Gas Governance in Suriname: The 2050 Framework Explained

Gas Act 2050 & Model Gas PSC

GLIAG  |  WORKING PAPER  |  SURINAME HORIZON 2050

Suriname’s Gas Act 2050

and Model Gas PSC

Legal, Fiscal and Contractual Architecture for an Integrated Gas Economy

Drs. M.P.T. Chin-A-Lien, MBA, M.Sc., Ing. Geologist

Principal Founding Partner & Chief Architect — Golden Lane Investments Advisory Group (GLIAG)

Certified Professional Geologist Nr. 5201-1996 (AAPG)

Chartered European Geologist Nr. 92-1996 (EFG)

Energy Negotiator June 2021 (AIEN)

www.petroleumenergyinsights.com

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Introduction

Suriname is entering a decisive phase in its energy development. Deepwater exploration has revealed significant hydrocarbon potential, including commercial-scale gas prospects that could support FLNG, gas-to-shore and regional energy integration. For over thirty years, the Petroleum Law of 1990 and Staatsolie’s Production Sharing Contracts (PSCs) have provided a robust backbone for upstream investment. Yet that backbone is fundamentally petroleum-centric. It does not provide a comprehensive, gas-specific legal, fiscal and contractual architecture for a modern gas economy.

This GLIAG Working Paper sets out an integrated blueprint for a Suriname Gas Act 2050 and a gas-specific Model PSC. It builds on current Surinamese practice, aligns with international fiscal and regulatory guidance, and embeds GLIAG’s Reference Codex approach as a tool for sustained, high-quality governance.

1.  Suriname’s Current Regime: Strengths and Gas-Specific Gaps

The Petroleum Law of 1990, enacted in 1991 and amended in 2001, establishes three key pillars for Suriname’s upstream regime: state ownership of petroleum resources, delegation of operational authority to Staatsolie, and reliance on PSCs as the main contractual instrument. Under Article 2, all petroleum resources belong to the State; rights to explore and produce are granted only through the State, represented by Staatsolie. Staatsolie negotiates PSCs with international oil companies (IOCs), who finance exploration at their own risk, recover costs from cost oil, and share profit oil with the State.

Over time, Suriname has strengthened this framework through three instruments:

• A Stabilisation Decree (S.B. 2018 No. 52), issued under Article 15 of the Petroleum Law, in which the Government provides public-law guarantees to PSC partners on fiscal and legal stability, arbitration and waiver of sovereign immunity;

• A Staatsolie Model PSC (updated in 2021), with R-factor mechanisms, clear royalty and profit-oil structures, detailed cost recovery provisions, and local content obligations;

• A developing ecosystem of explanatory materials and courses that unpack the PSC and its fiscal mechanics.

These elements form a hybrid regime: PSCs are private-law contracts between Staatsolie and contractors, while the Stabilisation Decree elevates key PSC guarantees into public law and binds the Government to respect them. This hybrid structure compares favourably with many regional peers, offering investors a combination of contractual flexibility and public-law certainty.

However, from a gas-governance perspective, the current framework is thin. It lacks:

• A dedicated gas pricing and tariff architecture, with clear netback and cost-plus rules across the gas value chain;

• Explicit domestic gas obligations calibrated to energy security, social policy and project bankability;

• Integrated treatment of gas-to-power, industrial gas, LPG, small-scale LNG and FLNG chains;

• Robust statutory provisions on transboundary reservoirs, unitization and joint development areas in the Guyana-Suriname Basin;

• A comprehensive framework for CCS, hydrogen and digital governance in the gas sector.

The Gas Act 2050 and Model Gas PSC proposed here are designed precisely to fill these gaps, without undermining the strengths of Suriname’s existing petroleum backbone.

2.  The Gas Act 2050: End-to-End Architecture for Gas Governance

A credible Gas Act cannot be a cosmetic overlay on the Petroleum Law. It must offer a standalone, but harmonised, architecture for gas. The proposed Suriname Gas Act 2050 is organised in more than twenty Parts that follow the gas molecule and the revenue stream from subsurface to end-use and sovereign wealth.

2.1  Foundational Provisions

At its core, the Act clarifies state ownership of natural gas, associated gas, condensate and NGLs, and the allocation of subsurface and pore-space rights for CCS, as well as the hierarchy of legal instruments: Constitution, Gas Act, Petroleum Law, fiscal statutes, regulations and contracts.

