RA 12120 — Philippine Natural Gas Industry Development Act

Signed: January 8, 2025 Effective: ~January 23, 2025 (15 days after publication)

Note on effective-date: The source-summary ingest pass recorded effective-date: 2024-08 in its frontmatter, but its own body text states “Effective: ~January 23, 2025” — matching this page and the law’s signing date (January 8, 2025) plus the standard 15-day-after-publication rule. The 2024-08 figure appears to be a stray/incorrect value; 2025-01-23 is used here as the better-supported date.

RA 12120 establishes the first comprehensive statutory framework for the Philippine Downstream Natural Gas Industry (PDNGI). It consolidates and supersedes the prior administrative regime (DC 2017-11-0012 / PDNGR), defines agency roles, creates a permit system, mandates indigenous gas priority over imports, introduces the aggregation mechanism, and requires DOE to publicly track stranded asset risk. The law explicitly frames natural gas as a transition fuel with an expected end-state of renewable energy. [RA 12120, §2(b)(h), 2025]

Chapter I — Policy and Scope (§1–3)

Declaration of Policy (§2)

Fourteen-point policy declaration [RA 12120, §2, 2025]:

Scope (§3)

Covers siting, construction, operation, maintenance, expansion, modification, rehabilitation, decommissioning, and abandonment of all PDNGI Facilities. Also covers accreditation of Participants in natural gas trade (purchase, supply, aggregation, bunkering, reselling, export). All DOE/ERC/agency activities relevant to PDNGI must conform to this Act. [RA 12120, §3, 2025]

Key Definitions (§4)

[RA 12120, §4, 2025]

Chapter II — Agency Powers (§4–16)

DOE (§5)

DOE has overall responsibility for supervising and monitoring the PDNGI. Powers include [RA 12120, §5, 2025]:

• Prepare the PDNG Development Plan (PDNG Dev Plan) within 2 years of effectivity, reviewed every 3 years; incorporates LNG storage, transmission, and distribution sub-plans; incorporated into the PEP
• Establish gas quality standards and PNS codes via a Technical Committee (TC) co-chaired with DTI-BPS; TC includes academe, trade/industry, consumer, professional associations, research institutions, government, testing institutions
• Create and co-chair (with DENR) an Inter-Agency HSSE Inspection and Monitoring Team (IA-HSSE IMT) — members: MARINA, PCG, DOLE, BFP, DOH, and others
• Issue permits for construction, operation, expansion, rehabilitation, decommissioning, and abandonment of PDNGI Facilities; accredit Participants; acknowledge import/export notifications — all governed by EVOSS (RA 11234)
• Review, suspend, or revoke permits for non-compliance
• Issue PDNG Transmission Code, Distribution Code, PLSR Terminal Code, and TPA Code within 2 years of IRR effectivity
• Endorse suspected anti-competitive behavior to PCC
• Require reports and real-time monitoring access
• Temporarily take over PDNGI operations during national emergency (directed by President upon NEDA recommendation)
• Develop national strategy for integrating renewable gases (hydrogen, ammonia, biomethane, synthetic methane) into the energy mix, with NREB input
• Regulate quality of service and rates of TPA conventional transportation systems (rate-setting on full cost recovery + reasonable return principle)
• Ensure unbundling and publication of TPA fees
• Assess and publicly report stranded asset risk for all natural gas infrastructure — maintain publicly accessible database of projects and risk assessments, updated regularly; issue regulations to mitigate stranded asset risk including early retirement mechanisms [RA 12120, §5(r), 2025]
• Coordinate with agencies to align natural gas development with national climate targets

ERC (§6)

ERC retains powers under RA 9136 (EPIRA) over power industry organization, operation, and regulation. ERC may create offices for regulating power generated from natural gas. [RA 12120, §6, 2025]

DENR (§7)

