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Document 02018L2001-20220607
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 (recast) (Text with EEA relevance)Text with EEA relevance
Consolidated text: 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 (recast) (Text with EEA relevance)Text with EEA relevance
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 (recast) (Text with EEA relevance)Text with EEA relevance
02018L2001 — EN — 07.06.2022 — 001.001
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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 (recast) (OJ L 328 21.12.2018, p. 82) |
Amended by:
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COMMISSION DELEGATED REGULATION (EU) 2022/759 of 14 December 2021 |
L 139 |
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18.5.2022 |
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Corrected by:
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
(recast)
(Text with EEA relevance)
Article 1
Subject matter
This Directive establishes a common framework for the promotion of energy from renewable sources. It sets a binding Union target for the overall share of energy from renewable sources in the Union's gross final consumption of energy in 2030. It also lays down rules on financial support for electricity from renewable sources, on self-consumption of such electricity, on the use of energy from renewable sources in the heating and cooling sector and in the transport sector, on regional cooperation between Member States, and between Member States and third countries, on guarantees of origin, on administrative procedures and on information and training. It also establishes sustainability and greenhouse gas emissions saving criteria for biofuels, bioliquids and biomass fuels.
Article 2
Definitions
For the purposes of this Directive, the relevant definitions in Directive 2009/72/EC of the European Parliament and of the Council ( 1 ) apply.
The following definitions also apply:
‘energy from renewable sources’ or ‘renewable energy’ means energy from renewable non-fossil sources, namely wind, solar (solar thermal and solar photovoltaic) and geothermal energy, ambient energy, tide, wave and other ocean energy, hydropower, biomass, landfill gas, sewage treatment plant gas, and biogas;
‘ambient energy’ means naturally occurring thermal energy and energy accumulated in the environment with constrained boundaries, which can be stored in the ambient air, excluding in exhaust air, or in surface or sewage water;
‘geothermal energy’ means energy stored in the form of heat beneath the surface of solid earth;
‘gross final consumption of energy’ means the energy commodities delivered for energy purposes to industry, transport, households, services including public services, agriculture, forestry and fisheries, the consumption of electricity and heat by the energy branch for electricity, heat and transport fuel production, and losses of electricity and heat in distribution and transmission;
‘support scheme’ means any instrument, scheme or mechanism applied by a Member State, or a group of Member States, that promotes the use of energy from renewable sources by reducing the cost of that energy, increasing the price at which it can be sold, or increasing, by means of a renewable energy obligation or otherwise, the volume of such energy purchased, including but not restricted to, investment aid, tax exemptions or reductions, tax refunds, renewable energy obligation support schemes including those using green certificates, and direct price support schemes including feed-in tariffs and sliding or fixed premium payments;
‘renewable energy obligation’ means a support scheme requiring energy producers to include a given share of energy from renewable sources in their production, requiring energy suppliers to include a given share of energy from renewable sources in their supply, or requiring energy consumers to include a given share of energy from renewable sources in their consumption, including schemes under which such requirements may be fulfilled by using green certificates;
‘financial instrument’ means a financial instrument as defined in point (29) of Article 2 of Regulation (EU, Euratom) 2018/1046 of the European Parliament and of the Council ( 2 );
‘SME’ means a micro, small or medium-sized enterprise as defined in Article 2 of the Annex to Commission Recommendation 2003/361/EC ( 3 );
‘waste heat and cold’ means unavoidable heat or cold generated as by-product in industrial or power generation installations, or in the tertiary sector, which would be dissipated unused in air or water without access to a district heating or cooling system, where a cogeneration process has been used or will be used or where cogeneration is not feasible;
‘repowering’ means renewing power plants that produce renewable energy, including the full or partial replacement of installations or operation systems and equipment for the purposes of replacing capacity or increasing the efficiency or capacity of the installation;
‘distribution system operator’ means an operator as defined in point (6) of Article 2 of Directive 2009/72/EC and in point (6) of Article 2 of Directive 2009/73/EC of the European Parliament and of the Council ( 4 );
‘guarantee of origin’ means an electronic document which has the sole function of providing evidence to a final customer that a given share or quantity of energy was produced from renewable sources;
‘residual energy mix’ means the total annual energy mix for a Member State, excluding the share covered by cancelled guarantees of origin;
‘renewables self-consumer’ means a final customer operating within its premises located within confined boundaries or, where permitted by a Member State, within other premises, who generates renewable electricity for its own consumption, and who may store or sell self-generated renewable electricity, provided that, for a non-household renewables self-consumer, those activities do not constitute its primary commercial or professional activity;
‘jointly acting renewables self-consumers’ means a group of at least two jointly acting renewables self-consumers in accordance with point (14) who are located in the same building or multi-apartment block;
‘renewable energy community’ means a legal entity:
which, in accordance with the applicable national law, is based on open and voluntary participation, is autonomous, and is effectively controlled by shareholders or members that are located in the proximity of the renewable energy projects that are owned and developed by that legal entity;
the shareholders or members of which are natural persons, SMEs or local authorities, including municipalities;
the primary purpose of which is to provide environmental, economic or social community benefits for its shareholders or members or for the local areas where it operates, rather than financial profits;
‘renewables power purchase agreement’ means a contract under which a natural or legal person agrees to purchase renewable electricity directly from an electricity producer;
‘peer-to-peer trading’ of renewable energy means the sale of renewable energy between market participants by means of a contract with pre-determined conditions governing the automated execution and settlement of the transaction, either directly between market participants or indirectly through a certified third-party market participant, such as an aggregator. The right to conduct peer-to-peer trading shall be without prejudice to the rights and obligations of the parties involved as final customers, producers, suppliers or aggregators;
‘district heating’ or ‘district cooling’ means the distribution of thermal energy in the form of steam, hot water or chilled liquids, from central or decentralised sources of production through a network to multiple buildings or sites, for the use of space or process heating or cooling;
‘efficient district heating and cooling’ means efficient district heating and cooling as defined in point (41) of Article 2 of Directive 2012/27/EU;
‘high-efficiency cogeneration’ means high-efficiency cogeneration as defined in point (34) of Article 2 of Directive 2012/27/EU;
‘energy performance certificate’ means energy performance certificate as defined in point (12) of Article 2 of Directive 2010/31/EU;
‘waste’ means waste as defined in point (1) of Article 3 of Directive 2008/98/EC, excluding substances that have been intentionally modified or contaminated in order to meet this definition;
‘biomass’ means the biodegradable fraction of products, waste and residues from biological origin from agriculture, including vegetal and animal substances, from forestry and related industries, including fisheries and aquaculture, as well as the biodegradable fraction of waste, including industrial and municipal waste of biological origin;
‘agricultural biomass’ means biomass produced from agriculture;
‘forest biomass’ means biomass produced from forestry;
‘biomass fuels’ means gaseous and solid fuels produced from biomass;
‘biogas’ means gaseous fuels produced from biomass;
‘biowaste’ means biowaste as defined in point (4) of Article 3 of Directive 2008/98/EC;
‘sourcing area’ means the geographically defined area from which the forest biomass feedstock is sourced, from which reliable and independent information is available and where conditions are sufficiently homogeneous to evaluate the risk of the sustainability and legality characteristics of the forest biomass;
‘forest regeneration’ means the re-establishment of a forest stand by natural or artificial means following the removal of the previous stand by felling or as a result of natural causes, including fire or storm;
‘bioliquids’ means liquid fuel for energy purposes other than for transport, including electricity and heating and cooling, produced from biomass;
‘biofuels’ means liquid fuel for transport produced from biomass;
‘advanced biofuels’ means biofuels that are produced from the feedstock listed in Part A of Annex IX;
‘recycled carbon fuels’ means liquid and gaseous fuels that are produced from 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, or from 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;
‘renewable liquid and gaseous transport fuels of non-biological origin’ means liquid or gaseous fuels which are used in the transport sector other than biofuels or biogas, the energy content of which is derived from renewable sources other than biomass;
‘low indirect land-use change-risk biofuels, bioliquids and biomass fuels’ means biofuels, bioliquids and biomass fuels, the feedstock of which was produced within schemes which avoid displacement effects of food and feed-crop based biofuels, bioliquids and biomass fuels through improved agricultural practices as well as through the cultivation of crops on areas which were previously not used for cultivation of crops, and which were produced in accordance with the sustainability criteria for biofuels, bioliquids and biomass fuels laid down in Article 29;
‘fuel supplier’ means an entity supplying fuel to the market that is responsible for passing fuel through an excise duty point or, in the case of electricity or where no excise is due or where duly justified, any other relevant entity designated by a Member State;
‘starch-rich crops’ means crops comprising mainly cereals, regardless of whether the grains alone or the whole plant, such as in the case of green maize, are used; tubers and root crops, such as potatoes, Jerusalem artichokes, sweet potatoes, cassava and yams; and corm crops, such as taro and cocoyam;
‘food and feed crops’ means starch-rich crops, sugar crops or oil crops produced on agricultural land as a main crop excluding residues, waste or ligno-cellulosic material and intermediate crops, such as catch crops and cover crops, provided that the use of such intermediate crops does not trigger demand for additional land;
‘ligno-cellulosic material’ means material composed of lignin, cellulose and hemicellulose, such as biomass sourced from forests, woody energy crops and forest-based industries' residues and wastes;
‘non-food cellulosic material’ means feedstock mainly composed of cellulose and hemicellulose, and having a lower lignin content than ligno-cellulosic material, including food and feed crop residues, such as straw, stover, husks and shells; grassy energy crops with a low starch content, such as ryegrass, switchgrass, miscanthus, giant cane; cover crops before and after main crops; ley crops; industrial residues, including from food and feed crops after vegetal oils, sugars, starches and protein have been extracted; and material from biowaste, where ley and cover crops are understood to be temporary, short-term sown pastures comprising grass-legume mixture with a low starch content to obtain fodder for livestock and improve soil fertility for obtaining higher yields of arable main crops;
‘residue’ means a substance that is not the end product(s) that a production process directly seeks to produce; it is not a primary aim of the production process and the process has not been deliberately modified to produce it;
‘agricultural, aquaculture, fisheries and forestry residues’ means residues that are directly generated by agriculture, aquaculture, fisheries and forestry and that do not include residues from related industries or processing;
‘actual value’ means the greenhouse gas emissions savings for some or all of the steps of a specific biofuel, bioliquid or biomass fuel production process, calculated in accordance with the methodology laid down in Part C of Annex V or Part B of Annex VI;
‘typical value’ means an estimate of the greenhouse gas emissions and greenhouse gas emissions savings for a particular biofuel, bioliquid or biomass fuel production pathway, which is representative of the Union consumption;
‘default value’ means a value derived from a typical value by the application of pre-determined factors and that may, in circumstances specified in this Directive, be used in place of an actual value.
Article 3
Binding overall Union target for 2030
If, on the basis of the assessment of the draft integrated national energy and climate plans submitted pursuant to Article 9 of Regulation (EU) 2018/1999, the Commission concludes that the national contributions of the Member States are insufficient for the collective achievement of the binding overall Union target, it shall follow the procedure laid down in Articles 9 and 31 of that Regulation.
The Commission shall support the high ambition of Member States through an enabling framework comprising the enhanced use of Union funds, including additional funds to facilitate a just transition of carbon intensive regions towards increased shares of renewable energy, in particular financial instruments, especially for the following purposes:
reducing the cost of capital for renewable energy projects;
developing projects and programmes for integrating renewable sources into the energy system, for increasing flexibility of the energy system, for maintaining grid stability and for managing grid congestions;
developing transmission and distribution grid infrastructure, intelligent networks, storage facilities and interconnections, with the objective of arriving at a 15 % electricity interconnection target by 2030, in order to increase the technically feasible and economically affordable level of renewable energy in the electricity system;
enhancing regional cooperation between Member States and between Member States and third countries, through joint projects, joint support schemes and the opening of support schemes for renewable electricity to producers located in other Member States.
Article 4
Support schemes for energy from renewable sources
To that end, with regard to direct price support schemes, support shall be granted in the form of a market premium, which could be, inter alia, sliding or fixed.
Member States may exempt small-scale installations and demonstration projects from this paragraph, without prejudice to the applicable Union law on the internal market for electricity.
Member States may exempt small-scale installations and demonstration projects from tendering procedures.
Member States may also consider establishing mechanisms to ensure the regional diversification in the deployment of renewable electricity, in particular to ensure cost-efficient system integration.
Member States may limit tendering procedures to specific technologies where opening support schemes to all producers of electricity from renewable sources would lead to a suboptimal result, in view of:
the long-term potential of a particular technology;
the need to achieve diversification;
grid integration costs;
network constraints and grid stability;
for biomass, the need to avoid distortions of raw materials markets.
Where support for electricity from renewable sources is granted by means of a tendering procedure, Member States shall, in order to ensure a high project realisation rate:
establish and publish non-discriminatory and transparent criteria to qualify for the tendering procedure and set clear dates and rules for delivery of the project;
publish information about previous tendering procedures, including project realisation rates.
By 31 December 2021 and every three years thereafter, the Commission shall report to the European Parliament and to the Council on the performance of support for electricity from renewable sources granted by means of tendering procedures in the Union, analysing in particular the ability of tendering procedures to:
achieve cost-reduction;
achieve technological improvement;
achieve high realisation rates;
provide non-discriminatory participation of small actors and, where applicable, local authorities;
limit environmental impact;
ensure local acceptability;
ensure security of supply and grid integration.
Article 5
Opening of support schemes for electricity from renewable sources
When opening participation in support schemes for electricity from renewable sources, Member States may provide that support for an indicative share of the newly-supported capacity, or of the budget allocated thereto, in each year is open to producers located in other Member States.
Such indicative shares may, in each year, amount to at least 5 % from 2023 to 2026 and at least 10 % from 2027 to 2030, or, where lower, to the level of interconnectivity of the Member State concerned in any given year.
In order to acquire further implementation experience, Member States may organise one or more pilot schemes where support is open to producers located in other Member States.
Article 6
Stability of financial support
Article 7
Calculation of the share of energy from renewable sources
The gross final consumption of energy from renewable sources in each Member State shall be calculated as the sum of:
gross final consumption of electricity from renewable sources;
gross final consumption of energy from renewable sources in the heating and cooling sector; and
final consumption of energy from renewable sources in the transport sector.
With regard to point (a), (b), or (c) of the first subparagraph, gas, electricity and hydrogen from renewable sources shall be considered only once for the purposes of calculating the share of gross final consumption of energy from renewable sources.
Subject to the second subparagraph of Article 29(1), biofuels, bioliquids and biomass fuels that do not fulfil the sustainability and greenhouse gas emissions saving criteria laid down in Article 29(2) to (7) and (10) shall not be taken into account.
In multi-fuel plants using renewable and non-renewable sources, only the part of electricity produced from renewable sources shall be taken into account. For the purposes of that calculation, the contribution of each energy source shall be calculated on the basis of its energy content.
The electricity generated by hydropower and wind power shall be accounted for in accordance with the normalisation rules set out in Annex II.
In multi-fuel plants using renewable and non-renewable sources, only the part of heating and cooling produced from renewable sources shall be taken into account. For the purposes of that calculation, the contribution of each energy source shall be calculated on the basis of its energy content.
Ambient and geothermal energy used for heating and cooling by means of heat pumps and district cooling systems shall be taken into account for the purposes of point (b) of the first subparagraph of paragraph 1, provided that the final energy output significantly exceeds the primary energy input required to drive the heat pumps. The quantity of heat or cold to be considered to be energy from renewable sources for the purposes of this Directive shall be calculated in accordance with the methodology set out in Annex VII and shall take into account energy use in all end-use sectors.
Thermal energy generated by passive energy systems, under which lower energy consumption is achieved passively through building design or from heat generated by energy from non-renewable sources, shall not be taken into account for the purposes of point (b) of the first subparagraph of paragraph 1.
By 31 December 2021, the Commission shall adopt delegated acts in accordance with Article 35 to supplement this Directive by establishing a methodology for calculating the quantity of renewable energy used for cooling and district cooling and to amend Annex VII.
That methodology shall include minimum seasonal performance factors for heat pumps operating in reverse mode.
For the purposes of point (c) of the first subparagraph of paragraph 1, the following requirements shall apply:
Final consumption of energy from renewable sources in the transport sector shall be calculated as the sum of all biofuels, biomass fuels and renewable liquid and gaseous transport fuels of non-biological origin consumed in the transport sector. However, renewable liquid and gaseous transport fuels of non-biological origin that are produced from renewable electricity shall be considered to be part of the calculation pursuant to point (a) of the first subparagraph of paragraph 1 only when calculating the quantity of electricity produced in a Member State from renewable sources.
For the calculation of final consumption of energy in the transport sector, the values regarding the energy content of transport fuels, as set out in Annex III, shall be used. For the determination of the energy content of transport fuels not included in Annex III, Member States shall use the relevant European Standards Organisation (ESO) standards in order to determine the calorific values of fuels. Where no ESO standard has been adopted for that purpose, Member States shall use the relevant International Organization for Standardisation (ISO) standards.
For the purposes of the first subparagraph of this paragraph, the sum referred to in the first subparagraph of paragraph 1 of this Article shall be adjusted in accordance with Articles 8, 10, 12 and 13.
In calculating a Member State's gross final consumption of energy for the purposes of measuring its compliance with the targets and indicative trajectory laid down in this Directive, the amount of energy consumed in aviation shall, as a proportion of that Member State's gross final consumption of energy, be considered to be no more than 6,18 %. For Cyprus and Malta the amount of energy consumed in aviation shall, as a proportion of those Member States' gross final consumption of energy, be considered to be no more than 4,12 %.
Member States shall ensure coherence of the statistical information used in calculating those sectoral and overall shares and of the statistical information reported to the Commission pursuant to that Regulation.
Article 8
Union renewable development platform and statistical transfers between Member States
Member States may agree on the statistical transfer of a specified amount of energy from renewable sources from one Member State to another Member State. The transferred quantity shall be:
deducted from the amount of energy from renewable sources that is taken into account in calculating the renewable energy share of the Member State making the transfer for the purposes of this Directive; and
added to the amount of energy from renewable sources that is taken into account in calculating the renewable energy share of the Member State accepting the transfer for the purposes of this Directive.
The Commission is empowered to adopt delegated acts in accordance with Article 35 to supplement this Directive by establishing the URDP and setting the conditions for the finalisation of transfers as referred to in paragraph 5 of this Article.
Article 9
Joint projects between Member States
The notification referred to in paragraph 2 shall:
describe the proposed installation or identify the refurbished installation;
specify the proportion or amount of electricity or heating or cooling produced from the installation which is to be regarded as counting towards the renewable energy share of the other Member State;
identify the Member State in whose favour the notification is being made; and
specify the period, in whole calendar years, during which the electricity or heating or cooling produced by the installation from renewable sources is to be regarded as counting towards the renewable energy share of the other Member State.
Article 10
Effects of joint projects between Member States
Within three months of the end of each year falling within the period referred to in point (d) of Article 9(3), the Member State that made the notification under Article 9 shall issue a letter of notification stating:
the total amount of electricity or heating or cooling produced from renewable sources during that year by the installation which was the subject of the notification under Article 9; and
the amount of electricity or heating or cooling produced from renewable sources during that year by that installation which is to count towards the renewable energy share of another Member State in accordance with the terms of the notification.
For the purposes of this Directive, the amount of electricity or heating or cooling from renewable sources notified in accordance with point (b) of paragraph 1 shall be:
deducted from the amount of electricity or heating or cooling from renewable sources that is taken into account in calculating the renewable energy share of the Member State issuing the letter of notification pursuant to paragraph 1; and
added to the amount of electricity or heating or cooling from renewable sources that is taken into account in calculating the renewable energy share of the Member State receiving the letter of notification pursuant to paragraph 2.
Article 11
Joint projects between Member States and third countries
Electricity from renewable sources produced in a third country shall be taken into account for the purposes of calculating the renewable energy shares of the Member States only where the following conditions are met:
the electricity is consumed in the Union, which is deemed to be met where:
an equivalent amount of electricity to the electricity accounted for has been firmly nominated to the allocated interconnection capacity by all responsible transmission system operators in the country of origin, the country of destination and, if relevant, each third country of transit;
an equivalent amount of electricity to the electricity accounted for has been firmly registered in the schedule of balance by the responsible transmission system operator on the Union side of an interconnector; and
the nominated capacity and the production of electricity from renewable sources by the installation referred to in point (b) refer to the same period of time;
the electricity is produced by an installation that became operational after 25 June 2009 or by the increased capacity of an installation that was refurbished after that date, under a joint project as referred to in paragraph 1;
the amount of electricity produced and exported has not received support from a support scheme of a third country other than investment aid granted to the installation; and
the electricity has been produced in accordance with international law, in a third country that is a signatory to the Council of Europe Convention for the Protection of Human Rights and Fundamental Freedoms, or other international conventions or treaties on human rights.
For the purposes of paragraph 4, Member States may apply to the Commission for account to be taken of electricity from renewable sources produced and consumed in a third country, in the context of the construction of an interconnector with a very long lead-time between a Member State and a third country where the following conditions are met:
construction of the interconnector started by 31 December 2026;
it is not possible for the interconnector to become operational by 31 December 2030;
it is possible for the interconnector to become operational by 31 December 2032;
after it becomes operational, the interconnector will be used for the export to the Union, in accordance with paragraph 2, of electricity from renewable sources;
the application relates to a joint project that fulfils the criteria set out in points (b) and (c) of paragraph 2 and that will use the interconnector after it becomes operational, and to a quantity of electricity that is no greater than the quantity that will be exported to the Union after the interconnector becomes operational.
The notification referred to in paragraph 4 shall:
describe the proposed installation or identify the refurbished installation;
specify the proportion or amount of electricity produced from the installation which is to be regarded as counting towards the renewable energy share of a Member State as well as, subject to confidentiality requirements, the corresponding financial arrangements;
specify the period, in whole calendar years, during which the electricity is to be regarded as counting towards the renewable energy share of the Member State; and
include a written acknowledgement of points (b) and (c) by the third country in whose territory the installation is to become operational and an indication of the proportion or amount of electricity produced by the installation which will be used domestically by that third country.
Article 12
Effects of joint projects between Member States and third countries
Within 12 months of the end of each year falling within the period specified under point (c) of Article 11(5), the notifying Member State shall issue a letter of notification stating:
the total amount of electricity produced from renewable sources during that year by the installation which was the subject of the notification under Article 11;
the amount of electricity produced from renewable sources during that year by that installation which is to count towards its renewable energy share in accordance with the terms of the notification under Article 11; and
evidence of compliance with the conditions laid down in Article 11(2).
Article 13
Joint support schemes
Without prejudice to the obligations of Member States under Article 5, two or more Member States may decide, on a voluntary basis, to join or partly coordinate their national support schemes. In such cases, a certain amount of energy from renewable sources produced in the territory of one participating Member State may count towards the renewable energy share of another participating Member State, provided that the Member States concerned:
make a statistical transfer of specified amounts of energy from renewable sources from one Member State to another Member State in accordance with Article 8; or
set up a distribution rule agreed by participating Member States that allocates amounts of energy from renewable sources between the participating Member States.
A distribution rule as referred to in point (b) of the first subparagraph shall be notified to the Commission not later than three months after the end of the first year in which it takes effect.
Article 14
Capacity increases
For the purposes of Article 9(2) and point (b) of Article 11(2), units of energy from renewable sources imputable to an increase in the capacity of an installation shall be treated as if they were produced by a separate installation becoming operational at the moment at which the increase of capacity occurred.
Article 15
Administrative procedures, regulations and codes
Member States shall, in particular, take the appropriate steps to ensure that:
administrative procedures are streamlined and expedited at the appropriate administrative level and predictable timeframes are established for the procedures referred to in the first subparagraph;
rules concerning authorisation, certification and licensing are objective, transparent and proportionate, do not discriminate between applicants and take fully into account the particularities of individual renewable energy technologies;
administrative charges paid by consumers, planners, architects, builders and equipment and system installers and suppliers are transparent and cost-related; and
simplified and less burdensome authorisation procedures, including a simple-notification procedure, are established for decentralised devices, and for producing and storing energy from renewable sources.
In establishing such measures or in their support schemes, Member States may take into account, where applicable, national measures relating to substantial increases in renewables self-consumption, in local energy storage and in energy efficiency, relating to cogeneration and relating to passive, low-energy or zero-energy buildings.
Member States shall, in their building regulations and codes or by other means with equivalent effect, require the use of minimum levels of energy from renewable sources in new buildings and in existing buildings that are subject to major renovation in so far as technically, functionally and economically feasible, and reflecting the results of the cost-optimal calculation carried out pursuant to Article 5(2) of Directive 2010/31/EU, and in so far as this does not negatively affect indoor air quality. Member States shall permit those minimum levels to be fulfilled, inter alia, through efficient district heating and cooling using a significant share of renewable energy and waste heat and cold.
The requirements laid down in the first subparagraph shall apply to the armed forces only to the extent that its application does not cause any conflict with the nature and primary aim of the activities of the armed forces and with the exception of material used exclusively for military purposes.
Member States shall describe policies and measures facilitating the uptake of renewables power purchase agreements in their integrated national energy and climate plans and progress reports pursuant to Regulation (EU) 2018/1999.
Article 16
Organisation and duration of the permit-granting process
Member States shall ensure that applicants have easy access to simple procedures for the settlement of disputes concerning the permit-granting process and the issuance of permits to build and operate renewable energy plants, including, where applicable, alternative dispute resolution mechanisms.
Where duly justified on the grounds of extraordinary circumstances, such as on grounds of overriding safety reasons where the repowering project impacts substantially on the grid or the original capacity, size or performance of the installation, that one-year period may be extended by up to one year.
Where the relevant authority decides that a notification is sufficient, it shall automatically grant the permit. Where that authority decides that the notification is not sufficient, it shall be necessary to apply for a new permit and the time-limits referred to in paragraph 6 shall apply.
Article 17
Simple-notification procedure for grid connections
The distribution system operator may, within a limited period following the notification, reject the requested grid connection or propose an alternative grid connection point on justified grounds of safety concerns or technical incompatibility of the system components. In the case of a positive decision by the distribution system operator, or in the absence of a decision by the distribution system operator within one month following the notification, the installation or aggregated production unit may be connected.
Article 18
Information and training
Article 19
Guarantees of origin for energy from renewable sources
Member States shall ensure that the same unit of energy from renewable sources is taken into account only once.
Member States shall ensure that when a producer receives financial support from a support scheme, the market value of the guarantee of origin for the same production is taken into account appropriately in the relevant support scheme.
It shall be presumed that the market value of the guarantee of origin has been taken into account appropriately in any of the following cases:
where the financial support is granted by way of a tendering procedure or a tradable green certificate system;
where the market value of the guarantees of origin is administratively taken into account in the level of financial support; or
where the guarantees of origin are not issued directly to the producer but to a supplier or consumer who buys the energy from renewable sources either in a competitive setting or in a long-term renewables power purchase agreement.
In order to take into account the market value of the guarantee of origin, Member States may, inter alia, decide to issue a guarantee of origin to the producer and immediately cancel it.
The guarantee of origin shall have no function in terms of a Member State's compliance with Article 3. Transfers of guarantees of origin, separately or together with the physical transfer of energy, shall have no effect on the decision of Member States to use statistical transfers, joint projects or joint support schemes for compliance with Article 3 or on the calculation of the gross final consumption of energy from renewable sources in accordance with Article 7.
A guarantee of origin shall specify at least:
the energy source from which the energy was produced and the start and end dates of production;
whether it relates to:
electricity;
gas, including hydrogen; or
heating or cooling;
the identity, location, type and capacity of the installation where the energy was produced;
whether the installation has benefited from investment support and whether the unit of energy has benefited in any other way from a national support scheme, and the type of support scheme;
the date on which the installation became operational; and
the date and country of issue and a unique identification number.
Simplified information may be specified on guarantees of origin from installations of less than 50 kW.
Where an electricity supplier is required to demonstrate the share or quantity of energy from renewable sources in its energy mix for the purposes of point (a) of Article 3(9) of Directive 2009/72/EC, it shall do so by using guarantees of origin except:
as regards the share of its energy mix corresponding to non-tracked commercial offers, if any, for which the supplier may use the residual mix; or
where a Member State decides not to issue guarantees of origin to a producer that receives financial support from a support scheme.
Where Member States have arranged to have guarantees of origin for other types of energy, suppliers shall use for disclosure the same type of guarantees of origin as the energy supplied. Likewise, guarantees of origin created pursuant to Article 14(10) of Directive 2012/27/EU may be used to substantiate any requirement to demonstrate the quantity of electricity produced from high-efficiency cogeneration. For the purposes of paragraph 2 of this Article, where electricity is generated from high-efficiency cogeneration using renewable sources, only one guarantee of origin specifying both characteristics may be issued.
Article 20
Access to and operation of the grids
Article 21
Renewables self-consumers
Member States shall ensure that renewables self-consumers, individually or through aggregators, are entitled:
to generate renewable energy, including for their own consumption, store and sell their excess production of renewable electricity, including through renewables power purchase agreements, electricity suppliers and peer-to-peer trading arrangements, without being subject:
in relation to the electricity that they consume from or feed into the grid, to discriminatory or disproportionate procedures and charges, and to network charges that are not cost-reflective;
in relation to their self-generated electricity from renewable sources remaining within their premises, to discriminatory or disproportionate procedures, and to any charges or fees;
to install and operate electricity storage systems combined with installations generating renewable electricity for self-consumption without liability for any double charge, including network charges, for stored electricity remaining within their premises;
to maintain their rights and obligations as final consumers;
to receive remuneration, including, where applicable, through support schemes, for the self-generated renewable electricity that they feed into the grid, which reflects the market value of that electricity and which may take into account its long-term value to the grid, the environment and society.
Member States may apply non-discriminatory and proportionate charges and fees to renewables self-consumers, in relation to their self-generated renewable electricity remaining within their premises in one or more of the following cases:
if the self-generated renewable electricity is effectively supported via support schemes, only to the extent that the economic viability of the project and the incentive effect of such support are not undermined;
from 1 December 2026, if the overall share of self-consumption installations exceeds 8 % of the total installed electricity capacity of a Member State, and if it is demonstrated, by means of a cost-benefit analysis performed by the national regulatory authority of that Member State, which is conducted by way of an open, transparent and participatory process, that the provision laid down in point (a)(ii) of paragraph 2 either results in a significant disproportionate burden on the long-term financial sustainability of the electric system, or creates an incentive exceeding what is objectively needed to achieve cost-effective deployment of renewable energy, and that such burden or incentive cannot be minimised by taking other reasonable actions; or
if the self-generated renewable electricity is produced in installations with a total installed electrical capacity of more than 30 kW.
Member States shall put in place an enabling framework to promote and facilitate the development of renewables self-consumption based on an assessment of the existing unjustified barriers to, and of the potential of, renewables self-consumption in their territories and energy networks. That enabling framework shall, inter alia:
address accessibility of renewables self-consumption to all final customers, including those in low-income or vulnerable households;
address unjustified barriers to the financing of projects in the market and measures to facilitate access to finance;
address other unjustified regulatory barriers to renewables self-consumption, including for tenants;
address incentives to building owners to create opportunities for renewables self-consumption, including for tenants;
grant renewables self-consumers, for self-generated renewable electricity that they feed into the grid, non-discriminatory access to relevant existing support schemes as well as to all electricity market segments;
ensure that renewables self-consumers contribute in an adequate and balanced way to the overall cost sharing of the system when electricity is fed into the grid.
