HTML PUBLIC "-//W3C//DTD HTML 4.01 Transitional//EN"L 52/12
EN
Official Journal of the European Union
24.2.2012
DECISIONS
COMMISSION IMPLEMENTING DECISION
of 10 February 2012
laying down rules concerning the transitional national plans referred to in Directive 2010/75/EU of
the European Parliament and of the Council on industrial emissions
(notified under document C(2012) 612)
(Text with EEA relevance)
(2012/115/EU)
THE EUROPEAN COMMISSION,
HAS ADOPTED THIS DECISION:
Having regard to the Treaty on the Functioning of the European
Article 1
Union,
Combustion plants to be included in the transitional
national plans
In accordance with the detailed provisions laid down in Section
Having regard to Directive 2010/75/EU of the European
1 of the Annex to this Decision, a transitional national plan
Parliament and of the Council of 24 November 2010 on
shall only include entire combustion plants covered by Chapter
industrial emissions (integrated pollution prevention and
III of Directive 2010/75/EU, taking into account the provisions
control) ( 1 ), and in particular Article 41(b) thereof,
of Article 32(1) and the aggregation rules provided for in
Article 29 of Directive 2010/75/EU.
Whereas:
Article 2
Content of the transitional national plans
(1) Article
32
of
Directive
2010/75/EU
provides
that
Member States, during the period from 1 January 2016
1. Each transitional national plan shall include the following
to 30 June 2020, may draw up and implement a tran
information in accordance with Section 2 of the Annex to this
sitional national plan covering particular combustion
Decision:
plants for which the plan shall cover emissions of one
or more of the following pollutants: nitrogen oxides,
sulphur dioxide and dust. For gas turbines, only
(a) a list of all the combustion plants that fall under the plan,
nitrogen oxides emissions shall be covered by the plan.
including all relevant information on their operational char
acteristics;
(2) Combustion
plants
covered
by
the
transitional
national
plan may be exempted from compliance with the
(b) the calculated contribution of each individual combustion
emission limit values referred to in Article 30(2) of
plant to the emission ceilings for 2016 and 2019;
Directive 2010/75/EU for the pollutants which are
subject to the plan or, where applicable, with the rates
of desulphurisation referred to in Article 31 of Directive
(c) a table setting out the emission ceilings for each of the
2010/75/EU.
pollutants the plan covers for the years 2016, 2017,
2018, 2019 and for the first semester of the year 2020;
(3) In
order
to
ensure
uniform
implementation
of
Article
32
of Directive 2010/75/EU, implementing rules should be
(d) the details of the calculation of those emission ceilings.
adopted.
In addition, the transitional national plan shall contain the
(4) The
measures
provided
for
in
this
Decision
are
in following information:
accordance with the opinion of the Committee estab
lished by Article 75(1) of Directive 2010/75/EU,
(a) a description of how the implementation of the plan shall
( 1 ) OJ L 334, 17.12.2010, p. 17.
be monitored and reported to the Commission;

