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Council Directive (EU) 2015/652 of 20 April 2015 laying down calculation methods and reporting requirements pursuant to Directive 98/70/EC of the European Parliament and of the Council relating to the quality of petrol and diesel fuels

OJ L 107, 25.4.2015, p. 26–67 (BG, ES, CS, DA, DE, ET, EL, EN, FR, HR, IT, LV, LT, HU, MT, NL, PL, PT, RO, SK, SL, FI, SV)

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25.4.2015   

EN

Official Journal of the European Union

L 107/26


COUNCIL DIRECTIVE (EU) 2015/652

of 20 April 2015

laying down calculation methods and reporting requirements pursuant to Directive 98/70/EC of the European Parliament and of the Council relating to the quality of petrol and diesel fuels

THE COUNCIL OF THE EUROPEAN UNION,

Having regard to the Treaty on the Functioning of the European Union,

Having regard to Directive 98/70/EC of the European Parliament and of the Council of 13 October 1998 relating to the quality of petrol and diesel fuels and amending Council Directive 93/12/EEC (1), and in particular Article 7a(5) thereof,

Having regard to the proposal from the European Commission,

Whereas:

(1)

The method for calculating greenhouse gas emissions of fuels and other energy from non-biological sources to be established pursuant to Article 7a(5) of Directive 98/70/EC should yield reporting of sufficient accuracy, so that the Commission can critically assess the performance of suppliers in meeting their obligations under Article 7a(2) of that Directive. The calculation method should ensure accuracy, while having due regard for the complexity of the associated administrative requirements. At the same time, it should incentivise suppliers to reduce the greenhouse gas intensity of the fuel they supply. Careful consideration should also be given to the impact of the calculation method on refineries in the Union. Hence, the calculation method should be based on average greenhouse gas intensities that represent an industry average value which is typical for a particular fuel. This would have the advantage of reducing the administrative burden on suppliers and Member States. At this stage, the proposed calculation method should not require differentiation of the greenhouse gas intensity of fuel on the basis of the source of the raw material, as this would affect current investments in certain refineries in the Union.

(2)

Reporting requirements for suppliers which are small and medium-sized enterprises (SMEs) as defined in Commission Recommendation 2003/361/EC (2) should be minimised as far as possible in the context of Article 7a(1) of Directive 98/70/EC. Similarly, importers of petrol and diesel refined outside the Union should not be obliged to provide detailed information about the sources of the crude oils used to make those fuels, as this information may not be available or may be difficult to obtain.

(3)

In order to incentivise further greenhouse gas emission reductions, savings claimed from upstream emission reductions (UERs), including from flaring and venting, should be included in the calculation of suppliers' life cycle greenhouse gas emissions. In order to facilitate the claiming of UERs by suppliers, the use of various emission schemes should be allowed for calculating and certifying emission reductions. Only UER projects which start after the date of the establishment of the fuel baseline standard set out in Article 7a(5)(b) of Directive 98/70/EC, i.e. 1 January 2011, should be eligible.

(4)

Weighted average greenhouse gas default values representing the crude oils consumed in the Union provide a simple calculation method by which suppliers may determine the greenhouse gas content of the fuel they supply.

(5)

UERs should be estimated and validated in accordance with principles and standards identified in International Standards, and in particular ISO 14064, ISO 14065 and ISO 14066.

(6)

It is furthermore appropriate to facilitate the implementation by Member States of legislation on UERs, including from flaring and venting. To this end, non-legislative guidance should be prepared under the auspices of the Commission on approaches to quantify, verify, validate, monitor and report such UERs (including reductions in flaring and venting at production sites) prior to the end of the transposition period set in Article 7 of this Directive.

(7)

Article7a(5)(b) of Directive 98/70/EC requires the establishment of a method to determine the fuel baseline standard based on the life cycle greenhouse gas emissions per unit of energy from fossil fuels in 2010. The fuel baseline standard should be based on the quantities of diesel, petrol, non-road gas oil, liquefied petroleum gas (LPG) and compressed natural gas (CNG) consumed using data officially reported by the Member States to the United Nations Framework Convention on Climate Change (UNFCCC) in 2010. The fuel baseline standard should not be the fossil fuel comparator that is used for calculating greenhouse gas savings from biofuels, which should remain as set out in Annex IV to Directive 98/70/EC.

(8)

Since the composition of the relevant fossil fuel mix changes little from year to year, the aggregate variation in the greenhouse gas intensity of the fossil fuels from year to year will also be small. It is therefore appropriate that the fuel baseline standard be based on the 2010 Union average consumption data as reported by the Member States to the UNFCCC.

(9)

The fuel baseline standard should represent an average upstream greenhouse gas intensity and the intensity of the fuel of a refinery of average complexity for fossil fuels. Hence, the fuel baseline standard should be calculated using the respective average fuel default values. The fuel baseline standard should remain unchanged for the period up until 2020, in order to provide regulatory certainty to suppliers in respect of their obligations to reduce the greenhouse gas intensity of the fuels they supply.

(10)

Article 7a(5)(d) of Directive 98/70/EC provides for the adoption of a method to calculate the contribution of electric road vehicles to reduce life cycle greenhouse gas emissions. Pursuant to that Article, the calculation method should be compatible with Article 3(4) of Directive 2009/28/EC of the European Parliament and of the Council (3). To ensure this compatibility, the same adjustment factor should be used for the powertrain efficiency.

(11)

Electricity supplied for use in road transport may be reported by suppliers, as laid down in Article 7a(1) of Directive 98/70/EC, as part of their annual reports to the Member States. In order to limit administrative costs, it is appropriate that the calculation method be based on an estimate rather than on an actual measurement of the consumption of electricity in an electric road vehicle or motorcycle for the purpose of supplier reporting.

(12)

It is appropriate to include a detailed approach for estimating the quantity and the greenhouse gas intensity of biofuels in cases where processing of a biofuel and a fossil fuel occurs during the same process. A specific method is needed because the resulting quantity of the biofuel is not measurable, such as during co-hydro treatment of vegetable oils with a fossil fuel. Article 7d(1) of Directive 98/70/EC stipulates that the life cycle greenhouse gas emissions of biofuels are, for the purposes of Article 7a and Article 7b(2) of that Directive, to be calculated with the same method. Therefore, the certification of greenhouse gas emissions by recognised voluntary schemes is as valid for the purposes of Article 7a as it is for the purposes of Article 7b(2) of Directive 98/70/EC.

(13)

The supplier reporting requirement laid down in Article 7a(1) of Directive 98/70/EC should be supplemented by a harmonised format and harmonised definitions of the data to be reported. A harmonisation of the definitions of data is needed for the proper execution of the greenhouse gas intensity calculation linked to an individual supplier's reporting obligations, as the data form key inputs into the calculation method harmonised pursuant to Article 7a(5)(a) of Directive 98/70/EC. These data include the supplier's identification, the quantity of fuel or energy placed on the market and the fuel or energy type placed on the market.

(14)

The supplier reporting requirement laid down in Article 7a(1) of Directive 98/70/EC should be supplemented by harmonised reporting requirements, a reporting format and harmonised definitions for Member State reporting to the Commission pertaining to the greenhouse gas performance of fuels consumed in the Union. In particular, these reporting requirements will enable the updating of the fossil fuel comparator described in point 19 of Part C of Annex IV to Directive 98/70/EC and point 19 of Part C of Annex V to Directive 2009/28/EC, and they will facilitate the reporting required pursuant to Articles 8(3) and 9(2) of Directive 98/70/EC as well as the updating of the calculation method to technical and scientific progress, in order to ensure that it meets its intended purpose. These data should include the quantity of fuel or energy placed on the market and fuel or energy type, the place of purchase and the origin of the fuel or energy placed on the market.

(15)

It is appropriate for Member States to allow suppliers to fulfil their reporting requirements by relying on equivalent data being collected pursuant to other Union or national legislation so as to reduce the administrative burden, provided that the reporting is conducted in accordance with the requirements set out in Annex IV and the definitions laid down in Annexes I and III.

(16)

In order to facilitate reporting by groups of suppliers pursuant to Article 7a(4) of Directive 98/70/EC, Article 7a(5)(c) of that Directive allows for the establishment of any necessary rules. It is desirable to facilitate such reporting in order to avoid disruption to physical fuel movements, since different suppliers place different fuels of differing proportions on the market, and hence may have to deploy different levels of resources to meet the greenhouse gas reduction target. It is therefore necessary to harmonise the definitions of the suppliers' identification, the quantity of fuel or energy placed on the market, the fuel or energy type, the place of purchase and the origin of the fuel or energy placed on the market. Furthermore, to avoid double counting in joint supplier reporting pursuant to Article 7a(4), it is appropriate to harmonise the implementation of the calculation and reporting method in the Member States, including the reporting to the Commission, so that the requisite information from a group of suppliers relates to a specific Member State.