Member States shall include a summary of the policies and measures under the enabling framework and an assessment of their implementation respectively in their integrated national energy and climate plans and progress reports pursuant to Regulation (EU) 2018/1999.
Article 22
Renewable energy communities
Member States shall ensure that renewable energy communities are entitled to:
produce, consume, store and sell renewable energy, including through renewables power purchase agreements;
share, within the renewable energy community, renewable energy that is produced by the production units owned by that renewable energy community, subject to the other requirements laid down in this Article and to maintaining the rights and obligations of the renewable energy community members as customers;
access all suitable energy markets both directly or through aggregation in a non-discriminatory manner.
Member States shall provide an enabling framework to promote and facilitate the development of renewable energy communities. That framework shall ensure, inter alia, that:
unjustified regulatory and administrative barriers to renewable energy communities are removed;
renewable energy communities that supply energy or provide aggregation or other commercial energy services are subject to the provisions relevant for such activities;
the relevant distribution system operator cooperates with renewable energy communities to facilitate energy transfers within renewable energy communities;
renewable energy communities are subject to fair, proportionate and transparent procedures, including registration and licensing procedures, and cost-reflective network charges, as well as relevant charges, levies and taxes, ensuring that they contribute, in an adequate, fair and balanced way, to the overall cost sharing of the system in line with a transparent cost-benefit analysis of distributed energy sources developed by the national competent authorities;
renewable energy communities are not subject to discriminatory treatment with regard to their activities, rights and obligations as final customers, producers, suppliers, distribution system operators, or as other market participants;
the participation in the renewable energy communities is accessible to all consumers, including those in low-income or vulnerable households;
tools to facilitate access to finance and information are available;
regulatory and capacity-building support is provided to public authorities in enabling and setting up renewable energy communities, and in helping authorities to participate directly;
rules to secure the equal and non-discriminatory treatment of consumers that participate in the renewable energy community are in place.
Article 23
Mainstreaming renewable energy in heating and cooling
For the purposes of paragraph 1, when calculating its share of renewable energy in the heating and cooling sector and its average annual increase in accordance with that paragraph, each Member State:
may count waste heat and cold, subject to a limit of 40 % of the average annual increase;
where its share of renewable energy in the heating and cooling sector is above 60 %, may count any such share as fulfilling the average annual increase; and
where its share of renewable energy in the heating and cooling sector is above 50 % and up to 60 %, may count any such share as fulfilling half of the average annual increase.
When deciding which measures to adopt for the purposes of deploying energy from renewable sources in the heating and cooling sector, Member States may take into account cost-effectiveness reflecting structural barriers arising from the high share of natural gas or cooling, or from a dispersed settlement structure with low population density.
Where those measures would result in a lower average annual increase than that referred to in paragraph 1 of this Article, Member States shall make it public, for instance by the means of their integrated national energy and climate progress reports pursuant to Article 20 of Regulation (EU) 2018/1999, and provide the Commission with reasons, including of choice of measures as referred to the second subparagraph of this paragraph.
Member States may implement the average annual increase referred to in paragraph 1 by means, inter alia, of one or more of the following options:
physical incorporation of renewable energy or waste heat and cold in the energy and energy fuel supplied for heating and cooling;
direct mitigation measures such as the installation of highly efficient renewable heating and cooling systems in buildings, or the use of renewable energy or waste heat and cold in industrial heating and cooling processes;
indirect mitigation measures covered by tradable certificates proving compliance with the obligation laid down in paragraph 1 through support to indirect mitigation measures, carried out by another economic operator such as an independent renewable technology installer or energy service company providing renewable installation services;
other policy measures, with an equivalent effect, to reach the average annual increase referred to in paragraph 1, including fiscal measures or other financial incentives.
When adopting and implementing the measures referred to in the first subparagraph, Member States shall aim to ensure the accessibility of measures to all consumers, in particular those in low-income or vulnerable households, who would not otherwise possess sufficient up-front capital to benefit.
Where entities are designated under paragraph 3, Member States shall ensure that the contribution by those designated entities is measurable and verifiable and that the designated entities report annually on:
the total amount of energy supplied for heating and cooling;
the total amount of renewable energy supplied for heating and cooling;
the amount of waste heat and cold supplied for heating and cooling;
the share of renewable energy and waste heat and cold in the total amount of energy supplied for heating and cooling; and
the type of renewable energy source.
Article 24
District heating and cooling
Where the termination of a contract is linked to physical disconnection, such a termination may be made conditional on compensation for the costs directly incurred as a result of the physical disconnection and for the undepreciated portion of assets needed to provide heat and cold to that customer.
Member States shall lay down the necessary measures to ensure that district heating and cooling systems contribute to the increase referred to in Article 23(1) of this Directive by implementing at least one of the two following options:
Endeavour to increase the share of energy from renewable sources and from waste heat and cold in district heating and cooling by at least one percentage point as an annual average calculated for the period 2021 to 2025 and for the period 2026 to 2030, starting from the share of energy from renewable sources and from waste heat and cold in district heating and cooling in 2020, expressed in terms of share of final energy consumption in district heating and cooling, by implementing measures that can be expected to trigger that average annual increase in years with normal climatic conditions.
Member States with a share of energy from renewable sources and from waste heat and cold in district heating and cooling above 60 % may count any such share as fulfilling the average annual increase referred to in the first subparagraph of this point.
Member States shall lay down the necessary measures to implement the average annual increase referred to in the first subparagraph of this point in their integrated national energy and climate plans pursuant to Annex I to Regulation (EU) 2018/1999.
Ensure that operators of district heating or cooling systems are obliged to connect suppliers of energy from renewable sources and from waste heat and cold or are obliged to offer to connect and purchase heat or cold from renewable sources and from waste heat and cold from third-party suppliers based on non-discriminatory criteria set by the competent authority of the Member State concerned, where they need to do one or more of the following:
meet demand from new customers;
replace existing heat or cold generation capacity;
expand existing heat or cold generation capacity.
Where a Member State exercises the option referred to in point (b) of paragraph 4, an operator of a district heating or cooling system may refuse to connect and to purchase heat or cold from a third-party supplier where:
the system lacks the necessary capacity due to other supplies of waste heat and cold, of heat or cold from renewable sources or of heat or cold produced by high-efficiency cogeneration;
the heat or cold from the third-party supplier does not meet the technical parameters necessary to connect and ensure the reliable and safe operation of the district heating and cooling system; or
the operator can demonstrate that providing access would lead to an excessive heat or cold cost increase for final customers compared to the cost of using the main local heat or cold supply with which the renewable source or waste heat and cold would compete.
Member States shall ensure that, when an operator of a district heating or cooling system refuses to connect a supplier of heating or cooling pursuant to the first subparagraph, information on the reasons for the refusal, as well as the conditions to be met and measures to be taken in the system in order to enable the connection, is provided by that operator to the competent authority in accordance with paragraph 9.
Where a Member State exercises the option referred to in point (b) of paragraph 4, it may exempt operators of the following district heating and cooling systems from the application of that point:
efficient district heating and cooling;
efficient district heating and cooling that exploits high-efficiency cogeneration;
district heating and cooling that, on the basis of a plan approved by the competent authority, is efficient district heating and cooling by 31 December 2025;
district heating and cooling with a total rated thermal input below 20 MW.
A Member State shall not be required to apply paragraphs 2 to 9 of this Article where:
its share of district heating and cooling is less than or equal to 2 % of the overall consumption of energy in heating and cooling on 24 December 2018;
its share of district heating and cooling is increased above 2 % by developing new efficient district heating and cooling based on its integrated national energy and climate plan pursuant to Annex I to Regulation (EU) 2018/1999 or the assessment referred to in Article 15(7) of this Directive; or
its share of systems referred to in paragraph 6 of this Article constitutes over 90 % of total sales of its district heating and cooling.
Article 25
Mainstreaming renewable energy in the transport sector
Member States may exempt, or distinguish between, different fuel suppliers and different energy carriers when setting the obligation on the fuel suppliers, ensuring that the varying degrees of maturity and the cost of different technologies are taken into account.
For the calculation of the minimum share referred to in the first subparagraph, Member States:
shall take into account renewable liquid and gaseous transport fuels of non-biological origin also when they are used as intermediate products for the production of conventional fuels; and
may take into account recycled carbon fuels.
Within the minimum share referred to in the first subparagraph, the contribution of advanced biofuels and biogas produced from the feedstock listed in Part A of Annex IX as a share of final consumption of energy in the transport sector shall be at least 0,2 % in 2022, at least 1 % in 2025 and at least 3,5 % in 2030.
Member States may exempt fuel suppliers supplying fuel in the form of electricity or renewable liquid and gaseous transport fuels of non-biological origin from the requirement to comply with the minimum share of advanced biofuels and biogas produced from the feedstock listed in Part A of Annex IX with respect to those fuels.
When setting the obligation referred to in the first and fourth subparagraphs to ensure the achievement of the share set out therein, Member States may do so, inter alia, by means of measures targeting volumes, energy content or greenhouse gas emissions, provided that it is demonstrated that the minimum shares referred to in the first and fourth subparagraphs are achieved.
By 1 January 2021, the Commission shall adopt a delegated act in accordance with Article 35 to supplement this Directive by establishing appropriate minimum thresholds for greenhouse gas emissions savings of recycled carbon fuels through a life-cycle assessment that takes into account the specificities of each fuel.
Article 26
Specific rules for biofuels, bioliquids and biomass fuels produced from food and feed crops
Where that share is below 1 % in a Member State, it may be increased to a maximum of 2 % of the final consumption of energy in the road and rail transport sectors.
Member States may set a lower limit and may distinguish, for the purposes of Article 29(1), between different biofuels, bioliquids and biomass fuels produced from food and feed crops, taking into account best available evidence on indirect land-use change impact. Member States may, for example, set a lower limit for the share of biofuels, bioliquids and biomass fuels produced from oil crops.
Where the share of biofuels and bioliquids, as well as of biomass fuels consumed in transport, produced from food and feed crops in a Member State is limited to a share lower than 7 % or a Member State decides to limit the share further, that Member State may reduce the minimum share referred to in the first subparagraph of Article 25(1) accordingly, by a maximum of 7 percentage points.
From 31 December 2023 until 31 December 2030 at the latest, that limit shall gradually decrease to 0 %.
By 1 February 2019, the Commission shall submit to the European Parliament and to the Council a report on the status of worldwide production expansion of the relevant food and feed crops.
By 1 February 2019, the Commission shall adopt a delegated act in accordance with Article 35 to supplement this Directive by setting out the criteria for certification of low indirect land-use change-risk biofuels, bioliquids and biomass fuels and for determining the high indirect land-use change-risk feedstock for which a significant expansion of the production area into land with high-carbon stock is observed. The report and the accompanying delegated act shall be based on the best available scientific data.
By 1 September 2023, the Commission shall review the criteria laid down in the delegated act referred to in the fourth subparagraph based on the best available scientific data and shall adopt delegated acts in accordance with Article 35 to amend such criteria, where appropriate, and to include a trajectory to gradually decrease the contribution to the Union target set in Article 3(1) and to the minimum share referred to in the first subparagraph of Article 25(1), of high indirect land-use change-risk biofuels, bioliquids and biomass fuels produced from feedstock for which a significant expansion of the production into land with high-carbon stock is observed.
Article 27
Calculation rules with regard to the minimum shares of renewable energy in the transport sector
For the calculation of the minimum shares referred to in the first and fourth subparagraphs of Article 25(1), the following provisions shall apply:
for the calculation of the denominator, that is the energy content of road- and rail- transport fuels supplied for consumption or use on the market, petrol, diesel, natural gas, biofuels, biogas, renewable liquid and gaseous transport fuels of non-biological origin, recycled carbon fuels and electricity supplied to the road and rail transport sectors, shall be taken into account;
for the calculation of the numerator, that is the amount of energy from renewable sources consumed in the transport sector for the purposes of the first subparagraph of Article 25(1), the energy content of all types of energy from renewable sources supplied to all transport sectors, including renewable electricity supplied to the road and rail transport sectors, shall be taken into account. Member States may also take into account recycled carbon fuels.
For the calculation of the numerator, the share of biofuels and biogas produced from the feedstock listed in Part B of Annex IX shall, except for in Cyprus and Malta, be limited to 1,7 % of the energy content of transport fuels supplied for consumption or use on the market. Member States may, where justified, modify that limit, taking into account the availability of feedstock. Any such modification shall be subject to approval by the Commission;
for the calculation of both numerator and denominator, the values regarding the energy content of transport fuels set out in Annex III shall be used. For the determination of the energy content of transport fuels not included in Annex III, the Member States shall use the relevant ESO standards for the determination of the calorific values of fuels. Where no ESO standard has been adopted for that purpose, the relevant ISO standards shall be used. The Commission is empowered to adopt delegated acts in accordance with Article 35 to amend this Directive by adapting the energy content of transport fuels, as set out in Annex III, in accordance with scientific and technical progress.
For the purposes of demonstrating compliance with the minimum shares referred to in Article 25(1):
the share of biofuels and biogas for transport produced from the feedstock listed in Annex IX may be considered to be twice its energy content;
the share of renewable electricity shall be considered to be four times its energy content when supplied to road vehicles and may be considered to be 1,5 times its energy content when supplied to rail transport;
with the exception of fuels produced from food and feed crops, the share of fuels supplied in the aviation and maritime sectors shall be considered to be 1,2 times their energy content.
By way of derogation from the first subparagraph of this paragraph, to determine the share of electricity for the purposes of paragraph 1 of this Article, in the case of electricity obtained from a direct connection to an installation generating renewable electricity and supplied to road vehicles, that electricity shall be fully counted as renewable.
In order to ensure that the expected increase in demand for electricity in the transport sector beyond the current baseline is met with additional renewable energy generation capacity, the Commission shall develop a framework on additionality in the transport sector and shall develop different options with a view to determining the baseline of Member States and measuring additionality.
For the purposes of this paragraph, where electricity is used for the production of renewable liquid and gaseous transport fuels of non-biological origin, either directly or for the production of intermediate products, the average share of electricity from renewable sources in the country of production, as measured two years before the year in question, shall be used to determine the share of renewable energy.
However, electricity obtained from direct connection to an installation generating renewable electricity may be fully counted as renewable electricity where it is used for the production of renewable liquid and gaseous transport fuels of non-biological origin, provided that the installation:
comes into operation after, or at the same time as, the installation producing the renewable liquid and gaseous transport fuels of non-biological origin; and
is not connected to the grid or is connected to the grid but evidence can be provided that the electricity concerned has been supplied without taking electricity from the grid.
Electricity that has been taken from the grid may be counted as fully renewable provided that it is produced exclusively from renewable sources and the renewable properties and other appropriate criteria have been demonstrated, ensuring that the renewable properties of that electricity are claimed only once and only in one end-use sector.
By 31 December 2021, the Commission shall adopt a delegated act in accordance with Article 35 to supplement this Directive by establishing a Union methodology setting out detailed rules by which economic operators are to comply with the requirements laid down in the fifth and sixth subparagraphs of this paragraph.
Article 28
Other provisions on renewable energy in the transport sector
Fuel suppliers shall enter the information necessary to verify compliance with the requirements laid down in the first and fourth subparagraphs of Article 25(1) into the relevant database.
The Commission is empowered to adopt delegated acts in accordance with Article 35 to amend the list of feedstock set out in Parts A and B of Annex IX by adding, but not removing, feedstock. Feedstock that can be processed only with advanced technologies shall be added to Part A of Annex IX. Feedstock that can be processed into biofuels, or biogas for transport, with mature technologies shall be added to Part B of Annex IX.
Such delegated acts shall be based on an analysis of the potential of the raw material as feedstock for the production of biofuels and biogas for transport, taking into account all of the following:
the principles of the circular economy and of the waste hierarchy established in Directive 2008/98/EC;
the Union sustainability criteria laid down in Article 29(2) to (7);
the need to avoid significant distortive effects on markets for (by-)products, wastes or residues;
the potential for delivering substantial greenhouse gas emissions savings compared to fossil fuels based on a life-cycle assessment of emissions;
the need to avoid negative impacts on the environment and biodiversity;
the need to avoid creating an additional demand for land.
The Commission shall, if appropriate, submit a proposal to amend the obligation relating to advanced biofuels and biogas produced from feedstock listed in Part A of Annex IX laid down in the fourth subparagraph of Article 25(1).
Article 29
Sustainability and greenhouse gas emissions saving criteria for biofuels, bioliquids and biomass fuels
Energy from biofuels, bioliquids and biomass fuels shall be taken into account for the purposes referred to in points (a), (b) and (c) of this subparagraph only if they fulfil the sustainability and the greenhouse gas emissions saving criteria laid down in paragraphs 2 to 7 and 10:
contributing towards the Union target set in Article 3(1) and the renewable energy shares of Member States;
measuring compliance with renewable energy obligations, including the obligation laid down in Article 25;
eligibility for financial support for the consumption of biofuels, bioliquids and biomass fuels.
However, biofuels, bioliquids and biomass fuels produced from waste and residues, other than agricultural, aquaculture, fisheries and forestry residues, are required to fulfil only the greenhouse gas emissions saving criteria laid down in paragraph 10 in order to be taken into account for the purposes referred to in points (a), (b) and (c) of the first subparagraph. This subparagraph shall also apply to waste and residues that are first processed into a product before being further processed into biofuels, bioliquids and biomass fuels.
Electricity, heating and cooling produced from municipal solid waste shall not be subject to the greenhouse gas emissions saving criteria laid down in paragraph 10.
Biomass fuels shall fulfil the sustainability and greenhouse gas emissions saving criteria laid down in paragraphs 2 to 7 and 10 if used in installations producing electricity, heating and cooling or fuels with a total rated thermal input equal to or exceeding 20 MW in the case of solid biomass fuels, and with a total rated thermal input equal to or exceeding 2 MW in the case of gaseous biomass fuels. Member States may apply the sustainability and greenhouse gas emissions saving criteria to installations with lower total rated thermal input.
The sustainability and the greenhouse gas emissions saving criteria laid down in paragraphs 2 to 7 and 10 shall apply irrespective of the geographical origin of the biomass.
Biofuels, bioliquids and biomass fuels produced from agricultural biomass taken into account for the purposes referred to in points (a), (b) and (c) of the first subparagraph of paragraph 1 shall not be made from raw material obtained from land with a high biodiversity value, namely land that had one of the following statuses in or after January 2008, whether or not the land continues to have that status:
primary forest and other wooded land, namely forest and other wooded land of native species, where there is no clearly visible indication of human activity and the ecological processes are not significantly disturbed;
highly biodiverse forest and other wooded land which is species-rich and not degraded, or has been identified as being highly biodiverse by the relevant competent authority, unless evidence is provided that the production of that raw material did not interfere with those nature protection purposes;
areas designated:
by law or by the relevant competent authority for nature protection purposes; or
for the protection of rare, threatened or endangered ecosystems or species recognised by international agreements or included in lists drawn up by intergovernmental organisations or the International Union for the Conservation of Nature, subject to their recognition in accordance with the first subparagraph of Article 30(4),
unless evidence is provided that the production of that raw material did not interfere with those nature protection purposes;
highly biodiverse grassland spanning more than one hectare that is:
natural, namely grassland that would remain grassland in the absence of human intervention and that maintains the natural species composition and ecological characteristics and processes; or
non-natural, namely grassland that would cease to be grassland in the absence of human intervention and that is species-rich and not degraded and has been identified as being highly biodiverse by the relevant competent authority, unless evidence is provided that the harvesting of the raw material is necessary to preserve its status as highly biodiverse grassland.
The Commission may adopt implementing acts further specifying the criteria by which to determine which grassland are to be covered by point (d) of the first subparagraph of this paragraph. Those implementing acts shall be adopted in accordance with the examination procedure referred to in Article 34(3).
Biofuels, bioliquids and biomass fuels produced from agricultural biomass taken into account for the purposes referred to in points (a), (b) and (c) of the first subparagraph of paragraph 1 shall not be made from raw material obtained from land with high-carbon stock, namely land that had one of the following statuses in January 2008 and no longer has that status:
wetlands, namely land that is covered with or saturated by water permanently or for a significant part of the year;
continuously forested areas, namely land spanning more than one hectare with trees higher than five metres and a canopy cover of more than 30 %, or trees able to reach those thresholds in situ;
land spanning more than one hectare with trees higher than five metres and a canopy cover of between 10 % and 30 %, or trees able to reach those thresholds in situ, unless evidence is provided that the carbon stock of the area before and after conversion is such that, when the methodology laid down in Part C of Annex V is applied, the conditions laid down in paragraph 10 of this Article would be fulfilled.
This paragraph shall not apply if, at the time the raw material was obtained, the land had the same status as it had in January 2008.
Biofuels, bioliquids and biomass fuels produced from forest biomass taken into account for the purposes referred to in points (a), (b) and (c) of the first subparagraph of paragraph 1 shall meet the following criteria to minimise the risk of using forest biomass derived from unsustainable production:
the country in which forest biomass was harvested has national or sub-national laws applicable in the area of harvest as well as monitoring and enforcement systems in place ensuring:
the legality of harvesting operations;
forest regeneration of harvested areas;
that areas designated by international or national law or by the relevant competent authority for nature protection purposes, including in wetlands and peatlands, are protected;
that harvesting is carried out considering maintenance of soil quality and biodiversity with the aim of minimising negative impacts; and
that harvesting maintains or improves the long-term production capacity of the forest;
when evidence referred to in point (a) of this paragraph is not available, the biofuels, bioliquids and biomass fuels produced from forest biomass shall be taken into account for the purposes referred to in points (a), (b) and (c) of the first subparagraph of paragraph 1 if management systems are in place at forest sourcing area level ensuring:
the legality of harvesting operations;
forest regeneration of harvested areas;
that areas designated by international or national law or by the relevant competent authority for nature protection purposes, including in wetlands and peatlands, are protected unless evidence is provided that the harvesting of that raw material does not interfere with those nature protection purposes;
that harvesting is carried out considering the maintenance of soil quality and biodiversity with the aim of minimising negative impacts; and
that harvesting maintains or improves the long-term production capacity of the forest.
Biofuels, bioliquids and biomass fuels produced from forest biomass taken into account for the purposes referred to in points (a), (b) and (c) of the first subparagraph of paragraph 1 shall meet the following land-use, land-use change and forestry (LULUCF) criteria:
the country or regional economic integration organisation of origin of the forest biomass is a Party to the Paris Agreement and:
it has submitted a nationally determined contribution (NDC) to the United Nations Framework Convention on Climate Change (UNFCCC), covering emissions and removals from agriculture, forestry and land use which ensures that changes in carbon stock associated with biomass harvest are accounted towards the country’s commitment to reduce or limit greenhouse gas emissions as specified in the NDC; or
it has national or sub-national laws in place, in accordance with Article 5 of the Paris Agreement, applicable in the area of harvest, to conserve and enhance carbon stocks and sinks, and provides evidence that reported LULUCF-sector emissions do not exceed removals;
where evidence referred to in point (a) of this paragraph is not available, the biofuels, bioliquids and biomass fuels produced from forest biomass shall be taken into account for the purposes referred to in points (a), (b) and (c) of the first subparagraph of paragraph 1 if management systems are in place at forest sourcing area level to ensure that carbon stocks and sinks levels in the forest are maintained, or strengthened over the long term.
The Commission shall, if appropriate, submit a legislative proposal to amend the criteria laid down in paragraphs 6 and 7 for the period after 2030.
The greenhouse gas emission savings from the use of biofuels, bioliquids and biomass fuels taken into account for the purposes referred to in paragraph 1 shall be:
at least 50 % for biofuels, biogas consumed in the transport sector, and bioliquids produced in installations in operation on or before 5 October 2015;
at least 60 % for biofuels, biogas consumed in the transport sector, and bioliquids produced in installations starting operation from 6 October 2015 until 31 December 2020;
at least 65 % for biofuels, biogas consumed in the transport sector, and bioliquids produced in installations starting operation from 1 January 2021;
at least 70 % for electricity, heating and cooling production from biomass fuels used in installations starting operation from 1 January 2021 until 31 December 2025, and 80 % for installations starting operation from 1 January 2026.
An installation shall be considered to be in operation once the physical production of biofuels, biogas consumed in the transport sector and bioliquids, and the physical production of heating and cooling and electricity from biomass fuels has started.
The greenhouse gas emission savings from the use of biofuels, biogas consumed in the transport sector, bioliquids and biomass fuels used in installations producing heating, cooling and electricity shall be calculated in accordance with Article 31(1).
Electricity from biomass fuels shall be taken into account for the purposes referred to in points (a), (b) and (c) of the first subparagraph of paragraph 1 only if it meets one or more of the following requirements:
it is produced in installations with a total rated thermal input below 50 MW;
for installations with a total rated thermal input from 50 to 100 MW, it is produced applying high-efficiency cogeneration technology, or, for electricity-only installations, meeting an energy efficiency level associated with the best available techniques (BAT-AEELs) as defined in Commission Implementing Decision (EU) 2017/1442 ( 5 );
for installations with a total rated thermal input above 100 MW, it is produced applying high-efficiency cogeneration technology, or, for electricity-only installations, achieving an net-electrical efficiency of at least 36 %;
it is produced applying Biomass CO2 Capture and Storage.
For the purposes of points (a), (b) and (c) of the first subparagraph of paragraph 1 of this Article, electricity-only-installations shall be taken into account only if they do not use fossil fuels as a main fuel and only if there is no cost-effective potential for the application of high-efficiency cogeneration technology according to the assessment in accordance with Article 14 of Directive 2012/27/EU.
For the purposes of points (a) and (b) of the first subparagraph of paragraph 1 of this Article, this paragraph shall apply only to installations starting operation or converted to the use of biomass fuels after 25 December 2021. For the purposes of point (c) of the first subparagraph of paragraph 1 of this Article, this paragraph shall be without prejudice to support granted under support schemes in accordance with Article 4 approved by 25 December 2021.
Member States may apply higher energy efficiency requirements than those referred in the first subparagraph to installations with lower rated thermal input.
The first subparagraph shall not apply to electricity from installations which are the object of a specific notification by a Member State to the Commission based on the duly substantiated existence of risks for the security of supply of electricity. Upon assessment of the notification, the Commission shall adopt a decision taking into account the elements included therein.
For the purposes referred to in point (c) of the first subparagraph of paragraph 1 of this Article, Member States may derogate, for a limited period of time, from the criteria laid down in paragraphs 2 to 7 and 10 and 11 of this Article by adopting different criteria for:
installations located in an outermost region as referred to in Article 349 TFEU to the extent that such facilities produce electricity or heating or cooling from biomass fuels; and
biomass fuels used in the installations referred to in point (a) of this subparagraph, irrespective of the place of origin of that biomass, provided that such criteria are objectively justified on the grounds that their aim is to ensure, for that outermost region, a smooth phase-in of the criteria laid down in paragraphs 2 to 7 and 10 and 11 of this Article and thereby incentivise the transition from fossil fuels to sustainable biomass fuels.
The different criteria referred to in this paragraph shall be subject to a specific notification by the relevant Member State to the Commission.
By 31 December 2026, the Commission shall assess the impact of such additional criteria on the internal market, accompanied, if necessary, by a proposal to ensure harmonisation thereof.
Article 30
Verification of compliance with the sustainability and greenhouse gas emissions saving criteria
Where biofuels, bioliquids and biomass fuels, or other fuels that are eligible for counting towards the numerator referred to in point (b) of Article 27(1), are to be taken into account for the purposes referred to in Articles 23 and 25 and in points (a), (b) and (c) of the first subparagraph of Article 29(1), Member States shall require economic operators to show that the sustainability and greenhouse gas emissions saving criteria laid down in Article 29(2) to (7) and (10) have been fulfilled. For those purposes, they shall require economic operators to use a mass balance system which:
allows consignments of raw material or fuels with differing sustainability and greenhouse gas emissions saving characteristics to be mixed for instance in a container, processing or logistical facility, transmission and distribution infrastructure or site;
allows consignments of raw material with differing energy content to be mixed for the purposes of further processing, provided that the size of consignments is adjusted according to their energy content;
requires information about the sustainability and greenhouse gas emissions saving characteristics and sizes of the consignments referred to in point (a) to remain assigned to the mixture; and
provides for the sum of all consignments withdrawn from the mixture to be described as having the same sustainability characteristics, in the same quantities, as the sum of all consignments added to the mixture and requires that this balance be achieved over an appropriate period of time.
The mass balance system shall ensure that each consignment is counted only once in point (a), (b) or (c) of the first subparagraph of Article 7(1) for the purposes of calculating the gross final consumption of energy from renewable sources and shall include information on whether support has been provided for the production of that consignment, and if so, on the type of support scheme.
Where a consignment is processed, information on the sustainability and greenhouse gas emissions saving characteristics of the consignment shall be adjusted and assigned to the output in accordance with the following rules:
when the processing of a consignment of raw material yields only one output that is intended for the production of biofuels, bioliquids or biomass fuels, renewable liquid and gaseous transport fuels of non-biological origin, or recycled carbon fuels, the size of the consignment and the related quantities of sustainability and greenhouse gas emissions saving characteristics shall be adjusted applying a conversion factor representing the ratio between the mass of the output that is intended for such production and the mass of the raw material entering the process;
when the processing of a consignment of raw material yields more than one output that is intended for the production of biofuels, bioliquids or biomass fuels, renewable liquid and gaseous transport fuels of non-biological origin, or recycled carbon fuels, for each output a separate conversion factor shall be applied and a separate mass balance shall be used.
The obligations laid down in this paragraph shall apply regardless of whether the biofuels, bioliquids, biomass fuels, renewable liquid and gaseous transport fuels of non-biological origin, or recycled carbon fuels are produced within the Union or are imported. Information about the geographic origin and feedstock type of biofuels, bioliquids and biomass fuels per fuel supplier shall be made available to consumers on the websites of operators, suppliers or the relevant competent authorities and shall be updated on an annual basis.
Member States shall submit to the Commission, in aggregated form, the information referred to in the first subparagraph of this paragraph. The Commission shall publish that information on the e-reporting platform referred to in Article 28 of Regulation (EU) 2018/1999 in summary form preserving the confidentiality of commercially sensitive information.
The Commission may decide that those schemes contain accurate information on measures taken for soil, water and air protection, for the restoration of degraded land, for the avoidance of excessive water consumption in areas where water is scarce, and for certification of biofuels, bioliquids and biomass fuels with low indirect land-use change-risk.
The Commission shall require that each voluntary scheme on which a decision has been adopted under paragraph 4 submit annually by 30 April a report to the Commission covering each of the points ►C1 set out in Annex XI to Regulation (EU) 2018/1999. ◄ The report shall cover the preceding calendar year. The requirement to submit a report shall apply only to voluntary schemes that have operated for at least 12 months.
The Commission shall make the reports drawn up by the voluntary schemes available, in an aggregated form or in full if appropriate, on the e-reporting platform referred to in Article 28 of Regulation (EU) 2018/1999.