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(b) a list of the measures that shall be applied to ensure that all
Article 4
combustion plants that are included in the plan comply on
1 July 2020 at the latest with the applicable emission limit
Implementation of the transitional national plan
values set out in Annex V to Directive 2010/75/EU.
In accordance with the second and third subparagraphs of
Article 32(5) of Directive 2010/75/EU, a Member State may
2. For the purposes of point (a) of the first subparagraph of
only implement its transitional national plan upon acceptance
paragraph 1, Member States shall use the template provided for
by the Commission.
in Table A.1 in Appendix A to the Annex to this Decision.
Article 5
For the purposes of point (c) of the first subparagraph of
paragraph 1, Member States shall use the template provided
Subsequent changes to the transitional national plan
for in Table B.3 in Appendix B to the Annex to this Decision.
1. Member
States
shall
establish
a
mechanism
that
allows
identifying any relevant changes to combustion plants falling
Article 3
under the transitional national plan which may affect the
applicable emission ceilings.
Setting emission ceilings in the transitional national plans
1. For
the
purposes
of
Article
32(3)
of
Directive
2010/75/EU
2. For the purposes of Article 32(6) of Directive
the emission ceilings shall be calculated in accordance with the
2010/75/EU, Member States shall inform the Commission of
methods set out in Section 3 of the Annex to this Decision.
any subsequent changes to the plan affecting the applicable
emission ceilings, in accordance with Section 4 of the Annex
2. Member
States
shall
use
the
template
provided
for
in to this Decision.
Table B.1 in Appendix B to the Annex to this Decision to
present the relevant emission limit values and minimum rates
Article 6
of desulphurisation, the calculated contributions of each
combustion plant to the 2016 emission ceilings and the total
Compliance monitoring, remedial action and reporting to
2016 emission ceilings.
the Commission
1. For the purposes of Article 32(4) of Directive
In the following cases, Member States shall, in the column of
2010/75/EU, the competent authorities shall monitor the
the template labelled ‘comments’, provide additional
emissions of nitrogen oxides, sulphur dioxide and dust of
information on the emission limit values applied for the calcu
each combustion plant falling under the transitional national
lation:
plan, by verifying the monitoring or calculation data of the
operators of the combustion plants.
(a) where emission limit values mentioned in the Notes to
Tables C.1 and C.2 in Appendix C to the Annex to this
2. Member States shall ensure that emissions of nitrogen
Decision have been applied;
oxides, sulphur dioxide and dust from the combustion plants
falling under the transitional national plan are limited to a
(b) where plants use multiple fuel types or consist of a
degree which allows compliance with the emission ceilings.
combination of multiple plant types.
Where there is a risk that emission ceilings are not complied
with, Member States shall take the necessary measures to
prevent any emissions exceeding those ceilings.
3. Member
States
shall
use
the
template
provided
for
in
Table B.2 in Appendix B to the Annex to this Decision to
present the relevant emission limit values and the minimum
3. Member
States
implementing
a
transitional
national
plan
rates of desulphurisation, the calculated contributions of each
shall report to the Commission every year within 12 months
combustion plant to the 2019 emission ceilings and the total
the plant-by-plant data listed in Article 72(3) of Directive
2019 emission ceilings.
2010/75/EU for all combustion plants included in the plan.
In the following cases, Member States shall, in the column of
Article 7
the template labelled ‘comments’, provide additional
information on the emission limit values applied for the calcu
This Decision is addressed to the Member States.
lation:
(a) where emission limit values mentioned in the Notes to
Done at Brussels, 10 February 2012.
Tables D.1 and D.2 in Appendix D to the Annex to this
Decision have been applied;
For the Commission
(b) where plants use multiple fuel types or consist of a
Janez POTONIK
combination of multiple plant types.
Member of the Commission

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ANNEX
1. Combustion
plants
to
be
included
in
the
transitional
national
plan
Parts of combustion plants (e.g. one or more individual combustion units which are sharing a common stack with
other units or which are in a situation as set out in Article 29(2) of Directive 2010/75/EU) shall not fall under a
transitional national plan ( 1 ).
For the purpose of the second indent, point (b) of Article 32(1) of Directive 2010/75/EU, combustion plants falling
under that provision also include plants which are not operated by a refinery operator, but are located within the
refinery and use the fuels referred to in that point.
Combustion plants that will be subject to the provisions of Chapter IV of Directive 2010/75/EU concerning waste
incineration plants and waste co-incineration plants at any point during the application of the transitional national
plan shall not be included in the transitional national plan.
2. Combustion
plant
data
to
be
included
in
the
transitional
national
plan
The transitional national plan shall include a list of all the combustion plants it covers and all data concerning
these plants which was used to calculate the emission ceilings.
The plant-by-plant data to be included relates to the total rated thermal input, the fuels used and the operating
characteristics of each combustion plant during the time period of the implementation of the transitional national
plan.
As a minimum, the following data shall be included in the transitional national plan for each of the combustion
plants falling under it:
(1) Name and location of the combustion plant ( 2 );
(2) Date on which the first permit for the combustion plant was granted;
(3) Date on which the application for the first permit for the combustion plant was submitted alongside with the
date on which the combustion plant was put into operation for the first time;
Note: This information is only required in case the combustion plant has been granted its first permit after
27 November 2002, but has been brought into operation no later than 27 November 2003.
(4) Any extension by at least 50 MW of the total rated thermal input of the combustion plant, which took place
between 27 November 2002 and 31 December 2010 (indicating the capacity added in MW) ( 3 );
(5) Total rated thermal input (MW) of each combustion plant on 31 December 2010;
(6) Annual number of operating hours ( 4 ) of each combustion plant, averaged over the period 2001-2010;
Note: This information is only required in case where specific emission limit values for combustion plants
operating less than 1 500 hours per year are used to calculate the contribution of the combustion
plant to the emission ceiling(s).
(7) Pollutants for which the combustion plant concerned is not covered by the transitional national plan
(if any) ( 5 ).
( 1 ) The same rule applies regarding Articles 33, 34 and 35 of Directive 2010/75/EU. Consequently, a part of a combustion plant cannot
be covered by the provisions of Article 33, 34 or 35, while another part (or parts) of that plant would be included in the transitional
national plan.
( 2 ) As has been reported in the emission inventories drawn up under Directive 2001/80/EC of the European Parliament and of the Council
of 23 October 2001 on the limitation of emissions of certain pollutants into the air from large combustion plants (OJ L 309,
27.11.2001, p. 1).
( 3 ) This information is needed in view of determining the relevant emission limit values on 1 January 2016 as set out in Article 10 of
Directive 2001/80/EC.
( 4 ) ‘operating hours’ means the time, expressed in hours, during which a combustion plant, in whole or in part, is operating and
discharging emissions into the air, excluding start-up and shut-down periods.
( 5 ) For example, gas turbines can only be covered by the transitional national plan concerning their NO x emissions. Other plants may be
covered by the transitional national plan for some pollutant(s), while being subject to the emission limit values from Annex V to
Directive 2010/75/EU for other pollutants.