(17)

Pursuant to Article 8(3) of Directive 98/70/EC, Member States are to submit an annual report of national fuel quality data for the preceding calendar year in accordance with the format established in Commission Decision 2002/159/EC (4). To cover the amendments introduced to Directive 98/70/EC by Directive 2009/30/EC of the European Parliament and of the Council (5), and the subsequent additional reporting requirements on the Member States, and in the interest of effectiveness and harmonisation, it is necessary to clarify which information should be reported, and to adopt a format for the submission of data by suppliers and Member States.

(18)

The Commission presented a draft measure to the Committee established by Directive 98/70/EC on 23 February 2012. The Committee was unable to adopt an opinion by the necessary qualified majority. It is therefore appropriate for the Commission to present a proposal to the Council pursuant to Article 5a(4) of Council Decision 1999/468/EC (6),

HAS ADOPTED THIS DIRECTIVE:

Article 1

Subject matter — Scope

1.   This Directive lays down rules on calculation methods and reporting requirements in accordance with Directive 98/70/EC.

2.   This Directive applies to fuels used to propel road vehicles, non-road mobile machinery (including inland waterway vessels when not at sea), agricultural and forestry tractors, recreational craft when not at sea and electricity for use in road vehicles.

Article 2

Definitions

For the purposes of this Directive, and in addition to the definitions already contained in Directive 98/70/EC, the following definitions apply:

(1)

‘upstream emissions’ means all greenhouse gas emissions occurring prior to the raw material entering a refinery or a processing plant where the fuel, as referred to in Annex I, was produced;

(2)

‘natural bitumen’ means any source of refinery raw material that:

(a)

has an American Petroleum Institute (API) gravity of 10 degrees or less when situated in a reservoir formation at the place of extraction as defined pursuant to the testing method of the American Society for Testing and Materials (ASTM) (7) D287;

(b)

has an annual average viscosity at reservoir temperature greater than that calculated by the equation: Viscosity (Centipoise) = 518,98e-0,038T, where T is the temperature in Celsius;

(c)

falls within the definition for tar sands under combined nomenclature (CN) code 2714 as outlined in Council Regulation (EEC) No 2658/87 (8); and

(d)

where the mobilisation of the source of the raw material is achieved by mining extraction or thermally enhanced gravity drainage where the thermal energy is mainly derived from sources other than the feedstock source itself;

(3)

‘oil shale’ means any source of refinery raw material as situated in a rock formation containing solid kerogen and falling within the definition for oil shale under CN code 2714 as outlined in Regulation (EEC) No 2658/87. Mobilisation of the source of the raw material is achieved by mining extraction or thermally enhanced gravity drainage;

(4)

‘fuel baseline standard’ means a fuel baseline standard based on the life cycle greenhouse gas emissions per unit of energy from fossil fuels in 2010;

(5)

‘conventional crude’ means any refinery raw material exhibiting an API gravity that is higher than 10 degrees when situated in a reservoir formation at its place of origin as measured per testing method ASTM D287, and not falling within the definition for CN code 2714 as set out in Regulation (EEC) No 2658/87.

Article 3

Method for calculating the greenhouse gas intensity of fuels and energy supplied other than biofuels and reporting by suppliers

1.   For the purposes of Article 7a(2) of Directive 98/70/EC, Member States shall ensure that suppliers use the calculation method set out in Annex I to this Directive to determine the greenhouse gas intensity of the fuels they supply.

2.   For the purposes of the second subparagraph of Article 7a(1) and of Article 7a(2) of Directive 98/70/EC, Member States shall require suppliers to report data using the definitions and the calculation method set out in Annex I to this Directive. The data shall be reported annually using the template set out in Annex IV to this Directive.

3.   For the purposes of Article 7a(4) of Directive 98/70/EC, any Member State shall ensure that a group of suppliers choosing to be considered as a single supplier meets its obligation under Article 7a(2) within that Member State.

4.   For suppliers that are SMEs, Member States shall apply the simplified method set out in Annex I to this Directive.

Article 4

Calculation of fuel baseline standard and greenhouse gas intensity reduction

For the purposes of verifying compliance by suppliers with their obligation under Article 7a(2) of Directive 98/70/EC, Member States shall require suppliers to compare their achieved reductions of life cycle greenhouse gas emissions from fuels and from electricity to the fuel baseline standard set out in Annex II to this Directive.

Article 5

Reporting by Member States

1.   When submitting reports to the Commission under Article 8(3) of Directive 98/70/EC, Member States shall provide the Commission with data related to compliance with Article 7a of that Directive, as defined in Annex III to this Directive.

2.   Member States shall use the ReportNet tools of the European Environment Agency provided pursuant to Regulation (EC) No 401/2009 of the European Parliament and of the Council (9) for the submission of the data set out in Annex III to this Directive. The data shall be transmitted by the Member States by means of electronic data transfer to the Central Data Repository managed by the European Environment Agency.

3.   The data shall be provided annually using the template set out in Annex IV. Member States shall notify the Commission of the date of transmission and the contact name of the competent authority responsible for verifying and reporting the data to the Commission.

Article 6

Penalties

Member States shall lay down the rules on penalties applicable to infringements of national provisions adopted pursuant to this Directive and shall take all measures necessary to ensure that they are implemented. The penalties provided for must be effective, proportionate and dissuasive. Member States shall notify those provisions to the Commission by 21 April 2017 and shall notify it without delay of any subsequent amendment affecting them.

Article 7

Transposition

1.   Member States shall bring into force the laws, regulations and administrative provisions necessary to comply with this Directive by 21 April 2017 at the latest. They shall immediately inform the Commission thereof.

2.   When Member States adopt those measures, they shall contain a reference to this Directive or shall be accompanied by such a reference on the occasion of their official publication. The methods of making such reference shall be laid down by Member States.

3.   Member States shall communicate to the Commission the text of the main measures of national law which they adopt in the field covered by this Directive.

Article 8

Entry into force

This Directive shall enter into force on the twentieth day following that of its publication in the Official Journal of the European Union.

Article 9

Addressees

This Directive is addressed to the Member States.

Done at Luxembourg, 20 April 2015.

For the Council

The President

J. DŪKLAVS


(1)  OJ L 350, 28.12.1998, p. 58.

(2)  Commission Recommendation 2003/361/EC of 6 May 2003 concerning the definition of micro, small and medium-sized enterprises (OJ L 124, 20.5.2003, p. 36).

(3)  Directive 2009/28/EC of the European Parliament and of the Council of 23 April 2009 on the promotion of the use of energy from renewable sources and amending and subsequently repealing Directives 2001/77/EC and 2003/30/EC (OJ L 140, 5.6.2009, p. 16).

(4)  Commission Decision 2002/159/EC of 18 February 2002 on a common format for the submission of summaries of national fuel quality data (OJ L 53, 23.2.2002, p. 30).

(5)  Directive 2009/30/EC of the European Parliament and of the Council of 23 April 2009 amending Directive 98/70/EC as regards the specification of petrol, diesel and gas-oil and introducing a mechanism to monitor and reduce greenhouse gas emissions and amending Council Directive 1999/32/EC as regards the specification of fuel used by inland waterway vessels and repealing Directive 93/12/EEC (OJ L 140, 5.6.2009, p. 88).

(6)  Council Decision 1999/468/EC of 28 June 1999 laying down the procedures for the exercise of implementing powers conferred on the Commission (OJ L 184, 17.7.1999, p. 23).

(7)  American Society for Testing and Materials: http://www.astm.org/index.shtml

(8)  Council Regulation (EEC) No 2658/87 of 23 July 1987 on the tariff and statistical nomenclature and on the Common Customs Tariff (OJ L 256, 7.9.1987, p. 1).

(9)  Regulation (EC) No 401/2009 of the European Parliament and of the Council of 23 April 2009 on the European Environment Agency and the European Environment Information and Observation Network (OJ L 126, 21.5.2009, p. 13).


ANNEX I

METHOD FOR THE CALCULATION AND REPORTING OF THE LIFE CYCLE GREENHOUSE GAS INTENSITY OF FUELS AND ENERGY BY SUPPLIERS

Part 1

Calculation of a supplier's greenhouse gas intensity of fuels and energy

The greenhouse gas intensity for fuels and energy is expressed in terms of grams of carbon dioxide equivalent per mega joule of fuel (gCO2eq/MJ).

1.

The greenhouse gases taken into account for the purposes of calculating the greenhouse gas intensity of fuel is carbon dioxide (CO2), nitrous oxide (N2O) and methane (CH4). For the purpose of calculating CO2 equivalence, emissions of those gases are valued in terms of CO2 equivalent emissions, as follows:

CO2: 1;

CH4: 25;

N2O: 298

2.

Emissions from the manufacture of machinery and equipment utilised in extraction, production, refining and consumption of fossil fuels are not taken into account in the greenhouse gas calculation.

3.

