa port, Thaketa, Yangon	MCV Terminal Ltd 🇨🇳	Import
Capacity 0.4 Mtpa Direction Import Ownership CNTIC VPower International Terminal (Yangon) Ltd 56% / Myanmar Business Consultant Group Ltd 44% Feed source Malaysia (Bintulu trial cargo Nov 2025) Serves Thanlyin and Thaketa LNG-to-power plants (Yangon) Cost — Source source Notes Floating-storage LNG import terminal at Thilawa port, Yangon, opened June 2020 to fuel the 477 MW Thaketa and 350 MW Thanlyin power plants; JV of CNTIC VPower (56%) and Myanmar Business Consultant Group (44%), operated by MCV Terminal Ltd. The CNTIC VPower FSU left in March 2023 and the terminal sat mothballed after 2021 post-coup foreign-exchange shortages. VERIFIED 2026-08-12: GEM wiki (updated 2026-07-20) still lists it as mothballed, but Reuters/Kpler (Dec 2025) confirm Myanmar resumed LNG imports in Nov 2025 — the Dapeng Princess carried a Bintulu cargo to the Thilawa FSU, restarting the Thanlyin (200 MW) and Thaketa (300 MW) plants at 150 MW with a 500 MW target and ~0.4 Mt imports expected in 2026, so the terminal is partially back in service.
	Mee Laung Gyaing FSRU Mee Lin Laung LNG Terminal	FSRU (import)	Shelved	Myanmar	4.5	—	Mata, Ayeyawady	—	Import
Capacity no published terminal capacity; est. ~4.5 Mtpa for 1,390 MW plant (Kanbauk convention: 4 Mtpa / 1,230 MW) Direction Import Ownership Supreme Trading Co Ltd (Supreme Group) / Zhefu Holding Group Co Ltd (China) Feed source — Serves Mee Laung Gyaing power station (1,390 MW, planned) Cost — Source source Notes FSRU-based LNG import terminal proposed at Mata, Ayeyawady, integrated with a 1,390 MW LNG-to-power plant; developers were Supreme Trading Co Ltd of Supreme Group and China's Zhefu Holding Group. Myanmar's junta approved the ~US$2.5bn project (plant plus infrastructure) in May 2021, but no construction or meaningful updates followed. VERIFIED 2026-08-12: GEM wiki (updated 2026-08-11) lists status 'shelved (inferred 2 y)' with inactive year 2022 — shelved because of the 2021 coup, sanctions and collapsed project financing; no 2026 revival reported. Note: Supreme Group's Myanmar LNG involvement was this project; no Shell role in any Myanmar LNG terminal was verified.
	Ahlone LNG Terminal Yangon LNG Terminal	FSRU (import)	Cancelled	Myanmar	4.0	—	Ahlone/Dala, Yangon	Toyo Thai Power Myanmar (TTCL unit) 🇹🇭	Import
Capacity original MOEE tender concept up to 4 Mtpa (2017, 1,250 MW plant); later TTCL 365 MW project — terminal capacity not separately published Direction Import Ownership TTCL (Thailand) 100% Feed source — Serves Ahlone CCPP / 365 MW LNG-to-power project (planned) Cost — Source source Notes Proposed LNG import terminal by Thailand's TTCL for a 365 MW LNG-to-power project at Ahlone/Dala, Yangon; the original concept was an FSRU on the Yangon River, with a PPA signed in January 2021; Total (TotalEnergies) had been in talks in 2016-2017 on Myanmar's first LNG terminal. TTCL shelved the project in 2022 and no updates followed. VERIFIED 2026-08-12: GEM wiki (updated 2026-08-12) lists status 'cancelled (inferred 4 y)' with inactive year 2024 — presumed cancelled after two-plus years without updates and post-coup conditions.
	Kanbauk FSRU	FSRU (import)	Cancelled	Myanmar	4.0	—	Kanbauk, Tanintharyi	—	Import
Capacity 4.0 Mtpa Direction Import Ownership Siemens Myanmar / TotalEnergies Gas & Power (TotalEnergies exited 2022) Feed source — Serves Kanbauk power station (1,230 MW, planned) Cost $2.1B Source source Notes FSRU-based LNG import terminal (4 Mtpa, ~US$2.1bn) proposed at Kanbauk, Tanintharyi, to fuel the 1,230 MW Kanbauk power station; developed by a TotalEnergies-Siemens consortium with Yadana partners (Chevron, PTTEP, MOGE). There were no updates after 2019 and TotalEnergies withdrew from Myanmar in 2022. VERIFIED 2026-08-12: GEM wiki (updated 2026-07-20) lists status 'cancelled (inferred 4 y)' — cancelled because of the 2021 coup, stalled talks and TotalEnergies' 2022 exit; coords are approximate (offshore FSRU site).
