Biofuel mandate tracker

Timeline

1. 2021

   Law 27.640 replaces the earlier 26.093 regime.

2. 2022

   Biodiesel minimum set at 7.5%; ethanol held at 12%.

3. 2026

   Framework remains in force with periodic price resolutions.

4. 2030

   Law scheduled for review and possible extension.

Requirements

• Bioethanol split between sugarcane and maize-based supply under quota.
• Biodiesel minimum may be raised by the enforcement authority within statutory limits.
• Volumes and prices allocated administratively to registered plants.

Compliance status & enforcement

Administrator

Secretaría de Energía

How compliance is shown

Monthly allocation resolutions and delivery reporting by registered producers and blenders.

Penalty for shortfall

Fines, suspension or removal from the biofuels registry under Law 27.640.

Tradable unit

None — physical blend obligation

Timeline

1. 2007

   NSW Biofuels Act commences.

2. 2017

   Queensland biobased petrol mandate begins.

3. 2026

   State mandates continue; a national SAF framework remains under consultation.

Requirements

• New South Wales: ethanol content requirement for primary wholesalers and large retailers, plus a biodiesel requirement.
• Queensland: minimum bio-based petrol and biodiesel content for liable fuel sellers.
• Exemptions available where supply or infrastructure is unavailable.

Compliance status & enforcement

Administrator

NSW Fair Trading / NSW Department of Primary Industries and the Queensland Department of Energy

How compliance is shown

Quarterly volume reporting by liable parties against the statutory percentage.

Penalty for shortfall

Penalty units under each state Act for failure to meet or report the minimum content.

Tradable unit

None — physical blend obligation

Timeline

1. 2024

   Law 14.993 (Combustível do Futuro) enacted.

2. 2025

   E30 gasoline blend and B15 diesel blend take effect (1 August 2025).

3. 2027

   ProBioQAV SAF obligation begins at a 1% emissions reduction for domestic aviation.

4. 2037

   SAF emissions-reduction obligation reaches 10%.

Requirements

• Anhydrous ethanol blend in gasoline set within a 22–35% band by CNPE resolution.
• Biodiesel blend in diesel rising on the CNPE schedule within a range up to B25.
• National SAF programme (ProBioQAV) sets an emissions-reduction obligation for domestic flights from 2027.
• Biomethane obligation introduced for the natural gas grid under the same law.

Compliance status & enforcement

Administrator

CNPE (target setting) and ANP (enforcement)

How compliance is shown

ANP inspects distributors and refiners; blend levels are verified through fuel-quality monitoring and volume reporting.

Penalty for shortfall

ANP administrative fines and product seizure for off-specification fuel.

Tradable unit

None — physical blend obligation

Timeline

1. 2017

   Law 13.576 creates the programme.

2. 2020

   First compliance year with individual distributor targets.

3. 2026

   Annual targets continue to rise under the CNPE decarbonisation curve.

4. 2030

   Cumulative decarbonisation target for the transport fuel matrix.

Requirements

• Annual national decarbonisation target set by the National Energy Policy Council and split among distributors by CNPE/ANP resolution.
• Biofuel producers must hold a certification issued by an accredited inspection firm to issue CBIOs.
• CBIOs are issued per unit of avoided emissions and traded on B3.

Compliance status & enforcement

Administrator

Agência Nacional do Petróleo, Gás Natural e Biocombustíveis (ANP)

How compliance is shown

Distributors buy and retire CBIOs on the B3 exchange; retirement is verified against each firm's individual target.

Penalty for shortfall

Fines from R$100,000 up to R$50 million depending on the size of the shortfall, under Law 13.576/2017.

Tradable unit

CBIO (one tonne CO2e avoided)

Timeline

1. 2011

   Programme starts under AB 32 authority.

2. 2018

   Amendments extend the target to a 20% CI reduction by 2030.

3. 2025

   Amended regulation takes effect with a steeper trajectory and auto-acceleration mechanism.

4. 2030

   30% carbon-intensity reduction versus 2010.

5. 2045

   90% carbon-intensity reduction versus 2010.

Requirements

• Carbon intensity of each fuel is certified through a CARB-approved lifecycle pathway application.
• Deficits are generated by fuels above the annual benchmark; credits by fuels below it.
• Quarterly and annual reporting through the LCFS Reporting Tool and Credit Bank & Transfer System.
• Third-party verification required for most pathway holders and reporting entities.

