Philippine Downstream Natural Gas Industry (PDNGI)
The PDNGI is the statutory term for the full system of facilities and participants involved in the transmission, distribution, and supply of natural gas in the Philippines downstream of upstream production. RA 12120 (effective ~January 23, 2025) establishes the first comprehensive legal framework governing this industry. [RA 12120, §4(cc), 2025]
Structure of the Industry
The PDNGI has three infrastructure layers and a commercial trading layer:
| Layer | Statutory Term | Description |
|---|---|---|
| Regasification | LNG Storage and Regasification Terminal | Receives, stores, and regasifies imported LNG; includes jetty, cryogenic tanks, vaporizers, send-out systems |
| Transmission | PDNG Transmission System | Conventional pipeline network from LNG terminal or indigenous source to distribution system |
| Distribution | PDNG Distribution System | Conventional or virtual transportation from receipt point to end-user; includes virtual pipelines (trucks, vessels) |
| Commercial | Participants | Suppliers, aggregators, bunker traders, resellers |
[RA 12120, §4(o)(aa)(ff)(cc), 2025]
Permit System
DOE issues two categories of permits for PDNGI Facilities [RA 12120, §18, 2025]:
Own-Use Permit — holder uses entire capacity exclusively for own use and affiliates; TPA not allowed without DOE approval.
TPA Permit — holder provides Third-Party Access on transparent, fair, reasonable, and non-discriminatory terms; may not use capacity for own use without DOE approval.
PDNGI Facilities do not require a legislative franchise — only a DOE Permit. This distinguishes the sector from the electricity transmission sector (NGCP requires a congressional franchise under RA 9511).
In addition to facility permits, Participants (natural gas traders) must be accredited by DOE. Import and export activities require notification acknowledgment from DOE.
All PDNGI permits are processed through the EVOSS system (RA 11234). [RA 12120, §5(d), 2025]
Aggregation
Aggregation is a key commercial mechanism that enables blending of indigenous and imported natural gas [RA 12120, §4(b)(c), 2025]:
- Aggregator procures indigenous gas and combines it with imported LNG, selling the blend to buyers in the Philippines or abroad
- DOE sets the minimum percentage of indigenous gas required in aggregated gas
- Aggregated gas (defined as blends with a required indigenous component) receives VAT exemption
- Pure imported LNG without any indigenous gas component is not aggregated gas and receives no VAT exemption
- DOE may direct attached agencies to participate in aggregation activities
Supply Priority Rules
RA 12120 establishes a statutory priority hierarchy [RA 12120, §23, 2025]:
- Indigenous natural gas (Malampaya and any future domestic fields) — highest priority
- Aggregated gas (blend of indigenous + imported) — second priority
- Pure imported LNG — lowest priority; no VAT exemption; subject to minimum percentage caps set by DOE
Power generated from indigenous natural gas has priority over other conventional energy sources. DOE must set a mandated minimum percentage of electricity demand to be sourced from indigenous gas, reviewed and adjusted as needed.