A Member State may notify such a national scheme to the Commission. The Commission shall give priority to the assessment of such a scheme in order to facilitate mutual bilateral and multilateral recognition of schemes for verification of compliance with the sustainability and greenhouse gas emissions saving criteria for biofuels, bioliquids and biomass fuels and with the greenhouse gas emissions savings thresholds for other fuels that are eligible for counting towards the numerator referred to in point (b) of Article 27(1). The Commission may decide, by means of implementing acts, whether such a notified national scheme complies with the conditions laid down in this Directive. Those implementing acts shall be adopted in accordance with the examination procedure referred to in Article 34(3).
Where the decision is positive, schemes established in accordance with this Article shall not refuse mutual recognition with that Member State's scheme, as regards verification of compliance with the sustainability and greenhouse gas emissions saving criteria laid down in Article 29(2) to (7) and (10) and the greenhouse gas emissions savings thresholds set in, and adopted pursuant to, Article 25(2).
The voluntary schemes referred to in paragraph 4 shall, at least annually, publish a list of their certification bodies used for independent auditing, indicating for each certification body by which entity or national public authority it was recognised and which entity or national public authority is monitoring it.
In those implementing acts, the Commission shall pay particular attention to the need to minimise administrative burden. The implementing acts shall set a time frame by which voluntary schemes are required to implement the standards. The Commission may repeal decisions recognising voluntary schemes pursuant to paragraph 4 in the event that those schemes fail to implement such standards in the time frame provided for. Where a Member State raises concerns that a voluntary scheme does not operate in accordance with the standards of reliability, transparency and independent auditing that constitute the basis for decisions under paragraph 4, the Commission shall investigate the matter and take appropriate action.
Competent authorities of the Member States shall supervise the operation of certification bodies that are conducting independent auditing under a voluntary scheme. Certification bodies shall submit, upon the request of competent authorities, all relevant information necessary to supervise the operation, including the exact date, time and location of audits. Where Member States find issues of non-conformity, they shall inform the voluntary scheme without delay.
Within six months of receipt of such a request and in accordance with the examination procedure referred to in Article 34(3), the Commission shall, by means of implementing acts, decide whether the Member State concerned may either:
take into account biofuels, bioliquids, biomass fuels and other fuels that are eligible for counting towards the numerator referred to in point (b) of Article 27(1) from that source for the purposes referred to in points (a), (b) and (c) of the first subparagraph of Article 29(1); or
by way of derogation from paragraph 9 of this Article, require suppliers of the source of biofuels, bioliquids, biomass fuels and other fuels that are eligible for counting towards the numerator referred to in point (b) of Article 27(1) to provide further evidence of compliance with those sustainability and greenhouse gas emissions saving criteria and those greenhouse gas emissions savings thresholds.
Article 31
Calculation of the greenhouse gas impact of biofuels, bioliquids and biomass fuels
For the purposes of Article 29(10), the greenhouse gas emissions saving from the use of biofuel, bioliquids and biomass fuels shall be calculated in one of the following ways:
where a default value for greenhouse gas emissions saving for the production pathway is laid down in Part A or B of Annex V for biofuels and bioliquids and in Part A of Annex VI for biomass fuels where the el value for those biofuels or bioliquids calculated in accordance with point 7 of Part C of Annex V and for those biomass fuels calculated in accordance with point 7 of Part B of Annex VI is equal to or less than zero, by using that default value;
by using an actual value calculated in accordance with the methodology laid down in Part C of Annex V for biofuels and bioliquids and in Part B of Annex VI for biomass fuels;
by using a value calculated as the sum of the factors of the formulas referred to in point 1 of Part C of Annex V, where disaggregated default values in Part D or E of Annex V may be used for some factors, and actual values, calculated in accordance with the methodology laid down in Part C of Annex V, are used for all other factors;
by using a value calculated as the sum of the factors of the formulas referred to in point 1 of Part B of Annex VI, where disaggregated default values in Part C of Annex VI may be used for some factors, and actual values, calculated in accordance with the methodology laid down in Part B of Annex VI, are used for all other factors.
Those data may, pursuant to such decisions, be used instead of the disaggregated default values for cultivation laid down in Part D or E of Annex V for biofuels and bioliquids and in Part C of Annex VI for biomass fuels.
The Commission is empowered to adopt delegated acts pursuant to Article 35 to amend, where appropriate, Annexes V and VI by adding or revising the default values or modifying the methodology.
In the case of an adaptation of, or addition to, the list of default values in Annexes V and VI:
where the contribution of a factor to overall emissions is small, where there is limited variation, or where the cost or difficulty of establishing actual values is high, the default values shall be typical of normal production processes;
in all other cases, the default values shall be conservative compared to normal production processes.
Article 32
Implementing acts
The implementing acts referred to in the second subparagraph of Article 29(3), Article 29(8), the first subparagraph of Article 30(5), the second subparagraph of Article 30(6), the first subparagraph of Article 30(8), the first subparagraph of Article 31(4) and Article 31(6) of this Directive, shall take full account of the provisions relating to greenhouse gas emissions reductions in accordance with Article 7a of Directive 98/70/EC of the European Parliament and of the Council ( 7 ).
Article 33
Monitoring by the Commission
That proposal shall take into account the experience of the implementation of this Directive, including its sustainability and greenhouse gas emissions saving criteria, and technological developments in energy from renewable sources.
Article 34
Committee procedure
Where the Committee delivers no opinion, the Commission shall not adopt the draft implementing act and the third subparagraph of Article 5(4) of Regulation (EU) No 182/2011 shall apply.
Article 35
Exercise of the delegation
Article 36
Transposition
When Member States adopt those measures, they shall contain a reference to this Directive or be accompanied by such a reference on the occasion of their official publication. They shall also include a statement that references in existing laws, regulations and administrative provisions to the Directive repealed by this Directive shall be construed as references to this Directive. Member States shall determine how such reference is to be made and how that statement is to be formulated.
Article 37
Repeal
Directive 2009/28/EC, as amended by the Directives listed in Part A of Annex X, is repealed with effect from 1 July 2021, without prejudice to the obligations of the Member States relating to the time-limits for the transposition into national law of the Directives set out in Part B of Annex X and without prejudice to the obligations of Member States in 2020 as laid down in Article 3(1) and set out in Part A of Annex I to Directive 2009/28/EC.
References to the repealed Directive shall be construed as references to this Directive and shall be read in accordance with the correlation table set out in Annex XI.
Article 38
Entry into force
This Directive shall enter into force on the third day following that of its publication in the Official Journal of the European Union.
Article 39
Addressees
This Directive is addressed to the Member States.
ANNEX I
NATIONAL OVERALL TARGETS FOR THE SHARE OF ENERGY FROM RENEWABLE SOURCES IN GROSS FINAL CONSUMPTION OF ENERGY IN 2020 ( 8 )
A. National overall targets
|
|
Share of energy from renewable sources in gross final consumption of energy, 2005 (S2005) |
Target for share of energy from renewable sources in gross final consumption of energy, 2020 (S2020) |
|
Belgium |
2,2 % |
13 % |
|
Bulgaria |
9,4 % |
16 % |
|
Czech Republic |
6,1 % |
13 % |
|
Denmark |
17,0 % |
30 % |
|
Germany |
5,8 % |
18 % |
|
Estonia |
18,0 % |
25 % |
|
Ireland |
3,1 % |
16 % |
|
Greece |
6,9 % |
18 % |
|
Spain |
8,7 % |
20 % |
|
France |
10,3 % |
23 % |
|
Croatia |
12,6 % |
20 % |
|
Italy |
5,2 % |
17 % |
|
Cyprus |
2,9 % |
13 % |
|
Latvia |
32,6 % |
40 % |
|
Lithuania |
15,0 % |
23 % |
|
Luxembourg |
0,9 % |
11 % |
|
Hungary |
4,3 % |
13 % |
|
Malta |
0,0 % |
10 % |
|
Netherlands |
2,4 % |
14 % |
|
Austria |
23,3 % |
34 % |
|
Poland |
7,2 % |
15 % |
|
Portugal |
20,5 % |
31 % |
|
Romania |
17,8 % |
24 % |
|
Slovenia |
16,0 % |
25 % |
|
Slovak Republic |
6,7 % |
14 % |
|
Finland |
28,5 % |
38 % |
|
Sweden |
39,8 % |
49 % |
|
United Kingdom |
1,3 % |
15 % |
ANNEX II
NORMALISATION RULE FOR ACCOUNTING FOR ELECTRICITY GENERATED FROM HYDROPOWER AND WIND POWER
The following rule shall be applied for the purposes of accounting for electricity generated from hydropower in a given Member State:
►C1
◄ where:
|
N |
= |
reference year; |
|
QN(norm) |
= |
normalised electricity generated by all hydropower plants of the Member State in year N, for accounting purposes; |
|
Qi |
= |
the quantity of electricity actually generated in year i by all hydropower plants of the Member State measured in GWh, excluding production from pumped storage units using water that has previously been pumped uphill; |
|
Ci |
= |
the total installed capacity, net of pumped storage, of all hydropower plants of the Member State at the end of year i, measured in MW. |
The following rule shall be applied for the purposes of accounting for electricity generated from onshore wind power in a given Member State:
►C1
◄ where:
|
N |
= |
reference year; |
|
QN(norm) |
= |
normalised electricity generated by all onshore wind power plants of the Member State in year N, for accounting purposes; |
|
Qi |
= |
the quantity of electricity actually generated in year i by all onshore wind power plants of the Member State measured in GWh; |
|
Cj |
= |
the total installed capacity of all the onshore wind power plants of the Member State at the end of year j, measured in MW; |
|
n |
= |
4 or the number of years preceding year N for which capacity and production data are available for the Member State in question, whichever is lower. |
The following rule shall be applied for the purposes of accounting for electricity generated from offshore wind power in a given Member State:
►C1
◄ where:
|
N |
= |
reference year; |
|
QN(norm) |
= |
normalised electricity generated by all offshore wind power plants of the Member State in year N, for accounting purposes; |
|
Qi |
= |
the quantity of electricity actually generated in year i by all offshore wind power plants of the Member State measured in GWh; |
|
Cj |
= |
the total installed capacity of all the offshore wind power plants of the Member State at the end of year j, measured in MW; |
|
n |
= |
4 or the number of years preceding year N for which capacity and production data are available for the Member State in question, whichever is lower. |
ANNEX III
ENERGY CONTENT OF FUELS
|
Fuel |
Energy content by weight (lower calorific value, MJ/kg) |
Energy content by volume (lower calorific value, MJ/l) |
|
FUELS FROM BIOMASS AND/OR BIOMASS PROCESSING OPERATIONS |
||
|
Bio-Propane |
46 |
24 |
|
Pure vegetable oil (oil produced from oil plants through pressing, extraction or comparable procedures, crude or refined but chemically unmodified) |
37 |
34 |
|
Biodiesel - fatty acid methyl ester (methyl-ester produced from oil of biomass origin) |
37 |
33 |
|
Biodiesel - fatty acid ethyl ester (ethyl-ester produced from oil of biomass origin) |
38 |
34 |
|
Biogas that can be purified to natural gas quality |
50 |
— |
|
Hydrotreated (thermochemically treated with hydrogen) oil of biomass origin, to be used for replacement of diesel |
44 |
34 |
|
Hydrotreated (thermochemically treated with hydrogen) oil of biomass origin, to be used for replacement of petrol |
45 |
30 |
|
Hydrotreated (thermochemically treated with hydrogen) oil of biomass origin, to be used for replacement of jet fuel |
44 |
34 |
|
Hydrotreated oil (thermochemically treated with hydrogen) of biomass origin, to be used for replacement of liquefied petroleum gas |
46 |
24 |
|
Co-processed oil (processed in a refinery simultaneously with fossil fuel) of biomass or pyrolysed biomass origin to be used for replacement of diesel |
43 |
36 |
|
Co-processed oil (processed in a refinery simultaneously with fossil fuel) of biomass or pyrolysed biomass origin, to be used to replace petrol |
44 |
32 |
|
Co-processed oil (processed in a refinery simultaneously with fossil fuel) of biomass or pyrolysed biomass origin, to be used to replace jet fuel |
43 |
33 |
|
Co-processed oil (processed in a refinery simultaneously with fossil fuel) of biomass or pyrolysed biomass origin, to be used to replace liquefied petroleum gas |
46 |
23 |
|
RENEWABLE FUELS THAT CAN BE PRODUCED FROM VARIOUS RENEWABLE SOURCES, INCLUDING BIOMASS |
||
|
Methanol from renewable sources |
20 |
16 |
|
Ethanol from renewable sources |
27 |
21 |
|
Propanol from renewable sources |
31 |
25 |
|
Butanol from renewable sources |
33 |
27 |
|
Fischer-Tropsch diesel (a synthetic hydrocarbon or mixture of synthetic hydrocarbons to be used for replacement of diesel) |
44 |
34 |
|
Fischer-Tropsch petrol (a synthetic hydrocarbon or mixture of synthetic hydrocarbons produced from biomass, to be used for replacement of petrol) |
44 |
33 |
|
Fischer-Tropsch jet fuel (a synthetic hydrocarbon or mixture of synthetic hydrocarbons produced from biomass, to be used for replacement of jet fuel) |
44 |
33 |
|
Fischer-Tropsch liquefied petroleum gas (a synthetic hydrocarbon or mixture of synthetic hydrocarbons, to be used for replacement of liquefied petroleum gas |
46 |
24 |
|
DME (dimethylether) |
28 |
19 |
|
Hydrogen from renewable sources |
120 |
— |
|
ETBE (ethyl-tertio-butyl-ether produced on the basis of ethanol) |
36 (of which 37 % from renewable sources) |
27 (of which 37 % from renewable sources) |
|
MTBE (methyl-tertio-butyl-ether produced on the basis of methanol) |
35 (of which 22 % from renewable sources) |
26 (of which 22 % from renewable sources) |
|
TAEE (tertiary-amyl-ethyl-ether produced on the basis of ethanol) |
38 (of which 29 % from renewable sources) |
29 (of which 29 % from renewable sources) |
|
TAME (tertiary-amyl-methyl-ether produced on the basis of methanol) |
36 (of which 18 % from renewable sources) |
28 (of which 18 % from renewable sources) |
|
THxEE (tertiary-hexyl-ethyl-ether produced on the basis of ethanol) |
38 (of which 25 % from renewable sources) |
30 (of which 25 % from renewable sources) |
|
THxME (tertiary-hexyl-methyl-ether produced on the basis of methanol) |
38 of which 14 % from renewable sources) |
30 (of which 14 % from renewable sources) |
|
FOSSIL FUELS |
||
|
Petrol |
43 |
32 |
|
Diesel |
43 |
36 |
ANNEX IV
CERTIFICATION OF INSTALLERS
The certification schemes or equivalent qualification schemes referred to in Article 18(3) shall be based on the following criteria:
The certification or qualification process shall be transparent and clearly defined by the Member States or by the administrative body that they appoint.
Installers of biomass, heat pump, shallow geothermal and solar photovoltaic and solar thermal energy shall be certified by an accredited training programme or training provider.
The accreditation of the training programme or provider shall be effected by Member States or by the administrative body that they appoint. The accrediting body shall ensure that the training programme offered by the training provider has continuity and regional or national coverage. The training provider shall have adequate technical facilities to provide practical training, including some laboratory equipment or corresponding facilities to provide practical training. The training provider shall also offer in addition to the basic training, shorter refresher courses on topical issues, including on new technologies, to enable life-long learning in installations. The training provider may be the manufacturer of the equipment or system, institutes or associations.
The training leading to certification or qualification of an installer shall include theoretical and practical parts. At the end of the training, the installer must have the skills required to install the relevant equipment and systems to meet the performance and reliability needs of the customer, incorporate quality craftsmanship, and comply with all applicable codes and standards, including energy and eco-labelling.
The training course shall end with an examination leading to a certificate or qualification. The examination shall include a practical assessment of successfully installing biomass boilers or stoves, heat pumps, shallow geothermal installations, solar photovoltaic or solar thermal installations.
The certification schemes or equivalent qualification schemes referred to in Article 18(3) shall take due account of the following guidelines:
Accredited training programmes should be offered to installers with work experience, who have undergone, or are undergoing, the following types of training:
in the case of biomass boiler and stove installers: training as a plumber, pipe fitter, heating engineer or technician of sanitary and heating or cooling equipment as a prerequisite;
in the case of heat pump installers: training as a plumber or refrigeration engineer and have basic electrical and plumbing skills (cutting pipe, soldering pipe joints, gluing pipe joints, lagging, sealing fittings, testing for leaks and installation of heating or cooling systems) as a prerequisite;
in the case of a solar photovoltaic or solar thermal installer: training as a plumber or electrician and have plumbing, electrical and roofing skills, including knowledge of soldering pipe joints, gluing pipe joints, sealing fittings, testing for plumbing leaks, ability to connect wiring, familiar with basic roof materials, flashing and sealing methods as a prerequisite; or
a vocational training scheme to provide an installer with adequate skills corresponding to a three years education in the skills referred to in point (a), (b) or (c), including both classroom and workplace learning.
The theoretical part of the biomass stove and boiler installer training should give an overview of the market situation of biomass and cover ecological aspects, biomass fuels, logistics, fire protection, related subsidies, combustion techniques, firing systems, optimal hydraulic solutions, cost and profitability comparison as well as the design, installation and maintenance of biomass boilers and stoves. The training should also provide good knowledge of any European standards for technology and biomass fuels, such as pellets, and biomass related national and Union law.
The theoretical part of the heat pump installer training should give an overview of the market situation for heat pumps and cover geothermal resources and ground source temperatures of different regions, soil and rock identification for thermal conductivity, regulations on using geothermal resources, feasibility of using heat pumps in buildings and determining the most suitable heat pump system, and knowledge about their technical requirements, safety, air filtering, connection with the heat source and system layout. The training should also provide good knowledge of any European standards for heat pumps, and of relevant national and Union law. The installer should demonstrate the following key competences:
a basic understanding of the physical and operation principles of a heat pump, including characteristics of the heat pump circle: context between low temperatures of the heat sink, high temperatures of the heat source, and the efficiency of the system, determination of the coefficient of performance and seasonal performance factor (SPF);
an understanding of the components and their function within a heat pump circle, including the compressor, expansion valve, evaporator, condenser, fixtures and fittings, lubricating oil, refrigerant, superheating and sub-cooling and cooling possibilities with heat pumps; and
the ability to choose and size the components in typical installation situations, including determining the typical values of the heat load of different buildings and for hot water production based on energy consumption, determining the capacity of the heat pump on the heat load for hot water production, on the storage mass of the building and on interruptible current supply; determine the buffer tank component and its volume and integration of a second heating system.
The theoretical part of the solar photovoltaic and solar thermal installer training should give an overview of the market situation of solar products and cost and profitability comparisons, and cover ecological aspects, components, characteristics and dimensioning of solar systems, selection of accurate systems and dimensioning of components, determination of the heat demand, fire protection, related subsidies, as well as the design, installation and maintenance of solar photovoltaic and solar thermal installations. The training should also provide good knowledge of any European standards for technology, and certification such as Solar Keymark, and related national and Union law. The installer should demonstrate the following key competences:
the ability to work safely using the required tools and equipment and implementing safety codes and standards and to identify plumbing, electrical and other hazards associated with solar installations;
the ability to identify systems and their components specific to active and passive systems, including the mechanical design, and to determine the components' location and system layout and configuration;
the ability to determine the required installation area, orientation and tilt for the solar photovoltaic and solar water heater, taking account of shading, solar access, structural integrity, the appropriateness of the installation for the building or the climate and to identify different installation methods suitable for roof types and the balance of system equipment required for the installation; and
for solar photovoltaic systems in particular, the ability to adapt the electrical design, including determining design currents, selecting appropriate conductor types and ratings for each electrical circuit, determining appropriate size, ratings and locations for all associated equipment and subsystems and selecting an appropriate interconnection point.
The installer certification should be time restricted, so that a refresher seminar or event would be necessary for continued certification.
ANNEX V
RULES FOR CALCULATING THE GREENHOUSE GAS IMPACT OF BIOFUELS, BIOLIQUIDS AND THEIR FOSSIL FUEL COMPARATORS
A. TYPICAL AND DEFAULT VALUES FOR BIOFUELS IF PRODUCED WITH NO NET CARBON EMISSIONS FROM LAND-USE CHANGE
|
Biofuel production pathway |
Greenhouse gas emissions saving – typical value |
Greenhouse gas emissions saving – default value |
|
sugar beet ethanol (no biogas from slop, natural gas as process fuel in conventional boiler) |
67 % |
59 % |
|
sugar beet ethanol (with biogas from slop, natural gas as process fuel in conventional boiler) |
77 % |
73 % |
|
sugar beet ethanol (no biogas from slop, natural gas as process fuel in CHP plant (*)) |
73 % |
68 % |
|
sugar beet ethanol (with biogas from slop, natural gas as process fuel in CHP plant (*)) |
79 % |
76 % |
|
sugar beet ethanol (no biogas from slop, lignite as process fuel in CHP plant (*)) |
58 % |
47 % |
|
sugar beet ethanol (with biogas from slop, lignite as process fuel in CHP plant (*)) |
71 % |
64 % |
|
corn (maize) ethanol (natural gas as process fuel in conventional boiler) |
48 % |
40 % |
|
corn (maize) ethanol, (natural gas as process fuel in CHP plant (*)) |
55 % |
48 % |
|
corn (maize) ethanol (lignite as process fuel in CHP plant (*)) |
40 % |
28 % |
|
corn (maize) ethanol (forest residues as process fuel in CHP plant (*)) |
69 % |
68 % |
|
other cereals excluding maize ethanol (natural gas as process fuel in conventional boiler) |
47 % |
38 % |
|
other cereals excluding maize ethanol (natural gas as process fuel in CHP plant (*)) |
53 % |
46 % |
|
other cereals excluding maize ethanol (lignite as process fuel in CHP plant (*)) |
37 % |
24 % |
|
other cereals excluding maize ethanol (forest residues as process fuel in CHP plant (*)) |
67 % |
67 % |
|
sugar cane ethanol |
70 % |
70 % |
|
the part from renewable sources of ethyl-tertio-butyl-ether (ETBE) |
Equal to that of the ethanol production pathway used |
|
|
the part from renewable sources of tertiary-amyl-ethyl-ether (TAEE) |
Equal to that of the ethanol production pathway used |
|
|
rape seed biodiesel |
52 % |
47 % |
|
sunflower biodiesel |
57 % |
52 % |
|
soybean biodiesel |
55 % |
50 % |
|
palm oil biodiesel (open effluent pond) |
33 % |
20 % |
|
palm oil biodiesel (process with methane capture at oil mill) |
51 % |
45 % |
|
waste cooking oil biodiesel |
88 % |
84 % |
|
animal fats from rendering biodiesel (**) |
84 % |
78 % |
|
hydrotreated vegetable oil from rape seed |
51 % |
47 % |
|
hydrotreated vegetable oil from sunflower |
58 % |
54 % |
|
hydrotreated vegetable oil from soybean |
55 % |
51 % |
|
hydrotreated vegetable oil from palm oil (open effluent pond) |
34 % |
22 % |
|
hydrotreated vegetable oil from palm oil (process with methane capture at oil mill) |
53 % |
49 % |
|
hydrotreated oil from waste cooking oil |
87 % |
83 % |
|
hydrotreated oil from animal fats from rendering (**) |
83 % |
77 % |
|
pure vegetable oil from rape seed |
59 % |
57 % |
|
pure vegetable oil from sunflower |
65 % |
64 % |
|
pure vegetable oil from soybean |
63 % |
61 % |
|
pure vegetable oil from palm oil (open effluent pond) |
40 % |
30 % |
|
pure vegetable oil from palm oil (process with methane capture at oil mill) |
59 % |
57 % |
|
pure oil from waste cooking oil |
98 % |
98 % |
|
(*) Default values for processes using CHP are valid only if all the process heat is supplied by CHP. (**) Applies only to biofuels produced from animal by-products classified as category 1 and 2 material in accordance with Regulation (EC) No 1069/2009 of the European Parliament and of the Council (1), for which emissions related to hygenisation as part of the rendering are not considered. |
||
|
(1)
Regulation (EC) No 1069/2009 of the European Parliament and of the Council of 21 October 2009 laying down health rules as regards animal by-products and derived products not intended for human consumption and repealing Regulation (EC) No 1774/2002 (Animal by-products Regulation) (OJ L 300, 14.11.2009, p. 1). |
||
B. ESTIMATED TYPICAL AND DEFAULT VALUES FOR FUTURE BIOFUELS THAT WERE NOT ON THE MARKET OR WERE ON THE MARKET ONLY IN NEGLIGIBLE QUANTITIES IN 2016, IF PRODUCED WITH NO NET CARBON EMISSIONS FROM LAND-USE CHANGE
|
Biofuel production pathway |
Greenhouse gas emissions saving - typical value |
Greenhouse gas emissions saving - default value |
|
wheat straw ethanol |
85 % |
83 % |
|
waste wood Fischer-Tropsch diesel in free-standing plant |
83 % |
83 % |
|
farmed wood Fischer-Tropsch diesel in free-standing plant |
82 % |
82 % |
|
waste wood Fischer-Tropsch petrol in free-standing plant |
83 % |
83 % |
|
farmed wood Fischer-Tropsch petrol in free-standing plant |
82 % |
82 % |
|
waste wood dimethylether (DME) in free-standing plant |
84 % |
84 % |
|
farmed wood dimethylether (DME) in free-standing plant |
83 % |
83 % |
|
waste wood methanol in free-standing plant |
84 % |
84 % |
|
farmed wood methanol in free-standing plant |
83 % |
83 % |
|
Fischer-Tropsch diesel from black-liquor gasification integrated with pulp mill |
89 % |
89 % |
|
Fischer-Tropsch petrol from black-liquor gasification integrated with pulp mill |
89 % |
89 % |
|
dimethylether (DME) from black-liquor gasification integrated with pulp mill |
89 % |
89 % |
|
Methanol from black-liquor gasification integrated with pulp mill |
89 % |
89 % |
|
the part from renewable sources of methyl-tertio-butyl-ether (MTBE) |
Equal to that of the methanol production pathway used |
|
C. METHODOLOGY
1. Greenhouse gas emissions from the production and use of transport fuels, biofuels and bioliquids shall be calculated as follows:
greenhouse gas emissions from the production and use of biofuels shall be calculated as:
E = eec + el + ep + etd + eu – esca – eccs – eccr,
where
|
E |
= |
total emissions from the use of the fuel; |
|
eec |
= |
emissions from the extraction or cultivation of raw materials; |
|
el |
= |
annualised emissions from carbon stock changes caused by land-use change; |
|
ep |
= |
emissions from processing; |
|
etd |
= |
emissions from transport and distribution; |
|
eu |
= |
emissions from the fuel in use; |
|
esca |
= |
emission savings from soil carbon accumulation via improved agricultural management; |
|
eccs |
= |
emission savings from CO2 capture and geological storage; and |
|
eccr |
= |
emission savings from CO2 capture and replacement. |
Emissions from the manufacture of machinery and equipment shall not be taken into account.
Greenhouse gas emissions from the production and use of bioliquids shall be calculated as for biofuels (E), but with the extension necessary for including the energy conversion to electricity and/or heat and cooling produced, as follows:
For energy installations delivering only heat:
For energy installations delivering only electricity:
where
|
ECh,el |
= |
Total greenhouse gas emissions from the final energy commodity. |
|
E |
= |
Total greenhouse gas emissions of the bioliquid before end-conversion. |
|
ηel |
= |
The electrical efficiency, defined as the annual electricity produced divided by the annual bioliquid input based on its energy content. |
|
ηh |
= |
The heat efficiency, defined as the annual useful heat output divided by the annual bioliquid input based on its energy content. |
For the electricity or mechanical energy coming from energy installations delivering useful heat together with electricity and/or mechanical energy:
For the useful heat coming from energy installations delivering heat together with electricity and/or mechanical energy:
where:
|
ECh,el |
= |
Total greenhouse gas emissions from the final energy commodity. |
|
E |
= |
Total greenhouse gas emissions of the bioliquid before end-conversion. |
|
ηel |
= |
The electrical efficiency, defined as the annual electricity produced divided by the annual fuel input based on its energy content. |
|
ηh |
= |
The heat efficiency, defined as the annual useful heat output divided by the annual fuel input based on its energy content. |
|
Cel |
= |
Fraction of exergy in the electricity, and/or mechanical energy, set to 100 % (Cel = 1). |
|
Ch |
= |
Carnot efficiency (fraction of exergy in the useful heat). |
The Carnot efficiency, Ch, for useful heat at different temperatures is defined as:
where
|
Th |
= |
Temperature, measured in absolute temperature (kelvin) of the useful heat at point of delivery. |
|
T0 |
= |
Temperature of surroundings, set at 273,15 kelvin (equal to 0 °C) |
If the excess heat is exported for heating of buildings, at a temperature below 150 °C (423,15 kelvin), Ch can alternatively be defined as follows:
|
Ch |
= |
Carnot efficiency in heat at 150 °C (423,15 kelvin), which is: 0,3546 |
For the purposes of that calculation, the following definitions apply:
‘cogeneration’ means the simultaneous generation in one process of thermal energy and electricity and/or mechanical energy;
‘useful heat’ means heat generated to satisfy an economical justifiable demand for heat, for heating and cooling purposes;
‘economically justifiable demand’ means the demand that does not exceed the needs for heat or cooling and which would otherwise be satisfied at market conditions.
2. Greenhouse gas emissions from biofuels and bioliquids shall be expressed as follows:
greenhouse gas emissions from biofuels, E, shall be expressed in terms of grams of CO2 equivalent per MJ of fuel, g CO2eq/MJ.
greenhouse gas emissions from bioliquids, EC, in terms of grams of CO2 equivalent per MJ of final energy commodity (heat or electricity), g CO2eq/MJ.
When heating and cooling are co-generated with electricity, emissions shall be allocated between heat and electricity (as under 1(b)), irrespective if the heat is used for actual heating purposes or for cooling ( 9 ).
Where the greenhouse gas emissions from the extraction or cultivation of raw materials eec are expressed in unit g CO2eq/dry-ton of feedstock, the conversion to grams of CO2 equivalent per MJ of fuel, g CO2eq/MJ, shall be calculated as follows ( 10 ):
where
Emissions per dry-ton feedstock shall be calculated as follows:
3. Greenhouse gas emissions savings from biofuels and bioliquids shall be calculated as follows:
greenhouse gas emissions savings from biofuels:
SAVING = (EF(t) – EB)/EF(t),
where
|
EB |
= |
total emissions from the biofuel; and |
|
EF(t) |
= |
total emissions from the fossil fuel comparator for transport |
greenhouse gas emissions savings from heat and cooling, and electricity being generated from bioliquids:
SAVING = (ECF(h&c,el) – ECB(h&c,el))/ECF(h&c,el),
where
|
ECB(h&c,el) |
= |
total emissions from the heat or electricity; and |
|
ECF(h&c,el) |
= |
total emissions from the fossil fuel comparator for useful heat or electricity. |
4. The greenhouse gases taken into account for the purposes of point 1 shall be CO2, N2O and CH4. For the purposes of calculating CO2 equivalence, those gases shall be valued as follows:
|
CO2 |
: |
1 |
|
N2O |
: |
298 |
|
CH4 |
: |
25 |
5. Emissions from the extraction or cultivation of raw materials, eec, shall include emissions from the extraction or cultivation process itself; from the collection, drying and storage of raw materials; from waste and leakages; and from the production of chemicals or products used in extraction or cultivation. Capture of CO2 in the cultivation of raw materials shall be excluded. Estimates of emissions from agriculture biomass cultivation may be derived from the use of regional averages for cultivation emissions included in the reports referred to in Article 31(4) or the information on the disaggregated default values for cultivation emissions included in this Annex, as an alternative to using actual values. In the absence of relevant information in those reports it is allowed to calculate averages based on local farming practises based for instance on data of a group of farms, as an alternative to using actual values.
