"Bio-bunkers are not capacity constrained; they are economics constrained, and policy asymmetry is dictating where volumes materialise." — Mahnoor Samee, New Fuels Lead APAC, Dan-Bunkering, APPEC 2026
The Margin Squeeze: Why Biofuel Producers Cannot Scale
The headline from APPEC 2026 was unambiguous: European Fatty Acid Methyl Ester (FAME) producers are not capacity-limited. European FAME plants currently operate at only 52% capacity, yet producers cannot justify investment to expand or even maintain current utilisation. The constraint is not hardware—it is the margin collapse between feedstock cost and wholesale price. This disconnect in production margins represents the primary structural barrier to scaling biofuel supply into 2027 and beyond.
The gap between Used Cooking Oil (UCO) procurement cost and Used Cooking Oil Methyl Ester (UCOME) wholesale value averages approximately USD 80 per metric tonne, according to Dan-Bunkering's September 2026 analysis presented to APPEC delegates. Industry experts and financial analysts consider USD 300–400 pmt the minimum margin necessary to sustain a profitable FAME production operation, cover maintenance, debt service, and fund reinvestment. That shortfall of USD 220–320 pmt means producers operate existing capacity at a loss or opt to curtail output entirely, even when market demand exists. Without guaranteed demand at premium prices or substantial policy support through renewable fuel obligations, the capital case for further investment does not close. Existing producers cannot justify retrofitting plants, upgrading quality control, or adding storage capacity when operating margins are insufficient to cover variable costs, much less capital recovery.
Singapore Demand Collapses; Rotterdam Holds—Policy, Not Supply, Decides
Regional fragmentation of biofuel demand is the defining feature of 2026's maritime fuel market. In Singapore, a major global bunkering hub, bio-bunker sales fell 45–60% year-over-year as conventional fuel prices rose and shipowners shifted away from biofuel premiums toward cheaper compliance alternatives such as pooling arrangements and speed optimisation. The economic pressure was simply too high; shipowners facing margin compression could not justify the cost differential of biofuels when conventional low-sulphur fuel oil remained available and operationally simpler. In sharp contrast, Rotterdam achieved two-year highs in biofuel volumes, driven by European Union mandates, FuelEU Maritime compliance incentives, and corporate cargo owner commitments to green freight.
This stark divergence exposes the absence of a genuine global biofuel market for shipping. Instead, policy design at the regional and national level—EU blending mandates, FuelEU Maritime carbon intensity requirements, Brazil's emerging biodiesel rules, and varying port-level incentives—is determining where volumes flow and at what premium. Ship suppliers in low-regulation ports such as Singapore cannot build reliable procurement pipelines because demand is speculative, price-sensitive, and entirely dependent on owner choice rather than legal obligation. Suppliers in regulated markets like the EU and Northern Europe can plan quarterly biofuel contracts with confidence, but only those serving vessel operators committed to EU trade routes or bound by corporate net-zero commitments. For procurement teams managing global fleets, this fragmentation means maintaining separate supplier relationships, negotiating different contract terms, and accepting regional pricing volatility. A USD 80–120 per tonne premium in Rotterdam may be USD 200–250 in Singapore when demand exists, making budget forecasting nearly impossible.
IMO Delay and Four Conflicting Carbon Proposals Create Procurement Paralysis
The International Maritime Organization's decision to defer its net-zero framework formal vote from October 2025 to October 2026 was intended to allow time for consensus-building. Instead, the delay has frozen investment and procurement decision-making across the entire bunker supply chain. The Marine Environment Protection Committee's vote on 17 October 2025 acknowledged that important gaps remained unresolved, but deferral has amplified uncertainty rather than reducing it.
Shipowners cannot justify long-term biofuel offtake agreements without knowing which carbon pricing mechanism will apply and at what severity. Fuel producers cannot commit capital to new FAME processing capacity or storage infrastructure without reliable demand forecasts extending through 2027 and beyond. Charterers cannot lock in green freight agreements with cargo owners because the cost of compliance—whether through biofuel premiums, remedial unit purchases, or emissions fund contributions—remains fundamentally uncertain. Meanwhile, four distinct proposals circulate within the IMO's regulatory framework, each with different economic implications for biofuel. The Economic Incentive Scheme imposes penalties on non-compliant vessels; the Zero-Emission Shipping Incentive Scheme backed by Japan emphasises financial rewards for clean fuels; Argentina's International Maritime Sustainability Funding and Reward scheme creates dedicated infrastructure funds; and the Bahamas-Liberia Feebate model redirects revenues to vulnerable states. Each would create different price signals for biofuel adoption. This regulatory fragmentation—unresolved through 2026 and now scheduled for deliberation in late October 2026 before 2027 implementation—is the primary reason biofuel procurement contracts remain unsigned and long-term pricing remains volatile. Supply chain actors are effectively in a holding pattern, unable to commit capital or sign multi-year agreements until the IMO's October 2026 vote clarifies which carbon cost mechanism will govern the industry.
