NR
Marcel P. T. Chin-A-Lien | Principal Founding Partner and Chief Architect | GLIAG
GLIAG-ESS-NR-20261004-001 | Revision 002 | 4 October 2026
We recommend advancing a competitively procured feasibility programme for a new refinery in Suriname, integrated where commercially justified with Gas-to-Shore, storage and marine logistics. The October fuel-market disruption adds a credible strategic reason to develop the project: crude-export income does not guarantee access to diesel, jet fuel or gasoline when suppliers restrict exports. It strengthens the case for investigation and preparation; construction should follow only when the project demonstrates durable cash generation and reliable supply.
The investor proposition is a refinery sized to contracted demand, configured for qualified feedstocks and supported by a competent operator. Its national proposition is continuity of essential fuel supply and greater flexibility in procurement. These propositions reinforce each other, but their benefits belong in separate financial accounts. Government should not disguise a strategic service as an assumed commercial refining margin.
This essay evaluates the eight supplied screenshots independently. It corrects the inference that Europe lacks refining power because its plants are absent from a largest-site ranking, develops the geological and commercial implications for Suriname, and proposes an investment sequence. NR means New Refinery; GtS means Gas-to-Shore. Numerical cases below are transparent screening assumptions, not engineering estimates or a bankable feasibility study.
Reuters reported on 1 October 2026 that Chinese refiners suspended October fuel exports to preserve domestic stocks, subject to possible later changes. Reuters also reported US pressure on France and Germany to release diesel stocks, with a potential US export restriction. The Financial Times reported on 30 September that Russia extended its diesel export ban through October. These reports support the mechanism illustrated in the screenshots: export availability can change through political decisions even where processing capacity exists. They do not establish a fuel shortage in Suriname. [1–3]
The photographed post points to an article dated 2 October 2026 by Giacomo Prandelli. Its accessible introduction and the supplied screenshots were examined; the full subscription article was not accessible. The chart is a ranking of maximum potential site capacity, not a verified inventory of operating output. It mixes refinery complexes and individual sites, and its top-15 regional arithmetic does not clearly reconcile every entry. We therefore do not adopt its ranking, capacity totals, Russian percentage loss or causal claims about climate policy as investment evidence. [4]
FuelsEurope reports 72 mainstream refineries operating in the EU, UK, Norway and Switzerland at the end of 2025, with 625.4 million tonnes of annual primary capacity. Absence from a list of the largest individual sites plainly does not mean absence of refining. Product-specific balances, conversion units, maintenance, import routes and inventories matter more than plant size. Europe can have substantial capacity and still be exposed to diesel imports. [5]
The transferable lesson for Suriname is exposure to tradable products. A large oil discovery, a crude-export terminal and a sovereign wealth fund answer different questions from whether a vessel can deliver the required diesel specification next week. A local refinery can reduce dependence on foreign processing decisions, while remaining exposed to crude opportunity cost, equipment availability and its own outages.
What exactly is scarce? If the constraint is temporary shipping capacity, storage and diversified procurement may offer faster protection than a refinery. If the constraint is recurring unavailability of suitable finished products, domestic conversion becomes more valuable. If the constraint is affordability, an uneconomic refinery can make the problem worse. The investment study must identify the binding constraint before selecting the asset.
Would the country still need the project after crisis margins normalise? A viable answer requires recurring customers, realistic operating costs and an efficient product slate. Scarcity premiums may finance buffers or improve a strong project; they should not justify a weak base case. The counterfactual is a well-run import system with diversified suppliers and adequate stocks, rather than an intentionally fragile import system.
Who pays for resilience? Households benefit from reliable transport and food distribution; mines, ports and fisheries benefit from fewer interruptions; the Treasury may benefit from a smaller exposure to sudden product-price shocks. The refinery company captures only the revenues in its contracts. Any separately purchased reserve or supply-availability service needs transparent pricing and measurable obligations.
Can one refinery become another concentration risk? Yes. A single local plant without emergency imports and adequate stocks exchanges foreign supplier dependence for domestic asset dependence. The strongest proposal combines refining with alternative import access, protected inventories, redundant utilities and disciplined maintenance.