6. For the purposes of the calculation referred to in point 1(a), greenhouse gas emissions savings from improved agriculture management, esca, such as shifting to reduced or zero-tillage, improved crop/rotation, the use of cover crops, including crop residue management, and the use of organic soil improver (e.g. compost, manure fermentation digestate), shall be taken into account only if solid and verifiable evidence is provided that the soil carbon has increased or that it is reasonable to expect to have increased over the period in which the raw materials concerned were cultivated while taking into account the emissions where such practices lead to increased fertiliser and herbicide use ( 11 ).
7. Annualised emissions from carbon stock changes caused by land-use change, el, shall be calculated by dividing total emissions equally over 20 years. For the calculation of those emissions, the following rule shall be applied:
el = (CSR – CSA) × 3,664 × 1/20 × 1/P – eB, ( 12 )
where
|
el |
= |
annualised greenhouse gas emissions from carbon stock change due to land-use change (measured as mass (grams) of CO2-equivalent per unit of biofuel or bioliquid energy (megajoules)). ‘Cropland’ (1) and ‘perennial cropland’ (2) shall be regarded as one land use; |
|
CSR |
= |
the carbon stock per unit area associated with the reference land-use (measured as mass (tonnes) of carbon per unit area, including both soil and vegetation). The reference land-use shall be the land-use in January 2008 or 20 years before the raw material was obtained, whichever was the later; |
|
CSA |
= |
the carbon stock per unit area associated with the actual land-use (measured as mass (tonnes) of carbon per unit area, including both soil and vegetation). In cases where the carbon stock accumulates over more than one year, the value attributed to CSA shall be the estimated stock per unit area after 20 years or when the crop reaches maturity, whichever the earlier; |
|
P |
= |
the productivity of the crop (measured as biofuel or bioliquid energy per unit area per year) and |
|
eB |
= |
bonus of 29 g CO2eq/MJ biofuel or bioliquid if biomass is obtained from restored degraded land under the conditions laid down in point 8. |
|
(1)
Cropland as defined by IPCC.
(2)
Perennial crops are defined as multi-annual crops, the stem of which is usually not annually harvested such as short rotation coppice and oil palm. |
||
8. The bonus of 29 g CO2eq/MJ shall be attributed if evidence is provided that the land:
was not in use for agriculture or any other activity in January 2008; and
is severely degraded land, including such land that was formerly in agricultural use.
The bonus of 29 g CO2eq/MJ shall apply for a period of up to 20 years from the date of conversion of the land to agricultural use, provided that a steady increase in carbon stocks as well as a sizable reduction in erosion phenomena for land falling under (b) are ensured.
9. ‘Severely degraded land’ means land that, for a significant period of time, has either been significantly salinated or presented significantly low organic matter content and has been severely eroded.
10. The Commission shall review, by 31 December 2020, guidelines for the calculation of land carbon stocks ( 13 ) drawing on the 2006 IPCC Guidelines for National Greenhouse Gas Inventories – volume 4 and in accordance with Regulation (EU) No 525/2013 and Regulation (EU) 2018/841 of the European Parliament and of the Council ( 14 ). The Commission guidelines shall serve as the basis for the calculation of land carbon stocks for the purposes of this Directive.
11. Emissions from processing, ep, shall include emissions from the processing itself; from waste and leakages; and from the production of chemicals or products used in processing including the CO2 emissions corresponding to the carbon contents of fossil inputs, whether or not actually combusted in the process.
In accounting for the consumption of electricity not produced within the fuel production plant, the greenhouse gas emissions intensity of the production and distribution of that electricity shall be assumed to be equal to the average emission intensity of the production and distribution of electricity in a defined region. By way of derogation from this rule, producers may use an average value for an individual electricity production plant for electricity produced by that plant, if that plant is not connected to the electricity grid.
Emissions from processing shall include emissions from drying of interim products and materials where relevant.
12. Emissions from transport and distribution, etd, shall include emissions from the transport of raw and semi-finished materials and from the storage and distribution of finished materials. Emissions from transport and distribution to be taken into account under point 5 shall not be covered by this point.
13. Emissions of the fuel in use, eu, shall be taken to be zero for biofuels and bioliquids.
Emissions of non-CO2 greenhouse gases (N2O and CH4) of the fuel in use shall be included in the eu factor for bioliquids.
14. Emission savings from CO2 capture and geological storage, eccs, that have not already been accounted for in ep, shall be limited to emissions avoided through the capture and storage of emitted CO2 directly related to the extraction, transport, processing and distribution of fuel if stored in compliance with Directive 2009/31/EC of the European Parliament and of the Council ( 15 ).
15. Emission savings from CO2 capture and replacement, eccr, shall be related directly to the production of biofuel or bioliquid they are attributed to, and shall be limited to emissions avoided through the capture of CO2 of which the carbon originates from biomass and which is used to replace fossil-derived CO2 in production of commercial products and services.
16. Where a cogeneration unit – providing heat and/or electricity to a fuel production process for which emissions are being calculated – produces excess electricity and/or excess useful heat, the greenhouse gas emissions shall be divided between the electricity and the useful heat according to the temperature of the heat (which reflects the usefulness (utility) of the heat). The useful part of the heat is found by multiplying its energy content with the Carnot efficiency, Ch, calculated as follows:
where
|
Th |
= |
Temperature, measured in absolute temperature (kelvin) of the useful heat at point of delivery. |
|
T0 |
= |
Temperature of surroundings, set at 273,15 kelvin (equal to 0 °C) |
If the excess heat is exported for heating of buildings, at a temperature below 150 °C (423,15 kelvin), Ch can alternatively be defined as follows:
|
Ch |
= |
Carnot efficiency in heat at 150 °C (423,15 kelvin), which is: 0,3546 |
For the purposes of that calculation, the actual efficiencies shall be used, defined as the annual mechanical energy, electricity and heat produced respectively divided by the annual energy input.
For the purposes of that calculation, the following definitions apply:
‘cogeneration’ shall mean the simultaneous generation in one process of thermal energy and electrical and/or mechanical energy;
‘useful heat’ shall mean heat generated to satisfy an economical justifiable demand for heat, for heating or cooling purposes;
‘economically justifiable demand’ shall mean the demand that does not exceed the needs for heat or cooling and which would otherwise be satisfied at market conditions.
17. Where a fuel production process produces, in combination, the fuel for which emissions are being calculated and one or more other products (co-products), greenhouse gas emissions shall be divided between the fuel or its intermediate product and the co-products in proportion to their energy content (determined by lower heating value in the case of co-products other than electricity and heat). The greenhouse gas intensity of excess useful heat or excess electricity is the same as the greenhouse gas intensity of heat or electricity delivered to the fuel production process and is determined from calculating the greenhouse intensity of all inputs and emissions, including the feedstock and CH4 and N2O emissions, to and from the cogeneration unit, boiler or other apparatus delivering heat or electricity to the fuel production process. In the case of cogeneration of electricity and heat, the calculation is performed following point 16.
18. For the purposes of the calculation referred to in point 17, the emissions to be divided shall be eec + el + esca + those fractions of ep, etd, eccs, and eccr that take place up to and including the process step at which a co-product is produced. If any allocation to co-products has taken place at an earlier process step in the life-cycle, the fraction of those emissions assigned in the last such process step to the intermediate fuel product shall be used for those purposes instead of the total of those emissions.
In the case of biofuels and bioliquids, all co-products shall be taken into account for the purposes of that calculation. No emissions shall be allocated to wastes and residues. Co-products that have a negative energy content shall be considered to have an energy content of zero for the purposes of the calculation.
Wastes and residues, including tree tops and branches, straw, husks, cobs and nut shells, and residues from processing, including crude glycerine (glycerine that is not refined) and bagasse, shall be considered to have zero life-cycle greenhouse gas emissions up to the process of collection of those materials irrespectively of whether they are processed to interim products before being transformed into the final product.
In the case of fuels produced in refineries, other than the combination of processing plants with boilers or cogeneration units providing heat and/or electricity to the processing plant, the unit of analysis for the purposes of the calculation referred to in point 17 shall be the refinery.
19. For biofuels, for the purposes of the calculation referred to in point 3, the fossil fuel comparator EF(t) shall be 94 g CO2eq/MJ.
For bioliquids used for the production of electricity, for the purposes of the calculation referred to in point 3, the fossil fuel comparator ECF(e) shall be 183 g CO2eq/MJ.
For bioliquids used for the production of useful heat, as well as for the production of heating and/or cooling, for the purposes of the calculation referred to in point 3, the fossil fuel comparator ECF(h&c) shall be 80 g CO2eq/MJ.
D. DISAGGREGATED DEFAULT VALUES FOR BIOFUELS AND BIOLIQUIDS
Disaggregated default values for cultivation: ‘eec ’ as defined in Part C of this Annex, including soil N2O emissions
|
Biofuel and bioliquid production pathway |
Greenhouse gas emissions – typical value (g CO2eq/MJ) |
Greenhouse gas emissions – default value (g CO2eq/MJ) |
|
sugar beet ethanol |
9,6 |
9,6 |
|
corn (maize) ethanol |
25,5 |
25,5 |
|
other cereals excluding corn (maize) ethanol |
27,0 |
27,0 |
|
sugar cane ethanol |
17,1 |
17,1 |
|
the part from renewable sources of ETBE |
Equal to that of the ethanol production pathway used |
|
|
the part from renewable sources of TAEE |
Equal to that of the ethanol production pathway used |
|
|
rape seed biodiesel |
32,0 |
32,0 |
|
sunflower biodiesel |
26,1 |
26,1 |
|
soybean biodiesel |
21,2 |
21,2 |
|
palm oil biodiesel |
26,0 |
26,0 |
|
waste cooking oil biodiesel |
0 |
0 |
|
animal fats from rendering biodiesel (*1) |
0 |
0 |
|
hydrotreated vegetable oil from rape seed |
33,4 |
33,4 |
|
hydrotreated vegetable oil from sunflower |
26,9 |
26,9 |
|
hydrotreated vegetable oil from soybean |
22,1 |
22,1 |
|
hydrotreated vegetable oil from palm oil |
27,3 |
27,3 |
|
hydrotreated oil from waste cooking oil |
0 |
0 |
|
hydrotreated oil from animal fats from rendering (*1) |
0 |
0 |
|
pure vegetable oil from rape seed |
33,4 |
33,4 |
|
pure vegetable oil from sunflower |
27,2 |
27,2 |
|
pure vegetable oil from soybean |
22,2 |
22,2 |
|
pure vegetable oil from palm oil |
27,1 |
27,1 |
|
pure oil from waste cooking oil |
0 |
0 |
|
(*1)
Applies only to biofuels produced from animal by-products classified as category 1 and 2 material in accordance with Regulation (EC) No 1069/2009, for which emissions related to hygenisation as part of the rendering are not considered. |
||
Disaggregated default values for cultivation: ‘eec ’ – for soil N2O emissions only (these are already included in the disaggregated values for cultivation emissions in the ‘eec ’ table)
|
Biofuel and bioliquid production pathway |
Greenhouse gas emissions – typical value (g CO2eq/MJ) |
Greenhouse gas emissions – default value (g CO2eq/MJ) |
|
sugar beet ethanol |
4,9 |
4,9 |
|
corn (maize) ethanol |
13,7 |
13,7 |
|
other cereals excluding corn (maize) ethanol |
14,1 |
14,1 |
|
sugar cane ethanol |
2,1 |
2,1 |
|
the part from renewable sources of ETBE |
Equal to that of the ethanol production pathway used |
|
|
the part from renewable sources of TAEE |
Equal to that of the ethanol production pathway used |
|
|
rape seed biodiesel |
17,6 |
17,6 |
|
sunflower biodiesel |
12,2 |
12,2 |
|
soybean biodiesel |
13,4 |
13,4 |
|
palm oil biodiesel |
16,5 |
16,5 |
|
waste cooking oil biodiesel |
0 |
0 |
|
animal fats from rendering biodiesel (*1) |
0 |
0 |
|
hydrotreated vegetable oil from rape seed |
18,0 |
18,0 |
|
hydrotreated vegetable oil from sunflower |
12,5 |
12,5 |
|
hydrotreated vegetable oil from soybean |
13,7 |
13,7 |
|
hydrotreated vegetable oil from palm oil |
16,9 |
16,9 |
|
hydrotreated oil from waste cooking oil |
0 |
0 |
|
hydrotreated oil from animal fats from rendering (*1) |
0 |
0 |
|
pure vegetable oil from rape seed |
17,6 |
17,6 |
|
pure vegetable oil from sunflower |
12,2 |
12,2 |
|
pure vegetable oil from soybean |
13,4 |
13,4 |
|
pure vegetable oil from palm oil |
16,5 |
16,5 |
|
pure oil from waste cooking oil |
0 |
0 |
|
(*1)
Note: applies only to biofuels produced from animal by-products classified as category 1 and 2 material in accordance with Regulation (EC) No 1069/2009, for which emissions related to hygenisation as part of the rendering are not considered. |
||
Disaggregated default values for processing: ‘ep ’ as defined in Part C of this Annex
|
Biofuel and bioliquid production pathway |
Greenhouse gas emissions – typical value (g CO2eq/MJ) |
Greenhouse gas emissions – default value (g CO2eq/MJ) |
|
sugar beet ethanol (no biogas from slop, natural gas as process fuel in conventional boiler) |
18,8 |
26,3 |
|
sugar beet ethanol (with biogas from slop, natural gas as process fuel in conventional boiler) |
9,7 |
13,6 |
|
sugar beet ethanol (no biogas from slop, natural gas as process fuel in CHP plant (*1)) |
13,2 |
18,5 |
|
sugar beet ethanol (with biogas from slop, natural gas as process fuel in CHP plant (*1)) |
7,6 |
10,6 |
|
sugar beet ethanol (no biogas from slop, lignite as process fuel in CHP plant (*1)) |
27,4 |
38,3 |
|
sugar beet ethanol (with biogas from slop, lignite as process fuel in CHP plant (*1)) |
15,7 |
22,0 |
|
corn (maize) ethanol (natural gas as process fuel in conventional boiler) |
20,8 |
29,1 |
|
corn (maize) ethanol, (natural gas as process fuel in CHP plant (*1)) |
14,8 |
20,8 |
|
corn (maize) ethanol (lignite as process fuel in CHP plant (*1)) |
28,6 |
40,1 |
|
corn (maize) ethanol (forest residues as process fuel in CHP plant (*1)) |
1,8 |
2,6 |
|
other cereals excluding maize ethanol (natural gas as process fuel in conventional boiler) |
21,0 |
29,3 |
|
other cereals excluding maize ethanol (natural gas as process fuel in CHP plant (*1)) |
15,1 |
21,1 |
|
other cereals excluding maize ethanol (lignite as process fuel in CHP plant (*1)) |
30,3 |
42,5 |
|
other cereals excluding maize ethanol (forest residues as process fuel in CHP plant (*1)) |
1,5 |
2,2 |
|
sugar cane ethanol |
1,3 |
1,8 |
|
the part from renewable sources of ETBE |
Equal to that of the ethanol production pathway used |
|
|
the part from renewable sources of TAEE |
Equal to that of the ethanol production pathway used |
|
|
rape seed biodiesel |
11,7 |
16,3 |
|
sunflower biodiesel |
11,8 |
16,5 |
|
soybean biodiesel |
12,1 |
16,9 |
|
palm oil biodiesel (open effluent pond) |
30,4 |
42,6 |
|
palm oil biodiesel (process with methane capture at oil mill) |
13,2 |
18,5 |
|
waste cooking oil biodiesel |
9,3 |
13,0 |
|
animal fats from rendering biodiesel (*2) |
13,6 |
19,1 |
|
hydrotreated vegetable oil from rape seed |
10,7 |
15,0 |
|
hydrotreated vegetable oil from sunflower |
10,5 |
14,7 |
|
hydrotreated vegetable oil from soybean |
10,9 |
15,2 |
|
hydrotreated vegetable oil from palm oil (open effluent pond) |
27,8 |
38,9 |
|
hydrotreated vegetable oil from palm oil (process with methane capture at oil mill) |
9,7 |
13,6 |
|
hydrotreated oil from waste cooking oil |
10,2 |
14,3 |
|
hydrotreated oil from animal fats from rendering (*2) |
14,5 |
20,3 |
|
pure vegetable oil from rape seed |
3,7 |
5,2 |
|
pure vegetable oil from sunflower |
3,8 |
5,4 |
|
pure vegetable oil from soybean |
4,2 |
5,9 |
|
pure vegetable oil from palm oil (open effluent pond) |
22,6 |
31,7 |
|
pure vegetable oil from palm oil (process with methane capture at oil mill) |
4,7 |
6,5 |
|
pure oil from waste cooking oil |
0,6 |
0,8 |
|
(*1)
Default values for processes using CHP are valid only if all the process heat is supplied by CHP.
(*2)
Note: applies only to biofuels produced from animal by-products classified as category 1 and 2 material in accordance with Regulation (EC) No 1069/2009, for which emissions related to hygenisation as part of the rendering are not considered. |
||
Disaggregated default values for oil extraction only (these are already included in the disaggregated values for processing emissions in the ‘ep ’ table)
|
Biofuel and bioliquid production pathway |
Greenhouse gas emissions – typical value (g CO2eq/MJ) |
Greenhouse gas emissions – default value (g CO2eq/MJ) |
|
rape seed biodiesel |
3,0 |
4,2 |
|
sunflower biodiesel |
2,9 |
4,0 |
|
soybean biodiesel |
3,2 |
4,4 |
|
palm oil biodiesel (open effluent pond) |
20,9 |
29,2 |
|
palm oil biodiesel (process with methane capture at oil mill) |
3,7 |
5,1 |
|
waste cooking oil biodiesel |
0 |
0 |
|
animal fats from rendering biodiesel (*1) |
4,3 |
6,1 |
|
hydrotreated vegetable oil from rape seed |
3,1 |
4,4 |
|
hydrotreated vegetable oil from sunflower |
3,0 |
4,1 |
|
hydrotreated vegetable oil from soybean |
3,3 |
4,6 |
|
hydrotreated vegetable oil from palm oil (open effluent pond) |
21,9 |
30,7 |
|
hydrotreated vegetable oil from palm oil (process with methane capture at oil mill) |
3,8 |
5,4 |
|
hydrotreated oil from waste cooking oil |
0 |
0 |
|
hydrotreated oil from animal fats from rendering (*1) |
4,3 |
6,0 |
|
pure vegetable oil from rape seed |
3,1 |
4,4 |
|
pure vegetable oil from sunflower |
3,0 |
4,2 |
|
pure vegetable oil from soybean |
3,4 |
4,7 |
|
pure vegetable oil from palm oil (open effluent pond) |
21,8 |
30,5 |
|
pure vegetable oil from palm oil (process with methane capture at oil mill) |
3,8 |
5,3 |
|
pure oil from waste cooking oil |
0 |
0 |
|
(*1)
Note: applies only to biofuels produced from animal by-products classified as category 1 and 2 material in accordance with Regulation (EC) No 1069/2009, for which emissions related to hygenisation as part of the rendering are not considered. |
||
Disaggregated default values for transport and distribution: ‘etd ’ as defined in Part C of this Annex
|
Biofuel and bioliquid production pathway |
Greenhouse gas emissions – typical value (g CO2eq/MJ) |
Greenhouse gas emissions – default value (g CO2eq/MJ) |
|
sugar beet ethanol (no biogas from slop, natural gas as process fuel in conventional boiler) |
2,3 |
2,3 |
|
sugar beet ethanol (with biogas from slop, natural gas as process fuel in conventional boiler) |
2,3 |
2,3 |
|
sugar beet ethanol (no biogas from slop, natural gas as process fuel in CHP plant (*1)) |
2,3 |
2,3 |
|
sugar beet ethanol (with biogas from slop, natural gas as process fuel in CHP plant (*1)) |
2,3 |
2,3 |
|
sugar beet ethanol (no biogas from slop, lignite as process fuel in CHP plant (*1)) |
2,3 |
2,3 |
|
sugar beet ethanol (with biogas from slop, lignite as process fuel in CHP plant (*1)) |
2,3 |
2,3 |
|
corn (maize) ethanol (natural gas as process fuel in CHP plant (*1)) |
2,2 |
2,2 |
|
corn (maize) ethanol (natural gas as process fuel in conventional boiler) |
2,2 |
2,2 |
|
corn (maize) ethanol (lignite as process fuel in CHP plant (*1)) |
2,2 |
2,2 |
|
corn (maize) ethanol (forest residues as process fuel in CHP plant (*1)) |
2,2 |
2,2 |
|
other cereals excluding maize ethanol (natural gas as process fuel in conventional boiler) |
2,2 |
2,2 |
|
other cereals excluding maize ethanol (natural gas as process fuel in CHP plant (*1)) |
2,2 |
2,2 |
|
other cereals excluding maize ethanol (lignite as process fuel in CHP plant (*1)) |
2,2 |
2,2 |
|
other cereals excluding maize ethanol (forest residues as process fuel in CHP plant (*1)) |
2,2 |
2,2 |
|
sugar cane ethanol |
9,7 |
9,7 |
|
the part from renewable sources of ETBE |
Equal to that of the ethanol production pathway used |
|
|
the part from renewable sources of TAEE |
Equal to that of the ethanol production pathway used |
|
|
rape seed biodiesel |
1,8 |
1,8 |
|
sunflower biodiesel |
2,1 |
2,1 |
|
soybean biodiesel |
8,9 |
8,9 |
|
palm oil biodiesel (open effluent pond) |
6,9 |
6,9 |
|
palm oil biodiesel (process with methane capture at oil mill) |
6,9 |
6,9 |
|
waste cooking oil biodiesel |
1,9 |
1,9 |
|
animal fats from rendering biodiesel (*1) |
1,6 |
1,6 |
|
hydrotreated vegetable oil from rape seed |
1,7 |
1,7 |
|
hydrotreated vegetable oil from sunflower |
2,0 |
2,0 |
|
hydrotreated vegetable oil from soybean |
9,2 |
9,2 |
|
hydrotreated vegetable oil from palm oil (open effluent pond) |
7,0 |
7,0 |
|
hydrotreated vegetable oil from palm oil (process with methane capture at oil mill) |
7,0 |
7,0 |
|
hydrotreated oil from waste cooking oil |
1,7 |
1,7 |
|
hydrotreated oil from animal fats from rendering (*2) |
1,5 |
1,5 |
|
pure vegetable oil from rape seed |
1,4 |
1,4 |
|
pure vegetable oil from sunflower |
1,7 |
1,7 |
|
pure vegetable oil from soybean |
8,8 |
8,8 |
|
pure vegetable oil from palm oil (open effluent pond) |
6,7 |
6,7 |
|
pure vegetable oil from palm oil (process with methane capture at oil mill) |
6,7 |
6,7 |
|
pure oil from waste cooking oil |
1,4 |
1,4 |
|
(*1)
Default values for processes using CHP are valid only if all the process heat is supplied by CHP.
(*2)
Note: applies only to biofuels produced from animal by-products classified as category 1 and 2 material in accordance with Regulation (EC) No 1069/2009, for which emissions related to hygenisation as part of the rendering are not considered. |
||
Disaggregated default values for transport and distribution of final fuel only. These are already included in the table of ‘transport and distribution emissions etd ’ as defined in Part C of this Annex, but the following values are useful if an economic operator wishes to declare actual transport emissions for crops or oil transport only).
|
Biofuel and bioliquid production pathway |
Greenhouse gas emissions – typical value (g CO2eq/MJ) |
Greenhouse gas emissions – default value (g CO2eq/MJ) |
|
sugar beet ethanol (no biogas from slop, natural gas as process fuel in conventional boiler) |
1,6 |
1,6 |
|
sugar beet ethanol (with biogas from slop, natural gas as process fuel in conventional boiler) |
1,6 |
1,6 |
|
sugar beet ethanol (no biogas from slop, natural gas as process fuel in CHP plant (*1)) |
1,6 |
1,6 |
|
sugar beet ethanol (with biogas from slop, natural gas as process fuel in CHP plant (*1)) |
1,6 |
1,6 |
|
sugar beet ethanol (no biogas from slop, lignite as process fuel in CHP plant (*1)) |
1,6 |
1,6 |
|
sugar beet ethanol (with biogas from slop, lignite as process fuel in CHP plant (*1)) |
1,6 |
1,6 |
|
corn (maize) ethanol (natural gas as process fuel in conventional boiler) |
1,6 |
1,6 |
|
corn (maize) ethanol (natural gas as process fuel in CHP plant (*1)) |
1,6 |
1,6 |
|
corn (maize) ethanol (lignite as process fuel in CHP plant (*1)) |
1,6 |
1,6 |
|
corn (maize) ethanol (forest residues as process fuel in CHP plant (*1)) |
1,6 |
1,6 |
|
other cereals excluding maize ethanol (natural gas as process fuel in conventional boiler) |
1,6 |
1,6 |
|
other cereals excluding maize ethanol (natural gas as process fuel in CHP plant (*1)) |
1,6 |
1,6 |
|
other cereals excluding maize ethanol (lignite as process fuel in CHP plant (*1)) |
1,6 |
1,6 |
|
other cereals excluding maize ethanol (forest residues as process fuel in CHP plant (*1)) |
1,6 |
1,6 |
|
sugar cane ethanol |
6,0 |
6,0 |
|
the part of ethyl-tertio-butyl-ether (ETBE) from renewable ethanol |
Will be considered to be equal to that of the ethanol production pathway used |
|
|
the part of tertiary-amyl-ethyl-ether (TAEE) from renewable ethanol |
Will be considered to be equal to that of the ethanol production pathway used |
|
|
rape seed biodiesel |
1,3 |
1,3 |
|
sunflower biodiesel |
1,3 |
1,3 |
|
soybean biodiesel |
1,3 |
1,3 |
|
palm oil biodiesel (open effluent pond) |
1,3 |
1,3 |
|
palm oil biodiesel (process with methane capture at oil mill) |
1,3 |
1,3 |
|
waste cooking oil biodiesel |
1,3 |
1,3 |
|
animal fats from rendering biodiesel (*2) |
1,3 |
1,3 |
|
hydrotreated vegetable oil from rape seed |
1,2 |
1,2 |
|
hydrotreated vegetable oil from sunflower |
1,2 |
1,2 |
|
hydrotreated vegetable oil from soybean |
1,2 |
1,2 |
|
hydrotreated vegetable oil from palm oil (open effluent pond) |
1,2 |
1,2 |
|
hydrotreated vegetable oil from palm oil (process with methane capture at oil mill) |
1,2 |
1,2 |
|
hydrotreated oil from waste cooking oil |
1,2 |
1,2 |
|
hydrotreated oil from animal fats from rendering (*2) |
1,2 |
1,2 |
|
pure vegetable oil from rape seed |
0,8 |
0,8 |
|
pure vegetable oil from sunflower |
0,8 |
0,8 |
|
pure vegetable oil from soybean |
0,8 |
0,8 |
|
pure vegetable oil from palm oil (open effluent pond) |
0,8 |
0,8 |
|
pure vegetable oil from palm oil (process with methane capture at oil mill) |
0,8 |
0,8 |
|
pure oil from waste cooking oil |
0,8 |
0,8 |
|
(*1)
Default values for processes using CHP are valid only if all the process heat is supplied by CHP.
(*2)
Note: applies only to biofuels produced from animal by-products classified as category 1 and 2 material in accordance with Regulation (EC) No 1069/2009, for which emissions related to hygenisation as part of the rendering are not considered. |
||
Total for cultivation, processing, transport and distribution
|
Biofuel and bioliquid production pathway |
Greenhouse gas emissions – typical value (g CO2eq/MJ) |
Greenhouse gas emissions – default value (g CO2eq/MJ) |
|
sugar beet ethanol (no biogas from slop, natural gas as process fuel in conventional boiler) |
30,7 |
38,2 |
|
sugar beet ethanol (with biogas from slop, natural gas as process fuel in conventional boiler) |
21,6 |
25,5 |
|
sugar beet ethanol (no biogas from slop, natural gas as process fuel in CHP plant (*1)) |
25,1 |
30,4 |
|
sugar beet ethanol (with biogas from slop, natural gas as process fuel in CHP plant (*1)) |
19,5 |
22,5 |
|
sugar beet ethanol (no biogas from slop, lignite as process fuel in CHP plant (*1)) |
39,3 |
50,2 |
|
sugar beet ethanol (with biogas from slop, lignite as process fuel in CHP plant (*1)) |
27,6 |
33,9 |
|
corn (maize) ethanol (natural gas as process fuel in conventional boiler) |
48,5 |
56,8 |
|
corn (maize) ethanol, (natural gas as process fuel in CHP plant (*1)) |
42,5 |
48,5 |
|
corn (maize) ethanol (lignite as process fuel in CHP plant (*1)) |
56,3 |
67,8 |
|
corn (maize) ethanol (forest residues as process fuel in CHP plant (*1)) |
29,5 |
30,3 |
|
other cereals excluding maize ethanol (natural gas as process fuel in conventional boiler) |
50,2 |
58,5 |
|
other cereals excluding maize ethanol (natural gas as process fuel in CHP plant (*1)) |
44,3 |
50,3 |
|
other cereals excluding maize ethanol (lignite as process fuel in CHP plant (*1)) |
59,5 |
71,7 |
|
other cereals excluding maize ethanol (forest residues as process fuel in CHP plant (*1) |
30,7 |
31,4 |
|
sugar cane ethanol |
28,1 |
28,6 |
|
the part from renewable sources of ETBE |
Equal to that of the ethanol production pathway used |
|
|
the part from renewable sources of TAEE |
Equal to that of the ethanol production pathway used |
|
|
rape seed biodiesel |
45,5 |
50,1 |
|
sunflower biodiesel |
40,0 |
44,7 |
|
soybean biodiesel |
42,2 |
47,0 |
|
palm oil biodiesel (open effluent pond) |
63,3 |
75,5 |
|
palm oil biodiesel (process with methane capture at oil mill) |
46,1 |
51,4 |
|
waste cooking oil biodiesel |
11,2 |
14,9 |
|
animals fats from rendering biodiesel (*1) |
15,2 |
20,7 |
|
hydrotreated vegetable oil from rape seed |
45,8 |
50,1 |
|
hydrotreated vegetable oil from sunflower |
39,4 |
43,6 |
|
hydrotreated vegetable oil from soybean |
42,2 |
46,5 |
|
hydrotreated vegetable oil from palm oil (open effluent pond) |
62,1 |
73,2 |
|
hydrotreated vegetable oil from palm oil (process with methane capture at oil mill) |
44,0 |
47,9 |
|
hydrotreated oil from waste cooking oil |
11,9 |
16,0 |
|
hydrotreated oil from animal fats from rendering (*2) |
16,0 |
21,8 |
|
pure vegetable oil from rape seed |
38,5 |
40,0 |
|
pure vegetable oil from sunflower |
32,7 |
34,3 |
|
pure vegetable oil from soybean |
35,2 |
36,9 |
|
pure vegetable oil from palm oil (open effluent pond) |
56,4 |
65,5 |
|
pure vegetable oil from palm oil (process with methane capture at oil mill) |
38,5 |
40,3 |
|
pure oil from waste cooking oil |
2,0 |
2,2 |
|
(*1)
Default values for processes using CHP are valid only if all the process heat is supplied by CHP.