Regulatory Roles
| Agency | Function |
|---|---|
| DOE | Overall regulator; permits, codes, PDNG Dev Plan, TPA rate-setting, stranded asset tracking |
| ERC | Rates for power generated from natural gas (EPIRA jurisdiction) |
| PCC | Anti-competitive behavior; all DOE/ERC referrals on market conduct |
| DENR + PCG | Environmental and marine protection compliance; DENR sets methane emission standards within 6 months of effectivity |
| MARINA | Jurisdiction over LNG carriers and marine facilities |
| DOTr/LTO/LTFRB | Permits for virtual pipelines, vehicles transporting gas |
| DTI-BPS | Philippine National Standards (PNS) for natural gas and PDNGI Facilities |
| NCIP | FPIC process for projects affecting ancestral domains (via EVOSS timelines) |
| PERPI | R&D on renewable gas technologies (hydrogen, ammonia, biomethane) with DOST/PNOC support |
Codes and Plans
DOE must issue the following within 2 years of IRR effectivity [RA 12120, §5(g), 2025]:
| Instrument | Purpose |
|---|---|
| PDNG Transmission Code | Performance standards for conventional transmission systems |
| PDNG Distribution Code | Performance standards for conventional and virtual distribution systems |
| PLSR Terminal Code | Performance standards for LNG Storage and Regasification Terminals |
| TPA Code | Performance standards for third-party access |
DOE must also prepare the PDNG Development Plan within 2 years of effectivity (reviewed every 3 years), incorporating PLSR Terminal Dev Plan, PDNG Transmission Dev Plan, and PDNG Distribution Dev Plan. The PDNG Dev Plan is incorporated into the PEP. [RA 12120, §5(a), 2025]
VAT Treatment
| Category | VAT Status |
|---|---|
| Purchase/sale of indigenous natural gas | VAT-exempt |
| Purchase/sale of aggregated gas (indigenous portion only) | VAT-exempt |
| Power from indigenous/aggregated gas generation | VAT-exempt |
| Pure imported LNG (no indigenous component) | Not exempt |
[RA 12120, §38, 2025]
Stranded Asset Risk
§5(r) is the first Philippine energy law to require public stranded asset risk tracking. DOE must [RA 12120, §5(r), 2025]:
- Develop a transparent methodology for evaluating stranded asset risk for all natural gas infrastructure (existing and proposed)
- Maintain a publicly accessible database of projects and risk assessments, updated regularly
- Issue regulations promoting responsible investment and encouraging timely transition to RE
- Facilitate early retirement of high-risk assets through financial mechanisms
- Coordinate with agencies to align gas development with national climate targets
This provision reflects the law’s explicit acknowledgment that natural gas is a transition fuel, not a permanent element of the energy mix.
Renewable Gases
RA 12120 extends DOE’s regulatory scope to renewable gases — hydrogen, ammonia, biomethane, synthetic methane, and other gases derived from renewable sources. DOE, in collaboration with NREB and PNOC, must develop safety standards for renewable gases addressing their unique properties and risks. [RA 12120, §4(jj), §36, 2025]
This is the first Philippine law to give DOE regulatory authority over hydrogen and ammonia as energy carriers.
Transition from Prior Regulatory Regime
The PDNGI has been governed by three successive instruments, each superseding the previous:
DC2017-11-0012 (original PDNGR) → DC2024-01-0007 (Amended PDNGR, Jan 2024) → RA 12120 (statute, Jan 2025) + DC2025-04-0005 (IRR, Mar 2025)
DC2024-01-0007 — Amended PDNGR (January 2024)
Issued January 17, 2024, DC2024-01-0007 was the last pre-statutory regime — a DOE circular under RA 7638, enacted about one year before RA 12120 became law. It repealed DC2017-11-0012 and introduced DNG-REC. It was itself repealed by DC2025-04-0005. [DC2024-01-0007, §§36, 38, 2024-01-17]
Key structural differences between DC2024-01-0007 and the current IRR (DC2025-04-0005):
| Feature | DC2024-01-0007 (repealed) | DC2025-04-0005 IRR (current) |
|---|---|---|
| Legal basis | RA 7638 (DOE Act) — circular only | RA 12120 (statute) |
| Terminology | “Operator” | “Permit Holder” |
| Accreditation validity | 15 years, renewable 15 years | 5 years, renewable every 5 years |
| TPA types | 2 — Negotiated, Competitive | 3 — Negotiated, Competitive, Regulated |
| Regulated TPA | Not recognized | Applies to Conventional Transportation Systems operating as public utilities; rates set by DOE |