The Golden Lane geological framework helps organise the feedstock search; it cannot replace laboratory assays. Source facies, maturity, migration, mixing and reservoir alteration affect crude properties. The commercially relevant question is how those properties behave in the specific process units and product markets proposed. Our earlier Golden Molecule essay sets out this geological-to-refinery framework and distinguishes offshore crude families from onshore Saramacca crude. It is background interpretation rather than an independent certification of future refinery yields. [9]
Before selecting configuration, obtain representative full crude assays and distillation curves, sulphur and nitrogen by fraction, acidity, metals, wax and cold-flow properties, salts, water and stability. Test blending and compatibility. Model hydrogen consumption, catalyst life, corrosion, residue outlets, jet certification and diesel cold-flow requirements. API gravity and a whole-crude sulphur number alone cannot establish a profitable diesel yield. [10]
TotalEnergies identifies GranMorgu as a sanctioned development with a 220,000 b/d FPSO and first oil expected in 2028. This provides an identifiable prospective supply source; it is not a domestic refinery supply commitment. Secure contracted crude access, delivery arrangements and pricing before treating that production as available feedstock. Project economics must value domestically sourced crude at its export opportunity cost, adjusted for demonstrable logistics differences. [7]
Suriname already has a refinery. Staatsolie identifies Tout Lui Faut processing capacity as 15,000 b/d and products including diesel, gasoline, fuel oil and bitumen. The decision is therefore incremental: expand or upgrade the existing system, construct a separate plant, or combine imports, storage and selected processing investments. Existing assets must be evaluated through engineering and commercial due diligence, without assuming that an offshore crude can be substituted into the present configuration at no cost. [6]
GtS may offer fuel, steam and power options for a refinery and a potential natural-gas feedstock for hydrogen manufacture. Each advantage depends on delivered gas price, treatment needs, reliable volumes, pipeline and generation costs, and the alternatives available. Gas can support process efficiency; it does not make the refinery emissions-free. Hydrogen production also creates an emissions and financing question that must be included in design.
Staatsolie announced commercial-field approval for Sloanea on 11 November 2025. Its announcement described an FLNG development concept, a planned FID in the second half of 2026 and possible first gas in 2030. This is not evidence of a signed domestic GtS supply agreement, nor confirmation that the planned FID has occurred. A refinery should not rely on Sloanea gas without an independently verified allocation, development schedule and binding delivery contract. [8]
The less obvious interaction is demand destruction. If gas replaces liquid fuels in power generation or industrial boilers, those barrels must disappear from the refinery demand forecast. A refinery designed on pre-GtS fuel consumption may subsequently become an oversized export business. Distinguish transport, marine, aviation, mining and industrial demand from electricity-related liquid-fuel demand, then forecast both with and without gas substitution.
The combined strategy is selective: GtS displaces suitable stationary fuel demand, while refining supplies liquid-fuel uses that remain competitive. Run refinery and gas economics separately before assessing shared infrastructure. Allocate costs by documented usage and avoided expenditure. Count a displaced fuel barrel once; do not book both the full refinery import saving and the full GtS saving against it.
The following case uses a hypothetical 30,000 b/d refinery at 90% utilisation: 9.855 million crude barrels processed annually. Annual contribution equals throughput multiplied by the realised product-basket netback less crude opportunity cost and variable processing costs. The contribution margins of USD 3, 6 and 10 per crude barrel below are assumptions after variable costs, but before fixed costs, sustaining capital, debt service, tax and shareholder distributions. They are not quoted market margins.
At those three assumptions, annual contribution is USD 29.6 million, USD 59.1 million and USD 98.6 million respectively. Every USD 1/bbl movement changes annual contribution by about USD 9.86 million at the assumed utilisation. At 75% utilisation, the corresponding sensitivity falls to USD 8.21 million, while fixed costs remain. Capacity is therefore a poor substitute for sustained profitable throughput.
For scale, a hypothetical USD 1 billion investment at a 10% capital-recovery rate over 20 years requires approximately USD 117.5 million annually, using a standard annuity calculation. That equals USD 11.92 per processed barrel at 90% utilisation, before fixed costs and sustaining capital. This is not a capex estimate, required return forecast or project valuation. It shows why configuration, capital discipline and utilisation must dominate the investment discussion.
The project model should reconcile monthly feedstock and product balances, landed import parity, export netbacks, duties, credit losses, working capital, turnarounds and depreciation. Include separate financing schedules and calculate debt-service coverage from cash available for debt service rather than EBITDA. No project IRR, NPV, payback or DSCR can responsibly be certified from the screenshots or these screening assumptions.