(*2)
Note: applies only to biofuels produced from animal by-products classified as category 1 and 2 material in accordance with Regulation (EC) No 1069/2009, for which emissions related to hygenisation as part of the rendering are not considered. |
||
E. ESTIMATED DISAGGREGATED DEFAULT VALUES FOR FUTURE BIOFUELS AND BIOLIQUIDS THAT WERE NOT ON THE MARKET OR WERE ONLY ON THE MARKET IN NEGLIGIBLE QUANTITIES IN 2016
Disaggregated default values for cultivation: ‘eec ’ as defined in Part C of this Annex, including N2O emissions (including chipping of waste or farmed wood)
|
Biofuel and bioliquid production pathway |
Greenhouse gas emissions – typical value (g CO2eq/MJ) |
Greenhouse gas emissions – default value (g CO2eq/MJ) |
|
wheat straw ethanol |
1,8 |
1,8 |
|
waste wood Fischer-Tropsch diesel in free-standing plant |
3,3 |
3,3 |
|
farmed wood Fischer-Tropsch diesel in free-standing plant |
8,2 |
8,2 |
|
waste wood Fischer-Tropsch petrol in free-standing plant |
3,3 |
3,3 |
|
farmed wood Fischer-Tropsch petrol in free-standing plant |
8,2 |
8,2 |
|
waste wood dimethylether (DME) in free-standing plant |
3,1 |
3,1 |
|
farmed wood dimethylether (DME) in free-standing plant |
7,6 |
7,6 |
|
waste wood methanol in free-standing plant |
3,1 |
3,1 |
|
farmed wood methanol in free-standing plant |
7,6 |
7,6 |
|
Fischer-Tropsch diesel from black-liquor gasification integrated with pulp mill |
2,5 |
2,5 |
|
Fischer-Tropsch petrol from black-liquor gasification integrated with pulp mill |
2,5 |
2,5 |
|
dimethylether (DME) from black-liquor gasification integrated with pulp mill |
2,5 |
2,5 |
|
Methanol from black-liquor gasification integrated with pulp mill |
2,5 |
2,5 |
|
the part from renewable sources of MTBE |
Equal to that of the methanol production pathway used |
|
Disaggregated default values for soil N2O emissions (included in disaggregated default values for cultivation emissions in the ‘eec ’ table)
|
Biofuel and bioliquid production pathway |
Greenhouse gas emissions – typical value (g CO2eq/MJ) |
Greenhouse gas emissions – default value (g CO2eq/MJ) |
|
wheat straw ethanol |
0 |
0 |
|
waste wood Fischer-Tropsch diesel in free-standing plant |
0 |
0 |
|
farmed wood Fischer-Tropsch diesel in free-standing plant |
4,4 |
4,4 |
|
waste wood Fischer-Tropsch petrol in free-standing plant |
0 |
0 |
|
farmed wood Fischer-Tropsch petrol in free-standing plant |
4,4 |
4,4 |
|
waste wood dimethylether (DME) in free-standing plant |
0 |
0 |
|
farmed wood dimethylether (DME) in free-standing plant |
4,1 |
4,1 |
|
waste wood methanol in free-standing plant |
0 |
0 |
|
farmed wood methanol in free-standing plant |
4,1 |
4,1 |
|
Fischer-Tropsch diesel from black-liquor gasification integrated with pulp mill |
0 |
0 |
|
Fischer-Tropsch petrol from black-liquor gasification integrated with pulp mill |
0 |
0 |
|
dimethylether (DME) from black-liquor gasification integrated with pulp mill |
0 |
0 |
|
Methanol from black-liquor gasification integrated with pulp mill |
0 |
0 |
|
the part from renewable sources of MTBE |
Equal to that of the methanol production pathway used |
|
Disaggregated default values for processing: ‘ep ’ as defined in Part C of this Annex
|
Biofuel and bioliquid production pathway |
Greenhouse gas emissions – typical value (g CO2eq/MJ) |
Greenhouse gas emissions – default value (g CO2eq/MJ) |
|
wheat straw ethanol |
4,8 |
6,8 |
|
waste wood Fischer-Tropsch diesel in free-standing plant |
0,1 |
0,1 |
|
farmed wood Fischer-Tropsch diesel in free-standing plant |
0,1 |
0,1 |
|
waste wood Fischer-Tropsch petrol in free-standing plant |
0,1 |
0,1 |
|
farmed wood Fischer-Tropsch petrol in free-standing plant |
0,1 |
0,1 |
|
waste wood dimethylether (DME) in free-standing plant |
0 |
0 |
|
farmed wood dimethylether (DME) in free-standing plant |
0 |
0 |
|
waste wood methanol in free-standing plant |
0 |
0 |
|
farmed wood methanol in free-standing plant |
0 |
0 |
|
Fischer-Tropsch diesel from black-liquor gasification integrated with pulp mill |
0 |
0 |
|
Fischer-Tropsch petrol from black-liquor gasification integrated with pulp mill |
0 |
0 |
|
dimethylether (DME) from black-liquor gasification integrated with pulp mill |
0 |
0 |
|
methanol from black-liquor gasification integrated with pulp mill |
0 |
0 |
|
the part from renewable sources of MTBE |
Equal to that of the methanol production pathway used |
|
Disaggregated default values for transport and distribution: ‘etd ’ as defined in Part C of this Annex
|
Biofuel and bioliquid production pathway |
Greenhouse gas emissions – typical value (g CO2eq/MJ) |
Greenhouse gas emissions – default value (g CO2eq/MJ) |
|
wheat straw ethanol |
7,1 |
7,1 |
|
waste wood Fischer-Tropsch diesel in free-standing plant |
12,2 |
12,2 |
|
farmed wood Fischer-Tropsch diesel in free-standing plant |
8,4 |
8,4 |
|
waste wood Fischer-Tropsch petrol in free-standing plant |
12,2 |
12,2 |
|
farmed wood Fischer-Tropsch petrol in free-standing plant |
8,4 |
8,4 |
|
waste wood dimethylether (DME) in free-standing plant |
12,1 |
12,1 |
|
farmed wood dimethylether (DME) in free-standing plant |
8,6 |
8,6 |
|
waste wood methanol in free-standing plant |
12,1 |
12,1 |
|
farmed wood methanol in free-standing plant |
8,6 |
8,6 |
|
Fischer-Tropsch diesel from black-liquor gasification integrated with pulp mill |
7,7 |
7,7 |
|
Fischer-Tropsch petrol from black-liquor gasification integrated with pulp mill |
7,9 |
7,9 |
|
dimethylether (DME) from black-liquor gasification integrated with pulp mill |
7,7 |
7,7 |
|
methanol from black-liquor gasification integrated with pulp mill |
7,9 |
7,9 |
|
the part from renewable sources of MTBE |
Equal to that of the methanol production pathway used |
|
Disaggregated default values for transport and distribution of final fuel only. These are already included in the table of ‘transport and distribution emissions etd ’ as defined in Part C of this Annex, but the following values are useful if an economic operator wishes to declare actual transport emissions for feedstock transport only).
|
Biofuel and bioliquid production pathway |
Greenhouse gas emissions – typical value (g CO2eq/MJ) |
Greenhouse gas emissions – default value (g CO2eq/MJ) |
|
wheat straw ethanol |
1,6 |
1,6 |
|
waste wood Fischer-Tropsch diesel in free-standing plant |
1,2 |
1,2 |
|
farmed wood Fischer-Tropsch diesel in free-standing plant |
1,2 |
1,2 |
|
waste wood Fischer-Tropsch petrol in free-standing plant |
1,2 |
1,2 |
|
farmed wood Fischer-Tropsch petrol in free-standing plant |
1,2 |
1,2 |
|
waste wood dimethylether (DME) in free-standing plant |
2,0 |
2,0 |
|
farmed wood dimethylether (DME) in free-standing plant |
2,0 |
2,0 |
|
waste wood methanol in free-standing plant |
2,0 |
2,0 |
|
farmed wood methanol in free-standing plant |
2,0 |
2,0 |
|
Fischer-Tropsch diesel from black-liquor gasification integrated with pulp mill |
2,0 |
2,0 |
|
Fischer-Tropsch petrol from black-liquor gasification integrated with pulp mill |
2,0 |
2,0 |
|
dimethylether (DME) from black-liquor gasification integrated with pulp mill |
2,0 |
2,0 |
|
methanol from black-liquor gasification integrated with pulp mill |
2,0 |
2,0 |
|
the part from renewable sources of MTBE |
Equal to that of the methanol production pathway used |
|
Total for cultivation, processing, transport and distribution
|
Biofuel and bioliquid production pathway |
Greenhouse gas emissions – typical value (g CO2eq/MJ) |
Greenhouse gas emissions – default value (g CO2eq/MJ) |
|
wheat straw ethanol |
13,7 |
15,7 |
|
waste wood Fischer-Tropsch diesel in free-standing plant |
15,6 |
15,6 |
|
farmed wood Fischer-Tropsch diesel in free-standing plant |
16,7 |
16,7 |
|
waste wood Fischer-Tropsch petrol in free-standing plant |
15,6 |
15,6 |
|
farmed wood Fischer-Tropsch petrol in free-standing plant |
16,7 |
16,7 |
|
waste wood dimethylether (DME) in free-standing plant |
15,2 |
15,2 |
|
farmed wood dimethylether (DME) in free-standing plant |
16,2 |
16,2 |
|
waste wood methanol in free-standing plant |
15,2 |
15,2 |
|
farmed wood methanol in free-standing plant |
16,2 |
16,2 |
|
Fischer-Tropsch diesel from black-liquor gasification integrated with pulp mill |
10,2 |
10,2 |
|
Fischer-Tropsch petrol from black-liquor gasification integrated with pulp mill |
10,4 |
10,4 |
|
dimethylether (DME) from black-liquor gasification integrated with pulp mill |
10,2 |
10,2 |
|
methanol from black-liquor gasification integrated with pulp mill |
10,4 |
10,4 |
|
the part from renewable sources of MTBE |
Equal to that of the methanol production pathway used |
|
ANNEX VI
RULES FOR CALCULATING THE GREENHOUSE GAS IMPACT OF BIOMASS FUELS AND THEIR FOSSIL FUEL COMPARATORS
A. Typical and default values of greenhouse gas emissions savings for biomass fuels if produced with no net-carbon emissions from land-use change
|
WOODCHIPS |
|||||
|
Biomass fuel production system |
Transport distance |
Greenhouse gas emissions savings –typical value |
Greenhouse gas emissions savings – default value |
||
|
Heat |
Electricity |
Heat |
Electricity |
||
|
Woodchips from forest residues |
1 to 500 km |
93 % |
89 % |
91 % |
87 % |
|
500 to 2 500 km |
89 % |
84 % |
87 % |
81 % |
|
|
2 500 to 10 000 km |
82 % |
73 % |
78 % |
67 % |
|
|
Above 10 000 km |
67 % |
51 % |
60 % |
41 % |
|
|
Woodchips from short rotation coppice (Eucalyptus) |
2 500 to 10 000 km |
77 % |
65 % |
73 % |
60 % |
|
Woodchips from short rotation coppice (Poplar – Fertilised) |
1 to 500 km |
89 % |
83 % |
87 % |
81 % |
|
500 to 2 500 km |
85 % |
78 % |
84 % |
76 % |
|
|
2 500 to 10 000 km |
78 % |
67 % |
74 % |
62 % |
|
|
Above 10 000 km |
63 % |
45 % |
57 % |
35 % |
|
|
Woodchips from short rotation coppice (Poplar – No fertilisation) |
1 to 500 km |
91 % |
87 % |
90 % |
85 % |
|
500 to 2 500 km |
88 % |
82 % |
86 % |
79 % |
|
|
2 500 to 10 000 km |
80 % |
70 % |
77 % |
65 % |
|
|
Above 10 000 km |
65 % |
48 % |
59 % |
39 % |
|
|
Woodchips from stemwood |
1 to 500 km |
93 % |
89 % |
92 % |
88 % |
|
500 to 2 500 km |
90 % |
85 % |
88 % |
82 % |
|
|
2 500 to 10 000 km |
82 % |
73 % |
79 % |
68 % |
|
|
Above 10 000 km |
67 % |
51 % |
61 % |
42 % |
|
|
Woodchips from industry residues |
1 to 500 km |
94 % |
92 % |
93 % |
90 % |
|
500 to 2 500 km |
91 % |
87 % |
90 % |
85 % |
|
|
2 500 to 10 000 km |
83 % |
75 % |
80 % |
71 % |
|
|
Above 10 000 km |
69 % |
54 % |
63 % |
44 % |
|
|
WOOD PELLETS (*1) |
||||||
|
Biomass fuel production system |
Transport distance |
Greenhouse gas emissions savings – typical value |
Greenhouse gas emissions savings – default value |
|||
|
Heat |
Electricity |
Heat |
Electricity |
|||
|
Wood briquettes or pellets from forest residues |
Case 1 |
1 to 500 km |
58 % |
37 % |
49 % |
24 % |
|
500 to 2 500 km |
58 % |
37 % |
49 % |
25 % |
||
|
2 500 to 10 000 km |
55 % |
34 % |
47 % |
21 % |
||
|
Above 10 000 km |
50 % |
26 % |
40 % |
11 % |
||
|
Case 2a |
1 to 500 km |
77 % |
66 % |
72 % |
59 % |
|
|
500 to 2 500 km |
77 % |
66 % |
72 % |
59 % |
||
|
2 500 to 10 000 km |
75 % |
62 % |
70 % |
55 % |
||
|
Above 10 000 km |
69 % |
54 % |
63 % |
45 % |
||
|
Case 3a |
1 to 500 km |
92 % |
88 % |
90 % |
85 % |
|
|
500 to 2 500 km |
92 % |
88 % |
90 % |
86 % |
||
|
2 500 to 10 000 km |
90 % |
85 % |
88 % |
81 % |
||
|
Above 10 000 km |
84 % |
76 % |
81 % |
72 % |
||
|
Wood briquettes or pellets from short rotation coppice (Eucalyptus) |
Case 1 |
2 500 to 10 000 km |
52 % |
28 % |
43 % |
15 % |
|
Case 2a |
2 500 to 10 000 km |
70 % |
56 % |
66 % |
49 % |
|
|
Case 3a |
2 500 to 10 000 km |
85 % |
78 % |
83 % |
75 % |
|
|
Wood briquettes or pellets from short rotation coppice (Poplar – Fertilised) |
Case 1 |
1 to 500 km |
54 % |
32 % |
46 % |
20 % |
|
500 to 10 000 km |
52 % |
29 % |
44 % |
16 % |
||
|
Above 10 000 km |
47 % |
21 % |
37 % |
7 % |
||
|
Case 2a |
1 to 500 km |
73 % |
60 % |
69 % |
54 % |
|
|
500 to 10 000 km |
71 % |
57 % |
67 % |
50 % |
||
|
Above 10 000 km |
66 % |
49 % |
60 % |
41 % |
||
|
Case 3a |
1 to 500 km |
88 % |
82 % |
87 % |
81 % |
|
|
500 to 10 000 km |
86 % |
79 % |
84 % |
77 % |
||
|
Above 10 000 km |
80 % |
71 % |
78 % |
67 % |
||
|
Wood briquettes or pellets from short rotation coppice (Poplar – No fertilisation) |
Case 1 |
1 to 500 km |
56 % |
35 % |
48 % |
23 % |
|
500 to 10 000 km |
54 % |
32 % |
46 % |
20 % |
||
|
Above 10 000 km |
49 % |
24 % |
40 % |
10 % |
||
|
Case 2a |
1 to 500 km |
76 % |
64 % |
72 % |
58 % |
|
|
500 to 10 000 km |
74 % |
61 % |
69 % |
54 % |
||
|
Above 10 000 km |
68 % |
53 % |
63 % |
45 % |
||
|
Case 3a |
1 to 500 km |
91 % |
86 % |
90 % |
85 % |
|
|
500 to 10 000 km |
89 % |
83 % |
87 % |
81 % |
||
|
Above 10 000 km |
83 % |
75 % |
81 % |
71 % |
||
|
Stemwood |
Case 1 |
1 to 500 km |
57 % |
37 % |
49 % |
24 % |
|
500 to 2 500 km |
58 % |
37 % |
49 % |
25 % |
||
|
2 500 to 10 000 km |
55 % |
34 % |
47 % |
21 % |
||
|
Above 10 000 km |
50 % |
26 % |
40 % |
11 % |
||
|
Case 2a |
1 to 500 km |
77 % |
66 % |
73 % |
60 % |
|
|
500 to 2 500 km |
77 % |
66 % |
73 % |
60 % |
||
|
2 500 to 10 000 km |
75 % |
63 % |
70 % |
56 % |
||
|
Above 10 000 km |
70 % |
55 % |
64 % |
46 % |
||
|
Case 3a |
1 to 500 km |
92 % |
88 % |
91 % |
86 % |
|
|
500 to 2 500 km |
92 % |
88 % |
91 % |
87 % |
||
|
2 500 to 10 000 km |
90 % |
85 % |
88 % |
83 % |
||
|
Above 10 000 km |
84 % |
77 % |
82 % |
73 % |
||
|
Wood briquettes or pellets from wood industry residues |
Case 1 |
1 to 500 km |
75 % |
62 % |
69 % |
55 % |
|
500 to 2 500 km |
75 % |
62 % |
70 % |
55 % |
||
|
2 500 to 10 000 km |
72 % |
59 % |
67 % |
51 % |
||
|
Above 10 000 km |
67 % |
51 % |
61 % |
42 % |
||
|
Case 2a |
1 to 500 km |
87 % |
80 % |
84 % |
76 % |
|
|
500 to 2 500 km |
87 % |
80 % |
84 % |
77 % |
||
|
2 500 to 10 000 km |
85 % |
77 % |
82 % |
73 % |
||
|
Above 10 000 km |
79 % |
69 % |
75 % |
63 % |
||
|
Case 3a |
1 to 500 km |
95 % |
93 % |
94 % |
91 % |
|
|
500 to 2 500 km |
95 % |
93 % |
94 % |
92 % |
||
|
2 500 to 10 000 km |
93 % |
90 % |
92 % |
88 % |
||
|
Above 10 000 km |
88 % |
82 % |
85 % |
78 % |
||
|
(*1)
Case 1 refers to processes in which a natural gas boiler is used to provide the process heat to the pellet mill. Electricity for the pellet mill is supplied from the grid; Case 2a refers to processes in which a woodchips boiler, fed with pre-dried chips, is used to provide process heat. Electricity for the pellet mill is supplied from the grid; Case 3a refers to processes in which a CHP, fed with pre-dried woodchips, is used to provide electricity and heat to the pellet mill. |
||||||
|
AGRICULTURE PATHWAYS |
|||||
|
Biomass fuel production system |
Transport distance |
Greenhouse gas emissions savings – typical value |
Greenhouse gas emissions savings – default value |
||
|
Heat |
Electricity |
Heat |
Electricity |
||
|
Agricultural Residues with density < 0,2 t/m3 (*1) |
1 to 500 km |
95 % |
92 % |
93 % |
90 % |
|
500 to 2 500 km |
89 % |
83 % |
86 % |
80 % |
|
|
2 500 to 10 000 km |
77 % |
66 % |
73 % |
60 % |
|
|
Above 10 000 km |
57 % |
36 % |
48 % |
23 % |
|
|
Agricultural Residues with density > 0,2 t/m3 (*2) |
1 to 500 km |
95 % |
92 % |
93 % |
90 % |
|
500 to 2 500 km |
93 % |
89 % |
92 % |
87 % |
|
|
2 500 to 10 000 km |
88 % |
82 % |
85 % |
78 % |
|
|
Above 10 000 km |
78 % |
68 % |
74 % |
61 % |
|
|
Straw pellets |
1 to 500 km |
88 % |
82 % |
85 % |
78 % |
|
500 to 10 000 km |
86 % |
79 % |
83 % |
74 % |
|
|
Above 10 000 km |
80 % |
70 % |
76 % |
64 % |
|
|
Bagasse briquettes |
500 to 10 000 km |
93 % |
89 % |
91 % |
87 % |
|
Above 10 000 km |
87 % |
81 % |
85 % |
77 % |
|
|
Palm Kernel Meal |
Above 10 000 km |
20 % |
-18 % |
11 % |
-33 % |
|
Palm Kernel Meal (no CH4 emissions from oil mill) |
Above 10 000 km |
46 % |
20 % |
42 % |
14 % |
|
(*1)
This group of materials includes agricultural residues with a low bulk density and it comprises materials such as straw bales, oat hulls, rice husks and sugar cane bagasse bales (not exhaustive list).
(*2)
The group of agricultural residues with higher bulk density includes materials such as corn cobs, nut shells, soybean hulls, palm kernel shells (not exhaustive list). |
|||||
|
BIOGAS FOR ELECTRICITY (*1) |
||||
|
Biogas production system |
Technological option |
Greenhouse gas emissions savings – typical value |
Greenhouse gas emissions savings – default value |
|
|
Wet manure (1) |
Case 1 |
Open digestate (2) |
146 % |
94 % |
|
Close digestate (3) |
246 % |
240 % |
||
|
Case 2 |
Open digestate |
136 % |
85 % |
|
|
Close digestate |
227 % |
219 % |
||
|
Case 3 |
Open digestate |
142 % |
86 % |
|
|
Close digestate |
243 % |
235 % |
||
|
Maize whole plant (4) |
Case 1 |
Open digestate |
36 % |
21 % |
|
Close digestate |
59 % |
53 % |
||
|
Case 2 |
Open digestate |
34 % |
18 % |
|
|
Close digestate |
55 % |
47 % |
||
|
Case 3 |
Open digestate |
28 % |
10 % |
|
|
Close digestate |
52 % |
43 % |
||
|
Biowaste |
Case 1 |
Open digestate |
47 % |
26 % |
|
Close digestate |
84 % |
78 % |
||
|
Case 2 |
Open digestate |
43 % |
21 % |
|
|
Close digestate |
77 % |
68 % |
||
|
Case 3 |
Open digestate |
38 % |
14 % |
|
|
Close digestate |
76 % |
66 % |
||
|
(*1)
Case 1 refers to pathways in which electricity and heat required in the process are supplied by the CHP engine itself. Case 2 refers to pathways in which the electricity required in the process is taken from the grid and the process heat is supplied by the CHP engine itself. In some Member States, operators are not allowed to claim the gross production for subsidies and case 1 is the more likely configuration. Case 3 refers to pathways in which the electricity required in the process is taken from the grid and the process heat is supplied by a biogas boiler. This case applies to some installations in which the CHP engine is not on-site and biogas is sold (but not upgraded to biomethane).
(1)
The values for biogas production from manure include negative emissions for emissions saved from raw manure management. The value of esca considered is equal to – 45 g CO2eq/MJ manure used in anaerobic digestion.
(2)
Open storage of digestate accounts for additional emissions of CH4 and N2O. The magnitude of those emissions changes with ambient conditions, substrate types and the digestion efficiency.
(3)
Close storage means that the digestate resulting from the digestion process is stored in a gas-tight tank and that the additional biogas released during storage is considered to be recovered for production of additional electricity or biomethane. No greenhouse gas emissions are included in that process.
(4)
Maize whole plant means maize harvested as fodder and ensiled for preservation. |
||||
|
BIOGAS FOR ELECTRICITY – MIXTURES OF MANURE AND MAIZE |
||||
|
Biogas production system |
Technological option |
Greenhouse gas emissions savings – typical value |
Greenhouse gas emissions savings – default value |
|
|
Manure – Maize 80 % - 20 % |
Case 1 |
Open digestate |
72 % |
45 % |
|
Close digestate |
120 % |
114 % |
||
|
Case 2 |
Open digestate |
67 % |
40 % |
|
|
Close digestate |
111 % |
103 % |
||
|
Case 3 |
Open digestate |
65 % |
35 % |
|
|
Close digestate |
114 % |
106 % |
||
|
Manure – Maize 70 % - 30 % |
Case 1 |
Open digestate |
60 % |
37 % |
|
Close digestate |
100 % |
94 % |
||
|
Case 2 |
Open digestate |
57 % |
32 % |
|
|
Close digestate |
93 % |
85 % |
||
|
Case 3 |
Open digestate |
53 % |
27 % |
|
|
Close digestate |
94 % |
85 % |
||
|
Manure – Maize 60 % - 40 % |
Case 1 |
Open digestate |
53 % |
32 % |
|
Close digestate |
88 % |
82 % |
||
|
Case 2 |
Open digestate |
50 % |
28 % |
|
|
Close digestate |
82 % |
73 % |
||
|
Case 3 |
Open digestate |
46 % |
22 % |
|
|
Close digestate |
81 % |
72 % |
||
|
BIOMETHANE FOR TRANSPORT (*1) |
|||
|
Biomethane production system |
Technological options |
Greenhouse gas emissions savings – typical value |
Greenhouse gas emissions savings – default value |
|
Wet manure |
Open digestate, no off-gas combustion |
117 % |
72 % |
|
Open digestate, off-gas combustion |
133 % |
94 % |
|
|
Close digestate, no off-gas combustion |
190 % |
179 % |
|
|
Close digestate, off-gas combustion |
206 % |
202 % |
|
|
Maize whole plant |
Open digestate, no off-gas combustion |
35 % |
17 % |
|
Open digestate, off-gas combustion |
51 % |
39 % |
|
|
Close digestate, no off-gas combustion |
52 % |
41 % |
|
|
Close digestate, off-gas combustion |
68 % |
63 % |
|
|
Biowaste |
Open digestate, no off-gas combustion |
43 % |
20 % |
|
Open digestate, off-gas combustion |
59 % |
42 % |
|
|
Close digestate, no off-gas combustion |
70 % |
58 % |
|
|
Close digestate, off-gas combustion |
86 % |
80 % |
|
|
(*1)
The greenhouse gas emissions savings for biomethane only refer to compressed biomethane relative to the fossil fuel comparator for transport of 94 g CO2eq/MJ. |
|||
|
BIOMETHANE – MIXTURES OF MANURE AND MAIZE (*1) |
|||
|
Biomethane production system |
Technological options |
Greenhouse gas emissions savings – typical value |
Greenhouse gas emissions savings – default value |
|
Manure – Maize 80 % - 20 % |
Open digestate, no off-gas combustion (1) |
62 % |
35 % |
|
Open digestate, off-gas combustion (2) |
78 % |
57 % |
|
|
Close digestate, no off-gas combustion |
97 % |
86 % |
|
|
Close digestate, off-gas combustion |
113 % |
108 % |
|
|
Manure – Maize 70 % - 30 % |
Open digestate, no off-gas combustion |
53 % |
29 % |
|
Open digestate, off-gas combustion |
69 % |
51 % |
|
|
Close digestate, no off-gas combustion |
83 % |
71 % |
|
|
Close digestate, off-gas combustion |
99 % |
94 % |
|
|
Manure – Maize 60 % - 40 % |
Open digestate, no off-gas combustion |
48 % |
25 % |
|
Open digestate, off-gas combustion |
64 % |
48 % |
|
|
Close digestate, no off-gas combustion |
74 % |
62 % |
|
|
Close digestate, off-gas combustion |
90 % |
84 % |
|
|
(*1)
The greenhouse gas emissions savings for biomethane only refer to compressed biomethane relative to the fossil fuel comparator for transport of 94 g CO2eq/MJ.
(1)
This category includes the following categories of technologies for biogas upgrade to biomethane: Pressure Swing Adsorption (PSA), Pressure Water Scrubbing (PWS), Membranes, Cryogenic, and Organic Physical Scrubbing (OPS). It includes an emission of 0,03 MJ CH4/MJ biomethane for the emission of methane in the off-gases.
(2)
This category includes the following categories of technologies for biogas upgrade to biomethane: Pressure Water Scrubbing (PWS) when water is recycled, Pressure Swing Adsorption (PSA), Chemical Scrubbing, Organic Physical Scrubbing (OPS), Membranes and Cryogenic upgrading. No methane emissions are considered for this category (the methane in the off-gas is combusted, if any). |
|||
B. METHODOLOGY
1. Greenhouse gas emissions from the production and use of biomass fuels, shall be calculated as follows:
Greenhouse gas emissions from the production and use of biomass fuels before conversion into electricity, heating and cooling, shall be calculated as:
E = eec + el + ep + etd + eu – esca – eccs – eccr,
Where
|
E |
= |
total emissions from the production of the fuel before energy conversion; |
|
eec |
= |
emissions from the extraction or cultivation of raw materials; |
|
el |
= |
annualised emissions from carbon stock changes caused by land-use change; |
|
ep |
= |
emissions from processing; |
|
etd |
= |
emissions from transport and distribution; |
|
eu |
= |
emissions from the fuel in use; |
|
esca |
= |
emission savings from soil carbon accumulation via improved agricultural management; |
|
eccs |
= |
emission savings from CO2 capture and geological storage; and |
|
eccr |
= |
emission savings from CO2 capture and replacement. |
Emissions from the manufacture of machinery and equipment shall not be taken into account.
In the case of co-digestion of different substrates in a biogas plant for the production of biogas or biomethane, the typical and default values of greenhouse gas emissions shall be calculated as:
where
|
E |
= |
greenhouse gas emissions per MJ biogas or biomethane produced from co-digestion of the defined mixture of substrates |
|
Sn |
= |
Share of feedstock n in energy content |
|
En |
= |
Emission in g CO2/MJ for pathway n as provided in Part D of this Annex (*) |
where
|
Pn |
= |
energy yield [MJ] per kilogram of wet input of feedstock n (**) |
|
Wn |
= |
weighting factor of substrate n defined as: |
where:
|
In |
= |
Annual input to digester of substrate n [tonne of fresh matter] |
|
AMn |
= |
Average annual moisture of substrate n [kg water/kg fresh matter] |
|
SMn |
= |
Standard moisture for substrate n (***). |
(*) For animal manure used as substrate, a bonus of 45 g CO2eq/MJ manure (– 54 kg CO2eq/t fresh matter) is added for improved agricultural and manure management.
(**) The following values of Pn shall be used for calculating typical and default values:
(***) The following values of the standard moisture for substrate SMn shall be used:
In the case of co-digestion of n substrates in a biogas plant for the production of electricity or biomethane, actual greenhouse gas emissions of biogas and biomethane are calculated as follows:
where
|
E |
= |
total emissions from the production of the biogas or biomethane before energy conversion; |
|
Sn |
= |
Share of feedstock n, in fraction of input to the digester; |
|
eec,n |
= |
emissions from the extraction or cultivation of feedstock n; |
|
etd,feedstock,n |
= |
emissions from transport of feedstock n to the digester; |
|
el,n |
= |
annualised emissions from carbon stock changes caused by land-use change, for feedstock n; |
|
esca |
= |
emission savings from improved agricultural management of feedstock n (*); |
|
ep |
= |
emissions from processing; |
|
etd,product |
= |
emissions from transport and distribution of biogas and/or biomethane; |
|
eu |
= |
emissions from the fuel in use, that is greenhouse gases emitted during combustion; |
|
eccs |
= |
emission savings from CO2 capture and geological storage; and |
|
eccr |
= |
emission savings from CO2 capture and replacement. |
(*) For esca a bonus of 45 g CO2eq/MJ manure shall be attributed for improved agricultural and manure management in the case animal manure is used as a substrate for the production of biogas and biomethane.
