1. business and industrial
2. energy
3. oil

Chapter 10
Colour code used in this document:
Green text: text included in the first draft (D1) of the revised LCP BREF (June 2013)
Green strikethrough text: text proposed to be deleted
Blue text: text proposed to be added
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10 BEST AVAILABLE TECHNIQUES (BAT)
CONCLUSIONS FOR LARGE COMBUSTION
PLANTS
Scope
These BAT conclusions concern the following activities specified in Annex I to
Directive 2010/75/EU, namely:
1.1: Combustion of fuels in installations with a total rated thermal input of 50 MWth
or more, only when this activity takes place in combustion plants with a total rated
thermal input of 50 MWth or more, including plants composed of aggregated units
of 15 MWth or more including plants composed of aggregated units of 15 MWth or
more.

1.4: Gasification of coal or other fuels in installations with a total rated thermal
input of 20 MWth or more, only when this activity is directly associated to a
combustion process.

5.2: Disposal or recovery of waste in waste co-incineration plants for nonhazardous waste with a capacity exceeding 3 tonnes per hour or for hazardous waste
with a capacity exceeding 10 tonnes per day, only when this activity takes taking
place in combustion plants covered under 1.1 above. with a total rated thermal input
of 50 MWth or more.
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
In particular, these BAT conclusions cover the following processes and activities:
combustion;
o
gasification associated to a combustion process;
o
upstream and downstream activities directly associated to the abovementioned activities
including as well as the emission prevention and control techniques applied.
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o
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The fuels considered in these BAT conclusions are any solid, liquid and/or gaseous combustible
material including:
 primary solid fuels (hard e.g. coal, brown coal, lignite, peat);
 biomass (as defined in Article 3(31) of Directive 2010/75/EU) (e.g. wood, sawdust,
bark, straw) and wood waste not contaminated by halogenated organic compounds
or metals;
 primary liquid fuels (e.g. heavy fuel oil and light fuel gas oil);
 gaseous fuels (e.g. natural gas, hydrogen-containing gas and syngas);
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Chapter 10
 other industry-specific fuels (production residues and e.g. by-products from
chemical and iron and steel industries);
 waste except for excluding unsorted municipal waste.
These BAT conclusions do not address the following activities:
 combustion of fuels in units with a rated thermal input of less than 15 MWth;
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 gasification of fuels, when not directly associated to the combustion of the resulting
syngas;
 gasification of fuels and subsequent combustion of syngas when directly associated
to the refining of mineral oil and gas;
G
 the upstream and downstream processesactivities not directly associated to
combustion or gasification processesactivities;
O
 combustion in process furnaces or heaters;
PR
 combustion in post-combustion plants;
 flaring;
IN
 combustion in coke battery ovens;
T
 combustion in cowpers;
D
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AF
 combustion in recovery boilers and total reduced sulphur burners within
installations for the production of pulp and paper; this is covered by the BAT
reference document for the Production of Pulp, Paper and Board;
 combustion of refinery fuels; this is covered by the BAT reference document for the
Refining of Mineral Oil and Gas;
waste incineration plants (as defined in IED Article 3(40) of Directive
2010/75/EU),
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 disposal or recovery of waste in:
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o
o
and in waste co-incineration plants where more than 40 % of the resulting
heat release comes from hazardous waste other than combustion plants, and
in
waste co-incineration plants combusting only wastes, except if these wastes
are composed at least partially of biomass as defined in Article 3(31) (b) (i)
to (iv) of Directive 2010/75/EU;
this is covered by the BAT reference document for Waste Incineration.
Other reference documents which are relevant for the activities covered by these BAT
conclusions are the following:
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Reference document
Subject
Common Waste Water and Waste Gas
Treatment/Management Systems in the
Chemical Sector (CWW)
Waste water and chemical waste gas
treatment/management systems
Economic and Cross-Media Effects (ECM)
Economic and cross-media effects of techniques
Energy Efficiency BREF (ENE)
Industrial Cooling Systems BREF (ICS)
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Storage and handling of fuels and additives (prevention of
unplanned emissions, including to soil and groundwater)
GeneralIntegrated energy efficiency at installation level
and energy efficiency in energy-using systems, processes,
activities or equipment
Emissions from Storage BREF (EFS)
Indirect cooling with water Cooling systems
I&SPretreatment of iron and steel process fuelsgases
pretreatment
Chemical process fuels pPretreatment of process fuels from
the chemical industry
Monitoring of emissions to air and water Emissions and
consumptions monitoring
Abatement of pollutants from waste incineration
Waste (pre-)acceptance procedures, waste handling /
storage
PR
Monitoring of Emissions to Air and Water
from IED-installations (ROM) General
Principles of Monitoring (MON)
Waste Incineration (WI)
G
Chemical BREFs series (LVOC, …)
O
Iron and Steel Production (IS)
Waste Treatments Industries (WT)
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The techniques listed and described in these BAT conclusions are neither prescriptive nor
exhaustive. Other techniques may be used that ensure at least an equivalent level of
environmental protection.
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Chapter 10
Definitions
For the purpose of these BAT conclusions, the following definitions apply:
Term used
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Combustion plant
Definition
Any technical apparatus in which fuels are oxidised in order to use the heat thus
generated, or, where the flue-gases of two or more such apparatuses are mixed,
and then treated before release, the combination formed by such apparatuses. For
the purposes of these BAT conclusions, a combination formed by separate
combustion units discharging their flue-gases through a common stack shall be
considered as a single combustion plant. For calculating the total rated thermal
input of such a combination, the capacities of all combustion units concerned,
which have a rated thermal input of at least 15 MW, shall be added.
A combustion plant first permitted (pursuant to the provisions in Articles 4 and 5
of Directive 2010/75/EU) at the installation following the publication of these
BAT conclusions or a complete replacement of a combustion plant on the
existing foundations of the installation following the publication of these BAT
conclusions
A combustion plant which is not a new plant
Ratio between the net electrical output (produced electricity produced at
alternator terminals minus imported energy) and the fuel/feedstock energy input
(as the fuel/feedstock lower heating value) at the combustion plant boundaryies
over a given period of time
Ratio between the net produced energy (electricity, hot water, steam, mechanical
energy produced minus imported electrical and/or thermal energy) and the fuel
energy input (as the fuel lower heating value) at the combustion power plant
boundaryies over a given period of time
Ratio between the net produced energy (electricity, hot water, steam, mechanical
energy produced, syngas (LHV basis) minus imported electrical and/or thermal
energy) and the fuel/feedstock energy input (as the fuel/feedstock lower heating
value) at the gasification plant boundary over a given period of time
The difference between the fuel energy input (fuel and imported electrical and
thermal energy for the operation of the combustion plant and its auxiliary
systems) and the sum of net electrical output and net mechanical thermal output.
Net outputs are calculated as gross outputs minus the energy used in the
combustion plant with its auxiliary systems (material unloading/handling, fluegas treatment facilities, fans, compressors, etc.).
Substances generated by the activities covered by the scope of this document, as
waste or by-products
Any combustion plant with the exception of engines and gas turbines, process
furnaces or heaters. This includes when the HRSG of a CCGT is operated with its
own burners without the gas turbine being in operation (i.e. supplementary firing)
A CCGT is a combustion plant where two thermodynamic cycles are used (i.e.
Brayton and Rankine cycles). In a CCGT, heat from the flue-gas of a gas turbine
(operating according to the Brayton cycle to produce electricity) is converted to
useful energy in a heat recovery steam generator (HRSG), where it is used to
generate steam, which then expands in a steam turbine (operating according to
the Rankine cycle to produce additional electricity).
For the purpose of these BAT conclusions, CCGT includes configurations both
with and without supplementary firing of the HRSG. Should the supplementary
firing of the HRSG operate alone, the HRSG is then considered to be a boiler
Process furnaces or heaters are:
 combustion plants whose flue-gases are used for the thermal treatment of
objects or feed material through a direct contact heating mechanism (e.g.
cement and lime kiln, glass furnace, asphalt kiln, drying process, chemical
reactor used in the (petro-)chemical industry), or
 combustion plants whose radiant and/or conductive heat is transferred to the
objects or feed material through a solid wall without using an intermediary
heat transfer fluid (e.g. coke battery furnace, cowper, furnace or reactor
heating a process stream used in the (petro-)chemical industry such as steam
cracker furnaces).
New plant
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Existing plant
Net electrical
efficiency
(combustion plant
and IGCC)
IN
Net total fuel
utilisation
(combustion plant)
AF
T
Net total fuel
utilisation
(gasification plant)
D
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Recoverable heat
G
Residues
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Boiler
W
O
Combined cycle gas
turbine (CCGT)
Process furnaces or
heaters
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Post-combustion
plant
O
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Maximum
continuous rating
(MCR)
PR
Emergency-load
plant / mode
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G
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Heavy fuel oil (HFO)
Chemical industry
gaseous and/or liquid
Process fuels from
the chemical industry
As
CH4
C3
C4+
CO
COD
Cd
Cd+Tl
AF
D
R
Equivalent full load
factor
T
IN
Peak-load plant /
mode
Mid-merit plant /
mode
Baseload plant /
mode
Light fuel oil
Gas oil
It should be noted that, As a consequence of the application of good energy
recovery practices, some of the process heaters / furnaces may have an associated
steam / electricity generation system. This is considered to be an integral design
feature of athe process heater / furnace that cannot be considered in isolation
System designed to purify the flue-gases by combustion which is not operated as
an independent combustion plant, such as thermal oxidiser equipment (i.e. tail
gas incinerator), used for the removal of pollutant (e.g. VOC) content from the
flue-gas with or without the recovery of the heat generated therein. Staged
combustion techniques, where each stage is confined within a separate chamber,
which may have distinct combustion process characteristics (e.g. fuel / air ratio,
temperature profile), are considered integrated in the combustion process and are
not considered post-combustion plants. Just the same, when gases generated
produced in a process heater / furnace or in another other combustion process
plant are subsequently oxidised in a distinct combustion plant to recover their
energetic value (with or without the use of auxiliary fuel) to produce electricity,
steam, hot water / oil or mechanical energy, the latter plant is not considered a
post-combustion plant
The maximum output (in MWel or MWth) that a combustion plant is capable of
producing continuously under normal operating conditions over a given period of
time
Combustion plant operation ing for less than 500 h/yrhours every year for a given
fuel. This mode also includes the situation when a combustion plant uses back-up
fuels alone or simultaneously with the main fuels for less than 500 h/yrhours
every year
Combustion plant operation ing between 500 and 1500 h/yrhours every year for a
given fuel
Combustion plant operation ing between 1500 and 4000 h/yrhours every year for
a given fuel
Combustion plant operation ng for more than 4000 h/yrhours every year for a
given fuel
Calculated for a given year as the fuel energy input divided by the total operating
time under normal operating conditions and then divided by the total rated
thermal input of the combustion plant (i.e. the sum of all the combustion units)
A group of oil products corresponding to light and middle distillates, which
distillates in the range of approximately 30 ºC to 380 ºC
Any petroleum-derived liquid fuel falling within CN code 2710 19 25, 2710 19
29, 2710 19 47, 2710 19 48, 2710 20 17 or 2710 20 19.
Or any petroleum-derived liquid fuel of which less than 65 % by volume
(including losses) distils at 250 °C and of which at least 85 % by volume
(including losses) distils at 350 °C by the ASTM D86 method
A mixture of predominantly gas oil and fuel oil which distils in the range of
approximately 380 ºC to 540 ºC.
Any petroleum-derived liquid fuel falling within CN code 2710 19 51 to 2710 19
68, 2710 20 31, 2710 20 35, 2710 20 39.
Or any petroleum-derived liquid fuel, other than gas oil, which, by reason of its
distillation limits, falls within the category of heavy oils intended for use as fuel
and of which less than 65 % by volume (including losses) distils at 250 °C by the
ASTM D86 method. If the distillation cannot be determined by the ASTM D86
method, the petroleum product is likewise categorised as a heavy fuel oil
The Gaseous and/or liquid by-products and residues generated by the
(petro-)chemical installationsindustry and used as non-commercial fuels in
combustion plants in boilers within the installation itself.
The sum of arsenic and its compounds, expressed as As
Methane
Hydrocarbons having a carbon number equal to three
Hydrocarbons having a carbon number of four or greater
Carbon monoxide
Chemical oxygen demand. Amount of oxygen needed for the total oxidation of
the organic matter to carbon dioxide.
The sum of cadmium and its compounds, expressed as Cd
The sum of cadmium, thallium and their compounds, expressed as Cd+Tl
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acadmium and its compounds, expressed as Cd;
bthallium and its compounds, expressed as Tl
Cr
The sum of chromium and its compounds, expressed as Cr
Cu
The sum of copper and its compounds, expressed as Cu
Dust
Total particulate matter (in air)
Fluoride
Dissolved fluoride, expressed as FHCN
Hydrogen cyanide
HCl
All inorganic gaseous chlorine compounds, chlorides expressed as HCl
HF
All inorganic gaseous fluorine compounds, fluorides expressed as HF
Hg
The sum of mercury and its compounds, expressed as Hg
H2 S
Hydrogen sulphide
NH3
Ammonia
N2 O
Dinitrogen monoxide (nitrous oxide)
The sum of nitrogen monoxide (NO) and nitrogen dioxide (NO2), expressed as
NOX
NO2
Ni
The sum of nickel and its compounds, expressed as Ni
Pb
The sum of lead and its compounds, expressed as Pb
PCDD/F
Polychlorinated dibenzo-dioxins and -furans
Sulphide, easily
The sum of dissolved sulphide and of those undissolved sulphides that are easily
released
released upon acidification, expressed as S2SOX
The sum of sulphur dioxide (SO2) and sulphur trioxide (SO3), expressed as SO2
SO2
Sulphur dioxide
SO3
Sulphur trioxide
Sulphite
Dissolved sulphite, expressed as SO32Sulphate
Dissolved sulphate, expressed as SO42The sum of antimony, arsenic, lead, chromium, cobalt, copper, manganese,
nickel,
vanadium
and
their
compounds,
expressed
as
Sb+As+Pb+Cr+Co+Cu+Mn+Ni+V
a. antimony and its compounds, expressed as Sb;
b. arsenic and its compounds, expressed as As;
c. lead and its compounds, expressed as Pb;
Sb+As+Pb+Cr+
d. chromium and its compounds, expressed as Cr;
Co+Cu+Mn+Ni+V
e. cobalt and its compounds, expressed as Co;
f. copper and its compounds, expressed as Cu;
g. manganese and its compounds, expressed as Mn;
h. nickel and its compounds, expressed as Ni;
i. vanadium and its compounds, expressed as V;
j. manganese and its compounds, expressed as Mn
TOC
Total organic carbon, expressed as C (in water)
TSS
Total suspended solids. Mass concentration of all suspended solids (in water),
measured via filtration through glass fibre filters and gravimetry
TVOC
Total volatile organic carbon, expressed as C (in air)
Zn
The sum of zinc and its compounds, expressed as Zn
Continuous
Measurement using an 'automated measuring system' (AMS) or a 'continuous
measurement
emission monitoring system' (CEM) permanently installed on site
Periodic
Determination of a measurand (a particular quantity subject to measurement) at
measurement
specified time intervals using manual or automated reference methods. A
periodic measurement of emissions to air is the average over 3 consecutive
measurements of at least half an hour). A periodic measurement of emissions to
water is a flow-proportional composite sample over 24-hour.
Predictive emissions
Predictive Emissions Monitoring Systems: System used to determine the
monitoring system
emissions concentration of a pollutant from an emission source on a continuous
(PEMS)
basis, based on its relationship with a number of characteristic continuously
monitored process parameters (e.g. the fuel gas consumption, the air/fuel ratio)
and fuel or feed quality data (e.g. the Ssulphur content)
Direct discharge
Discharge to a receiving water body at the point where the emission leaves the
installation without further downstream treatment
Start-up and shutThe time period of plant operation as determined pursuant to the provisions of
down period
Commission Implementing Decision 2012/249/EU of 7 May 2012, concerning
the determination of start-up and shut-down periods for the purposes of Directive
2010/75 of the European Parliament and the Council on industrial emissions
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Valid
(hourly average)
An hourly average is considered valid when there is no maintenance or
malfunction of the automated measuring system
For the purposes of these BAT conclusions, the following acronyms apply:
Acronyms
Definition
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Automated measuring system
Air supply unit
Bubbling fluidised bed (combustion)
Blast furnace gas
Combined cycle gas turbine, with or without supplementary firing
Continuous emission monitoring system
Circulating fluidised bed (combustion)
Combined heat and power
Coke oven gas
Carbonyl sulphide
Pilot fuel ignited
Duct dry sorbent injection
Fluidised bed combustion
Flue-gas desulphurisation
Gas diesel
Heavy fuel oil
Heat recovery steam generator
Integrated gasification combined cycle plant
Light fuel oil
Lower heating value
Low-NOX burner
No BAT-AEL
Non-conventional (fuel)
Not determined
Methyl diethanolamine
Open-cycle gas turbine
Pulverised combustion
Predictive emissions monitoring system
Pressurised fluidised bed (combustion)
Quality Assurance/Quality Control
Selective catalytic reduction
Flue-gas desulphurisation by using a spray dryer
Spark ignited
Selective non-catalytic reduction
Wet flue-gas desulphurisation
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AMS
ASU
BFB(C)
BFG
CCGT
CEM
CFB(C)
CHP
COG
COS
DF
DSI
FBC
FGD
GD
HFO
HRSG
IGCC
LFO
LHV
LNB
NA
NC (fuel)
ND
MDEA
OCGT
PC
PEMS
PFB(C)
QA/QC
SCR
SDS
SG
SNCR
WFGD
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Chapter 10
General considerations
Best Available Techniques
The techniques listed and described in these BAT conclusions are neither prescriptive nor
exhaustive. Other techniques may be used that ensure at least an equivalent level of
environmental protection.
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Unless otherwise stated, these BAT conclusions are generally applicable.
Expression of Emission levels associated with the best available techniques (BAT-AELs)
for emissions to air
PR
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Unless stated otherwise, Emission levels associated with the best available techniques (BATAELs) for emissions to air given in these BAT conclusions refer to concentrations, are
expressed: as either mass of emitted substances per volume of waste flue-gas under the
following standard conditions: dry gas, temperature of 273.15 K, pressure of 101.3 kPa (273.15
K, 101.3 kPa), after deduction of water vapour content (dry gas), and expressed in the units
g/Nm3, mg/Nm3, µg/Nm3 or ng I-TEQ/Nm3.

