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Document 32023R1185
Commission Delegated Regulation (EU) 2023/1185 of 10 February 2023 supplementing Directive (EU) 2018/2001 of the European Parliament and of the Council by establishing a minimum threshold for greenhouse gas emissions savings of recycled carbon fuels and by specifying a methodology for assessing greenhouse gas emissions savings from renewable liquid and gaseous transport fuels of non-biological origin and from recycled carbon fuels
Commission Delegated Regulation (EU) 2023/1185 of 10 February 2023 supplementing Directive (EU) 2018/2001 of the European Parliament and of the Council by establishing a minimum threshold for greenhouse gas emissions savings of recycled carbon fuels and by specifying a methodology for assessing greenhouse gas emissions savings from renewable liquid and gaseous transport fuels of non-biological origin and from recycled carbon fuels
Commission Delegated Regulation (EU) 2023/1185 of 10 February 2023 supplementing Directive (EU) 2018/2001 of the European Parliament and of the Council by establishing a minimum threshold for greenhouse gas emissions savings of recycled carbon fuels and by specifying a methodology for assessing greenhouse gas emissions savings from renewable liquid and gaseous transport fuels of non-biological origin and from recycled carbon fuels
C/2023/1086
OJ L 157, 20.6.2023, p. 20–33
(BG, ES, CS, DA, DE, ET, EL, EN, FR, GA, HR, IT, LV, LT, HU, MT, NL, PL, PT, RO, SK, SL, FI, SV)
In force
|
20.6.2023 |
EN |
Official Journal of the European Union |
L 157/20 |
COMMISSION DELEGATED REGULATION (EU) 2023/1185
of 10 February 2023
supplementing Directive (EU) 2018/2001 of the European Parliament and of the Council by establishing a minimum threshold for greenhouse gas emissions savings of recycled carbon fuels and by specifying a methodology for assessing greenhouse gas emissions savings from renewable liquid and gaseous transport fuels of non-biological origin and from recycled carbon fuels
THE EUROPEAN COMMISSION,
Having regard to the Treaty on the Functioning of the European Union,
Having regard to Directive (EU) 2018/2001 of the European Parliament and of the Council of 11 December 2018 on the promotion of the use of energy from renewable sources (1), and in particular Articles 25(2) and 28(5) thereof,
Whereas:
|
(1) |
Taking into account the need to substantially reduce greenhouse gas emissions in the transport sector and the possibility for each fuel to make significant greenhouse gas emissions savings by applying carbon capture and storage techniques, among other measures, and considering the greenhouse gas saving requirements set for other fuels in Directive (EU) 2018/2001, a minimum greenhouse gas emission saving threshold of 70 % should be set for all types of recycled carbon fuels. |
|
(2) |
Clear rules need to be set, based on objective and non-discriminatory criteria, for calculating greenhouse gas emissions savings for renewable liquid and gaseous transport fuels of non-biological origin and recycled carbon fuels and their fossil fuel comparators. |
|
(3) |
The greenhouse gas emissions accounting methodology should take into account the full life-cycle emissions from producing renewable liquid and gaseous transport fuels of non-biological origin and recycled carbon fuels and be based on objective and non-discriminatory criteria. |
|
(4) |
Credits should not be granted for capturing CO2 which has already been taken into account under other provisions of Union law. Therefore that kind of captured CO2 should not be considered as being avoided when determining the emissions from the inputs’ existing use or fate. |
|
(5) |
The origin of carbon used for the production of renewable liquid and gaseous transport fuels of non-biological origin and recycled carbon fuels is not relevant for determining emission savings of such fuels in the short term, as currently many carbon sources are available and can be captured while making progress on decarbonisation. In an economy on a trajectory towards climate neutrality by 2050, sources of carbon that can be captured should become scarce in the medium- to long-term, increasingly restricted to CO2 emissions that are hardest to abate. In addition, the continued use of renewable liquid and gaseous transport fuels of non-biological origin and recycled carbon fuels that contain carbon from non-sustainable fuel is not compatible with a trajectory towards climate neutrality by 2050 as it would entail the continued use of non-sustainable fuels and their related emissions. Therefore, capturing of emissions from non-sustainable fuels should not be considered as avoiding emissions indefinitely when determining the greenhouse gas emissions savings from the use of renewable liquid and gaseous transport fuels of non-biological origin and recycled carbon fuels. Captured emissions from the combustion of non-sustainable fuels for the production of electricity should be considered avoided emissions up to 2035, as most should be abated by that date, while emissions from other uses of non-sustainable fuels should be considered avoided emissions up to 2040, as these emissions will remain longer. These dates will be subject to review in light of the implementation in the sectors covered by Directive 2003/87/EC of the European Parliament and of the Council (2) of the Union-wide climate target for 2040. The Union-wide climate target for 2040 is to be proposed by the Commission at the latest within six months of the first global stocktake carried out under the Paris Agreement, in accordance with Regulation (EU) 2021/1119 of the European Parliament and of the Council (3). The implementation of the target in Directive 2003/87/EC will further determine the expected scarcity of emissions in each sector. |