Greenhouse gas emissions from the use of biomass fuels in producing electricity, heating and cooling, including the energy conversion to electricity and/or heat or cooling produced, shall be calculated as follows:
For energy installations delivering only heat:
For energy installations delivering only electricity:
where
|
ECh,el |
= |
Total greenhouse gas emissions from the final energy commodity. |
|
E |
= |
Total greenhouse gas emissions of the fuel before end-conversion. |
|
ηel |
= |
The electrical efficiency, defined as the annual electricity produced divided by the annual fuel input, based on its energy content. |
|
ηh |
= |
The heat efficiency, defined as the annual useful heat output divided by the annual fuel input, based on its energy content. |
For the electricity or mechanical energy coming from energy installations delivering useful heat together with electricity and/or mechanical energy:
For the useful heat coming from energy installations delivering heat together with electricity and/or mechanical energy:
where:
|
ECh,el |
= |
Total greenhouse gas emissions from the final energy commodity. |
|
E |
= |
Total greenhouse gas emissions of the fuel before end-conversion. |
|
ηel |
= |
The electrical efficiency, defined as the annual electricity produced divided by the annual energy input, based on its energy content. |
|
ηh |
= |
The heat efficiency, defined as the annual useful heat output divided by the annual energy input, based on its energy content. |
|
Cel |
= |
Fraction of exergy in the electricity, and/or mechanical energy, set to 100 % (Cel = 1). |
|
Ch |
= |
Carnot efficiency (fraction of exergy in the useful heat). |
The Carnot efficiency, Ch, for useful heat at different temperatures is defined as:
where:
|
Th |
= |
Temperature, measured in absolute temperature (kelvin) of the useful heat at point of delivery. |
|
T0 |
= |
Temperature of surroundings, set at 273,15 kelvin (equal to 0 °C). |
If the excess heat is exported for heating of buildings, at a temperature below 150 °C (423,15 kelvin), Ch can alternatively be defined as follows:
|
Ch |
= |
Carnot efficiency in heat at 150 °C (423,15 kelvin), which is: 0,3546 |
For the purposes of that calculation, the following definitions apply:
‘cogeneration’ shall mean the simultaneous generation in one process of thermal energy and electricity and/or mechanical energy;
‘useful heat’ shall mean heat generated to satisfy an economical justifiable demand for heat, for heating or cooling purposes;
‘economically justifiable demand’ shall mean the demand that does not exceed the needs for heat or cooling and which would otherwise be satisfied at market conditions.
2. Greenhouse gas emissions from biomass fuels shall be expressed as follows:
greenhouse gas emissions from biomass fuels, E, shall be expressed in terms of grams of CO2 equivalent per MJ of biomass fuel, g CO2eq/MJ;
greenhouse gas emissions from heating or electricity, produced from biomass fuels, EC, shall be expressed in terms of grams of CO2 equivalent per MJ of final energy commodity (heat or electricity), g CO2eq/MJ.
When heating and cooling are co-generated with electricity, emissions shall be allocated between heat and electricity (as under point 1(d)), irrespective if the heat is used for actual heating purposes or for cooling. ( 16 )
Where the greenhouse gas emissions from the extraction or cultivation of raw materials eec are expressed in unit g CO2eq/dry-ton of feedstock, the conversion to grams of CO2 equivalent per MJ of fuel, g CO2eq /MJ, shall be calculated as follows ( 17 ):
Where
Emissions per dry-ton feedstock shall be calculated as follows:
3. Greenhouse gas emissions savings from biomass fuels shall be calculated as follows:
greenhouse gas emissions savings from biomass fuels used as transport fuels:
SAVING = (EF(t) – EB)/EF(t)
where
|
EB |
= |
total emissions from biomass fuels used as transport fuels; and |
|
EF(t) |
= |
total emissions from the fossil fuel comparator for transport |
greenhouse gas emissions savings from heat and cooling, and electricity being generated from biomass fuels:
SAVING = (ECF(h&c,el) – ECB(h&c,el))/ECF (h&c,el),
where
|
ECB(h&c,el) |
= |
total emissions from the heat or electricity, |
|
ECF(h&c,el) |
= |
total emissions from the fossil fuel comparator for useful heat or electricity. |
4. The greenhouse gases taken into account for the purposes of point 1 shall be CO2, N2O and CH4. For the purposes of calculating CO2 equivalence, those gases shall be valued as follows:
5. Emissions from the extraction, harvesting or cultivation of raw materials, eec, shall include emissions from the extraction, harvesting or cultivation process itself; from the collection, drying and storage of raw materials; from waste and leakages; and from the production of chemicals or products used in extraction or cultivation. Capture of CO2 in the cultivation of raw materials shall be excluded. Estimates of emissions from agriculture biomass cultivation may be derived from the regional averages for cultivation emissions included in the reports referred to in Article 31(4) of this Directive or the information on the disaggregated default values for cultivation emissions included in this Annex, as an alternative to using actual values. In the absence of relevant information in those reports it is allowed to calculate averages based on local farming practises based for instance on data of a group of farms, as an alternative to using actual values.
Estimates of emissions from cultivation and harvesting of forestry biomass may be derived from the use of averages for cultivation and harvesting emissions calculated for geographical areas at national level, as an alternative to using actual values.
6. For the purposes of the calculation referred to in point 1(a), emission savings from improved agriculture management, esca, such as shifting to reduced or zero-tillage, improved crop/rotation, the use of cover crops, including crop residue management, and the use of organic soil improver (e.g. compost, manure fermentation digestate), shall be taken into account only if solid and verifiable evidence is provided that the soil carbon has increased or that it is reasonable to expect to have increased over the period in which the raw materials concerned were cultivated while taking into account the emissions where such practices lead to increased fertiliser and herbicide use ( 18 ).
7. Annualised emissions from carbon stock changes caused by land-use change, el, shall be calculated by dividing total emissions equally over 20 years. For the calculation of those emissions the following rule shall be applied:
el = (CSR – CSA) × 3,664 × 1/20 × 1/P – eB, ( 19 )
where
|
el |
= |
annualised greenhouse gas emissions from carbon stock change due to land-use change (measured as mass of CO2-equivalent per unit biomass fuel energy). ‘Cropland’ ( 20 ) and ‘perennial cropland’ ( 21 ) shall be regarded as one land use; |
|
CSR |
= |
the carbon stock per unit area associated with the reference land use (measured as mass (tonnes) of carbon per unit area, including both soil and vegetation). The reference land use shall be the land use in January 2008 or 20 years before the raw material was obtained, whichever was the later; |
|
CSA |
= |
the carbon stock per unit area associated with the actual land use (measured as mass (tonnes) of carbon per unit area, including both soil and vegetation). In cases where the carbon stock accumulates over more than one year, the value attributed to CSA shall be the estimated stock per unit area after 20 years or when the crop reaches maturity, whichever the earlier; |
|
P |
= |
the productivity of the crop (measured as biomass fuel energy per unit area per year); and |
|
eB |
= |
bonus of 29 g CO2eq/MJ biomass fuel if biomass is obtained from restored degraded land under the conditions laid down in point 8. |
8. The bonus of 29 g CO2eq/MJ shall be attributed if evidence is provided that the land:
was not in use for agriculture in January 2008 or any other activity; and
is severely degraded land, including such land that was formerly in agricultural use.
The bonus of 29 g CO2eq/MJ shall apply for a period of up to 20 years from the date of conversion of the land to agricultural use, provided that a steady increase in carbon stocks as well as a sizable reduction in erosion phenomena for land falling under (b) are ensured.
9. ‘Severely degraded land’ means land that, for a significant period of time, has either been significantly salinated or presented significantly low organic matter content and has been severely eroded.
10. In accordance with point 10 of Part C of Annex V to this Directive, Commission Decision 2010/335/EU ( 22 ), which provides for guidelines for the calculation of land carbon stocks in relation to this Directive, drawing on the 2006 IPCC Guidelines for National Greenhouse Gas Inventories – volume 4, and in accordance with Regulations (EU) No 525/2013 and (EU) 2018/841, shall serve as the basis for the calculation of land carbon stocks.
11. Emissions from processing, ep, shall include emissions from the processing itself; from waste and leakages; and from the production of chemicals or products used in processing, including the CO2 emissions corresponding to the carbon contents of fossil inputs, whether or not actually combusted in the process.
In accounting for the consumption of electricity not produced within the solid or gaseous biomass fuel production plant, the greenhouse gas emissions intensity of the production and distribution of that electricity shall be assumed to be equal to the average emission intensity of the production and distribution of electricity in a defined region. By way of derogation from this rule, producers may use an average value for an individual electricity production plant for electricity produced by that plant, if that plant is not connected to the electricity grid.
Emissions from processing shall include emissions from drying of interim products and materials where relevant.
12. Emissions from transport and distribution, etd, shall include emissions from the transport of raw and semi-finished materials and from the storage and distribution of finished materials. Emissions from transport and distribution to be taken into account under point 5 shall not be covered by this point.
13. Emissions of CO2 from fuel in use, eu, shall be taken to be zero for biomass fuels. Emissions of non-CO2 greenhouse gases (CH4 and N2O) from the fuel in use shall be included in the eu factor.
14. Emission savings from CO2 capture and geological storage, eccs, that have not already been accounted for in ep, shall be limited to emissions avoided through the capture and storage of emitted CO2 directly related to the extraction, transport, processing and distribution of biomass fuel if stored in compliance with Directive 2009/31/EC.
15. Emission savings from CO2 capture and replacement, eccr, shall be related directly to the production of biomass fuel they are attributed to, and shall be limited to emissions avoided through the capture of CO2 of which the carbon originates from biomass and which is used to replace fossil-derived CO2 in production of commercial products and services.
16. Where a cogeneration unit – providing heat and/or electricity to a biomass fuel production process for which emissions are being calculated – produces excess electricity and/or excess useful heat, the greenhouse gas emissions shall be divided between the electricity and the useful heat according to the temperature of the heat (which reflects the usefulness (utility) of the heat). The useful part of the heat is found by multiplying its energy content with the Carnot efficiency, Ch, calculated as follows:
where
|
Th |
= |
Temperature, measured in absolute temperature (kelvin) of the useful heat at point of delivery. |
|
T0 |
= |
Temperature of surroundings, set at 273,15 kelvin (equal to 0 °C). |
If the excess heat is exported for heating of buildings, at a temperature below 150 °C (423,15 kelvin), Ch can alternatively be defined as follows:
|
Ch |
= |
Carnot efficiency in heat at 150 °C (423,15 kelvin), which is: 0,3546 |
For the purposes of that calculation, the actual efficiencies shall be used, defined as the annual mechanical energy, electricity and heat produced respectively divided by the annual energy input.
For the purposes of that calculation, the following definitions apply:
‘cogeneration’ shall mean the simultaneous generation in one process of thermal energy and electrical and/or mechanical energy;
‘useful heat’ shall mean heat generated to satisfy an economical justifiable demand for heat, for heating or cooling purposes;
‘economically justifiable demand’ shall mean the demand that does not exceed the needs for heat or cooling and which would otherwise be satisfied at market conditions.
17. Where a biomass fuel production process produces, in combination, the fuel for which emissions are being calculated and one or more other products (‘co-products’), greenhouse gas emissions shall be divided between the fuel or its intermediate product and the co-products in proportion to their energy content (determined by lower heating value in the case of co-products other than electricity and heat). The greenhouse gas intensity of excess useful heat or excess electricity is the same as the greenhouse gas intensity of heat or electricity delivered to the biomass fuel production process and is determined from calculating the greenhouse gas intensity of all inputs and emissions, including the feedstock and CH4 and N2O emissions, to and from the cogeneration unit, boiler or other apparatus delivering heat or electricity to the biomass fuel production process. In the case of cogeneration of electricity and heat, the calculation is performed following point 16.
18. For the purposes of the calculations referred to in point 17, the emissions to be divided shall be eec + el + esca + those fractions of ep, etd, eccs and eccr that take place up to and including the process step at which a co-product is produced. If any allocation to co-products has taken place at an earlier process step in the life-cycle, the fraction of those emissions assigned in the last such process step to the intermediate fuel product shall be used for those purposes instead of the total of those emissions.
►C1 In the case of biogas and biomethane, all co-products shall be taken into account for the purposes of that calculation. ◄ No emissions shall be allocated to wastes and residues. Co-products that have a negative energy content shall be considered to have an energy content of zero for the purposes of the calculation.
Wastes and residues, including tree tops and branches, straw, husks, cobs and nut shells, and residues from processing, including crude glycerine (glycerine that is not refined) and bagasse, shall be considered to have zero life-cycle greenhouse gas emissions up to the process of collection of those materials irrespectively of whether they are processed to interim products before being transformed into the final product.
In the case of biomass fuels produced in refineries, other than the combination of processing plants with boilers or cogeneration units providing heat and/or electricity to the processing plant, the unit of analysis for the purposes of the calculation referred to in point 17 shall be the refinery.
19. For biomass fuels used for the production of electricity, for the purposes of the calculation referred to in point 3, the fossil fuel comparator ECF(el) shall be 183 g CO2eq/MJ electricity or 212 g CO2eq/MJ electricity for the outermost regions.
For biomass fuels used for the production of useful heat, as well as for the production of heating and/or cooling, for the purposes of the calculation referred to in point 3, the fossil fuel comparator ECF(h) shall be 80 g CO2eq/MJ heat.
For biomass fuels used for the production of useful heat, in which a direct physical substitution of coal can be demonstrated, for the purposes of the calculation referred to in point 3, the fossil fuel comparator ECF(h) shall be 124 g CO2eq/MJ heat.
For biomass fuels used as transport fuels, for the purposes of the calculation referred to in point 3, the fossil fuel comparator EF(t) shall be 94 g CO2eq/MJ.
C. DISAGGREGATED DEFAULT VALUES FOR BIOMASS FUELS
Wood briquettes or pellets
|
Biomass fuel production system |
Transport distance |
Greenhouse gas emissions – typical value (g CO2eq/MJ) |
Greenhouse gas emissions – default value (g CO2eq/MJ) |
||||||
|
Cultivation |
Processing |
Transport |
Non-CO2 emissions from the fuel in use |
Cultivation |
Processing |
Transport |
Non-CO2 emissions from the fuel in use |
||
|
Wood chips from forest residues |
1 to 500 km |
0,0 |
1,6 |
3,0 |
0,4 |
0,0 |
1,9 |
3,6 |
0,5 |
|
500 to 2 500 km |
0,0 |
1,6 |
5,2 |
0,4 |
0,0 |
1,9 |
6,2 |
0,5 |
|
|
2 500 to 10 000 km |
0,0 |
1,6 |
10,5 |
0,4 |
0,0 |
1,9 |
12,6 |
0,5 |
|
|
Above 10 000 km |
0,0 |
1,6 |
20,5 |
0,4 |
0,0 |
1,9 |
24,6 |
0,5 |
|
|
Wood chips from SRC (Eucalyptus) |
2 500 to 10 000 km |
4,4 |
0,0 |
11,0 |
0,4 |
4,4 |
0,0 |
13,2 |
0,5 |
|
Wood chips from SRC (Poplar – fertilised) |
1 to 500 km |
3,9 |
0,0 |
3,5 |
0,4 |
3,9 |
0,0 |
4,2 |
0,5 |
|
500 to 2 500 km |
3,9 |
0,0 |
5,6 |
0,4 |
3,9 |
0,0 |
6,8 |
0,5 |
|
|
2 500 to 10 000 km |
3,9 |
0,0 |
11,0 |
0,4 |
3,9 |
0,0 |
13,2 |
0,5 |
|
|
Above 10 000 km |
3,9 |
0,0 |
21,0 |
0,4 |
3,9 |
0,0 |
25,2 |
0,5 |
|
|
Wood chips from SRC (Poplar – Not fertilised) |
1 to 500 km |
2,2 |
0,0 |
3,5 |
0,4 |
2,2 |
0,0 |
4,2 |
0,5 |
|
500 to 2 500 km |
2,2 |
0,0 |
5,6 |
0,4 |
2,2 |
0,0 |
6,8 |
0,5 |
|
|
2 500 to 10 000 km |
2,2 |
0,0 |
11,0 |
0,4 |
2,2 |
0,0 |
13,2 |
0,5 |
|
|
Above 10 000 km |
2,2 |
0,0 |
21,0 |
0,4 |
2,2 |
0,0 |
25,2 |
0,5 |
|
|
Wood chips from stemwood |
1 to 500 km |
1,1 |
0,3 |
3,0 |
0,4 |
1,1 |
0,4 |
3,6 |
0,5 |
|
500 to 2 500 km |
1,1 |
0,3 |
5,2 |
0,4 |
1,1 |
0,4 |
6,2 |
0,5 |
|
|
2 500 to 10 000 km |
1,1 |
0,3 |
10,5 |
0,4 |
1,1 |
0,4 |
12,6 |
0,5 |
|
|
Above 10 000 km |
1,1 |
0,3 |
20,5 |
0,4 |
1,1 |
0,4 |
24,6 |
0,5 |
|
|
Wood chips from wood industry residues |
1 to 500 km |
0,0 |
0,3 |
3,0 |
0,4 |
0,0 |
0,4 |
3,6 |
0,5 |
|
500 to 2 500 km |
0,0 |
0,3 |
5,2 |
0,4 |
0,0 |
0,4 |
6,2 |
0,5 |
|
|
2 500 to 10 000 km |
0,0 |
0,3 |
10,5 |
0,4 |
0,0 |
0,4 |
12,6 |
0,5 |
|
|
Above 10 000 km |
0,0 |
0,3 |
20,5 |
0,4 |
0,0 |
0,4 |
24,6 |
0,5 |
|
Wood briquettes or pellets
|
Biomass fuel production system |
Transport distance |
Greenhouse gas emissions – typical value (g CO2eq/MJ) |
Greenhouse gas emissions – default value (g CO2eq/MJ) |
||||||
|
|
|
Cultivation |
Processing |
Transport & distribution |
Non-CO2 emissions from the fuel in use |
Cultivation |
Processing |
Transport & distribution |
Non-CO2 emissions from the fuel in use |
|
Wood briquettes or pellets from forest residues (case 1) |
1 to 500 km |
0,0 |
25,8 |
2,9 |
0,3 |
0,0 |
30,9 |
3,5 |
0,3 |
|
500 to 2 500 km |
0,0 |
25,8 |
2,8 |
0,3 |
0,0 |
30,9 |
3,3 |
0,3 |
|
|
2 500 to 10 000 km |
0,0 |
25,8 |
4,3 |
0,3 |
0,0 |
30,9 |
5,2 |
0,3 |
|
|
Above 10 000 km |
0,0 |
25,8 |
7,9 |
0,3 |
0,0 |
30,9 |
9,5 |
0,3 |
|
|
Wood briquettes or pellets from forest residues (case 2a) |
1 to 500 km |
0,0 |
12,5 |
3,0 |
0,3 |
0,0 |
15,0 |
3,6 |
0,3 |
|
500 to 2 500 km |
0,0 |
12,5 |
2,9 |
0,3 |
0,0 |
15,0 |
3,5 |
0,3 |
|
|
2 500 to 10 000 km |
0,0 |
12,5 |
4,4 |
0,3 |
0,0 |
15,0 |
5,3 |
0,3 |
|
|
Above 10 000 km |
0,0 |
12,5 |
8,1 |
0,3 |
0,0 |
15,0 |
9,8 |
0,3 |
|
|
Wood briquettes or pellets from forest residues (case 3a) |
1 to 500 km |
0,0 |
2,4 |
3,0 |
0,3 |
0,0 |
2,8 |
3,6 |
0,3 |
|
500 to 2 500 km |
0,0 |
2,4 |
2,9 |
0,3 |
0,0 |
2,8 |
3,5 |
0,3 |
|
|
2 500 to 10 000 km |
0,0 |
2,4 |
4,4 |
0,3 |
0,0 |
2,8 |
5,3 |
0,3 |
|
|
Above 10 000 km |
0,0 |
2,4 |
8,2 |
0,3 |
0,0 |
2,8 |
9,8 |
0,3 |
|
|
Wood briquettes from short rotation coppice (Eucalyptus – case 1) |
2 500 to 10 000 km |
3,9 |
24,5 |
4,3 |
0,3 |
3,9 |
29,4 |
5,2 |
0,3 |
|
Wood briquettes from short rotation coppice (Eucalyptus – case 2a) |
2 500 to 10 000 km |
5,0 |
10,6 |
4,4 |
0,3 |
5,0 |
12,7 |
5,3 |
0,3 |
|
Wood briquettes from short rotation coppice (Eucalyptus – case 3a) |
2 500 to 10 000 km |
5,3 |
0,3 |
4,4 |
0,3 |
5,3 |
0,4 |
5,3 |
0,3 |
|
Wood briquettes from short rotation coppice (Poplar – Fertilised – case 1) |
1 to 500 km |
3,4 |
24,5 |
2,9 |
0,3 |
3,4 |
29,4 |
3,5 |
0,3 |
|
500 to 10 000 km |
3,4 |
24,5 |
4,3 |
0,3 |
3,4 |
29,4 |
5,2 |
0,3 |
|
|
Above 10 000 km |
3,4 |
24,5 |
7,9 |
0,3 |
3,4 |
29,4 |
9,5 |
0,3 |
|
|
Wood briquettes from short rotation coppice (Poplar – Fertilised – case 2a) |
1 to 500 km |
4,4 |
10,6 |
3,0 |
0,3 |
4,4 |
12,7 |
3,6 |
0,3 |
|
500 to 10 000 km |
4,4 |
10,6 |
4,4 |
0,3 |
4,4 |
12,7 |
5,3 |
0,3 |
|
|
Above 10 000 km |
4,4 |
10,6 |
8,1 |
0,3 |
4,4 |
12,7 |
9,8 |
0,3 |
|
|
Wood briquettes from short rotation coppice (Poplar – Fertilised – case 3a) |
1 to 500 km |
4,6 |
0,3 |
3,0 |
0,3 |
4,6 |
0,4 |
3,6 |
0,3 |
|
500 to 10 000 km |
4,6 |
0,3 |
4,4 |
0,3 |
4,6 |
0,4 |
5,3 |
0,3 |
|
|
Above 10 000 km |
4,6 |
0,3 |
8,2 |
0,3 |
4,6 |
0,4 |
9,8 |
0,3 |
|
|
Wood briquettes from short rotation coppice (Poplar – no fertilisation – case 1) |
1 to 500 km |
2,0 |
24,5 |
2,9 |
0,3 |
2,0 |
29,4 |
3,5 |
0,3 |
|
500 to 2 500 km |
2,0 |
24,5 |
4,3 |
0,3 |
2,0 |
29,4 |
5,2 |
0,3 |
|
|
2 500 to 10 000 km |
2,0 |
24,5 |
7,9 |
0,3 |
2,0 |
29,4 |
9,5 |
0,3 |
|
|
Wood briquettes from short rotation coppice (Poplar – no fertilisation – case 2a) |
1 to 500 km |
2,5 |
10,6 |
3,0 |
0,3 |
2,5 |
12,7 |
3,6 |
0,3 |
|
500 to 10 000 km |
2,5 |
10,6 |
4,4 |
0,3 |
2,5 |
12,7 |
5,3 |
0,3 |
|
|
Above 10 000 km |
2,5 |
10,6 |
8,1 |
0,3 |
2,5 |
12,7 |
9,8 |
0,3 |
|
|
Wood briquettes from short rotation coppice (Poplar – no fertilisation– case 3a) |
1 to 500 km |
2,6 |
0,3 |
3,0 |
0,3 |
2,6 |
0,4 |
3,6 |
0,3 |
|
500 to 10 000 km |
2,6 |
0,3 |
4,4 |
0,3 |
2,6 |
0,4 |
5,3 |
0,3 |
|
|
Above 10 000 km |
2,6 |
0,3 |
8,2 |
0,3 |
2,6 |
0,4 |
9,8 |
0,3 |
|
|
Wood briquettes or pellets from stemwood (case 1) |
1 to 500 km |
1,1 |
24,8 |
2,9 |
0,3 |
1,1 |
29,8 |
3,5 |
0,3 |
|
500 to 2 500 km |
1,1 |
24,8 |
2,8 |
0,3 |
1,1 |
29,8 |
3,3 |
0,3 |
|
|
2 500 to 10 000 km |
1,1 |
24,8 |
4,3 |
0,3 |
1,1 |
29,8 |
5,2 |
0,3 |
|
|
Above 10 000 km |
1,1 |
24,8 |
7,9 |
0,3 |
1,1 |
29,8 |
9,5 |
0,3 |
|
|
Wood briquettes or pellets from stemwood (case 2a) |
1 to 500 km |
1,4 |
11,0 |
3,0 |
0,3 |
1,4 |
13,2 |
3,6 |
0,3 |
|
500 to 2 500 km |
1,4 |
11,0 |
2,9 |
0,3 |
1,4 |
13,2 |
3,5 |
0,3 |
|
|
2 500 to 10 000 km |
1,4 |
11,0 |
4,4 |
0,3 |
1,4 |
13,2 |
5,3 |
0,3 |
|
|
Above 10 000 km |
1,4 |
11,0 |
8,1 |
0,3 |
1,4 |
13,2 |
9,8 |
0,3 |
|
|
Wood briquettes or pellets from stemwood (case 3a) |
1 to 500 km |
1,4 |
0,8 |
3,0 |
0,3 |
1,4 |
0,9 |
3,6 |
0,3 |
|
500 to 2 500 km |
1,4 |
0,8 |
2,9 |
0,3 |
1,4 |
0,9 |
3,5 |
0,3 |
|
|
2 500 to 10 000 km |
1,4 |
0,8 |
4,4 |
0,3 |
1,4 |
0,9 |
5,3 |
0,3 |
|
|
Above 10 000 km |
1,4 |
0,8 |
8,2 |
0,3 |
1,4 |
0,9 |
9,8 |
0,3 |
|
|
Wood briquettes or pellets from wood industry residues (case 1) |
1 to 500 km |
0,0 |
14,3 |
2,8 |
0,3 |
0,0 |
17,2 |
3,3 |
0,3 |
|
500 to 2 500 km |
0,0 |
14,3 |
2,7 |
0,3 |
0,0 |
17,2 |
3,2 |
0,3 |
|
|
2 500 to 10 000 km |
0,0 |
14,3 |
4,2 |
0,3 |
0,0 |
17,2 |
5,0 |
0,3 |
|
|
Above 10 000 km |
0,0 |
14,3 |
7,7 |
0,3 |
0,0 |
17,2 |
9,2 |
0,3 |
|
|
Wood briquettes or pellets from wood industry residues (case 2a) |
1 to 500 km |
0,0 |
6,0 |
2,8 |
0,3 |
0,0 |
7,2 |
3,4 |
0,3 |
|
500 to 2 500 km |
0,0 |
6,0 |
2,7 |
0,3 |
0,0 |
7,2 |
3,3 |
0,3 |
|
|
2 500 to 10 000 km |
0,0 |
6,0 |
4,2 |
0,3 |
0,0 |
7,2 |
5,1 |
0,3 |
|
|
Above 10 000 km |
0,0 |
6,0 |
7,8 |
0,3 |
0,0 |
7,2 |
9,3 |
0,3 |
|
|
Wood briquettes or pellets from wood industry residues (case 3a) |
1 to 500 km |
0,0 |
0,2 |
2,8 |
0,3 |
0,0 |
0,3 |
3,4 |
0,3 |
|
500 to 2 500 km |
0,0 |
0,2 |
2,7 |
0,3 |
0,0 |
0,3 |
3,3 |
0,3 |
|
|
2 500 to 10 000 km |
0,0 |
0,2 |
4,2 |
0,3 |
0,0 |
0,3 |
5,1 |
0,3 |
|
|
Above 10 000 km |
0,0 |
0,2 |
7,8 |
0,3 |
0,0 |
0,3 |
9,3 |
0,3 |
|
Agriculture pathways
|
Biomass fuel production system |
Transport distance |
Greenhouse gas emissions – typical value (g CO2eq/MJ) |
Greenhouse gas emissions – default value (g CO2eq/MJ) |
||||||
|
|
|
Cultivation |
Processing |
Transport & distribution |
Non-CO2 emissions from the fuel in use |
Cultivation |
Processing |
Transport & distribution |
Non-CO2 emissions from the fuel in use |
|
Agricultural Residues with density < 0,2 t/m3 |
1 to 500 km |
0,0 |
0,9 |
2,6 |
0,2 |
0,0 |
1,1 |
3,1 |
0,3 |
|
500 to 2 500 km |
0,0 |
0,9 |
6,5 |
0,2 |
0,0 |
1,1 |
7,8 |
0,3 |
|
|
2 500 to 10 000 km |
0,0 |
0,9 |
14,2 |
0,2 |
0,0 |
1,1 |
17,0 |
0,3 |
|
|
Above 10 000 km |
0,0 |
0,9 |
28,3 |
0,2 |
0,0 |
1,1 |
34,0 |
0,3 |
|
|
Agricultural Residues with density > 0,2 t/m3 |
1 to 500 km |
0,0 |
0,9 |
2,6 |
0,2 |
0,0 |
1,1 |
3,1 |
0,3 |
|
500 to 2 500 km |
0,0 |
0,9 |
3,6 |
0,2 |
0,0 |
1,1 |
4,4 |
0,3 |
|
|
2 500 to 10 000 km |
0,0 |
0,9 |
7,1 |
0,2 |
0,0 |
1,1 |
8,5 |
0,3 |
|
|
Above 10 000 km |
0,0 |
0,9 |
13,6 |
0,2 |
0,0 |
1,1 |
16,3 |
0,3 |
|
|
Straw pellets |
1 to 500 km |
0,0 |
5,0 |
3,0 |
0,2 |
0,0 |
6,0 |
3,6 |
0,3 |
|
500 to 10 000 km |
0,0 |
5,0 |
4,6 |
0,2 |
0,0 |
6,0 |
5,5 |
0,3 |
|
|
Above 10 000 km |
0,0 |
5,0 |
8,3 |
0,2 |
0,0 |
6,0 |
10,0 |
0,3 |
|
|
Bagasse briquettes |
500 to 10 000 km |
0,0 |
0,3 |
4,3 |
0,4 |
0,0 |
0,4 |
5,2 |
0,5 |
|
Above 10 000 km |
0,0 |
0,3 |
8,0 |
0,4 |
0,0 |
0,4 |
9,5 |
0,5 |
|
|
Palm Kernel Meal |
Above 10 000 km |
21,6 |
21,1 |
11,2 |
0,2 |
21,6 |
25,4 |
13,5 |
0,3 |
|
Palm Kernel Meal (no CH4 emissions from oil mill) |
Above 10 000 km |
21,6 |
3,5 |
11,2 |
0,2 |
21,6 |
4,2 |
13,5 |
0,3 |
Disaggregated default values for biogas for the production of electricity
|
Biomass fuel production system |
Technology |
TYPICAL VALUE [g CO2eq/MJ] |
DEFAULT VALUE [g CO2eq/MJ] |
|||||||||
|
Cultivation |
Processing |
Non-CO2 emissions from the fuel in use |
Transport |
Manure credits |
Cultivation |
Processing |
Non-CO2 emissions from the fuel in use |
Transport |
Manure credits |
|||
|
Wet manure (1) |
case 1 |
Open digestate |
0,0 |
69,6 |
8,9 |
0,8 |
– 107,3 |
0,0 |
97,4 |
12,5 |
0,8 |
– 107,3 |
|
Close digestate |
0,0 |
0,0 |
8,9 |
0,8 |
– 97,6 |
0,0 |
0,0 |
12,5 |
0,8 |
– 97,6 |
||
|
case 2 |
Open digestate |
0,0 |
74,1 |
8,9 |
0,8 |
– 107,3 |
0,0 |
103,7 |
12,5 |
0,8 |
– 107,3 |
|
|
Close digestate |
0,0 |
4,2 |
8,9 |
0,8 |
– 97,6 |
0,0 |
5,9 |
12,5 |
0,8 |
– 97,6 |
||
|
case 3 |
Open digestate |
0,0 |
83,2 |
8,9 |
0,9 |
– 120,7 |
0,0 |
116,4 |
12,5 |
0,9 |
– 120,7 |
|
|
Close digestate |
0,0 |
4,6 |
8,9 |
0,8 |
– 108,5 |
0,0 |
6,4 |
12,5 |
0,8 |
– 108,5 |
||
|
Maize whole plant (2) |
case 1 |
Open digestate |
15,6 |
13,5 |
8,9 |
0,0 (3) |
— |
15,6 |
18,9 |
12,5 |
0,0 |
— |
|
Close digestate |
15,2 |
0,0 |
8,9 |
0,0 |
— |
15,2 |
0,0 |
12,5 |
0,0 |
— |
||
|
case 2 |
Open digestate |
15,6 |
18,8 |
8,9 |
0,0 |
— |
15,6 |
26,3 |
12,5 |
0,0 |
— |
|
|
Close digestate |
15,2 |
5,2 |
8,9 |
0,0 |
— |
15,2 |
7,2 |
12,5 |
0,0 |
— |
||
|
case 3 |
Open digestate |
17,5 |
21,0 |
8,9 |
0,0 |
— |
17,5 |
29,3 |
12,5 |
0,0 |
— |
|
|
Close digestate |
17,1 |
5,7 |
8,9 |
0,0 |
— |
17,1 |
7,9 |
12,5 |
0,0 |
— |
||
|
Biowaste |
case 1 |
Open digestate |
0,0 |
21,8 |
8,9 |
0,5 |
— |
0,0 |
30,6 |
12,5 |
0,5 |
— |
|
Close digestate |
0,0 |
0,0 |
8,9 |
0,5 |
— |
0,0 |
0,0 |
12,5 |
0,5 |
— |
||
|
case 2 |
Open digestate |
0,0 |
27,9 |
8,9 |
0,5 |
— |
0,0 |
39,0 |
12,5 |
0,5 |
— |
|
|
Close digestate |
0,0 |
5,9 |
8,9 |
0,5 |
— |
0,0 |
8,3 |
12,5 |
0,5 |
— |
||
|
case 3 |
Open digestate |
0,0 |
31,2 |
8,9 |
0,5 |
— |
0,0 |
43,7 |
12,5 |
0,5 |
— |
|
|
Close digestate |
0,0 |
6,5 |
8,9 |
0,5 |
— |
0,0 |
9,1 |
12,5 |
0,5 |
— |
||
|
(1)
The values for biogas production from manure include negative emissions for emissions saved from raw manure management. The value of esca considered is equal to – 45 g CO2eq/MJ manure used in anaerobic digestion.