A supplier's greenhouse gas intensity from the life cycle greenhouse gas emissions of all fuels and energy supplied shall be calculated in accordance with the formula below:

Formula

where:

(a)

‘#’ means the supplier's identification (i.e. the identification of the entity liable to pay excise duty) defined in Commission Regulation (EC) No 684/2009 (1) as the Trader Excise Number (System for Exchange of Excise Data (SEED) registration number or value added tax (VAT) identification number in point 5(a) of Table 1 of Annex I to that Regulation for Destination Type codes 1 to 5 and 8), which is also the entity liable to pay the excise duty in accordance with Article 8 of Council Directive 2008/118/EC (2) at the time that excise duty became chargeable in accordance with Article 7(2) of Directive 2008/118/EC. If this identification is not available, Member States shall ensure that an equivalent means of identification is established in accordance with a national excise duty reporting scheme;

(b)

‘x’ means the fuel and energy types falling within the scope of this Directive as expressed in point17(c) of Table 1 of Annex I to Regulation (EC) No 684/2009. If these data are not available, Member States shall collect equivalent data in accordance with a nationally established excise duty reporting scheme;

(c)

‘MJx’ means the total energy supplied and converted from reported volumes of fuel ‘x’ expressed in mega joules. This is calculated as follows:

(i)

The quantity of each fuel per fuel type

It is derived from data reported pursuant to points 17(d), (f) and (o) of Table 1 of Annex I to Regulation (EC) No 684/2009. Biofuel quantities are converted to their lower-heat-value energy content pursuant to the energy densities set out in Annex III to Directive 2009/28/EC. Quantities of fuels from non-biological origin are converted to their lower-heat-value energy content pursuant to energy densities set out in Appendix 1 to the Joint Research Centre-EUCAR-CONCAWE (JEC) (3) Well-to-Tank report (version 4) of July 2013 (4);

(ii)

Simultaneous co-processing of fossil fuels and biofuels

Processing includes any modification during the life cycle of a fuel or energy supplied causing a change to the molecular structure of the product. The addition of denaturant does not fall under this processing. The quantity of biofuels co-processed with fuels from non-biological origin reflects the post-processing state of the biofuel. The quantity of the co-processed biofuel is determined according to the energy balance and efficiency of the co-processing process as set out in point 17 of Part C of Annex IV to Directive 98/70/EC.

Where multiple biofuels are blended with fossil fuels, the quantity and type of each biofuel is taken into account in the calculation and reported by suppliers to the Member States.

The quantity of biofuel supplied that does not meet the sustainability criteria referred to in Article 7b(1) of Directive 98/70/EC is counted as fossil fuel.

E85 petrol-ethanol blend shall be calculated as a separate fuel for the purpose of Article 6 of Regulation (EC) No 443/2009 of the European Parliament and of the Council (5).

If quantities are not collected pursuant to Regulation (EC) No 684/2009, Member States shall collect equivalent data in accordance with a nationally established excise duty reporting scheme;

(iii)

Quantity of electricity consumed

This is the amount of electricity consumed in road vehicles or motorcycles where a supplier reports this amount of energy to the relevant authority in each Member State in accordance with the following formula:

Electricity consumed = distance travelled (km) × electricity consumption efficiency (MJ/km);

(d)

Upstream emission reduction (UER)

‘UER’ is the upstream emission reduction of greenhouse gases claimed by a supplier, measured in gCO2eq if quantified and reported in accordance with the following requirements:

(i)

Eligibility

UERs shall only be applied to the upstream emission's part of the average default values for petrol, diesel, CNG or LPG.

UERs originating from any country may be counted as a reduction in greenhouse gas emissions against fuels from any feedstock source supplied by any supplier.

UERs shall only be counted if they are associated with projects that have started after 1 January 2011.

It is not necessary to prove that UERs would not have taken place without the reporting requirement set out in Article 7a of Directive 98/70/EC;

(ii)

Calculation

UERs shall be estimated and validated in accordance with principles and standards identified in International Standards, and in particular ISO 14064, ISO 14065 and ISO 14066.

The UERs and baseline emissions are to be monitored, reported and verified in accordance with ISO 14064 and providing results of equivalent confidence of Commission Regulation (EU) No 600/2012 (6) and Commission Regulation (EU) No 601/2012 (7). The verification of methods for estimating UERs must be done in accordance with ISO 14064-3 and the organisation verifying this must be accredited in accordance with ISO 14065;

(e)

‘GHGix’ is the greenhouse gas intensity of fuel or energy ‘x’ expressed in gCO2eq/MJ. Suppliers shall calculate the greenhouse gas intensity of each fuel or energy as follows:

(i)

Greenhouse gas intensity of fuels from a non-biological origin is the ‘weighted life cycle greenhouse gas intensity’ per fuel type listed in the last column of the table under point 5 of Part 2 of this Annex;

(ii)

Electricity is calculated as described in point 6 of Part 2;

(iii)

Greenhouse gas intensity of biofuels

The greenhouse gas intensity of biofuels meeting the sustainability criteria referred to in Article 7b(1) of Directive 98/70/EC is calculated in accordance with Article 7d of that Directive. In case data on the life cycle greenhouse gas emissions of biofuels was obtained in accordance with an agreement or scheme that has been the subject of a decision pursuant to Article 7c(4) of Directive 98/70/EC covering Article 7b(2) of that Directive, this data is also to be used to establish the greenhouse gas intensity of biofuels under Article 7b(1) of that Directive. The greenhouse gas intensity for biofuels not meeting the sustainability criteria referred to in Article 7b(1) of Directive 98/70/EC is equal to the greenhouse intensity of the respective fossil fuel derived from conventional crude oil or gas;

(iv)

Simultaneous co-processing of fuels from non-biological origin and biofuels

The greenhouse gas intensity of biofuels co-processed with fossil fuels shall reflect the post-processing state of the biofuel;

(f)

‘AF’ represents the adjustment factors for powertrain efficiencies:

Predominant conversion technology

Efficiency factor

Internal combustion engine

1

Battery electric powertrain

0,4

Hydrogen fuel cell electric powertrain

0,4

Part 2

Reporting by suppliers for fuels other than biofuels

1.   UERs of fossil fuels

In order for UERs to be eligible for the purposes of the reporting and calculation method, suppliers shall report the following to the authority designated by the Member States:

(a)

the starting date of the project, which must be after 1 January 2011;

(b)

the annual emission reductions in gCO2eq;

(c)

the duration for which the claimed reductions occurred;

(d)

the project location closest to the source of the emissions in latitude and longitude coordinates in degrees to the fourth decimal place;

(e)

the baseline annual emissions prior to installation of reduction measures and annual emissions after the reduction measures have been implemented in gCO2eq/MJ of feedstock produced;

(f)

the non-reusable certificate number uniquely identifying the scheme and the claimed greenhouse gas reductions;

(g)

the non-reusable number uniquely identifying the calculation method and the associated scheme;

(h)

where the project relates to oil extraction, the average annual historical and reporting year gas-to-oil ratio (GOR) in solution, reservoir pressure, depth and well production rate of the crude oil.

2.   Origin

‘Origin’ means the feedstock trade name listed in point 7 of Part 2 of this Annex, but only where suppliers hold the necessary information by virtue of:

(a)

being a person or undertaking importing crude oil from third countries or receiving a crude oil delivery from another Member State pursuant to Article 1 of Council Regulation (EC) No 2964/95 (8); or

(b)

arrangements to share information agreed with other suppliers.

In all other cases, origin shall refer to whether the fuel is of EU or non-EU origin.

The information collected and reported by suppliers to the Member States concerning the origin of fuels shall be confidential, but this shall not prevent the publication by the Commission of general information or information in summary form which does not contain details relating to individual undertakings;

For biofuels, origin means the biofuel production pathway set out in Annex IV to Directive 98/70/EC.

Where multiple feedstocks are used, suppliers shall report on the quantity in metric tonnes of finished product of each feedstock produced in the respective processing facility during the reporting year.

3.   Place of purchase

‘Place of purchase’ means the country and name of the processing facility where the fuel or energy underwent the last substantial transformation used to confer the origin of the fuel or energy in accordance with Commission Regulation (EEC) No 2454/93 (9).

4.   SMEs

By way of derogation for suppliers that are SMEs, ‘origin’ and ‘place of purchase’ is either EU or non-EU, as appropriate, irrespective of whether they import crude oil or they supply petroleum oils and oils obtained from bituminous materials.