2.2  Institutional Architecture

The Act defines a purpose-built institutional framework for gas:

• Ministry of Natural Resources as policy lead;

• Gas Authority as system architect and technical brain for integrated gas planning;

• Staatsolie as National Oil & Gas Company and commercial arm of the state;

• An independent Regulator for gas and power, focusing on tariffs, licences and market conduct;

• Pipeline/transmission system operator;

• Market operator for gas trading, capacity auctions and balancing;

• Competition authority, environmental authority and fiscal oversight bodies.

2.3  Functional Domains

With institutional roles clarified, the Act covers the main functional domains of gas governance:

Domain	Key Provisions
Resource Management	Reservoir management, flaring and venting limits, gas reinjection, conservation, domestic unitisation and reserves reporting.
Licensing	Upstream licences for exploration and production; midstream licences for processing, storage, transmission and LNG; downstream licences for distribution, gas-to-power, LPG and industrial gas supply.
Pipeline Law & Network Access	Onshore and offshore pipeline regimes, third-party access, capacity allocation, expansion obligations, interconnection and integrity standards.
Gas Pricing Architecture	Upstream gas valuation, midstream tariffs, domestic gas pricing for power, industry and households, export pricing and indexation, social pricing and strategic reserves.
Transfer Pricing & Anti-Avoidance	Detailed rules for affiliate gas sales, LNG chain transfer pricing, shipping and marketing hubs, management and financing fees, aligned with OECD BEPS and IMF guidance.
Fiscal Regime	Royalties, income and profit tax, resource-rent mechanisms, carbon levies and excise duties, consistent with IMF principles for resource taxation and stability.
Domestic Gas Obligations	Statutory DMO, emergency allocation rules, strategic gas reserves and interaction with PSCs and gas pricing.
Gas-to-Power & Downstream	Gas-fired power, PPAs, ancillary services, grid reliability and integrated planning.
LPG & Household Energy	Licensing and safety standards for LPG production, bottling and distribution, cylinder regimes and social pricing.
LNG and FLNG	Licensing, safety and port rules for liquefaction, LNG terminals and small-scale LNG and bunkering.
Regional Integration	Cross-border pipelines, shared infrastructure, regional LNG hubs and electricity trade in CARICOM and the Atlantic basin.
Transboundary Reservoirs & JDAs	Recognition of shared and cross-border reservoirs, cooperation duties, framework agreements and joint development areas.
Allocation & Unitization	Methodologies for apportioning production and reserves in unitised, commingled or shared fields, including re-determination rules and expert determination.
Environment, CCS & Climate	Methane management, flaring and venting controls, CCS permitting and liability, decommissioning and ESG reporting.
Local Content & Capability	Statutory obligations for employment, training, SME participation and technology transfer.
Digital Governance & International Law	Digital permitting, metering and reporting, smart contracts, and compatibility with UNCLOS, investment treaties and climate agreements.
Dispute Resolution & Transitional Provisions	Expert determination, arbitration, court jurisdiction, change-in-law and transitional rules for existing PSCs and gas projects.

This end-to-end architecture ensures that gas governance is grounded in primary legislation — transparently debated, implemented and updated over time.

3.  A Gas-Specific Model PSC: Operationalising the Act

The PSC is the practical bridge between law and project. Suriname’s existing Model PSC is robust for oil, but gas requires adaptations. The gas-specific Model PSC proposed here keeps the familiar structure but re-engineers key articles around gas realities.

The PSC is organised into ten Parts:

Part	Content
Part 1	General Provisions: definitions, interpretation, scope, and precedence between PSC, Gas Act, Petroleum Law and regulations.
Part 2	Exploration, Appraisal and Development: work commitments, appraisal obligations, gas-focused development plans and reservoir management standards.
Part 3	Cost Recovery and Production Sharing: Cost Gas and Profit Gas articles, cost classification, cost recovery limits and sharing mechanisms for gas, condensate and NGLs.
Part 4	Domestic Gas Obligations and Marketing: DMO article, gas marketing and sales provisions and gas-to-power and industrial supply clauses.
Part 5	Infrastructure, LNG and FLNG: gas-to-shore infrastructure, FLNG and LNG participation/tolling, and transportation and processing agreements.
Part 6	Fiscal, Transfer Pricing and Stabilisation: royalties and taxes, gas-specific transfer pricing article and stabilisation/economic equilibrium clause.
Part 7	Local Content, Environment and HSE: local content and capability obligations, environmental and ESG duties and health, safety and security.
Part 8	Transboundary, Unitization and Shared Facilities: unitization obligations and shared facilities/tie-back provisions.
Part 9	Accounting, Reporting and Audit: accounting standards, measurement and allocation, reporting and transparency, and audit and inspection rights.
Part 10	Dispute Resolution, Assignment and Termination: dispute resolution, assignment/change of control, termination/abandonment, force majeure/change in law and miscellaneous provisions.

