Europe’s biofuels sector has faced a string of setbacks. BP has decided not to proceed with a standalone biofuels plant in Rotterdam, signalling a pivot towards lower-risk co-processing in existing refineries and away from an earlier 2030 biofuels target. Days earlier, Shell concluded that completing its Rotterdam facility would not be competitive and chose to stop the project. In the UK, Greenergy first suspended operations and later proposed closing its Immingham biodiesel plant after a strategic review. Ensus has warned that its Teesside bioethanol site could close without additional policy support, with UK trade and tariff changes cited among the pressures. Together, these events point to a tougher environment for HVO, SAF and crop-based ethanol across key European markets.
What happened?
BP’s Rotterdam decision reflects a focus on projects that meet its investment-return thresholds and a shift of biofuel activity towards co-processing and Brazilian ethanol operations. Shell’s review of its Rotterdam project found that expected costs and market dynamics undermined competitiveness, so the company will not restart construction. In the UK, Greenergy’s announcements describe unsupportive market conditions at Immingham, progressing from temporary suspension to a proposed closure and job consultation. Ensus has stated that import tariff changes and market conditions threaten the viability of the Teesside plant, and has engaged with government.
Why it matters?
Two cancelled Rotterdam projects remove sizeable new hydrotreated fuels/SAF capacity from Europe’s near-term pipeline, signalling that large stand-alone builds are struggling to clear return hurdles; both BP and Shell explicitly cited competitiveness and cost as reasons to halt, which tightens expected supply growth for renewable diesel and SAF across the region. In the UK road-fuel market Greenergy’s Immingham proposal would take out roughly a quarter of domestic biodiesel capacity, with the company pointing to market conditions, slower policy increases than the EU and competition from subsidised imports factors that can raise sourcing risk and concentrate supply.
For ethanol, Ensus Teesside has warned of an “imminent” closure risk linked to tariff changes and market conditions; beyond E10 fuel blending, that loss would also hit the UK’s industrial CO₂ by-product stream, for which Ensus is a major producer highlighting cross-sector knock-on effects if domestic output falls.
Taken together, these developments mean airlines, fuel suppliers and fleets face a tougher balancing act: rising legal obligations (e.g., ReFuelEU for aviation) on one side and a slower, more selective build-out of European renewable capacity on the other raising the premium on robust offtake, diversified sourcing and error-resistant evidence chains.
What appears to be driving decisions?
Company statements point to project competitiveness and higher completion costs for new builds in Rotterdam (BP and Shell). UK announcements and trade coverage reference market conditions and competition affecting waste-based biodiesel, and the impact of tariff changes on ethanol economics cited by Ensus and others. These are documented factors rather than speculation, and they explain why some operators are favouring co-processing or deferring standalone capacity until conditions improve.
What to do now?
For the next 12–24 months, assume policy friction and uneven transposition rather than smooth, linear roll-out. Build a plan that works under multiple policy paths: model low/medium/high availability for HVO/SAF/ethanol, and test how each case affects your RED III, ReFuelEU and (in the UK) RTFO obligations, contract volumes and credit positions. Convert this into a calendar of decision points (e.g., when to lock offtake, when to switch feedstocks, when to trigger contingency).
On procurement and contracts, prioritise flexibility over headline price. Use shorter tenors or phased volumes with reopeners tied to recognition/eligibility events (e.g., scheme or national guidance changes), and strengthen legal hygiene: warranties on data accuracy, right-to-audit, change-notification, evidence-retention, and flow-down of scheme rules to sub-suppliers. Where you face import competition, add origin and classification representations (waste/residue status, Annex IX where relevant) plus audit rights to deter misclassification risk.
Operationally, reduce evidence risk before audit week. Harmonise mass-balance boundaries and product groups across sites, reconcile GHG files to current scheme methods, and check that traceability processes match the latest instructions for your scheme and Member State. Run an internal check (or external pre-audit) focused on double-counting controls, supplier due diligence and transaction matching these are the first places strain shows when markets tighten.
On technology choices, if you are evaluating co-processing as a bridge, confirm acceptance in your chosen voluntary scheme and the applicable allocation method before investing; if not accepted in the target scope/market, bank the analysis and avoid sunk cost. For ethanol exposure, stress-test E10/E5 demand, tariff scenarios and by-product dependencies (e.g., food-grade CO₂) so that supply switches do not trigger unexpected downstream issues.
Finally, stay policy-literate without over-committing to any single forecast. Track national transpositions of RED III, Commission implementing acts and airline/fuel supplier guidance on ReFuelEU; in the UK, follow RTFO consultations and any trade/tariff announcements. Where consultations are open, submit evidence on feasibility and timing measured input now often shapes the rules you will live with later.