(2)
Maize whole plant means maize harvested as fodder and ensiled for preservation.
(3)
Transport of agricultural raw materials to the transformation plant is, according to the methodology provided in the Commission's report of 25 February 2010 on sustainability requirements for the use of solid and gaseous biomass sources in electricity, heating and cooling, included in the ‘cultivation’ value. The value for transport of maize silage accounts for 0,4 g CO2eq/MJ biogas. |
||||||||||||
Disaggregated default values for biomethane
|
Biomethane production system |
Technological option |
TYPICAL VALUE [g CO2eq/MJ] |
DEFAULT VALUE [g CO2eq/MJ] |
|||||||||||
|
Cultivation |
Processing |
Upgrading |
Transport |
Compression at filling station |
Manure credits |
Cultivation |
Processing |
Upgrading |
Transport |
Compression at filling station |
Manure credits |
|||
|
Wet manure |
Open digestate |
no off-gas combustion |
0,0 |
84,2 |
19,5 |
1,0 |
3,3 |
– 124,4 |
0,0 |
117,9 |
27,3 |
1,0 |
4,6 |
– 124,4 |
|
off-gas combustion |
0,0 |
84,2 |
4,5 |
1,0 |
3,3 |
– 124,4 |
0,0 |
117,9 |
6,3 |
1,0 |
4,6 |
– 124,4 |
||
|
Close digestate |
no off-gas combustion |
0,0 |
3,2 |
19,5 |
0,9 |
3,3 |
– 111,9 |
0,0 |
4,4 |
27,3 |
0,9 |
4,6 |
– 111,9 |
|
|
off-gas combustion |
0,0 |
3,2 |
4,5 |
0,9 |
3,3 |
– 111,9 |
0,0 |
4,4 |
6,3 |
0,9 |
4,6 |
– 111,9 |
||
|
Maize whole plant |
Open digestate |
no off-gas combustion |
18,1 |
20,1 |
19,5 |
0,0 |
3,3 |
— |
18,1 |
28,1 |
27,3 |
0,0 |
4,6 |
— |
|
off-gas combustion |
18,1 |
20,1 |
4,5 |
0,0 |
3,3 |
— |
18,1 |
28,1 |
6,3 |
0,0 |
4,6 |
— |
||
|
Close digestate |
no off-gas combustion |
17,6 |
4,3 |
19,5 |
0,0 |
3,3 |
— |
17,6 |
6,0 |
27,3 |
0,0 |
4,6 |
— |
|
|
off-gas combustion |
17,6 |
4,3 |
4,5 |
0,0 |
3,3 |
— |
17,6 |
6,0 |
6,3 |
0,0 |
4,6 |
— |
||
|
Biowaste |
Open digestate |
no off-gas combustion |
0,0 |
30,6 |
19,5 |
0,6 |
3,3 |
— |
0,0 |
42,8 |
27,3 |
0,6 |
4,6 |
— |
|
off-gas combustion |
0,0 |
30,6 |
4,5 |
0,6 |
3,3 |
— |
0,0 |
42,8 |
6,3 |
0,6 |
4,6 |
— |
||
|
Close digestate |
no off-gas combustion |
0,0 |
5,1 |
19,5 |
0,5 |
3,3 |
— |
0,0 |
7,2 |
27,3 |
0,5 |
4,6 |
— |
|
|
off-gas combustion |
0,0 |
5,1 |
4,5 |
0,5 |
3,3 |
— |
0,0 |
7,2 |
6,3 |
0,5 |
4,6 |
— |
||
D. TOTAL TYPICAL AND DEFAULT VALUES FOR BIOMASS FUEL PATHWAYS
|
Biomass fuel production system |
Transport distance |
Greenhouse gas emissions – typical value (g CO2eq/MJ) |
Greenhouse gas emissions – default value (g CO2eq/MJ) |
|
Woodchips from forest residues |
1 to 500 km |
5 |
6 |
|
500 to 2 500 km |
7 |
9 |
|
|
2 500 to 10 000 km |
12 |
15 |
|
|
Above 10 000 km |
22 |
27 |
|
|
Woodchips from short rotation coppice (Eucalyptus) |
2 500 to 10 000 km |
16 |
18 |
|
Woodchips from short rotation coppice (Poplar – Fertilised) |
1 to 500 km |
8 |
9 |
|
500 to 2 500 km |
10 |
11 |
|
|
2 500 to 10 000 km |
15 |
18 |
|
|
Above 10 000 km |
25 |
30 |
|
|
Woodchips from short rotation coppice (Poplar – No fertilisation) |
1 to 500 km |
6 |
7 |
|
500 to 2 500 km |
8 |
10 |
|
|
2 500 to 10 000 km |
14 |
16 |
|
|
Above 10 000 km |
24 |
28 |
|
|
Woodchips from stemwood |
1 to 500 km |
5 |
6 |
|
500 to 2 500 km |
7 |
8 |
|
|
2 500 to 10 000 km |
12 |
15 |
|
|
Above 10 000 km |
22 |
27 |
|
|
Woodchips from industry residues |
1 to 500 km |
4 |
5 |
|
500 to 2 500 km |
6 |
7 |
|
|
2 500 to 10 000 km |
11 |
13 |
|
|
Above 10 000 km |
21 |
25 |
|
|
Wood briquettes or pellets from forest residues (case 1) |
1 to 500 km |
29 |
35 |
|
500 to 2 500 km |
29 |
35 |
|
|
2 500 to 10 000 km |
30 |
36 |
|
|
Above 10 000 km |
34 |
41 |
|
|
Wood briquettes or pellets from forest residues (case 2a) |
1 to 500 km |
16 |
19 |
|
500 to 2 500 km |
16 |
19 |
|
|
2 500 to 10 000 km |
17 |
21 |
|
|
Above 10 000 km |
21 |
25 |
|
|
Wood briquettes or pellets from forest residues (case 3a) |
1 to 500 km |
6 |
7 |
|
500 to 2 500 km |
6 |
7 |
|
|
2 500 to 10 000 km |
7 |
8 |
|
|
Above 10 000 km |
11 |
13 |
|
|
Wood briquettes or pellets from short rotation coppice (Eucalyptus – case 1) |
2 500 to 10 000 km |
33 |
39 |
|
Wood briquettes or pellets from short rotation coppice (Eucalyptus – case 2a) |
2 500 to 10 000 km |
20 |
23 |
|
Wood briquettes or pellets from short rotation coppice (Eucalyptus – case 3a) |
2 500 to 10 000 km |
10 |
11 |
|
Wood briquettes or pellets from short rotation coppice (Poplar – Fertilised – case 1) |
1 to 500 km |
31 |
37 |
|
500 to 10 000 km |
32 |
38 |
|
|
Above 10 000 km |
36 |
43 |
|
|
Wood briquettes or pellets from short rotation coppice (Poplar – Fertilised – case 2a) |
1 to 500 km |
18 |
21 |
|
500 to 10 000 km |
20 |
23 |
|
|
Above 10 000 km |
23 |
27 |
|
|
Wood briquettes or pellets from short rotation coppice (Poplar – Fertilised – case 3a) |
1 to 500 km |
8 |
9 |
|
500 to 10 000 km |
10 |
11 |
|
|
Above 10 000 km |
13 |
15 |
|
|
Wood briquettes or pellets from short rotation coppice (Poplar – no fertilisation – case 1) |
1 to 500 km |
30 |
35 |
|
500 to 10 000 km |
31 |
37 |
|
|
Above 10 000 km |
35 |
41 |
|
|
Wood briquettes or pellets from short rotation coppice (Poplar – no fertilisation – case 2a) |
1 to 500 km |
16 |
19 |
|
500 to 10 000 km |
18 |
21 |
|
|
Above 10 000 km |
21 |
25 |
|
|
Wood briquettes or pellets from short rotation coppice (Poplar – no fertilisation – case 3a) |
1 to 500 km |
6 |
7 |
|
500 to 10 000 km |
8 |
9 |
|
|
Above 10 000 km |
11 |
13 |
|
|
Wood briquettes or pellets from stemwood (case 1) |
1 to 500 km |
29 |
35 |
|
500 to 2 500 km |
29 |
34 |
|
|
2 500 to 10 000 km |
30 |
36 |
|
|
Above 10 000 km |
34 |
41 |
|
|
Wood briquettes or pellets from stemwood (case 2a) |
1 to 500 km |
16 |
18 |
|
500 to 2 500 km |
15 |
18 |
|
|
2 500 to 10 000 km |
17 |
20 |
|
|
Above 10 000 km |
21 |
25 |
|
|
Wood briquettes or pellets from stemwood (case 3a) |
1 to 500 km |
5 |
6 |
|
500 to 2 500 km |
5 |
6 |
|
|
2 500 to 10 000 km |
7 |
8 |
|
|
Above 10 000 km |
11 |
12 |
|
|
Wood briquettes or pellets from wood industry residues (case 1) |
1 to 500 km |
17 |
21 |
|
500 to 2 500 km |
17 |
21 |
|
|
2 500 to 10 000 km |
19 |
23 |
|
|
Above 10 000 km |
22 |
27 |
|
|
Wood briquettes or pellets from wood industry residues (case 2a) |
1 to 500 km |
9 |
11 |
|
500 to 2 500 km |
9 |
11 |
|
|
2 500 to 10 000 km |
10 |
13 |
|
|
Above 10 000 km |
14 |
17 |
|
|
Wood briquettes or pellets from wood industry residues (case 3a) |
1 to 500 km |
3 |
4 |
|
500 to 2 500 km |
3 |
4 |
|
|
2 500 to 10 000 |
5 |
6 |
|
|
Above 10 000 km |
8 |
10 |
Case 1 refers to processes in which a Natural Gas boiler is used to provide the process heat to the pellet mill. Process electricity is purchased from the grid.
Case 2a refers to processes in which a boiler fuelled with wood chips is used to provide the process heat to the pellet mill. Process electricity is purchased from the grid.
Case 3a refers to processes in which a CHP, fuelled with wood chips, is used to provide heat and electricity to the pellet mill.
|
Biomass fuel production system |
Transport distance |
Greenhouse gas emissions – typical value (g CO2eq/MJ) |
Greenhouse gas emissions – default value (g CO2eq/MJ) |
|
Agricultural Residues with density < 0,2 t/m3 (1) |
1 to 500 km |
4 |
4 |
|
500 to 2 500 km |
8 |
9 |
|
|
2 500 to 10 000 km |
15 |
18 |
|
|
Above 10 000 km |
29 |
35 |
|
|
Agricultural Residues with density > 0,2 t/m3 (2) |
1 to 500 km |
4 |
4 |
|
500 to 2 500 km |
5 |
6 |
|
|
2 500 to 10 000 km |
8 |
10 |
|
|
Above 10 000 km |
15 |
18 |
|
|
Straw pellets |
1 to 500 km |
8 |
10 |
|
500 to 10 000 km |
10 |
12 |
|
|
Above 10 000 km |
14 |
16 |
|
|
Bagasse briquettes |
500 to 10 000 km |
5 |
6 |
|
Above 10 000 km |
9 |
10 |
|
|
Palm Kernel Meal |
Above 10 000 km |
54 |
61 |
|
Palm Kernel Meal (no CH4 emissions from oil mill) |
Above 10 000 km |
37 |
40 |
|
(1)
This group of materials includes agricultural residues with a low bulk density and it comprises materials such as straw bales, oat hulls, rice husks and sugar cane bagasse bales (not exhaustive list).
(2)
The group of agricultural residues with higher bulk density includes materials such as corn cobs, nut shells, soybean hulls, palm kernel shells (not exhaustive list). |
|||
Typical and default values – biogas for electricity
|
Biogas production system |
Technological option |
Typical value |
Default value |
|
|
Greenhouse gas emissions (g CO2eq/MJ) |
Greenhouse gas emissions (g CO2eq/MJ) |
|||
|
Biogas for electricity from wet manure |
Case 1 |
Open digestate (1) |
– 28 |
3 |
|
Close digestate (2) |
– 88 |
– 84 |
||
|
Case 2 |
Open digestate |
– 23 |
10 |
|
|
Close digestate |
– 84 |
– 78 |
||
|
Case 3 |
Open digestate |
– 28 |
9 |
|
|
Close digestate |
– 94 |
– 89 |
||
|
Biogas for electricity from maize whole plant |
Case 1 |
Open digestate |
38 |
47 |
|
Close digestate |
24 |
28 |
||
|
Case 2 |
Open digestate |
43 |
54 |
|
|
Close digestate |
29 |
35 |
||
|
Case 3 |
Open digestate |
47 |
59 |
|
|
Close digestate |
32 |
38 |
||
|
Biogas for electricity from biowaste |
Case 1 |
Open digestate |
31 |
44 |
|
Close digestate |
9 |
13 |
||
|
Case 2 |
Open digestate |
37 |
52 |
|
|
Close digestate |
15 |
21 |
||
|
Case 3 |
Open digestate |
41 |
57 |
|
|
Close digestate |
16 |
22 |
||
|
(1)
Open storage of digestate accounts for additional emissions of methane which change with the weather, the substrate and the digestion efficiency. In these calculations the amounts are taken to be equal to 0,05 MJ CH4/MJ biogas for manure, 0,035 MJ CH4/MJ biogas for maize and 0,01 MJ CH4/MJ biogas for biowaste.
(2)
Close storage means that the digestate resulting from the digestion process is stored in a gas tight tank and the additional biogas released during storage is considered to be recovered for production of additional electricity or biomethane. |
||||
Typical and default values for biomethane
|
Biomethane production system |
Technological option |
Greenhouse gas emissions – typical value (g CO2eq/MJ) |
Greenhouse gas emissions – default value (g CO2eq/MJ) |
|
Biomethane from wet manure |
Open digestate, no off-gas combustion (1) |
– 20 |
22 |
|
Open digestate, off-gas combustion (2) |
– 35 |
1 |
|
|
Close digestate, no off-gas combustion |
– 88 |
– 79 |
|
|
Close digestate, off-gas combustion |
– 103 |
– 100 |
|
|
Biomethane from maize whole plant |
Open digestate, no off-gas combustion |
58 |
73 |
|
Open digestate, off-gas combustion |
43 |
52 |
|
|
Close digestate, no off-gas combustion |
41 |
51 |
|
|
Close digestate, off-gas combustion |
26 |
30 |
|
|
Biomethane from biowaste |
Open digestate, no off-gas combustion |
51 |
71 |
|
Open digestate, off-gas combustion |
36 |
50 |
|
|
Close digestate, no off-gas combustion |
25 |
35 |
|
|
Close digestate, off-gas combustion |
10 |
14 |
|
|
(1)
This category includes the following categories of technologies for biogas upgrade to biomethane: Pressure Swing Adsorption (PSA), Pressure Water Scrubbing (PWS), Membranes, Cryogenic, and Organic Physical Scrubbing (OPS). It includes an emission of 0,03 MJ CH4/MJ biomethane for the emission of methane in the off-gases.
(2)
This category includes the following categories of technologies for biogas upgrade to biomethane: Pressure Water Scrubbing (PWS) when water is recycled, Pressure Swing Adsorption (PSA), Chemical Scrubbing, Organic Physical Scrubbing (OPS), Membranes and Cryogenic upgrading. No methane emissions are considered for this category (the methane in the off-gas is combusted, if any). |
|||
Typical and default values – biogas for electricity – mixtures of manure and maize: greenhouse gas emissions with shares given on a fresh mass basis
|
Biogas production system |
Technological options |
Greenhouse gas emissions – typical value (g CO2eq/MJ) |
Greenhouse gas emissions – default value (g CO2eq/MJ) |
|
|
Manure – Maize 80 % - 20 % |
Case 1 |
Open digestate |
17 |
33 |
|
Close digestate |
– 12 |
– 9 |
||
|
Case 2 |
Open digestate |
22 |
40 |
|
|
Close digestate |
– 7 |
– 2 |
||
|
Case 3 |
Open digestate |
23 |
43 |
|
|
Close digestate |
– 9 |
– 4 |
||
|
Manure – Maize 70 % - 30 % |
Case 1 |
Open digestate |
24 |
37 |
|
Close digestate |
0 |
3 |
||
|
Case 2 |
Open digestate |
29 |
45 |
|
|
Close digestate |
4 |
10 |
||
|
Case 3 |
Open digestate |
31 |
48 |
|
|
Close digestate |
4 |
10 |
||
|
Manure – Maize 60 % - 40 % |
Case 1 |
Open digestate |
28 |
40 |
|
Close digestate |
7 |
11 |
||
|
Case 2 |
Open digestate |
33 |
47 |
|
|
Close digestate |
12 |
18 |
||
|
Case 3 |
Open digestate |
36 |
52 |
|
|
Close digestate |
12 |
18 |
||
Comments
Case 1 refers to pathways in which electricity and heat required in the process are supplied by the CHP engine itself.
Case 2 refers to pathways in which the electricity required in the process is taken from the grid and the process heat is supplied by the CHP engine itself. In some Member States, operators are not allowed to claim the gross production for subsidies and case 1 is the more likely configuration.
Case 3 refers to pathways in which the electricity required in the process is taken from the grid and the process heat is supplied by a biogas boiler. This case applies to some installations in which the CHP engine is not on-site and biogas is sold (but not upgraded to biomethane).
Typical and default values – biomethane - mixtures of manure and maize: greenhouse gas emissions with shares given on a fresh mass basis
|
Biomethane production system |
Technological options |
Typical value |
Default value |
|
(g CO2eq/MJ) |
(g CO2eq/MJ) |
||
|
Manure – Maize 80 % - 20 % |
Open digestate, no off-gas combustion |
32 |
57 |
|
Open digestate, off-gas combustion |
17 |
36 |
|
|
Close digestate, no off-gas combustion |
– 1 |
9 |
|
|
Close digestate, off-gas combustion |
– 16 |
– 12 |
|
|
Manure – Maize 70 % - 30 % |
Open digestate, no off-gas combustion |
41 |
62 |
|
Open digestate, off-gas combustion |
26 |
41 |
|
|
Close digestate, no off-gas combustion |
13 |
22 |
|
|
Close digestate, off-gas combustion |
– 2 |
1 |
|
|
Manure – Maize 60 % - 40 % |
Open digestate, no off-gas combustion |
46 |
66 |
|
Open digestate, off-gas combustion |
31 |
45 |
|
|
Close digestate, no off-gas combustion |
22 |
31 |
|
|
Close digestate, off-gas combustion |
7 |
10 |
Where biomethane is used as Compressed Biomethane as a transport fuel, a value of 3,3 g CO2eq/MJ biomethane needs to be added to the typical values and a value of 4,6 g CO2eq/MJ biomethane to the default values.
ANNEX VII
ACCOUNTING OF RENEWABLE ENERGY USED FOR HEATING AND COOLING
PART A: ACCOUNTING OF RENEWABLE ENERGY FROM HEAT PUMPS USED FOR HEATING
The amount of aerothermal, geothermal or hydrothermal energy captured by heat pumps to be considered to be energy from renewable sources for the purposes of this Directive, ERES, shall be calculated in accordance with the following formula:
ERES = Qusable * (1 – 1/SPF)
where
|
— |
Qusable |
= |
the estimated total usable heat delivered by heat pumps fulfilling the criteria referred to in Article 7(4), implemented as follows: Only heat pumps for which SPF > 1,15 * 1/η shall be taken into account, |
|
— |
SPF |
= |
the estimated average seasonal performance factor for those heat pumps, |
|
— |
Η |
= |
the ratio between total gross production of electricity and the primary energy consumption for the production of electricity and shall be calculated as an EU average based on Eurostat data. |
PART B: ACCOUNTING OF RENEWABLE ENERGY USED FOR COOLING
1. DEFINITIONS
When calculating renewable energy used for cooling the following definitions shall apply:
‘cooling’ means the extraction of heat from an enclosed or indoor space (comfort application) or from a process in order to reduce the space or process temperature to, or maintain it at, a specified temperature (set point); for cooling systems, the extracted heat is rejected into and absorbed by the ambient air, ambient water or the ground, where the environment (air, ground, and water) provides a sink for the heat extracted and thus functions as a cold source;
‘cooling system’ means an assembly of components consisting of a heat extraction system, one or several cooling devices and a heat rejection system, complemented in the case of active cooling with a cooling medium in the form of fluid that work together to generate a specified heat transfer and, thus, ensures a required temperature;
for space cooling, the cooling system can be either a free cooling system or a cooling system embedding a cooling generator, and for which cooling is one of the primary functions;
for process cooling, the cooling system is embedding a cooling generator, and for which cooling is one of the primary functions;
‘free cooling’ means a cooling system using a natural cold source to extract heat from the space or process to be cooled via fluid(s) transportation with pump(s) and/or fan(s) and which does not require the use of a cooling generator;
‘cooling generator’ means the part of a cooling system that generates a temperature difference allowing heat extraction from the space or process to be cooled, using a vapour compression cycle, a sorption cycle or driven by another thermodynamic cycle, used when the cold source is unavailable or insufficient;
‘active cooling’ means the removal of heat from a space or process, for which an energy input is needed to meet the cooling demand, used when the natural flow of energy is unavailable or insufficient and can occur with or without a cooling generator;
‘passive cooling’ means the removal of heat by the natural flow of energy through conduction, convection, radiation or mass transfer without the need for moving a cooling fluid to extract and reject heat or to generate a lower temperature with a cooling generator, including decreasing the need for cooling by building design features such as building insulation, green roof, vegetal wall, shading or increased building mass, by ventilation or by using comfort fans;
‘ventilation’ means the natural or forced movement of air to introduce ambient air inside a space with the aim to ensure appropriate indoor air quality, including temperature;
‘comfort fan’ means a product that includes a fan and electric motor assembly to move air and provide summer comfort by increasing the air speed around human body giving a thermal feeling of coolness;
‘renewable energy quantity for cooling’ means the cooling supply that has been generated with a specified energy efficiency expressed as a Seasonal Performance Factor calculated in primary energy;
‘heat sink’ or ‘cold source’ means an external natural sink into which the heat extracted from the space or process is transferred; it can be ambient air, ambient water in the form of natural or artificial water bodies and geothermal formations beneath the surface of solid earth;
‘heat extraction system’ means a device that removes heat from the space or process to be cooled, such as an evaporator in a vapour compression cycle;
‘cooling device’ means a device designed to perform active cooling;
‘heat rejection system’ means the device where the final heat transfer from the cooling medium to the heat sink occurs, such as the air-to-refrigerant condenser in an air-cooled vapour compression cycle;
‘energy input’ means the energy needed to transport the fluid (free cooling), or the energy needed to transport the fluid and to drive the cooling generator (active cooling with a cooling generator);
‘district cooling’ means the distribution of thermal energy in the form of chilled liquids, from central or decentralised sources of production through a network to multiple buildings or sites, for the use of space or process cooling;
‘primary seasonal performance factor’ means a metric of the primary energy conversion efficiency of the cooling system;
‘equivalent full load hours’ means the number of hours a cooling system runs with full load to produce the amount of cooling that it actually produces during a year but at varying loads;
‘Cooling Degree Days’ means the climate values computed with a base of 18 °C used as input to determine equivalent full load hours.
2. SCOPE
When calculating the amount of renewable energy used for cooling, Member States shall count active cooling, including district cooling, regardless of whether it is free cooling or a cooling generator is used.
Member States shall not count:
passive cooling, although where ventilation air is used as a heat transport medium for cooling, the corresponding cooling supply, which can be supplied either by a cooling generator or by free cooling is part of renewable cooling calculation.
the following technologies or processes of cooling:
cooling in means of transportation ( 23 );
cooling systems whose primary function is to produce or store perishable materials at specified temperatures (refrigeration and freezing);
cooling systems with space or process cooling temperature set points lower than 2 °C;
cooling systems with space or process cooling temperature set points above 30 °C;
cooling of waste heat resulting from energy generation, industrial processes and the tertiary sector (waste heat) ( 24 ).
energy used for cooling in power generation plants; cement, iron and steel manufacturing; wastewater treatment plants; information technology facilities (such as data centres); power transmission and distribution facilities; and transportation infrastructures.
Member States may exclude more categories of cooling systems from the calculation of the renewable energy used for cooling in order to preserve natural cold sources in specific geographic areas for environmental protection reasons. Examples are the protection of rivers or lakes from the risk of overheating.
3. METHODOLOGY FOR ACCOUNTING OF RENEWABLE ENERGY FOR INDIVIDUAL AND DISTRICT COOLING
Only cooling systems operating above the minimum efficiency requirement expressed as primary Seasonal Performance Factor (SPFp) in section 3.2, second paragraph shall be considered to produce renewable energy.
3.1. Renewable energy quantity for cooling
The renewable energy quantity for cooling (ERES-C) shall be calculated with the following formula:
where:
is the amount of heat released to the ambient air, ambient water or to the ground by the cooling system (
25
);
EINPUT is the energy consumption of the cooling system, including energy consumption of the auxiliary systems for measured systems, such as district cooling;
is the cooling energy supplied by the cooling system (
26
);
is defined at cooling system level as the share of the cooling supply that can be considered as renewable according to the SPF requirements, expressed as a percentage. The SPF is established without accounting for distribution losses. For district cooling, this means that the SPF is established per cooling generator, or at free cooling system level. For cooling systems where standard SPF can apply, the F(1) and F(2) coefficients according to Commission Regulation (EU) 2016/2281 (
27
) and the linked Commission Communication (
28
) are not used as correction factors.
For 100 % renewable heat driven cooling (absorption and adsorption) the cooling delivered should be considered fully renewable.
The calculation steps needed for and 
are explained in Sections 3.2 to 3.4.
3.2.
Calculation of the share of Seasonal Performance Factor that qualifies as renewable energy –
SSPF
is the share of cooling supply that can be counted as renewable. The increases with increasing SPFp values. The SPFp
(
29
) is defined as described in Commission Regulation (EU) 2016/2281 and Commission Regulation (EU) No 206/2012 (
30
), except that the default primary energy factor for electricity has been updated to 2.1 in Directive 2012/27/EU (as amended by Directive (EU) 2018/2002 (
31
)) of the European Parliament and of the Council. Boundary conditions from the EN14511 standard shall be used.
The minimum efficiency requirement of the cooling system expressed in primary seasonal performance factor shall be at least 1.4 (SPFpLOW
). For to be 100 % the minimum efficiency requirement of the cooling system shall be at least 6 (SPFpHIGH
). For all the other cooling systems the following calculation shall be applied:
SPFp is the efficiency of the cooling system expressed as primary seasonal performance factor;
is the minimum seasonal performance factor expressed in primary energy and based upon the efficiency of standard cooling systems (minimum eco-design requirements);
is the upper threshold for seasonal performance factor expressed in primary energy and based on best practices for free cooling used in district cooling (
32
).
3.3. Calculation of renewable energy quantity for cooling using standard and measured SPFp
Standard and measured SPF
Standardised SPF values are available for electric vapour compression cooling generators and combustion engine vapour compression cooling generator due to the Ecodesign requirements in Regulation (EU) No 206/2012 and (EU) No 2016/2281. Values are available for these cooling generators up to 2 MW for comfort cooling and up to 1.5 MW for process cooling. For other technologies and capacity scales standard values are not available. As regards district cooling, standard values are not available but measurements are used and available; these allow to compute SPF values at least on a yearly basis.
To calculate the quantity of renewable cooling, standard SPF values may be used where available. Where standard values are not available or measurement is standard practice, measured SPF values shall be used, separated by cooling capacity thresholds. For cooling generators with a cooling capacity below 1.5 MW, standard SPF can be used, while measured SPF shall be used for district cooling, for cooling generators with cooling capacities higher than or equal to 1.5 MW and cooling generators for which standard values are not available.