Compliance status & enforcement

Administrator

California Air Resources Board

How compliance is shown

Credits and deficits are reconciled annually; credits are bankable indefinitely and freely tradable, with a cost-containment credit price ceiling.

Penalty for shortfall

Enforcement action and penalties under the Health and Safety Code; persistent deficit balances trigger a compliance curve adjustment.

Tradable unit

LCFS credit (one metric tonne CO2e)

Timeline

1. 2022

   Regulations registered; registration and reporting begin.

2. 2023

   First reduction requirement of 3.5 gCO2e/MJ takes effect (1 July).

3. 2026

   Requirement steps up on the annual schedule toward 2030.

4. 2030

   14 gCO2e/MJ carbon-intensity reduction.

Requirements

• Reduction requirement rises each year to 14 gCO2e/MJ by 2030.
• Legacy volumetric requirements remain: 5% renewable content in gasoline and 2% in diesel.
• Credits are created by low-carbon-intensity fuel supply, CI-reducing projects at facilities, and end-use fuel switching.
• Registration, quarterly reporting and annual verification by an accredited third party.

Compliance status & enforcement

Administrator

Environment and Climate Change Canada

How compliance is shown

Credit creation and retirement tracked in the CFR Credit and Tracking System; a compliance-credit market plus a compliance fund mechanism capped at a set price.

Penalty for shortfall

Offences and penalties under CEPA 1999, including monetary penalties and prosecution.

Tradable unit

CFR compliance credit (one tonne CO2e)

Timeline

1. 2001

   Fuel-ethanol pilot programme begins in selected provinces.

2. 2017

   Nationwide E10 by 2020 announced by NDRC and partner agencies.

3. 2020

   Nationwide rollout deferred; coverage stays provincial.

4. 2026

   Programme remains province-by-province with SAF pilots added.

Requirements

• Provincial implementation plans designate which regions sell only ethanol gasoline.
• Ethanol supplied by licensed fuel-ethanol producers under state allocation.
• The originally announced nationwide E10 rollout was not implemented on the 2020 timetable.

Compliance status & enforcement

Administrator

National Development and Reform Commission with provincial energy bureaus

How compliance is shown

Provincial monitoring of retail fuel supply and refinery output allocations.

Penalty for shortfall

Provincial administrative enforcement against non-conforming retailers.

Tradable unit

None — physical blend obligation

Timeline

1. 2005

   Ethanol blending begins in major cities.

2. 2008

   Biodiesel blending introduced nationally.

3. 2026

   Blend levels set by resolution and adjusted with supply conditions.

Requirements

• Blend percentages set and adjusted by resolution, with regional variation where supply is constrained.
• Producers must be registered and meet national fuel-quality specifications.
• Blend levels have been temporarily reduced during feedstock or price shocks.

Compliance status & enforcement

Administrator

Ministerio de Minas y Energía

How compliance is shown

Blending reported by wholesalers; verification through the fuel information system SICOM.

Penalty for shortfall

Sanctions under the fuel-quality regime, including fines and suspension of registration.

Tradable unit

None — physical blend obligation

Timeline

1. 2023

   RED III enters into force (November 2023).

2. 2025

   Transposition deadline for transport targets (21 May 2025).

3. 2026

   Union Database reporting operational for all liquid and gaseous fuels.

4. 2030

   29% renewable transport share or 14.5% GHG-intensity cut; 5.5% advanced/RFNBO sub-target.

Requirements

• Choose either a 29% renewable energy share in transport or a 14.5% GHG-intensity reduction by 2030.
• Combined sub-target of 5.5% for advanced biofuels and renewable fuels of non-biological origin by 2030, of which at least 1% RFNBO.
• Crop-based biofuels capped at the 2020 national share plus one percentage point, and no more than 7% of road and rail transport energy.
• All fuel must meet RED III sustainability and GHG-saving criteria, verified through a recognised voluntary scheme.
• Member states had to transpose the transport provisions into national law by 21 May 2025.

Compliance status & enforcement

Administrator

European Commission plus each member state's national fuel authority

How compliance is shown

Fuel suppliers surrender proof of sustainability issued under a Commission-recognised certification scheme (ISCC EU, REDcert EU, 2BSvs, RSB EU RED) and report through the Union Database for Biofuels.

Penalty for shortfall

Set nationally: buy-out charges, fines or licence conditions imposed by each member state's implementing law.