at a standardised O2 content of:
Activity
IN
Reference conditions for oxygen used to express BAT-AELs in this document are shown in the
table given below.
Oxygen reference conditions
AF
T
Combustion of solid fuels
Combustion of solid fuels in combination
with liquid and/or gaseous fuels
Waste co-incineration
Combustion of liquid and/or gaseous fuels
when not taking place in a gas turbine or
an engine
Combustion of liquid and/or gaseous fuels
when taking place in a gas turbine or an
engine
Combustion in IGCC plants
6%
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3%
G
15 %
o
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
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6 % for solid fuels, waste co-incineration, multi-fuel firing of solid fuel with
gaseous and/or liquid fuels;
o 3 % for combustion plants, other than gas turbines and engines combusting
liquid and/or gaseous fuels;
o 15 % for gas turbines and engines combusting liquid and/or gaseous fuels, and
for multi-fuel fired IGCC plants.
without subtraction of uncertainty.
W
The formula for calculating the emission concentration at the reference oxygen level is:
ER =
where
ER (mg/Nm3)
OR (vol-%)
EM (mg/Nm3)
OM (vol-%)
8
=
=
=
=
21 – OR
21 – OM
×
EM
emission concentration at the reference oxygen level OR;
reference oxygen level;
measured emission concentration;
measured oxygen level.
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Where emission levels associated with the best available techniques (BAT-AELs) are given for
different averaging periods, all of those BAT-AELs apply.
Unless stated otherwise, BAT-AELs for emissions to water given in these BAT conclusions are
given without subtraction of uncertainty as mass of emitted substances per volume of waste
water, expressed in the units g/l, mg/l or µg/l.
Unless stated otherwise, the techniques identified in these BAT conclusions are generally
applicable.
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For averaging periods, the following definitions apply:
Averaging period
Daily average
Average of samples obtained
during one year (for periodic
measurements)
PR
Average over the sampling
period
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Yearly average
Definition
Emissions to air: maximum over one year of the Averages over a period
of 24 hours of valid hourly averages obtained given by a continuous
measurements
Emissions to air: Average over a period of one year of valid hourly
averages obtained by a continuous measurements.
Average value of three consecutive measurements of at least 30 minutes
each (1)
Emissions to air: Average of the values obtained during one year of the
periodic measurements taken with the monitoring frequency set for each
parameter
Emissions to water: average (weighted according to the daily flows)
over one year of the periodic measurements taken with the monitoring
frequency set for the relevant parameter
T
IN
(1) For any parameter where, due to sampling or analytical limitations, 30-minute sampling is inappropriate, a suitable
sampling period is employed.
AF
Emission levels associated with the best available techniques (BAT-AELs) for emissions to
water
N
G
D
R
Emission levels associated with the best available techniques (BAT-AELs) for emissions to
water given in these BAT conclusions refer to concentrations, expressed as mass of emitted
substances per volume of water, and expressed in µg/l, mg/l, or g/l. The BAT-AELs refer to 24hour flow-proportional composite samples, taken with the minimum frequency set for the
relevant parameter and under normal operating conditions. Time-proportional sampling can be
used provided that sufficient flow stability is demonstrated.
KI
Energy efficiency levels associated with the best available techniques (BAT-AEELs)
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An energy efficiency level associated with the best available techniques (BAT-AEEL) refers to
the ratio between the plant's net energy output(s) and the plant's fuel/feedstock energy input.
The net energy output(s) is determined at the combustion, gasification, or IGCC plant
boundaries and for the plant operated at maximum continuous rating (MCR) conditions. In the
case of combined heat and power (CHP) plants, the net total fuel utilisation BAT-AEEL refers
to the combustion plant being operated at full load simultaneously for both heat and power, and
the net electrical efficiency BAT-AEEL refers to the combustion plant generating only
electricity at MCR. The net mechanical energy efficiency refers to the integral (over a given
period of time) of the differential of pressure (in Pascal) multiplied by the corresponding
volumetric flow rate of the gas/liquid (in cubic metre per second) driven.
BAT-AEELs are expressed as a percentage of the fuel/feedstock energy input (as lower heating
value, LHV).
For averaging periods, the following definitions apply:
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Chapter 10
Averaging period
Definition
For net electrical efficiency: ratio between the net electrical output
(electricity produced at alternator terminals minus imported energy) and
fuel/feedstock energy input (as the fuel/feedstock lower heating value)
at the combustion plant boundary over a period of one year.
Yearly average
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For net total fuel utilisation: ratio between the net produced energy
(electricity, hot water, steam, mechanical energy produced minus
imported electrical and/or thermal energy) and fuel energy input (as the
fuel lower heating value) at the combustion plant boundary over a
period of one year
Categorisation of combustion plants according to their total rated thermal input
PR
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For the purpose of these BAT conclusions, when a range of values for the total rated thermal
input is indicated, this is to be read as 'equal to or greater than the lower end of the range and
lower than the upper end of the range'. For example, the plant category 100-300 MWth is to be
read as: combustion plants with a total rated thermal input equal to or greater than 100 MWth
and lower than 300 MWth.
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NOTE to the TWG: whilst cross-references are provided to other parts of this document in
order to aid the work of the TWG, they will not be included in the final BAT conclusions
themselves. Such cross-references are displayed in brackets and italics.
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10.1
General BAT conclusions
Unless otherwise stated, the BAT conclusions presented in this section are generally applicable.
The processfuel-specific BAT conclusions included in Sections 10.2 to 10.7 apply, in addition
to these general BAT conclusions mentioned in this section.
10.1.1
Environmental management systems
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BAT 1. In order to improve the overall environmental performance of large combustion
plants, BAT is to implement and adhere to an environmental management system (EMS)
that incorporates all of the following features:
T
IN
PR
structure and responsibility
recruitment, training, awareness and competence
communication
employee involvement
documentation
effective efficient process control
planned regular maintenance programmes
emergency preparedness and response
safeguarding compliance with environmental legislation;
AF
(a)
(b)
(c)
(d)
(e)
(f)
(g)
(h)
(i)
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i. commitment of the management, including senior management;
ii. definition of an environmental policy that includes the continuous improvement of the
installation by the management;
iii. planning and establishing the necessary procedures, objectives and targets, in
conjunction with financial planning and investment;
iv. implementation of procedures paying particular attention to:
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v. checking performance and taking corrective action, paying particular attention to:
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(a) monitoring and measurement (see also the reference document on the
General Principles of Monitoring monitoring of emissions to air and
water from IED-installations – ROM)
(b) corrective and preventive action
(c) maintenance of records
(d) independent (where practicable) internal and external auditing in order
to determine whether or not the EMS conforms to planned
arrangements and has been properly implemented and maintained;
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vi. review of the EMS and its continuing suitability, adequacy and effectiveness by senior
management;
vii. following the development of cleaner technologies;
viii. consideration for the environmental impacts from the eventual decommissioning of the
installation at the stage of designing a new plant, and throughout its operating life
including;
(a) avoiding underground structures;
(b) incorporating features that facilitate dismantling;
(c) choosing surface finishes that are easily decontaminated;
(d) using an equipment configuration that minimises trapped chemicals and
facilitates drain-down or cleaning;
(e) designing flexible, self-contained equipment that enables phased
closure;
(f) using biodegradable and recyclable materials where possible;
TL/JFF/EIPPCB/Revised LCP_Draft 1
April 2015
11
Chapter 10
ix. application of sectoral benchmarking on a regular basis.
Specifically for this large combustion plants sector, it is also important to consider the following
potential features of the EMS, described in the relevant BAT where appropriate:
N
G
D
R
AF
T
IN
PR
O
G
R
ES
S
x. identify proper risk points for fuels subject to self-ignition and survey accordingly the
fuel storage areas.
xi. quality assurance/quality control programmes to ensure that the characteristics of all
fuels are fully determined and controlled (see BAT 5);
xii. a management plan in order to minimise the occurrence and duration of other than
normal operating condition periods, including start-up and shutdown periods (see BAT 6
and BAT 6 bis).
xiii. a waste management plan to ensure that waste is avoided, prepared for reuse, recycled or
otherwise recovered, including the use of techniques in BAT 13;
xiv. environmental and safety management system to identify and plan to prevent and deal
with uncontrolled and/or unplanned emissions to the environment, in particular:
(a) emissions to soil and groundwater from the handling and storage of
fuels, additives, by-products and wastes
(b) due to the risk of self-heating and/or self-ignition of fuel in the storage
and handling activities;
xv. a dust management plan to prevent or where not practicable, to reduce diffuse emissions
from loading, unloading, storage and/or handling of fuels, residues and additives;
xvi. a noise management plan where a noise nuisance at sensitive receptors is expected or
sustained, including;
(a) a protocol for conducting noise monitoring at the plant boundary;
(b) a noise reduction programme (see techniques in BAT 14);
(c) a protocol for response to noise incidents containing appropriate actions
and timelines;
(d) a review of historic noise incidents, remedies and dissemination of
noise incident knowledge to the affected parties;
xvii. For the combustion or co-incineration of malodourous substances, an odour management
plan including:
(a) a protocol for conducting odour monitoring;
(b) where necessary, an odour elimination programme to identify and
eliminate or reduce the odour emissions;
(c) a protocol to record odour incidents and the appropriate actions and
timelines;
(d) a review of historic odour incidents, remedies and the dissemination to
the affected parties of odour incident knowledge.
KI
Where an assessment shows any of the abovementioned plans are not necessary, a record is
made of the decision, including the reasons.
W
O
R
Applicability
The scope (e.g. level of detail) and nature of the EMS (e.g. standardised or non-standardised) is
generally related to the nature, scale and complexity of the installation, and the range of
environmental impacts it may have.
10.1.2
BAT 2.
Monitoring
BAT is to monitor emissions to:
a. air, after all the flue-gas treatment steps, and before mixing with
other flue-gases and releasing;
b. water, at the point of discharge,
12
April 2015
TL/JFF/EIPPCB/Revised LCP_Draft 1
Chapter 10
for the pollutants given in each BAT-AEL table of these conclusions, with at least the
frequency indicated in the same table and in accordance with EN standards. If EN
standards are not available, BAT is to use ISO, national or other international
standards that ensure the provision of data of an equivalent scientific quality.
R
ES
S
BAT 3.
BAT is to monitor the net electrical efficiency and/or the net total fuel
utilisation and/or the net mechanical energy efficiency of the gasification and/or
combustion plants by periodically carrying out performance tests at full load, according to
EN standards. If EN standards are not available, BAT is to use ISO, national or other
international standards that ensure the provision of data of an equivalent scientific
quality. A performance tests is carried out in particular after the commissioning of the
plant and after each modification that could significantly affect the net electrical efficiency
and/or the net total fuel utilisation and/or the net mechanical energy efficiency of the
plant.
PR
O
G
Applicability
Monitoring of the net electrical efficiency applies only to plants generating only power, to CHP
and to IGCC plants. Monitoring of the net total fuel utilisation applies only to plants generating
only heat, to CHP and to gasification plants (including IGCC plants). Monitoring of the net
mechanical drive efficiency only applies to plants used for mechanical drive applications.
IN
In order to ensure general good environmental and combustion performance, BAT is
to monitor the process parameters and the additional environmental parameters given
below.
Parameter
T
All combustion
plants
D
R
Waste generation
All combustion
plants
AF
Energy output
(power, heat,
mechanical output)
Applicability
G
Waste water flow
N
Noise level
Combustion plants
using coal, lignite,
biomass, peat, HFO
Zn emissions to air
Combustion plants
co-incinerating
sewage sludges
N2O emissions to
air
biomass- and peatfired CFB boilers
KI
R
All combustion
plants
Sb, As, Pb, Cr, Co,
Cu, Mn, Ni, V, Cd,
and Tl emissions to
air
O
W
All combustion
plants
TL/JFF/EIPPCB/Revised LCP_Draft 1
April 2015
Point of
measurement
At
plant/installation
boundaries
At
plant/installation
boundaries
Monitoring
frequency
Continuous
Before discharge
to receiving
At
plant/installation
boundaries
After all the fluegas treatment,
steps, and before
mixing with other
flue-gases and
releasing
After all the fluegas treatment
steps, and before
mixing with other
flue-gases and
releasing
After all the fluegas treatment
steps, and before
mixing with other
flue-gases and
releasing
3 times/yr
3 times/yr
3 times/yr
Twice /yr
13
Chapter 10
{This BAT conclusion is based on information given in Sections 5.1.4.4, 5.5.3.6, 6.1.3.2 and
6.1.3.3}
BAT 3……bis. BAT is to monitor key process parameters relevant for emissions to air and
water including continuous or periodic measurement of flow, oxygen content, and
temperature in the case of flue-gas streams as well as continuous measurement of flow,
pH, and temperature in the case of waste water streams from flue-gas treatment.

NOX




OCGT on offshore
platforms
W
O
N2 O



CO


14
Coal and/or lignite
in circulating
fluidised bed boilers
Solid biomass
and/or peat in
circulating fluidised
bed boilers
Coal and/or lignite
including waste coincineration
Solid biomass
and/or peat
including waste coincineration
HFO- and/or gas
oil-fired boilers and
engines
Gas oil-fired gas
R

Monitoring
associated
with
BAT 4 bis
PR
O
G
Continuous
(2) (3)
All sizes
Generic EN
standards
Continuous
(2) (4)
BAT 19,
BAT 26,
BAT 32,
BAT 36,
BAT 41,
BAT 46, 0,
BAT 48,
BAT 52,
BAT 53,
BAT 65,
BAT 74,
BAT 75,
BAT 83
All sizes
EN 14792
At least once
every year
(5)
BAT 60
All sizes
EN 21258
At least once
every year
(6)
BAT 19,
BAT 26
Continuous
(2) (4)
BAT 19,
BAT 26,
BAT 32,
BAT 37,
BAT 42,
BAT 49,
BAT 54,
BAT 65,
BAT 74,
BAT 75,
BAT 83
KI

Generic EN
standards
IN

All sizes
D
R

Minimum
monitoring
frequency
G

When SCR and/or
SNCR is used
Coal and/or lignite
including waste coincineration plants
Solid biomass
and/or peat
including waste coincineration plants
HFO- and/or gas
oil-fired boilers and
engines
Gas oil-fired gas
turbines
Natural gas-fired
boilers, engines, and
turbines
Iron and steel
process gases
Process fuels from
the chemical
industry in boilers
IGCC plants
N

NH3
Standard(s)
(1)
T
Fuel/Process
Combustion
plant total
rated thermal
input
AF
Substance/
Parameter
R
ES
S
BAT 3 ter. …BAT is to monitor emissions to air with at least the frequency given below
and in accordance with EN standards. If EN standards are not available, BAT is to use
ISO, national or other international standards that ensure the provision of data of an
equivalent scientific quality.
All sizes
April 2015
Generic EN
standards
TL/JFF/EIPPCB/Revised LCP_Draft 1
Chapter 10
Substance/
Parameter
Combustion
plant total
rated thermal
input
Fuel/Process
Standard(s)
(1)
turbines
Natural gas-fired
boilers, engines, and
turbines
 Iron and steel
process gases
 Process fuels from
the chemical
industry in boilers
 IGCC plants
Minimum
monitoring
frequency
Monitoring
associated
with


SO2

EN 14791
BAT 43
D
R
At least once
every three
months (7)
All sizes
No EN
standard
available
At least once
every year
—
BAT 21,
BAT 66
N
KI

W
O
R
HCl
Continuous
(2)
All sizes
When SCR is used
Coal and/or lignite
Process fuels from
the chemical
industry in boilers
All sizes
EN 1911
At least once
every three
months (2)
(8)
Solid biomass
and/or peat
All sizes
Generic EN
standards
Continuous
(2) (9)
BAT 28
All sizes
Generic EN
standards
Continuous
(9)
BAT 76, 0
All sizes
No EN
standard
available
At least once
every three
months (2)
(8)
BAT 21,
BAT 66
BAT 28
G


Generic EN
standards
BAT 21,
BAT 28,
BAT 33,
BAT 38,
BAT 56,
BAT 66,
BAT 76, 0,
BAT 84
Gas oil-fired gas
turbines


All sizes
AF

SO3
BAT 61
T

At least once
every year
(5)
G
Coal and/or lignite
including waste coincineration
Solid biomass
and/or peat
including waste coincineration
HFO- and/or gas
oil-fired boilers and
engines
Iron and steel
process gases
Process fuels from
the chemical
industry in boilers
IGCC plants
EN 15058
O

All sizes
PR
OCGT on offshore
platforms
IN

R
ES
S


Waste coincineration in coal,
lignite, solid
biomass and/or peat
combustion plants
 Coal and/or lignite
 Process fuels from
the chemical
industry in boilers

Solid biomass
and/or peat
All sizes
No EN
standard
available
At least once
every year

Waste coincineration in coal,
lignite, solid
biomass and/or peat
All sizes
Generic EN
standards
Continuous
(9)
HF
TL/JFF/EIPPCB/Revised LCP_Draft 1
April 2015
BAT 76, 0
15
Chapter 10





Continuous
(2)
Continuous
(7) (10)
At least once
every three
months (7)
—
At least once
every year
(11)
BAT 22,
BAT 29,
BAT 34,
BAT 39
All sizes
Generic EN
standards
and
EN 13284-2

Gas oil-fired gas
turbines
All sizes
EN 13284-1
N
IGCC plants
R
KI

Hg
AF
T
EN 14385
EN 14385
At least once
every six
months (7)
(8)
At least once
every three
months (7)
(8)
At least once
every year
(11)
At least once
every three
months (8)
(13)
≥ 300 MWth
EN 14385
≥ 100 MWth
EN 14385
< 300 MWth
EN 13211
≥ 300 MWth
Generic EN
standards
and
EN 14884
Continuous
(9)
BAT 39
BAT 78,
BAT 79
BAT 85
BAT 23

Solid biomass
and/or peat
All sizes
EN 13211
At least once
every year
(13)
BAT 30

Waste coincineration in solid
biomass and/or peat
combustion plants
All sizes
EN 13211
At least once
every three
months (8)
BAT 80
≥ 100 MWth
EN 13211
At least once
every year
(13)
BAT 85

16
< 300 MWth
Coal and/or lignite
including waste coincineration
W
O

All sizes
D
R
Waste coincineration in coal,
lignite, solid
biomass and/or peat
combustion plants
G

PR
HFO- and/or gas
oil-fired engines


Metals and
metalloids
except
mercury
(As, Cd, Co,
Cr, Cu, Mn,
Ni, Pb, Sb,
Se, Tl, V,
Zn)
BAT 22,
BAT 29,
BAT 34,
BAT 58,
BAT 67,
BAT 78,
BAT 79,
BAT 85
All sizes

Coal and/or lignite
Solid biomass
and/or peat
 HFO- and/or gas
oil-fired boilers and
engines
Monitoring
associated
with
Generic EN
standards
and
EN 13284-2
IN
Dust
combustion plants
Coal and/or lignite
including waste coincineration
Solid biomass
and/or peat
including waste coincineration
HFO- and/or gas
oil-fired boilers
Iron and steel
process gases
Process fuels from
the chemical
industry in boilers
IGCC plants
Minimum
monitoring
frequency
R
ES
S

Standard(s)
(1)
G
Fuel/Process
Combustion
plant total
rated thermal
input
O
Substance/
Parameter
IGCC plants
April 2015
TL/JFF/EIPPCB/Revised LCP_Draft 1
Chapter 10
Substance/
Parameter
Combustion
plant total
rated thermal
input
Fuel/Process
Standard(s)
(1)
Minimum
monitoring
frequency
Monitoring
associated
with
All sizes
EN 12619
At least once
every six
months (8)
BAT 37,
BAT 69
All sizes
Generic EN
standards
and EN ISO
13199
Continuous
(9)
BAT 81
All sizes
No EN
standard
available
At least once
every year
BAT 50
All sizes
EN ISO
25139

CH4
Natural gas-fired
engines engines
All sizes
IN
PCDD/F
PR

Process fuels from
the chemical
industry in boilers
 Waste coincineration in coal,
lignite, solid
biomass and/or peat
combustion plants
G
Formaldehy
de
At least once
every year
(6)
BAT 50
At least once
every six
months (8)
(12)
BAT 69,
BAT 81
O
TVOC
HFO- and/or gas
oil-fired engines
 Process fuels from
the chemical
industry in boilers
 Waste coincineration in coal,
lignite, solid
biomass and/or peat
combustion plants
 Natural gas in
spark-ignited leanburn gas (SG) and
dual fuel (DF)
engines
R
ES
S

EN 1948-1,
EN 1949-2,
EN 1948-3
W
O
R
KI
N
G
D
R
AF
T
(1) Generic EN standards for continuous measurements are EN 15267-1, EN 15267-2, EN 15267-3, and EN 14181.
EN standards for periodic measurements are given in the table.
(2) In the case of plants with a rated thermal input of < 100 MWth operated in emergency-load mode, the monitoring
frequency may be reduced to at least once every year. In the case of plants with a rated thermal input of < 100 MWth
operated in peak-load mode, the monitoring frequency may be reduced to at least once every six months.
(3) In the case of combined use of dedusting and wet abatement techniques (e.g. wet FGD or flue-gas condenser), the
monitoring frequency may be reduced to at least once every year, if it is demonstrated that the emission levels are
consistently within the BAT-AELs set.
(4) In the case of natural gas-fired turbines with a rated thermal input of < 100 MWth operated in emergency- or peakload modes, or in the case of existing OCGTs, PEMS may be used alternatively.
(5) PEMS may be used alternatively.
(6) The measurement is performed with a combustion plant load of > 70 %.
(7) In the case of plants operated in emergency-load mode, the monitoring frequency may be reduced to at least once
every year. In the case of plants operated in peak-load mode, the monitoring frequency may be reduced to at least
once every six months.
(8) The monitoring frequency may be reduced if it is demonstrated that the emission levels are consistently within the
BAT-AELs set. In these specific cases, periodic measurements could be carried out each time that a change of the
fuel and/or waste characteristics may have an impact on the emissions, but in any case at least once every year.
(9) The monitoring frequency may be reduced if it is demonstrated that the emission levels are consistently within the
BAT-AELs set. In these specific cases, periodic measurements could be carried out each time that a change of the
fuel and/or waste characteristics may have an impact on the emissions, but in any case at least once every six months.
(10) The monitoring frequency may be reduced if it is demonstrated that the emission levels are consistently within
the BAT-AELs set due to the fuel used. In these specific cases, periodic measurements could be carried out each time
that a change of the fuel characteristics may have an impact on the emissions, but in any case at least once every three
months for plants not operated in emergency- or peak-load modes.
(11) The list of pollutants monitored and the monitoring frequency may be adjusted after an initial characterisation of
the fuel (see BAT 5) based on a risk assessment of the load of pollutants in the emissions to air, but in any case at
least each time that a change of the fuel characteristics may have an impact on the emissions.
(12) In the case of process fuels from the chemical industry, monitoring is only applicable when the fuels contain
chlorine compounds.
(13) The monitoring frequency does not apply in the case of plants operated in peak- or emergency-load modes.
TL/JFF/EIPPCB/Revised LCP_Draft 1
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17
Chapter 10
BAT 3
quater. BAT is to monitor emissions to water from flue-gas treatment with at
least the frequency given below and in accordance with EN standards. If EN standards are
not available, BAT is to use ISO, national or other international standards that ensure the
provision of data of an equivalent scientific quality.
Substance/Parameter
Minimum
monitoring
frequency
Standard(s)
Total organic carbon
(TOC)
EN 1484
Chemical oxygen demand
(COD)
R
ES
S
EN 872
EN ISO 10304-1
EN ISO 10304-1
G
No EN standard available
BAT 11
EN ISO 10304-3
O
At least once every
month
PR
Various EN standards available
(e.g. EN ISO 11885 or
EN ISO 17294-2)
Various EN standards available
(e.g. EN ISO 12846 or
EN ISO 17852)
Various EN standards available
(e.g. EN ISO 10304-1 or
EN ISO 15682)
EN 12260
T
Hg
No EN standard available
IN
Total suspended solids
(TSS)
Fluoride (F-)
Sulphate (SO42-)
Sulphide, easily released
(S2-)
Sulphite (SO32-)
As
Cd
Cr
Cu
Metals and
Ni
metalloids
Pb
Zn
AF
Chloride (Cl-)
—
—
W
O
R
KI
N
G
D
R
Total nitrogen
Monitoring
associated with
18
April 2015
TL/JFF/EIPPCB/Revised LCP_Draft 1
Chapter 10
10.1.3
General environmental and combustion performance
BAT 4.
In order to improve the general environmental performance of combustion
plants and to reduce their emissions to air of CO and unburnt substances, BAT is to
ensure an optimised complete combustion through stable combustion conditions and to
use an appropriate combination of the techniques given below.
Select or switch totally or partially
to another fuel(s) with a better
environmental profile (with e.g. low
S or Hgsulphur and/or mercury
content) amongst the available fuels
Generally applicable
Applicable within the constraints
given by the energy policy of the
Member State. Applicable within
the constraints associated with the
availability of different types of
fuel with a better environmental
profile as a whole, which may be
impacted by the energy policy of
the Member State.
For existing plants, the type of fuel
chosen may be limited by the
configuration and the design of the
plant
PR
O
b. Fuel choice
Applicability
R
ES
S
a. Fuel blending and mixing
Description
Ensure
stable
combustion
conditions and/or reduce the
emission of pollutants by mixing
different qualities of the same fuel
type (e.g. biomass)
G
Technique
IN
Replace part of a fuel by another
fuel with a better environmental
profile (e.g. use coal and syngas
from biomass gasification instead
of coal only)
See description in Section 10.8
Use of advanced computerised
control system to enable the good
performance of the boiler with
improving combustion conditions
to support the reduction of
emissions. This also includes
high-performance monitoring
Good
design
of
furnace,
combustion chambers, burners,…
and associated devices
Good design and operation of the
ammonia injection system to enable
the achievement of a homogenous
NH3/NOX mixture that favours the
NOX reduction reaction while
limiting the NH3 slip
See description in Section 10.8
Regular
planned
maintenance
according
to
suppliers'
recommendations
Advanced computerised
control system
e.
Good design of the
combustion equipment
KI
N
G
D
R
d.
AF
T
c. Multi-fuel firing
W
O
R
Good design and
f. operation of the ammonia
injection system
g.
Maintenance of the
combustion system
Ratio of replaced fuel may be
limited by configuration of the
existing plant and its associated
achieved level of performance
Generally applicable to new
plants. The applicability to old
plants may be constrained by the
need to retrofit the combustion
and/or control command system(s)
Generally applicable to new plants
Only applicable to plants using
SNCR and/or SCR techniques
Generally applicable
{This BAT conclusion is based on information given in Section 5.1.4.2}
BAT 4 bis.
In order to reduce emissions of ammonia to air from the use of selective
catalytic reduction (SCR) and/or selective non-catalytic reduction (SNCR) for the
abatement of NOX emissions, BAT is to optimise the design and/or operation of SCR
and/or SNCR (e.g. optimised and homogeneous distribution of the reagent/NO X ratio,
optimum size of the reagent drops, stable operating conditions).
BAT-associated emission levels
TL/JFF/EIPPCB/Revised LCP_Draft 1
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19
Chapter 10
The BAT-associated emission level (BAT-AEL) for emissions of NH3 to air from the use of
SCR and/or SNCR is < 5–10 mg/Nm3 as a yearly average or average over the sampling period.
The lower end of the range may correspond to the combined use of SCR with wet abatement
techniques (e.g. wet FGD or flue-gas condenser), and the upper end of the range may
correspond to the use of SNCR without wet abatement techniques.
The associated monitoring is in BAT 3 ter.
R
ES
S
BAT 5.
In order to improve the general environmental performance of combustion and
/or gasification plants and to reduce emissions to air, BAT is to ensure include the
following elements in the QA/QC programmes for all the fuels used includes the following
elements , as part of the environmental management system (see BAT 1):
i.
An initial full characterisation including at least the parameters listed below and in
accordance with EN standards. ISO, national or other international standards may be
used provided they ensure the provision of data of an equivalent scientific quality.
Periodic control of the fuel quality to ensure it is within the criteria of the
characterisation and the plant design. The frequency of testing and the parameters
chosen from the table below are based on the variability of the fuel and an assessment
of the risk of pollutant releases (e.g. concentration in fuel, flue-gas treatment
employed).
Integration of the results in the advanced control system (See description in
Section 10.8).
PR
O
G
ii.
iii.
AF
T
IN
Description
Characterisation and QA/QC testing can be performed by the operator and/or the fuel supplier.
If performed by the supplier, the full results are provided to the operator through a product
(fuel) supplier specification and/or guarantee.
Sampling frequency
D
R
Fuel(s)
representative daily biomass fuel samples
A monthly composite sample which is
created using the daily composite samples
G
Biomass/peat
N



KI
once / week
once / month and at each change of
coal/lignite origin
3 times / year, of the fuel that is combusted
when the periodic measurements of metal
emissions to air take place and at each change
of coal/lignite place of origin
W
O
R
Coal/lignite
Gas oil/HFO
At each fuel delivery
LFO
At each fuel delivery
Natural gas
monthly (provided by the fuel supplier)
Noncommercial
fuels
inProcess
fuels from the
chemical
At each change of production mode that leads
to a change in the by-product residues used as
fuel
20





April 2015
Analysis and Characterisation
Substances/Parameters subject to
characterisation
LHV
moisture
Ash, metals
C, Cl, F, N, S
metals and metalloids (As, Cd, Co, Cr,
Cu, Hg, Mn, Ni, Pb, Sb, Tl, V, Zn)
LHV,
moisture,
volatiles, ash, fixed carbon, C, H, N, O,
S

Br, Cl, F

metals and metalloids trace species (As,
Cd, Co, Cr, Cu, Hg, Mn, Ni, Pb, Sb, Tl,
V, Zn)






Ash, metals
C, S, N, Ni, V
Ash, metals
N, C, S content
LHV
C2H6 8, C3, C4, CH4, CO2, H2, H2S, N2,
Wobbe índex


Br, C, Cl, F, H, N, O, S
metals and metalloids trace species (As,
Cd, Co, Cr, Cu, Hg, Mn, Ni, Pb, Sb, Tl,
V, Zn)
TL/JFF/EIPPCB/Revised LCP_Draft 1
Chapter 10
plantsindustry
(1)
Iron and steel
process gases
Wastes