5.   Average life cycle greenhouse gas intensity default values for fuels other than biofuels and electricity

Raw material source and process

Fuel placed on the market

Life cycle GHG intensity (gCO2eq/MJ)

Weighted life cycle GHG intensity (gCO2eq/MJ)

Conventional crude

Petrol

93,2

93,3

Natural Gas-to-Liquid

94,3

Coal-to-Liquid

172

Natural bitumen

107

Oil shale

131,3

Conventional crude

Diesel or gasoil

95

95,1

Natural Gas-to-Liquid

94,3

Coal-to-Liquid

172

Natural bitumen

108,5

Oil shale

133,7

Any fossil sources

Liquefied Petroleum Gas in a spark ignition engine

73,6

73,6

Natural Gas, EU mix

Compressed Natural Gas in a spark ignition engine

69,3

69,3

Natural Gas, EU mix

Liquefied Natural Gas in a spark ignition engine

74,5

74,5

Sabatier reaction of hydrogen from non-biological renewable energy electrolysis

Compressed synthetic methane in a spark ignition engine

3,3

3,3

Natural gas using steam reforming

Compressed Hydrogen in a fuel cell

104,3

104,3

Electrolysis fully powered by non-biological renewable energy

Compressed Hydrogen in a fuel cell

9,1

9,1

Coal

Compressed Hydrogen in a fuel cell

234,4

234,4

Coal with Carbon Capture and Storage of process emissions

Compressed Hydrogen in a fuel cell

52,7

52,7

Waste plastic derived from fossil feedstocks

Petrol, diesel or gasoil

86

86

6.   Electricity

For the reporting by energy suppliers of electricity consumed by electric vehicles and motorcycles, Member States should calculate national average life cycle default values in accordance with appropriate International Standards.

Alternatively, Member States may permit their suppliers to establish greenhouse gas intensity values (gCO2eq/MJ) for electricity from data reported by Member States on the basis of:

(a)

Regulation (EC) No 1099/2008 of the European Parliament and of the Council (10);

(b)

Regulation (EU) No 525/2013 of the European Parliament and of the Council (11); or

(c)

Commission Delegated Regulation (EU) No 666/2014 (12).

7.   Feedstock trade name

Country

Feedstock trade name

API

Sulphur (wt %)

Abu Dhabi

Al Bunduq

38,5

1,1

Abu Dhabi

Mubarraz

38,1

0,9

Abu Dhabi

Murban

40,5

0,8

Abu Dhabi

Zakum (Lower Zakum/Abu Dhabi Marine)

40,6

1

Abu Dhabi

Umm Shaif (Abu Dhabi Marine)

37,4

1,5

Abu Dhabi

Arzanah

44

0

Abu Dhabi

Abu Al Bu Khoosh

31,6

2

Abu Dhabi

Murban Bottoms

21,4

Not available (NA)

Abu Dhabi

Top Murban

21

NA

Abu Dhabi

Upper Zakum

34,4

1,7

Algeria

Arzew

44,3

0,1

Algeria

Hassi Messaoud

42,8

0,2

Algeria

Zarzaitine

43

0,1

Algeria

Algerian

44

0,1

Algeria

Skikda

44,3

0,1

Algeria

Saharan Blend

45,5

0,1

Algeria

Hassi Ramal

60

0,1

Algeria

Algerian Condensate

64,5

NA

Algeria

Algerian Mix

45,6

0,2

Algeria

Algerian Condensate (Arzew)

65,8

0

Algeria

Algerian Condensate (Bejaia)

65,0

0

Algeria

Top Algerian

24,6

NA

Angola

Cabinda

31,7

0,2

Angola

Takula

33,7

0,1

Angola

Soyo Blend

33,7

0,2

Angola

Mandji

29,5

1,3

Angola

Malongo (West)

26

NA

Angola

Cavala-1

42,3

NA

Angola

Sulele (South-1)

38,7

NA

Angola

Palanca

40

0,14

Angola

Malongo (North)

30

NA

Angola

Malongo (South)

25

NA

Angola

Nemba

38,5

0

Angola

Girassol

31,3

NA

Angola

Kuito

20

NA

Angola

Hungo

28,8

NA

Angola

Kissinje

30,5

0,37

Angola

Dalia

23,6

1,48

Angola

Gimboa

23,7

0,65

Angola

Mondo

28,8

0,44

Angola

Plutonio

33,2

0,036

Angola

Saxi Batuque Blend

33,2

0,36

Angola

Xikomba

34,4

0,41

Argentina

Tierra del Fuego

42,4

NA

Argentina

Santa Cruz

26,9

NA

Argentina

Escalante

24

0,2

Argentina

Canadon Seco

27

0,2

Argentina

Hidra

51,7

0,05

Argentina

Medanito

34,93

0,48

Armenia

Armenian Miscellaneous

NA

NA

Australia

Jabiru

42,3

0,03

Australia

Kooroopa (Jurassic)

42

NA

Australia

Talgeberry (Jurassic)

43

NA

Australia

Talgeberry (Up Cretaceous)

51

NA

Australia

Woodside Condensate

51,8

NA

Australia

Saladin-3 (Top Barrow)

49

NA

Australia

Harriet

38

NA

Australia

Skua-3 (Challis Field)

43

NA

Australia

Barrow Island

36,8

0,1

Australia

Northwest Shelf Condensate

53,1

0

Australia

Jackson Blend

41,9

0

Australia

Cooper Basin

45,2

0,02

Australia

Griffin

55

0,03

Australia

Buffalo Crude

53

NA

Australia

Cossack

48,2

0,04

Australia

Elang

56,2

NA

Australia

Enfield

21,7

0,13

Australia

Gippsland (Bass Strait)

45,4

0,1

Azerbaijan

Azeri Light

34,8

0,15

Bahrain

Bahrain Miscellaneous

NA

NA

Belarus

Belarus Miscellaneous

NA

NA

Benin

Seme

22,6

0,5

Benin

Benin Miscellaneous

NA

NA

Belize

Belize Light Crude

40

NA

Belize

Belize Miscellaneous

NA

NA

Bolivia

Bolivian Condensate

58,8

0,1

Brazil

Garoupa

30,5

0,1

Brazil

Sergipano

25,1

0,4

Brazil

Campos Basin

20

NA

Brazil

Urucu (Upper Amazon)

42

NA

Brazil

Marlim

20

NA

Brazil

Brazil Polvo

19,6

1,14

Brazil

Roncador

28,3

0,58

Brazil

Roncador Heavy

18

NA

Brazil

Albacora East

19,8

0,52

Brunei

Seria Light

36,2

0,1

Brunei

Champion

24,4

0,1

Brunei

Champion Condensate

65

0,1

Brunei

Brunei LS Blend

32

0,1

Brunei

Brunei Condensate

65

NA

Brunei

Champion Export

23,9

0,12

Cameroon

Kole Marine Blend

34,9

0,3

Cameroon

Lokele

21,5

0,5

Cameroon

Moudi Light

40

NA

Cameroon

Moudi Heavy

21,3

NA

Cameroon

Ebome

32,1

0,35

Cameroon

Cameroon Miscellaneous

NA

NA

Canada

Peace River Light

41

NA

Canada

Peace River Medium

33

NA

Canada

Peace River Heavy

23

NA

Canada

Manyberries

36,5

NA

Canada

Rainbow Light and Medium

40,7

NA

Canada

Pembina

33

NA

Canada

Bells Hill Lake

32

NA

Canada

Fosterton Condensate

63

NA

Canada

Rangeland Condensate

67,3

NA

Canada

Redwater

35

NA

Canada

Lloydminster

20,7

2,8

Canada

Wainwright-Kinsella

23,1

2,3

Canada

Bow River Heavy

26,7

2,4

Canada

Fosterton

21,4

3

Canada

Smiley-Coleville

22,5

2,2

Canada

Midale

29

2,4

Canada

Milk River Pipeline

36

1,4

Canada

Ipl-Mix Sweet

40

0,2

Canada

Ipl-Mix Sour

38

0,5

Canada

Ipl Condensate

55

0,3

Canada

Aurora Light

39,5

0,4

Canada

Aurora Condensate

65

0,3

Canada

Reagan Field

35

0,2

Canada

Synthetic Canada

30,3

1,7

Canada

Cold Lake

13,2

4,1

Canada

Cold Lake Blend

26,9

3

Canada

Canadian Federated

39,4

0,3

Canada

Chauvin

22

2,7

Canada

Gcos

23

NA

Canada

Gulf Alberta L & M

35,1

1

Canada

Light Sour Blend

35

1,2

Canada

Lloyd Blend

22

2,8

Canada

Peace River Condensate

54,9

NA

Canada

Sarnium Condensate

57,7

NA

Canada

Saskatchewan Light

32,9

NA

Canada

Sweet Mixed Blend

38

0,5

Canada

Syncrude

32

0,1

Canada

Rangeland — South L & M

39,5

0,5

Canada

Northblend Nevis

34

NA

Canada

Canadian Common Condensate

55

NA

Canada

Canadian Common

39

0,3

Canada

Waterton Condensate

65,1

NA

Canada

Panuke Condensate

56

NA

Canada

Federated Light and Medium

39,7

2

Canada

Wabasca

23

NA

Canada

Hibernia

37,3

0,37

Canada

BC Light

40

NA

Canada

Boundary

39

NA

Canada

Albian Heavy

21

NA

Canada

Koch Alberta

34

NA

Canada

Terra Nova

32,3

NA

Canada

Echo Blend

20,6

3,15

Canada

Western Canadian Blend

19,8

3

Canada

Western Canadian Select

20,5

3,33

Canada

White Rose

31,0

0,31

Canada

Access

22

NA

Canada

Premium Albian Synthetic Heavy

20,9

NA

Canada

Albian Residuum Blend (ARB)