Tradable unit

Proof of Sustainability (PoS) certificates; national tickets or quota units

Timeline

1. 2025

   -2% GHG intensity versus the 91.16 gCO2e/MJ baseline.

2. 2030

   -6% GHG intensity; on-shore power obligation at core ports.

3. 2035

   -14.5% GHG intensity.

4. 2050

   -80% GHG intensity.

Requirements

• GHG-intensity limit applies well-to-wake to 100% of energy used on intra-EU voyages and 50% on extra-EU voyages.
• Containerships and passenger ships must use on-shore power at core TEN-T ports from 2030.
• Compliance may be pooled between ships and banked or borrowed between years within limits.
• Verified FuelEU report and compliance balance per ship, per year.

Compliance status & enforcement

Administrator

European Commission, flag/port state authorities and accredited verifiers

How compliance is shown

Accredited verifier checks the ship's monitoring plan and annual energy report; the compliance balance is recorded in the FuelEU database and a FuelEU document of compliance is issued.

Penalty for shortfall

Remedial penalty proportional to the deficit (EUR 2,400 per tonne of VLSFO-equivalent energy), increased by 10% for repeat non-compliance; ships may be denied entry after two years of non-compliance.

Tradable unit

FuelEU compliance surplus / deficit balance

Timeline

1. 2025

   2% SAF minimum share at Union airports.

2. 2030

   6% SAF, including a 1.2% synthetic-fuel sub-quota.

3. 2035

   20% SAF, including 5% synthetic fuel.

4. 2050

   70% SAF, including 35% synthetic fuel.

Requirements

• Fuel suppliers must ensure the minimum SAF share in aviation fuel supplied at each Union airport.
• A synthetic-fuel (e-SAF) sub-quota applies from 2030 alongside the headline SAF share.
• Aircraft operators must uplift at least 90% of their annual fuel requirement at each Union airport (anti-tankering rule).
• Annual reporting of fuel uplifted and SAF supplied to the EU Aviation Safety Agency.

Compliance status & enforcement

Administrator

European Union Aviation Safety Agency and national competent authorities

How compliance is shown

Annual reports from suppliers and operators, verified against sustainability certification; a Union SAF flexibility mechanism allows pooled supply across airports until 2034.

Penalty for shortfall

Administrative fines set by member states, calculated to exceed at least twice the price differential between conventional jet fuel and SAF for the shortfall.

Tradable unit

None — physical blend obligation

Timeline

1. 2019

   TIRIB replaces the previous TGAP mechanism.

2. 2022

   Renamed TIRUERT and extended to aviation fuel.

3. 2026

   Incorporation rates set annually in the finance law.

4. 2030

   Rates aligned with the RED III transport target.

Requirements

• Separate incorporation rates for the petrol pool, the diesel pool and, since 2022, aviation fuel.
• Sub-targets for advanced feedstocks and caps on crop-based and high-ILUC-risk feedstocks.
• Sustainability proof required through a recognised voluntary scheme and the national CarbuRe registry.

Compliance status & enforcement

Administrator

Direction générale des douanes et droits indirects

How compliance is shown

Annual declaration of energy incorporated; shortfalls are taxed at a rate applied to the missing percentage points.

Penalty for shortfall

TIRUERT tax liability proportional to the shortfall, plus customs penalties for false declaration.

Tradable unit

None — physical blend obligation

Timeline

1. 2015

   Volume quota replaced by a greenhouse-gas quota.

2. 2022

   RED II implementation raises the trajectory and adds advanced sub-quotas.

3. 2026

   Quota level continues on the statutory schedule.

4. 2030

   25% GHG reduction obligation under current law.

Requirements

• Quota obligation expressed as a GHG reduction, not a volume share.
• Sub-quota for advanced biofuels from Annex IX Part A feedstocks.
• Caps on crop-based biofuels and on the use of biofuels from used cooking oil and animal fats.
• Electricity supplied to road vehicles can generate quota credits.

Compliance status & enforcement

Administrator

Hauptzollamt Frankfurt (Oder) — Biokraftstoffquotenstelle

How compliance is shown

Annual quota declaration with Nabisy sustainability certificates; obligations can be transferred between parties by contract.

Penalty for shortfall

Penalty payment per tonne of CO2-equivalent shortfall under §37c BImSchG.

Tradable unit

THG quota (tonnes CO2e), tradable by contract

Timeline

1. 2018

   National Policy on Biofuels sets a 20% target for 2030.

2. 2022

   Target advanced to ethanol supply year 2025–26; E10 achieved nationally.