	Cambodia LNG Project	Regasification (import)	Cancelled	Cambodia	3.6	—	Phnom Penh	—	Import
Capacity Phase 2 FSRU 0.6 Mtpa + Phase 3 terminal 3 Mtpa (planned) Direction Import Ownership Cambodia Natural Gas Corp (CNGC) 100% Feed source China (ISO-tank trial import, Jan 2020) Serves Phnom Penh gas/power market (planned) Cost — Source source Notes Three-phase Phnom Penh LNG scheme by Cambodia Natural Gas Corp: container/ISO-tank imports (first cargo from China January 2020), then a chartered 0.6 Mtpa FSRU (2021-2023) and a 3 Mtpa onshore import terminal (2024-2029). FSRU and terminal plans stalled on COVID-19 and financing; no updates since July 2021, when CNOOC Gas & Power was reportedly weighing a stake. VERIFIED 2026-08-12: GEM wiki (updated 2026-08-11) lists phases 2-3 as 'cancelled (inferred 4 y)' with inactive year 2025 — inferred cancelled after 4+ years without updates.
	Botum Sakor LNG Terminal	FSRU (import)	Under construction	Cambodia	1.1	—	Botum Sakor, Koh Kong	—	Import
Capacity 1.1 Mtpa Direction Import Ownership Government of Cambodia (per GEM); developed by Royal Group's Botum Sakor Energy Feed source — Serves Botum Sakor power station (900 MW, under construction) Cost $1.3B Source source Notes FSRU-based LNG import terminal at Botum Sakor, Koh Kong, to supply the Royal Group's 900 MW gas-fired power station that replaced a scrapped coal plant; GEM lists 1.1 Mtpa capacity and ~US$1.342bn cost for the terminal-plus-plant development. LNG Prime (Feb 2026) reports HD Hyundai Heavy Industries won ~US$574m contracts to build an FSRU and a dedicated LNG carrier for the project, and Cambodia's Ministry of Mines and Energy targets Phase 1 (450 MW) by end-2026 and Phase 2 (450 MW) in 2027. VERIFIED 2026-08-12: GEM wiki (updated 2026-08-12) still lists the terminal as proposed, but the placed FSRU order and ongoing power-plant construction (O&M contract with SN Power, Jan 2026) make 'under construction' the accurate mid-2026 status.
	Thi Vai LNG LNG Vietnam Thi Vai Terminal	Regasification (import)	Operating	Vietnam	1.0	2023	Vung Tau Port, Ba Ria-Vung Tau Province	PV Gas (via LNG Vietnam JV) 🇻🇳	Import
Capacity 1 Mtpa nameplate Phase 1; regas send-out uprated to ~2.5 Mtpa (288 t/h) Apr 2026; Phase 2 expansion to 3 Mtpa total planned; 14 Mm3/d FSRU planned 2026-2029 · 1 phase operating; Phase 2 proposed Direction Import Ownership LNG Vietnam JV: PetroVietnam Gas (PV Gas) 51%, Bitexco 39%, Tokyo Gas 10% Feed source Imported LNG (first cargo July 2023) Serves Nhon Trach 3 & 4 LNG power plants (PV Power, Dong Nai); EVN peak power Cost $285M Source source Notes Vietnam's first LNG import terminal: Samsung C&T-built, first cargo July 2023, inaugurated Oct 2023. Phase 1 nameplate is 1 Mtpa, but PV Gas uprated regasification send-out to 288 t/h (~2.5 Mtpa) in April 2026 (DNV-verified) to meet peak power demand. Expansion to 3 Mtpa total is proposed (EPC expected late 2025, none announced as of mid-2026) and an FSRU (14 Mm3/d, ~3.76 Mtpa) is planned at Vung Tau port 2026-2029. VERIFIED 2026-08-12: operating; GEM page updated 11 Aug 2026 documents the Apr 2026 uprate and pending Phase 2/FSRU.
	Cai Mep LNG Hai Linh LNG Terminal	Regasification (import)	Operating	Vietnam	3.0	2025	Phu Long, Vung Tau, Ba Ria-Vung Tau Province	Cai Mep LNG (AG&P LNG) 🇵🇭	Import
Capacity 3 Mtpa initial, expandable to 6 Mtpa; 3 onshore tanks (220,000 m3 storage) · 3 tanks Direction Import Ownership Cai Mep LNG Company: AG&P LNG (Nebula Energy) agreed 21 Apr 2026 to acquire 100% from Hai Linh (previously 49% AG&P / 51% Hai Linh since Mar 2024) Feed source Imported LNG (first commissioning cargo from Russia's Sakhalin 2, May 2025) Serves Hiep Phuoc power station; Phu My industrial zone and 3.9 GW Phu My power complex Cost $500M Source source Notes Originally proposed as Hai Linh LNG in the late 2000s, revived in 2019 with USTDA feasibility study; Nebula Energy's AG&P LNG bought 49% in March 2024. Terminal received its commissioning cargo in May 2025 and began operating, becoming Vietnam's second operating import terminal; AG&P announced on 21 Apr 2026 an agreement to take 100% ownership (pending regulatory approval). VERIFIED 2026-08-12: operating since Q3 2025 per AG&P press release 21 Apr 2026 and GEM page (Mar 2026 snapshot).