In addition, for all cooling systems without standard SPF, which includes all free cooling solutions and heat activated cooling generators, a measured SPF shall be established in order to take advantage of the calculation methodology for renewable cooling.
Definition of standard SPF values
SPF values are expressed in terms of primary energy efficiency calculated using primary energy factors following Regulation (EU) 2016/2281 to determine the space cooling efficiency for the different types of cooling generators ( 33 ). The primary energy factor in Regulation (EU) 2016/2281 shall be calculated as 1/η, where η is the average ratio of total gross production of electricity to the primary energy consumption for electricity production in the whole EU. With the amendment of the default primary energy factor for electricity, called coefficient in point (1) of the Annex to Directive (EU) 2018/2002 amending footnote (3) in Annex IV of Directive 2012/27/EU, the primary energy factor of 2.5 in Regulation (EU) 2016/2281 shall be replaced by 2.1 when calculating the SPF values.
When primary energy carriers, such as heat or gas are used as energy input to drive the cooling generator, the default primary energy factor (1/η) is 1, reflecting the lack of energy transformation η = 1.
The standard operating conditions and the other parameters necessary for the determination of the SPF are defined in Regulation (EU) 2016/2281 and Regulation (EU) No 206/2012, depending on the cooling generator category. Boundary conditions are the ones defined in the EN14511 standard.
For reversible cooling generators (reversible heat pumps), which are excluded from the scope of Regulation (EU) 2016/2281 because their heating function is covered by Commission Regulation (EU) No 813/2013 ( 34 ) with regard to Ecodesign requirements for space heaters and combination heaters, the same SPF calculation that is defined for similar non reversible cooling generators in Regulation (EU) 2016/2281 shall be used.
For instance, for electric vapour compression cooling generators, the SPFp shall be defined as follows (the index p is used to clarify that the SPF is defined in terms of primary energy):
Where:
F(1) and F(2) are correction factors according to Regulation (EU) 2016/2281 and the linked Commission Communication. These coefficients do not apply to process cooling in Regulation (EU) 2016/2281 as the SEPR final energy metrics is directly used. In absence of adapted values, the same values used for SEER conversion shall be used for the SEPR conversion.
SPF boundary conditions
For defining the SPF of the cooling generator, the SPF boundary conditions defined in Regulation (EU) No 2281/2016 and in Regulation (EU) No 206/2012 shall be used. In the case of water-to-air and water-to-water cooling generators, the energy input required to make the cold source available is included via the F(2) correction factor. The SPF boundary conditions are shown in Figure 1. These boundary conditions shall apply for all cooling systems, either free cooling systems or systems containing cooling generators.
These boundary conditions are similar to the ones for heat pumps (used in heating mode) in Commission Decision 2013/114/EU ( 36 ). The difference is that for heat pumps, the electricity consumption corresponding to auxiliary power consumption (thermostat-off mode, standby mode, off mode, crankcase heater) is not taken into account to evaluate the SPF. However, as in the case of cooling both standard SPF values and measured SPF will be used, and given the fact that in the measured SPF auxiliary consumption is taken into account, it is necessary to include auxiliary power consumption in both situations.
For district cooling, distribution cold losses and distribution pump electric consumption between the cooling plant and the customer substation shall not be included in the estimation of the SPF.
In the case of air based cooling systems ensuring also the ventilation function, the cooling supply due to ventilation air flow shall not be accounted. The fan power needed for the ventilation shall also be discounted in proportion of the ratio of the ventilation air flow to the cooling air flow.
Figure 1 Illustration of SPF boundary conditions for cooling generator using standard SPF and district cooling (and other large cooling systems using measured SPF), where EINPUT_AUX is the energy input to fan and/or pump and EINPUT_CG the energy input to the cooling generator
In the case of air based cooling systems with internal cold recovery, the cooling supply due to the cold recovery shall not be accounted. The fan power needed for the cold recovery performed by the heat exchanger shall be discounted in proportion of the ratio of the pressure losses due to the cold recovery heat exchanger to the total pressure losses of the air based cooling system.
3.4. Calculation using standard values
A simplified method may be used for individual cooling systems of less than 1.5 MW capacity, for which a standard SPF value is available, to estimate the total cooling energy supplied.
Under the simplified method, the cooling energy supplied by the cooling system (QCsupply) is the nominal cooling capacity (Pc) multiplied by the number of equivalent full load hours (EFLH). A single Cooling Degree Days (CDD) value may be used for a whole country, or distinct values for different climate zones provided that nominal capacities and SPFs are available for these climate zones.
The following default methods may be used to compute EFLH:
Where:
τs is an activity factor to account for the operation time of the specific processes (e.g. all year long τs = 1, not on weekends τs = 5/7). There is no default value.
3.4.1. Calculation using measured values
Systems for which no standard values exist, as well as cooling systems larger than 1.5 MW capacity and district cooling systems, shall calculate their renewable cooling based on the following measurements:
Measured energy input: The measured energy input includes all energy sources for the cooling system, including any cooling generator, i.e. electricity, gas, heat etc.. It includes also auxiliary pumps and fans used in the cooling system but not for the distribution of cooling to a building or a process. In case of air-based cooling with ventilation function, only the additional energy input due to cooling shall be included in the energy input of the cooling system.
Measured cooling energy supply: The cooling energy supply shall be measured as the output from the cooling system and subtracted any cold losses in order to estimate the net cooling energy supply to the building or process that is the end-user of the cooling. The cold losses include losses in a district cooling system and in the cooling distribution system in a building or an industrial site. In case of air-based cooling with ventilation function, the cooling energy supply shall be net of the effect of fresh air introduction for ventilation purposes.
The measurements need to be carried out for the specific year to be reported i.e. all energy input and all cooling energy supply for the whole year.
3.4.2. District cooling: additional requirements
For district cooling systems the net cooling supply at customer level shall be accounted when defining the net cooling supply, denoted as QC_Supply_net Thermal losses occurring in the distribution network (Qc_LOSS ) shall be deducted from the gross cooling supply (Qc_Supply_gross ) as follows:
QC_Supply_net = Qc_Supply_gross- - Qc_LOSS
3.4.2.1.
District cooling systems can be divided in subsystems, which comprise at least one cooling generator or free cooling system. This requires the measurement of the cooling energy supply and of the energy input for each sub-system as well as the allocation of cold losses per sub-system as follows:
3.4.2.2.
When dividing a cooling system into subsystems, the auxiliaries (e.g. controls, pumps and fans) of the cooling generator(s) and/or free cooling system(s) shall be included in the same subsystem(s). Auxiliary energy corresponding to cooling distribution inside the building, e.g. secondary pumps and terminal units (e.g. fan coils, fans of air handling units) are not accounted for.
For auxiliaries which cannot be allocated to a specific subsystem, for instance district cooling network pumps which deliver the cooling energy supplied by all cooling generators, their primary energy consumption shall be allocated to each cooling subsystem in the proportion of the cooling energy supplied by the cooling generators and/or the free cooling systems of each subsystem, in the same way as with cold losses in the network, as follows
where:
EINPUT_AUX1_i is the auxiliary energy consumption of subsystem ‘I’;
EINPUT_AUX12 is the auxiliary energy consumption of the entire cooling system, which cannot be allocated to a specific cooling subsystem.
3.5. Calculation of renewable energy quantity for cooling for the overall renewable shares and for the heating and cooling renewable energy shares
For the calculation of the overall renewable energy shares, the renewable energy quantity for cooling shall be added both to the numerator ‘gross final consumption of energy from renewable sources’ and to the denominator ‘gross final consumption of energy’.
For the calculation of the heating and cooling renewable energy shares the renewable energy quantity for cooling shall be added both to the numerator ‘gross final consumption of energy from renewable sources for heating and cooling’ and to the denominator ‘gross final consumption of energy for heating and cooling’.
3.6. Guidance on the development of more accurate methodologies and calculations
It is envisaged and encouraged that Member States do their own estimations for both SPF and EFLH. Any such national/regional approaches should be based on accurate assumptions, representative samples of sufficient size, resulting in a significantly improved estimate of renewable energy compared to that obtained using the methodology set out in this Delegated Act. Such improved methodologies may be based on detailed calculation based on technical data taking into account, among other factors, year of installation, quality of installation, compressor type and machine size, operation mode, distribution system, cascading of generators and the regional climate. Member States that use alternative methodologies and/or values shall submit them to the Commission together with a report describing the method and data used. The Commission will, if necessary, translate the documents and publish them on its transparency platform.
ANNEX VIII
PART A. PROVISIONAL ESTIMATED INDIRECT LAND-USE CHANGE EMISSIONS FROM BIOFUEL, BIOLIQUID AND BIOMASS FUEL FEEDSTOCK (g CO2eq/MJ) ( 37 )
|
Feedstock group |
Mean (1) |
Interpercentile range derived from the sensitivity analysis (2) |
|
Cereals and other starch-rich crops |
12 |
8 to 16 |
|
Sugars |
13 |
4 to 17 |
|
Oil crops |
55 |
33 to 66 |
|
(1)
The mean values included here represent a weighted average of the individually modelled feedstock values.
(2)
The range included here reflects 90 % of the results using the fifth and ninety-fifth percentile values resulting from the analysis. The fifth percentile suggests a value below which 5 % of the observations were found (namely, 5 % of total data used showed results below 8, 4, and 33 g CO2eq/MJ). The ninety-fifth percentile suggests a value below which 95 % of the observations were found (namely, 5 % of total data used showed results above 16, 17, and 66 g CO2eq/MJ). |
||
PART B. BIOFUELS, BIOLIQUIDS AND BIOMASS FUELS FOR WHICH THE ESTIMATED INDIRECT LAND-USE CHANGE EMISSIONS ARE CONSIDERED TO BE ZERO
Biofuels, bioliquids and biomass fuels produced from the following feedstock categories will be considered to have estimated indirect land-use change emissions of zero:
feedstocks which are not listed under part A of this Annex.
feedstocks, the production of which has led to direct land-use change, namely, a change from one of the following IPCC land cover categories: forest land, grassland, wetlands, settlements, or other land, to cropland or perennial cropland ( 38 ). In such a case a direct land-use change emission value (el) should have been calculated in accordance with point 7 of part C of Annex V.
ANNEX IX
Part A. Feedstocks for the production of biogas for transport and advanced biofuels, the contribution of which towards the minimum shares referred to in the first and fourth subparagraphs of Article 25(1) may be considered to be twice their energy content:
Algae if cultivated on land in ponds or photobioreactors;
Biomass fraction of mixed municipal waste, but not separated household waste subject to recycling targets under point (a) of Article 11(2) of Directive 2008/98/EC;
Biowaste as defined in point (4) of Article 3 of Directive 2008/98/EC from private households subject to separate collection as defined in point (11) of Article 3 of that Directive;
Biomass fraction of industrial waste not fit for use in the food or feed chain, including material from retail and wholesale and the agro-food and fish and aquaculture industry, and excluding feedstocks listed in part B of this Annex;
Straw;
Animal manure and sewage sludge;
Palm oil mill effluent and empty palm fruit bunches;
Tall oil pitch;
Crude glycerine;
Bagasse;
Grape marcs and wine lees;
Nut shells;
Husks;
Cobs cleaned of kernels of corn;
Biomass fraction of wastes and residues from forestry and forest-based industries, namely, bark, branches, pre-commercial thinnings, leaves, needles, tree tops, saw dust, cutter shavings, black liquor, brown liquor, fibre sludge, lignin and tall oil;
Other non-food cellulosic material;
Other ligno-cellulosic material except saw logs and veneer logs.
Part B. Feedstocks for the production of biofuels and biogas for transport, the contribution of which towards the minimum share established in the first subparagraph of Article 25(1) shall be limited and may be considered to be twice their energy content:
Used cooking oil;
Animal fats classified as categories 1 and 2 in accordance with Regulation (EC) No 1069/2009.
ANNEX X
PART A
Repealed Directive with a list of the successive amendments thereto (referred to in Article 37)
|
Directive 2009/28/EC of the European Parliament and of the Council (OJ L 140, 5.6.2009, p. 16) |
|
|
Council Directive 2013/18/EU (OJ L 158, 10.6.2013, p. 230) |
|
|
Directive (EU) 2015/1513 of the European Parliament and of the Council (OJ L 239, 15.9.2015, p. 1) |
Only Article 2 |
PART B
Time-limits for transposition into national law
(referred to in Article 36)
|
Directive |
Time-limit for transposition |
|
2009/28/EC |
25 June 2009 |
|
2013/18/EU |
1 July 2013 |
|
(EU) 2015/1513 |
10 September 2017 |
ANNEX XI
Correlation table
|
Directive 2009/28/EC |
This Directive |
|
Article 1 |
Article 1 |
|
Article 2, first subparagraph |
Article 2, first subparagraph |
|
Article 2, second subparagraph, introductory wording |
Article 2, second subparagraph, introductory wording |
|
Article 2, second subparagraph, point (a) |
Article 2, second subparagraph, point (1) |
|
Article 2, second subparagraph, point (b) |
— |
|
— |
Article 2, second subparagraph, point (2) |
|
Article 2, second subparagraph, point (c) |
Article 2, second subparagraph, point (3) |
|
Article 2, second subparagraph, point (d) |
— |
|
Article 2, second subparagraph, points (e), (f), (g), (h), (i), (j), (k), (l), (m), (n), (o), (p), (q), (r), (s), (t), (u), (v) and (w) |
Article 2, second subparagraph, points (24), (4), (19), (32), (33), (12), (5), (6), (45), (46), (47), (23), (39), (41), (42), (43), (36), (44) and (37) |
|
— |
Article 2, second subparagraph, points (7), (8), (9), (10), (11), (13), (14), (15), (16), (17), (18), (20), (21), (22), (25), (26), (27), (28), (29), (30), (31), (34), (35), (38) and (40) |
|
Article 3 |
— |
|
— |
Article 3 |
|
Article 4 |
— |
|
— |
Article 4 |
|
— |
Article 5 |
|
— |
Article 6 |
|
Article 5(1) |
Article 7(1) |
|
Article 5(2) |
— |
|
Article 5(3) |
Article 7(2) |
|
Article 5(4), first, second, third and fourth subparagraphs |
Article 7(3), first, second, third and fourth subparagraphs |
|
— |
Article 7(3), fifth and sixth subparagraphs |
|
— |
Article 7(4) |
|
Article 5(5), |
Article 27(1), first subparagraph, point (c) |
|
Article 5(6) and (7) |
Article 7(5) and (6) |
|
Article 6(1) |
Article 8(1) |
|
— |
Article 8(2) and (3) |
|
Article 6(2) and (3) |
Article 8(4) and (5) |
|
Article 7(1), (2), (3), (4) and (5) |
Article 9(1), (2), (3), (4) and (5) |
|
— |
Article 9(6) |
|
Article 8 |
Article 10 |
|
Article 9(1) |
Article 11(1) |
|
Article 9(2), first subparagraph, points (a), (b) and (c) |
Article 11(2), first subparagraph, points (a), (b) and (c) |
|
— |
Article 11(2), first subparagraph, point (d) |
|
Article 10 |
Article 12 |
|
Article 11(1), (2) and (3) |
Article 13(1), (2) and (3) |
|
— |
Article 13(4) |
|
Article 12 |
Article 14 |
|
Article 13(1), first subparagraph |
Article 15(1), first subparagraph |
|
Article 13(1), second subparagraph |
Article 15(1), second subparagraph |
|
Article 13(1), second subparagraph, points (a) and (b) |
— |
|
Article 13(1), second subparagraph, points (c), (d), (e) and (f) |
Article 15(1), second subparagraph, points (a), (b), (c) and (d) |
|
Article 13(2), (3), (4) and (5) |
Article 15(2), (3), (4) and (5) |
|
Article 13(6), first subparagraph |
Article 15(6), first subparagraph |
|
Article 13(6), second, third, fourth and fifth subparagraphs |
— |
|
— |
Article 15, (7) and (8) |
|
— |
Article 16 |
|
— |
Article 17 |
|
Article 14 |
Article 18 |
|
Article 15(1) |
Article 19(1) |
|
Article 15(2), first, second and third subparagraphs |
Article 19(2) first, second and third subparagraphs |
|
— |
Article 19(2), fourth and fifth subparagraphs |
|
Article 15(2), fourth subparagraph |
Article 19(2), sixth subparagraph |
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Article 15(3) |
— |
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— |
Article 19(3) and (4) |
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Article 15(4) and (5) |
Article 19(5) and (6) |
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Article 15(6), first subparagraph, point (a) |
Article 19(7), first subparagraph, point (a) |
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Article 15(6), first subparagraph, point (b)(i) |
Article 19(7), first subparagraph, point (b)(i) |
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— |
Article 19(7), first subparagraph, point (b)(ii) |
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Article 15(6), first subparagraph, point (b)(ii) |
Article 19(7), first subparagraph, point (b)(iii) |
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Article 15(6), first subparagraph, points (c), (d), (e) and (f) |
Article 19(7), first subparagraph, points (c), (d), (e) and (f) |
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— |
Article 19(7), second subparagraph |
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Article 15(7) |
Article 19(8) |
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Article 15(8) |
— |
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Article 15(9) and (10) |
Article 19(9) and (10) |
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— |
Article 19(11) |
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Article 15(11) |
Article 19(12) |
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Article 15(12) |
— |
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— |
Article 19(13) |
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Article 16(1), (2), (3), (4), (5), (6), (7) and (8) |
— |
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Article 16(9), (10) and (11) |
Article 20(1), (2) and (3) |
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— |
Article 21 |
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— |
Article 22 |
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— |
Article 23 |
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— |
Article 24 |
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— |
Article 25 |
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— |
Article 26 |
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— |
Article 27 |
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— |
Article 28 |
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Article 17(1), first and second subparagraphs |
Article 29(1), first and second subparagraphs |
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— |
Article 29(1), third, fourth and fifth subparagraphs |
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— |
Article 29(2) |
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Article 17(2), first and second subparagraphs |
— |
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Article 17(2), third subparagraph |
Article 29(10), third subparagraph |
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Article 17(3), first subparagraph, point (a) |
Article 29(3), first subparagraph, point (a) |
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— |
Article 29(3), first subparagraph, point (b) |
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Article 17(3), first subparagraph, points (b) and (c) |
Article 29(3), first subparagraph, points (c) and (d) |
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— |
Article 29(3), second subparagraph |
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Article 17(4) |
Article 29(4) |
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Article 17(5) |
Article 29(5) |
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Article 17(6) and (7) |
— |
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— |
Article 29(6), (7), (8), (9), (10) and (11) |
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Article 17(8) |
Article 29(12) |
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Article 17(9) |
— |
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— |
Article 29(13) and (14) |
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Article 18(1), first subparagraph |
Article 30(1), first subparagraph |
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Article 18(1), first subparagraph, points (a), (b) and (c) |
Article 30(1), first subparagraph, points (a), (c) and (d) |
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— |
Article 30(1), first subparagraph, point (b) |
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— |
Article 30(1), second subparagraph |
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Article 18(2) |
— |
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— |
Article 30(2) |
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Article 18(3), first subparagraph |
Article 30(3), first subparagraph |
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Article 18(3), second and third subparagraphs |
— |
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Article 18(3), fourth and fifth subparagraphs |
Article 30(3), second and third subparagraphs |
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Article 18(4), first subparagraph |
— |
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Article 18(4), second and third subparagraphs |
Article 30(4), first and second subparagraphs |
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Article 18(4), fourth subparagraph |
— |
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Article 18(5), first and second subparagraphs |
Article 30(7), first and second subparagraphs |
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Article 18(5), third subparagraph |
Article 30(8), first and second subparagraphs |
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Article 18(5), fourth subparagraph |
Article 30(5), third subparagraph |
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— |
Article 30(6), first subparagraph |
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Article 18(5), fifth subparagraph |
Article 30(6), second subparagraph |
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Article 18(6), first and second subparagraphs |
Article 30(5), first and second subparagraphs |
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Article 18(6), third subparagraph |
— |
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Article 18(6), fourth subparagraph |
Article 30(6), third subparagraph |
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— |
Article 30(6), fourth subparagraph |
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Article 18(6), fifth subparagraph |
Article 30(6), fifth subparagraph |
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Article 18(7) |
Article 30(9), first subparagraph |
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— |
Article 30(9), second subparagraph |
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Article 18(8) and (9) |
— |
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— |
Article 30(10) |
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Article 19(1), first subparagraph |
Article 31(1), first subparagraph |
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Article 19(1), first subparagraph, points (a), (b) and (c) |
Article 31(1), first subparagraph, points (a), (b) and (c) |
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— |
Article 31(1), first subparagraph, point (d) |
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Article 19(2), (3) and (4) |
Article 31(2), (3) and (4) |
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Article 19(5) |
— |
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Article 19(7), first subparagraph |
Article 31(5), first subparagraph |
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Article 19(7), first subparagraph, first, second third and fourth indents |
— |
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Article 19(7), second and third subparagraphs |
Article 31(5), second and third subparagraphs |
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Article 19(8) |
Article 31(6) |
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Article 20 |
Article 32 |
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Article 22 |
— |
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Article 23(1) and (2) |
Article 33(1) and (2) |
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Article 23(3), (4), (5), (6), (7) and (8) |
— |
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Article 23(9) |
Article 33(3) |
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Article 23(10) |
Article 33(4) |
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Article 24 |
— |
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Article 25(1) |
Article 34(1) |
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Article 25(2) |
Article 34(2) |
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Article 25(3) |
Article 34(3) |
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Article 25a(1) |
Article 35(1) |
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Article 25a(2) |
Article 35(2) and (3) |
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Article 25a(3) |
Article 35(4) |
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— |
Article 35(5) |
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Article 25a(4) and (5) |
Article 35(6) and (7) |
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Article 26 |
— |
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Article 27 |
Article 36 |
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— |
Article 37 |
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Article 28 |
Article 38 |
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Article 29 |
Article 39 |
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Annex I |
Annex I |
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Annex II |
Annex II |
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Annex III |
Annex III |
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Annex IV |
Annex IV |
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Annex V |
Annex V |
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Annex VI |
— |
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— |
Annex VI |
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Annex VII |
Annex VII |
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Annex VIII |
Annex VIII |
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Annex IX |
Annex IX |
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— |
Annex X |
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— |
Annex XI |
( 1 ) Directive 2009/72/EC of the European Parliament and of the Council of 13 July 2009 concerning common rules for the internal market in electricity and repealing Directive 2003/54/EC (OJ L 211, 14.8.2009, p. 55).
( 2 ) Regulation (EU, Euratom) 2018/1046 of the European Parliament and of the Council of 18 July 2018 on the financial rules applicable to the general budget of the Union, amending Regulations (EU) No 1296/2013, (EU) No 1301/2013, (EU) No 1303/2013, (EU) No 1304/2013, (EU) No 1309/2013, (EU) No 1316/2013, (EU) No 223/2014, (EU) No 283/2014, and Decision No 541/2014/EU and repealing Regulation (EU, Euratom) No 966/2012 (OJ L 193, 30.7.2018, p. 1).
( 3 ) 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).
( 4 ) Directive 2009/73/EC of the European Parliament and of the Council of 13 July 2009 concerning common rules for the internal market in natural gas and repealing Directive 2003/55/EC (OJ L 211, 14.8.2009, p. 94).
( 5 ) Commission Implementing Decision (EU) 2017/1442 of 31 July 2017 establishing best available techniques (BAT) conclusions, under Directive 2010/75/EU of the European Parliament and of the Council, for large combustion plants (OJ L 212, 17.8.2017, p. 1).
( 6 ) Regulation (EC) No 1059/2003 of the European Parliament and of the Council of 26 May 2003 on the establishment of a common classification of territorial units for statistics (NUTS) (OJ L 154, 21.6.2003, p. 1).
( 7 ) 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 (OJ L 350, 28.12.1998, p. 58).
( 8 ) In order to be able to achieve the national objectives set out in this Annex, it is underlined that the State aid guidelines for environmental protection recognise the continued need for national mechanisms of support for the promotion of energy from renewable sources.
( 9 ) Heat or waste heat is used to generate cooling (chilled air or water) through absorption chillers . Therefore, it is appropriate to calculate only the emissions associated to the heat produced per MJ of heat, irrespectively if the end-use of the heat is actual heating or cooling via absorption chillers.
( 10 ) The formula for calculating greenhouse gas emissions from the extraction or cultivation of raw materials eec describes cases where feedstock is converted into biofuels in one step. For more complex supply chains, adjustments are needed for calculating greenhouse gas emissions from the extraction or cultivation of raw materials eec for intermediate products.
( 11 ) Measurements of soil carbon can constitute such evidence, e.g. by a first measurement in advance of the cultivation and subsequent ones at regular intervals several years apart. In such a case, before the second measurement is available, increase in soil carbon would be estimated on the basis of representative experiments or soil models. From the second measurement onwards, the measurements would constitute the basis for determining the existence of an increase in soil carbon and its magnitude.
( 12 ) The quotient obtained by dividing the molecular weight of CO2 (44,010 g/mol) by the molecular weight of carbon (12,011 g/mol) is equal to 3,664.
( 13 ) Commission Decision 2010/335/EU of 10 June 2010 on guidelines for the calculation of land carbon stocks for the purpose of Annex V to Directive 2009/28/EC (OJ L 151, 17.6.2010, p. 19).
( 14 ) Regulation (EU) 2018/841 of the European Parliament and of the Council of 30 May 2018 on the inclusion of greenhouse gas emissions and removals from land use, land use change and forestry in the 2030 climate and energy framework, and amending Regulation (EU) No 525/2013 and Decision No 529/2013/EU (OJ L 156, 19.6.2018, p. 1).
( 15 ) Directive 2009/31/EC of the European Parliament and of the Council of 23 April 2009 on the geological storage of carbon dioxide and amending Council Directive 85/337/EEC, European Parliament and Council Directives 2000/60/EC, 2001/80/EC, 2004/35/EC, 2006/12/EC, 2008/1/EC and Regulation (EC) No 1013/2006 (OJ L 140, 5.6.2009, p. 114).
( 16 ) Heat or waste heat is used to generate cooling (chilled air or water) through absorption chillers. Therefore, it is appropriate to calculate only the emissions associated to the heat produced, per MJ of heat, irrespectively if the end-use of the heat is actual heating or cooling via absorption chillers.
( 17 ) The formula for calculating greenhouse gas emissions from the extraction or cultivation of raw materials eec describes cases where feedstock is converted into biofuels in one step. For more complex supply chains, adjustments are needed for calculating greenhouse gas emissions from the extraction or cultivation of raw materials eec for intermediate products.
( 18 ) Measurements of soil carbon can constitute such evidence, e.g. by a first measurement in advance of the cultivation and subsequent ones at regular intervals several years apart. In such a case, before the second measurement is available, increase in soil carbon would be estimated on the basis of representative experiments or soil models. From the second measurement onwards, the measurements would constitute the basis for determining the existence of an increase in soil carbon and its magnitude.
( 19 ) The quotient obtained by dividing the molecular weight of CO2 (44,010 g/mol) by the molecular weight of carbon (12,011 g/mol) is equal to 3,664.
( 20 ) Cropland as defined by IPCC.
( 21 ) Perennial crops are defined as multi-annual crops, the stem of which is usually not annually harvested such as short rotation coppice and oil palm.
( 22 ) Commission Decision 2010/335/EU of 10 June 2010 on guidelines for the calculation of land carbon stocks for the purpose of Annex V to Directive 2009/28/EC (OJ L 151, 17.6.2010, p. 19).
( 23 ) The renewable cooling definition concerns only stationary cooling.
( 24 ) Waste heat is defined in Article 2(9) of this Directive. Waste heat can be accounted for the purposes of Articles 23 and 24 of this Directive.
( 25 ) The quantity of cold source corresponds to the quantity of heat absorbed by ambient air, ambient water and the ground acting as heat sinks. Ambient air and ambient water correspond to ambient energy as defined in Article 2(2) of this Directive. The ground correspond to geothermal energy as defined in Article 2(3) of this Directive.
( 26 ) From a thermodynamical point of view, cooling supply corresponds to a portion of the heat released by a cooling system to ambient air, ambient water or to the ground, which function as a heat sink or cold source. Ambient air and ambient water correspond to ambient energy as defined in Article 2(2) of this Directive. The heat sink or cold source function of the ground corresponds to geothermal energy as defined in Article 2(3) of this Directive.
( 27 ) Commission Regulation (EU) 2016/2281 of 30 November 2016 implementing Directive 2009/125/EC of the European Parliament and of the Council establishing a framework for the setting of ecodesign requirements for energy-related products, with regard to ecodesign requirements for air heating products, cooling products, high temperature process chillers and fan coil units (OJ L 346, 20.12.2016, p. 1).
( 28 ) https://eur-lex.europa.eu/legal-content/EN/TXT/?uri=uriserv:OJ.C_.2017.229.01.0001.01.ENG&toc=OJ:C:2017:229:TOC
( 29 ) In case the real operating conditions of cooling generators lead to SPF values substantially lower than planned in standard conditions because of different installation provisions, Member States may exclude these systems from the scope of the renewable cooling definition (e.g. a water cooled cooling generator using a dry cooler instead of a cooling tower to release heat to ambient air).
( 30 ) Commission Regulation (EU) No 206/2012 of 6 March 2012 implementing Directive 2009/125/EC of the European Parliament and of the Council with regard to ecodesign requirements for air conditioners and comfort fans (OJ L 72, 10.3.2012, p. 7).
( 31 ) Directive (EU) 2018/2002 of the European Parliament and of the Council of 11 December 2018 amending Directive 2012/27/EU on energy efficiency (OJ L 328, 21.12.2018, p. 210).
( 32 ) ENER/C1/2018-493, Renewable cooling under the revised Renewable Energy Directive, TU-Wien, 2021.
( 33 ) SPFp is identical to η s,c defined in Regulation (EU) No 2016/2281.
( 34 ) Commission Regulation (EU) No 813/2013 of 2 August 2013 implementing Directive 2009/125/EC of the European Parliament and of the Council with regard to ecodesign requirements for space heaters and combination heaters (OJ L 239, 6.9.2013, p. 136).
( 35 ) Part 1 of the study ENER/C1/2018-493 on ‘Cooling Technologies Overview and Market Share’ provides more detailed definitions and equations for these metrics in chapter 1.5 ‘Energy efficiency metrics of state-of-the-art cooling systems’.
( 36 ) Commission Decision of 1 March 2013 establishing the guidelines for Member States on calculating renewable energy from heat pumps from different heat pump technologies pursuant to Article 5 of Directive 2009/28/EC of the European Parliament and of the Council (OJ L 62, 6.3.2013, p. 27).
( 37 ) The mean values reported here represent a weighted average of the individually modelled feedstock values. The magnitude of the values in the Annex is sensitive to the range of assumptions (such as treatment of co-products, yield developments, carbon stocks and displacement of other commodities) used in the economic models developed for their estimation. Although it is therefore not possible to fully characterise the uncertainty range associated with such estimates, a sensitivity analysis conducted on the results based on a random variation of key parameters, a so-called Monte Carlo analysis, was conducted.
( 38 ) Perennial crops are defined as multi-annual crops, the stem of which is usually not annually harvested such as short rotation coppice and oil palm.