To be defined in the (pre)-acceptance
procedure
LHV, C2H6 , C3, C4, CH4, CO2, H2, N2,
H2S, COS, dust, Wobbe índex
LHV,
moisture,
volatiles, ash, Br, C, Cl, F, H, N, O, S
metals and metalloids trace species (Cd,
Tl, Hg, Sb, As, Pb, Cr, Co, Cu, Mn, Ni,
V, Zn)
(1) The list of substances/parameters characterised can be reduced to only those that can reasonably be expected to be
present in the fuel(s) based on information on the raw materials and the production processes.
R
ES
S
{This BAT conclusion is based on information given in Sections 5.2.1.2 and 5.2.3.2}
PR
O
G
BAT 6.
In order to minimise the emissions during start-up and shutdown periods,
BAT is to shorten those periods to the minimum time necessary to meet the consumer (e.g.
the grid) requirements use one or a combination of the techniques in BAT 4 (e.g. fuel
choice) during those periods and/or to reduce the occurrence and duration of those
periods by setting up and implementing a management plan as part of the environmental
management system (see BAT 1 and BAT 6 bis), with a special focus on start-up and
shutdown periods, including unplanned shutdown periods. This plan may include the
reduction of the minimum start-up and shutdown loads for stable generation, as defined in
the Commission Implementing Decision 2012/249/EU (using e.g. low load design concepts
in gas turbines).
AF


risk assessment of OTNOC;
appropriate design of the systems considered relevant in generating OTNOC that may
have an impact on emissions to air, water and/or soil;
specific preventive maintenance action plan of these relevant systems;
corrective actions, recording, review of OTNOC and update of the risk assessment if
necessary.
D
R


T
IN
BAT 6 bis.
In order to reduce emissions to air during other than normal operating
conditions (OTNOC), BAT is to minimise the occurrence and duration of those periods by
setting up and implementing a management plan as part of the environmental
management system (see BAT 1), that includes all of the following elements:
G
BAT 6 ter.
BAT is to monitor emissions to air and/or to water during OTNOC,
providing that the monitoring system is not involved in the occurrence of the OTNOC.
W
O
R
KI
N
BAT 6 quater.
In order to prevent or reduce emissions to air during normal
operating conditions (NOC), BAT is to ensure, by appropriate design, operation and
maintenance, that the emission abatement systems are used at optimal capacity and
availability.
TL/JFF/EIPPCB/Revised LCP_Draft 1
April 2015
21
Chapter 10
10.1.4
Energy efficiency
BAT 7.
In order to increase the energy efficiency of combustion plants that are not
operated in peak- and/or emergency-load modes, BAT is to use an appropriate
combination of the techniques given below.
Technique
Ultra-supercritical
steam conditions
Applicability
Applicable to new baseload
plants > 300 MWth.
Only applicable to new baseload
plants of ≥ 600 MWth.
Not applicable when the purpose
of the combustion plant is to
produce low steam temperatures
and/or pressures in process
industries.
Not applicable to gas turbines
and engines generating steam in
CHP mode.
For combustion plants burning
biomass, the applicability may
be
constrained
by
hightemperature corrosion in the
case of certain biomasses
Applicable for existing plants
> 1000 MWth.
Applicability may be limited for
existing plants < 1000 MWth
when the steam turbine cannot
be
adapted
for
the
implementation of a double
reheat cycle (e.g. material not
resistant enough for supporting
such pressure / temperature).
O
PR
G
Operate withat the highest possible
pressure and temperature of the working
medium gas or steam, within the
constraints associated with e.g. the control
of NOX emissions or the characteristics of
energy demanded
Operate with the highest possible pressure
drop in the low pressure end of the steam
turbine through utilisation of the lowest
possible temperature of the cooling water
(fresh water cooling)
Operate with lower turbine exhaust
pressure through utilisation of the lowest
possible temperature of the condenser
cooling water, within the design conditions
Recovery of heat (mainly from the steam
cooling system) for producing hot water /
steam which isto be used in industrial
processes/activities or in district heating.
Additional heat recovery is possible from:
 flue-gas
 grate cooling
 circulating fluidised bed
Preheat water coming out of the steam
condenser in the steam circuit with
Generally applicable
Optimisation of the
steam cycle
W
O
d.
R
KI
N
Optimisation of the
c. working medium
conditions
D
R
AF
T
IN
Supercritical and
b. ultra-supercritical
steam conditions
Use of a steam circuit, including steam
reheating systems, in which steam can
reach pressures above 220.6 bar and
temperatures above 374°C in the case of
supercritical conditions, and above 250–
300 bar and temperatures above 580–
600°C in the case of ultra-supercritical
conditions
G
R
ES
S
a.
Description
Use of a steam circuit, including double or
triple steam reheat systems, in which steam
can reach pressures of about 300 bar and
temperatures of about 600°C
e.
Heat recovery by
cogeneration (CHP)
f.
Regenerative feedwater heating
22
April 2015
Generally applicable
Generally aApplicable within
the
constraints
given
byassociated with the local
power and heat demand.
The applicability may be limited
in the case of gas compressors
with
an
unpredictable
operational heat profile
Generally applicable to new and
existing combined-cycle plants
TL/JFF/EIPPCB/Revised LCP_Draft 1
Chapter 10
Preheating of
g.
combustion air
Steam turbine
h.
upgrades
recovered heat from the plant, before
reusing it in the boiler
Preheating combustion air byThe reuseing
of part of the recovered heat recovered
from the combustion flue-gas to preheat
the air used in combustion
This includes techniques such as
iIncreaseing temperature and pressure of
medium-pressure steam, addition of a lowpressure turbine, modifications of theblade
geometry of the turbine rotor blades
See description in Section 10.8.
The computerised control of the main
combustion parameters enables, in order to
improve the combustion efficiency
j.
Cooling tower
discharge
The release of Dischargeemissions to air
through a cooling tower and not via a
dedicated stack
O
PR
IN
T
AF
D
R
Generally applicable to new and
existing plants fitted with wet
FGD
The rReduction of fuel moisture content
before combustion to improve combustion
conditions
Applicable to the combustion of
biomass and/or, peat, andor to
the combustion of lignite within
the
constraints
given
byassociated
with
autospontaneous
combustion
risks (e.g. the moisture content
of peat is kept above 40 %
throughout the delivery chain
during transport to the plant).
Applicable on a-case-by-case
basis for the gasification of
biomass depending on the
gasification process
The
retrofit
of
existing
combustion or
gasification
plants may be restricted by the
extra calorific value that can be
obtained from the drying
operation and by the limited
retrofit possibilities offered by
some boiler designs or plant
KI
R
O
W
l.
Fuel predrying
Generally applicable to new
plants. The applicability to old
plants may be constrained by the
need to retrofit the combustion
and/or
control
command
system(s)
Applicable to new and existing
plants
Only applicable to plants fitted
with wet FGD where reheating
of the flue-gas is necessary
before release, and where the
combustion
plant
cooling
system is a cooling tower
Applicable when the cooling
tower is selected as the cooling
system. Applicable to existing
plants subject to existing
material and location design
constraints
The dDesign of the stack in order to enable
water vapour condensation from the
saturated flue-gas and thus to avoid the
need to use a flue-gas reheatergas-gas
heater after the wet FGD
N
G
k. Wet stack
Generally applicable The
applicability may be restricted
by demand/steam conditions
and/or limited plant lifetime
G
i.
Advanced
computerised
control system
Only applicable to steam circuits
and not to hot boilers.
Applicability to existing plants
may be limited due to
constraints associated with the
plant configuration and the
amount of recoverable heat
Generally aApplicable within
the constraints related to the
need to control given by the
needs of NOX emissions control
R
ES
S
Feed-water
preheating using
recovered heat
TL/JFF/EIPPCB/Revised LCP_Draft 1
April 2015
23
Chapter 10
m. Fuel preheating
Preheating of fuel by using recovered heat
Combustion
optimisation
See description in Section 10.8.
Optimising the combustion minimises
Minimising the content of unburnt
substances in the flue-gases and in solid
combustion residues
Minimisation of
heat losses
r.
Minimisation of
energy consumption
R
ES
S
Use of advanced materials proven to be to
reachcapable of withstanding high
operating temperatures and pressures and
thus to achieve increased steam /
combustion process efficiencies
Minimising residual heat losses, e.g.
through the slag and by isolating insulating
radiating sources
Minimising
the
internal
energy
consumption by, e.g. scarification of the
evaporator, (greater efficiency of the feed
water pump), etc.
The flue-gas condenser is a heat exchanger
recovering heat, where water is heated by
the flue-gases before it is heated in the
steam condensers. The vapour content in
the flue-gases thus condense as it is cooled
by the heating waterSee description in
Section 10.8
Only applicable to new plants
Only applicable to solid-fuelfired combustion plants and to
gasification / IGCC plants
Generally applicable
CHP readiness
See description in Section 10.8
G
t.
D
R
AF
s. Flue-gas condenser
T
IN
q.
Heat accumulation storage in CHP mode
G
p. Advanced materials
Only Applicable to CHP plants.
The applicability may be limited
in the case of low heat load
demand
O
o. Heat accumulation
Generally applicable
PR
n.
configurations
Generally applicable within the
constraints related to the boiler
design and to the need to control
NOX emissions given by the
needs of NOX emissions control
Generally applicable to CHP
plants provided there is enough
demand for low-temperature
heat
Only applicable to new plants
where there is a realistic
potential for the future use of
heat in the vicinity of the plant
when immediate opportunities
for heat supply at the time of
building are unavailable
KI
Diffuse emissions from unloading, storage and handling of
fuel and additives
R
10.1.5
N
{This BAT conclusion is based on information given in Section 3.3.4}
W
O
BAT 8.
In order to reduce VOC emissions to air from the storage of liquid fuels, BAT
is to use in storage tanks one of the techniques given below.
a.
24
Sealing roof
The storage tanks are fitted with
floating roofs equipped with high
efficiency seals or a fixed roof tank
connected to a vapour recovery
system. High efficiency seals are
specific devices for limiting the
losses of vapour
April 2015
Applicable to liquid-fuel-fired
combustion plants
TL/JFF/EIPPCB/Revised LCP_Draft 1
Chapter 10
b.
Closed-loop system
For internal inspections, tanks have
to be periodically emptied, cleaned,
and rendered gas-free. This cleaning
includes dissolving the tank bottom.
Closed-loop systems that can be
combined with end-of-pipe mobile
abatement techniques prevent or
reduce VOC emissions
Applicable to liquid-fuel-fired
combustion plants
m. Cover stockpiles
G
N
KI
W
O
R
r.
s.
t.
Enclosed
conveyors and
protected
transfer points
G
Applicability
O
Use water spray systems in storage areas
and/or stockpiles
Cover stockpiles (e.g. of petroleum coke)
Applicable to solid-fuel-fired
combustion plants
Applicable in sites where
freezing does not occur. Not
applicable to fuels with high
surface moisture content
Generally
applicable
to
solid-fuel-fired
combustion
plants
Grow grass over long-term storage areas
Applicable when dusty fuel is
supplied and handled
Apply the transfer of extracted fuels via
closed belt conveyors or trains directly to
the on-site fuel storage area
Applicable to plants located
near to mines providing the
fuel
Use cleaning devices for conveyor belts
Applicable to solid-fuel-fired
combustion plants
D
R
Grass over longn. term storage
areas
Direct transfer
o. of extracted
fuels
Use cleaning
p. devices for
conveyor belts
Optimise on-site
q.
transport
PR
l.
Storage water
spray systems
IN
Minimise the
k. height of the fuel
drop
Description
Use loading and unloading equipment that
minimises the height of the fuel drop to the
stockpile (e.g. when storing fine wood
material and dry peat)
T
Technique
capture emissions nearest to the source;
abate the captured pollutants;
optimise the capture efficiency and subsequent cleaning;
use the techniques given below.
AF
a.
b.
c.
d.
R
ES
S
BAT 9.
In order to reduce diffuse emissions to air, including odorous substances, from
the unloading, storage and handling of fuels, waste and additives, BAT is to:
Rationalise on-site transport systems to
minimise movements
Use enclosed conveyors, pneumatic
transfer systems, silos with well-designed,
robust extraction, and filtration equipment
on delivery, conveyor, and transfer points
of dusty materials, e.g. dry peat, dusty
biomass, coal, lignite, waste, lime, and
limestone
Generally applicable
Not applicable to fuels with
high surface moisture content
Leak detection
systems
Use leak detection systems and alarms
Applicable when natural gas is
supplied and handled
Air treatment of
sewage sludge
storages
Apply suction plants and subsequent
cleaning devices to silos bunkers and
hoppers storing sewage sludge. For
abatement, the odorous air can be led
directly to the combustion chamber or
burner, where it can be used as combustion
air
Applicable to plants storing
sewage sludge before coincineration
The BAT reference document on Emissions from Storage (EFS BREF) contains BAT
conclusions that are of relevance for combustion plants storing fuels, waste and additives.
TL/JFF/EIPPCB/Revised LCP_Draft 1
April 2015
25
Chapter 10
10.1.6
Water usage and emissions to water and water
consumption
BAT 10. In order to reduce water usage consumption and the volume of contaminated
waste water discharged into receiving waters, BAT is to use one or a combination of the
techniques given below.
d.
Segregate/reuse
non-contaminated
water streams
(e.g. oncethrough cooling
water, rain water)
Generally applicable
R
ES
S
Applicable to new plants.
Applicable to existing plants
within the constraints given by
the configuration of the water
circuits
G
Applicable to new plants.
Applicable to existing plants
within the constraints given by
the configuration of the water
circuits Not applicable to waste
water from cooling systems
operated with seawater or in
once-through mode
O
Maximise
internal Water
recycling
Applicability
IN
PR
c.
a.
T
b.
Use water and
drainage systems
segregating
contaminated
water streams
Description
Avoid the use of potable water for
processes and abatement techniques
Design of an industrial site with optimised
water
management,
where
each
(potentially) contaminated water stream
(from e.g. wet abatement, run-offs, etc.) is
collected and treated separately, depending
on the pollution content
Increase the number and/or capacity of
water recycling systems when building new
plants or modernising/revamping existing
plants, e.g. implementing the reuse of
cleaned waste water for FGD limestone
slurry preparation Residual aqueous
streams from the plant are reused for other
purposes. The degree of recycling is limited
by the quality requirements of the recipient
water stream and the water balance of the
plant
Design of an industrial site in order to
avoid sending non-contaminated water to
general waste water treatment system and
to reuse as much as possible collected
water internally for industrial/sanitary
purpose in substitution of other raw water.
Water is transferred to the gas phase using
heat. This is typically carried out in vapourcompression evaporation systems. The
water vapour is condensed and reused (after
further treatment, if needed). The
concentrated waste water requires further
treatment (e.g. crystallisation or spraydrying) and/or disposal
Ash is conveyed to the silos with systems
using vacuum and/or pressure
D
R
AF
a.
Technique
Avoid the use of
potable water
Evaporation
c
Dry ash handling
Not applicable to plants where
the
additional
energy
consumption
offsets
the
environmental benefits
Generally applicable
KI
N
G
b
Applicable to new plants.
Applicable to existing plants
within the constraints given by
the configuration of the water
circuits
R
{This BAT conclusion is based on information given in Section 3.3.5}
W
O
BAT 10 bis. In order to prevent the contamination of uncontaminated waste water and
to reduce emissions to water, BAT is to segregate waste water streams and to treat them
separately, depending on the pollutant content.
Description
Waste water streams that are typically segregated include surface water run-off, cooling water,
and waste water from flue-gas treatment.
Applicability
The applicability may be restricted in the case of existing plants due to the configuration of the
drainage systems.
26
April 2015
TL/JFF/EIPPCB/Revised LCP_Draft 1
Chapter 10
BAT 11. In order to reduce the emission of pollutants contained waste water discharged
into receiving waters, combustion plants fitted with wet abatement techniques for
controlling their emissions to air, BAT is to use a combination of the techniques given
below.
b.
Physicochemical
treatment
Zero liquid
discharge (ZLD)
Applicability
Sedimentation, filtration, oil separation.
Generally applicable
Removal of fluoride, sulphide, COD,
particulates by adding chemicals to cause
the solids to settle, and removal of metals
by increasing the pH (precipitation,
flocculation, coagulation, sedimentation,
neutralisation)
Generally applicable
Precipitation, softening, crystallisation,
evaporation
Applicable only to plants
discharging to very sensitive
receiving waters, where techniques
(a) and (b) do not enable meeting
the environmental quality
standards
W
O
R
KI
N
G
D
R
AF
T
IN
PR
O
G
c.
Description
R
ES
S
a.
Technique
Mechanical
treatment
TL/JFF/EIPPCB/Revised LCP_Draft 1
April 2015
27
Chapter 10
BAT 11
In order to reduce emissions to water from flue-gas treatment, BAT is to
use an appropriate combination of the techniques given below, and to use secondary
techniques as close as possible to the source in order to avoid dilution.
Typical pollutants
prevented/abated
Primary techniques
Aerobic biological treatment
e.
Anoxic/anaerobic biological
treatment
Coagulation and flocculation
f.
Crystallisation
g.
Filtration (e.g. sand filtration,
microfiltration, ultrafiltration)
d.
R
ES
S
c.
Secondary techniques (1)
Organic compounds,
Generally applicable
mercury (Hg)
Generally applicable for the treatment of
organic compounds. Aerobic biological
Biodegradable organic
treatment of ammonium (NH4+) may not
compounds,
be applicable in the case of high
ammonium (NH4+)
chloride concentrations (i.e. around 10
g/l)
Mercury (Hg), nitrate
Generally applicable
(NO3-), nitrite (NO2-)
Suspended solids
Generally applicable
Metals and metalloids,
sulphate (SO42-),
Generally applicable
fluoride (F-)
G
Adsorption on activated
carbon
Generally applicable
O
b.
Organic compounds,
ammonia (NH3)
PR
a.
Optimised combustion (see
BAT 4) and flue-gas treatment
systems (e.g. SCR/SNCR, see
BAT 6 quinquies)
Suspended solids
Suspended solids, free
oil
i. Ion exchange
Metals
j. Neutralisation
Acids, alkalis
k. Oil/water separation
Free oil
Sulphide (S2-), sulphite
l. Oxidation
(SO32-)
Metals and metalloids,
m. Precipitation
sulphate (SO42-),
fluoride (F-)
n. Sedimentation
Suspended solids
o. Stripping
Ammonia (NH3)
(1) The descriptions of the techniques are given in Section 10.8.6.
Flotation
Generally applicable
Generally applicable
Generally applicable
Generally applicable
Generally applicable
Generally applicable
Generally applicable
Generally applicable
Generally applicable
N
G
D
R
AF
T
h.
Applicability
IN
Technique
KI
{This BAT conclusion is based on information given in Section 3.3.5}
O
R
BAT-associated emission levels
The BAT-associated emission levels (BAT-AELs) to receiving waters are given in Table 10.1.
W
The BAT-AELs refer to direct discharges to a receiving water body at the point where the
emission leaves the installation.
28
April 2015
TL/JFF/EIPPCB/Revised LCP_Draft 1
Chapter 10
Table 10.1: BAT-AELs for emissions to water from combustion plants fitted with wet abatement
techniques
Unit
COD(2)
Suspended solids
Fluoride as F (3)
Chloride as Cl (3)
Sulphate as SO4 (3)
Sulphide as S
Sulphite as SO3
Total N
THC
mg/l
BAT-AEL
Average of samples
obtained during one year
30–150
5–30
1–15
500–1000
300–1500 (1)
0.01–0.1
1–5
1–50
1–10
Sb+As+Pb+Cr+Co+Cu+Mn+Ni+V
0.01–1
0.01–0.25
0.001–0.015
0.01–0.5
Periodic
measurement:
once/month
G
Cd+Tl
Hg
Zn
Monitoring
frequency
R
ES
S
Parameters
IN
PR
O
(1) The lower end of the ranges is achieved by plants where other streams than just the stream from the wet abatement
techniques, are mixed before discharging into receiving waters.
(2) Due to difficulties in monitoring COD emissions in the case of high levels of chlorides in waters, TOC is directly
measured instead of COD when chloride concentration exceeds 1000 mg/l, and COD concentration is then estimated
through a plant-specific correlation pattern.
(3) BAT-AELs not applicable when using salty water e.g. for seawater WFGD
Table 10.1: BAT-AELs for direct discharges to a receiving water body from flue-gas treatment
T
Substance/Parameter
W
O
R
KI
N
G
D
R
AF
Total organic carbon (TOC)
Chemical oxygen demand (COD)
Total suspended solids (TSS)
Fluoride (F-)
Sulphate (SO42-)
Sulphide (S2-), easily released
Sulphite (SO32-)
As
Cd
Cr
Cu
Metals and metalloids
Hg
Ni
Pb
Zn
BAT-AELs
Daily average
20–50 mg/l (1)
60–150 mg/l (1)
10–30 mg/l
10–25 mg/l
1.3–2.0 g/l (2) (3)
0.1–0.2 mg/l
1–20 mg/l
10–50 µg/l
2–5 µg/l
10–50 µg/l
10–50 µg/l
0.5–5 µg/l
10–50 µg/l
10–20 µg/l
50–200 µg/l
(1) Either the BAT-AEL for TOC or the BAT-AEL for COD applies. TOC
monitoring is the preferred option because it does not rely on the use of very
toxic compounds.
(2) The BAT-AEL only applies to plants using calcium compounds in flue-gas
treatment.
(3) The upper end of the range may not apply in the case of high salinity of the
waste water (e.g. chloride concentrations ≥ 5 g/l) due to the increased solubility
of calcium sulphate.
The associated monitoring is in BAT 3 quater.
TL/JFF/EIPPCB/Revised LCP_Draft 1
April 2015
29
Chapter 10
10.1.7
Waste, by-products and residuesWaste management
BAT 12. In order to prevent or, where it is not practicable, to reduce waste generation,
BAT is to adopt and implement a waste management plan that ensures that waste is, in
order of priority, avoided, reused, recycled, recovered or safely disposed of. For specific
waste streams, deviations from the order of priority may be justified based on life-cycle
thinking taking into account the overall impacts of the generation and management of
such waste.
G
the proportion of residues which arise as by-products;
waste reuse according to the specific requested quality criteria;
waste recycling;
other recovery,
O
a.
b.
c.
d.
R
ES
S
BAT 13. In order to reduce the quantityies of wastes sent for disposal from the
combustion process and abatement techniques sent for disposal, BAT is to organise
operations on the site so as to maximise, in order of priority and taking into account lifecycle thinking:
Technique
PR
by implementing an appropriate combination of on-site and/or off-site technical
measurestechniques such as:
Description
Applicability
Generally
applicable
The
applicability may be limited by
the mechanical condition of the
catalyst
and
the
required
performance with respect to
controlling NOX, and NH3
emissions
Energy
recovery by
f. reusing waste
reuse in the
fuel mix
The residual energy content of ash and sludges
generated by the combustion of coal, lignite,
heavy fuel oil, peat, or biomass can be recovered
on site and/or off site when the waste has a
residual calorific value. Energy recovery by
on-site reuse in a fuel mix is possible, e.g. for
sludge and carbon-rich ash
Generally aApplicable to plants
that can accept waste in the fuel
mix, and subject to the technical
possibility of feeding the fuels
into the combustion chamber
Reuse of the
FGD gypsum
Off-site reuse of the gypsum generated by the wet
abatement of SOXFGD as a substitute for
rawmined gypsum (e.g. as fillers in the
plasterboard industry). The amount quality of
limestone used in the wet FGD influences the
purity of the gypsum
KI
O
R
g.
N
G
D
R
AF
T
IN
Regeneration
e. of spent
catalysts
On-site Catalyst regenerations (e.g. up to 4four
times for SCR catalysts) restores some or all of the
original performances, extending the service life
of the catalyst to several decades. Regeneration is
integrated in a catalyst management scheme
W
Reuse of
residues in the
h.
construction
sector
Off-site Reuse of residues (of e.g. from the residue
of semi-dry desulphurisation processes, fly ash,
bottom ash) as a construction material (e.g. in road
constructionbuilding, in concrete production – to
replace sand -, or in the cement industry)
Generally aApplicable within the
constraints given by associated
with the required gypsum quality,
andthe
health
demand
requirements associated to a
specific use, and by the market
conditions
Generally aApplicable within the
constraints given by associated
with the required material quality
(e.g. physical properties, content
of harmful substances) associated
to each specific use, and by the
market conditions
{This BAT conclusion is based on information given in Sections 3.1.11 and 3.3.6}
30
April 2015
TL/JFF/EIPPCB/Revised LCP_Draft 1
Chapter 10
10.1.8
Noise emissions
BAT 14. In order to reduce noise emissions from relevant sources in combustion plants
(e.g. boiler soot blowers, cutting-straw hammer-mills, fuel pneumatic transport to the
burner), BAT is to use one or a combination of the techniques given below.
Description
Applicability
Generally aApplicable to new
Strategic planning of
Noise levels can be reduced by plants. In the case of existing
the Appropriate location increasing the distance between the plants, the relocation of equipment
a.
of equipment and
emitter and the receiver and by using and production units may be
buildings
buildings as noise screens
restricted by the lack of space or by
excessive costs
The noise-reduction programme
includes identification of sources and
affected areas, calculations and
Noise-reduction
b.
measurements of noise levels,
Generally applicable
programme
identification of the most costeffective combination of techniques,
their implementation, and monitoring
This includes:
 improved
inspection
and
maintenance of equipment to
prevent failures;

