Philippine Natural Gas Industry Development Act — R.A. No. 12120
11 chapters · 53 sections · OCR from certified copy
Declares the policy of the State to promote natural gas as a safe, efficient and cost-effective source of energy and an indispensable contributor to energy security by establishing the Philippine Downstream Natural Gas Industry (PDNGI) for the benefit of all segments of the nation's population and all sectors of the economy.
View full actLNG Import Terminals
9 terminals · 2 operating · 5 shelved · 2 cancelled · hover a terminal to light up its dot on the map
Ownership — all 9 PH LNG terminals
| Mariveles LNG Terminal via Samat LNG Corp | 100% |
| Vires FSRU via A Brown Co Inc | 100% |
| FGEN Batangas LNG Terminal via First Gen | 80% |
| FGEN LNG Terminal via Prime Infrastructure Capital | 60% |
| Batangas Clean Energy LNG Terminal via ENEX Energy Corp | 50% |
| Philippines LNG Terminal via Meralco PowerGen | 40.2% |
| Philippines LNG Terminal via San Miguel Global Power | 33% |
| Philippines LNG Terminal via AboitizPower | 26.8% |
| FGEN LNG Terminal via First Gen | 20% |
PNOC holds no equity in the 9 tracked private terminals. PNOC's own LNG ventures: BOLT (Bataan Open Access LNG Terminal, under development, 2024-25); small-scale Bataan LNG JV with an investor (2024, minority); minimum 10% stake floated for a PNOC-led Batangas hub (2018) - none has reached FID.
| Pagbilao Grande Island LNG Terminal via Energy World Corp Ltd | 100% |
| Tabangao FSRU via Shell PLC | 100% |
| Batangas Clean Energy LNG Terminal via Blackstone via Gen X Energy LP | 50% |
| Luzon LNG via Excelerate Energy Inc | 24.3% |
| FGEN LNG Terminal via Tokyo Gas | 20% |
| FGEN Batangas LNG Terminal via Tokyo Gas | 20% |
% = share of total ownership across all 9 terminals (each facility = 100%) · click any chip for the per-company / per-facility breakdown
FGEN LNG Corp · serves First Gen Clean Energy Complex gas plant · Santa Rita, Batangas City, Batangas
Atlantic Gulf & Pacific Company Industrial (AG&P LNG) · serves Ilijan gas power plant (1,200 MW, San Mi · Batangas Bay, Batangas City, Batangas
FGEN LNG Corp · serves Planned permanent onshore replacement fo · Santa Rita, Batangas City, Batangas
Luzon LNG Terminal Inc · serves Planned open-access supply to Luzon gas · Batangas Bay, offshore Batangas
Energy World Corp Ltd · serves Planned 650-MW gas-fired power plant and · Pagbilao Grande Island, Quezon
serves Planned supply to the Batangas Clean Ene · Tabangao Port, Batangas City, Batangas
Samat LNG Corp · serves Manufacturing industries, small independ · PNOC Industrial Park, Limay/Mariveles, Bataan
Batangas Clean Energy Inc · serves Planned 1,000-1,200 MW CCGT power plant · Himmel Industrial Complex, Batangas
serves Planned 450-500 MW floating power plant · Barangay Simlong, Batangas City, Batangas
Gas Network Code — Structured Viewer
SingaporeJul 2026 edition · issued by the Energy Market Authority under s.61B of the Gas Act (Cap. 116A) · operated by PowerGas Ltd (Transporter) · sources: [Info] Gas Network Code - Jul 26
Gas Network Code — Modification History
55 approved modifications · EMA approval dates · first proposal 2008/December/P1
| No. | GNC Reference | Modification | Proposal Ref | Proposer | EMA Approval |
|---|
Source: Summary of Gas Network Code Modifications · updated 27 Jul 26 · extracted from the PDFs in [Info] Gas Network Code - Jul 26
Liquefied Natural Gas (LNG) — Importers & Market Structure
Singapore~60% of Singapore’s gas imports are now LNG (2025) · EMA licences gas importers under the Gas Act (Cap. 116A) · 5 licenced LNG importers per SLNG + Singapore GasCo (2025) · licence award dates: BG aggregator 2008 · second tranche 2016 · additions 2021 · GasCo 2025 · sources: SLNG, EMA media releases, Straits Times (Mar 2026), Energy Intelligence (Sep 2025)