Rotterdam's Bio-LNG Growth Points to a Niche Solution, Not Scale
One bright spot emerged in early 2026: Rotterdam's bio-LNG volumes grew more than sixfold year-over-year, reaching 17,644 cubic metres in 2025 compared to just 2,775 m³ in 2024. For LNG-fuelled vessels, this represents a drop-in decarbonisation pathway that avoids major equipment modifications and maintains operational flexibility. Bio-LNG production utilises existing biogas infrastructure and methane conversion technology, making it potentially more scalable than FAME in regions with strong waste-to-energy programmes.
However, the absolute volume remains negligible within Rotterdam's total bunkering market. The port bunkered more than 1 million cubic metres of LNG in 2025 for the first time, yet bio-LNG represented less than 1.8% of that volume. Moreover, the broader bunker market contracted significantly. Rotterdam reported total bunker sales declined 25% year-over-year in Q1 2026, with fossil fuel grades bearing the sharpest falls: VLSFO down 44%, HSFO down 25%, and ULSFO down 13%. Bio-fuels absorbed some of that volume reallocation, but the movement is driven by regulatory compliance and carbon accounting strategies rather than cost competitiveness or genuine demand preference. Bio-LNG's advantage remains technical compatibility, not economic scale. Like FAME, bio-LNG supply is episodic, geographically concentrated, and dependent on local policy support. The sixfold growth in absolute terms represents a structural shift in how bunkering infrastructure is being deployed, but not yet a mass-market transition.
Brazil's Biodiesel Mandate: A Template for Regional Policy, Not Global Supply
Brazil's National Petroleum Agency (ANP) is finalising a marine biodiesel blending mandate by year-end 2026, expected to unlock 230–368 million litres of annual demand. For investors and supplier networks, Brazil presents a unique opportunity: its domestic feedstock base—abundant biodiesel production capacity and world-leading ethanol infrastructure—is sufficient to support a marine mandate without competing with global supply chains or disrupting land-use patterns. Unlike European FAME production, which depends on imported waste cooking oil and used fats, Brazil's mandate can draw on domestic oilseed production managed within existing agricultural frameworks.
That self-sufficiency is also why Brazil's decision, while significant for Latin American bunkering hubs like Santos, does not resolve the global supply crunch for biofuels. Supply is not the binding constraint in Brazil; rather, policy design and local demand creation are. Brazil's biodiesel mandate exemplifies how regional policy can unlock biofuel demand when combined with long-term feedstock security and domestic production scale. However, replicating this model globally requires coordinated feedstock policy, integrated port infrastructure investment, and multimodal supply chain alignment—structures that do not exist. For ship suppliers operating across multiple jurisdictions, Brazil's biodiesel mandate and ethanol framework create one more fragmented demand signal layered atop EU mandates, FuelEU requirements, and Singapore's spot-market dynamics. Rather than simplifying procurement planning, regional mandates are proliferating.
What This Means for Bunker Traders and Suppliers in 2027
For suppliers, procurement managers, and ship operators, 2027 will not materially resolve the 2026 picture unless two structural conditions align: hard IMO net-zero clarity (which will not arrive before late 2026 or early 2027 at earliest) and a material improvement in FAME producer margins—which requires either a sharp spike in compliance-driven demand or a sustained drop in UCO feedstock costs. Neither is assured. Global biofuel production is projected to reach only 23 million tonnes of oil equivalent by 2026, yet fully decarbonising shipping through biofuels alone would require approximately 250 Mtoe annually—a gap so stark that biofuels alone cannot be the solution.
Ship suppliers should prepare for fragmented, policy-driven regional demand through 2027 and beyond. Build direct relationships with producers in EU-regulated markets (Rotterdam, Hamburg, Antwerp) to secure quarterly volumes on fixed-price contracts where possible. For suppliers in non-regulated hubs (Singapore, Dubai, Houston), biofuels remain a secondary compliance tool rather than a primary business driver; treat biofuel enquiries as opportunistic rather than baseline. Procurement teams should prioritise securing long-term contracts with vessel operators committed to corporate decarbonisation pledges and green freight agreements with cargo owners—demand that is not dependent on IMO action. Until the IMO votes in late 2026 and regulatory clarity settles margins, the biofuel market will remain a collection of local policies, fragmented regional premiums, and episodic opportunities rather than a unified global commodity.