Assume, solely for illustration, that 20,000 b/d of a genuinely replaceable imported product basket faces an additional USD 20/bbl scarcity premium for 90 days. Gross premium exposure is USD 36 million. At 40,000 b/d it is USD 72 million. The calculation is volume × days × premium, and does not assume that all refinery throughput becomes the scarce product. Domestic refining protects this exposure only to the extent that its actual compliant output substitutes for those imports and remains available during the disruption.
Avoided import expenditure is not net national value. Deduct crude export earnings forgone, imported catalysts and equipment, foreign financing and operator payments, environmental costs and any public subsidy. Compare the result with the cost of stocks and diversified imports. Refining may keep part of the conversion margin and local services in-country, but it does not retain the entire value of the imported barrel.
Stock planning also needs arithmetic. At an assumed critical-fuel demand of 20,000 b/d, 30 days of usable stock means 600,000 barrels; at USD 100/bbl it ties up USD 60 million in inventory before tanks, financing, handling and losses. This is an illustrative reserve case, not a recommended reserve requirement. Product availability during a refinery outage, usable tank capacity and replenishment time must determine the final design.
A useful resilience indicator is the share of critical product demand deliverable during a simultaneous supplier disruption and local asset outage. That reveals weaknesses hidden by annual capacity totals. Evaluate independently operated tanks, alternative jetties, spare parts, power backup, water availability and emergency product contracts. A refinery adds resilience when these dependencies are managed as a system.
The defensible regional position is a reliable supplier of certified fuels to contracted customers in Suriname and selected nearby markets. Shorter routes and smaller delivery parcels may help; each claimed advantage requires an actual freight quote and customer comparison. Large export refineries may retain structural cost advantages. Europe is a potential outlet for qualified surplus cargoes, but should not anchor the investment without durable offtake and a competitive delivered netback.
The IEA Oil 2025 outlook anticipated net global refining additions exceeding refined-product demand growth through 2030. That outlook predates the October 2026 disruption and is used here as a structural downside test, not a current market-price forecast. A long-lived Suriname asset must survive both trade interruptions and periods of inexpensive imported products. [11]
Our base planning scenario is continuing episodic supply stress with margins returning toward competitive levels between events. The project proceeds only if its normal-market case meets the sponsor’s return requirement. A prolonged fragmentation scenario raises the value of reliable regional delivery, provided crude access and operations remain intact. An oversupply and faster-substitution scenario depresses product margins and reduces domestic demand; staged capacity and export contracts become decisive.
No probabilities are assigned without a calibrated forecasting model. Monitor product cracks, Atlantic freight, supplier export rules, regional stock coverage, local customer contracts, gas delivery milestones and engineering capex quotations. A sustained deterioration in post-GtS demand or normalised margins should reduce project size or halt the investment, even if political enthusiasm remains strong. A refinery begun now cannot resolve this week’s shortage; immediate protection comes from procurement and usable stocks.
Select an experienced operating partner through competition and require credible commissioning, staffing and maintenance plans. Contracts should address product quality, volumes, credit support, crude-pricing formulae, maintenance outages and remedies. Availability obligations must remain achievable under force majeure and should not imply unlimited guarantees. Lenders need enforceable rights and technical assurance, rather than reliance on a sovereignty narrative.
A storage and logistics company can be evaluated separately from the refining company, with shared facilities governed by transparent service agreements. This allows commercially viable early infrastructure to proceed while preserving the option to add conversion later. A tolling arrangement with an established regional processor is another credible comparison, although it retains exposure to foreign operating conditions and export policy.
If government purchases a strategic reserve or availability service, make its payment explicit, budgeted and performance-based. Domestic fuel-price controls that prevent cost recovery can undermine supply security. Public participation should be justified against alternative uses of capital, with independent procurement and reporting. Refining, power, gas and crude production should have auditable accounts and arm’s-length interfaces.
Environmental and social work belongs in feasibility, not after plant selection. Assess coastal flood and drainage risks, spills, air emissions, water withdrawal, wastewater, occupational safety and community effects. Evaluate emissions and remediation costs alongside the financing terms they influence. The ability to operate safely and remain financeable is part of the commercial design.
In the first 90 days, build a product-by-product demand and import dataset, quantify critical services, secure assay access, compare sites and commission a pre-feasibility competition. Gather preliminary customer commitments and delivered crude, gas and logistics quotations. This is a proposed work programme, not a forecast that approvals or contracts will be completed in 90 days.