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(8) Annual amount of fuel used (TJ/year), averaged over the period 2001-2010, split over 6 fuel types: hard coal,
lignite, biomass, other solid fuels, liquid fuels, gaseous fuels ( 1 );
(9) Annual waste gas flow rate (Nm 3 /year), averaged over the period 2001-2010 ( 2 );
Note 1: In the case of combustion plants firing multiple fuel types and/or consisting of multiple plant types,
the waste gas flow rate needs to be provided for each of the fuel types and/or combustion plant
types separately ( 3 ).
Note 2: If the waste gas flow rate is calculated from the amount of fuel used (and not based on actual
monitored waste gas flows), the factor (or factors in case of multiple fuels or combustion plant
types) used for the calculation (Nm 3 /GJ) needs to be reported.
(10) Quantity of sulphur input via indigenous solid fuels ( 4 ) used (tonnes S/year), averaged over the period
2001-2010;
Note: This information is only required in case where the combustion plant uses indigenous solid fuels and
where the minimum desulphurisation rate is used to calculate the contribution of the combustion plant
to the emission ceiling for sulphur dioxide (for 2016 and/or 2019).
Where combustion plants covered by the transitional national plan are gas turbines or gas engines, the transitional
national plan must specifically indicate this.
3. Determining
the
emission
ceilings
3.1. Calculation method for the individual plant contributions to the 2016 and 2019 emission ceilings
3.1.1. General case
In order to determine the applicable emission ceilings for a pollutant for the years 2016 and 2019, the
contribution of each combustion plant expressed in tonnes per year (tpa) shall be calculated using the
following equation:
Contribution to ceiling (tpa) = Waste gas flow rate (Nm 3 pa) × ELV (mg/Nm 3 ) × 1,0 × 10 –9
where:
— ‘Waste gas flow rate’ is the volumetric flow rate of waste gases expressed in cubic metres per year (Nm 3 pa),
averaged over the years 2001-2010. It is expressed at standard temperature (273 K) and pressure (101,3 kPa),
at the relevant reference oxygen content (i.e. the same one as used for the emission limit value (ELV)) and after
correction for the water vapour content,
— ‘ELV’ is the relevant emission limit value for the pollutant concerned expressed in mg/Nm 3 , assuming an
oxygen content by volume in the waste gas of 6 % in the case of solid fuels, 3 % in the case of liquid and
gaseous fuels (for combustion plants other than gas turbines or gas engines) and 15 % in the case of gas
turbines and gas engines.
The details on how to determine the emission limit values for calculating the 2016 and 2019 emission ceilings are
provided in sections 3.2 and 3.3.
3.1.2. Specific case of plants firing multiple fuel types and/or consisting of multiple plant types
The equation referred to in section 3.1.1 cannot be used for combustion plants that fired multiple fuel types in the
period 2001-2010 (simultaneously or not) or are consisting of multiple plant types.
( 1 ) For combustion plants which, at any point during the period 2001-2010, have been co-incinerating waste (other than waste which is
‘biomass’ according to the definition under Article 3(31)(b) of Directive 2010/75/EU and were consequently covered by Directive
2000/76/EC of the European Parliament and of the Council of 4 December 2000 on the incineration of waste (OJ L 332, 28.12.2000,
p. 91)), the amount of waste burned during that period shall not be included under this point.
( 2 ) See section 3.1.1 of this Annex concerning the applicable reference conditions.
( 3 ) See section 3.1.2 of this Annex.
( 4 ) ‘indigenous solid fuel’ means a naturally occurring solid fuel fired in a combustion plant specifically designed for that fuel and extracted
locally.