|
(6) |
Emissions from activities listed in Annex I to Directive 2003/87/EC, namely from industrial processes or from the combustion of non-sustainable fuels, should be prevented, even if they could be captured and used to produce renewable liquid and gaseous transport fuels of non-biological origin and recycled carbon fuels. These emissions are subject to carbon pricing to incentivise abating the emissions from non-sustainable fuels in the first place. Therefore, where such emissions are not taken into account upstream through an effective carbon pricing, those emissions must be accounted for and should not be considered as being avoided. |
|
(7) |
Renewable liquid and gaseous transport fuels of non-biological origin and recycled carbon fuels can be produced in various processes, which may yield a mixture of different types of fuels. The methodology to assess the greenhouse gas emissions savings should therefore be able to derive the actual emission savings from those processes, including processes that yield both renewable liquid and gaseous transport fuels of non-biological origin and recycled carbon fuels. |
|
(8) |
To determine the greenhouse gas emissions intensity of renewable liquid and gaseous transport fuels of non-biological origin and recycled carbon fuels it is necessary to calculate the share of the energy content of such fuels in the output of a process. For this purpose, the fraction of each type of fuel should be determined by dividing the relevant energy input for the type of fuel in question by the total relevant energy inputs into the process. In case of the production of renewable liquid and gaseous transport fuels of non-biological origin, it is necessary to determine whether the relevant electricity input should be considered as fully renewable. The relevant electricity input should be counted as fully renewable if the provisions under Article 27(3) fifth and sixth subparagraph of Directive (EU) 2018/2001 are fulfilled. Otherwise, the average share of electricity from renewable sources in the country of production, as measured two years before the year in question, should be used to determine the share of renewable energy. In case of the production of recycled carbon fuels, only liquid or solid waste streams of non-renewable origin which are not suitable for material recovery in accordance with Article 4 of Directive 2008/98/EC of the European Parliament and of the Council (4) and waste processing gas and exhaust gas of non-renewable origin which are produced as an unavoidable and unintentional consequence of the production process in industrial installations can be considered as relevant energy input for the production of recycled carbon fuels. |
|
(9) |
The fossil fuel comparator for renewable liquid and gaseous transport fuels of non-biological origin and recycled carbon fuels should be set at 94 gCO2eq/MJ in line with the value set out for biofuels and bioliquids in Directive (EU) 2018/2001. |
|
(10) |
The main objective of promoting recycled carbon fuels is to reduce greenhouse gas emissions by improving the efficiency of use of eligible feedstock compared to present uses. Given that feedstock that can be used to produce recycled carbon fuels may already have been in use to produce energy, it is appropriate to take the greenhouse gas emissions resulting from the diversion of the use of those rigid inputs from its current use into account when calculating greenhouse gas emissions. The same should apply for rigid inputs obtained from incorporated processes and used to produce renewable liquid and gaseous transport fuels of non-biological origin. |
|
(11) |
If the electricity used to produce renewable liquid and gaseous transport fuels of non-biological origin is taken from the electricity grid and is not considered as fully renewable, the average carbon intensity of electricity consumed in the Member State where the fuel is produced should be applied, given that that best describes the greenhouse gas intensity of the whole process. Alternatively, electricity taken from the electricity grid that is used in the production process of renewable liquid and gaseous transport fuels of non-biological origin and recycled carbon fuels that does not qualify as fully renewable according to Article 27(3) of Directive (EU) 2018/2001, could be attributed greenhouse gas emissions values depending on the number of full load hours the installation producing renewable liquid and gaseous transport fuels of non-biological origin and recycled carbon fuels is operating. If the electricity used to produce renewable liquid and gaseous transport fuels of non-biological origin is considered fully renewable according to the rules set out in Article 27 of Directive (EU) 2018/2001, a carbon intensity of zero should be applied to this electricity supply, |
HAS ADOPTED THIS REGULATION:
Article 1
This Regulation establishes a minimum threshold for greenhouse gas emissions savings of recycled carbon fuels and specifies the methodology to calculate the greenhouse gas emissions savings from renewable liquid and gaseous transport fuels of non-biological origin and from recycled carbon fuels.