4.  Flagship Clause 1 — Domestic Market Obligation (DMO)

The DMO article acknowledges gas as a strategic resource and obliges contractors to supply a defined share of their entitlement gas to the domestic market, at delivery points specified in approved development plans. Priority sectors include power generation, LPG and designated gas-anchored industrial projects. Volumes are capped by technical and commercial availability, avoiding open-ended obligations.

Pricing is anchored in:

• Netback from export or alternative markets, starting from LNG or pipeline prices and subtracting midstream and downstream costs; or

• Cost-plus formulas reflecting full-cycle costs and reasonable remuneration;

as specified in regulations under the Gas Act and Domestic Gas Pricing Orders. This structure balances affordability for domestic users with fiscal and contractual predictability for investors.

GLIAG Drafting Notes

• Set DMO volumes in ranges rather than fixed points, allowing calibration over time;

• Align DMO implementation with gas tariff and transportation codes, so physical and commercial delivery is viable;

• Conduct periodic DMO reviews tied to fiscal rules and national development strategies, drawing on IMF work on resource-rich fiscal frameworks.

The DMO is not a burden on the project. It is the mechanism through which gas becomes a national asset rather than an export commodity.

5.  Flagship Clause 2 — Gas Valuation and Netback Pricing

The Gas Valuation article applies arm’s-length rules to gas sales. For third-party sales, gas is valued at realised prices at the delivery point. For affiliate sales or transfers to related entities for processing, liquefaction or marketing, gas is valued using netback or cost-plus methods, following IMF guidance and industry practice.

Netback calculations start from benchmark LNG or gas prices — JKM, TTF, Henry Hub-linked contracts — and subtract liquefaction tolls, shipping tariffs, regasification fees and marketing costs to derive upstream values. Cost-plus is reserved for cases where netback is impracticable, such as captive domestic uses.

Operationalisation

• The PSC requires detailed documentation of downstream contracts and costs;

• The Gas Act enables regulators and tax authorities to publish reference netback series, similar to ACCC LNG netback price curves, as guidance for market and fiscal decisions;

• Adjustment powers are granted to correct non-arm’s-length pricing, with clear procedures and dispute-resolution mechanisms.

GLIAG’s Codex supports this with formulas, worked examples and links to comparative practice, so netback is applied consistently rather than ad hoc.

6.  Flagship Clause 3 — FLNG and LNG Participation

The FLNG/LNG article allows contractors, subject to Government approval, to participate in or contract with FLNG and LNG facilities, either as equity partners or tolling customers. Costs related to FLNG/LNG can be recoverable under the PSC to the extent that they are directly linked to the Contract Area’s gas and incurred under approved development plans and good industry practice.

Two Model Choices

• Integrated LNG PSC: Liquefaction is treated as part of petroleum operations and fully integrated into cost recovery and profit sharing;

• Separate LNG Joint Ventures: Upstream PSCs focus on gas supply and liquefaction is handled through tolling contracts, with fees entering netback calculations.

Rather than hard-coding one model, the Gas Act authorises both and sets boundary conditions: transparency, alignment with domestic gas obligations, and regulatory oversight of safety, environment and maritime operations. The PSC then provides clear options for project structuring.

The choice between integrated and tolling models is not technical. It is a sovereign decision about how deeply Suriname wishes to participate in its own gas value chain.

7.  Flagship Clause 4 — Unitization of Shared and Transboundary Reservoirs

The Unitization article requires contractors to notify the Government of shared or transboundary reservoirs and, upon request, to enter unitization agreements with other licensees, aligned with domestic law and any intergovernmental framework or joint development treaties.

Unitization Agreements Must Cover

• Definition of the unit area and appointment of a unit operator;

• Initial participating interests and re-determination mechanisms;

• Integrated reservoir management, cost-sharing and allocation plans;

• Data sharing, HSE and decommissioning obligations.

The PSC prohibits commercial production from recognised transboundary reservoirs without approved unitization or joint development arrangements, save for tightly controlled provisional arrangements consistent with international law.

GLIAG’s Codex uses AIPN’s 2020 Unitization and Unit Operating Agreement model and comparative case studies to support negotiating and drafting such agreements.

8.  GLIAG’s Reference Codex: Knowledge Backbone of the Gas Act

A sophisticated Gas Act and PSC regime requires more than legal texts. It needs an institutional memory and analytical capability that can sustain high-quality decisions over time. GLIAG’s Reference Codex is conceived as that backbone.