3. 2025

   E20 blending achieved across the national petrol pool.

4. 2026 onward

   Consolidation of E20 and expansion of flex-fuel and E100 retail.

Requirements

• Oil marketing companies procure ethanol through periodic tenders at administered prices by feedstock category.
• Blend targets are tracked per ethanol supply year (November–October).
• E100 and flex-fuel vehicle rollout supported alongside the blending obligation.

Compliance status & enforcement

Administrator

Ministry of Petroleum & Natural Gas

How compliance is shown

Monthly blending statistics reported by OMCs against the ethanol supply year target.

Penalty for shortfall

Administrative — the obligation sits on state oil marketing companies rather than private obligated parties.

Tradable unit

None — physical blend obligation

Timeline

1. 2023

   Obligation announced; voluntary phase begins.

2. 2025-26

   Mandatory blending phase starts at 1%.

3. 2026-27

   Blending share steps up under the notified schedule.

4. 2028-29

   Obligation reaches 5% CBG in CNG and PNG.

Requirements

• Obligation applies to CNG (transport) and domestic PNG segments.
• Blend share rises on a published annual schedule to 2028–29.
• CBG procured from plants under the SATAT initiative and other registered producers.

Compliance status & enforcement

Administrator

Ministry of Petroleum & Natural Gas and PNGRB

How compliance is shown

National CBG Coordination Committee monitors blending volumes reported by city gas distribution entities.

Penalty for shortfall

Regulatory action by PNGRB against licensed CGD entities that miss the obligation.

Tradable unit

None — physical blend obligation

Timeline

1. 2020

   B30 mandate implemented nationally.

2. 2023

   B35 mandate implemented.

3. 2025

   B40 mandate takes effect from 1 January 2025.

4. 2026 onward

   Government roadmap targets a step to B50 subject to feedstock and capacity readiness.

Requirements

• Allocation quotas issued to registered FAME producers and fuel distributors each year.
• Programme part-funded by the palm oil export levy administered by BPDPKS.
• Blend level applies to both subsidised (PSO) and non-subsidised diesel, with staged coverage.

Compliance status & enforcement

Administrator

Ministry of Energy and Mineral Resources (MEMR) with BPDPKS

How compliance is shown

Quarterly allocation and realisation reporting by producers and distributors; levy-funded incentive payments settled against delivered volumes.

Penalty for shortfall

Reduction or withdrawal of allocation quota and administrative sanctions under MEMR regulation.

Tradable unit

None — physical blend obligation

Timeline

1. 2021–2023

   Pilot phase with voluntary state participation.

2. 2024–2026

   First phase, still voluntary for states.

3. 2027–2035

   Mandatory phase for most ICAO member states.

Requirements

• Annual emissions monitoring, reporting and verification for all operators above the threshold.
• CORSIA eligible fuels must be certified by an ICAO-approved sustainability certification scheme.
• Offsetting requirements calculated from the sector growth factor against the 85% of 2019 baseline.

Compliance status & enforcement

Administrator

ICAO with national civil aviation authorities

How compliance is shown

Verified emissions reports submitted to the state of the operator; eligible emissions units cancelled at the end of each compliance period.

Penalty for shortfall

Enforcement is national — states apply their own penalties for failure to cancel units or report.

Tradable unit

CORSIA eligible emissions unit

Timeline

1. 2023

   Revised IMO GHG strategy sets net-zero around 2050.

2. 2025

   Net-zero framework text approved by MEPC.

3. 2027–2028

   Framework expected to apply following formal adoption and entry into force.

4. 2050

   Net-zero GHG emissions from international shipping.

Requirements

• Annual well-to-wake GHG fuel-intensity limits with a base and a stricter direct-compliance target.
• Remedial units purchased for shortfalls; surplus units tradable and bankable.
• Revenues directed to an IMO net-zero fund supporting the transition.

Compliance status & enforcement

Administrator

International Maritime Organization, enforced by flag and port states

How compliance is shown

Fuel-intensity reporting through the IMO Data Collection System with verification by recognised organisations.

Penalty for shortfall

Purchase of remedial units for the deficit; flag- and port-state enforcement under MARPOL.

Tradable unit

Remedial / surplus unit (tonnes CO2e)

Timeline

1. 2022

   10% by 2030 target announced in the SAF public-private council.

2. 2024

   Judgement criteria for suppliers formalised under the Act.