Article 2
The greenhouse gas emissions savings from the use of recycled carbon fuels shall be at least 70 %.
Article 3
The greenhouse gas emissions savings from renewable liquid and gaseous transport fuels of non-biological origin and from recycled carbon fuels shall be determined in accordance with the methodology set out in the Annex.
Article 4
This Regulation shall enter into force on the twentieth day following that of its publication in the Official Journal of the European Union.
This Regulation shall be binding in its entirety and directly applicable in all Member States.
Done at Brussels, 10 February 2023.
For the Commission
The President
Ursula VON DER LEYEN
(1) OJ L 328, 21.12.2018, p. 82.
(2) Directive 2003/87/EC of the European Parliament and of the Council of 13 October 2003 establishing a scheme for greenhouse gas emission allowance trading within the Community and amending Council Directive 96/61/EC (OJ L 275, 25.10.2003, p. 32).
(3) Regulation (EU) 2021/1119 of the European Parliament and of the Council of 30 June 2021 establishing the framework for achieving climate neutrality and amending Regulations (EC) No 401/2009 and (EU) 2018/1999 (OJ L 243, 9.7.2021, p. 1).
(4) Directive 2008/98/EC of the European Parliament and of the Council of 19 November 2008 on waste and repealing certain Directives (OJ L 312, 22.11.2008, p. 3).
ANNEX
Methodology for determining greenhouse gas emissions savings from renewable liquid and gaseous transport fuels of non-biological origin and from recycled carbon fuels
A. METHODOLOGY
|
1. |
Greenhouse gas emissions from the production and use of renewable liquid and gaseous transport fuels of non-biological origin or recycled carbon fuels shall be calculated as follows:
E = e i + e p + e td + e u – e ccs where:
Emissions from the manufacture of machinery and equipment shall not be taken into account. The greenhouse gas emissions intensity of renewable liquid and gaseous transport fuels of non-biological origin or recycled carbon fuels shall be determined by dividing the total emissions of the process covering each element of the formula by the total amount of fuel stemming from the process and shall be expressed in terms of grams of CO2 equivalent per MJ of fuel (gCO2eq/MJ fuel). If a fuel is a mix of renewable liquid and gaseous transport fuels of non-biological origin, recycled carbon fuels and other fuels, all (fuel) types shall be considered to have the same emission intensity. The exception to this rule is the case of co-processing where renewable liquid and gaseous transport fuels of non-biological origin and recycled carbon fuels are only partially replacing a conventional input in a process. In such a situation it shall be distinguished in the calculation of the greenhouse gas emissions intensity on a proportional basis of the energetic value of inputs between:
An analogous distinction between processes shall be applied where renewable liquid and gaseous transport fuels of non-biological origin and recycled carbon fuels are processed together with biomass. The greenhouse gas emissions intensity may be calculated as an average for the entire production of fuels occurring during a period of at most one calendar month but may also be calculated for shorter time intervals. Where electricity qualifying as fully renewable according to the methodology set out in Directive (EU) 2018/2001 is used as input that enhances the heating value of the fuel or intermediate products, the time interval shall be in line with the requirements applying for temporal correlation. Where relevant, greenhouse gas emissions intensity values calculated for individual time intervals may then be used to calculate an average greenhouse gas emissions intensity for a period of up to one month, provided that the individual values calculated for each time period meet the minimum savings threshold of 70 %. |