Over the following study phase, compare four alternatives on an identical basis: improved imports with storage, existing-refinery upgrades, a new appropriately configured plant, and contracted regional processing. Candidate scales of 20–30, 50 and 75–100 kb/d can be screened; none is endorsed here. Do not scale from offshore production alone. Select the configuration that meets the actual product balance at the best risk-adjusted cost.
Advance to front-end engineering only with credible feedstock access, bankable customer demand, a suitable site, an experienced operator and a downside case that supports financing. Final sanction requires a supported capital estimate, permits, independently reviewed process guarantees, committed financing and contracts. The current evidence establishes an additional strategic rationale; it does not establish that these gates have passed.
GLIAG’s role is to connect subsurface interpretation, feedstock qualification, commercial modelling and policy choices in one accountable decision process. The proposed NR and GtS programme should make those links visible to investors. GIP and Basin Watch can support the evidence trail and monitoring as their workflows become operational; this essay does not claim that the analysis has been deployed to the live platform.
Yes, the October export restrictions add another reason to pursue a New Refinery in Suriname: they demonstrate that buying power and crude wealth do not always secure finished-fuel delivery. The most persuasive investment case is reliable local and regional conversion supported by qualified crude, contracted demand and disciplined operating costs.
We advocate moving the project forward through feasibility, commercial engagement and staged infrastructure. The strongest promotion is a proposal that can survive scrutiny: competitive in ordinary markets, useful in stressed markets, and coordinated with GtS so that gas substitution improves the national system without leaving the refinery oversized.
GLIAG’s proprietary Bankable New Refinery 5-Pack is available on commercial terms to serious investors, strategic sponsors, refinery operators, offtakers, banks, development finance institutions and government principals. It connects the geological feedstock case with commercial configuration, financing logic and sovereign value in five coordinated deliverables. Acquisition, licensing and commissioned adaptation can be discussed for Suriname, Guyana or a coordinated Guyana–Suriname platform, subject to scope, confidentiality and written agreement.
| Component | Content and investment purpose |
|---|---|
| 1 Terms of Reference | Defines the sponsor mandate, study scope, feedstock and market workstreams, technical requirements, governance and acceptance criteria. |
| 2 Refinery Feasibility Study for Bankability | Integrates the pre-feasibility basis, assays, configuration options, product balances, utilities, logistics and phased capital and operating costs. |
| 3 Dynamic Financial Model | Connects yields and commercial assumptions to cash flow, NPV, IRR, debt coverage, tax, working capital and downside sensitivities. |
| 4 Bankable Investors Deck | Presents the investment thesis, evidence, risk allocation, financing requirements and next decision gates for sponsors and finance providers. |
| 5 Executive Investment One-Pager | Condenses the opportunity, key assumptions, investment request and conditions for progression into a senior decision brief. |
To request a confidential introductory briefing and the scope and fee proposal, contact Marcel P. T. Chin-A-Lien at info@gliag.com, quoting “New Refinery 5-Pack”. Access to proprietary studies and models is arranged under NDA and the applicable engagement or licence terms. The package is designed to support a bankability process; financing approval remains subject to project-specific engineering, contracts, permits, due diligence and lender decisions.
Request the New Refinery 5-Pack commercial briefing
Read The Billion-Barrel Conversion Gap and published commercial scope
The following connected reading brings together the author’s publicly accessible essays directly relevant to New Refinery development, GtS, feedstock qualification, energy security and sovereign conversion. Titles link to the individual website articles; each line explains its relevance. Earlier numbers and schedules remain historical assumptions from their original editions, rather than updated forecasts endorsed by this essay. The category archives below retain access to related publications and subsequent additions.
Investment Insights: Guyana & Suriname Billion-Barrel Refinery Opportunity
The Billion-Barrel Conversion Gap develops the phased GSB refinery investment case and introduces the proprietary commercial Refinery 5-Pack.
Why Suriname Needs a Modern Oil Refinery
The original modern-refinery proposition examines the economic, strategic and social case for domestic processing in Suriname.
Invest in Suriname: A Self-Funding Modular Refinery
The Refinery That Pays for Itself introduces the commercial study, financial waterfall and controlled investor access under NDA.
How a Suriname’s New Refinery Can Ensure Energy Security
Examines the distinction between crude availability and finished-fuel security, and the refinery’s role in the conversion economy.
Guyana-Suriname Basin: Time to Build a Refinery Before 2028
One Billion Barrels, Zero Refined argues for timely downstream preparation alongside offshore development; its milestones reflect its publication date.