| Compliance transition | 6 months | 2 years |
| Participant: Importer | Separate category (§4(aa)) | Folded into “Supplier” |
| Processing timelines | 15cd completeness + 45cd evaluation + 15cd decision | 3 wd completeness + 12 wd evaluation + 5 wd decision |
| Accreditation approval body | OIMB Director | DNG-REC |
| Aggregation framework | DOE may mandate; no formal minimum-% mechanism | Gas Policy sets minimum indigenous % (deadline ~Oct 2025) |
| Stranded asset tracking | Absent | Required per RA 12120 §5(r) |
| Renewable gas | Absent | §36 and §4(jj) bring hydrogen/ammonia under DOE |
| Fine schedule | None specified; “per existing laws” | Specific amounts (₱100K–₱1M) per §57 |
DC2017-11-0012 — Original PDNGR (November 2017)
DC2017-11-0012 (“Philippine Downstream Natural Gas Regulation”) was the founding regulatory instrument for the downstream gas industry. Issued by Sec. Alfonso Cusi under RA 7638, it established the first structured permit and accreditation system for PDNGI facilities and repealed the earlier interim rules (DC2002-08-005). It was in effect from ~December 2017 until January 2024 when DC2024-01-0007 repealed it. [DC2017-11-0012, §§19–21, 2017]
Distinctive features of the original PDNGR not carried forward into DC2024 or RA 12120:
- Congressional franchise required (Rule 7): Transmission/Distribution pipelines operating as public utilities required a congressional franchise under Article XII §11 of the 1987 Constitution (60% Filipino ownership). DC2024 revised this to PSA/CA 146 compliance only; RA 12120 eliminated the franchise requirement entirely (only DOE Permit needed). [DC2017-11-0012, Rule 7, 2017]
- Infrastructure Development Period (IDP) TPA exemption (Rule 8): New infrastructure projects were exempt from TPA obligations during an IDP — a concession to initial capital investment. This exemption was removed in DC2024-01-0007 and not carried into RA 12120. [DC2017-11-0012, §8.3, 2017]
- Participants: Importer + Supplier only (Annex C): The original PDNGR recognized only two commercial participant categories: Importer (LNG) and Supplier (natural gas). DC2024 added Aggregator, Reseller, and Bunker Trader; RA 12120 formally defined all four. [DC2017-11-0012, Annex C, 2017]
- ITMS on DNG-REC (Annex A): DNG-REC had four member Directors (OIMB, LS, FS, plus ITMS). DC2024-01-0007 and DC2025-04-0005 removed ITMS, leaving three member Directors. [DC2017-11-0012, Annex A §2, 2017]
- Singapore ICC arbitration (Rule 16): DOE–Operator disputes went to ICC arbitration with Singapore as venue. This was removed in DC2024, which reverted to DOE administrative proceedings under DC2002-07-004. [DC2017-11-0012, Rule 16, 2017]
DC2017-11-0012 vs. RA 12120 — Key Structural Changes:
| Feature | Prior PDNGR (DC2017) | RA 12120 + IRR |
|---|---|---|
| Legal basis | Regulatory issuance (DC) | Primary legislation |
| Pipeline public utilities | Congressional franchise required | Only DOE Permit required; no franchise |
| TPA | Mandatory for excess capacity; IDP exemption | TPA vs Own-Use Permit tracks; no IDP exemption |
| Participants | Importer, Supplier | Supplier, Aggregator, Bunker Trader, Reseller |
| DNG-REC members | 4 Directors (incl. ITMS) | 3 Directors (excl. ITMS) |
| Aggregation mechanism | None | §§4(b)(c): DOE sets minimum indigenous % |
| Stranded asset tracking | Absent | §5(r) mandates public tracking |
| Renewable gas scope | Absent | §36 and §4(jj): hydrogen/ammonia under DOE |
| Indigenous gas priority | No explicit mandate | §23 mandates priority + minimum % |
IRR Implementation (DC2025-04-0005)
DC2025-04-0005, issued March 26, 2025 by Sec. Lotilla (effective ~April 10, 2025), is the IRR of RA 12120. It provides procedural detail not in the Act itself. [DC2025-04-0005, §§1–68, 2025-03-26]
DNG-REC
The IRR creates the Downstream Natural Gas Review and Evaluation Committee (DNG-REC) as the primary permit evaluation body. [DC2025-04-0005, §22, 2025-03-26]
| Role | Position |
|---|---|
| Chair | Supervising Undersecretary, OIMB |
| Vice Chair | Supervising Assistant Secretary, OIMB |
| Members | Director (OIMB), Director (Legal Services), Director (Financial Services) |
A DNG-TWG (Technical Working Group) conducts legal, technical, and financial evaluation before DNG-REC decision. Secretariat is headed by the Assistant Director, OIMB; Natural Gas Management Division (NGMD) provides staff support.