|
2. |
Greenhouse gas emission savings from renewable liquid and gaseous transport fuels of non-biological origin or from recycled carbon fuels shall be calculated as follows:
Savings = (E F – E)/E F where:
For all renewable liquid and gaseous transport fuels of non-biological origin and recycled carbon fuels, the total emissions from the fossil fuel comparator shall be 94 gCO2eq/MJ. |
|
3. |
If the output of a process does not fully qualify as renewable liquid and gaseous transport fuels of non-biological origin or recycled carbon fuel, their respective shares in the total output shall be determined as follows:
The relevant energy for material inputs is the lower heating value of the material input that enters into the molecular structure of the fuel (1). For electricity inputs that are used to enhance the heating value of the fuel or intermediate products the relevant energy is the energy of the electricity. For industrial off-gases, it is the energy in the off-gas based on their lower heating value. In case of heat that is used to enhance the heating value of the fuel or intermediate product, the relevant energy is the useful energy in the heat that is used to synthesise the fuel. Useful heat is the total heat energy multiplied by the Carnot efficiency, as defined in Annex V, part C, point (1)(b) of Directive (EU) 2018/2001. Other inputs are only taken into account when determining the emission intensity of the fuel. |
|
4. |
When determining emissions from supply of inputs, it shall be distinguished between elastic inputs and rigid inputs. Rigid inputs are those whose supply cannot be expanded to meet extra demand. Thus, all inputs qualifying as a carbon source for the production of recycled carbon fuels are rigid, as well as outputs produced in fixed ratio by an incorporated process (2) and which represent less than 10 % of the economic value of the output. If it represents 10 % or more of the economic value, it shall be treated as elastic. In principle, elastic inputs are those whose supply can be increased to meet extra demand. Petroleum products from refineries fall into this category because refineries can change the ratio of their products. |
|
5. |
Electricity qualifying as fully renewable according to Article 27(3) of Directive (EU) 2018/2001, shall be attributed zero greenhouse gas emissions. |
|
6. |
One of the three following alternative methods shall be applied during each calendar year to attribute greenhouse gas emissions values to the electricity taken from the grid that does not qualify as fully renewable according to Article 27(3) of Directive (EU) 2018/2001 and is used to produce renewable liquid and gaseous transport fuels of non-biological origin and recycled carbon fuels:
If the method set in point (b) is used, it shall also be applied to electricity that is used to produce renewable liquid and gaseous transport fuels of non-biological origin and recycled carbon fuels and qualifies as fully renewable according to Article 27(3) of Directive (EU) 2018/2001. |
|
7. |
GHG emissions of elastic inputs that are obtained from an incorporated process shall be determined based on data from their actual production process. This shall include all emissions arising due to their production over the whole supply chain (including emissions arising from the extraction of the primary energy required to make the input, processing of the input and transportation of the input). Combustion emissions related to the carbon content of fuel inputs shall not be included (3).