closing of doors and windows of
Operational measures
covered enclosed areas, if
and management
possible;
c. techniques in buildings
Generally applicable
containing noisy
 equipment
operated
by
equipment
experienced staff;
 avoidance of noisy activities
during at night-time, if possible;
 provisions for noise control
during maintenance activities
This
potentially
includes
compressors, pumps and disks.
Generally applicable when the to
 compressors with ≤ 85 dB(A);
d. Low-noise equipment
new equipment is new or replaced
 speed-controlled pumps;
 avoidance of punched disks
Installation of noise-reducers on
e. Noise-reducers
Generally applicable
equipment and ducts
Vibration insulation of machinery
and decoupled arrangement of noise
f. Vibration insulation
Generally applicable
sources and potentially resonant
components
Enclosure of noisy equipment in
separate structures such as buildings
Enclose noisy
g.
or soundproofed cabinets where
Generally applicable
equipment
internal-external lining is made of
impact-absorbent material
This potentially includes:
 sound-absorbing materials in
walls and ceilings;
h. Soundproof buildings
Generally applicable
 sound-isolating doors;
 double-glazed windows
Noise propagation can be reduced by
Generally applicable to new plants.
inserting obstacles barriers between
In the case of existing plants, the
i. Noise abatement
the emitter and receiver. Appropriate
insertion of obstacles may be
obstacles barriers include protection
restricted by the lack of space
walls, embankments, and buildings
W
O
R
KI
N
G
D
R
AF
T
IN
PR
O
G
R
ES
S
Technique
TL/JFF/EIPPCB/Revised LCP_Draft 1
April 2015
31
Chapter 10
Technique
j.
Noise-control
equipment
Description
This includes:
i.
noise-reducers
ii.
vibration or acoustic
insulation, or vibration isolation
iii.
enclosure of noisy
equipment
iv.
soundproofing of buildings
Applicability
The applicability may be restricted
by lack of space
{This BAT conclusion is based on information given in Section 3.3.8}
Prevention of soil and groundwater contamination
R
ES
S
10.1.9
10.1.10
IN
PR
O
G
BAT 15. In order to prevent soil and groundwater contamination from the
unloading, storage and handling of solid fuels and additives, BAT is to implement
prevention measures including:
a. Storing fuels on sealed surfaces with drainage and drain collection and water treatment by
settling-out
b. Collecting and treating before discharge:
i. any leakages from the point of generation, collection, handling, storage, and
transport of waste;
ii. surface run-off (rainwater) from fuel storage areas that washes fuel particles away
(i.e. the settling-out portion is treated).
{This BAT conclusion is based on information given in Section 3.3.7}
Design and decommissioning
AF
T
BAT 16. In order to prevent pollution upon decommissioning, BAT is to use the
following techniques for new plants.
Design considerations for end-of-life plant decommissioning:
W
O
R
KI
N
G
D
R
a. considering the environmental impact from the eventual decommissioning of the installation
at the stage of designing a new plant, as forethought makes decommissioning easier, cleaner
and cheaper;
b. considering the environmental risks for the contamination of land (and groundwater) and
the generation of large quantities of solid waste; preventive techniques are process-specific
but general considerations may include:
i.
avoiding underground structures;
ii.
incorporating features that facilitate dismantling;
iii.
choosing surface finishes that are easily decontaminated;
iv.
using an equipment configuration that minimises trapped chemicals and
facilitates drain-down or cleaning;
v.
designing flexible, self-contained units that enable phased closure;
vi.
using biodegradable and recyclable materials where possible.
32
April 2015
TL/JFF/EIPPCB/Revised LCP_Draft 1
Chapter 10
10.2
10.2.1
BAT conclusions for the combustion of solid fuels
BAT conclusions for the combustion of coal and/or lignite
Unless otherwise stated, the BAT conclusions presented in this section are generally applicable
to the combustion of coal and/or lignite. They apply in addition to the general BAT conclusions
given in Section 10.1.
10.2.1.1
General environmental performance
Description
Applicability
G
Combustion processes such as
pulverised combustion, fluidised
bed boilerscombustion or moving
grate firing allow this integration
O
Generally applicable
PR
Technique
Integrated combustion process
assuring ensuring a high boiler
efficiency
and
including
primary measurestechniques to
a.
reduce the generation of NOX
emissions, such as air and fuel
staging, advanced low-NOX
burners and/or reburning, etc.
R
ES
S
BAT 17. In order to improve the general environmental performance of the combustion
of coal and/or lignite, and in addition to BAT 4, BAT is to use the technique given below.
10.2.1.2
Energy efficiency
IN
{This BAT conclusion is based on information given in Section 5.1.4.2}
D
R
Technique
AF
T
BAT 18. In order to increase the energy efficiency of coal and/or lignite combustion, BAT
is to use a combination of the techniques described in BAT 7 and of the technique given
below.
N
G
a. Lignite pre-drying
R
KI
b. Dry bottom ash handling
Description
Reduction of lignite moisture
content before combustion to
improve
combustion
conditions
Ash is conveyed to the silos
with systems using vacuum
and/or
pressure
thereby
allowing a significant amount
of energy to be recovered and
the boiler efficiency to be
increased by recirculating the
air used to cool the ash
Applicability
Applicable to new and existing
lignite-combustion plants
Generally applicable
W
O
{This BAT conclusion is based on information given in Section 5.1.4.3}
TL/JFF/EIPPCB/Revised LCP_Draft 1
April 2015
33
Chapter 10
BAT-associated environmental performance levels
The BAT-associated energy efficiency levels for coal and/or lignite combustion are given in
Table 10.2.
Table 10.2: BAT-associated environmental performance energy efficiency levels (BAT-AEELs)
for energy efficiency offor coal and/or lignite combustion
39 to above42
45–46 (2)
33.5–44 42 (2) (3)
42–44 (5)
33.5–42.5
36.5–to above 40 (2)
32.5–41.5 40 (2) (3)
36.5–40
31.5–39.5
-
-
75–97
75–97
75–97
75–97
PR
1
75–97
O
> ≥1000 MWth coal-fired
whose main purpose is
electricity production
> ≥ 1000 lignite-fired
< 1000 MWth coal-fired
whose main purpose is
electricity production
< 1000 lignite-fired
< 1000 MWth whose main
purpose is heat production
G
Combustion plant total
rated thermal input
(MWth)
R
ES
S
BAT-AEEPLs (yearly average – LHV basis) (7)
Net total fuel utilisation
Net electrical efficiency (%) (1) (8)
(%) (1) (6) (9)–- CHP
mode
New plant or and
New plants (2) (4)
Existing plants (2) (3)
existing plants
W
O
R
KI
N
G
D
R
AF
T
IN
( ) Within the given BAT-AEEL ranges, the achieved energy efficiency can be negatively affected (up to 4four
percentage points) by the type of cooling system used or the geographical location of the combustion plant and the
load variations.
(2) The lower end of the BAT-AEEL ranges is achieved in the case of unfavourable climatic local conditions, lowgrade lignite-fired plants, plants operated in peak or mid-merit modes and and/or older plants (first commissioned
before 1985).
(3) The achievable improvement of thermal efficiency depends on the specific plant, but an incremental improvement
of more than 3three percentage points is seen as associated with the use of BAT for existing plants, depending on the
original design of the plant and on the retrofits already performed.
(4) The higher end of the BAT-AEEL range can be achieved with high steam parameters (pressure, temperature).
(5) In the case of plants burning lignite with a lower heating value below 6 MJ/kg, the lower end of the BAT-AEEL
range is 41.5 %.
(6) These levels may not be achievable in the case of excessively low heat demand.
(7) These BAT-AEELs do not apply in the case of plants operated in peak- or emergency-load modes.
(8) Net electrical efficiency BAT-AEELs apply to CHP plants and to plants generating only power.
(9) Net total fuel utilisation BAT-AEELs apply to CHP plants and to plants generating only heat.
34
April 2015
TL/JFF/EIPPCB/Revised LCP_Draft 1
Chapter 10
10.2.1.3
NOX, N2O, NH3 and CO emissions to air
BAT 19. In order to prevent and/or reduce NOX emissions to air while limiting CO and
N2O and NH3 (if SNCR or SCR techniques are used) emissions to air from the combustion
of coal and/or lignite, BAT is to use one or a combination of the techniques given below.
Plants < 100 MWth
a. Complete combustion
Description
See description in Section 10.8.
CFB boilers allow achieving a good
combustion
performance
while
limiting NOX emissions to air,
sometimes without the need for an
additional technique
Applicability
Generally applicable
R
ES
S
Technique
See descriptions in Section 10.8 for
each single technique.
Primary techniques are used in
combination, alone for lignite-fired PC
boilers, sometimes in combination
with SNCR in fluidised bed boilers
and grate-firing, and possibly in
combination with SNCR or SCR in
coal-fired PC boilers.
c. SNCR
See description in Section 10.8.
Sometimes applied in addition to
primary measures at coal PC or gratefiring plants
Applicable to coal PC
plants
d. SCR
See description in Section 10.8.
Sometimes applied in addition to
primary measures at coal PC plants
Applicable to coal PC
plants
G
Combination of primary
techniques (air staging
including boosted
b. overfire air, fuel
staging, flue-gas
recirculation, LNB) for
NOX reduction
AF
T
IN
PR
O
Generally applicable
D
R
{This BAT conclusion is based on information given in Section 5.1.4.6}
Plants 100 MWth – 300 MWth
Technique
Complete combustion
N
G
c
KI
Combination of primary
techniques (air staging
including boosted overfire
air, fuel staging, flue-gas
recirculation, LNB) for
NOX reduction
W
O
R
d
e
SNCR
f
SCR
Description
See description in Section 10.8.
Generally used in combination with
other techniques included in this table
See description in Section 10.8 for
each single technique. Primary
techniques are used in combination,
alone for lignite-fired PC boilers,
sometimes in combination with SNCR
in fluidised bed boilers, and in
combination with SNCR or sometimes
SCR in coal-fired PC boilers.
See description in Section 10.8.
Applied alone or in combination with
primary measures in coal-fired PC
boilers, and sometimes in fluidisedbed boilers together with primary
measures
See description in Section 10.8.
Sometimes applied in addition to
primary measures in coal PC plants
TL/JFF/EIPPCB/Revised LCP_Draft 1
April 2015
Applicability
Generally applicable
Generally applicable
Generally applicable
Generally applicable
35
Chapter 10
Combined techniques for
NOX and SOX reduction
g
See description in Section 10.8. Not
very common, they can be applied
either alone or in combination with
other primary techniques in coal-fired
PC boilers
Applicable on a case-bycase basis, depending on
the fuel characteristics
and combustion process
{This BAT conclusion is based on information given in Section 5.1.4.6}
Plants > 300 MWth
R
ES
S
G
Generally applicable
Generally applicable
See description in Section 10.8.
SNCR is applied either alone or
in combination with other
primary techniques in fluidisedbed boilers Can be applied with
a 'slip' SCR system
W
O
R
KI
N
G
D
R
Selective non-catalytic
reduction (SNCR)
c.
AF
T
IN
Combination of other
primary techniques for
NOX reduction (e.g. air
b. staging including boosted
overfire air, fuel staging,
flue-gas
recirculation,
LNB) for NOX reduction
Applicability
O
Complete combustion
Combustion optimisation
a.
Description
See description in Section 10.8.
Generally used in combination
with other techniques included
in this table
See description in Section 10.8
for each single technique.
Primary techniques are used in
combination, alone for lignitefired PC boilers, sometimes in
combination with SNCR in
fluidised bed boilers, and
almost
always
with
an
additional SCR in coal-fired PC
boilers.The
choice
and
performance of appropriate
(combination
of)
primary
techniques may be influenced
by the boiler design
PR
Technique
d.
36
Selective catalytic
reduction (SCR)
See description in Section 10.8.
SCR is applied either alone or
in combination with other
primary techniques. in coalfired PC boilers
April 2015
Generally applicable The
applicability may be limited in
the
case
of
boilers
of ≥ 300 MWth with a high
cross-sectional area preventing
a homogeneous mixing of NH3
and NOX.
The applicability may be
limited in the case of
combustion plants operated in
emergencyor
peak-load
modes with highly variable
boiler loads
Generally applicable
Not applicable to combustion
plants of < 300 MWth operated
in emergency-load mode.
Not generally applicable to
combustion
plants
of
< 100 MWth.
There may be technical and
economic
restrictions
for
retrofitting existing plants
operated in peak-load mode
and
existing
plants
of
≥ 300 MWth
operated
in
emergency-load mode
TL/JFF/EIPPCB/Revised LCP_Draft 1
Chapter 10
e.
Combined techniques for
NOX and SOX reduction
See description in Section 10.8.
Not very common, They can be
applied either alone or in
combination with other primary
techniques in coal-fired PC
boilers
Applicable on a case-by-case
basis, depending on the fuel
characteristics and combustion
process
{This BAT conclusion is based on information given in Section 5.1.4.6}
R
ES
S
BAT-associated emission levels
The BAT-associated emission levels for NOX, NH3 and CO are given in Table 10.3.
Table 10.3: BAT-associated emission levels (BAT-AELs) for NOX, NH3 and CO emissions to air
from the combustion of coal and/or lignite
100–
200
100–
150
<100
100–300
100–270
100–180
50–180
65–85
100
65–150
180
Existing
plants
ND
155–240
ND
130–175
ND
165–330
ND
155–210
80–125
140–220
AF
80–125
New or
existing
plant
G
New
plants
T
50–85
150
D
R
> ≥ 300 FBC
boiler
combusting
coal and/or
lignite (coallignite) and
lignite-fired
PC boilerPC
lignite firing
> ≥300 coalfired PC
boilercoal
firing
Existing
plants (4)
80–220
200 (6)
Yearly
average
O
New
plants
Yearly
average
10–140 100
<5
10–140 100
<5
12 < 5–100
(7) 80
< 1–3.5
1 < 5–100 (7)
55
< 1–3.5
PR
Yearly average
BAT-AELs (mg/Nm3)
Daily average or
average over the
sampling period
IN
Combustion
plant total
rated
thermal
input
(MWth)
Monitoring
frequency
Continuous
measurement
KI
N
G
(1) Ammonia emissions are associated with the use of SCR and SNCR.
(4) These BAT-AELs do not apply when plants operate in peak- or emergency-load modes.
(6) In the case of plants operated in peak- or emergency-load modes, the higher end of the range is 220 mg/Nm3.
(7) The higher end of the BAT-AEL range can be as high as 140 mg/Nm3 in the case of limitations due to boiler
design, and/or in the case of fluidised bed boilers not fitted with secondary abatement techniques for NO X emissions
reduction.
NB: NA = not applicable; ND = not determined
R
The associated monitoring is in BAT 3 ter.
W
O
BAT 20. In order to prevent or reduce N2O emissions to air from the combustion of coal
and lignite in circulating fluidised-bed boilers, BAT is to apply BAT BAT 4 and the
technique given below.
Technique
Combustion temperature
a.
control
Description
Control of the combustion
temperature enables achieving
balanced emissions to air of N2O
and NOX
Applicability
Generally applicable
{This BAT conclusion is based on information given in Section 5.1.4.6}
BAT-associated emission levels
TL/JFF/EIPPCB/Revised LCP_Draft 1
April 2015
37
Chapter 10
The BAT-associated emission levels for N2O in circulating fluidised bed boilers NOX, NH3 and
CO are given in Table 10.4. Table 10.6.
Table 10.4: BAT-associated emission levels (BAT-AELs) for N2O emissions to air from the
combustion of coal and/or lignite in circulating fluidised bed boilers
BAT-AELs (mg/Nm3)
Pollutant
CFBC boiler
N2O
Average over the
sampling period of
samples obtained
during one year
20–150
Monitoring frequency
R
ES
S
Combustion plant
twice/yr
The associated monitoring is in BAT 3 ter.
SOX, HCl, and HF emissions to air
G
10.2.1.4
Technique
PR
O
BAT 21. In order to prevent and/or reduce SOX, HCl and HF emissions to air from the
combustion of coal and/or lignite, BAT is to use one or a combination of the techniques
given below.
Description
IN
Use of fuel with low Ssulphur
(e.g. down to 0.1 weight % - dry
basis), chlorine or fluorine
contentCl-,
F-coal/lignite
content.
Often
used
in
combination with other end-ofpipe techniques for combustion
plants of > 50 MWth
Applicability
Applicable within the constraints
associated with the availability of
different types of fuel, which may
be impacted by the energy policy
of the Member State. The
applicability may be limited due
to design constraints in the case
of plants combusting highly
specific indigenous fuels
AF
T
a. Fuel choice
D
R
See description in Section 10.8.
Applied in combination with a
downstream
dedusting
devicesystem
See description in Section 10.8.
Generally Mostly used in
combustion
plants
of
< 300 MWth, in combination
with a dedusting devicesystem
(ESP, Fabricbag filter). Can be
used for HCl/HF removal when
no specific FGD end-of-pipe
technique is implemented
Generally applicable
DSI (Duct Dry sorbent
injection) (DSI)
R
KI
c.
N
G
Boiler sorbent injection
b.
(in-furnace or in-bed)
O
Circulating fluidised bed
(CFB) dry scrubber
W
d.
e. Spray-dry absorber (SDA)
38
Generally applicable
See description in Section 10.8
Generally applicable
See description in Section 10.8.
Generally Mostly used in
combustion plants of < 1500
MWth for the combustion of
fuels with low and moderate
sulphur content
Generally applicable
April 2015
TL/JFF/EIPPCB/Revised LCP_Draft 1
Chapter 10
Not applicable to combustion
plants operated in emergencyload mode.
See description in Section 10.8
Applicable on a case-by-case
basis, depending on the fuel
characteristics and combustion
process
i. Wet scrubbing
Retrofit Replacement of the
gas-gas heater located
j.
downstream of the wet FGD
or SDA
Generally applicable
PR
O
Combined techniques for
h.
NOX and SOX reduction
Applicable to plants > 300 MWth
See description in Section 10.8.
Not very common, they can be
applied either alone or in
combination with other primary
techniques in coal-fired PC
boilers
See description in Section 10.8.
The techniques cCan be used for
HCl/HF removal when no
specific
FGD
end-of-pipe
technique is implemented
Replacement of the gas-gas
heater downstream of the wet
FGD by a multi-pipe heat
extractor, or removal and
discharge of the flue-gas via a
cooling tower or a wet stack
R
ES
S
g. Seawater FGD
There may be technical and
economic
restrictions
for
applying the technique to
combustion
plants
of
< 300 MWth, and for retrofitting
existing plants operated in peakload mode
See description in Section 10.8
G
Wet flue-gas desulphurisation
(Wet FGD)
IN
f.
Only applicable when the to
combustion plants is fitted with a
wet FGD system and a
downstream gas-gas heater or
SDA, when the heat exchanger
needs to be changed or replaced
AF
T
{This BAT conclusion is based on information given in Section 5.1.4.5}
D
R
BAT-associated emission levels
The BAT-associated emission levels for SO2 SOXare given in Table 10.5.
G
Table 10.5: BAT-associated emission levels (BAT-AELs) for SO2 SOX emissions to air from the
combustion of coal and/or lignite with S content < 3 %
KI
N
Combustion
plant total rated
thermal input
(MWth)
Daily
average
Yearly average
Daily
average or
average
over the
sampling
period
Existing
plants
ND 170–
400
ND 135–
250
New plants
Existing
plants (3)
New
plants
> 50–<100
150–200
150–360 400
ND NA
100–300
80–150
80–200
ND NA
10–75
10–130
25–110
25–205 220
(4)
20–150
20–180
25–185
50–220
R
O
W
BAT-AELs (mg/Nm3)
> ≥300
(Pulverised
combustion)PC
boiler
> ≥ 300
(Fluidised bed
boilers) (1)
TL/JFF/EIPPCB/Revised LCP_Draft 1
April 2015
Monitoring
frequency
Continuous
measurement (2)
39
Chapter 10
(1) For circulating fluidised bed boilers, the lower end of the range can be achieved by using a high efficiency wet
FGD system. The higher end of the range can be achieved by using boiler in-bed sorbent injection.
(2) SO2 is continuously measured, while SO3 is only periodically measured (e.g. during calibration of the SO 2
monitoring system).
(3) These BAT-AELs do not apply when plants operate in peak- or emergency-load modes.
(4) The higher end of the BAT-AEL range is 220 mg/Nm3 in the case of plants operated in peak- or emergency-load
modes.
NB: NA = No BAT-AEL
R
ES
S
For a plant with a total rated thermal input of more than 300 MWth, which is specifically
designed to fire indigenous fuels and which can demonstrate that it cannot achieve the BATAELs mentioned in Table 10.5 for techno-economic reasons, the upper end of the yearly BATAEL range may be as follows:
(i) existing PC boiler: [130 + (RCG – 4350) * 0.03] mg/Nm3 with a maximum of 400 mg/Nm3;
(ii) new PC boiler: [75 + (RCG – 5000) * 0.015] mg/Nm3 with a maximum of 270 mg/Nm3;
O
G
(iii) existing fluidised bed boiler: [180 + (RCG – 6000) * 0.03] mg/Nm3 with a maximum of
400 mg/Nm3;
PR
(iv) new fluidised bed boiler: [150 + (RCG – 10000) * 0.015] mg/Nm3 with a maximum of
270 mg/Nm3;
IN
in which RCG represents the concentration of SO2 in the raw flue-gas as a yearly average (under
the standard conditions given under General considerations) at the inlet of the SOX abatement
system, expressed at a reference oxygen content of 6 % O2.
AF
T
In these cases the daily BAT-AELs set out in Table 10.5 do not apply.
The associated monitoring is in BAT 3 ter.
D
R
The BAT-associated emission levels for HCl and HF are given in Table 10.6.
N
G
Table 10.6: BAT-associated emission levels (BAT-AELs) for HCl and HF emissions to air from the
combustion of coal and/or lignite
KI
Combustion
plant total
rated thermal
input
(MWth)
W
O
R
Pollutant
HCl
HF
≥ 100
< 100
≥ 100
< 100
BAT-AELs (mg/Nm3)
Average of samples obtained during
one year
BAT-AELs
BAT-AELs
(average of
(average of
samples
samples obtained
obtained during
during one year one year mg/Nm3)
3
mg/Nm )
Existing plant (1)
New plant
< 1–3 5
< 1–5 (2)
< 1–6 10
2–10
< 0.1–2
< 0.1–3 2 (3)
< 0.1–3
0.2–5
Monitoring
frequency
4 times/yr
(1) The lower end of these BAT-AEL ranges may be difficult to achieve in the case of plants fitted with a wet FGD
system and a downstream gas-gas heater.
(2) In the case of CFB boilers and in the case of plants operated in peak- or emergency-load mode, the higher end of
the range is 10 mg/Nm3.
(3) In the case of plants operated in peak- or emergency-load modes, the higher end of the BAT-AEL range is
6 mg/Nm3.
The associated monitoring is in BAT 3 ter.
40
April 2015
TL/JFF/EIPPCB/Revised LCP_Draft 1
Chapter 10
10.2.1.5
Dust and particulate-bound metal emissions to air
BAT 22. In order to reduce dust and particulate-bound metal emissions to air from the
combustion of coal and/or lignite, BAT is to use one or a combination of the techniques
given below.
Cyclones
b
Electrostatic precipitator (ESP)
c
Bag filter
d
Boiler sorbent injection (infurnace or in-bed)
Applicability
Generally applicable
Generally applicable
Generally applicable
Generally applicable when
the technique is mainly used
for SOX, HCl and/or HF
abatement
O
G
a
Description
See description in Section 10.8.
Only used as a pre-cleaning stage
in the flue-gas path, in
combination
with
other
technique(s) listed in this table
See description in Section 10.8
At least a two-fields ESP is used
for smaller plants
See description in Section 10.8
See description in Section 10.8
Generally used in fluidised bed
boilers sized 50–100 MWth in
combination with an ESP/bag
filter
R
ES
S
Technique
IN
PR
WFGDWet flue-gas
desulphurisation (FGD)
See description in Section 10.8.
Generally used in combustion
plants
of
≥ 300 MWth
in
combination with an ESP/bag
filter
AF
f
Dry or semi-dry FGD system
(e.g. SDA, DSI)
T
e
See descriptions in Section 10.8.
Generally used in fluidised bed
boilers sized 100–300 of up to
800 MWth in combination with
an ESP/bag filter