	Son My LNG	Regasification (import)	Proposed	Vietnam	3.6	—	Son My, Ham Tan District, Binh Thuan Province	Son My LNG Terminal LLC 🇻🇳	Import
Capacity Phase 1 3.6 Mtpa (GEM tracker table lists 2.4 Mtpa/phase, 4.8 Mtpa total); Phase 2 to 6 Mtpa total 2027-2030; potential long-run 10 Mtpa · 2 phases Direction Import Ownership Son My LNG Terminal LLC: PV Gas 61%, AES 39% Feed source Imported LNG Serves Son My I and Son My II power stations (Binh Thuan) Cost $1.4B Source source Notes US$1.4 billion terminal by Son My LNG Terminal LLC (PV Gas 61%, AES 39%); JV agreement signed Sept 2021 and exchanged August 2025. Investment policy approval granted by Binh Thuan People's Committee July 2023; US$3.2 billion EXIM/DFC financing discussed for terminal plus Son My II power plant. Latest planned start is Q1 2027 but construction had not begun as of mid-2026. VERIFIED 2026-08-12: proposed/pre-construction per GEM page updated 12 Aug 2026.
	Bac Lieu LNG Bac Lieu LNG-to-Power Terminal	FSRU (import)	Proposed	Vietnam	2.0	—	Hoa Binh, Bac Lieu Province (Mekong Delta)	Bac Lieu LNG Power Company Ltd 🇸🇬	Import
Capacity 2 Mtpa floating LNG import terminal (FSRU) Direction Import Ownership Bac Lieu LNG Power Company Ltd — Delta Offshore Energy (DeltaOE), Singapore Feed source Imported LNG Serves Bac Lieu 3,200 MW LNG-to-power plant Cost — Source source Notes Correction to task brief: this project is NOT Novatek-led (Novatek's Vietnam project is Ca Na, Ninh Thuan). Bac Lieu is Delta Offshore Energy's 2 Mtpa floating import terminal feeding a 3.2 GW power plant; announced Sept 2019, construction once targeted 2024 never started amid unresolved PPA and government-guarantee issues. Listed in the April 2025 PDP8 amendment; on 10 Mar 2026 Bac Lieu LNG Power Co and EVNNPT signed the grid-connection principle agreement (500 kV Bac Lieu-Thot Not line) targeting phased COD 2030. VERIFIED 2026-08-12: proposed/pre-FID, no construction, per GEM page updated 11 Aug 2026.
	Quynh Lap LNG	Regasification (import)	Under construction	Vietnam	1.15	—	Quynh Lap commune, Hoang Mai township, Nghe An Province	PV Power (consortium lead) 🇻🇳	Import
Capacity 1.15 Mtpa; receiving terminal for ~100,000 DWT carriers Direction Import Ownership Consortium approved 12 Feb 2026 (Decision 26/QD-UBND): PetroVietnam Power (PV Power), SK Innovation, Nghe An Sugar (NASU) Feed source Imported LNG Serves Quynh Lap power station (2 x CCGT, 1,500 MW) Cost — Source source Notes ~US$2.25 billion LNG-to-power project in PDP8; Nghe An province approved the PV Power-SK Innovation-NASU consortium on 12 Feb 2026 and construction of technical infrastructure began 18 May 2026 (Korea Herald, LNG Prime, VnEconomy). The gas receiving terminal (~1.15 Mtpa, 100,000 DWT) is part of the integrated project targeting commercial operation by December 2030. VERIFIED 2026-08-12: under construction (groundbreaking May 2026) per GEM page updated 11 Aug 2026; GEM's tracker status column still reads 'proposed' pending terminal-specific works.
	Hai Lang LNG	Regasification (import)	Proposed	Vietnam	1.5	—	Hai Lang District, Quang Tri Province	—	Import
Capacity 1.5 Mtpa phase 1; receives 170,000-226,000 m3 LNG carriers Direction Import Ownership T&T Group 40%; KOGAS 20%; Hanwha Energy 20%; KOSPO 20% Feed source Imported LNG Serves Hai Lang power station (1.5 GW phase 1) Cost — Source source Notes LNG-to-power project approved by Quang Tri People's Committee Oct 2021; consortium planned EPC Q4 2025, construction from Jan 2026 and COD by 31 Dec 2029, but as of July 2026 there was no clear evidence construction had begun. Project has faced delays and feasibility controversy (SFOC warned of a potentially overpriced stranded asset). VERIFIED 2026-08-12: proposed — GEM page updated 12 Aug 2026 reclassified from 'under construction' to proposed.