However, GHG emissions from the elastic inputs that are not obtained from an incorporated process shall be determined based on the values included in Part B of this Annex. If the input is not included in the list, information of the emission intensity may be drawn from the latest version of the JEC-WTW report, the ECOINVENT database, official sources such as the IPCC, IEA or government, other reviewed sources such as the E3 and GEMIS database and peer reviewed publications. |
|
8. |
The supplier of each input, excluding those where the values are taken from part B of this Annex, shall calculate the emissions intensity (4) of the input following the procedures in this document, and report the value to the next production step or final fuel producer. The same rule applies to the suppliers of inputs further back in the supply chain. |
|
9. |
Emissions from rigid inputs shall include the emissions resulting from the diversion of those inputs from a previous or alternative use. These emissions shall take into account the loss of production of electricity, heat or products that were previously generated using the input as well as any emissions due to additional treatment of the input and transport. The following rules shall apply:
|
|
10. |
Emissions from existing use or fate include all emissions in the existing use or fate of the input that are avoided when the input is used for fuel production. These emissions shall include the CO2 equivalent of the carbon incorporated in the chemical composition of the fuel that would have otherwise been emitted as CO2 into the atmosphere. This includes CO2 that was captured and incorporated into the fuel provided that at least one of the following conditions is fulfilled:
Captured CO2 stemming from a fuel that is deliberately combusted for the specific purpose of producing the CO2 and CO2, the capture of which has received an emissions credit under other provisions of the law shall not be included. Emissions associated with the inputs like electricity and heat and consumable materials used in the capture process of CO2 shall be included in the calculation of emissions attributed to inputs. |
|
11. |
The dates established in point 10(a) will be subject to review considering the implementation in the sectors covered by Directive 2003/87/EC of the Union-wide climate target for 2040 established in accordance with Article 4(3) of Regulation (EU) 2021/1119. |
|
12. |
Emissions from processing shall include direct atmospheric emissions from the processing itself, from waste treatment and from leakages. |
|
13. |
Emissions from combustion of the fuel refer to the total combustion emissions of the fuel in use. |
|
14. |
The greenhouse gases taken into account in emissions calculations, and their carbon dioxide equivalents, shall be the same as specified in Annex V, part C, point 4 of Directive (EU) 2018/2001. |
|
15. |
Where a process yields multiple co-products such as fuels or chemicals, as well as energy co-products such as heat, electricity or mechanical energy exported from the plant, greenhouse gas emissions shall be allocated to these co-products applying the following approaches in the following manner:
|
|
16. |
Emissions from transport and distribution shall include emissions from the storage and distribution of the finished fuels. Emissions attributed to inputs e i shall include emissions from their associated transport and storage. |
|
17. |
Where a process for making renewable liquid and gaseous transport fuels of non-biological origin or recycled carbon fuels produces carbon emissions that are permanently stored in accordance with Directive 2009/31/EC on the geological storage of carbon dioxide, this may be credited to the products of the process as a reduction in emissions under e ccs . Emissions arising due to the storage operation (including transport of the carbon dioxide) will also need to be taken into account under e p . |
B. ‘STANDARD VALUES’ FOR GREENHOUSE GAS EMISSION INTENSITIES OF ELASTIC INPUTS
The GHG intensities of inputs other than electricity are shown in the table below:
|
|
Total emissions gCO2eq/MJ |
Upstream emissions gCO2eq/MJ |
Combustion emissions gCO2eq/MJ |
|
Natural gas |
66,0 |
9,7 |
56,2 |
|
Diesel |
95,1 |
21,9 |
73,2 |
|
Gasoline |
93,3 |
19,9 |
73,4 |
|
Heavy fuel oil |
94,2 |
13,6 |
80,6 |
|
Methanol |
97,1 |
28,2 |
68,9 |
|
Hard coal |
112,3 |
16,2 |
96,1 |
|
Lignite |
116,7 |
1,7 |
115,0 |
|
|
gCO2eq/kg |
|
Ammonia |
2 351,3 |
|
Calcium chloride (CaCl2) |
38,8 |
|
Cyclohexane |
723,0 |
|
Hydrochloric acid (HCl) |
1 061,1 |
|
Lubricants |
947,0 |
|
Magnesium sulphate (MgSO4) |
191,8 |
|
Nitrogen |
56,4 |
|
Phosphoric acid (H3PO4) |
3 124,7 |
|
Potassium hydroxide (KOH) |
419,1 |
|
Pure CaO for processes |
1 193,2 |
|
Sodium carbonate (Na2CO3) |
1 245,1 |
|
Sodium chloride (NaCl) |
13,3 |
|
Sodium hydroxide (NaOH) |
529,7 |
|
Sodium methoxide (Na(CH3O)) |
2 425,5 |
|
SO2 |
53,3 |
|
Sulphuric acid (H2SO4) |
217,5 |
|
Urea |
1 846,6 |
C. GHG EMISSION INTENSITY OF ELECTRICITY
The greenhouse gas emission intensity of electricity shall be determined at the level of countries or at the level of bidding zones. The greenhouse gas emission intensity of electricity may be determined at the level of bidding zones only, if the required data are publicly available. The calculation the carbon intensity of electricity, expressed as gCO2eq/kWh electricity, shall consider all potential primary energy sources for electricity generation, type of plant, conversion efficiencies and own electricity consumption in the power plant.