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Those combustion plants require the application of different emission limit values and/or reference conditions for
calculating their contribution to the emission ceilings. Hence, the following method shall be used.
Contribution to ceiling (tpa) = Σ [Waste gas flow rate (Nm 3 pa) × ELV (mg/Nm 3 ) × 1,0 × 10 –9 ]
This equation implies that, for each of the fuel types used in the period 2001-2010, the average annual waste gas
volume (Nm 3 per year) is multiplied by the relevant emission limit value (corresponding to the total rated thermal
input of the entire combustion plant). The products of these multiplications are then added for all of the fuel types
used.
It must be ensured that, for each fuel type, the waste gas volume and the emission limit value multiplied are
expressed at the same reference oxygen content.
The same approach applies in cases where, in the period 2001-2010, taking into account Article 29(1) and (2) of
Directive 2010/75/EU, a single combustion plant consisted of a combination of different plant types. Illustrative
examples are:
— one or more gas turbines combined with one or more other types of combustion plants,
— one or more gas engines combined with one or more other types of combustion plants.
3.1.3. Minimum rate of desulphurisation (MDR)
The equation referred to in section 3.1.1 cannot be used for combustion plants firing indigenous solid fuel ( 1 ) and
which cannot comply with the relevant emission limit values set for sulphur dioxide in Directive 2010/75/EU due
to the characteristics of this fuel.
For such plants, the calculation of their contribution to the emission ceiling applicable for sulphur dioxide may be
based on the application of the relevant minimum rates of desulphurisation ( 2 ) rather than on the emission limit
values for sulphur dioxide.
In that case, the contribution of the combustion plant to the sulphur dioxide emission ceiling expressed in tonnes
per year (tpa) shall be calculated using the following equation:
Contribution to SO 2 ceiling (tpa) = Sulphur input (tpa) × (1 – (MDR/100)) × 2
where:
— ‘Sulphur input’ is the annual quantity of sulphur (S) contained in the indigenous solid fuel which was used in
the combustion plant, expressed in tonnes per year (tpa), averaged over the period 2001-2010,
— ‘MDR’ is the relevant minimum rate of desulphurisation, expressed in percent.
The details on how to determine the relevant minimum rate of desulphurisation for calculating the 2016 and
2019 emission ceilings for sulphur dioxide are provided in sections 3.2 and 3.3.
3.2. Relevant emission limit values and minimum rates of desulphurisation for calculating the 2016 emission ceilings
According to Article 32(3) of Directive 2010/75/EU, the emission ceiling(s) for the year 2016 shall be calculated
on the basis of the relevant emission limit values set out in Annexes III to VII to Directive 2001/80/EC or, where
applicable, on the basis of the minimum rate of desulphurisation set out in Annex III to Directive 2001/80/EC.
Thus, the calculation of the 2016 emission ceilings is based upon the relevant emission limit values and MDR,
which would have been applicable on 1 January 2016 to the combustion plant concerned under Directive
2001/80/EC, taking into account the following provisions ( 3 ).
( 1 ) This applies for combustion plants which have been firing indigenous solid fuel in the period 2001-2010.
( 2 ) ‘rate of desulphurisation’ means the ratio over a given period of time of the quantity of sulphur which is not emitted into air by a
combustion plant to the quantity of sulphur contained in the solid fuel which is introduced into the combustion plant facilities and
which is used in the plant over the same period of time.
( 3 ) The relevant emission limit values for calculating the emission ceilings are not affected by the inclusion of a plant in a National
Emission Reduction Plan under Article 4(6) of Directive 2001/80/EC.