Generally applicable when
the technique is mainly used
for SOX, HCl and/or HF
abatement
Applicable
to
plants
> 100 MWth
Generally applicable when
the technique is mainly used
for SOX, HCl and/or HF
abatement
Applicable
to
plants
> 300 MWth
D
R
{This BAT conclusion is based on information given in Sections 5.1.4.4 and 9.4.4}
G
BAT-associated emission levels
The BAT-associated emission levels for dust emissions to air are given in Table 10.7.
N
Table 10.7: BAT-associated emission levels (BAT-AELs) for dust emissions to air from the
combustion of coal and/or lignite
KI
BAT-AELs (mg/Nm3)
W
O
R
Combustion
plant total
rated
thermal
input
(MWth)
> 50–<100
100–300
300–1000
≥ 1000
Yearly average (1)
Unit
3
mg/Nm
Daily average or average
over the sampling period
New plants
Existing
plants
New plants
Existing
plants
2–15
2–10
< 2–5
< 2–5 3
2–20
2–20
1 2–15
< 1 2–10
4–20 ND
3–20 ND
3–10 ND
4 3–10
4–28
4–25
4 3–20
4 3–16 20
Monitoring
frequency
Continuous
measurement
(1) These BAT-AELs do not apply when plants operate in peak- or emergency-load modes.
The associated monitoring is in BAT 3 ter.
TL/JFF/EIPPCB/Revised LCP_Draft 1
April 2015
41
Chapter 10
10.2.1.6
Mercury emissions to air
BAT 23. In order to reduce mercury emissions to air from the combustion of coal and/or
lignite, BAT is to use an appropriate combination of the techniques given below.
N
W
O
R
KI
d.
G
D
R
AF
T
IN
c.
PR
O
G
b.
R
ES
S
a.
Technique
Description
Applicability
Co-benefit from measures techniques primarily used taken for to reduce emissions of other
pollutants
See
description
in
Bag filter
Section 10.8. See BAT
Generally applicable
BAT 22
See description in
Section 10.8. See BAT
BAT 22.
Electrostatic precipitator
Better mercury removal
Generally applicable
(ESP)
efficiency is achieved at
flue-gas temperatures
below 130°C
Generally applicable to plants > 300
MWth
See
description
in Applicable to coal-fired PC boilers for
Section 10.8. See BAT plants < 300 MWth
BAT 19.
Not applicable to combustion plants of
Only
used
in < 300 MWth operated in emergency-load
combination with other mode.
Selective catalytic reduction
techniques to enhance or
(SCR)
reduce
the
mercury Not generally applicable to combustion
oxidation before capture plants of < 100 MWth.
in a subsequent FGD or
dedusting
unitsystem, There may be technical and economic
depending
on
the restrictions for retrofitting existing plants
selected strategy
operated in peak-load mode and existing
plants of ≥ 300 MWth operated in
emergency-load mode
Generally applicable when there is a
need to reduce SOX content in emissions
to air
Applicable when the technique is mainly
used for SOX, HCl and/or HF abatement.
Flue-gas desulphurisation
(FGD) technique (e.g. wet
See
descriptions
in Wet FGD is not applicable to
limestone scrubbersFGD,
Section 10.8. See BAT combustion
plants
operated
in
spray- dryer
BAT 221
emergency-load mode.
scrubbersabsorber or ductdry
sorbent injection)
There may be technical and economic
restrictions for applying wet FGD to
combustion plants of < 300 MWth, and
for retrofitting existing combustion
plants operated in peak-load mode
Specific measurestechniques to reduce for mercury reductionemissions
Applicable within the constraints
SelectUse coal and/or
associated with the availability of
lignite fuels with low
Fuel choice
different types of fuel, which may be
Hgmercury content < 25
impacted by the energy policy of the
µg/kg
Member State
See
description
in
Section 10.8.
Carbon sorbent
Generally
used
in
(e.g. activated carbon)
combination with an
Generally applicable
injection in the flue-gas
ESP/bag filter. The use
of this technique may
require
additional
e.
f.
42
April 2015
TL/JFF/EIPPCB/Revised LCP_Draft 1
Chapter 10
R
ES
S
G
Applicability is subject to a previous
survey for characterising the fuel and for
estimating the potential effectiveness of
the technique
PR
h. Fuel pretreatment
Generally aApplicable in the case of a
low halogen content in the fuel, within
the constraints associated with the
control of halogen emissions to air and
within the constraints associated with the
corrosion potential of equipment
O
Use of halogenated additives
g. toin the fuel or injected in the
furnace
treatment steps to further
segregate the mercurycontaining
carbon
fraction prior to further
reuse
Addition of halogens
(e.g.
brominated
additives)
into
the
furnace to oxidise the
flue-gaselemental
mercury into a soluble or
particulate
species,
thereby
enhancing
mercury removal in
downstream
control
devicesabatement
systems
Fuel washing, blending
and mixing in order to
limit/reduce
the
Hgmercury content or
improve mercury capture
by pollution control
equipment
{This BAT conclusion is based on information given in Section 5.1.4.4.}
IN
BAT-associated emission levels
The BAT-associated emission levels for mercury are given in Table 10.8 and
< 300
≥ 300
AF
BAT-AELs (µg/Nm3) (1)
New
Existing
plants
plants
D
R
Combustion plant total
rated thermal input
(MWth)
T
Table 10.8:
BAT-associated emission levels (BAT-AELs) for mercury emissions to air
from the combustion of coal (anthracite and bituminous)
0.5 < 1–5
< 1–9 10
0.2 < 1–2
0.2 < 1–4 6
Averaging
period
Average of
samples obtained
during one year
Yearly average
Monitoring frequency
Periodic measurement four
times/yr
Continuous measurement
G
(1) These BAT-AELs do not apply in the case of plants of < 300 MWth operated in peak- or emergency-load modes.
KI
N
Table 10.9: BAT-associated emission levels (BAT-AELs) for mercury emissions to air from the
combustion of sub-bituminous coal and lignite
R
Combustion plant total
rated thermal input
(MWth)
Averaging period
Monitoring frequency
Average of samples
Periodic measurement
obtained during one
times/yr
year
0.5 < 1–4 5
0.5 < 1–10
Yearly average
Continuous measurement
≥ 300
(1) These BAT-AELs do not apply in the case of plants operated in peak- or emergency-load modes.
O
W
BAT-AELs (µg/Nm3) (1)
Existing
New plants
plants
< 300
< 1–7 10
2–10 20
The associated monitoring is in BAT 3 ter.
10.2.2
BAT conclusions for the combustion of solid biomass
and/or peat
TL/JFF/EIPPCB/Revised LCP_Draft 1
April 2015
43
Chapter 10
Unless otherwise stated, the BAT conclusions presented in this section are generally applicable
to the combustion of solid biomass and/or peat, in addition to the general BAT conclusions
given in Section 10.1.
10.2.2.1
General environmental performance
BAT 24. In order to improve the general environmental performance of the combustion
of solid biomass and/or peat, BAT is to use a combination of the techniques given in BAT 4
and below.
a.
Fuel classification based on
size and quality
Description
The storage systems control and
hold the biomass fuel according
to quality and size
Applicability
Applicable
plants
to
{This BAT conclusion is based on information given in Section 5.2.3.2}
Energy efficiency
biomass-fired
G
10.2.2.2
R
ES
S
Technique
Technique
PR
O
BAT 25. In order to increase the energy efficiency of the combustion of solid biomass
and/or peat, BAT is to use an appropriate combination of the techniques given in BAT 7
and to reduce the moisture content of the fuel by either or both of the techniques given
below.
Description
IN
The fuel supplier or the internal
management
adheres
to
the
moisture (and size) specification in
the contract or internal document
AF
T
Fuel specification in the
a supplier contract or internal
document
Press, steam or flue-gas
drying
See description in Section 10.8
Generally applicable
D
R
b
Applicability
Applicable
within
the
constraints given by the safe
transportation of fuel (e.g.
minimum moisture content of
peat)
W
O
R
KI
N
G
{This BAT conclusion is based on information given in Section 5.2.3.3}
44
April 2015
TL/JFF/EIPPCB/Revised LCP_Draft 1
Chapter 10
BAT-associated environmental performance levels
The BAT-associated energy efficiency levels are given in Table 10.10.
Table 10.10: BAT-associated energy efficiency levels (BAT-AEELs) for the combustion of solid
biomass and/or peat
Parameter
Existing
New
BAT-AEPL
Yearly average (LHV basis)
80 – 102
Net
total
fuel
utilisation
95 – 102
%
Existing Net
electrical
New
efficiency
28 to above 34
31 to above 34
G
Generating only heat or
CHP
plants
whose
recoverable heat generation
does not exceed the heat
demand
Generating only power or
CHP
plants
whose
recoverable heat generation
exceeds the heat demand
Unit
R
ES
S
Type of combustion plant
O
BAT-AEEPLs (1)
(yearly average – LHV basis)
Net total fuel utilisation (%) (3) (4)
Net electrical efficiency (%) (2)
New plant
Existing plant
New plant
Existing plant
31 to above 34
28 to above 34
95–102
80–102
33.5– > 38
28– 38
73–99
73–99
PR
Type of plant
Solid biomass and/or peat
boiler
AF
T
IN
(1) These BAT-AEELs do not apply in the case of plants operated in peak- or emergency-load modes.
(2) Net electrical efficiency BAT-AEELs apply to CHP plants and to plants generating only power.
(3) Net total fuel utilisation BAT-AEELs apply to CHP plants and to plants generating only heat.
(4) These levels may not be achievable in the case of an excessively low potential heat demand.
10.2.2.3
NOX, N2O, NH3 and CO emissions to air
D
R
BAT 26. In order to prevent and/or reduce NOX emissions to air while limiting CO and
N2O and NH3 emissions to air from in the combustion of solid biomass and/or peat, BAT is
to use one or a combination of the techniques given below.
(Advanced) lLow-NOX
burners (LNB)
Air staging combustion
KI
b.
Combustion optimisation
N
a.
c.
Description
G
Technique
Generally applicable
See descriptions in
Section 10.8.
R
O
Flue-gas recirculation
W
f.
Selective catalytic reduction
(SCR)
Generally applicable
Generally applicable
d. Fuel staging (reburning)
e.
Applicability
See
description
in
Section 10.8. The use of
high-alkali fuels (e.g.
straw)
may
require
installing SCR after the
dust abatement system
Applicable to pulverised combustion and
FBC boiler plants Generally applicable
Not applicable in the high-dust
configuration when using high-alkali fuel
(e.g. straw)
Not applicable in the case of plants
operated in emergency-load mode.
There may be technical and economic
restrictions for retrofitting existing plants
operated in peak-load mode.
Not generally applicable to plants of
< 100 MWth
TL/JFF/EIPPCB/Revised LCP_Draft 1
April 2015
45
Chapter 10
Selective non-catalytic
reduction (SNCR)
g.
Generally applicable
Not applicable to combustion plants
operated in emergency-load mode with
highly variable loads.
See description in
Section 10.8
The applicability may be limited in the
case of combustion plants operated in
peak-load mode with highly variable
boiler loads
{This BAT conclusion is based on information given in Sections 5.2.3.4 and 9.4.4}
R
ES
S
BAT-associated emission levels
The BAT-associated emission levels for NOX, NH3 and CO are given in Table 10.11.
Table 10.11: BAT-associated emission levels (BAT-AELs) for NOX, NH3 and CO emissions to air
from the combustion of solid biomass and/or peat
BAT-AEL
Continuous
measurement
1
NH3 ( )
CO
All
Existing plant
Yearly
Daily
average
average
70–250
120–310
50–140
100–220
40–140
95–150
1–5
ND
4–80
ND
G
mg/Nm3
NOX
New plant
Yearly
Daily
average
average
70–200
120–260
50–130
100–220
40–130
65–150
1–5
ND
4–80
ND
O
50–100
100–300
> 300
Unit
Monitoring
frequency
PR
Combustion
plant rated
Pollutant
thermal input
(MWth)
IN
(1) Ammonia emissions are associated with the use of SCR and SNCR
BAT-AELs (mg/Nm3)
50–< 100
New
plants
Existing
plants (2)
70–200
70–250
Daily average or
average over the
sampling period
New
Existing
plants
plants
AF
Yearly average
CO (2)
NH3 (1)
Yearly
average
Yearly
average
T
NOX
D
R
Combustion
plant total
rated thermal
input
(MWth)
120–260
120–310
4 20–250
80
4 15–160
80
50–140
50–180
100–200
100–220
1–5
130
140
220
40–140
40–160
95–200
65–150
4 5–50 80
> ≥ 300
130
140
150
1
( ) Ammonia emissions are associated with the use of SCR and SNCR.
(2) These BAT-AELs do not apply when plants operate in peak- or emergency-load modes.
Continuous
measurement
KI
N
G
100–300
Monitoring
frequency
R
The associated monitoring is in BAT 3 ter.
W
O
BAT 27. In order to prevent or reduce N2O emissions to air from the combustion of solid
biomass and peat in circulating fluidised bed boilers, BAT is to apply BAT 4 and the
technique given below.
a.
Technique
Combustion temperature
control
Description
Control of the combustion
temperature enables achieving
balanced emissions to air of N2O and
NOX
Applicability
Generally applicable
{This BAT conclusion is based on information given in Section 5.2.3.4}
46
April 2015
TL/JFF/EIPPCB/Revised LCP_Draft 1
Chapter 10
10.2.2.4
SOX, and HCl and HF emissions to air
BAT 28. In order to prevent and/or reduce SOX, HCl and HF emissions to air infrom the
combustion of solid biomass and/or peat, BAT is to use one or a combination of the
techniques given below.
Description
By switching to a different biomass
fuel (e.g. lower sulphur, or lower
fluorine and/or chlorine fuel), the
corresponding emissions are reduced
a. Fuel choice
Spray-dry absorber
(SDA)
There may be technical and economic
restrictions for retrofitting existing
plants operated in peak-load mode
Not applicable if an alkali sorbent
substance is already contained in the
fuel
Generally applicable
Generally applicable
See descriptions in Section 10.8
Generally applicable
T
See descriptions in Section 10.8. The
technique is used in combination
combined with a dust abatement
technique
AF
f.
IN
Boiler sorbent
d. injection (in-furnace
or in-bed)
DSI (Duct Dry
e. sorbent injection)
(DSI)
O
See descriptions in Section 10.8
PR
Wet flue-gas
c. desulphurisation
(Wet FGD)
G
b. Flue-gas condenser
Applicability
The applicability is limited by the
Applicable within the constraints
associated with the availability of
different types of fuel, which may be
impacted by the energy policy of the
Member State
Applicable to plants serving a district
heating network
Generally applicable
Applicable to plants using higher
sulphur fuel
Not applicable to combustion plants
operated in emergency-load mode.
R
ES
S
Technique
D
R
{This BAT conclusion is based on information given in Section 5.2.3.5}
N
G
BAT-associated emission levels
The BAT-associated emission levels for SO2 SOX, HCl, and HF are given in Table 10.12.
The BAT-associated emission levels for HCl and HF are given in Table 10.12.-bis.
W
O
R
KI
Table 10.12: BAT-associated emission levels (BAT-AELs) for SO2X, HCl, and HF emissions to air
from the combustion of solid biomass and/or peat
Fuel
(% in LHV basis)
BAT-AEL
Pollutan
t
Biomass or biomass /
peat with peat % < 20
Peat or biomass / peat
with peat % ≥ 70
SOX
Unit
mg/N
m³
Monitorin
g
frequency
Continuous
measureme
nt (1)
20  peat % < 70
TL/JFF/EIPPCB/Revised LCP_Draft 1
April 2015
Average of
samples
obtained
during one
year
Yearly average
Daily
averag
e
-
1–50
8–70
-
100–165
ND
Intermediate,
within the
ranges given in
the two lines
above
ND
47
Chapter 10
HCl
25  straw % < 100
All
-
0.3–8
< 14
-
< 18
Intermediate,
within the
ranges given in
the two lines
above
ND
-
-
-
Periodic
measureme
nt
4 times/yr
HF
< 0.01–0.8
ND: Not Derived
(1) Only SO2 is continuously measured, SO3 is periodically measured (e.g. during calibration)
Existing plant
(2)
New plant
Daily average or average over the
sampling period
Yearly average
15–70
<10–50
<10–35
15–100
<10–70
<10–50
30–175
<20–85
<20–70
IN
< 100
100–300
≥ 300
Existing plant
O
New
plant
PR
Combustion plant total rated
thermal input
(MWth)
G
BAT-AELs for SO2 (mg/Nm3) (1)
ND
R
ES
S
Biomass or biomass /
peat (with peat % <
20), including straw
with straw % < 25
Straw  100%
30–215
<20–175
<20–85
AF
T
(1) For existing plants burning 100% peat, the higher end of the BAT-AEL range for yearly average is 100 mg/Nm3
and the higher end of the BAT-AEL range for daily average is 215 mg/Nm3.
(2) These BAT-AELs do not apply when plants operate in peak- or emergency-load modes.
D
R
Table 10.12-bis: BAT-associated emission levels (BAT-AELs) for HCl and HF emissions to air from
the combustion of solid biomass and/or peat
BAT-AELs for HCl (mg/Nm3) (1)
Existing plant
(2) (3)
G
New plant
New
plant
N
Combustion plant
total rated thermal
input
(MWth)
Daily average or
average over the
sampling period
R
KI
Yearly average or average
of samples obtained during
one year
Existing
plant
< 0.3–7
0.3–15
1–12
1–35
100–300
0.3–5
0.3–9
1–12
1–12
0.3–5
0.3–5
1–12
1–12
W
O
< 100
≥ 300
BAT-AELs for HF
(mg/Nm3)
Existing
New
plant
plant
(3) (4)
Average over the
sampling period
< 0.01–1
< 0.01–
0.8
< 0.01–
0.3
< 0.01–1.3
< 0.01–1
< 0.01–0.5
1
( ) For existing plants burning 100 % high Cl content biomass such as straw, the higher end of the BAT-AEL range
for yearly average is 20 mg/Nm3 and the higher end of the BAT-AEL range for daily average is 35 mg/Nm3.
(2) These BAT-AELs do not apply when plants operate in peak- or emergency-load modes.
(3) The lower end of these BAT-AEL ranges may be difficult to achieve in the case of plants fitted with a wet FGD
system and a downstream gas-gas heater.
(4) In the case of plants operated in peak- or emergency-load modes, the BAT-AEL range is 0.01–1.3 mg/Nm3.
The associated monitoring is in BAT 3 ter.
48
April 2015
TL/JFF/EIPPCB/Revised LCP_Draft 1
Chapter 10
10.2.2.5
Dust and particulate-bound metals emissions to air
BAT 29. In order to reduce dust and particulate-bound metals emissions to air in from
the combustion of solid biomass and/or peat, BAT is to use one or a combination of the
techniques given below.
Fuel choice
b. Bag filter
See description in Section 10.8
High-performance
Eelectrostatic
precipitator (ESP)
See description in Section 10.8
d.
Dry, semi-dry or wet
FGD system
See description in Section 10.8
Applicable within the constraints
associated with the availability of
different types of fuel, which may
be impacted by the energy policy of
the Member State
Applicable within the constraints
given
by
space
availability
Generally applicable
Applicable within the constraints
given by space availability.
Generally applicable
Generally applicable when the
technique is mainly used for SOX,
HCl and/or HF abatement
G
c.
Applicability
R
ES
S
a.
Description
By switching to a different fuel or
by modulating the fuel blending
(e.g. fuel with lower sulphur or
lower chlorine ash content fuel), the
corresponding
emissions
are
reduced
PR
O
Technique
{This BAT conclusion is based on information given in Section 5.2.3.6}
IN
BAT-associated emission levels
The BAT-associated emission levels for dust are given in Table 10.13.
Type of
plant
New
Existing
Pollutant
Unit
mg/Nm³
G
D
R
Dust
AF
T
Table 10.13: BAT-associated emission levels (BAT-AELs) for dust emissions to air from the
combustion of solid biomass and/or peat
O
R
KI
N
Combustion plant total rated
thermal input
(MWth)
< 100
100–300
≥ 300
Monitoring
frequency
Continuous
measurement
BAT-AEL
Daily average
Yearly average
2–12
< 1– 3
2–20
< 1–10
BAT-AELs for dust (mg/Nm3)
New
plant
Existing
plant (1)
Yearly average
2–5
2–5
2–5
2–15
2–12
2–10
New plant
Existing plant
Daily average or average over the
sampling period
2–20
2–16
2–10
2–24
2–18
2–18
W
(1) These BAT-AELs do not apply when plants operate in peak- or emergency-load modes.
The associated monitoring is in BAT 3 ter.
TL/JFF/EIPPCB/Revised LCP_Draft 1
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49
Chapter 10
10.2.2.6
Mercury emissions to air
BAT 30. In order to prevent or reduce mercury emissions to air in from the combustion
of solid biomass and/or peat, BAT is to use one or a combination of the techniques given
below.
Technique
Description
Applicability
a. Fuel choice
R
ES
S
Specific techniques to reduce mercury emissions
Applicable within the constraints
associated with the availability of
different types of fuel, which may be
See descriptions in
impacted by the energy policy of the
Section 10.8
Member State
Activated carbon duct
b. injection
Generally applicable
Co-benefit from techniques used to reduce emissions of other pollutants
G
Generally applicable for new plants.
Applicable within the constraints given
by space availability in existing plants
Only applicable when the technique is
mainly used for dust abatement
Only applicable when the technique is
used for dust abatement
Applicable when the technique is
mainly used for SOX, HCl and/or HF
abatement.
PR
O
c. Bag filter
Electrostatic precipitator
d. (ESP)
IN
See descriptions in
Section 10.8
Dry, semi-dry or wet FGD
Not applicable to combustion plants
operated in emergency-load mode.
AF
T
e. system
D
R
There may be technical and economic
restrictions for retrofitting existing
plants operated in peak-load mode
{This BAT conclusion is based on information given in Section 5.2.3.7}
N
G
BAT-associated emission levels
The BAT-associated emission levels for mercury are given in Table 10.14.
R
KI
Table 10.14: BAT-associated emission levels (BAT-AELs) for mercury emissions to air from the
combustion of solid biomass and/or peat
O
Pollutant
W
Mercury
Unit
BAT-AELs for Hg (1)
Average of samples obtained during one
year over the sampling period
Monitoring
frequency
µg/Nm3
< 1–5
Periodic
measurement 1
time/yr
(1) These BAT-AELs do not apply in the case of plants operated in peak- or emergency-load modes.
The associated monitoring is in BAT 3 ter.
50
April 2015
TL/JFF/EIPPCB/Revised LCP_Draft 1
Chapter 10
10.3
10.3.1
BAT conclusions for the combustion of liquid fuels
HFO- and/or LFO gas oil-fired boilers
Unless otherwise stated, the BAT conclusions presented in this section are generally applicable
to the combustion of HFO and/or LFO gas oil in boilers,. They apply in addition to the general
BAT conclusions given in Section 10.1.
Energy efficiency
R
ES
S
10.3.1.1
BAT 31. In order to increase the energy efficiency of the HFO and LFO combustion in
boilers, BAT is to use an appropriate combination of the techniques given in BAT 7 and
below:
a. Preheating of fuel by using waste heat
Regenerative feed-water heating by
b. using recovered heat
See descriptions in
Section 10.8
Applicable to new boilers > 300MWth
PR
c. Supercritical steam parameters
Applicability
Generally applicable to HFO-fired
boiler combustion plants
Generally applicable for new plants,
but plant-specific for existing plants
G
Description
O
Technique
Generally applicable
IN
See description in
Section 10.8.
Preheating of combustion air by using If the preheating
d. recovered heat
temperature is higher than
150 ºC, NOX emissions tend
to increase
AF
T
{This BAT conclusion is based on information given in Section 6.3.2.2}
D
R
BAT-associated environmental performance levels
The BAT-associated energy efficiency levels of the combustion offor HFO and/or LFO gas oil
combustion in boilers are given in Table 10.5
G
Table 10.15: BAT-associated energy efficiency levels (BAT-AEELs) in the combustion offor HFO
and/or LFO gas oil combustion in boilers
Type of combustion plant
Parameter
N
Generating only heat
New
or
CHP plants whose
Net total fuel
recoverable heat
utilisation
generation does not
Existing
exceed the heat
demand
Generating only power
New
or CHP plants whose
Net electrical
recoverable heat
efficiency
generation exceeds the Existing
heat demand
Unit
R
KI
> 90
80 to above 96
%
W
O
TL/JFF/EIPPCB/Revised LCP_Draft 1
BAT-AEPL
(yearly average, LHV basis)
April 2015
above 38
30 to above 38
51
Chapter 10
Type of plant
HFO- and/or gas oil-fired
boiler
BAT-AEEPLs (1)
(yearly average – LHV basis)
Net electrical efficiency (%) (2)
Net total fuel utilisation (%) (3) (4)
New plant
Existing plant
New plant
Existing plant
above 38
30 to above 38
> 90
80 to above 96
> 37.4
35.6–37.4
80–96
80–96
(1) These BAT-AEELs do not apply in the case of plants operated in peak- or emergency-load modes.
(2) Net electrical efficiency BAT-AEELs apply to CHP plants and to plants generating only power.
(3) Net total fuel utilisation BAT-AEELs apply CHP plants and to plants generating only heat.
(4) These levels may not be achievable in the case of an excessively low potential heat demand.
10.3.1.2
R
ES
S
The associated monitoring is in BAT 3 ter.