20,03

2,62

Canada

Christina Lake

20,5

3

Canada

CNRL

34

NA

Canada

Husky Synthetic Blend

31,91

0,11

Canada

Premium Albian Synthetic (PAS)

35,5

0,04

Canada

Seal Heavy (SH)

19,89

4,54

Canada

Suncor Synthetic A (OSA)

33,61

0,178

Canada

Suncor Synthetic H (OSH)

19,53

3,079

Canada

Peace Sour

33

NA

Canada

Western Canadian Resid

20,7

NA

Canada

Christina Dilbit Blend

21,0

NA

Canada

Christina Lake Dilbit

38,08

3,80

Chad

Doba Blend (Early Production)

24,8

0,14

Chad

Doba Blend (Later Production)

20,8

0,17

Chile

Chile Miscellaneous

NA

NA

China

Taching (Daqing)

33

0,1

China

Shengli

24,2

1

China

Beibu

NA

NA

China

Chengbei

17

NA

China

Lufeng

34,4

NA

China

Xijiang

28

NA

China

Wei Zhou

39,9

NA

China

Liu Hua

21

NA

China

Boz Hong

17

0,282

China

Peng Lai

21,8

0,29

China

Xi Xiang

32,18

0,09

Colombia

Onto

35,3

0,5

Colombia

Putamayo

35

0,5

Colombia

Rio Zulia

40,4

0,3

Colombia

Orito

34,9

0,5

Colombia

Cano-Limon

30,8

0,5

Colombia

Lasmo

30

NA

Colombia

Cano Duya-1

28

NA

Colombia

Corocora-1

31,6

NA

Colombia

Suria Sur-1

32

NA

Colombia

Tunane-1

29

NA

Colombia

Casanare

23

NA

Colombia

Cusiana

44,4

0,2

Colombia

Vasconia

27,3

0,6

Colombia

Castilla Blend

20,8

1,72

Colombia

Cupiaga

43,11

0,082

Colombia

South Blend

28,6

0,72

Congo (Brazzaville)

Emeraude

23,6

0,5

Congo (Brazzaville)

Djeno Blend

26,9

0,3

Congo (Brazzaville)

Viodo Marina-1

26,5

NA

Congo (Brazzaville)

Nkossa

47

0,03

Congo (Kinshasa)

Muanda

34

0,1

Congo (Kinshasa)

Congo/Zaire

31,7

0,1

Congo (Kinshasa)

Coco

30,4

0,15

Côte d'Ivoire

Espoir

31,4

0,3

Côte d'Ivoire

Lion Cote

41,1

0,101

Denmark

Dan

30,4

0,3

Denmark

Gorm

33,9

0,2

Denmark

Danish North Sea

34,5

0,26

Dubai

Dubai (Fateh)

31,1

2

Dubai

Margham Light

50,3

0

Ecuador

Oriente

29,2

1

Ecuador

Quito

29,5

0,7

Ecuador

Santa Elena

35

0,1

Ecuador

Limoncoha-1

28

NA

Ecuador

Frontera-1

30,7

NA

Ecuador

Bogi-1

21,2

NA

Ecuador

Napo

19

2

Ecuador

Napo Light

19,3

NA

Egypt

Belayim

27,5

2,2

Egypt

El Morgan

29,4

1,7

Egypt

Rhas Gharib

24,3

3,3

Egypt

Gulf of Suez Mix

31,9

1,5

Egypt

Geysum

19,5

NA

Egypt

East Gharib (J-1)

37,9

NA

Egypt

Mango-1

35,1

NA

Egypt

Rhas Budran

25

NA

Egypt

Zeit Bay

34,1

0,1

Egypt

East Zeit Mix

39

0,87

Equatorial Guinea

Zafiro

30,3

NA

Equatorial Guinea

Alba Condensate

55

NA

Equatorial Guinea

Ceiba

30,1

0,42

Gabon

Gamba

31,8

0,1

Gabon

Mandji

30,5

1,1

Gabon

Lucina Marine

39,5

0,1

Gabon

Oguendjo

35

NA

Gabon

Rabi-Kouanga

34

0,6

Gabon

T'Catamba

44,3

0,21

Gabon

Rabi

33,4

0,06

Gabon

Rabi Blend

34

NA

Gabon

Rabi Light

37,7

0,15

Gabon

Etame Marin

36

NA

Gabon

Olende

17,6

1,54

Gabon

Gabonian Miscellaneous

NA

NA

Georgia

Georgian Miscellaneous

NA

NA

Ghana

Bonsu

32

0,1

Ghana

Salt Pond

37,4

0,1

Guatemala

Coban

27,7

NA

Guatemala

Rubelsanto

27

NA

India

Bombay High

39,4

0,2

Indonesia

Minas (Sumatron Light)

34,5

0,1

Indonesia

Ardjuna

35,2

0,1

Indonesia

Attaka

42,3

0,1

Indonesia

Suri

18,4

0,2

Indonesia

Sanga Sanga

25,7

0,2

Indonesia

Sepinggan

37,9

0,9

Indonesia

Walio

34,1

0,7

Indonesia

Arimbi

31,8

0,2

Indonesia

Poleng

43,2

0,2

Indonesia

Handil

32,8

0,1

Indonesia

Jatibarang

29

0,1

Indonesia

Cinta

33,4

0,1

Indonesia

Bekapai

40

0,1

Indonesia

Katapa

52

0,1

Indonesia

Salawati

38

0,5

Indonesia

Duri (Sumatran Heavy)

21,1

0,2

Indonesia

Sembakung

37,5

0,1

Indonesia

Badak

41,3

0,1

Indonesia

Arun Condensate

54,5

NA

Indonesia

Udang

38

0,1

Indonesia

Klamono

18,7

1

Indonesia

Bunya

31,7

0,1

Indonesia

Pamusian

18,1

0,2

Indonesia

Kerindigan

21,6

0,3

Indonesia

Melahin

24,7

0,3

Indonesia

Bunyu

31,7

0,1

Indonesia

Camar

36,3

NA

Indonesia

Cinta Heavy

27

NA

Indonesia

Lalang

40,4

NA

Indonesia

Kakap

46,6

NA

Indonesia

Sisi-1

40

NA

Indonesia

Giti-1

33,6

NA

Indonesia

Ayu-1

34,3

NA

Indonesia

Bima

22,5

NA

Indonesia

Padang Isle

34,7

NA

Indonesia

Intan

32,8

NA

Indonesia

Sepinggan — Yakin Mixed

31,7

0,1

Indonesia

Widuri

32

0,1

Indonesia

Belida

45,9

0

Indonesia

Senipah

51,9

0,03

Iran

Iranian Light

33,8

1,4

Iran

Iranian Heavy

31

1,7

Iran

Soroosh (Cyrus)

18,1

3,3

Iran

Dorrood (Darius)

33,6

2,4

Iran

Rostam

35,9

1,55

Iran

Salmon (Sassan)

33,9

1,9

Iran

Foroozan (Fereidoon)

31,3

2,5

Iran

Aboozar (Ardeshir)

26,9

2,5

Iran

Sirri

30,9

2,3

Iran

Bahrgansar/Nowruz (SIRIP Blend)

27,1

2,5

Iran

Bahr/Nowruz

25,0

2,5

Iran

Iranian Miscellaneous

NA

NA

Iraq

Basrah Light (Pers. Gulf)

33,7

2

Iraq

Kirkuk (Pers. Gulf)

35,1

1,9

Iraq

Mishrif (Pers. Gulf)

28

NA

Iraq

Bai Hasson (Pers. Gulf)

34,1

2,4

Iraq

Basrah Medium (Pers. Gulf)

31,1

2,6

Iraq

Basrah Heavy (Pers. Gulf)

24,7

3,5

Iraq

Kirkuk Blend (Pers. Gulf)

35,1

2

Iraq

N. Rumalia (Pers. Gulf)

34,3

2

Iraq

Ras el Behar

33

NA

Iraq

Basrah Light (Red Sea)

33,7

2

Iraq

Kirkuk (Red Sea)

36,1

1,9

Iraq

Mishrif (Red Sea)

28

NA

Iraq

Bai Hasson (Red Sea)

34,1

2,4

Iraq

Basrah Medium (Red Sea)

31,1

2,6

Iraq

Basrah Heavy (Red Sea)

24,7

3,5

Iraq

Kirkuk Blend (Red Sea)

34

1,9

Iraq

N. Rumalia (Red Sea)

34,3

2

Iraq

Ratawi

23,5

4,1

Iraq

Basrah Light (Turkey)

33,7

2

Iraq

Kirkuk (Turkey)

36,1

1,9

Iraq

Mishrif (Turkey)

28

NA

Iraq

Bai Hasson (Turkey)