The calculation shall consider all carbon equivalent emissions, associated with the combustion and supply of the fuels used for electricity production. This relies on the amount of different fuels used in the electricity production facilities and the emission factors from fuel combustion and the upstream fuel emission factors.
Greenhouse Gases other than CO2 shall be converted to CO2eq by multiplying their Global Warming Potential (GWP) relative to CO2 over the 100-year time horizon as set out in Annex V, part C, point 4 to Directive (EU) 2018/2001. Because of their biogenic origin, CO2 emissions from the combustion of biomass fuels are not accounted for, but emissions of CH4 and N2O shall be accounted for.
For the calculation of the GHG emissions from fuels combustion, the IPCC default emission factors for stationary combustion in the energy industries shall be used (IPCC 2006). The upstream emissions shall include emissions from all the processes and phases required to make the fuel ready to supply the power production; they result from the extraction, refining and transport of the fuel used for electricity production.
In addition, all the upstream emissions from the cultivation, harvesting, collection, processing and transport of biomass shall be considered. Peat and the components of waste materials that are from fossil origins shall be treated as a fossil fuel.
The fuels used for gross electricity production in electricity only plants are determined based on the electricity production and the efficiency of conversion to electricity. In the case of Combined Heat and Power (CHP), the fuels used for heat produced in CHP shall be counted by considering alternative heat production with average overall efficiencies of 85 %, while the rest shall be attributed to electricity generation.
For nuclear power plants, the conversion efficiency from nuclear heat shall be assumed to be 33 % or data provided by Eurostat or a similar, accredited source.
No fuels are associated with electricity production from renewables that include hydro, solar, wind and geothermal. The emissions from the construction and decommissioning and waste management of electricity producing facilities are not considered. Thus, the carbon equivalent emissions associated with the renewable electricity (wind, solar, hydro and geothermal) production are considered to be equal to zero.
The CO2 equivalent emissions from gross electricity production shall include upstream emissions from JEC WTW v5 (Prussi et al, 2020) listed in Table 3 and the default emission factors for stationary combustion from IPCC Guidelines for National Greenhouse Gas Inventories (IPCC 2006) listed in Tables 1 and 2. The upstream emissions for supplying the fuel used shall be calculated applying the JEC WTW v5 upstream emission factors (Prussi et al, 2020).
The calculation of the carbon intensity of electricity shall be done following the formula:
|
where: |
e gross_prod |
= |
CO2 equivalent emissions |
|
|
= |
upstream CO2 equivalent emission factors |
|
|
|
= |
CO2 equivalent emission factors from fuels combustion |
|
|
B i |
= |
fuel consumption for electricity generation |
|
|
|
= |
fuels used for electricity production |
The amount of net electricity production is determined by the gross electricity production, own electricity consumption in the power plant and the electricity losses in pump storage.
|
where: |
E net |
= |
net electricity production |
|
E gross |
= |
gross electricity production |
|
|
E own |
= |
own internal electricity consumption in power plant |
|
|
E pump |
= |
electricity for pumping |
The carbon intensity of net produced electricity shall be the total gross GHG emissions for producing or using the net electricity:
where: CI = CO2 equivalent emissions from electricity production 
Electricity production and fuel consumption data
Data on electricity production and fuel consumption shall be sourced from IEA Data and statistics that provides data on energy balances and electricity produced using various fuels, e.g. from IEA website, Data and Statistic section (‘Energy Statistics Data Browser’) (6).
For EU Member States, Eurostat data are more detailed and can be used instead. Where the greenhouse gas emission intensity is established at the level of bidding zones, data from official national statistics of the same level of detail as the IEA data shall be used. Fuel consumption data shall include available data at the highest level of detail available from national statistics: solid fossil fuels, manufactured gases, peat and peat products, oil shale and oil sands, oil and petroleum products, natural gas, renewables and biofuels, non-renewable waste and nuclear. Renewables and biofuels include biofuels, renewable municipal waste, hydro, ocean, geothermal, wind, solar and heat pumps.