	Quang Ninh LNG Cam Pha LNG Terminal	Regasification (import)	Proposed	Vietnam	1.2	—	Cam Pha city, Quang Ninh Province	Quang Ninh LNG Power JSC 🇯🇵	Import
Capacity 1.2 Mtpa planned; JOGMEC 2025 lists planned start year 2029 Direction Import Ownership Quang Ninh LNG Power JSC — Marubeni, Tokyo Gas, PetroVietnam (JV established Nov 2022) Feed source Imported LNG Serves Quang Ninh Combined Cycle power station (1,500 MW) Cost — Source source Notes First northern-Vietnam LNG-to-power project (~US$2 billion); site clearance in Cam Pha pursued in 2025 and The Investor (Aug 2025) reported local authorities would grant developers land. Prime Minister Chinh requested construction start in Q2/Q3 2025, but no confirmed construction start as of mid-2026. VERIFIED 2026-08-12: proposed per GEM page updated 12 Aug 2026.
	Ca Na LNG Ca Na LNG Power Complex Terminal	Regasification (import)	Proposed	Vietnam	1.2	—	Ca Na, Phuoc Diem commune, Thuan Nam district, Ninh Thuan Province	—	Import
Capacity regas throughput 1-1.2 Mtpa per Jan 2026 investment deal (1.2); 220,000 m3 tank; vessels up to 97,000 t; phase 1 complex ~US$2.13bn Direction Import Ownership Novatek (MOU since 2019); investor selection via international bidding (Sept 2021) Feed source Imported LNG Serves Ca Na LNG power complex (1,500 MW phase 1, up to 6,000 MW) Cost — Source source Notes This is Novatek's Vietnam project — the task brief's 'Bac Lieu LNG (Novatek-led)' is a mix-up (Bac Lieu is Delta Offshore Energy). LNG import terminal added to the Ca Na power complex by prime-minister decision April 2021; phase 1 (1,500 MW) approved by Ninh Thuan People's Committee (Decision 2162/QD-UBND), originally to operate Q3 2024 — missed. In March 2024 Vietnam's Deputy Minister of Industry and Trade urged Novatek to accelerate; no construction reported. VERIFIED 2026-08-12: proposed per GEM page (no updates as of mid-2026); Ca Na power station is in PDP8 but the terminal is not separately listed.
	Nghi Son LNG Thanh Hoa LNG Terminal	Regasification (import)	Proposed	Vietnam	1.2	—	Nghi Son Economic Zone, Tinh Gia District, Thanh Hoa Province	—	Import
Capacity 1.2 Mtpa planned Direction Import Ownership Undetermined — investor selection re-run repeatedly (Gulf Group initial agreement Aug 2023; shortlisted: JERA/Sovico, KEPCO-KOGAS-Daewoo E&C-Anh Phat, Gulf Energy, SK E&S; Greenwell Energy Canada announced Dec 2024, not materialized) Feed source Imported LNG Serves Nghi Son power station (1,500 MW) Cost — Source source Notes Proposed Aug 2023 (Thanh Hoa province + Gulf Group provisional agreement) as part of the US$2.4 billion Nghi Son LNG-to-power complex. Investor-selection tender was cancelled for the third time in July 2025 after no bids by the 10 June 2025 deadline; JERA expressed renewed interest in Sept 2025. VERIFIED 2026-08-12: proposed, no FID or construction per GEM page updated 12 Aug 2026.
	Long Son LNG	Regasification (import)	Proposed (stale)	Vietnam	4.4	—	Long Son, Ba Ria-Vung Tau Province	—	Import
Capacity 3.5-4.4 Mtpa planned Direction Import Ownership EVN (proposed); possible Mitsubishi Corp and GE participation Feed source Imported LNG Serves Long Son LNG power complex (1,200-1,500 MW phase 1) Cost — Source source Notes Long Son LNG Power Complex proposed by EVN (~US$3.78 billion) with terminal capacity 3.5-4.4 Mtpa, originally targeted for 2025-2026 operation. GEM page has not been updated since 2020 and no recent progress reports were found, so status is unverified beyond 'proposed'. VERIFIED 2026-08-12: proposed (stale) — no evidence of advancement; GEM page unmaintained since 2020.
	Northern Vietnam LNG Hai Phong LNG Terminal	Regasification (import)	Shelved	Vietnam	1.2	—	Hai Phong	—	Import
Capacity 1.2 Mtpa total (Phase 1 0.7 Mtpa + Phase 2 0.5 Mtpa) · 2 phases Direction Import Ownership ITECO JSC and Excelerate Energy LP (term sheet reported June/Aug 2024) Feed source Imported LNG Serves Hai Phong industrial and power demand Cost — Source source Notes Greenfield import terminal in Hai Phong co-developed by Excelerate Energy and ITECO JSC per term sheet reported Aug 2024, with Phase 1 (0.7 Mtpa) planned online 2027; the proposal dates to Dec 2021 (ITECO-JAPEX share purchase agreement). GEM infers the project is shelved as of August 2026 due to no evidence of progress since 2024. VERIFIED 2026-08-12: shelved (inferred) per GEM page updated 12 Aug 2026.