NOX, NH3 and CO emissions to air
Description
See description in Section 10.8
IN
a. Fuel choice
b.
Applicability
Applicable within the constraints
associated with the availability of
different types of fuel, which may be
impacted by the energy policy of the
Member State
Generally applicable
Applicable within the constraints of
water availability
PR
Technique
O
G
BAT 32. In order to prevent and/or reduce NOX emissions to air while limiting NH3 and
CO emissions to air from the combustion of HFO- and/or gas oil-fired in boilers, BAT is to
use one or a combination of the techniques given below.
Water/sSteam addition
injection
See description in Section 10.8
See description in Section 10.8
d. Fuel staging (reburning)
See description in Section 10.8
e. Flue-gas recirculation
See description in Section 10.8
Generally applicable
See description in Section 10.8
Generally applicable
Advanced computerised
process control system
N
KI
See description in Section 10.8
R
Selective catalytic reduction
h.
(SCR)
O
Selective non-catalytic
reduction (SNCR)
Generally applicable to new plants.
The applicability to old plants may be
constrained by the need to retrofit the
combustion and/or control command
system(s)
Not applicable to in the case of plants
operated in emergency-load mode.
There may be technical and economic
restrictions for retrofitting existing
plants operated in peak-load mode.
Not generally applicable to combustion
plants of < 100 MWth
Generally applicable
Not applicable to combustion plants
operated in emergency-load mode with
highly variable loads.
W
i.
Generally applicable
Generally applicable
AF
See description in Section 10.8
G
g.
Dry lLow-NOX burners
(LNB)
D
R
f.
T
c. Air staging
See description in Section 10.8
The applicability may be limited in the
case of combustion plants operated in
peak-load mode with highly variable
boiler loads
{This BAT conclusion is based on information given in Section 6.3.2.3}
52
April 2015
TL/JFF/EIPPCB/Revised LCP_Draft 1
Chapter 10
BAT-associated emission levels
The BAT-associated emission levels for NOX, NH3 and CO emissions to air from the
combustion of HFO and/or LFO gas oil in boilers that are not emergency plants are given in
Table 10.16.
Table 10.16: BAT-associated emission levels (BAT-AELs) for NOX NH3 and CO emissions to air
from the combustion of HFO and/or LFO gas oil in boilers
Pollutant
Existing
New
Existing
New
< 100 MWth
≥ 100 MWth
Unit
Monitoring
frequency
mg/Nm3
Continuous
measurement
NOX
BAT-AEL
Yearly average Daily average
75–270
ND
75–200
ND
45–110
85–145
45–75
85–100
< 1–5
ND
1–20
ND
R
ES
S
Type of combustion plant
NH3 (1)
CO
All
O
G
N.D. not determined
(1) Ammonia emissions are associated with the use of SCR or SNCR
PR
IN
T
AF
Combustio
n plant
total rated
thermal
input
(MWth)
BAT-AELs (mg/Nm3)
NOX
CO
Daily average
or average
Yearly average
Yearly average
over the
(2)
sampling
period
AllNew
AllExisting New Existin
New
or
daily
plants
plant
g
plants
existin averag
(2)
s
plants
g plant
e
75–
200
75 150–
270
≥ 100
MWth
45–75
45–110
ND
100–
215
85–
100
D
R
< 100
MWth
ND
210–
365
1–30
20
85–145
1–20
ND
BAT-AELs for
NH3 (1) (mg/Nm3)
Allyearly
averag
e
< 1 –5
Monitorin
g
frequency
Alldaily
average
ND
Continuou
s
measurem
ent
N
G
(1) Ammonia emissions are associated with the use of SCR and SNCR.
(2) These BAT-AELs do not apply when plants operate in peak- or emergency-load modes.
W
O
R
KI
The associated monitoring is in BAT 3 ter.
TL/JFF/EIPPCB/Revised LCP_Draft 1
April 2015
53
Chapter 10
10.3.1.3
SOX, HCl and HF emissions to air
BAT 33. In order to prevent and/or to reduce SOX, HCl and HF emissions to air from the
combustion of HFO- and/or LFOgas oil-fired boilers, BAT is to use one or a combination
of the techniques given below.
Description
Applicability
See description in Section 10.8
b. Flue-gas condenser
See description in Section 10.8
Wet flue-gas
c. desulphurisation (Wet
FGD)
See description in Section 10.8
O
G
a. Fuel choice
Applicable within the constraints
associated with the availability of
different types of fuel, which may
be impacted by the energy policy
of the Member State
Applicable to plants serving a
district heating network
Generally applicable
Applicable to plants > 100 MWth.
There may be technical and
economic restrictions for applying
the technique to combustion
plants of < 300 MWth.
R
ES
S
Technique
PR
Not applicable to combustion
plants operated in emergencyload mode.
IN
There may be technical and
economic
restrictions
for
retrofitting
existing
plants
operated in peak-load mode
Spray-dry absorber
(SDA)
T
AF
See description in Section 10.8
N
G
e.
D
R
Duct sorbent injection
d. (DSI) (Dry in-duct
sorbent injection)
See description in Section 10.8.
Commonly used in plants below
300 MWth, in combination with a
dedusting device (ESP, fabric filter)
The technique is combined with a dust
abatement technique
KI
R
Generally applicable to the
combustion of fuels with a low or
moderate sulphur content
Applicable
to
plants
of
≥ 100 MWth.
There may be technical and
economic restrictions for applying
the technique to combustion
plants of < 300 MWth.
See description in Section 10.8
Not applicable to combustion
plants operated in emergencyload mode.
W
O
f. Seawater FGD
Generally applicable
There may be technical and
economic
restrictions
for
retrofitting
existing
plants
operated in peak-load mode
{This BAT conclusion is based on information given in Section 6.3.2.4}
Note to TWG: please provide information on end-of-pipe technique other than WFGD applied
in plants
54
April 2015
TL/JFF/EIPPCB/Revised LCP_Draft 1
Chapter 10
BAT-associated emission levels
The BAT-associated emission levels for SO2 SOX from the combustion of HFO and/or LFOgas
oil in boilers are given in Table 10.17.
Table 10.17: BAT-associated emission levels (BAT-AELs) for SO2 SOX emissions to air from the
combustion of HFO and/or LFOgas oil in boilers
BAT-AEL
Pollutant
Unit
Monitoring
frequency
Yearly average
SOX
mg/Nm³
Continuous
measurement (1)
50–110 (2)
< 70
Daily
average
< 150–170
< 120
R
ES
S
Type of
combustion
plant
Existing
New
(1) Only SO2 is continuously measured, SO3 is periodically measured (e.g. during calibration).
(2) The low end of the range (e.g. < 50 mg/Nm3) is achieved by combustion plants using LFO.
BAT-AELs for SO2x (mg/Nm3)
< 70
50–175
< 70
35–50
50–110 (2)
50–175
50–110 (2)
50–110
< 300
≥ 300
New
plants
Monitoring
frequency
Existing
plants
O
Existing
plants (3)
< 120
150–200
< 120
50–120
IN
New plants
G
Daily average or average
over the sampling period
Yearly average
PR
Combustion
plant total rated
thermal input
(MWth)
< 150–170
150–200
< 150–170
150–175
Continuous
measurement (1)
(1) Only SO2 is continuously measured, SO3 is periodically measured (e.g. during calibration).
(2) The low end of the range (e.g. < 50 mg/Nm3) is achieved by combustion plants using LFO.
T
(3) These BAT-AELs do not apply when plants operate in peak- or emergency-load modes.
AF
The associated monitoring is in BAT 3 ter.
Dust and particulate-bound metals emissions to air
D
R
10.3.1.4
G
BAT 34. In order to reduce dust and particulate-bound metal emissions to air from the
combustion of HFO- and/or LFOgas oil-fired in boilers, BAT is to use one or a
combination of the techniques given below.
N
Technique
R
KI
a. Fuel choice
W
O
b.
Electrostatic precipitator
(ESP)
Description
See description in Section 10.8
See description in Section 10.8
Applicability
Applicable within the constraints
associated with the availability of
different types of fuel, which may be
impacted by the energy policy of the
Member State.
Generally applicable to new plants.
Applicable to existing plants within
the constraints given by space
availability
c. Bag filter
See description in Section 10.8
d. ESP + Wet FGD
See description in Section 10.8
e. Multicyclones
See description in Section 10.8
Generally applicable
See description in Section 10.8
Generally applicable when the
technique is mainly used for SOX,
HCl and/or HF abatement.
f.
Dry, semi-dry or wet FGD
system
{This BAT conclusion is based on information given in Section 6.3.2.5}
TL/JFF/EIPPCB/Revised LCP_Draft 1
April 2015
55
Chapter 10
BAT-associated emission levels
The BAT-associated emission levels for dust from the combustion of HFO and/or LFOgas oil in
boilers are given in Table 10.18.
Table 10.18: BAT-associated emission levels (BAT-AELs) for dust emissions to air from the
combustion of HFO and/or LFOgas oil in boilers
Type of combustion
Pollutant
plant
BAT-AEL
Yearly
Daily average
average
< 1–6
ND
Unit
Monitoring frequency
R
ES
S
New
Dust
mg/Nm3
Continuous measurement
Existing, all but
< 1–10 (1)
7–15
emergency plants
N.D. not determined
(1) The low–end of the range (e.g. < 1) is achieved by combustion plants using low-ash LFO
Daily average or average
over the sampling period
< 300
New plants
< 1–6
2–15
< 12–6
< 1–10 (1)
2–20
< 1 2– 10 (1)
ND 7–18
Existing
plants, all
but
emergency
plants
Monitoring
frequency
O
New plants
Existing
plants, all but
emergency
plants (2)
PR
Yearly average
Combustion
plant total rated
thermal input
(MWth)
G
BAT-AELs for dust (mg/Nm3)
7–2515
Continuous
measurement
IN
≥ 300
ND 7–10
7–15
N.D. not determined
(1) The low–end of the range (e.g. < 1) is achieved by combustion plants using low-ash LFO
AF
T
(2) These BAT-AELs do not apply when plants operate in peak- or emergency-load modes.
10.3.2
D
R
The associated monitoring is in BAT 3 ter.
HFO- and/or gas oil-fired engines
W
O
R
KI
N
G
Unless otherwise stated, the BAT conclusions presented in this section are generally applicable
to the combustion of HFO and/or gas oil in reciprocating engines, in addition to the general
BAT conclusions given in Section 10.1.
56
April 2015
TL/JFF/EIPPCB/Revised LCP_Draft 1
Chapter 10
10.3.2.1
Energy efficiency
BAT 35. In order to increase the energy efficiency of HFO and/or gas oil combustion in
reciprocating engines, BAT is to use an appropriate combination of the techniques given
in BAT 7 and below.
G
R
ES
S
Technique
Description
Applicability
Preheating of fuel using waste
a.
See description in Section 10.8 Generally applicable
heat
See description in Section 10.8.
Preheating of combustion air If preheating temperature is
b.
Generally applicable
higher than 150 ºC, NOX
using waste heat
emissions tend to increase
Generally applicable to new plants
except when operated in emergency- or
peak-load modes.
Applicable for existing base load plants
within the constraints given by the plant
configuration
See description in Section 10.8 Applicable to existing engines within
the constraints associated with the
steam cycle design and the space
availability.
IN
PR
O
c. Combined cycle
Not applicable to existing engines
operated in emergency- or peak-load
modes
AF
T
BAT-associated environmental performance levels
The BAT-associated energy efficiency levels offor the combustion of HFO and/or gas oil in
reciprocating engines are given in Table 10.19.
D
R
Table 10.19: BAT-associated energy efficiency levels (BAT-AEELs) infor the combustion of HFO
and/or gas oil in reciprocating engines
Type of combustion plant
New
R
O
W
Unit
BAT-AEPL
(Yearly average, LHV basis)
40 – 48
Existing
KI
N
G
Generating only
power or CHP plants
whose recoverable
heat generation
exceeds the heat
demand
Parameter
Type of combustion
plant
HFO- and/or gas oil-fired
reciprocating engine
Net electrical
efficiency
%
45 to above 48
BAT-AEEPLs (1)
(yearly average – LHV basis)
Net electrical efficiency (%) (2)
New plant
Existing plant
45 to above 48
40–48
> 48
39.4–48
(1) These BAT-AEELs do not apply in the case of plants operated in peak- or emergency-load modes.
(2) Net electrical efficiency BAT-AEELs apply to CHP plants and to plants generating only power.
{This BAT conclusion is based on information given in Section 6.3.3.1}
TL/JFF/EIPPCB/Revised LCP_Draft 1
April 2015
57
Chapter 10
10.3.2.2
NOX, NH3, CO and unburnt carbon volatile organic compounds'
emissions to air
BAT 36. In order to prevent and/or reduce NOX emissions to air from the combustion of
HFO and/or gas oil in reciprocating engines, BAT is to use one or a combination of the
techniques described in BAT 7 and given below.
Technique
Good maintenance of
a.
the engine
Low-NOX combustion
b. concept in diesel
engines
Applicability
Generally applicable
Generally
plants
aApplicable
to
new
R
ES
S
See description in Section 10.8
Not applicable during water
shortages
Applicable within the constraints of
water availability.
See description in Section 10.8
Humid air injection
(HAM)
See description in Section 10.8
G
Water/steam addition
injection
The retrofit to existing engines may
be constrained due to major
modifications to the fuel injection
system
d.
PR
O
c.
Description
Generally applicable
T
IN
Not applicable to in the case of
plants operated in emergency-load
mode plants.
Selective catalytic
e.
reduction (SCR)
AF
D
R
Exhaust-gas
recirculation (EGR)
Retrofitting existing plants may be
constrained by the availability of
sufficient space
See description in Section 10.8
Not applicable
engines
to
four-stroke
G
f.
See description in Section 10.8
There may be technical and
economic
restrictions
for
retrofitting existing plants operated
in peak-load mode.
N
{This BAT conclusion is based on information given in Section 6.3.3.2}
R
KI
BAT 37. In order to prevent and/or reduce emissions of CO and volatile organic
compounds unburnt carbon emissions to air from the combustion of HFO and/or gas oil in
reciprocating engines, BAT is to ensure complete combustion by using use one or a
combination of the techniques given in BAT 4 and below.
O
Technique
W
a. Good engine design
b.
Good maintenance of the
combustion system
Description
Applicability
See description in Section 10.8
Applicable to new plants
See description in Section 10.8
Generally applicable
c. Process control techniques
Process control techniques, based
on accurate monitoring and welloptimised system to reduce
emissions of CO and NOX
d. Oxidation catalysts
See description in Section 10.8
e. Combustion optimisation
See description in Section 10.8
Applicable to new plants
Not applicable to combustion
plants operated in emergencyload mode plants
Generally applicable
{This BAT conclusion is based on information given in Section 6.3.3.2}
58
April 2015
TL/JFF/EIPPCB/Revised LCP_Draft 1
Chapter 10
BAT-associated emission levels
The BAT-associated emission levels for NOX, NH3, CO and unburnt carbons (as TVOC)
emissions to air from the combustion of HFO and/or gas oil in reciprocating engines that are not
emergency plants are given in Table 10.20.
Table 10.20: BAT-associated emission levels (BAT-AELs) for NOX, NH3 and CO and TVOC
emissions to air from the combustion of HFO and/or gas oil in reciprocating engines
BAT-AEL
Existing
New
90–250
NOX
1
All but emergency plants
Yearly
average
NH3 ( )
CO
mg/Nm3
Continuous
measurement
Periodic
measurement
TOC
1
<5
50–100
-
PR
( ) Ammonia emissions are associated with the use of SCR.
< 140
ND
< 150
-
ND
ND
-
-
10–40
Daily
average
R
ES
S
Unit
G
All but
emergency
plants
Pollutant
Average of
samples
obtained
during one
year
-
O
Type of engine
Monitoring
frequency
BAT-AELs (mg/Nm3)
T
Daily average or
average over the
sampling period
AF
Yearly average
D
R
Combustion
plant total
rated
thermal
input
(MWth)
CO
Existing
New
plants
plants
2
()
120
115– 90 125– 145–
< 140 625 250
160
260
G
New
plants
N
All sizes but
emergency
plants
NH3 (1)
TVOC
Yearly
average
Average
of
samples
obtained
during
one year
over the
sampling
period
IN
NOX
Yearly
average
(2)
Existing
plants
(3)
120
150–750
310
Monitoring
frequency
New or existing plants
50–175
100
1–< 5
10–40
Continuous
measurement
R
KI
(1) Ammonia emissions are associated with the use of SCR.
(2) These BAT-AELs do not apply when plants operate in peak- or emergency-load modes.
(3) The BAT-AEL range for plants operating in emergency- or peak-load modes is 1150–1900 mg/Nm3.
W
O
The associated monitoring is in BAT 3 ter.
TL/JFF/EIPPCB/Revised LCP_Draft 1
April 2015
59
Chapter 10
10.3.2.3
SOX, HCl and HF emissions to air
BAT 38. In order to prevent and/or reduce SOX, HCl and HF emissions to air from the
combustion of HFO and/or gas oil in reciprocating engines, BAT is to use one or a
combination of the techniques given below.
a. Fuel choice
b. Process control
Duct sorbent
c. injection (DSI) with
bag filter
Description
See
description
in
Section 10.8.
Low-ash, low-asphaltene and
low-sulphur fuel
See description in
Section 10.8.
See
description
in
Section 10.8. The technique
is used in combination with a
dust abatement technique
Applicability
Applicable within the constraints associated
with the availability of different types of fuel,
which may be impacted by the energy policy
of the Member State
R
ES
S
Technique
Generally applicable.
Not applicable to emergency plants
Generally applicable
Wet flue-gas
d. desulphurisation
(Wet FGD)
G
Not applicable to combustion plants operated
in emergency-load mode.
See description in
Section 10.8.
PR
O
There may be technical and economic
restrictions for retrofitting existing plants
operated in peak-load mode
{This BAT conclusion is based on information given in Section 6.3.3.3}
IN
BAT-associated emission levels
The BAT-associated emission levels for SO2 SOX from the combustion of HFO and/or gas oil in
reciprocating engines are given in Table 10.21.
All but
emergency
plants
Pollutant
Existing
New
Monitoring
frequency
Unit
D
R
Type of engine
AF
T
Table 10.21: BAT-associated emission levels (BAT-AELs) for SO2 SOX emissions to air from the
combustion of HFO and/or gas oil in reciprocating engines
SOX
1
mg/Nm³
Continuous
measurement
(1)
BAT-AEL
Yearly average
Daily
average
100–200
ND
< 100
< 110
BAT-AELs for SO2x (mg/Nm3)
Daily average or average
over the sampling period
Yearly average
O
R
KI
Combustion
plant total rated
thermal input
(MWth)
N
G
( ) Only SO2 is continuously measured, SO3 is periodically measured (e.g. during calibration)
New plants
Existing
plants (2)
New plants
Monitoring
frequency
Existing
plants
W
All sizes but
ND
Continuous
emergency
< 45–100
100–200
< 60–110
105–235
measurement (1)
plants
(1) Only SO2 is continuously measured, SO3 is periodically measured (e.g. during calibration).
(2) These BAT-AELs do not apply when plants operate in peak- or emergency-load modes.
The associated monitoring is in BAT 3 ter.
60
April 2015
TL/JFF/EIPPCB/Revised LCP_Draft 1
Chapter 10
10.3.2.4
Dust and particulate-bound metals emissions to air
BAT 39. In order to prevent or reduce dust and particulate-bound metals emissions from
the combustion of HFO and/or gas oil in reciprocating engines, BAT is to use one or a
combination of the techniques given below.
b.
Process control
c.
Bag filter
d.
Electrostatic
precipitator (ESP)
See description in
Section 10.8
e.
Multicyclones
See description in
Section 10.8
f.
Dry, semi-dry or
wet FGD system
See descriptions in
Section 10.8
R
ES
S
Fuel choice
Generally applicable
Generally applicable. to new plants
Not applicable to combustion plants operated
in emergency-load mode plants. Applicable
to existing plants within the constraints given
by space availability
Generally applicable
O
a.
Applicability
Applicable within the constraints associated
with the availability of different types of
fuel, which may be impacted by the energy
policy of the Member State
G
Description
See description in
Section 10.8.
Low-ash, low-asphaltene and
low-sulphur fuel
See description in
Section 10.8
See description in
Section 10.8
Generally applicable when the technique is
mainly used for SOX, HCl and/or HF
abatement
PR
Technique
{This BAT conclusion is based on information given in Section 6.3.3.4}
T
IN
BAT-associated emission levels
The BAT-associated dust emission levels for dust from the combustion of HFO and/or gas oil in
reciprocating engines are given in Table 10.22.
AF
Table 10.22: BAT-associated emission levels (BAT-AELs) for dust emissions to air from the
combustion of HFO and/or gas oil in reciprocating engines
Pollutant
Unit
New
Existing, all but
emergency mode
Dust
mg/Nm3
BAT-AEL
Yearly
Daily average
average
1–5
6–12
1–10
ND
Monitoring frequency
Continuous measurement
KI
N
G
D
R
Type of engine
O
W
All sizes but
emergency
plants
Daily average or average
over the sampling period
Yearly average
R
Combustion
plant total rated
thermal input
(MWth)
BAT-AELs for dust (mg/Nm3)
New plants
Existing
plants, all but
emergency
plants (1)
New
plants
Existing
plants, all
but
emergency
plants
1–5
2–7
1–10
2–20
6–12 15
ND 6–40
Monitoring
frequency
Continuous
measurement
(1) These BAT-AELs do not apply when plants operate in peak- or emergency-load modes.
The associated monitoring is in BAT 3 ter.
TL/JFF/EIPPCB/Revised LCP_Draft 1
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61
Chapter 10
10.3.3
LFOGas oil-fired gas turbines
Unless stated otherwise, the BAT conclusions presented in this section are generally applicable
to the combustion of LFOgas oil in gas turbines,. They apply in addition to the general BAT
conclusions given in Section 10.1.
10.3.3.1
Energy efficiency
R
ES
S
BAT 40. In order to increase the energy efficiency of the LFOgas oil combustion in gas
turbines, BAT is to use an appropriate combination of the techniques given in BAT 7 and
below.
Description
Applicability
See description in Section 10.8 Generally applicable to new gas turbines
Generally Aapplicable to new gas
turbines except when operated in
emergency- or peak-load modes.
b. Combined cycle (CCGT)
See description in Section 10.8
G
Technique
a. Double reheat
PR
O
Applicable to existing gas turbines within
the constraints associated with the steam
cycle design and the space availability.
Not applicable to gas turbines operated in
emergency- or peak-load modes
IN
{This BAT conclusion is based on information given in Section 6.3.4.1}
AF
T
BAT-associated environmental performance levels
The BAT-associated energy efficiency levels offor the combustion of LFOgas oil in gas turbines
that are not emergency plants are given in Table 10.23.
D
R
Table 10.23: BAT-associated energy efficiency levels (BAT-AEELs) offor existing baseload and
mid-merit LFOgas oil-fired gas turbines
KI
O
Type of combustion plant
Gas oil-fired open-cycle gas
turbine
Gas oil-fired combined
cycle gas turbine
W
Net electrical efficiency
N
Existing
New
Existing
New
R
Open
cycle
Combined
cycle
Parameter
G
Type of gas turbine
Unit
%
BAT-associated environmental
performance levels
25 to above 31
above 31
33 to above 44
above 40
BAT-AEEPLs (1)
(yearly average – LHV basis)
Net electrical efficiency (%) (2)
New plant
Existing plant
above 31
25 to above 31
> 35.7
25–35.7
above 40
33 to above –44
>44
33–44
(1) These BAT-AEELs do not apply in the case of plants operated in peak- or emergency-load modes.
(2) Net electrical efficiency BAT-AEELs apply to CHP plants and to plants generating only power.
62
April 2015
TL/JFF/EIPPCB/Revised LCP_Draft 1
Chapter 10
10.3.3.2
NOX, NH3 and CO emissions to air
BAT 41.
In order to prevent and/or reduce NOX emissions to air from the
combustion of LFO gas oil in gas turbines, BAT is to use one or a combination of the
techniques given below.
Description
Water/or steam
a. addition
See description in
Section 10.8
Advanced lLow-NOX
b. burners (LNB) for
liquid fuels
See description in
Section 10.8
Applicability
Not applicable during water shortages in dry
areas
The applicability may be limited due to
water availability
Only Aapplicable to turbine models for
which the low-NOX burners are available on
the market
R
ES
S
Technique
Not applicable to in the case of plants
operated in emergency-load mode. plants
G
See description in
Section 10.8
O
Selective catalytic
reduction (SCR)
PR
c.
Applicable within the constraints given by
space availability.
Retrofitting existing plants may be
constrained by the availability of sufficient
space.
There may be technical and economic
restrictions for retrofitting existing plants
operated in peak-load mode
IN