Transforming Suriname: From Value Leakage to Capture
Sets out phased modular refining as a mechanism for reducing value leakage and building an SH-2050 conversion platform.
Impact of Suriname’s New Modular Refinery
Analyses the refinery’s potential BPM6 current-account effects and distinguishes national macroeconomic value from project returns.
Suriname’s Economic Transformation: The GLIAG Model Explained
Combines hybrid FLNG, Gas-to-Shore and modular refining in an integrated economic-transformation strategy.
Powering Future: Gas-to-Shore for Suriname and Guyana
The Sovereign Gas Conversion evaluates hybrid export and domestic-gas development, investment gates and the parallel GtS 5-Pack.
Suriname’s Gas Architecture: A Pre-FID Strategy
Before FID examines the legal, commercial and industrial architecture required to preserve domestic gas options before commitments become fixed.
Suriname’s Multi-Hub Future: Turning Gas-to-Shore into Sovereignty
Links multiple offshore hubs to phased onshore gas infrastructure, refinery utilities, industrial demand and sovereign capability.
Why Gas-to-Shore Infrastructure and New Refinery are Key to Guyana-Suriname Development
Explains how continuing exploration can support the long-term infrastructure rationale for GtS and a New Refinery.
From Gas-to-Shore to Growth-to-State
Explores gas utilisation as a platform for reliable power, industry, infrastructure, employment and wider national development.
An early Sloanea strategy compares FLNG export, domestic Gas-to-Shore and hybrid regional monetisation architectures.
Evaluating Suriname’s Gas Commercialization Pathways
Compares FLNG, GtS and hybrid commercialisation pathways for Sloanea, including domestic allocation and export monetisation.
Gas Governance in Suriname: The 2050 Framework Explained
Proposes a gas-specific legal and fiscal framework through a Suriname Gas Act 2050 and model gas PSC.
The Legal Framework for Sloanea Gas Development
The Sovereign Molecule examines export licensing, domestic gas reservation and the legal architecture of LNG exports.
Sloanea Gas Discovery: Evolution in Petroleum Law
Places Sloanea development within comparative petroleum law and the institutional evolution of gas-producing jurisdictions.
Sloanea Gas Development: Fiscal Strategies that Drive Investment
Evaluates fiscal incentives for Sloanea through the project-bankability question and the timing of government receipts.
Gas-to-Shore and Refinery: Projecting Suriname’s Cash Waterfall
The Enhanced Waterfall models illustrative fiscal capture from NR and GtS and separates macroeconomic benefits from Treasury cash.
Suriname’s Petroleum Future: Debt vs. Net Sovereign Cash
Debt Before Oil develops Net Sovereign Cash Available after financing, debt service and other claims on petroleum receipts.
GranMorgu’s Revenue Waterfall: A Look at Suriname’s Future
The Waterfall and the Windfall examines GranMorgu’s fiscal allocation and the distinction between headline petroleum value and state receipts.
Inventory vs. Accessible Supply: Key Insights for Suriname’s Oil Sector
The Accessible Barrel Doctrine distinguishes reported stocks from fuel that is physically usable, deliverable and commercially accessible.
Stranded Energy: Lessons for Suriname’s Petroleum Future
When Energy Becomes Stranded compares institutional, security and commercial failures and their implications for Sloanea, GtS and refining.
Commercial Energy Integration: Key Insights for 2026
From Molecules to Markets connects commercial energy integration with GLIAG’s sovereign conversion doctrine.
From Oil to Prosperity: Suriname’s Strategic Energy Execution Framework
Examines coordinated oil, gas and electricity execution while preserving institutional independence and fiscal discipline.
Suriname: Van Olie-inkomsten naar een Weerbare Productiestaat
Dutch-language commentary proposes converting temporary petroleum income into durable production capacity and national resilience.
Transforming Suriname’s Petroleum Wealth into National Capability
Beyond Local Content proposes judging petroleum development by lasting national capability rather than contract awards alone.
Staatsolie’s Financial Future: Beyond Traditional Metrics
Reframes Staatsolie’s financial performance around investment obligations, sovereign exposure and long-term energy capability.
SURINAME HORIZON 2050 and Beyond: From Vision to Execution – The Conversion Execution Navigator
The Conversion Execution Navigator translates SH-2050 into a sequenced programme linking infrastructure, institutions and production timing.