Licensed LNG importers — full roster
| Importer | Group | Licence | Role | Notes |
|---|---|---|---|---|
| Shell Gas Marketing Pte Ltdformerly BG Singapore Gas Marketing Pte Ltd | Shell plc | 18 Apr 2008 | Term importer | First importer — EMA appointed BG Asia Pacific as exclusive LNG Aggregator (up to 3 Mtpa); first LNG cargo May 2013; renamed after Shell–BG merger (2016) |
| Shell Eastern Trading (Pte) Ltd | Shell plc | 24 Oct 2016 | Term importer | Second-tranche importer (EMA 2014 RFP); imports from 2017 |
| Pavilion Energy Singapore Pte Ltdformerly Pavilion Gas Pte Ltd | Shell plc (acquired 2025; licence kept separate) | 24 Oct 2016 | Term importer | Second-tranche importer (EMA 2014 RFP); Shell acquired 2025, separate licence retained |
| ExxonMobil LNG Asia Pacific Pte Ltd | ExxonMobil | 25 Mar 2021 | Term importer | Added via EMA 2020 RFP (Post-3 Mtpa framework) |
| SembCorp Fuels (Singapore) Pte Ltd | Sembcorp Industries | 25 Mar 2021 | Term importer | Added via EMA 2020 RFP (Post-3 Mtpa framework) |
| Singapore GasCo Pte Ltd | Government of Singapore | Sep 2025 | State gas aggregator | Established 7 May 2025; centralises NEW power-sector procurement (existing genco contracts grandfathered; industrial users exempt); first RFP Q1 2026, key test at 2028 contract roll-off |
Import framework notes
- Licence class: EMA’s “Gas Importer” licence (Gas Shipper, Retailer or Importer) under the Gas Act (Cap. 116A) — required to import natural gas into Singapore; terminal access at SLNG sits on top.
- Licence history (award dates): 18 Apr 2008 — EMA appointed BG Asia Pacific (BG Singapore Gas Marketing, now Shell Gas Marketing) as exclusive LNG Aggregator, up to 3 Mtpa (until 2023 or 3 Mtpa of long-term sales, whichever earlier); first LNG cargo May 2013. 24 Oct 2016 — second-tranche licences awarded to Pavilion Gas and Shell Eastern Trading via the June 2014 RFP (imports from 2017). 25 Mar 2021 — ExxonMobil LNG Asia Pacific and SembCorp Fuels appointed under the Post-3 Mtpa framework. Sep 2025 — Singapore GasCo (established 7 May 2025) licensed as the state gas aggregator.
- Original framework: BG’s exclusive aggregator franchise (2008) covered the first tranche — first LNG cargo at SLNG arrived May 2013 — before the June 2014 RFP opened the second tranche, won by Pavilion Gas and Shell Eastern Trading (licences 24 Oct 2016, imports from 2017).
- Post-3 Mtpa framework: EMA opened the market — 2020 RFP appointed ExxonMobil LNG Asia Pacific and SembCorp Fuels as additional term importers (Mar 2021), and allowed spot LNG import: supply terms ≤ 12 months, annual cap at 10% of total contracted gas quantity (LNG + piped), first-committed-first-served terminal capacity; allowed spot quantity CY2026 = 22,920,624.55 MMBtu.
- 2025: Shell completed its acquisition of Pavilion Energy — the two keep separate importer licences; Singapore GasCo Pte Ltd was established to centralise procurement & supply of natural gas to the power sector (gas import licence, Sep 2025) — it takes on new long-term supply going forward while incumbents honour existing contracts.
- Centralisation mechanics (EMA decision 23 Oct 2023): centralised procurement applies to the power sector’s new contracts and renewals — existing genco contracts with licensed importers are grandfathered, and industrial / non-power customers are exempt (still buy via licensed importers). GasCo’s first LNG/gas RFP is planned for Q1 2026; initial volumes are modest because legacy contracts cover most needs, with the main transition at the 2028 contract roll-off.
- 2026: ST counts “four licensed LNG importers” (Shell incl. both entities, ExxonMobil, Pavilion, Sembcorp); GasCo stands ready to buy additional cargoes amid Middle East supply disruption (Hormuz closure).