3. 2030

   10% SAF share of international jet fuel supplied in Japan.

Requirements

• Obligation placed on fuel suppliers rather than airlines.
• Applies to jet fuel uplifted for international departures from Japanese airports.
• Supported by domestic SAF production investment under the GX programme.

Compliance status & enforcement

Administrator

Ministry of Economy, Trade and Industry (METI) — Agency for Natural Resources and Energy

How compliance is shown

Annual plans and reporting by designated energy suppliers under the Energy Supply Structure Sophistication Act.

Penalty for shortfall

Recommendations, publication of non-compliance and orders under the Act.

Tradable unit

None — physical blend obligation

Timeline

1. 2010s

   E10 applied in the Kisumu supply region.

2. 2019

   Energy Act (No. 1 of 2019) provides the enabling powers for biofuels regulation.

3. Jun 2025

   Draft Energy (Biofuels) Regulations published by EPRA for public consultation.

4. 16 Dec 2025

   Energy (Biofuels) Regulations, 2025 gazetted as Legal Notice 199 of 2025.

5. 2026

   Phased implementation of licensed blending across the fuel supply chain.

Requirements

• Construction permits and licences required for biofuel production facilities under Parts II and III of the Regulations.
• Blending, storage and distribution of biofuels carried out only by licensed parties.
• Ethanol and biodiesel must meet national fuel-quality standards before release to the market.
• Phased rollout sequenced by depot as blending infrastructure is installed.

Compliance status & enforcement

Administrator

Energy and Petroleum Regulatory Authority (EPRA), Ministry of Energy and Petroleum

How compliance is shown

Licensing, depot-level blending records and EPRA fuel-quality inspections.

Penalty for shortfall

Licence suspension or revocation and penalties under the Energy Act, Cap. 314.

Tradable unit

None — physical blend obligation

Timeline

1. 2019

   B10 mandate for transport in force nationwide.

2. 2020–2022

   B20 rollout completed across the designated states.

3. 2026

   B30 feasibility and phased implementation under government review.

Requirements

• Petroleum companies must blend palm methyl ester into diesel sold for road transport.
• B20 rollout applied state by state as storage and blending facilities are upgraded.
• B7 applies to the industrial sector.

Compliance status & enforcement

Administrator

Ministry of Plantation and Commodities with the Malaysian Palm Oil Board

How compliance is shown

Licensed blending facilities report volumes; enforcement through petroleum licensing.

Penalty for shortfall

Licence conditions and administrative action under commodity and petroleum regulations.

Tradable unit

None — physical blend obligation

Timeline

1. 2018

   Current HBE framework begins.

2. 2022

   RED II implementation; advanced sub-obligation strengthened.

3. 2026

   Obligation rises on the trajectory set for RED III alignment.

4. 2030

   Alignment with the RED III 29% transport target.

Requirements

• Annual obligation expressed as a share of energy supplied, with sub-obligations for advanced biofuels.
• Separate reduction obligation for the aviation and maritime pools introduced alongside EU rules.
• Double counting applies to Annex IX Part A and B feedstocks within caps.

Compliance status & enforcement

Administrator

Nederlandse Emissieautoriteit (NEa)

How compliance is shown

Hernieuwbare Brandstofeenheden (HBEs) are registered and traded in the NEa register and redeemed annually.

Penalty for shortfall

Administrative fine per unredeemed HBE plus an order to make up the shortfall.

Tradable unit

Hernieuwbare Brandstofeenheid (HBE)

Timeline

1. 2024

   SB 84 signed into law, authorising the standard.

2. 2025–2026

   Environmental Improvement Board rulemaking and programme start-up.

3. 2030

   20% carbon-intensity reduction versus 2018.

4. 2040

   30% carbon-intensity reduction versus 2018.

Requirements

• Regulated parties register and report fuel volumes and carbon intensities to the Environment Department.
• Carbon intensities are set through approved lifecycle pathway applications.
• Deficits from high-carbon fuels must be offset with credits generated by low-carbon fuels, including electricity and biomethane.
• Annual compliance demonstration with verification requirements phased in.

Compliance status & enforcement

Administrator

New Mexico Environment Department and the Environmental Improvement Board

How compliance is shown

A credit and deficit market administered by the Environment Department; credits are bankable and tradable between regulated parties.

Penalty for shortfall

Civil penalties under the Air Quality Control Act plus retirement of replacement credits for outstanding deficits.