34,1

2,4

Iraq

Basrah Medium (Turkey)

31,1

2,6

Iraq

Basrah Heavy (Turkey)

24,7

3,5

Iraq

Kirkuk Blend (Turkey)

34

1,9

Iraq

N. Rumalia (Turkey)

34,3

2

Iraq

FAO Blend

27,7

3,6

Kazakhstan

Kumkol

42,5

0,07

Kazakhstan

CPC Blend

44,2

0,54

Kuwait

Mina al Ahmadi (Kuwait Export)

31,4

2,5

Kuwait

Magwa (Lower Jurassic)

38

NA

Kuwait

Burgan (Wafra)

23,3

3,4

Libya

Bu Attifel

43,6

0

Libya

Amna (high pour)

36,1

0,2

Libya

Brega

40,4

0,2

Libya

Sirtica

43,3

0,43

Libya

Zueitina

41,3

0,3

Libya

Bunker Hunt

37,6

0,2

Libya

El Hofra

42,3

0,3

Libya

Dahra

41

0,4

Libya

Sarir

38,3

0,2

Libya

Zueitina Condensate

65

0,1

Libya

El Sharara

42,1

0,07

Malaysia

Miri Light

36,3

0,1

Malaysia

Tembungo

37,5

NA

Malaysia

Labuan Blend

33,2

0,1

Malaysia

Tapis

44,3

0,1

Malaysia

Tembungo

37,4

0

Malaysia

Bintulu

26,5

0,1

Malaysia

Bekok

49

NA

Malaysia

Pulai

42,6

NA

Malaysia

Dulang

39

0,037

Mauritania

Chinguetti

28,2

0,51

Mexico

Isthmus

32,8

1,5

Mexico

Maya

22

3,3

Mexico

Olmeca

39

NA

Mexico

Altamira

16

NA

Mexico

Topped Isthmus

26,1

1,72

Netherlands

Alba

19,59

NA

Neutral Zone

Eocene (Wafra)

18,6

4,6

Neutral Zone

Hout

32,8

1,9

Neutral Zone

Khafji

28,5

2,9

Neutral Zone

Burgan (Wafra)

23,3

3,4

Neutral Zone

Ratawi

23,5

4,1

Neutral Zone

Neutral Zone Mix

23,1

NA

Neutral Zone

Khafji Blend

23,4

3,8

Nigeria

Forcados Blend

29,7

0,3

Nigeria

Escravos

36,2

0,1

Nigeria

Brass River

40,9

0,1

Nigeria

Qua Iboe

35,8

0,1

Nigeria

Bonny Medium

25,2

0,2

Nigeria

Pennington

36,6

0,1

Nigeria

Bomu

33

0,2

Nigeria

Bonny Light

36,7

0,1

Nigeria

Brass Blend

40,9

0,1

Nigeria

Gilli Gilli

47,3

NA

Nigeria

Adanga

35,1

NA

Nigeria

Iyak-3

36

NA

Nigeria

Antan

35,2

NA

Nigeria

OSO

47

0,06

Nigeria

Ukpokiti

42,3

0,01

Nigeria

Yoho

39,6

NA

Nigeria

Okwori

36,9

NA

Nigeria

Bonga

28,1

NA

Nigeria

ERHA

31,7

0,21

Nigeria

Amenam Blend

39

0,09

Nigeria

Akpo

45,17

0,06

Nigeria

EA

38

NA

Nigeria

Agbami

47,2

0,044

Norway

Ekofisk

43,4

0,2

Norway

Tor

42

0,1

Norway

Statfjord

38,4

0,3

Norway

Heidrun

29

NA

Norway

Norwegian Forties

37,1

NA

Norway

Gullfaks

28,6

0,4

Norway

Oseberg

32,5

0,2

Norway

Norne

33,1

0,19

Norway

Troll

28,3

0,31

Norway

Draugen

39,6

NA

Norway

Sleipner Condensate

62

0,02

Oman

Oman Export

36,3

0,8

Papua New Guinea

Kutubu

44

0,04

Peru

Loreto

34

0,3

Peru

Talara

32,7

0,1

Peru

High Cold Test

37,5

NA

Peru

Bayovar

22,6

NA

Peru

Low Cold Test

34,3

NA

Peru

Carmen Central-5

20,7

NA

Peru

Shiviyacu-23

20,8

NA

Peru

Mayna

25,7

NA

Philippines

Nido

26,5

NA

Philippines

Philippines Miscellaneous

NA

NA

Qatar

Dukhan

41,7

1,3

Qatar

Qatar Marine

35,3

1,6

Qatar

Qatar Land

41,4

NA

Ras Al Khaimah

Rak Condensate

54,1

NA

Ras Al Khaimah

Ras Al Khaimah Miscellaneous

NA

NA

Russia

Urals

31

2

Russia

Russian Export Blend

32,5

1,4

Russia

M100

17,6

2,02

Russia

M100 Heavy

16,67

2,09

Russia

Siberian Light

37,8

0,4

Russia

E4 (Gravenshon)

19,84

1,95

Russia

E4 Heavy

18

2,35

Russia

Purovsky Condensate

64,1

0,01

Russia

Sokol

39,7

0,18

Saudi Arabia

Light (Pers. Gulf)

33,4

1,8

Saudi Arabia

Heavy (Pers. Gulf) (Safaniya)

27,9

2,8

Saudi Arabia

Medium (Pers. Gulf) (Khursaniyah)

30,8

2,4

Saudi Arabia

Extra Light (Pers. Gulf) (Berri)

37,8

1,1

Saudi Arabia

Light (Yanbu)

33,4

1,2

Saudi Arabia

Heavy (Yanbu)

27,9

2,8

Saudi Arabia

Medium (Yanbu)

30,8

2,4

Saudi Arabia

Berri (Yanbu)

37,8

1,1

Saudi Arabia

Medium (Zuluf/Marjan)

31,1

2,5

Sharjah

Mubarek Sharjah

37

0,6

Sharjah

Sharjah Condensate

49,7

0,1

Singapore

Rantau

50,5

0,1

Spain

Amposta Marina North

37

NA

Spain

Casablanca

34

NA

Spain

El Dorado

26,6

NA

Syria

Syrian Straight

15

NA

Syria

Thayyem

35

NA

Syria

Omar Blend

38

NA

Syria

Omar

36,5

0,1

Syria

Syrian Light

36

0,6

Syria

Souedie

24,9

3,8

Thailand

Erawan Condensate

54,1

NA

Thailand

Sirikit

41

NA

Thailand

Nang Nuan

30

NA

Thailand

Bualuang

27

NA

Thailand

Benchamas

42,4

0,12

Trinidad and Tobago

Galeota Mix

32,8

0,3

Trinidad and Tobago

Trintopec

24,8

NA

Trinidad and Tobago

Land/Trinmar

23,4

1,2

Trinidad and Tobago

Calypso Miscellaneous

30,84

0,59

Tunisia

Zarzaitine

41,9

0,1

Tunisia

Ashtart

29

1

Tunisia

El Borma

43,3

0,1

Tunisia

Ezzaouia-2

41,5

NA

Turkey

Turkish Miscellaneous

NA

NA

Ukraine

Ukraine Miscellaneous

NA

NA

United Kingdom

Auk

37,2

0,5

United Kingdom

Beatrice

38,7

0,05

United Kingdom

Brae

33,6

0,7

United Kingdom

Buchan

33,7

0,8

United Kingdom

Claymore

30,5

1,6

United Kingdom

S.V. (Brent)

36,7

0,3

United Kingdom

Tartan

41,7

0,6

United Kingdom

Tern

35

0,7

United Kingdom

Magnus

39,3

0,3

United Kingdom

Dunlin

34,9

0,4

United Kingdom

Fulmar

40

0,3

United Kingdom

Hutton

30,5

0,7

United Kingdom

N.W. Hutton

36,2

0,3

United Kingdom

Maureen

35,5

0,6

United Kingdom

Murchison

38,8

0,3

United Kingdom

Ninian Blend

35,6

0,4

United Kingdom

Montrose

40,1

0,2

United Kingdom

Beryl

36,5

0,4

United Kingdom

Piper

35,6

0,9

United Kingdom

Forties

36,6

0,3

United Kingdom

Brent Blend

38

0,4

United Kingdom

Flotta

35,7

1,1

United Kingdom

Thistle

37

0,3

United Kingdom

S.V. (Ninian)

38

0,3

United Kingdom

Argyle

38,6

0,2

United Kingdom

Heather

33,8

0,7

United Kingdom

South Birch

38,6

NA

United Kingdom

Wytch Farm

41,5

NA

United Kingdom

Cormorant North

34,9

0,7

United Kingdom

Cormorant South (Cormorant ‘A’)