Co-chairs IA-HSSE IMT with DOE; determines and monitors environmental compliance (siting, construction, operation, decommissioning) under existing environmental laws (Clean Air Act, NIPAS Acts, CARP). Within 6 months of effectivity, DENR must establish national standards for methane emissions and other pollutants from natural gas industries not otherwise regulated. [RA 12120, §7, 2025]

PCG (§8)

Together with DENR, monitors marine environmental protection standards for offshore and waterfront PDNGI Facility siting, construction, operation, and decommissioning. [RA 12120, §8, 2025]

DOTr / MARINA (§9–10)

MARINA has general jurisdiction over LNG carriers. DOTr and attached agencies (LTO, LTFRB, MARINA) in coordination with DOE/DENR/DOH/DTI-BPS issue guidelines and permits for virtual pipelines, motor vehicles, and marine vessels transporting natural gas, and for offshore LNG terminals. [RA 12120, §9–10, 2025]

DTI-BPS (§11)

Co-chairs TC with DOE; formulates, promulgates, and revises Philippine National Standards (PNS) for natural gas and PDNGI Facilities. [RA 12120, §11, 2025]

DOST (§12)

Undertakes scientific and technological R&D for improvement of PDNGI technologies. [RA 12120, §12, 2025]

DOH (§13)

Ensures and monitors HSSE health standards; recommends standards for health risk assessments for gas accidents; develops guidelines for treatment of gas accident patients; requires health data from PDNGI Facilities. [RA 12120, §13, 2025]

PCC (§14)

Referral agency for all anti-competitive behavior. DOE/ERC must refer any suspected anti-competitive agreement or market abuse to the PCC for investigation and adjudication. ERC/DOE assist PCC on highly technical matters. PCC enforces RA 10667 (Philippine Competition Act) across the PDNGI. [RA 12120, §14, 2025]

NCIP (§15)

Upon DOE endorsement (PEP certification or certification as energy project of national significance), NCIP processes Section 59 (IPRA) certification in accordance with timelines under RA 11234 (EVOSS). [RA 12120, §15, 2025]

PERPI (§16)

Pursuant to RA 11572, PERPI conducts R&D on renewable gas technologies (production, storage, distribution) with support from DOST and PNOC. [RA 12120, §16, 2025]

Chapter III — Organization and Operation (§17–26)

Aggregation (§17)

DOE is the lead agency for aggregation. DOE designates aggregator(s) and issues policies on aggregation, adhering to economies of scale, energy transparency, competitive pricing, security and reliability, and consumer welfare. DOE-attached agencies may be directed to participate in aggregation. [RA 12120, §17, 2025]

DOE Permits and Issuances (§18)

DOE evaluates and issues two permit tracks:

• Own-Use Permit — holder uses entire capacity exclusively for own use
• TPA Permit — holder provides third-party access to capacity

DOE also accredits Participants (suppliers, aggregators, bunker traders, resellers) and acknowledges import/export notifications. [RA 12120, §18, 2025]

Confidential Information (§21)

DOE, ERC, or PCC determines whether submitted documents are confidential. Government shall not disclose confidential or proprietary information unless allowed by the holder or required by law. [RA 12120, §21, 2025]

Natural Gas Supply (§23)

Key supply provisions [RA 12120, §23, 2025]:

• Indigenous over imported: procurement and utilization of indigenous natural gas (including by gas-fired power plants) shall be prioritized over imported, consistent with energy security and consumer welfare
• Indigenous natural gas suppliers/aggregators must provide fair and open access in a non-discriminatory, transparent manner
• Power from indigenous natural gas has priority over other conventional energy sources
• DOE shall establish mechanisms for optimal utilization of indigenous gas in generation/transmission/distribution, including mandated minimum percentage of electricity demand to be sourced from indigenous natural gas (percentage reviewed and adjusted as needed)
• PDNGI Facilities may be designed for both indigenous and imported gas, per DOE standards

Decommissioning (§24)