Tradable unit

Clean transportation fuel credit

Timeline

1. July 2022

   B5 minimum in all heating oil sold statewide.

2. July 2025

   B10 minimum statewide.

3. July 2030

   B20 minimum statewide.

4. NYC 2034

   New York City reaches B50 under Local Law 119.

Requirements

• Every gallon of heating oil sold for use in New York must contain at least the statutory biodiesel percentage.
• Biodiesel must meet ASTM D6751 and the blended fuel ASTM D396.
• Distributors must document the biodiesel content of each delivery.
• New York City applies its own stricter Local Law 119 schedule for heating oil sold in the city.

Compliance status & enforcement

Administrator

New York State Energy Research and Development Authority with the Department of Environmental Conservation; NYC Department of Environmental Protection for the city schedule

How compliance is shown

Blend content is documented on delivery tickets and supplier records, which are subject to state inspection; NYC filings are made to DEP under Local Law 119.

Penalty for shortfall

Penalties under state energy and environmental law, and civil penalties under the NYC Administrative Code for the city requirement.

Tradable unit

None — physical blend obligation

Timeline

1. 2007

   Nigerian Bio-Fuel Policy and Incentives published in the Official Gazette.

2. 2021–2024

   Ethanol and biodiesel project development advanced with partners.

3. 2026

   E10 blending still awaiting domestic supply and an enforcement instrument.

Requirements

• Domestic feedstock and ethanol plants developed under the NNPC-led programme.
• Blending to be introduced as domestic production capacity comes online.
• Fiscal incentives available to approved biofuel projects.

Compliance status & enforcement

Administrator

Federal Ministry of Petroleum Resources with NNPC Limited

How compliance is shown

Project approvals and off-take arrangements; no enforced supplier obligation yet.

Penalty for shortfall

Not applicable until a blending obligation is gazetted.

Tradable unit

None — physical blend obligation

Timeline

1. 2009

   Turnover requirement introduced.

2. 2020

   Aviation biofuel requirement of 0.5% begins.

3. 2026

   Road and aviation shares continue on the regulated schedule.

4. 2030

   Requirements aligned with the national climate plan.

Requirements

• Road transport turnover requirement with an advanced-biofuel sub-requirement.
• Aviation fuel suppliers must supply a minimum share of advanced sustainable aviation fuel.
• Non-road machinery and shipping covered by separate requirements.

Compliance status & enforcement

Administrator

Miljødirektoratet (Norwegian Environment Agency)

How compliance is shown

Annual reporting of volumes and sustainability documentation to the Environment Agency.

Penalty for shortfall

Coercive fines and enforcement under the Pollution Control Act.

Tradable unit

None — physical blend obligation

Timeline

1. 2016

   Programme begins with a 0.25% reduction.

2. 2022

   Rulemaking extends targets to 2035.

3. 2030

   20% carbon-intensity reduction.

4. 2035

   37% carbon-intensity reduction.

Requirements

• Registered importers report volumes and carbon intensities quarterly.
• Carbon-intensity values come from OR-GREET certified pathways.
• Annual compliance report and third-party verification for larger reporters.

Compliance status & enforcement

Administrator

Oregon Department of Environmental Quality

How compliance is shown

Credit and deficit accounting in the Oregon Fuels Reporting System, with tradable credits and unlimited banking.

Penalty for shortfall

Civil penalties under Oregon DEQ enforcement rules for unresolved deficits.

Tradable unit

Clean Fuels Program credit

Timeline

1. 2007

   B1 biodiesel blend takes effect under the Biofuels Act.

2. 2009

   E10 gasoline and B2 diesel blends take effect.

3. 2024

   Biodiesel blend raised to B3.

4. 2026

   Step-up toward B5 subject to Department of Energy circulars.

Requirements

• Oil companies must blend bioethanol into every litre of gasoline placed on the market.
• Diesel must carry the prescribed coconut methyl ester share set by the National Biofuels Board.
• Locally produced bioethanol has first call on the mandated volume.

Compliance status & enforcement

Administrator

Department of Energy with the National Biofuels Board

How compliance is shown

Monthly reporting of blended volumes by oil industry participants to the Department of Energy.

Penalty for shortfall

Fines and suspension of business permits under RA 9367.

Tradable unit

None — physical blend obligation

Timeline

1. 2012

   Mandatory blending regulations gazetted.

2. 2020

   Biofuels Regulatory Framework published.

3. 2026

   Commencement still awaiting the pricing and support framework.