{This BAT conclusion is based on information given in Section 6.3.4.2}
D
R
Technique
AF
T
BAT 42. In order to prevent and/or reduce carbon monoxide (CO) emissions to air from
the combustion of LFO gas oil in gas turbines, BAT is to achieve complete combustion by
applying use one or a combination of the techniques given in BAT 4 and below.
See description in
Section 10.8
KI
b. Combustion optimisation
Applicability
Not applicable to combustion plants
operated in emergency-load mode plants.
Applicable within the constraints given
by space availability
Retrofitting existing plants may
constrained by the availability
sufficient space
N
G
a. Oxidation catalysts
Description
See description in
Section 10.8
be
of
Generally applicable
W
O
R
{This BAT conclusion is based on information given in Section 6.3.4.2}
BAT-associated emission levels
The BAT-associated emission levels for NOX, NH3 and CO emissions to air from the
combustion of LFO in gas turbines that are not emergency plants are given in
TL/JFF/EIPPCB/Revised LCP_Draft 1
April 2015
63
Chapter 10
Table 10.24: BAT-associated emission levels for NOX, NH3 and CO emissions to air from
LFO-fired gas turbines
Type of gas turbine
All but
emergency
mode
Pollutant
Unit
Monitoring frequency
mg/Nm³
Continuous
measurement
New
NOX
Existing
1
NH3 ( )
CO
All
BAT-AEL
Yearly
Daily
average
average
20–40
ND
< 90
30–250
< 1–5
6–60
ND
ND
10.3.3.3
R
ES
S
(1) Ammonia emissions are associated with the use of SCR technique.
SOX and dust emissions to air
Description
Applicability
Applicable within the constraints associated with the
availability of different types of fuel, which may be
impacted by the energy policy of the Member State
O
Technique
G
BAT 43. In order to prevent and/or reduce SOX and dust emissions to air from the
combustion of LFO gas oil in gas turbines, BAT is to use the techniques given belowin
BAT 4.
PR
See description in
Section 10.8
a. Fuel choice
{This BAT conclusion is based on information given in Sections 6.3.4.3 and 6.3.4.4}
T
IN
BAT-associated emissions levels
The BAT-associated emission levels for SO2SOX and dust from the combustion of LFO gas oil
in gas turbines that are not emergency plants are given in Table 10.25.
All but
emergency
mode
Existing
New
Pollutan
t
dust
SOX
Dust
SOX
Unit
D
R
Type of gas turbine
AF
Table 10.25: BAT-associated emission levels for SO2SOX and dust emissions to air from the
combustion of LFOgas oil in gas turbines
mg/Nm³
Monitoring frequency
Continuous measurement
Continuous measurement (1)
Continuous measurement
Continuous measurement (1)
BAT-AEL
Yearly average
1–4
1–35
1–2
1–20
N
G
(1) Only SO2 is continuously measured, SO3 is periodically measured (e.g. during calibration). Continuous monitoring
fuel sulphur content and correlating it with SOX emissions is an alternative monitoring method possible if only
primary techniques are implemented.
BAT-AELs (mg/Nm3)
R
KI
SO2x
Daily average
or average
Yearly
over the
2
average ( )
sampling
period
W
O
Combustion
plant total rated
thermal input
(MWth)
All sizes but
emergency
plants
Dust
Daily average
or average
Yearly
over the
2
average ( )
sampling
period
New plants or
existing plants
New plants or existing plants
1–20 / 1–35
35–60
50–66
Monitoring
frequency
1–2 / 1–4
2–5
2–10
Continuous
measurement (1)
(1) Only SO2 is continuously measured, SO3 is periodically measured (e.g. during calibration). Continuous monitoring
fuel sulphur content and correlating it with SOX emissions is an alternative monitoring method possible if only
primary techniques are implemented.
(2) These BAT-AELs do not apply when plants operate in peak- or emergency-load modes.
64
April 2015
TL/JFF/EIPPCB/Revised LCP_Draft 1
Chapter 10
10.4
BAT conclusions for the combustion of gaseous fuels
10.4.1
BAT conclusions for the combustion of natural gas
Unless otherwise stated, the BAT conclusions presented in this section are generally applicable
to the combustion of natural gas,. They apply in addition to the general BAT conclusions given
in Section 10.1.
Energy efficiency
R
ES
S
10.4.1.1
BAT 44. In order to increase the energy efficiency of natural gas combustion, BAT is to
use one or a combination of the techniques described in BAT 7 and of the techniques given
below.
Regenerative feedwater
heating
See description in Section 10.8.
The regenerative stream can be generated by
the boiler or the steam turbine
See description in Section 10.8
Energy efficiency optimisation refers to the
efficiency of the total combined cycle and not
only to the gas turbine
G
D
R
c. Combined cycle
(CCGT)
AF
T
IN
PR
b.
See description in Section 10.8
Applicability
Applicable to new gas
turbines, including CCGTs
O
a. CHP readiness
Description
G
Technique
Generally applicable
Generally aApplicable to
new gas turbines and
engines except when
operated in emergency- or
peak-load modes.
Applicable to existing gas
turbines and engines within
the constraints associated
with the steam cycle design
and the space availability.
Not applicable to existing
gas turbines and engines
operated in emergency- or
peak-load modes.
R
KI
N
Not applicable to boilers
and to existing baseload
open-cycle gas turbines
operated in mid-merit load
or baseload modes ,
provided there is enough
available space
W
O
{[This BAT conclusion is based on information given in Section 7.1.4.2}
BAT 45. In order to use energy efficiently, BAT is to use expansion turbines to recover the
energy content of the pressurised supplied fuel gasesnatural gas.
Description
An expansion turbine (or turbo expander) is an apparatus that can be installed on the natural gas
supply line (instead of a throttling expansion valve) to generate power from the expansion of the
high-pressure natural gas to the supply pressure of the gas turbine. The throttling valve is kept
as back-up, in case the expansion turbine is not available.
Applicability
The applicability of the technique may be limited by the amount of recoverable energy.
TL/JFF/EIPPCB/Revised LCP_Draft 1
April 2015
65
Chapter 10
BAT-associated environmental performance levels
The BAT-associated energy efficiency levels for the combustion of natural gas are given in
Table 10.26.
Table 10.26: BAT-associated environmental performance energy efficiency levels (BAT-AEELs)
for the energy efficiency of the combustion of natural gas fired combustion plants
BAT-AEELs for energy efficiency (yearly average) (3)
Net electrical efficiency
(%) (1)
New
Existing
plants
plants
Net total
fuel
utilisation
(%) (2) (4)
Net mechanical energy
efficiency (%) (5)
Existing
New plant
plant
R
ES
S
Type of combustion plant
Gas engine
56–85
NA
-
56–78
-
40–42.5
to above 42
38–40
78–95
-
-
IN
NA
O
G
35–44
NA
PR
NA
78–95
-
T
CHP gas engines (2)
Gas-fired boiler
Gas-fired boiler only
producing electricity and
CHP gas-fired boilers
whose recoverable heat
generation exceeds the heat
demand
Gas–fired boiler only
producing heat and CHP
gas-fired boilers whose
recoverable heat generation
does not exceed the heat
demand
Open-cycle gas turbine
42–46.5
to above
46.5
-
36–41.5
to above 41
Combined cycle gas turbine (CCGT)
CCGT ≥ 50 MWth for
57–60.5
electricity generation only
48.5 to
(3)
above 58
CHP CCGT plant (50–600
57–60.5
MWth) whose recoverable
42 to above
heat generation exceeds the
46
heat demand
CHP CCGT plants (50–600
MWth) whose recoverable
heat generation does not
2
exceed the heat demand ( )
CHP CCGT plant (> ≥ 600
MWth) whose recoverable
57–60.5
heat generation exceeds the
50–51
heat demand
CHP CCGT plants (>
MWth) whose recoverable
heat generation does not
2
exceed the heat demand ( )
33–41.5
28–39
NA
36.5–41
33.5–41
47–60
45 –58
NA
NA
NA
47–60
40–46
67–95
60–95
NA
NA
-
60–95
-
47–60
44–51
80–95
NA
-
80–92
-
W
O
R
KI
N
G
D
R
Gas turbine ≥ 50 MWth
AF
Gas engine (1)
66
April 2015
NA
TL/JFF/EIPPCB/Revised LCP_Draft 1
Chapter 10
(1) Electrical efficiency applies for plants producing power only and for plants whose recoverable heat generation
exceeds the heat demand. Net electrical efficiency BAT-AEELs apply to CHP plants and to plants generating only
power.
(2) The energy efficiencies in CHP plants are very much dependent upon the specific situation and the local demand
of electricity and heat. Net total fuel utilisation BAT-AEELs may not be achievable in the case of an excessively low
heat demand.
(3) These BAT-AEELs do not apply to plants operated in peak- or emergency-load modes. Not applicable for plants
(< 500 h/yr).
(4) These BAT-AEELs apply to CHP combustion plants and to combustion plants generating only heat.
(5) These BAT-AEELs apply to combustion plants used for mechanical drive applications.
10.4.1.2
NOX, CO, NMVOC and CH4 emissions to air
R
ES
S
NB: NA = no BAT-AEL
BAT 46. In order to prevent and/or reduce NOX emissions to air from the combustion of
natural gas in boilers, BAT is to use one or a combination of the techniques given below.
G
See description in Section 10.8
AF
T
IN
b. Flue-gas recirculation
(Ultra-) Low-NOX burners
c.
(LNB)
((U)LNB)
D
R
d. Selective catalytic reduction
(SCR)
See description in Section 10.8
G
N
KI
R
f.
Advanced computerised
process control system
Generally applicable
Generally applicable
Retrofit may be limited for older
plants due to boiler design
constraints Generally applicable
Not applicable for in the case of
combustion plants operated in
emergency-load mode plants.
See description in Section 10.8
See description in Section 10.8.
This technique is often used in
combination with other techniques or
may be used alone for very welltuned plants operated in emergencyload mode plants
TL/JFF/EIPPCB/Revised LCP_Draft 1
Not generally applicable to
combustion plants of < 100 MWth.
Retrofitting existing plants may be
constrained by the availability of
significant space.
For
peak-load
plants,
the
economic viability may depend on
the energy market conditions
O
W
e. Selective Nnon-Ccatalytic
Rreduction (SNCR)
Applicability
O
a. Air and/or fuel staging
Description
See descriptions in Section 10.8.
Air staging (over fire air) is often
associated with low-NOX burners
See description in Section 10.8
PR
Technique
April 2015
There may be technical and
economic
restrictions
for
retrofitting
existing
plants
operated in peak-load mode
Not applicable to emergencyplants
Not applicable to combustion
plants operated in emergency-load
mode with highly variable loads.
The applicability may be limited
in the case of combustion plants
operated in peak-load mode with
highly variable boiler loads
Generally applicable to new
plants. The applicability to old
combustion plants may be
constrained by the need to retrofit
the combustion and/or control
command system(s)
67
Chapter 10
Reduction of the combustion
air temperature
g.
Generally applicable within the
constraints associated with the
process needs
See description in Section 10.8
{This BAT conclusion is based on information given in Section 7.1.4.3}
BAT 47. In order to prevent and/or reduce NOX emissions to air from the combustion of
natural gas in gas turbines while limiting NH3 slip in the case of SCR use, BAT is to use
one or a combination of the techniques given below.
a. Dry low-NOX burners (DLN)
See description in Section 10.8
b. Selective catalytic reduction
(SCR)
See description in Section 10.8
Applicability
The aApplicability may be limited in
the case of very old turbines
(retrofitting package not available) or
when steam/water injection systems
are installed
Not applicable in the case of
combustion plants operated in to
emergency-load mode plants.
Retrofitting existing plants may be
constrained by the availability of
significant sufficient space.
For peak-load plants, the economic
viability may depend on the energy
market conditions
There may be technical and
economic restrictions for retrofitting
existing plants operated in peak-load
mode
R
ES
S
Description
IN
PR
O
G
Technique
T
AF
Generally applicable
The applicability may be limited due
to water availability
Generally applicable to new plants.
The applicability to old combustion
plants may be constrained by the
need to retrofit the combustion
and/or control command system(s)
N
G
d. Advanced computerised
process control system
D
R
c. Water/steam addition
Water or steam injection
See description in Section 10.8.
This technique is uUsed in existing
gas turbines and when a DLN retrofit
DLN package is not available
See description in Section 10.8.
This technique is often used in
combination with other techniques or
may be used alone for very welltuned emergency plants operated in
emergency-load mode
Adaptation of the process control and
related equipment to maintain for
keeping good combustion efficiency
when the demand in energy is
varying varies, e.g. by improving the
inlet airflow control capability or by
splitting the combustion process in
decoupled combustion stages
W
O
R
KI
e. Low-load design concept
f.
Low-NOX burners (LNB)
See description in Section 10.8
Applicable depending on the gas
turbines design
Generally
applicable
to
supplementary firing for heat
recovery steam generators (HRSG)
in the case of combined cycle gas
turbine (CCGT) combustion plants
(CCGTs)
{This BAT conclusion is based on information given in Section 7.1.4.3}
68
April 2015
TL/JFF/EIPPCB/Revised LCP_Draft 1
Chapter 10
BAT 48. In order to prevent and/or reduce NOX emissions to air from the combustion of
natural gas in engines, BAT is to use one or a combination of the techniques given below.
Description
See description in Section 10.8.
Generally used in combination with
SCR
a. Lean-burn concept
See description in Section 10.8
c. Selective catalytic reduction
(SCR)
See description in Section 10.8
Only aApplicable to new gas-fired
engines
Applicable to new gas-fired engines
but not to spark ignited engines
Only applicable to new spark plug
or other ignited (SG)-type engines
Retrofitting existing plants may be
constrained by the availability of
significant sufficient space.
Not applicable in the case of
combustion plants operated in to
emergency-load mode plants.
For peak-load plants, the economic
viability may depend on the energy
market conditions
There may be technical and
economic restrictions for retrofitting
existing plants operated in peakload mode
PR
O
G
b. Advanced lean-burn concept
Applicability
R
ES
S
Technique
See description in Section 10.8.
This technique is often used in
combination with other techniques or
may be used alone for very welltuned emergency combustion plants
operated in emergency-load mode
T
IN
d. Advanced computerised
process control system
Generally applicable to new plants.
The applicability to old combustion
plants may be constrained by the
need to retrofit the combustion
and/or control command system(s)
AF
{This BAT conclusion is based on information given in Section 7.1.4.3}
D
R
BAT 49. In order to prevent and/or reduce CO emissions to air from the combustion of
natural gas, BAT is to use one or both a combination of the techniques given below.
Technique
Description
Applicability
Good furnace/combustion
chamber design
Use of high performance
monitoring
Maintenance of the
combustion system
Applicable to new plants
N
1.
G
a. Complete Combustion optimisation See description in Section 10.8
Generally applicable
KI
2.
W
O
R
3.
Generally applicable
b. Well optimised system to reduce
emissions of NOX
c. Advanced automated process
control
d
Application of Oxidation catalysts
Generally applicable
See description in Section 10.8
Generally applicable
See description in Section 10.8
Generally applicable
.
{This BAT conclusion is based on information given in Section 7.1.4.3}
TL/JFF/EIPPCB/Revised LCP_Draft 1
April 2015
69
Chapter 10
The BAT-associated emission levels for NOX and CO emissions to air from the combustion of
natural gas are given in Table 10.27 (for gas turbines) and in Table 10.28 (for boilers and
engines).
Table 10.27: BAT-associated emission levels (BAT-AELs) for NOX and CO emissions to air from
the combustion of natural gas in gas turbines
7–50 (13)
6–35 (13)
3 < 5–40
(13)
≥ 50
7–55 75 (5)
6–50
3 < 5–40
( 6) ( 9)
7–85
6–60
3–40
NA
5–80
Continuous
measurement
Continuous
measurement or
PEMS
G
≥ 50
Monitoring
frequency
PR
O
New OCGT gas turbines
( 1)
Existing OCGT gas
turbines (excluding
turbines for mechanical
drive applications) – All
but emergency-load
mode
Existing gas turbines for
mechanical drive – All
but emergency mode
Existing gas turbines –
Emergency mode
( 2)
IN
Type of gas turbine
R
ES
S
BAT-AELs (mg/Nm3) (3)
NOX
CO
Daily
average or
Yearly
Yearly
average over
average
average
the sampling
(7) (14)
(7) (14)
period
Open-cycle gas turbines (OCGTs)
Combustion
plant total
rated
thermal
input
(MWth)
44–125
Continuous
measurement or
PEMS
Continuous
measurement,
or PEMS
Combined cycle gas turbines (CCGTs) (11) (15)
1–5
15–55
10–50
1–50
18–35
15–40 (12)
10–30 (12)
25
1–15
< 5–30 (12)
Continuous
measurement
Continuous
measurement
Continuous
measurement
18–50
10–40 35
1 < 5–30
(9)
Continuous
measurement
18–65
10–50
< 5–30 (9)
15–35
10–25
1–15
Continuous
measurement
50–600
35– 55
10–45
1–15
< 5–30 (9)
Continuous
measurement
50–600
35–80 85
25–55 (10)
75
1 < 5–30
(9)
Continuous
measurement
T
9–20
D
R
≥ 50
AF
15–25
≥ 600
N
G
New dual fuel CCGT –
Natural gas mode
Existing dual fuel CCGT
– Natural gas mode
New single fuel CCGT
> 600 MWth
Existing single fuel
CCGT
> 600 MWth with a net
total fuel
utilisation < 75 %
Existing CCGT
with a net total fuel
utilisation ≥ 75 %
New single fuel CCGT
50–600 MWth
Existing single fuel
CCGT 50–600 MWth
with a net total fuel
utilisation of < 75 %
Existing single fuel
CCGT 50–600 MWth
with a net total fuel
utilisation of ≥ 75 %
W
O
R
KI
≥ 600
Open- and combined cycle gas turbines
Existing gas turbines –
Emergency-load mode
( 2)
Existing gas turbines for
mechanical drive
applications – All but
emergency-load mode
70
≥ 50
NA
60–140
NA 44–125
NA 5–80
Continuous
measurement or
PEMS
≥ 50
7–65 85
6–60
3 < 5–40
(9)
Continuous
measurement or
PEMS
April 2015
TL/JFF/EIPPCB/Revised LCP_Draft 1
Chapter 10
Existing/New dual fuel
gas turbine combusting
liquid fuels in
emergency-load mode
≥ 50
145–250
NA
NA
PR
O
G
R
ES
S
(1) The higher end of the ranges is achieved when the plants operate on peak mode.
(2) The lower end of the BAT-AEL NOX range for NOX can be achieved with water injection or dry low-NOX premix
burners.
(3) These BAT-AELs also apply to the combustion of natural gas in dual-fuel-fired turbines.
(5) The higher end of the range is 80 mg/Nm3 in the case of plants operated in peak-load mode.
(6) The higher end of the range is 80 mg/Nm3 in the case of existing plants that cannot be fitted with dry techniques
for NOX reduction.
(7) These BAT-AELs do not apply in the case of plants operated in peak-load mode.
(9) The higher end of the range is 50 mg/Nm3 when plants operate at low load (e.g. with an equivalent full load factor
below 60 %).
(10) Where it can be demonstrated that it is not possible to further retrofit a plant operated in peak-load mode due to
techno-economic reasons, the higher end of the range is 75 mg/Nm3.
(11) These BAT-AELs do not apply to turbines for mechanical drive applications or to plants operated in emergencyload mode.
(12) A correction factor may be applied to the higher end of the BAT-AEL range, corresponding to [higher end] x EE /
55 where EE is the net electrical energy efficiency of the plant determined at ISO baseload conditions.
(13) A correction factor may be applied to the higher end of the range, corresponding to [higher end] x EE / 39 where
EE is the net electrical energy efficiency of the plant determined at ISO baseload conditions.
(14) Optimising the functioning of an existing technique to reduce further NOX emissions may lead to levels of CO
emissions at the higher end of the BAT-AEL range for CO.
(15) When the boiler of a CCGT operates alone (i.e. the gas turbine does not operate), the BAT-AELs that apply are
those related to boilers (see Table 10.28).
NB: NA = No BAT-AEL
IN
The associated monitoring is in BAT 3 ter.
T
Table 10.28: BAT-associated emission levels (BAT-AELs) for NOX and CO emissions to air from
the combustion of natural gas in boilers and engines
AF
D
R
Type of combustion plant
BAT-AELs (mg/Nm3)
NOX
CO
Daily average or
Yearly average
Yearly
average over the
(3) (4)
average (3) (4)
sampling period
Boilers
1–5
NA < 85
10–60
< 5–15
1–15
85–110
50–100
< 5–40
Gas eEngines (1)
G
New boilers
N
Existing boiler
NA
20–75
30–100
Existing gas engines
NA 55–110 (2)
20–100
30–100
R
KI
New gas engine
Monitoring
frequency
Continuous
measurement
Continuous
measurement
Continuous
measurement
Continuous
measurement
1
W
O
( ) These BAT-AELs only apply to SG- and DF-type engines. They do not apply to GD-type engines.
(2) In the case of engines operated in emergency-load mode that could not apply the lean-burn concept or use an SCR
system for techno-economic reasons, the higher end of the range is 175 mg/Nm3.
(3) These BAT-AELs do not apply when plants operate in peak- or emergency-load modes.
(4) Optimising the functioning of an existing technique to reduce further NOX emissions may lead to levels of CO
emissions at the higher end of the BAT-AELs for CO.
NB: NA = No BAT-AEL
The associated monitoring is in BAT 3 ter.
The BAT-associated emission level for NH3 slip when using SRC is less < 3
as yearly average based on continuous measurement*.
TL/JFF/EIPPCB/Revised LCP_Draft 1
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Chapter 10
BAT 50. In order to reduce non-methane volatile organic compounds (NMVOC) and
methane (CH4) emissions to air from the combustion of natural gas in spark-ignited leanburn gas (SG) and dual fuel (DF) engines, BAT is to ensure complete an optimised and
stable combustion conditions and/or to apply oxidation catalysts.
The BAT-associated emission levels for formaldehyde NMVOC and CH4 are presented given in
Table 10.29.
BAT-AELs (mg/Nm3)
Aaverage over the sampling period of
samples obtained during one year 4–40
2–15
200–400
185–500 (1)
Pollutant
NMVOC
Formaldehyde
CH4
R
ES
S
Table 10.29: BAT-associated emission levels (BAT-AELs) for NMVOC formaldehyde and CH4
emissions to air from the combustion of natural gas in an SG or DF engines
Monitoring frequency
Periodic measurements:
4 times/yr
Periodic measurements:
4 times/yr
1
O
G
( ) This BAT-AEL applies only to an SG-type engine and is expressed as C at maximum continuous
rating (MCR)
PR
The associated monitoring is in BAT 3 ter.
{This BAT conclusion is based on information given in Section 7.1.4.3}
BAT conclusions for the combustion of iron and steel
process gases
IN
10.4.2
D
R
AF
T
Unless otherwise stated, the BAT conclusions presented in this section are generally applicable
to the combustion plants combusting of iron and steel process gases (e.g. blast furnace, coke
oven, basic oxygen furnace gases), alone individually, in combination, or simultaneously, or in
combination with other gaseous and/or liquid and/or solid commercial fuels,. They apply in
addition to the general BAT conclusions given in Section 10.1.
10.4.2.1
Energy efficiency
KI
N
G
BAT 51. In order to increase the energy efficiency for of the combustion of iron and steel
process gases in boilers and CCGTs, only or in combination with other gaseous, liquid
and/or solid fuels, BAT is to use one or a combination of the techniques listed in BAT 7
and of the technique given below.
R
Technique
See description Section 10.8
O
a. Process gases
management system
Description
Applicability
Only aApplicable to
integrated Iron and Steel
steelworks
W
{This BAT conclusion is based on information given in Sections 7.3.4.1 and 5.1.4.3}
BAT-associated environmental performance levels
The BAT-associated energy efficiency levels for the combustion of iron and steel process gases
only or in combination with other gaseous and/or liquid fuels are presented are given in Table
10.30.
The BAT-associated energy efficiency levels for the combustion, in CCGTs, of iron and steel
process gases and natural gas are presented are given in Table 10.31.