Input data from literature sources
Table 1
Default emissions factors for stationary combustion [g/MJ fuel on a net calorific value]
|
Fuel |
CO2 |
CH4 |
N2O |
||||
|
Solid fossil fuels |
|
|
|
||||
|
Anthracite |
98,3 |
0,001 |
0,0015 |
||||
|
Coking coal |
94,6 |
0,001 |
0,0015 |
||||
|
Other bituminous coal |
94,6 |
0,001 |
0,0015 |
||||
|
Sub-bituminous coal |
96,1 |
0,001 |
0,0015 |
||||
|
Lignite |
101 |
0,001 |
0,0015 |
||||
|
Patent fuel |
97,5 |
0,001 |
0,0015 |
||||
|
Coke oven coke |
107 |
0,001 |
0,0015 |
||||
|
Gas coke |
107 |
0,001 |
0,0001 |
||||
|
Coal tar |
80,7 |
0,001 |
0,0015 |
||||
|
Brown coal briquettes |
97,5 |
0,001 |
0,0015 |
||||
|
Manufactured gases |
|
|
|
||||
|
Gas works gas |
44,4 |
0,001 |
0,0001 |
||||
|
Coke oven gas |
44,4 |
0,001 |
0,0001 |
||||
|
Blast furnace gas |
260 |
0,001 |
0,0001 |
||||
|
Other recovered gases |
182 |
0,001 |
0,0001 |
||||
|
Peat and peat products |
106 |
0,001 |
0,0015 |
||||
|
Oil shale and oil sands |
73,3 |
0,003 |
0,0006 |
||||
|
Oil and petroleum products |
|
|
|
||||
|
Crude oil |
73,3 |
0,003 |
0,0006 |
||||
|
Natural gas liquids |
64,2 |
0,003 |
0,0006 |
||||
|
Refinery feedstocks |
73,3 |
0,003 |
0,0006 |
||||
|
Additives and oxygenates |
73,3 |
0,003 |
0,0006 |
||||
|
Other hydrocarbons |
73,3 |
0,003 |
0,0006 |
||||
|
Refinery gas |
57,6 |
0,001 |
0,0001 |
||||
|
Ethane |
61,6 |
0,001 |
0,0001 |
||||
|
Liquefied petroleum gases |
63,1 |
0,001 |
0,0001 |
||||
|
Motor gasoline |
69,3 |
0,003 |
0,0006 |
||||
|
Aviation gasoline |
70 |
0,003 |
0,0006 |
||||
|
Gasoline-type jet fuel |
70 |
0,003 |
0,0006 |
||||
|
Kerosene-type jet fuel |
71,5 |
0,003 |
0,0006 |
||||
|
Other kerosene |
71,5 |
0,003 |
0,0006 |
||||
|
Naphtha |
73,3 |
0,003 |
0,0006 |
||||
|
Gas oil and diesel oil |
74,1 |
0,003 |
0,0006 |
||||
|
Fuel oil |
77,4 |
0,003 |
0,0006 |
||||
|
White spirit and SBP |
73,3 |
0,003 |
0,0006 |
||||
|
Lubricants |
73,3 |
0,003 |
0,0006 |
||||
|
Bitumen |
80,7 |
0,003 |
0,0006 |
||||
|
Petroleum coke |
97,5 |
0,003 |
0,0006 |
||||
|
Paraffin waxes |
73,3 |
0,003 |
0,0006 |
||||
|
Other oil products |
73,3 |
0,003 |
0,0006 |
||||
|
Natural gas |
56,1 |
0,001 |
0,0001 |
||||
|
Waste |
|
|
|
||||
|
Industrial waste (non-renewable) |
143 |
0,03 |
0,004 |
||||
|
Non-renewable municipal waste |
91,7 |
0,03 |
0,004 |
||||
|
|||||||
Table 2
Default emissions factors for stationary combustion of fuels of biomass origin [g/MJ fuel on a net calorific value]
|
Fuel |
CO2 |
CH4 |
N2O |
||
|
Primary solid biofuels |
0 |
0,03 |
0,004 |
||
|
Charcoal |
0 |
0,2 |
0,004 |
||
|
Biogases |
0 |
0,001 |
0,0001 |
||
|
Renewable municipal waste |
0 |
0,03 |
0,004 |
||
|
Pure biogasoline |
0 |
0,003 |
0,0006 |
||
|
Blended biogasoline |
0 |
0,003 |
0,0006 |
||
|
Pure biodiesels |
0 |
0,003 |
0,0006 |
||
|
Blended biodiesels |
0 |
0,003 |
0,0006 |
||
|
Pure bio jet kerosene |
0 |
0,003 |
0,0006 |
||
|
Blended bio jet kerosene |
0 |
0,003 |
0,0006 |
||
|
Other liquid biofuels |