Requirements

• Licensed manufacturers would have to blend at the prescribed rates once implementation is triggered.
• A biofuels pricing framework and support mechanism must be published first.
• Biofuels Regulatory Framework sets out feedstock and licensing conditions.

Compliance status & enforcement

Administrator

Department of Mineral Resources and Energy

How compliance is shown

Petroleum manufacturing and wholesale licences with volume reporting.

Penalty for shortfall

Licence enforcement under the Petroleum Products Act.

Tradable unit

None — physical blend obligation

Timeline

1. 2015

   RFS starts at a 2.5% biodiesel blending obligation.

2. 2021

   Obligation raised to 3.5%.

3. 2024

   Obligation raised to 4.0%.

4. 2030

   Step-up path toward 5% under the announced schedule.

Requirements

• Obligation falls on refiners and importers placing automotive diesel on the domestic market.
• Blending share is set by presidential decree and steps up every two to three years.
• Feedstock and GHG criteria applied through the administering agency's verification rules.

Compliance status & enforcement

Administrator

Ministry of Trade, Industry and Energy with the Korea Energy Agency

How compliance is shown

Annual reporting of diesel volumes and blended biodiesel to the Korea Energy Agency.

Penalty for shortfall

Corrective orders and administrative fines under the Petroleum and Alternative Fuel Business Act.

Tradable unit

None — physical blend obligation

Timeline

1. 2024

   SAF expansion strategy announced with a 1% 2027 target.

2. 2026

   Implementing rules and supply arrangements being prepared.

3. 2027

   1% SAF blend for international departures.

Requirements

• Applies to jet fuel uplifted for international departures.
• Domestic co-processed SAF approved for commercial supply ahead of the mandate.
• Implementation detail set jointly by the transport and energy ministries.

Compliance status & enforcement

Administrator

Ministry of Land, Infrastructure and Transport with MOTIE

How compliance is shown

Supplier and airline reporting of SAF uplift at Korean international airports.

Penalty for shortfall

To be defined in the implementing rules.

Tradable unit

None — physical blend obligation

Timeline

1. 2018

   Obligation introduced for petrol and diesel.

2. 2024

   Levels cut sharply to 6% for both petrol and diesel.

3. 2026

   Levels raised again following the 2025 legislative revision.

4. 2030

   Trajectory to be confirmed by the ongoing review.

Requirements

• Separate reduction levels for petrol and for diesel.
• Reduction achieved by blending biofuels certified under the Swedish sustainability act.
• Aviation fuel covered by a separate reduction obligation.

Compliance status & enforcement

Administrator

Swedish Energy Agency (Energimyndigheten)

How compliance is shown

Annual reduction declaration with sustainability certification; limited over-compliance can be carried forward.

Penalty for shortfall

Reduction-obligation charge per kilogram of CO2e shortfall.

Tradable unit

None — physical blend obligation

Timeline

1. 2008

   B2 mandatory biodiesel blend introduced.

2. 2019

   B10 designated the base diesel grade.

3. 2024

   E20 promoted as the base gasohol grade.

4. 2026

   Blend levels adjusted periodically with feedstock availability.

Requirements

• Base diesel grade blend level set by the Department of Energy Business and adjusted with palm-oil supply.
• Gasohol E10, E20 and E85 grades sold with E20 promoted as the base grade.
• Oil Fuel Fund used to manage retail price differentials between grades.

Compliance status & enforcement

Administrator

Ministry of Energy — Department of Energy Business

How compliance is shown

Fuel-quality notifications and inspection of refiners, blenders and retail stations.

Penalty for shortfall

Penalties under the Fuel Trade Act for off-specification fuel.

Tradable unit

None — physical blend obligation

Timeline

1. Oct 2023

   Ministry of Energy and Infrastructure publishes the SAF General Policy.

2. 7 Dec 2023

   General Policy for Sustainable Aviation Fuel formally issued by the Cabinet.

3. 2026

   Domestic SAF production and supply arrangements being built out.

4. 2031

   1% SAF share for national carriers.

Requirements

• Applies to fuel uplifted by UAE national carriers at UAE airports.
• Emphasis on domestically produced SAF from waste and residue feedstock.
• Supported by a national SAF roadmap and certification arrangements.

Compliance status & enforcement

Administrator

Ministry of Energy and Infrastructure with the General Civil Aviation Authority

How compliance is shown

Reporting of SAF uplift volumes by carriers and fuel suppliers.