	Vung Ang LNG	Regasification (import)	Proposed	Vietnam	2.2	—	Ky Loi commune, Ky Anh district, Ha Tinh Province	—	Import
Capacity 2.2 Mtpa terminal (2021 proposal); phase 1 planned 1-3 Mtpa, operation 2029-2030 Direction Import Ownership PV Power (PetroVietnam Power) 51% / B.Grimm Power 34% / Vietnam Machinery Installation Corp (Lilama); consortium approved by Ha Tinh Jun 2026, PetroVietnam green-light Sep 2025 Feed source Imported LNG Serves Vung Ang III power center (2.4-4.8 GW) Cost — Source source Notes Proposed 2021 to convert Vung Ang III from coal to LNG (2.2 Mtpa terminal, operation 2026-27); the Siemens Energy-led proposal is presumed cancelled and the associated power station is listed among 'behind schedule or cannot be implemented' projects in PDP8. March 2024 reports of Vingroup/T&T/Hoanh Son/Samsung interest did not confirm a sponsor. VERIFIED 2026-08-12: proposed/stale with no confirmed developer per GEM page.
	Quang Nam LNG	Regasification (import)	Cancelled	Vietnam	2.5	—	Quang Nam Province	—	Import
Capacity no published terminal capacity; est. ~2.5 Mtpa from 3.2 GW semi-offshore plant scope (≈0.8 Mtpa/GW, Vietnam convention) Direction Import Ownership Energy Capital Vietnam (ECV) Feed source US-sourced LNG (planned) Serves ECV LNG-to-power project (relocated from Bac Lieu) Cost — Source source Notes ECV moved its LNG-to-power project from Bac Lieu to Quang Nam in Nov 2018; no development updates since, and the associated power station is not listed in PDP8, so GEM infers shelving. VERIFIED 2026-08-12: shelved per GEM page. CAPACITY ESTIMATE: no published figure; ~2.5 Mtpa derived from 3.2 GW plant scope.
	Khanh Hoa LNG	Regasification (import)	Shelved	Vietnam	3.0	—	Van Phong Economic Zone, Khanh Hoa Province (central Vietnam)	—	Import
Capacity 3 Mtpa planned (2030 target from 2020 proposal) Direction Import Ownership Millennium Energy (US) Feed source Imported LNG Serves Van Phong EZ LNG-to-power project (US$15bn complex per 2020 reports) Cost — Source source Notes US Millennium Energy Corporation proposed two LNG projects in Van Phong EZ (reported May 2021); no updates since, so GEM presumes shelving. VERIFIED 2026-08-12: shelved per GEM page.
	Mui Ke Ga FSRU Mui Ke Ga LNG-to-Power Terminal	FSRU (import)	Shelved	Vietnam	1.5	—	Mui Ke Ga, Binh Thuan Province	—	Import
Capacity 1.5 Mtpa phase 1 (expandable in later phases) Direction Import Ownership Energy Capital Vietnam (ECV) with Gunvor International and B.Grimm Power (consortium agreement Dec 2021) Feed source Imported LNG (Gunvor long-term supply agreement) Serves Mui Ke Ga LNG-to-power project (offshore FSRU connected by subsea pipeline) Cost — Source source Notes ECV-Gunvor JV (Dec 2020) planned an FSRU-based LNG-to-power project with FID targeted late 2021 and COD 2025 — both missed; the project is listed among 'behind schedule or cannot be implemented' projects in PDP8. GEM's August 2026 listing classifies it as shelved (inferred, ~2 years inactive), though an earlier page revision said proposed/pre-FID. VERIFIED 2026-08-12: shelved (inferred) per GEM.
	Greater Sunrise LNG Sunrise FLNG Terminal / Timor LNG (TLNG)	Liquefaction (export)	Proposed	Timor-Leste	3.6	—	Greater Sunrise fields, Timor Sea (~150 km south of Timor-Leste, ~450 km NW of Darwin); current concept: onshore Tasi Mane/Beaco, Timor-Leste	Woodside Energy 🇦🇺	Export
Capacity GEM nameplate 3.6 Mtpa; TLNG Timor concept targets ~5 Mtpa (Nov 2025); Tasi Mane master plan up to ~20 Mtpa over 4 trains · 1 train initially (expandable to 4) Direction Export Ownership Sunrise Joint Venture: Timor GAP EP 56.56%, Woodside Energy 33.44%, Osaka Gas 10% Feed source Sunrise and Troubadour fields — 2C resources ~5.1-5.3 Tcf gas, 226 million bbl condensate Serves LNG export (Asia); TLNG concept adds domestic gas and helium extraction Cost — Source source Notes Decades-delayed development of the Sunrise/Troubadour fields; Timor-Leste bought ConocoPhillips' 30% (2018, US$350m) and Shell's 26.56% (2018, US$300m) stakes. The Wood PLC concept study (Apr-Nov 2024) concluded the Timor-Leste processing option is viable and most advantageous; on 25 Nov 2025 Woodside and Timor-Leste's MPRM signed a Cooperation Agreement to mature a greenfield Timor-based ~5 Mtpa LNG concept (TLNG) with domestic gas and helium plant, first LNG possible 2032-2035 subject to concept selection and FID — site selection was targeted for mid-2026 and remains pending, with the Darwin-pipeline alternative still on the table (Reuters, 28 Jan 2026). VERIFIED 2026-08-12: proposed, no FID, per GEM gas-project page (updated 12 Aug 2026), Woodside/MPRM joint release 25 Nov 2025 and TATOLI May 2026; operator Woodside Energy was unaffected by the June 2025 Santos merger (Santos held no Greater Sunrise interest).