No Permit Holder may abandon/decommission any PDNGI Facility without prior DOE written authorization and DOE-approved abandonment plan based on Philippine or internationally accepted standards. DOE and DENR provide joint guidelines. [RA 12120, §24, 2025]

Chapter IV — Facility Operation (§27–32)

Cross-Ownership (§28)

Entity may hold interest in both upstream and downstream facilities and supply/aggregation — cross-ownership allowed for operational/financial feasibility, subject to PCC review under RA 10667 and DOE review for energy security/cost/market stability impacts. [RA 12120, §28, 2025]

Own-Use vs TPA (§29–31)

Own-Use (§29): Permit Holder uses entire capacity exclusively; may not enter TPA arrangements without DOE approval. DOE may allow TPA by an Own-Use holder if necessary for LNG supply availability.

TPA (§30): TPA Permit Holder must use entire capacity for TPA; may not use for Own-Use without DOE approval. Regular capacity reports submitted to DOE.

TPA Principles (§31): TPA must be transparent, fair, reasonable, and non-discriminatory. Encourages diverse and sustainable market beyond power sector. Safe, secure, reliable, efficient operations for Permit Holder and third-party users. Open consultation with existing and potential users; regular publication of available capacity, terms, conditions, and rates.

Congestion Management (§32): If a TPA Permit Holder cannot or does not release capacity without justifiable reason, DOE may direct its release. [RA 12120, §27–32, 2025]

Chapter V — Standards (§33–36)

All PDNGI Facilities must comply with Philippine and internationally accepted standards for quality, efficiency, structural integrity, and HSSE best practices. Standards apply to both initial permitting and continued operation. [RA 12120, §33–35, 2025]

DOE in collaboration with NREB and PNOC shall develop and implement safety standards for renewable gases (hydrogen, ammonia, biomethane, etc.) addressing their unique properties and risks. [RA 12120, §36, 2025]

Chapter VI — Permit Holder Responsibilities (§37)

Key responsibilities [RA 12120, §37, 2025]:

• Align goals with declared policies and PEP
• Bear direct responsibility and accountability for construction, operation, maintenance
• Secure permit before any activity
• Comply with regulatory obligations and report to DOE and other agencies
• Allow BIR and BOC entry for tax purposes; allow DOE, IA-HSSE IMT, ERC, PCC entry for inspection
• Give preference to qualified local talent and local companies
• Establish and maintain a decommissioning fund at start of operations (consistent with DENR Environmental Guarantee Fund guidelines)
• Unbundle and publish rates and fees
• Not engage in anti-competitive behavior

Chapter VII — Incentives (§38)

Fiscal Incentives

All PDNGI Facilities (DOE-certified) undergo evaluation for possible inclusion in the Strategic Investment Priority Plan (SIPP) for incentives under CREATE Act (RA 11534 / NIRC Title XIII). [RA 12120, §38, 2025]

VAT Exemption

The following are VAT-exempt [RA 12120, §38, 2025]:

• Purchase and sale of indigenous natural gas and aggregated gas (the VAT exemption for aggregated gas applies only to the indigenous-gas portion)
• Purchase and sale of electricity or ancillary services produced by generation facilities using indigenous or aggregated gas

Not VAT-exempt: purely imported LNG without any indigenous gas component (it does not qualify as “aggregated gas”).

Chapter VIII — Competition (§39–40)

No Permit Holder, Participant, or affiliate may engage in anti-competitive behavior or abuse dominant position under RA 10667. DOE issues policies promoting competitive access to both capital and off-taker markets. [RA 12120, §39–40, 2025]

Chapter IX — Penalties (§41–42)

Administrative (§41): Fine range PhP 50,000–5,000,000 per violation for standards violations, code violations, and non-compliance with DOE orders; permit/accreditation suspension or revocation. Schedule of fines increases every 5 years. Anti-competitive behavior penalties under RA 10667. [RA 12120, §41, 2025]

The IRR (DC2025-04-0005, §57) sets specific fine amounts within the statutory range:

[DC2025-04-0005, §57, 2025-03-26]

Criminal (§42): Applicable fines and penalties under existing penal laws for criminal violations. [RA 12120, §42, 2025]

Chapter X — Transitory (§43–44)

Existing PDNGI Facilities constructed prior to effectivity continue under existing permits; must comply with additional requirements as applicable. All existing Permit Holders and Participants must comply within 2 years from IRR effectivity. Existing permits, licenses, and authorizations not inconsistent with this Act remain valid. Existing PDNG Transmission and Distribution Systems continue until expiration of their franchise. [RA 12120, §43, 2025]

Chapter XI — Final Provisions (§45–53)

[RA 12120, §45–53, 2025]

Key Structural Notes

• No franchise required: PDNGI Facilities need only a DOE Permit — not a legislative franchise — distinguishing this from the electricity sector where NGCP operates under a congressional franchise (RA 9511).
• EVOSS applies to all permits: §5(d) explicitly routes all PDNGI permitting through the EVOSS system (RA 11234).
• Stranded asset risk: §5(r) is the first Philippine energy law to mandate public tracking of stranded asset risk — a direct acknowledgment of energy transition risk for gas infrastructure.
• Renewable gases included: §36 extends the law’s scope to hydrogen, ammonia, and biomethane via safety standards, making this the first law to give DOE regulatory authority over hydrogen.
• PCC, not ERC, handles competition: Market conduct issues in PDNGI go to PCC under RA 10667, not to ERC. ERC retains jurisdiction only over power sector rates.

Implementing Rules and Regulations

DC2025-04-0005 (IRR of RA 12120), issued March 26, 2025 by Sec. Raphael P.M. Lotilla, effective ~April 10, 2025. Promulgated pursuant to §49 of this Act. [DC2025-04-0005, §68, 2025-03-26]

Key IRR Provisions

DNG-REC created: The IRR establishes the Downstream Natural Gas Review and Evaluation Committee (DNG-REC) chaired by the Supervising Undersecretary of the Oil Industry Management Bureau (OIMB). DNG-REC evaluates and approves all permits and accreditations; DOE Secretary approval required only for Permit to Construct and Permit to Operate and Maintain. [DC2025-04-0005, §22, 2025-03-26]

Permit sequence: NTP (1 year) → PTC (per approved construction schedule) → POM (max 25 years, renewable). Applications for PTC and POM submitted 30 working days before NTP expiry and facility completion, respectively. [DC2025-04-0005, §§20–21, 2025-03-26]

Accreditation validity: 5 years, renewable every 5 years. [DC2025-04-0005, §30, 2025-03-26]

Three TPA types: Negotiated TPA (private commercial terms); Competitive TPA (open bidding to non-Affiliates); Regulated TPA (public-utility conventional pipeline open to the public, DOE-regulated rates). [DC2025-04-0005, §§44–46, 2025-03-26]

Gas Policy deadline: DOE must issue the Gas Policy (aggregation rules, indigenous gas supply prioritization, minimum indigenous percentage) within six (6) months of IRR effectivity (~October 2025). [DC2025-04-0005, §§5(p), 60, 2025-03-26]

Codes deadline: Four PDNGI codes (Transmission, Distribution, PLSR Terminal, TPA) must be issued within two (2) years of IRR effectivity (~April 2027). [DC2025-04-0005, §5(g), 2025-03-26]

Transition period: Existing Permit Holders and Participants must comply with all Act provisions within two (2) years of IRR effectivity. Pending applications are held in abeyance until the Gas Policy is issued. [DC2025-04-0005, §§59–60, 2025-03-26]

Repealing clause: DC2024-01-0007 (Amended Philippine Downstream Natural Gas Regulation) is repealed. PD 87, RA 9136, and RA 9513 are explicitly saved. [DC2025-04-0005, §§66–67, 2025-03-26]

Full text: Cleaned copy