35,7

0,6

United Kingdom

Alba

19,2

NA

United Kingdom

Foinhaven

26,3

0,38

United Kingdom

Schiehallion

25,8

NA

United Kingdom

Captain

19,1

0,7

United Kingdom

Harding

20,7

0,59

US Alaska

ANS

NA

NA

US Colorado

Niobrara

NA

NA

US New Mexico

Four Corners

NA

NA

US North Dakota

Bakken

NA

NA

US North Dakota

North Dakota Sweet

NA

NA

US Texas

WTI

NA

NA

US Texas

Eagle Ford

NA

NA

US Utah

Covenant

NA

NA

US Federal OCS

Beta

NA

NA

US Federal OCS

Carpinteria

NA

NA

US Federal OCS

Dos Cuadras

NA

NA

US Federal OCS

Hondo

NA

NA

US Federal OCS

Hueneme

NA

NA

US Federal OCS

Pescado

NA

NA

US Federal OCS

Point Arguello

NA

NA

US Federal OCS

Point Pedernales

NA

NA

US Federal OCS

Sacate

NA

NA

US Federal OCS

Santa Clara

NA

NA

US Federal OCS

Sockeye

NA

NA

Uzbekistan

Uzbekistan Miscellaneous

NA

NA

Venezuela

Jobo (Monagas)

12,6

2

Venezuela

Lama Lamar

36,7

1

Venezuela

Mariago

27

1,5

Venezuela

Ruiz

32,4

1,3

Venezuela

Tucipido

36

0,3

Venezuela

Venez Lot 17

36,3

0,9

Venezuela

Mara 16/18

16,5

3,5

Venezuela

Tia Juana Light

32,1

1,1

Venezuela

Tia Juana Med 26

24,8

1,6

Venezuela

Officina

35,1

0,7

Venezuela

Bachaquero

16,8

2,4

Venezuela

Cento Lago

36,9

1,1

Venezuela

Lagunillas

17,8

2,2

Venezuela

La Rosa Medium

25,3

1,7

Venezuela

San Joaquin

42

0,2

Venezuela

Lagotreco

29,5

1,3

Venezuela

Lagocinco

36

1,1

Venezuela

Boscan

10,1

5,5

Venezuela

Leona

24,1

1,5

Venezuela

Barinas

26,2

1,8

Venezuela

Sylvestre

28,4

1

Venezuela

Mesa

29,2

1,2

Venezuela

Ceuta

31,8

1,2

Venezuela

Lago Medio

31,5

1,2

Venezuela

Tigre

24,5

NA

Venezuela

Anaco Wax

41,5

0,2

Venezuela

Santa Rosa

49

0,1

Venezuela

Bombai

19,6

1,6

Venezuela

Aguasay

41,1

0,3

Venezuela

Anaco

43,4

0,1

Venezuela

BCF-Bach/Lag17

16,8

2,4

Venezuela

BCF-Bach/Lag21

20,4

2,1

Venezuela

BCF-21,9

21,9

NA

Venezuela

BCF-24

23,5

1,9

Venezuela

BCF-31

31

1,2

Venezuela

BCF Blend

34

1

Venezuela

Bolival Coast

23,5

1,8

Venezuela

Ceuta/Bach 18

18,5

2,3

Venezuela

Corridor Block

26,9

1,6

Venezuela

Cretaceous

42

0,4

Venezuela

Guanipa

30

0,7

Venezuela

Lago Mix Med.

23,4

1,9

Venezuela

Larosa/Lagun

23,8

1,8

Venezuela

Menemoto

19,3

2,2

Venezuela

Cabimas

20,8

1,8

Venezuela

BCF-23

23

1,9

Venezuela

Oficina/Mesa

32,2

0,9

Venezuela

Pilon

13,8

2

Venezuela

Recon (Venez)

34

NA

Venezuela

102 Tj (25)

25

1,6

Venezuela

Tjl Cretaceous

39

0,6

Venezuela

Tia Juana Pesado (Heavy)

12,1

2,7

Venezuela

Mesa-Recon

28,4

1,3

Venezuela

Oritupano

19

2

Venezuela

Hombre Pintado

29,7

0,3

Venezuela

Merey

17,4

2,2

Venezuela

Lago Light

41,2

0,4

Venezuela

Laguna

11,2

0,3

Venezuela

Bach/Cueta Mix

24

1,2

Venezuela

Bachaquero 13

13

2,7

Venezuela

Ceuta — 28

28

1,6

Venezuela

Temblador

23,1

0,8

Venezuela

Lagomar

32

1,2

Venezuela

Taparito

17

NA

Venezuela

BCF-Heavy

16,7

NA

Venezuela

BCF-Medium

22

NA

Venezuela

Caripito Blend

17,8

NA

Venezuela

Laguna/Ceuta Mix

18,1

NA

Venezuela

Morichal

10,6

NA

Venezuela

Pedenales

20,1

NA

Venezuela

Quiriquire

16,3

NA

Venezuela

Tucupita

17

NA

Venezuela

Furrial-2 (E. Venezuela)

27

NA

Venezuela

Curazao Blend

18

NA

Venezuela

Santa Barbara

36,5

NA

Venezuela

Cerro Negro

15

NA

Venezuela

BCF22

21,1

2,11

Venezuela

Hamaca

26

1,55

Venezuela

Zuata 10

15

NA

Venezuela

Zuata 20

25

NA

Venezuela

Zuata 30

35

NA

Venezuela

Monogas

15,9

3,3

Venezuela

Corocoro

24

NA

Venezuela

Petrozuata

19,5

2,69

Venezuela

Morichal 16

16

NA

Venezuela

Guafita

28,6

0,73

Vietnam

Bach Ho (White Tiger)

38,6

0

Vietnam

Dai Hung (Big Bear)

36,9

0,1

Vietnam

Rang Dong

37,7

0,5

Vietnam

Ruby

35,6

0,08

Vietnam

Su Tu Den (Black Lion)

36,8

0,05

Yemen

North Yemeni Blend

40,5

NA

Yemen

Alif

40,4

0,1

Yemen

Maarib Lt.

49

0,2

Yemen

Masila Blend

30-31

0,6

Yemen

Shabwa Blend

34,6

0,6

Any

Oil shale

NA

NA

Any

Shale oil

NA

NA

Any

Natural Gas: piped from source

NA

NA

Any

Natural Gas: from LNG

NA

NA

Any

Shale gas: piped from source

NA

NA

Any

Coal

NA

NA


(1)  Commission Regulation (EC) No 684/2009 of 24 July 2009 implementing Council Directive 2008/118/EC as regards the computerised procedures for the movement of excise goods under suspension of excise duty (OJ L 197, 29.7.2009, p. 24).

(2)  Council Directive 2008/118/EC of 16 December 2008 concerning the general arrangements for excise duty and repealing Directive 92/12/EEC (OJ L 9, 14.1.2009, p. 12).

(3)  The JEC consortium brings together the European Commission Joint Research Centre (JRC), EUCAR (European Council for Automotive R&D) and CONCAWE (the oil companies' European association for environment, health and safety in refining and distribution).

(4)  http://iet.jrc.ec.europa.eu/about-jec/sites/about-jec/files/documents/report_2013/wtt_report_v4_july_2013_final.pdf

(5)  Regulation (EC) No 443/2009 of the European Parliament and of the Council of 23 April 2009 setting emission performance standards for new passenger cars as part of the Community's integrated approach to reduce CO2 emissions from light-duty vehicles (OJ L 140, 5.6.2009, p. 1).

(6)  Commission Regulation (EU) No 600/2012 of 21 June 2012 on the verification of greenhouse gas emission reports and tonne-kilometre reports and the accreditation of verifiers pursuant to Directive 2003/87/EC of the European Parliament and of the Council (OJ L 181, 12.7.2012, p. 1).

(7)  Commission Regulation (EU) No 601/2012 of 21 June 2012 on the monitoring and reporting of greenhouse gas emissions pursuant to Directive 2003/87/EC of the European Parliament and of the Council (OJ L 181, 12.7.2012, p. 30).

(8)  Council Regulation (EC) No 2964/95 of 20 December 1995 introducing registration for crude oil imports and deliveries in the Community (OJ L 310, 22.12.1995, p. 5).

(9)  Commission Regulation (EEC) No 2454/93 of 2 July 1993 laying down provisions for the implementation of Council Regulation (EEC) No 2913/92 establishing the Community Customs Code (OJ L 253, 11.10.1993, p. 1).

(10)  Regulation (EC) No 1099/2008 of the European Parliament and of the Council of 22 October 2008 on energy statistics (OJ L 304, 14.11.2008, p. 1).

(11)  Regulation (EU) No 525/2013 of the European Parliament and of the Council of 21 May 2013 on a mechanism for monitoring and reporting greenhouse gas emissions and for reporting other information at national and Union level relevant to climate change and repealing Decision No 280/2004/EC (OJ L 165, 18.6.2013, p. 13).

(12)  Commission Delegated Regulation (EU) No 666/2014 of 12 March 2014 establishing substantive requirements for a Union inventory system and taking into account changes in the global warming potentials and internationally agreed inventory guidelines pursuant to Regulation (EU) No 525/2013 of the European Parliament and of the Council (OJ L 179, 19.6.2014, p. 26).