	Singapore LNG Terminal SLNG Terminal; Jurong Island LNG Terminal	Regasification (import)	Operating	Singapore	11.0	2013	Jurong Island, West Region Jurong Island	Singapore LNG Corporation Pte Ltd (SLNG) 🇸🇬	Import
Capacity 11.0 mtpa total: Phase 1 3.5 mtpa, Phase 2 2.5 mtpa, Phase 3 5 mtpa · 3 phases Direction Import Ownership Singapore LNG Corp (100%) Feed source Imported LNG (global spot and term supply) Serves Singapore power generation (~95% of electricity from gas), industry, LNG truck-loading, small-scale LNG and bunkering Cost $1.7B Source source Notes Asia's first multi-user LNG import terminal on Jurong Island: Phase 1 (3.5 mtpa) commissioned 2013, Phase 2 (2.5 mtpa) 2014, Phase 3 (5 mtpa) 2018, reaching 11 mtpa nameplate. A new LNG truck-loading facility is under construction (target completion 2026) and in July 2026 SLNG signed a terminal-use agreement with Chinese utility Jiaxing Gas; no Phase 4 expansion is reported, with the second terminal (SLNG 2) being built instead. VERIFIED 2026-08-12 — GEM wiki lists all three phases operating (page edited 2026-08-11); truck-loading and Jiaxing Gas deal per GEM references (Rigzone Aug 2025, LNG Prime Jul 2026).
	SLNG 2 LNG Terminal Singapore Second LNG Terminal	FSRU (import)	Under construction	Singapore	5.0	—	Offshore Singapore, FSRU to be moored at Jurong Port Singapore (main island)	Singapore LNG Corporation Pte Ltd (SLNG) 🇸🇬	Import
Capacity 5 mtpa FSRU · 1 FSRU (204,000 cbm) Direction Import Ownership Singapore LNG Corp (100%) Feed source Imported LNG Serves Singapore gas grid (power and industrial demand); with the existing Jurong Island terminal lifts SLNG combined throughput capacity to up to 15 mtpa Cost $413M Source source Notes Singapore's second LNG import terminal, first announced July 2021 and revived by SLNG in Oct 2023 as a 5-mtpa FSRU project; SLNG chartered a 204,000-cbm newbuild FSRU from MOL (Oct 2024). The FSRU (~US$413m) is under construction at Hanwha Ocean's Geoje yard, keel laid 26 May 2026 with delivery expected Oct 2027, while onshore connecting-infrastructure EPC (main process area, FSRU jetty, grid pipelines) went to China Communications Construction Company (Singapore) in Nov 2025 with groundbreaking in late March 2026; the FSRU is planned to be connected to the gas network by 2030. GEM's status field still reads 'proposed' but construction is demonstrably underway in mid-2026. VERIFIED 2026-08-12 — GEM page (ed. 31 Jul 2026) documents keel laying, onshore groundbreaking and MOL/CCCC contracts.
	FGEN LNG Terminal FGEN Batangas FSRU; BW Batangas FSRU terminal	FSRU (import)	Operating	Philippines	5.3	2023	Santa Rita, Batangas City, Batangas Luzon	FGEN LNG Corp 🇵🇭	Import
Capacity 5.3 mtpa regasification (DOE reported 5.0-5.26 mtpa) · 1 FSRU (BW Batangas, ex-BW Paris) Direction Import Ownership FGEN LNG Corp — Prime Infrastructure Capital 60%, First Gen 20%, Tokyo Gas 20% (sale closed Nov 2025); FSRU owned/operated by BW LNG Feed source Imported LNG (spot cargoes; term supply agreements being pursued) Serves First Gen Clean Energy Complex gas plants: Sta. Rita (1,000 MW), San Lorenzo (500 MW), San Gabriel (414 MW), Avion (97 MW) Cost $370M Source source Notes Interim offshore LNG import terminal built by First Gen and Tokyo Gas at the First Gen Clean Energy Complex; construction began June 2021, FSRU BW Batangas (ex-BW Paris) arrived June 2023, commissioning Sept-Oct 2023 with first cargo in October. The terminal fuels First Gen's four gas power plants — it does NOT serve the Ilijan plant, which is supplied by the AG&P Philippines LNG Terminal. DOE granted a 25-year operating permit in Jan 2025, and Prime Infrastructure Capital completed its 60% acquisition of FGEN LNG in Nov 2025 (First Gen and Tokyo Gas each retain 20%). VERIFIED 2026-08-12 — GEM page (ed. 12 Aug 2026) status operating; 2025 license and Prime Infra deal per GEM background and references (Offshore Energy Jan 2025, GMA Nov 2025).