The second Conversion Trilogy essay develops a systems approach to turning geological opportunity into enduring national capability.
Transforming Suriname’s Petroleum into Productive Power
Connects petroleum wealth, industrialisation and sovereign capacity through coordinated offshore-to-onshore development.
Suriname’s Horizon 2050: A Roadmap for Sustainable Petroleum Management
The SH-2050 execution timeline aligns petroleum development, debt obligations, institutional preparation and fiscal-space management.
Suriname Horizon 2050: A Strategic National Transition Framework
Introduces a production-synchronised national transition framework for Suriname through 2050.
Navigating Suriname’s Oil Era: A Fiscal Management Guide
Examines the first-oil fiscal claims stack and the discipline needed before resource income becomes usable development capital.
Transforming Offshore Energy: Governance in the Guyana-Suriname Basin
Places offshore development within climate governance, transition finance and the institutional requirements for sovereign energy transformation.
Golden Lane™ Crude: A Game Changer for Caribbean Refineries
The Golden Molecule connects source-rock interpretation and crude properties to refinery configuration, qualification and bankability.
Analyzing Liza and Suriname’s Oil Properties for Better Insights
Reading the Molecule examines public geochemical evidence, remaining data gaps and a proposed crude-fingerprint qualification programme.
Liza Birth Certificate and Crude’s Geological Journey: From Source to Refinery
Liza’s Birth Certificate follows the crude from its petroleum system to assay interpretation and downstream processing decisions.
Liza Crude: Guyana’s High-Value Light Oil Explained
An earlier Liza crude comparison considers residual fractions and refining value; later assay essays provide the more detailed interpretation.
Guyana Suriname Super Basin – Production-Depletion & Fiscal Revenue Outlook
Examines Stabroek depletion, GranMorgu and the timing of Suriname’s possible production-plateau extension.
GranMorgu Development: A Comprehensive Reservoir Analysis
Synthesises reservoir quality and flow-test disclosures across Blocks 58, 52 and 53 as evidence for development potential.
Suriname’s Block 52: A Dual-Hydrocarbon Revolution
Evaluates Block 52’s oil and gas discoveries and their implications for domestic gas and refinery preparation.
THE EMERGING GAS-CONDENSATE SYSTEM OF THE GUYANA-SURINAME BASIN
Develops a geological interpretation of the emerging gas-condensate system and possible future infrastructure implications.
The Hormuz Factor: Analyzing Global Energy Vulnerabilities
The Hormuz Factor stress-tests transport-route vulnerability and distinguishes hydrocarbon resources from secure physical delivery.
Gas Is Becoming the Geopolitical Fuel — A Reading of 2025 Global Petroleum Trends
Interprets global gas trends and their significance for energy strategy and geopolitical exposure.
Gas as Geopolitical Fuel: Implications for Suriname
Discusses the strategic implications of gas-market geopolitics for Suriname.
Junín 5: Transforming 35 Billion Barrels into Bankable Assets
Applies the conversion-to-bankability test to Junín 5, providing a regional comparator for feedstock, contracts and operating constraints.
[1] Reuters 1 October 2026 Chinese refiners suspend October fuel exports
[2] Reuters 1 October 2026 US pressure on European diesel stocks
[3] Financial Times 30 September 2026 Russia extends diesel export ban
[4] The Merchant’s News 2 October 2026 article linked in supplied screenshots
[5] FuelsEurope statistics refinery capacity and operating sites
[6] Staatsolie Our Business refinery capacity and products
[7] TotalEnergies GranMorgu project overview
[8] Staatsolie 13 November 2025 Sloanea commercial-field approval
[9] GLIAG The Golden Molecule New Refinery dossier Revision 004
[10] US EIA Refinery complexity and processing units
[11] IEA Oil 2025 executive summary structural refining outlook
[12] GLIAG related oil properties essay
[13] GLIAG Gas to Shore archive
Revision 002 adds 48 connected author essays and the commercial New Refinery 5-Pack.
© 2026 GLIAG. Author’s original analysis. All rights reserved. No reproduction, commercial redistribution, automated extraction or use for AI training without written permission, except as permitted by applicable law. Third-party material remains the property of its respective owners. This public strategic essay is not an engineering design, reserve certification, investment offer or legal opinion. Public sources were reviewed on 4 October 2026. Screening assumptions require independent verification before investment. Forward-looking scenarios may differ materially from outcomes.
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