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The emission limit values and MDR shall be determined on the basis of the total rated thermal input of the entire
combustion plant on 31 December 2010, the type(s) of fuel used and the annual number of operating hours
averaged over the period 2001-2010. Where combustion plants have been extended by at least 50 MW in the
period between 27 November 2002 and 31 December 2010, the rules for calculating the relevant emission limit
values as set out in Article 10 of Directive 2001/80/EC shall be applied.
For all gas turbines included in the transitional national plan, the relevant emission limit value concerning nitrogen
oxides is the one set out in Part B of Annex VI to Directive 2001/80/EC, irrespective of Article 2(7)(j) of Directive
2001/80/EC.
As no emission limit values have been set out in Directive 2001/80/EC for gas engines, the relevant emission limit
value for nitrogen oxides is the one set out in Part 1 of Annex V to Directive 2010/75/EU.
For combustion plants which have been using different fuel types in the period 2001-2010, the relevant emission
limit values shall be listed for each individual fuel. Section 3.1.2 provides details on the method to be used to
calculate the contribution of each of those plants to the emission ceilings.
Directive 2001/80/EC allows certain combustion plants operating less than 1 500 hours (as a rolling average over
a five-year period) to comply with less stringent emission limit values. The, latter can only be used for calculating
the contribution of an individual plant to the 2016 emission ceiling if the average number of operating hours for
the plant over the years 2001-2010 is less than 1 500 hours per year.
An overview of the relevant emission limit values as set out in Annexes III to VII of Directive 2001/80/EC and of
the relevant MDR established in Annex III to Directive 2001/80/EC is provided in Tables C.1, C.2 and C.3 in
Appendix C to this Annex ( 1 ).
3.3. Relevant emission limit values and minimum rates of desulphurisation for calculating the 2019 emission ceilings
According to Article 32(3) of Directive 2010/75/EU, the emission ceilings for the year 2019 shall be calculated on
the basis of the relevant emission limit values set out in Part 1 of Annex V to Directive 2010/75/EU or, where
applicable, the relevant rates of desulphurisation set out in Part 5 of Annex V to Directive 2010/75/EU. Thus, the
calculation of the 2019 emission ceilings is based upon the relevant emission limit values and MDR, which would
be applicable on 1 January 2019 under Directive 2010/75/EU to the combustion plant concerned.
The emission limit values and MDR shall be determined on the basis of the total rated thermal input of the entire
combustion plant on 31 December 2010, of the type(s) of fuel used and of the annual number of operating hours
averaged over the period 2001-2010.
An overview of the relevant emission limit values as set out in Part 1 of Annex V to Directive 2010/75/EU and of
the relevant MDR established in Part 5 of Annex V to Directive 2010/75/EU is provided in Tables D.1, D.2 and
D.3 in Appendix D of this Annex.
For combustion plants which have been using different fuel types in the period 2001-2010, the relevant emission
limit values shall be listed for each individual fuel. Section 3.1.2 provides details on the method to be used to
calculate the contribution of each of those plants to the emission ceilings.
Directive 2010/75/EU allows certain combustion plants operating less than 1 500 hours (as a rolling average over
a five-year period) to comply with less stringent emission limit values. The latter can only be applied for calculating
the contribution of a plant to the 2019 emission ceiling if the average number of operating hours for that plant
over the years 2001-2010 is less than 1 500 hours per year.
3.4. Calculating
the
emission
ceilings
3.4.1. Calculating the 2016 and 2019 emission ceilings
For the years 2016 and 2019, the total emission ceilings per pollutant shall be determined by adding up the
contributions of each individual plant to the respective emission ceilings:
ceiling2016 (tpa) = Σ [individual plant contribution to 2016 ceiling]
ceiling2019 (tpa) = Σ [individual plant contribution to 2019 ceiling]
( 1 ) This overview is not exhaustive. In particular, it does not cover situations where a combustion plant had been extended by at least
50 MW between 27 November 2002 and 31 December 2010, in which case also the emission limit values listed in the Parts B of
Annexes III to VII to Directive 2001/80/EC are of relevance (application of Article 10 of Directive 2001/80/EC).