	Philippines LNG Terminal PHLNG Terminal; Ilijan LNG Terminal; AG&P LNG Terminal; Batangas LNG Terminal	Regasification (import)	Operating	Philippines	5.0	2023	Batangas Bay, Batangas City, Batangas Luzon	Atlantic Gulf & Pacific Company Industrial (AG&P LNG) 🇵🇭	Import
Capacity 5 mtpa; ~200,000 cbm storage · 1 FSU (ISH, 137,500 cbm) + onshore regasification Direction Import Ownership Acquired Jan 2025 by SPPC/EERI consortium of Meralco PowerGen, AboitizPower (Therma NatGas) and San Miguel Global Power; developed by AG&P Terminals & Logistics (parents Nebula Energy 80%, Osaka Gas, JBIC, Asiya) Feed source Imported LNG (2024 cargoes all spot; 10-year 0.8-mtpa Vitol supply deal signed Mar 2025) Serves Ilijan gas power plant (1,200 MW, San Miguel) plus power, industrial and commercial customers (open-access) Cost $263M Source source Notes Philippines' first LNG import terminal, developed by AG&P subsidiary Linseed Field Power Corp at Batangas Bay; construction from 2021, first cargo and FSU berthing April 2023, commercial operations from September 2023 supplying the 1,200-MW Ilijan plant. Together with FGEN Batangas FSRU it received 19 cargoes in 2024, all bought on the spot market. In March 2024 Meralco PowerGen, AboitizPower and San Miguel agreed and in January 2025 closed the US$3.3bn acquisition of the integrated LNG-to-power facility (this terminal plus Ilijan power station). VERIFIED 2026-08-12 — GEM page (ed. 12 Aug 2026) status operating; Jan 2025 deal completion and Mar 2025 Vitol agreement documented with LNG Prime and Reuters references.
	Luzon LNG Filipinas LNG Gateway Project FSRU	FSRU (import)	Shelved	Philippines	4.4	—	Batangas Bay, offshore Batangas Luzon	Luzon LNG Terminal Inc 🇺🇸	Import
Capacity 4.4 mtpa FSRU · 1 FSRU Direction Import Ownership Luzon LNG Terminal Inc (LLTI; parent companies incl. Excelerate Energy Inc ~24.3% and Excelerate Energy Holdings LLC) Feed source Imported LNG Serves Planned open-access supply to Luzon gas power plants (incl. EGCO Group as potential anchor offtaker) Cost — Source source Notes FSRU-based 'open access' import terminal in Batangas Bay proposed by Excelerate Energy (with Topline Energy Corp); DOE application April 2021, project on DOE approved list April 2023, earlier expected online by 2025. IGU 2024 and 2025 reports still listed it 'under construction' with the start year shifted from 2025 to 2028, but GEM notes no project activity since Excelerate's April 2021 application and no evidence construction began, classifying it shelved as of 2026. Momentum shifted after Aboitiz Power, Meralco and San Miguel instead acquired the operating AG&P Philippines LNG Terminal (closed Jan 2025). VERIFIED 2026-08-12 — GEM page (ed. 12 Aug 2026) explicitly classifies the project as shelved.
	FGEN Batangas LNG Terminal FGEN onshore LNG terminal	Regasification (import)	Shelved	Philippines	5.0	—	Santa Rita, Batangas City, Batangas Luzon	FGEN LNG Corp 🇵🇭	Import
Capacity 5 mtpa onshore (earlier reported 3-5 mtpa) Direction Import Ownership FGEN LNG Corp (First Gen 80%, Tokyo Gas 20%) Feed source Imported LNG Serves Planned permanent onshore replacement for the interim FGEN Batangas FSRU Cost $1.0B Source source Notes First Gen and Tokyo Gas' originally planned onshore LNG import terminal at Santa Rita (joint-venture agreement Dec 2018, DOE NTP application Dec 2018); in 2019 the plan evolved into an interim FSRU with a permanent onshore terminal to follow. Per an S&P Global article (2023), developers completed several FEED rounds and an EPC process but 'paused' and pivoted to the floating solution, with the full terminal to be 'reevaluated in the future'. GEM considers it shelved as of 2026 — no updates on the permanent facility despite the 25-year operating license granted for the FSRU in Jan 2025. VERIFIED 2026-08-12 — GEM page (ed. 12 Aug 2026) background states it is considered shelved.
	Batangas Clean Energy LNG Terminal BCE LNG Terminal	Regasification (import)	Cancelled	Philippines	3.0	—	Himmel Industrial Complex, Batangas Luzon	Batangas Clean Energy Inc 🇵🇭	Import
Capacity 3 mtpa Direction Import Ownership Batangas Clean Energy Inc (ENEX Energy Corp 50%, Blackstone via Gen X Energy LP 50%; Lucio Tan Group exited 2021) Feed source Imported LNG Serves Planned 1,000-1,200 MW CCGT power plant (still planned; Enex targets 2027, sourcing gas from a nearby LNG facility) Cost $1.5B Source source Notes Lucio Tan-led LNG import terminal plus CCGT power plant certified as an energy project of national significance end-2020 (PHP 82.5bn / ~US$1.5bn). After failing to apply for an LNG permit extension in August 2021 the LNG terminal was cancelled, though the power plant continued: Ayala's ACE Enexor (now ENEX Energy) took 50% in Nov 2021 with Blackstone's Gen X Energy holding the rest, and Enex confirmed in May 2025 it still intends the ~1,000 MW power project. GEM's status field still reads 'proposed' but its background explicitly states the terminal was cancelled. VERIFIED 2026-08-12 — GEM page (ed. 11 Aug 2026).