Penalty for shortfall

To be set out in implementing regulations.

Tradable unit

None — physical blend obligation

Timeline

1. 2025

   Mandate starts at 2% of jet fuel supplied.

2. 2028

   Power-to-liquid sub-obligation begins at 0.2%.

3. 2030

   10% SAF share.

4. 2040

   22% SAF share, held flat thereafter pending review.

Requirements

• Obligation applies to suppliers of jet fuel above the annual threshold.
• Separate power-to-liquid sub-obligation begins in 2028.
• HEFA-derived SAF is capped as a share of the obligation and the cap declines over time.
• A revenue-certainty mechanism supports UK SAF plants alongside the mandate.

Compliance status & enforcement

Administrator

Department for Transport — Low Carbon Fuels Unit

How compliance is shown

SAF certificates issued for eligible supply and redeemed against the annual obligation, mirroring the RTFC system.

Penalty for shortfall

Buy-out price per certificate not redeemed, set separately for the main and PtL obligations.

Tradable unit

SAF certificate

Timeline

1. 2008

   Obligation begins.

2. 2018

   Development-fuel sub-target and crop cap introduced.

3. 2026

   Annual obligation share continues on the published trajectory.

4. 2032

   Crop cap steps down to its lowest level under the current order.

Requirements

• Main obligation set as a percentage of relevant fuel supplied, with a separate development-fuel sub-target.
• Crop-derived biofuel capped and stepping down over the obligation period.
• Fuels must meet RTFO sustainability criteria, verified and reported quarterly.

Compliance status & enforcement

Administrator

Department for Transport, administered by the Low Carbon Fuels Unit

How compliance is shown

Renewable Transport Fuel Certificates (RTFCs) are issued per litre or kilogram supplied and redeemed against the annual obligation.

Penalty for shortfall

Fixed buy-out price per RTFC not redeemed, payable to the administrator.

Tradable unit

Renewable Transport Fuel Certificate (RTFC)

Timeline

1. 2005 / 2007

   Programme created by the Energy Policy Act and expanded by the Energy Independence and Security Act.

2. 2023–2025

   First multi-year 'set' rule establishing volumes beyond the statutory table.

3. 2026–2027

   Second set rulemaking establishing annual volumes, including the eRIN question.

4. Annual

   Compliance demonstration each 31 March for the preceding calendar year.

Requirements

• Obligated parties are refiners and importers of gasoline and diesel; each receives a percentage renewable volume obligation applied to its production.
• Four nested categories: total renewable fuel, advanced biofuel, cellulosic biofuel and biomass-based diesel, each with its own D-code.
• Fuel must meet lifecycle GHG-reduction thresholds for its category (20% conventional, 50% advanced/biomass-based diesel, 60% cellulosic).
• Up to 20% of an annual obligation may be met with RINs carried over from the prior year.

Compliance status & enforcement

Administrator

US Environmental Protection Agency

How compliance is shown

Renewable Identification Numbers (RINs) are generated at production, tracked in the EPA Moderated Transaction System (EMTS) and retired against the annual obligation each March.

Penalty for shortfall

Civil penalties per day of violation under the Clean Air Act, plus mandatory retirement of replacement RINs; cellulosic waiver credits may substitute for cellulosic RINs.

Tradable unit

Renewable Identification Number (RIN)

Timeline

1. 2021

   HB 1091 signed, directing Ecology to adopt a clean fuel standard.

2. 2023

   Programme begins with reporting and the first compliance obligation.

3. 2034

   20% carbon-intensity reduction versus 2017.

4. 2038

   45% carbon-intensity reduction versus 2017 under the 2025 amendments.

Requirements

• Fuel suppliers register in the Washington Fuels Reporting System and report volumes and carbon intensities quarterly.
• Carbon-intensity values are certified through WA-GREET fuel pathway applications approved by Ecology.
• Fuels above the annual benchmark generate deficits; fuels below it generate tradable credits.
• Annual compliance report with third-party verification for larger reporting entities.

Compliance status & enforcement

Administrator

Washington State Department of Ecology

How compliance is shown

Credits and deficits are reconciled annually in the Washington Fuels Reporting System; credits are bankable and tradable, with a credit clearance market when prices reach the ceiling.

Penalty for shortfall

Civil penalties under the Clean Fuel Standard rule for unresolved deficits, plus mandatory retirement of replacement credits.

Tradable unit

Clean Fuel Standard credit (one metric tonne CO2e)