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3.4.2. Calculating the 2017, 2018 and 2020 emission ceilings
The ceilings for the year 2017 (ceiling2017) shall be calculated using the following equation:
ceiling2017 ceiling2016 – ceiling2016 – ceiling2019
3
The ceilings for the year 2018 (ceiling2018) shall be calculated using the following equation:
2
ceiling2018 ceiling2016 – ceiling2016 – ceiling2019
3
The ceilings for the first semester of 2020 (ceiling2020) are half of the ceilings for 2019:
ceiling2019
ceiling2020
2
4. Subsequent
changes
to
transitional
national
plans
Member States shall inform the Commission at least on the following:
(a) the combustion plants which opt for the limited lifetime derogation in accordance with Article 33 of Directive
2010/75/EU;
Note: While Member States shall communicate their transitional national plans to the Commission on
1 January 2013 at the latest, operators have until 1 January 2014 to notify the competent authority
whether they seek to opt for the limited lifetime derogation. Thus, a combustion plant may be initially
included in the transitional national plan submitted to the Commission before being subject to a limited
lifetime derogation. The combustion plant must then be removed from the transitional national plan
once the competent authority has been notified by the operator of the combustion plant about the
decision to opt for the limited lifetime derogation. The contributions to the applicable emission ceiling(s)
of each of the combustion plants that would fall under Article 33 of Directive 2010/75/EU must then
be deducted from the emission ceiling(s) as calculated in the latest accepted version of the transitional
national plan (or, if no such plan has been accepted, as calculated in the latest version of the transitional
national plan submitted to the Commission).
(b) the combustion plants which are closed (i.e. those plants that have definitively stopped operating) or the total
rated thermal input of which is reduced to less than 50 MW;
(c) the combustion plants which start to co-incinerate waste after 31 December 2015 and which would therefore
fall under Chapter IV of Directive 2010/75/EU.
Note: As mentioned in Article 32(3) of Directive 2010/75/EU, where a plant included in the transitional
national plan is closed or no longer falls within the scope of Chapter III of Directive 2010/75/EU, this
shall not result in an increase in total annual emissions from the remaining plants covered by the
transitional national plan.
For the purpose of Article 32(6) of Directive 2010/75/EU, Member States do not have the obligation to
communicate to the Commission the following information since the subsequent changes they refer to should
not affect the applicable emission ceiling(s):
— a reduction or an increase of the total rated thermal input after 31 December 2010 (other than a reduction to
less than 50 MW),
— a reduction or an increase of the number of annual operating hours after 2010,
— a change in fuel use (type, quantity) occurring after 2010 (other than a switch to burning waste, which would
qualify the plant as a waste co-incineration plant causing its exclusion from the transitional national plan).
Changes affecting the name of the plant (e.g. due to a change of operator) shall be reported via the emission
inventories to be provided by Member States in accordance with Article 6(3) of this Decision and Article 72(3) of
Directive 2010/75/EU.

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Appendix A
Table A.1
Template for the list of combustion plants to be included in the transitional national plan
A
B
C
D
E
F
G
H
EN

Date on which the application for
Any extension by at least 50 MW
the first permit for the plant has
OR
of the total rated thermal input of Total rated thermal
Annual number of
Pollutant(s) (SO 2, NO x, dust) for
Number Plant
name
Plant location
Date on which the first the combustion plant, which took
which the plant concerned is NOT
(address)
been submitted and date on which
input on 31.12.2010
operating hours
the plant has been put into
permit for the plant has
place between 27 November
(MW)
(average 2001-2010)
covered by the transitional
operation for the first time
been granted
2002 and 31 December 2010
national plan
(total extension in MW)
A
I
J
K
L
M
icial
Annual quantity of S in indigenous solid
Indicate if the
Annual amount of fuel used
Average annual waste gas flow rate fuels used which was introduced into the Conversion factor(s) used in case the
waste gas flow rate was calculated
Jour
Number
plant is a gas
(average 2001-2010)
(average 2001-2010)
combustion plant
turbine or gas
(average 2001-2010)
from the fuel input (per fuel type)
nal
engine
(TJ/year) (Nm3 /y) (tpa) (Nm3 /GJ)
of
the
hard coal lignite biomass other
solid
fuels liquid
fuels gaseous
fuels
European
Union
L
52/19

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Appendix B
Table B.1
Template for calculating the 2016 emission ceilings
A
B
C
D
E
F
G
H
I
J
K
EN

reference oxygen
relevant ELV for
relevant
plant's contribution
plant's contribution
plant's contribution
desulphurisation
to the 2016 SO
relevant ELV for
relevant ELV for

2
to the 2016 NO x
to the 2016 dust
Number name
content
SO 2
rate
ceiling
NO x
ceiling
dust
ceiling comments
(%) (mg/Nm3 ) (where
applicable) (tpa) (mg/Nm3 ) (tpa) (mg/Nm3 ) (tpa)
(individual plant data)
SUM
TOTAL SO 2
TOTAL NO x
TOTAL dust
CEILING
CEILING
CEILING
Off
icial
Jour
Table B.2
nal
Template for calculating the 2019 emission ceilings
of
the
European
A
B
C
D
E
F
G
H
I
J
K
reference oxygen
relevant ELV for
relevant
plant's contribution
plant's contribution
plant's contribution
desulphurisation
to the 2019 SO
relevant ELV for
relevant ELV for