	Pagbilao Grande Island LNG Terminal Quezon LNG; P9B Terminal	Regasification (import)	Shelved	Philippines	3.0	—	Pagbilao Grande Island, Quezon Luzon	Energy World Corp Ltd 🇬🇧	Import
Capacity 3 mtpa (Phase 1 1.5 mtpa, Phase 2 doubles) · 2 phases Direction Import Ownership Energy World Corp Ltd (100%) Feed source Imported LNG Serves Planned 650-MW gas-fired power plant and Pagbilao Combined Cycle power station Cost — Source source Notes Energy World Corporation's onshore regasification terminal on Grande Island, Pagbilao; first permitted 2011 (extended 2015, re-permitted by DOE Jan 2019), construction reportedly 90% complete end-2020 and 80% complete Sept 2021. The company could not draw its PHP 6.75bn loan because the associated gas plant was never connected to the Luzon grid, and its ASX share price collapsed. The 2025 IGU report still listed the terminal under construction with a 2028 start year, but GEM retroactively infers it shelved as of 2023 given no updates in over four years and EWC's record of misleading construction updates. VERIFIED 2026-08-12 — GEM page (ed. 12 Aug 2026) status 'shelved (inferred 2 y)'.
	Mariveles LNG Terminal Samat LNG Terminal; Bataan small-scale LNG terminal	Regasification (import, small-scale)	Shelved	Philippines	0.4	—	PNOC Industrial Park, Limay/Mariveles, Bataan Luzon	Samat LNG Corp 🇸🇬	Import
Capacity 0.2-0.4 mtpa (200,000-400,000 t/yr) · 2 phases Direction Import Ownership Samat LNG Corp (100%; parent company Tectoroe Pte Ltd) Feed source Imported LNG Serves Manufacturing industries, small independent power producers and transport fuel Cost $67M Source source Notes Planned first small-scale LNG import terminal in the Philippines, developed by Samat LNG Corp at PNOC's industrial park in Limay, Bataan; DOE notice to proceed Jan 2023, commercial operations originally targeted H1 2024, long-term land lease with PNOC signed Sept 2023 (PNOC considered taking a stake in Jan 2024). No developments since early 2024 — GEM considers the project shelved as of 2026. VERIFIED 2026-08-12 — GEM page (ed. 11 Aug 2026) lists status 'proposed' with background stating it is considered shelved.
	Tabangao FSRU Shell Energy Philippines LNG terminal	FSRU (import)	Shelved	Philippines	3.0	—	Tabangao Port, Batangas City, Batangas Luzon	—	Import
Capacity 3 mtpa FSRU · 1 leased FSRU Direction Import Ownership Shell Energy (Shell PLC, 100%) Feed source Imported LNG Serves Planned supply to the Batangas Clean Energy (Enex) ~1,100-MW plant and third parties Cost $63M Source source Notes Shell's FSRU import terminal at Tabangao Port (site of the former Shell refinery), first proposed 2013 and revived Jan 2021; June 2022 reports put investment at PHP 3.5bn (~US$66m) with construction planned from 2024, and DOE data (Dec 2023) targeted 2025 completion. No updates in over two years as of Aug 2025, and a May 2025 Shell shareholder update on Tabangao investments made no mention of the LNG terminal, so GEM infers the project is shelved. VERIFIED 2026-08-12 — GEM page (ed. 11 Aug 2026) status 'shelved (inferred 2 y)'.
	Vires FSRU Vires Energy LNG Terminal; VEC LNG terminal	FSRU (import)	Cancelled	Philippines	3.0	—	Barangay Simlong, Batangas City, Batangas Luzon	—	Import
Capacity 3 mtpa regasification · 1 FSRU (~162,400 cbm) Direction Import Ownership Vires Energy Corp (A Brown Co Inc, 100%) Feed source Imported LNG Serves Planned 450-500 MW floating power plant (anchor market) Cost — Source source Notes Vires Energy's integrated FSRU and floating power plant project off Barangay Simlong in Batangas Bay; DOE NTP April 2021, expected online Jan 2023 then April 2026. In September 2024 Vires withdrew its NTP and scrapped the LNG terminal (the BW Group FSRU planned for the project was never deployed), intending to import gas via pipeline for its power station instead; Vires subsequently also dropped the gas power project (Dec 2025). VERIFIED 2026-08-12 — GEM page (ed. 12 Aug 2026) status 'cancelled (confirmed)'; cancellation corroborated by Philstar (Aug 2024) and Inquirer reports.