Processing timeline: DNG-TWG evaluates in 12 working days → DNG-REC decides in 5 working days. DOE Secretary approval required only for PTC and POM. [DC2025-04-0005, Annex A, 2025-03-26]
Permit Sequence and Validity
| Permit | Trigger | Validity |
|---|---|---|
| Notice to Proceed (NTP) | Pre-construction site/design clearance | 1 year |
| Permit to Construct (PTC) | Application 30 wd before NTP expiration; DOE Secretary approval | Per approved project baseline schedule |
| Permit to Operate and Maintain (POM) | Application 30 wd from completion; onsite verification by DNG-TWG + IA-HSSE IMT (10 wd); DOE Secretary approval | 25 years maximum; renewable |
| Other Permits (PTE, PTR, PTM, Decommissioning) | Per circumstances | Per Permit Holder proposal, DOE-verified |
[DC2025-04-0005, §§20–21, Annex A, 2025-03-26]
Accreditation
Participants (suppliers, aggregators, bunker traders, resellers) must obtain DOE Accreditation before conducting natural gas trade. Validity: 5 years from issuance, renewable every 5 years. DNG-REC approval required for all accreditations. [DC2025-04-0005, §§29–30, 2025-03-26]
Three Types of TPA
The IRR distinguishes three TPA modes based on facility type and access structure: [DC2025-04-0005, §§44–46, 2025-03-26]
| TPA Type | Facility | Access Mode |
|---|---|---|
| Negotiated TPA | Non-public-utility facility | Permit Holder and third party agree on private commercial terms; Permit Holder submits notarized copy to DOE |
| Competitive TPA | Non-public-utility facility | Permit Holder offers capacity to non-Affiliates via open, transparent, non-discriminatory selection; terms of reference submitted to DOE |
| Regulated TPA | Conventional Transportation System (fixed pipeline — public utility) | Open offer to public; availment per DOE-approved guidelines; rates and terms subject to DOE regulation |
Congestion management: if TPA Permit Holder withholds capacity without justifiable reason, DOE may direct its release per TPA Code. [DC2025-04-0005, §47, 2025-03-26]
Key IRR Deadlines
| Deadline | Action |
|---|---|
| Within 6 months of IRR effectivity (~Oct 2025) | DOE to issue Gas Policy (aggregation rules, indigenous gas prioritization, supply mechanisms) |
| Within 2 years of IRR effectivity (~Apr 2027) | DOE to issue PDNG Transmission Code, PDNG Distribution Code, PLSR Terminal Code, and TPA Code |
| Within 2 years of IRR effectivity (~Apr 2027) | Existing Permit Holders and Participants must comply with all Act provisions |
[DC2025-04-0005, §§5(g), 5(p), 59, 2025-03-26]
Administrative Fine Schedule (IRR)
| Violation | Fine |
|---|---|
| Industry standards violation | ₱500,000 per violation |
| Non-compliance with lawful DOE orders | ₱1,000,000 per instance |
| Failure to submit reportorial requirements | ₱200,000 per instance |
| Failure to fulfill §§52–53 duties | ₱100,000 per instance |
Schedule reviewed every 5 years. Anti-competitive behavior penalties per RA 10667. [DC2025-04-0005, §57, 2025-03-26]
Repealing and Saving
DC2025-04-0005 repeals DC2024-01-0007 (Amended Philippine Downstream Natural Gas Regulation). PD 87, RA 9136 (EPIRA), and RA 9513 (RE Act) are explicitly saved — they remain fully operative. [DC2025-04-0005, §§66–67, 2025-03-26]