The Codex is a curated, digital repository that includes:

• Suriname-specific legal instruments: Petroleum Law, Mining Decree, Stabilisation Decree, Staatsolie Model PSC, open-door instructions and local content provisions;

• Comparative contracts and model agreements: deepwater PSCs, gross-split PSCs, JDZ PSCs, AIPN UUOA, and selected gas-to-power and LNG contracts;

• International guidance: IMF and World Bank materials on gas taxation, fiscal frameworks, governance and environmental tax reform;

• Drafting notes: rationale, options and trade-offs for key Gas Act chapters and PSC articles — DMO, valuation/netback, FLNG/LNG, unitization, CCS, hydrogen, local content.

The Codex is not a static library. It is a working tool for policymakers, Staatsolie, regulators and GLIAG’s own drafting teams — making reforms more resilient and transparent.

9.  Implementation, Sequencing and Political-Economy Realism

Experience from resource-rich countries shows that well-designed frameworks can fail if they are implemented without regard to capacity constraints, political incentives and macroeconomic dynamics. For Suriname, three implementation principles stand out.

9.1  Sequencing

The Gas Act should come into force with a core set of companion instruments:

• Gas Fiscal Code that operationalises royalties, taxes, resource-rent mechanisms and carbon levies for gas projects;

• Transfer Pricing Manual for Gas and LNG, detailing netback and cost-plus application, documentation and audit;

• Gas Tariff and Transportation Codes for pipelines, processing and storage, including cost-of-service and regulated return methodologies;

• LNG Export and Gas Safety Regulations, covering liquefaction, terminals, shipping and LPG regimes.

More advanced codes — for CCS, hydrogen, digital trading platforms — can be phased in as projects and capacities mature.

9.2  Fiscal Stability

The Gas Act and PSC stabilisation/economic equilibrium clauses must strike a balance: predictable enough to support long-term investment and financing, flexible enough to accommodate shocks, policy learning and evolving international norms — including carbon pricing and climate obligations. This requires clear boundaries on stabilisation, transparent adjustment mechanisms, and integration with broader fiscal rules for resource-rich countries.

9.3  Governance and Transparency

Good governance and transparency across tax administration, contract management and public finance are essential to converting resource wealth into broad-based prosperity. The Gas Act and PSC regime should embed:

• Disclosure of contracts and revenues aligned with EITI;

• Public reporting on DMO performance and gas pricing;

• Robust oversight institutions with clear mandates and adequate resourcing.

10.  Conclusion: From Legal Draft to Strategic Instrument

Suriname’s move towards gas production offers a unique opportunity to move from a petroleum-centric, hybrid PSC regime to a fully integrated gas governance architecture. The proposed Gas Act 2050 and gas-specific Model PSC, supported by GLIAG’s Reference Codex, provide the legal, fiscal and contractual scaffolding for that transition.

They build on existing strengths — state ownership, a capable Staatsolie, a competitive PSC framework and a stabilisation decree — while addressing gas-specific challenges: domestic obligations, netback pricing, FLNG/LNG integration, transboundary reservoirs, CCS, hydrogen and digital governance.

If implemented with care, sequenced properly and supported by strong institutions, this framework can help Suriname turn offshore gas into long-term national value: affordable and reliable energy, diversified industry, robust and well-governed public revenues, and credible environmental stewardship.

 GLIAG DOCTRINE

 A Gas Act is not a regulatory instrument alone.

 It is the legal expression of a sovereign choice:

 to convert geological fortune into enduring national capability.

About GLIAG

Golden Lane Investments Advisory Group (GLIAG) is an independent strategic petroleum advisory platform specialising in upstream petroleum geology, sovereign energy strategy, PSC architecture and national capability development. GLIAG focuses on the Guyana-Suriname Basin and the broader Atlantic energy frontier, publishing strategic intelligence, working papers and flagship reports at petroleumenergyinsights.com.

Drs. M.P.T. Chin-A-Lien, MBA, M.Sc., Ing. Geologist

Principal Founding Partner & Chief Architect

Certified Professional Geologist Nr. 5201-1996 (AAPG)  |  Chartered European Geologist Nr. 92-1996 (EFG)  |  Energy Negotiator June 2021 (AIEN)

petroleumenergyinsights.com

Disclaimer

This publication reflects the independent professional opinion of the author and GLIAG. It is intended to stimulate strategic discussion and does not constitute legal, fiscal or investment advice. All project schedules, commercial assumptions and development concepts remain subject to operator decisions, government approvals and market conditions.

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