ANNEX II

CALCULATION OF THE FUEL BASELINE STANDARD OF FOSSIL FUELS

Calculation method

(a)

The fuel baseline standard is calculated based on Union average fossil fuel consumption of petrol, diesel, gasoil, LPG and CNG, as follows:

Formula

where:

 

‘x’ represents the different fuels and energy falling within the scope of this Directive and as defined in the table below;

 

‘GHGix’ is the greenhouse gas intensity of the annual supply sold on the market of fuel ‘x’ or energy falling within the scope of this Directive expressed in gCO2eq/MJ. The values for fossil fuels presented in point 5 of Part 2 of Annex I are used;

 

‘MJx’ is the total energy supplied and converted from reported volumes of fuel ‘x’ expressed in mega joules.

(b)

Consumption data

The consumption data used for calculation of the value is as follows:

Fuel

Energy Consumption (MJ)

Source

diesel

7 894 969 × 106

2010 Member States reporting to the UNFCCC

non-road gasoil

240 763 × 106

petrol

3 844 356 × 106

LPG

217 563 × 106

CNG

51 037 × 106

Greenhouse gas intensity

The fuel baseline standard for 2010 shall be: 94,1 gCO2eq/MJ


ANNEX III

MEMBER STATE REPORTING TO THE COMMISSION

1.

By 31 December each year, Member States are to report the data listed in point 3. These data must be reported for all fuel and energy placed on the market in each Member State. Where multiple biofuels are blended with fossil fuels, the data for each biofuel must be provided.

2.

The data listed in point 3 are to be reported separately for fuel or energy placed on the market by suppliers within a given Member State (including joint suppliers operating in a single Member State).

3.

For each fuel and energy, Member States are to report the following data to the Commission, as aggregated according to point 2 and as defined in Annex I:

(a)

fuel or energy type;

(b)

volume or quantity of fuel or electricity;

(c)

greenhouse gas intensity;

(d)

UERs;

(e)

origin;

(f)

place of purchase.


ANNEX IV

TEMPLATE FOR REPORTING INFORMATION FOR CONSISTENCY OF THE REPORTED DATA

Fuel — Single Suppliers

Entry

Joint Reporting (YES/NO)

Country

Supplier1

Fuel type7

Fuel CN code7

Quantity2

Average GHG intensity

Upstream Emission Reduction5

Reduction on 2010 average

by litres

by energy

1

 

 

 

 

 

 

 

 

 

 

 

CN code

GHG intensity4

Feedstock

CN code

GHG intensity4

sustainable (YES/NO)

 

Component F.1 (Fossil Fuel Component)

Component B.1 (Biofuel Component)

 

 

 

 

 

 

 

Component F.n (Fossil Fuel Component)

Component B.m (Biofuel Component)

 

 

 

 

 

 

 

 

k

 

 

 

 

 

 

 

 

 

 

 

CN code2

GHG intensity4

Feedstock

CN code2

GHG intensity4

sustainable (YES/NO)

 

Component F.1 (Fossil Fuel Component)

Component B.1 (Biofuel Component)

 

 

 

 

 

 

 

Component F.n (Fossil Fuel Component)

Component B.m (Biofuel Component)

 

 

 

 

 

 

 

 


Fuel — Joint Suppliers

Entry

Joint Reporting (YES/NO)

Country

Supplier1

Fuel type7

Fuel CN code7

Quantity2

Average GHG intensity

Upstream Emission Reduction5

Reduction on 2010 average

by litres

by energy

I

YES

 

 

 

 

 

 

 

 

 

YES

 

 

 

 

 

 

 

 

 

Subtotal

 

 

 

 

 

 

CN code

GHG intensity4

Feedstock

CN code

GHG intensity4

sustainable (YES/NO)

 

Component F.1 (Fossil Fuel Component)

Component B.1 (Biofuel Component)

 

 

 

 

 

 

 

Component F.n (Fossil Fuel Component)

Component B.m (Biofuel Component)

 

 

 

 

 

 

 

 

x

YES

 

 

 

 

 

 

 

 

 

YES

 

 

 

 

 

 

 

 

 

Subtotal

 

 

 

 

 

 

CN code2

GHG intensity4

Feedstock

CN code2

GHG intensity4

sustainable (YES/NO)

 

Component F.1 (Fossil Fuel Component)

Component B.1 (Biofuel Component)

 

 

 

 

 

 

 

Component F.n (Fossil Fuel Component)

Component B.m (Biofuel Component)

 

 

 

 

 

 

 

 


Electricity

Joint Reporting

Country

Supplier1

Energy type7

Quantity6

GHG intensity

Reduction on 2010 average

by energy

NO

 

 

 

 

 

 


Joint Supplier Information

 

Country

Supplier1

Energy type7

Quantity6

GHG intensity

Reduction on 2010 average

by energy

YES

 

 

 

 

 

 

YES

 

 

 

 

 

 

 

Subtotal

 

 

 

 

 


Origin — Single Suppliers8

Entry 1

component F.1

Entry 1

component F.n

Entry k

component F.1

Entry k

component F.n

Feedstock Trade Name

API gravity3

Tonnes

Feedstock Trade Name

API gravity3

Tonnes

Feedstock Trade Name

API gravity3

Tonnes

Feedstock Trade Name

API gravity3

Tonnes

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 


Entry 1

component B.1

Entry 1

component B.m

Entry k

component B.1

Entry k

component B.m

Bio Pathway

API gravity3

Tonnes

Bio Pathway

API gravity3

Tonnes

Bio Pathway

API gravity3

Tonnes

Bio Pathway

API gravity3

Tonnes

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 


Origin — Joint Suppliers8

Entry l

component F.1

Entry l

component F.n

Entry X

component F.1

Entry X

component F.n

Feedstock Trade Name

API gravity3

Tonnes

Feedstock Trade Name

API gravity3

Tonnes

Feedstock Trade Name

API gravity3

Tonnes

Feedstock Trade Name

API gravity3

Tonnes

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 


Entry l

component B.1

Entry l

component B.m

Entry X

component B.1

Entry X

component B.m

Bio Pathway

API gravity3

Tonnes

Bio Pathway

API gravity3

Tonnes

Bio Pathway

API gravity3

Tonnes

Bio Pathway

API gravity3

Tonnes

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 


Place of Purchase9

Entry

Component

Refinery/ Processing Facility Names

Country

Refinery/ Processing Facility Names

Country

Refinery/ Processing Facility Names

Country

Refinery/ Processing Facility Names

Country

Refinery/ Processing Facility Names

Country

Refinery/ Processing Facility Names

Country

1

F.1

 

 

 

 

 

 

 

 

 

 

 

 

1

F.n

 

 

 

 

 

 

 

 

 

 

 

 

1

B.1

 

 

 

 

 

 

 

 

 

 

 

 

1

B.m

 

 

 

 

 

 

 

 

 

 

 

 

k

F.1

 

 

 

 

 

 

 

 

 

 

 

 

k

F.n

 

 

 

 

 

 

 

 

 

 

 

 

k

B.1

 

 

 

 

 

 

 

 

 

 

 

 

k

B.m

 

 

 

 

 

 

 

 

 

 

 

 

l

F.1

 

 

 

 

 

 

 

 

 

 

 

 

l

F.n

 

 

 

 

 

 

 

 

 

 

 

 

l

B.1

 

 

 

 

 

 

 

 

 

 

 

 

l

B.m

 

 

 

 

 

 

 

 

 

 

 

 

X

F.1

 

 

 

 

 

 

 

 

 

 

 

 

X

F.n

 

 

 

 

 

 

 

 

 

 

 

 

X

B.1

 

 

 

 

 

 

 

 

 

 

 

 

X

B.m

 

 

 

 

 

 

 

 

 

 

 

 


Total energy reported and reduction achieved per Member State

Volume (by energy)10

GHG intensity

Reduction on 2010 average

 

 

 

Format Notes

The template for supplier reporting is identical to the template for Member State reporting.

Shaded cells do not have to be filled in.

1.

Supplier identification is defined in point 3(a) of Part 1 of Annex I;

2.

Quantity of fuel is defined in point 3(c) of Part 1 of Annex I;

3.

American Petroleum Institute (API) gravity is defined pursuant to testing method ASTM D287;

4.

Greenhouse gas intensity is defined in point 3(e) of Part 1 of Annex I;

5.

UER is defined in point 3(d) of Part 1 of Annex I; reporting specifications are defined in point 1 of Part 2 of Annex I;

6.

Quantity of electricity is defined in point 6 of Part 2 of Annex I;

7.

Fuel types and corresponding CN codes are defined in point 3(b) of Part 1 of Annex I;

8.

Origin is defined in points 2 and 4 of Part 2 of Annex I;

9.

Place of Purchase is defined in points 3 and 4 of Part 2 of Annex I;

10.

Total quantity of energy (fuel and electricity) consumed.


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