0 |
0,003 |
0,0006 |
||
|
|||||
Table 3
Fuel upstream emission factors [gCO2eq/MJ fuel on a net calorific value]
|
Fuel |
Emission factor |
||
|
Hard coal |
15,9 |
||
|
Brown coal |
1,7 |
||
|
Peat |
0 |
||
|
Coal gases |
0 |
||
|
Petroleum Products |
11,6 |
||
|
Natural gas |
12,7 |
||
|
Solid biofuels |
0,7 |
||
|
Liquid biofuels |
46,8 |
||
|
Industrial Waste |
0 |
||
|
Municipal waste |
0 |
||
|
Biogases |
13,7 |
||
|
Nuclear |
1,2 |
||
|
|||
Table A includes the values for the GHG emission intensity of electricity at country level in the European Union. If the greenhouse gas emission intensity of electricity is determined at country level, these values shall be used for electricity sourced in the European Union until more recent data becomes available to determine the emission intensity of electricity (7).
Table A
Emission intensity of electricity in the European Union 2020
|
Country |
Emission intensity of generated electricity (gCO2eq/MJ) |
||
|
Austria |
39,7 |
||
|
Belgium |
56,7 |
||
|
Bulgaria |
119,2 |
||
|
Cyprus |
206,6 |
||
|
Czechia |
132,5 |
||
|
Germany |
99,3 |
||
|
Denmark |
27,1 |
||
|
Estonia |
139,8 |
||
|
Greece |
125,2 |
||
|
Spain |
54,1 |
||
|
Finland |
22,9 |
||
|
France |
19,6 |
||
|
Croatia |
55,4 |
||
|
Hungary |
72,9 |
||
|
Ireland |
89,4 |
||
|
Italy |
92,3 |
||
|
Latvia |
39,4 |
||
|
Lithuania |
57,7 |
||
|
Luxembourg |
52,0 |
||
|
Malta |
133,9 |
||
|
Netherlands |
99,9 |
||
|
Poland |
196,5 |
||
|
Portugal |
61,6 |
||
|
Romania |
86,1 |
||
|
Slovakia |
45,6 |
||
|
Slovenia |
70,1 |
||
|
Sweden |
4,1 |
||
|
|||
(1) For material inputs containing water, the lower heating value is taken to be the lower heating value of the dry part of the material input (i.e. not taking into account the energy needed to evaporate the water). Renewable liquid and gaseous transport fuels of non-biological origin used as intermediate products for the production of conventional fuels are not considered.
(2) Incorporated processes include processes that take place in the same industrial complex, or that supply the input via a dedicated supply infrastructure, or that supply more than half of the energy of all inputs to the production of the renewable liquid and gaseous transport fuel of non-biological origin or recycled carbon fuel.
(3) If carbon intensities are taken from the table in part B, combustion emissions shall not be considered. This is because combustion emissions are counted in processing or in the combustion emissions of the final fuel.
(4) Consistent with section 6 the emissions intensity shall not include the emissions embedded in the carbon content of the supplied input.
(5) Note that it is the relative values of the co-products that matters, so general inflation is not an issue.
(6) Example: https://www.iea.org/data-and-statistics/data-tools/energy-statistics-data-browser?country=GERMANY&energy=Coal&year=202.
(7) Updated data will be made available by the European Commission on a regular basis.