- Terminal & grid: SLNG operates regulated third-party access with EMA-approved Throughput tariffs; regasified LNG flows into PowerGas’s network under the Gas Network Code (see Gas Network Code section).
Sources: SLNG Throughput Services (“5 licenced LNG importers”) · EMA media releases (Mar 2021 appointments; 9 Jul 2020 RFP; Sep 2025 Singapore GasCo) · Straits Times 13–14 Mar 2026 · Energy Intelligence 9 Sep 2025 · GEM wiki (SLNG / SLNG 2) · verified Aug 2026.
Piped Natural Gas (PNG) — Pipeline Routes & Contract Status
Singaporepiped gas from Malaysia & Indonesia · ~40% of gas imports (2025) and falling · EMA SES 2024: piped imports −7% y/y · WNTS contract ended 2023 · indicative pipeline routes on map
Pipeline routes — fields, pipes & status
History — how the gas gets in
“Running out of gas” — why Singapore is pivoting to LNG
- Indonesia: the West Natuna 22-year contract ended in 2023; Indonesia also announced it would halt Suban (Corridor block) supply at contract expiry and redirect gas domestically. Sembcorp’s replacement deal for Mako (Duyung PSC) gas was terminated in Mar 2025.
- Malaysia: Petronas prioritises domestic demand — it became a net LNG importer in 2024 (~3.3 Mt imports); Reuters (Nov 2025) expects piped volumes to Singapore to keep declining as neighbours’ fields serve home markets.
- The numbers: EMA’s 2024 statistics show piped imports down 7% while LNG grew — LNG crossed 50% of imports in 2024 and reached ~60% in 2025.
- GasCo: the state aggregator centralises new power-sector procurement, with its first LNG portfolio RFP in Q1 2026 for supply from 2028 — Singapore’s post-pipeline era is an LNG era.
Sources: EMA Singapore Energy Statistics 2024 (11 Mtoe imports; LNG 6 Mtoe; piped −7%) · EMA media releases (2008 BG aggregator; 2016 second tranche; 2021 importers; 23 Oct 2023 centralisation; 7 May 2025 GasCo) · GEM Global Gas Infrastructure Tracker (WNTS 640 km / 3.4 bcm-yr / 2001; Malaysia–Singapore 70 km / 1991; Grissik–Batam–Singapore 470 km / 2003) · Sembcorp media (2003 “Jurong Island receiving terminal”; Jun 2023; Sep 2024 “beyond 2028”; Mar 2025 termination) · Business Times (2 Sep 2024; 13 Mar 2025) · Reuters (21 Nov 2025 GasCo 2028 RFP) · VietnamPlus (Apr 2026, 40% piped in 2025) · Wikipedia (PGU 2,623 km; 1992 Senoko contract) · map routes are indicative, not survey-grade · verified Aug 2026.
Electricity Market (NEMS) — 2026 Market Generation
SingaporeReal dispatched electricity, half-hour by half-hour · EMC Metered Generation by Facility Type · 01 Jan – 30 Jul 2026 · 70,896 records · open full-screen dashboard →
Daily generation profile
stacked by facility type, 48 half-hour periods · ESS below zero = batteries charging (drawing from the grid) · showing the latest day (30 Jul 2026) · click a legend item for players & contracts
ESS — the duck-curve arbitrage
Average MW by hour (per-day, Jan–Jul 2026) · batteries charge at midday solar surplus, discharge into the 08:00 & 20:00 peaks
Weekday vs weekend load
average half-hour profile, MW · weekends shed ~5–10% of demand
Monthly generation mix
gross injection by facility type, GWh · CCGT/COGEN carries ~93–94% of the load year-round
Expected generation margin vs average USEP
Fuel cost = 5.8 MMBtu/MWh × 15% of rolling 3-month avg Dated Brent · margin = average USEP − fuel cost (excl. O&M) · USEP: NEMS · Dated Brent: investing.com monthly avg
Source: Energy Market Company — NEMS Market Data Download, Metered Generation by Facility Type (MG) · CSVs Jan–Jul 2026 · gross injection in MWh per half-hour, displayed as MW (= MWh × 2) · facility types: CCGT/COGEN/TRIGEN, IGS, ST, IMPORT, GT, ESS (negative = charging), OTHERS · verified Aug 2026.