2
to the 2019 NO x
to the 2019 dust
Number name
content
SO 2
rate
ceiling
NO x
ceiling
dust
ceiling comments
Union
(%) (mg/Nm3 ) (where
applicable) (tpa) (mg/Nm3 ) (tpa) (mg/Nm3 ) (tpa)
(individual plant data)
SUM
TOTAL SO 2
TOTAL NO x
TOTAL dust
CEILING
CEILING
CEILING
24.2.2012

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Table B.3
Overview of emission ceilings
(tonnes per year)
2020
2016 2017 2018 2019
(1 January-30 June)
SO 2
NO x
Dust

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Appendix C
Table C.1
Emission limit values relevant for the calculation of the individual contributions to the 2016 emission ceilings
for combustion plants other than gas turbines and gas engines
ELV (mg/Nm 3 )
Pollutant Fuel
type
50-100 MW >
100-300
MW
> 300-500 MW >
500
MW
SO 2
Solid 2
000
2 000 to 400 (linear scale) (Note 1) 400
Liquid 1
700 1
700
to
400
400
(linear scale)
Gaseous 35
in
general
5 for liquefied gas
800 for coke oven gas and blast furnace gas
NO x
Solid
600 200
(Note 6)
(Note 2)
(Note 3)
Liquid 450 400
Gaseous 300 200
Dust Solid 100 50
(Note
4)
Liquid 50
(Note
5)
Gaseous 5
in
general
10 for blast furnace gas
50 for steel industry gases that can be used elsewhere
The reference oxygen content is 6 % for solid fuels and 3 % for liquid and gaseous fuels.
Notes:
1. 800 mg/Nm 3 for plants with a rated thermal input greater than or equal to 400 MW, which do not operate more than
1 500 hours per year.
2. 1 200 mg/Nm 3 for plants that in the 12-month period ending on 1 January 2001 operated on, and continue to
operate on, solid fuels whose volatile content is < 10 %.
3. 450 mg/Nm 3 for plants which do not operate more than 1 500 hours per year.
4. 100 mg/Nm 3 for plants for which the original construction licence or, in the absence of such a procedure, the original
operating licence was granted before 1 July 1987 and which are burning solid fuel with a heat content of less than
5 800 kJ/kg, a moisture content > 45 % by weight, a combined moisture and ash content > 60 % by weight and a
calcium oxide content > 10 %.
5. 100 mg/Nm 3 for plants with a rated thermal input below 500 MW and burning liquid fuel with an ash content
> 0,06 %.
6. for plants located in the French Overseas Departments, the Azores, Madeira or the Canary Islands the following ELV
apply: solid fuels in general: 650 mg/Nm 3 ; solid fuels with < 10 % volatile compounds: 1 300 mg/Nm 3 ; liquid fuels:
450 mg/Nm 3 ; gaseous fuels: 350 mg/Nm 3 .

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EN
24.2.2012 Official
Journal
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European
Union L
52/23
Table C.2
Emission limit values relevant for the calculation of the individual contributions to the 2016 emission ceiling for
NO x for gas turbines and gas engines
ELV for NO x
(mg/Nm 3 )
Gas engines (firing gaseous fuels) 100
Gas turbines (including CCGT) firing the following fuels:
Natural gas (Note 1)
50
(Notes 2 and 3)
Gaseous fuels other than natural gas 120
Light and middle distillates 120
The reference oxygen content is 15 %.
Notes:
1. Naturally occurring methane with not more than 20 % (by volume) of inerts and other constituents.
2. 75 mg/Nm 3 in the following cases (where the efficiency of the gas turbine is determined at ISO base load conditions):
— gas turbines, used in combined heat and power systems having an overall efficiency greater than 75 %,
— gas turbines used in combined cycle plants having an annual average overall electrical efficiency greater than 55 %,
— gas turbines for mechanical drives.
3. For single cycle gas turbines not falling into any of the categories mentioned under Note 2, but having an efficiency
greater than 35 % (at ISO base load conditions), the ELV shall be 50 × η/35 where η is the gas turbine efficiency (at
ISO base load conditions) expressed as a percentage.
Table C.3
Minimum rates of desulphurisation relevant for the calculation of the individual contributions to the 2016
emission ceiling for SO 2 in case of combustion plants firing indigenous solid fuels which cannot comply
with the emission limit values for SO 2 referred to in Article 30(2) and (3) of Directive 2010/75/EU due to
the characteristics of this fuel
Total rated thermal input Minimum
rate
of
desulphurisation
50-100 MW 60
%
> 100-300 MW 75
%
> 300-500 MW 90
%
> 500 MW 94
%
in
general
92 % for plants where a contract for the fitting of FGD or lime injection equipment has
been entered into, and work on its installation has commenced, before 1 January 2001

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L 52/24
EN
Official Journal of the European Union
24.2.2012
Appendix D
Table D.1.
Emission limit values relevant for the calculation of the individual contributions to the 2019 emission ceilings
for combustion plants other than gas turbines and gas engines
ELV (mg/Nm 3 )
Pollutant Fuel
type
50-100 MW >
100-300
MW >
300-500
MW >
500
MW
SO 2
Coal, lignite and
400 250 200
other solid fuels
(Note 1)
Biomass (Note 1) 200
Peat (Note 1) 300 200
Liquid 350
250
200
(Note 2)
(Note 2)
(Note 3)
Gaseous 35
in
general
5 for liquefied gas
400 for low calorific gases from coke oven
200 for low calorific gases from blast furnace
NO x
Coal, lignite and
300
200
200
other solid fuels
(Notes 4 and 5)
(Note 5)
(Note 6)
Biomass and peat 300
250
200
200
(Note 5)
(Note 5)
(Note 5)
(Note 6)
Liquid 450 200 150
150
(Notes 5 and 7)
(Notes 5 and 7)
(Note 3)
Natural gas (Note 8) 100
Other gases 300 200
Dust Coal,
lignite
and
30 25 20
other solid fuels
Biomass and peat 30 20
Liquid 30 25 20
Gaseous 5
in
general
10 for blast furnace gas
30 for gases produced by the steel industry which can be used elsewhere
The reference oxygen content is 6 % for solid fuels and 3 % for liquid and gaseous fuels.
Notes:
1. 800 mg/Nm 3 for plants which do not operate more than 1 500 operating hours per year.
2. 850 mg/Nm 3 for plants which do not operate more than 1 500 operating hours per year.
3. 400 mg/Nm 3 for plants which do not operate more than 1 500 operating hours per year.
4. 450 mg/Nm 3 in case of pulverised lignite combustion.
5. 450 mg/Nm 3 for plants which do not operate more than 1 500 operating hours per year.

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EN
24.2.2012 Official
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European
Union L
52/25
6. 450 mg/Nm 3 for plants which were granted a permit before 1 July 1987 and which do not operate more than 1 500
operating hours per year.
7. 450 mg/Nm 3 for plants in chemical installations using liquid production residues as non-commercial fuel for own
consumption.
8. Naturally occurring methane with not more than 20 % (by volume) of inerts and other constituents.
Table D.2.
Emission limit values relevant for the calculation of the individual contributions to the 2019 emission ceiling for
NO x for gas turbines and gas engines
ELV for NO x
(mg/Nm 3 )
Gas engines (firing gaseous fuels) 100
Gas turbines (including CCGT) firing the following fuels:
Natural gas (Note 1)
50
(Notes 2, 3 and 4)
Gaseous fuels other than natural gas 120
(Note 5)
Light and middle distillates 90
(Note 5)
The reference oxygen content is 15 %.
Notes:
1. Natural gas is naturally occurring methane with not more than 20 % (by volume) of inerts and other constituents.
2. 75 mg/Nm 3 in the following cases (where the efficiency of the gas turbine is determined at ISO base load conditions):
— gas turbines, used in combined heat and power systems having an overall efficiency greater than 75 %,
— gas turbines used in combined cycle plants having an annual average overall electrical efficiency greater than 55 %,
— gas turbines for mechanical drives.
3. For single cycle gas turbines not falling into any of the categories mentioned under Note 2, but having an efficiency
greater than 35 % (at ISO base load conditions), the ELV shall be 50 × η/35 where η is the gas turbine efficiency (at
ISO base load conditions) expressed as a percentage.
4. 150 mg/Nm 3 for plants which do not operate more than 1 500 operating hours per year.
5. 200 mg/Nm 3 for plants which do not operate more than 1 500 operating hours per year.
Table D.3.
Minimum rates of desulphurisation relevant for the calculation of the individual contributions to the 2019
emission ceiling for SO 2 in case of combustion plants firing indigenous solid fuels which cannot comply
with the emission limit values for SO 2 referred to in Article 30(2) and (3) of Directive 2010/75/EU due to
the characteristics of this fuel
Total rated thermal input Minimum
rate
of
desulphurisation
50-100 MW 80
%
> 100-300 MW 90
%
> 300 MW 96
%
in
general
95 % for plants firing oil shale

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