The BAT-associated energy efficiency levels for the combustion of iron and steel process gases
in combination with coal and possibly other gaseous and/or liquid fuels are the ones given in
72
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Chapter 10
Table 10.30: BAT-associated environmental performance levels for energy efficiency levels (BATAEELs) offor the combustion of iron and steel process gases in a boilers alone or in
combination with other gaseous and/or liquid fuels
BAT-AEELs (% - yearly average) (2)
Combustion pPlant type
Net total fuel utilisation
(4)
(CHP plants)
32.5–40
25–40
50–84
Existing multi-fuel firing gas–
boilers producing power only
and multi-fuel firing gas–
boilers whose recoverable
heat generation exceed the
heat demand
New multi-fuel firing gas–
boilers producing heat only
and multi-fuel firing gas–
boilers whose recoverable
heat generation does not
exceed the heat demand (1)
R
ES
S
Net electrical efficiency (3)
50–84
G
40–42.5
PR
O
(1) The wide range of energy efficiencies in CHP plants is very much largely dependent on the specific situation and
the local demand of for electricity and heat.
(2) These BAT-AEELs do not apply in the case of plants operated in peak- or emergency-load modes.
(3) These BAT-AEELs apply to CHP plants and to plants generating only power.
(4) These BAT-AEELs apply to CHP plants and to plants generating only heat.
Parameter
Unit
AF
Combustion pPlant type
T
IN
Table 10.31: BAT-associated environmental performance levels for energy efficiency levels (BATAEELs) of for the combustion of iron and steel process gases and natural gas in a
CCGTs
D
R
CHP CCGTs whose recoverable
heat generation does not exceed
the heat demand
Existing
plant
New
plant
60–82
%
Net electrical
efficiency
43–48
38.5–45
> 47
above 44
W
O
R
KI
N
G
CCGT Ggenerating
only power or CHP
CCGTs whose
recoverable heat
generation exceeds the
heat demand
Net total fuel
utilisation
BAT-AEELs
(yearly average, LHV basis)
TL/JFF/EIPPCB/Revised LCP_Draft 1
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Chapter 10
10.4.2.2
NOX and CO emissions to air
BAT 52. In order to prevent and/or reduce NOX emissions to air from the combustion of
iron and steel process gases in boilers only or in combination with other gaseous fuels
and/or liquid fuels, BAT is to use one or a combination of the techniques given below.
Applicability
Specially designed low-NOX
burners in multiple rows per type of
fuel or including specific features
for multi-fuel firing (e.g. multiple
dedicated nozzles for burning
different fuels, or including fuels
premixing)
See description in Section 10.8
See description in Section 10.8
See description in Section 10.8
Specially designed LowNOX burners (LNB)
Generally applicable
Generally applicable
Generally applicable
Not applicable to combustion
plants operated in emergency-load
mode.
Not generally applicable to plants
of < 100 MWth.
Retrofitting existing plants may be
constrained by significant the
availability of sufficient space
availability and by the combustion
plant configuration.
There may be technical and
economic
restrictions
for
retrofitting existing plants operated
in peak-load mode.
Generally applicable
Not applicable to combustion
plants operated in emergency-load
mode.
e. Selective catalytic reduction
(SCR)
See description in Section 10.8
The applicability may be limited in
the case of combustion plants
operated in peak-load mode with
frequent fuel changes and frequent
load variations
Generally applicable to new plants.
See description in Section 10.8.
The applicability to old combustion
This technique is used in
plants may be constrained by the
combination with other techniques need to retrofit the combustion
and/or control command system(s)
KI
N
G
f. Selective non-catalytic
reduction (SNCR)
D
R
AF
T
IN
See description in Section 10.8
PR
O
b. Air staging
c. Fuel staging
d. Flue-gas recirculation
Generally applicable
R
ES
S
a.
Description
See description Section 10.8.
G
Technique
O
R
g. Advanced computerised
process control system
W
{This BAT conclusion is based on information given in Section 7.3.4.2}
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BAT 53. In order to prevent and/or reduce NOX emissions to air from the combustion of
iron and steel process gases and natural gas in CCGTs, BAT is to use one or a
combination of the techniques given below.
Technique
Description
See description in Section 10.8.
Applicability
Applicable within the constraints
associated with the reactiveness of
iron and steel process gases such as
coke oven gas.
G
D
R
AF
T
IN
PR
O
G
R
ES
S
a. Dry low-NOX burners (DLN) DLN that combust iron and steel
The applicability may be limited in
process gases differ from the ones
the case of a very old turbine
that combust natural gas only
(retrofitting package not available)
or when steam/water injection
systems are installed
Generally Only applicable to
supplementary firing for heat
b. Low-NOX burners (LNB)
See description in Section 10.8.
recovery steam generators (HRSG)
of combined cycle gas turbine
(CCGT) combustion plants
Not applicable to combustion plants
operated in emergency-load mode.
Retrofitting existing plants may be
constrained by the availability of
c. Selective catalytic reduction
See description in Section 10.8
significant sufficient space.
(SCR)
There may be technical and
economic restrictions for retrofitting
existing plants operated in peakload mode
See description in Section 10.8.
In dual fuel gas turbines using DLN
Generally applicable
Water/steam addition
for iron and steel process gases
d.
Water or steam injection
combustion, water/steam addition is The applicability may be limited
generally used when combusting due to water availability
natural gas
Generally applicable to new plants.
See description in Section 10.8.
The applicability to old combustion
e. Advanced computerised
This technique is used in
plants may be constrained by the
process control system
combination with other techniques
need to retrofit the combustion
and/or control command system(s)
W
O
R
KI
N
{This BAT conclusion is based on information given in Section 7.3.4.2}
TL/JFF/EIPPCB/Revised LCP_Draft 1
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75
Chapter 10
BAT 54. In order to prevent and/or reduce CO emissions to air from the combustion of
iron and steel process gases, only or in combination with other gaseous fuels and/or liquid
fuels, BAT is to applyuse one or a combination of the following techniques given below.
Technique
Description
See description in Section
10.8
a. Complete Combustion optimisation
b. Good furnace/combustion chamber design
Generally applicable
Applicable to new plants
Generally applicable
Generally applicable
1. Use of high performance monitoring
2.Maintenance of the combustion system
Generally applicable
R
ES
S
See description in Section
10.8
c. Advanced computerised process control
Applicability
d. Well optimised system to reduce emissions of NOX
Generally applicable
Only applicable to
CCGTs.
O
{This BAT conclusion is based on information given in Section 7.3.4.2}
G
See description in Section The applicability may be
10.8
limited by lack of space,
the load requirements
and the sulphur content
of the fuel
e. Oxidation catalysts
PR
The BAT-associated emission levels for NOX and CO concentrations associated with BAT from
the combustion of iron and steel process gases are given in Table 10.32.
IN
Table 10.32: BAT-associated emission levels (BAT-AELs) for NOX and CO emissions to air from
the combustion of iron and steel process gases, only or in combination with other
gaseous fuels and/or liquid fuels in boilers, or, with natural gas in CCGTs
Existing boiler
3
New CCGT
15
T
3
CO
Yearly average
(4)
Yearly average
(4)
AF
New boilers
Daily average or
average over
the sampling
period
22–100 (5)(9)
15–65
< 5–35
1–25
22–160 (5) (6)
20–100
1 < 5–100
30–50
20–35
D
R
O2
reference
level (%)
G
Combustion
pPlant type
BAT-AELs (mg/Nm3) (1)
NOX
Monitoring
frequency
Continuous
measurement
Continuous
measurement
< 5–20
Continuous
measurement
(1) Emissions from pPlants combusting a mixture of gases with an equivalent LHV of > 20 MJ/Nm3 are expected to
emit at the higher end of the BAT-AEL ranges.
(4) These BAT-AELs do not apply to plants operated in peak- or emergency-load modes.
(5) The higher end of the BAT-AEL range may be different on days when auxiliary liquid fuels are used. In this case,
the higher end of the BAT-AEL range may correspond to the higher end of the BAT-AEL range reported in the BAT
conclusions that apply to the combustion of the corresponding (auxiliary) fuel and to the case of plants operated in
peak- or emergency-load modes.
(6) The higher end of the BAT-AEL range may be exceeded a few days every year in the case of plants not fitted with
SCR when using a high share of COG and/or combusting COG with a relatively high level of H2. In this case the
higher end of the BAT-AEL range is 220 mg/Nm3.
(7) The lower end of the BAT-AEL range can be achieved when using SCR.
(8) In the case of plants operated in emergency- or peak-load modes, the higher end of the BAT-AEL range is
80 mg/Nm3.
15
30–70 ( ) 120
7
20–50 100 ( )
1 < 5–20
W
O
R
KI
N
Existing CCGTs
8
The associated monitoring is in BAT 3 ter.
BAT 55. In order to prevent and reduce NOX emissions to air from the combustion of iron
and steel process gases (alone or with other gaseous and/or liquid fuels) in combination
with coal, BAT is to use one or a combination of the techniques described in BAT 19 and
of the following technique, depending on the fuels combusted:
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Chapter 10
Technique
Description
Specially
designed
low-NOX
burners in multiple rows per type of
fuel or including specific features
Specially designed low-NOX
a.
for multi-fuel firing (e.g. multiple
burners
dedicated nozzles for burning
different fuels, or including fuels
premixing)
Applicability
Generally applicable with specific
features depending on the type of
multi-fired fuels and on their range
of variability
{This BAT conclusion is based on information given in Sections 7.3.4.2 and 5.1.4.6}
R
ES
S
The CO, NOX and NH3 emission levels associated with BAT are given in
Table 10.33.
Table 10.33: BAT-associated emission levels for NOX, NH3 and CO emissions to air from the
combustion of iron and steel process gases (alone or with other gaseous and/or liquid
fuels) in combination with coal
50–150
50–180
65–100
65–180
ND
10–100
<5
10–100
<5
140–220
80–125
80–220
G
BAT-AEL
for NH3 (1)
(yearly
average mg/Nm3)
O
PR
ND
IN
> 300 FBC
(coal-lignite)
and PC firing
> 300 PC
coal firing
BAT-AEL
for CO
(yearly
average mg/Nm3)
T
100–300
BAT-AEL for NOX
(daily average mg/Nm3)
New
Existing
plants
plants
12–80
< 1–3.5
1–55
< 1–3.5
Continuous
measurement
AF
< 100
BAT-AEL for NOX
(yearly average mg/Nm3)
New
Existing
plants
plants
100–
100–270
200
100–
100–180
150
W
O
R
KI
N
G
D
R
(1) Ammonia emissions are associated with the use of SCR and SNCR.
TL/JFF/EIPPCB/Revised LCP_Draft 1
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Chapter 10
10.4.2.3
SOX emissions to air
BAT 56. In order to prevent and/or reduce SOX emissions to air from the combustion of
iron and steel process gases in boilers, only or in combination with other gaseous fuels
and/or liquid fuels, BAT is to use a combination of the techniques given below.
Process gas management system
and auxiliary fuel choice
R
ES
S
Generally
applicable, within
the
constraints
associated with
the availability of
different types of
fuel
IN
PR
b.
Coke oven gas pretreatment at
the iron- and steel-worksfacility
Applicability
Generally
aApplicable
to
integrated plants
G
a.
Description
Use of one of the following techniques:
 desulphurisation by absorption systems;
 wet oxidative desulphurisation
See description in Section 10.8.
Use, as much as the iron- and steel-works
allow it, of:
 a majority of blast furnace gas with low
sulphur content in the fuel diet;
 a combination of fuels with averaged
low sulphur content, e.g. individual
process fuels with very low S content
such as:
o BFG with Ssulphur content
< 10 mg/Nm3;
o coke oven gas with Ssulphur
content < 300 mg/Nm3;
and auxiliary fuels such as:
o natural gas;
o liquid fuels with Ssulphur content
of ≤ 0.4 % (in boilers).
Use of a limited amount of fuels with
containing higher Ssulphur content
O
Technique
AF
T
{This BAT conclusion is based on information given in Section 7.3.4.3}
D
R
BAT-associated emission levels
The BAT-associated emission levels (BAT-AELs) for SO2X emissions to air concentrations
associated with BAT from the combustion of iron and steel process gases, only or in
combination with other gaseous fuels and/or liquid fuels in boilers, or with natural gas in
CCGTs, are given in Table 10.34.
KI
N
G
Table 10.34: BAT-associated emission levels (BAT-AELs) for SO2 SOX emissions from the
combustion of iron and steel process gases, only or in combination with other gaseous
fuels and/or liquid fuels in boilers, or with natural gas in CCGTs
Type of
combustion
plant
O2 reference
level (%)
Boiler
SOX
3
CCGT
SOX
15
W
O
R
Pollutant
Monitoring
frequency
Continuous
measurement (1)
Continuous
measurement (1)
BAT-AELs for SO2 (mg/Nm3)
Daily average
or average
Yearly average
over the
(4)
sampling
period
50–200 (2)(3)
25–150
20–70 60
10–45 35
1
( ) Only SO2 is continuously measured, SO3 is periodically measured (e.g. during calibration).
(2) Higher levels can be expected when HFO/LFO or other non-conventional liquid fuels with high sulphur content
are combusted.
(3) The higher end of the BAT-AEL range may be different on days when auxiliary liquid fuels are used. In this case,
the higher end of the BAT-AEL range may correspond to the higher end of the BAT-AEL range reported in the BAT
conclusions that apply to the combustion of the corresponding (auxiliary) fuel and to the case of plants operated in
peak- or emergency-load modes.
(4) These BAT-AELs do not apply when plants operate in peak-load or emergency-load modes.
The associated monitoring is in BAT 3 ter.
78
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Chapter 10
BAT 57. In order to reduce SOX emissions to air from the combustion of iron and steel
process gases (alone or with other gaseous and/or liquid fuels) in combination with coal,
BAT is to use one or a combination of the techniques described in BAT BAT 21.
{This BAT conclusion is based on information given in Sections 7.3.4.3 and 5.1.4.5}
The BAT-associated emission levels for SOX from the combustion of iron and steel process
gases in combination with coal and possibly other gaseous and/or liquid fuels are given in
Table 10.35.
150–200
80–150
10–75
10–130
20–150
20–180
1
25–110
Monitoring
frequency
ND
G
50–100
100–300
> 300 (Pulverised
combustion)
> 300 (Fluidised
bed boilers) (1)
Existing
plants
(daily
average)
O
New plants
(yearly
average)
BAT-AEL (mg/Nm3)
New
Existing
plants
plants (yearly
(daily
average)
average)
150–400
ND
80–200
25–220
Continuous
measurement (2)
PR
Combustion
plant rated
thermal input
(MWth)
R
ES
S
Table 10.35: BAT-associated emission levels for SOX emissions to air from the combustion of iron
and steel process gases (alone or with other gaseous and/or liquid fuels) in
combination with coal with S content < 3 %
ND
IN
( ) The lower end of the range is achieved by high efficient wet FGD system. The higher end can be achieved by a
boiler / in-bed sorbent injection.
(2) Only SO2 is continuously measured, SO3 is periodically measured (e.g. during calibration).
10.4.2.4
Dust emissions to air
Fuel choice / management
W
O
R
KI
N
G
a.
D
R
Technique
AF
T
BAT 58. In order to reduce dust emissions to air from the combustion of iron and steel
process gases, only or in combination with other gaseous, liquid, and/or solid fuels, BAT is
to use one or a combination of the techniques given below.
b.
Blast furnace gas pretreatment at
the iron- and steel-works plant
c.
Basic oxygen furnace gas
pretreatment at the iron- and steelworks plant
TL/JFF/EIPPCB/Revised LCP_Draft 1
Description
Use of a combination of
process
gases
and
auxiliary fuels with low
averaged low dust or ash
content, as much as the
iron- and steel-works
allow it
Use of one or a
combination
of
dry
dedusting
devices
primary (e.g. deflectors,
dust catchers, cyclones,
electrostatic precipitators)
and/or subsequent dust
abatement
secondary
dedusting
techniques
(cyclones,
venturi
scrubbers,
hurdle-type
scrubbers,
venturi
scrubbers, annular gap
scrubbers,
wet
electrostatic precipitators,
disintegrators)
Use of dry (e.g. ESP or
bag filter) or wet (e.g.
wet ESP or scrubber)
April 2015
Applicability
Generally applicable, within the
constraints associated with the
availability of different types of
fuel
Generally Only applicable if blast
furnace gas is combusted
Generally Only applicable if
basic oxygen furnace gas is
combusted
79
Chapter 10
dedusting one or a
combination of dedusting
techniques
(e.g.
deflectors in combination
with
venturi-type
scrubbers or dry or wet
ESP). Further description
is given in the Iron and
Steel BREF
e.
Electrostatic precipitator (ESP)
Only applicable to plants
combusting auxiliary fuels with
high ash content in a significant
proportion coal and to plants
combusting liquid fuels in a
significant proportion (> 10–15%
of the yearly fuel input) with high
ash content
See
descriptions
in
Section 10.8. Can be
combined with WFGD
for
enhanced
dust
reduction
Bag filter
R
ES
S
d.
G
{This BAT conclusion is based on information given in Section 7.3.4.4}
PR
O
BAT-associated emission levels
The BAT-associated emission levels (BAT-AELs) for dust emissions to air from the
combustion of iron and steel process gases are given in Table 10.36.
Table 10.36: BAT-associated emission levels (BAT-AELs) for dust emissions to air from the
combustion of iron and steel process gases, or multi gaseous fuel combustion,
including iron and steel process gases
Fuel diet
Boiler
Monitoring
frequency
-
3
Continuous
measurement
< 2–5
NA
< 1–4
15
Periodic
measurement:
4 times/yr
8–45 (1)
2–15
-
3
Continuous
measurement
4–25
1–15
-
6
Continuous
measurement
2–15 (3)
O
R
KI
N
G
CCGT
O2
reference
level (%)
< 1–7
D
R
Iron and steel
process gas(es),
alone or in
combination
with other
gaseous fuels
Iron and steel
process gas(es)
with liquid fuels,
alone or in
combination
with other
gaseous fuels
Iron and steel
process gas(es)
with coal, alone
or in
combination
with other
gaseous and
or/liquid fuels
AF
Combustion
plant type
T
IN
BAT-AELs for dust (mg/Nm3) (1)
Daily
average
Average of
samples
or
Yearly
average
obtained
average
over the
during one
sampling
year
period
W
Boiler
(1) The upper end of the range (15–45 mg/Nm3) is expected to be achieved when firing liquid fuels.
(3) The upper end of the BAT-AEL range may be higher on days when auxiliary liquid fuels are used. In this case, the
higher end of the BAT-AEL range may correspond to the higher end of the BAT-AEL range reported in the BAT
conclusions that apply to the combustion of the corresponding (auxiliary) fuel and to the case of plants operated in
peak- or emergency-load modes.
NB: NA = No BAT-AELs
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The associated monitoring is in BAT 3 ter.
10.4.3
BAT conclusions for the combustion of gaseous and/or
liquid fuels on offshore platforms
Unless otherwise stated, the BAT conclusions presented in this section are generally applicable
to the combustion of gaseous and/or liquid fuels on offshore platforms,, They apply in addition
to the general BAT conclusions given in Section 10.1.
Techniques
Generally applicable
G
Minimise the 'spinning
reserve'
Applicability
PR
O
a.
Description
When running with spinning
reserve for operational reliability
reasons, the number of additional
turbines is minimised, except in
exceptional circumstances
Provide a fuel gas supply from a
point in the topside oil and gas
process which offers a minimum
range of fuel gas combustion
parameters, e.g. calorific value, and
minimum
concentrations
of
sulphurous compounds to minimise
SO2 formation. For liquid distillate
fuels, preference is given to lowsulphur fuels
Operate multiple generator or
compressor sets at load points
which minimise pollution
Optimise and maintain inlet and
exhaust systems in a way that keeps
the pressure losses as low as
possible
Optimise the process in order to
minimise the mechanical power
requirements
R
ES
S
BAT 59. In order to improve the general environmental performance of the combustion
of gaseous and/or liquid fuels on offshore platforms, BAT is to use one or a combination of
the techniques given below.
Generally applicable
AF
T
IN
b. Fuel choice
D
R
c. Load control
G
d. Control pressure losses
KI
N
e. Process optimisation
Heat recovery
W
O
R
f.
g. Injection timing
Power integration of multiple
h.
gas/oil fields
Utilisation of gas turbine / engine
exhaust heat for platform heating
purposes
Optimise injection timing in
engines
Use of a central power source to a
number
of
participating
installations platforms located at
different gas/oil fields
Generally applicable
Generally applicable
Generally applicable
Generally applicable to new
plants.
In existing plants, the
applicability
may
be
restricted by the level of heat
demand and the combustion
plant layout (space)
Generally applicable for
engines
The applicability may be
limited dependings on the
location of the different
gas/oil fields and on the
organisation of the different
participating
installations
platforms,
including
alignment of time schedules
regarding planning, start-up
and cessation of production
{This BAT conclusion is based on information given in Sections 7.4.4.1, 7.4.4.2 and 3.3.4}
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Chapter 10
BAT 60. In order to prevent and/or reduce NOX emissions to air from the combustion of
gaseous and/or liquid fuels on offshore platforms, BAT is to use one or a combination of
the techniques given below.
See description in Section 10.8
b.
Lean-burn concept
See description in Section 10.8
c.
Low-NOX burners
See description in Section 10.8
d.
Advanced computerised
process control system
See description in Section 10.8
R
ES
S
Dry low-NOX burners
(DLN)
G
a.
Applicability
Applicable to new gas turbines
(standard equipment) within the
constraints associated with the fuel
quality variations.
The applicability may be limited for
existing gas turbines by: availability of
retrofitting package (for low load
operation), complexity of the platform
organisation and space availability
Only Generally applicable to new gasfired engines
Generally Only applicable to boilers
Generally applicable to new plants.
The applicability to old combustion
plants may be constrained by the need
to retrofit the combustion and/or
control command system(s)
O
Description
PR
Technique
{This BAT conclusion is based on information given in Section 7.4.4.3}
IN
BAT 61. In order to prevent and/or reduce CO emissions to air from the combustion of
gaseous and/or liquid fuels in gas turbines on offshore platforms, BAT is to use one or a
combination of the techniques listed in BAT 42 and BAT 49.
AF
T
BAT-associated emission levels
The BAT–associated emission levels for NOX and CO emissions to air are presented given in
Table 10.37.
G
D
R
Table 10.37: BAT-associated emission levels (BAT-AELs) for NOX and CO emissions to air from
the combustion of gaseous and/or liquid fuels in open-cycle gas turbines on offshore
platforms
NOX
Daily average
Average over the
sampling period
KI
R
W
O
New gas turbines
combusting gaseous fuels
(3)
Existing gas turbines(1)
combusting gaseous fuels
(3)
Existing/New dual fuel
gas turbine combusting
liquid fuels
CO
(yearly
average
Average over
the sampling
period
N
Plant type
BAT-AELs (mg/Nm3) (2)
NOX (yearly
average)
5 7–50 (4)
6–40
< 75 50
ND < 50–290
(1)
6–125
< 100
145–250
Monitoring
frequency
Continuous
measurement or
PEMS
Continuous
measurement or
PEMS
< 100
(1) The lower end of the BAT-AEL range iscan be achieved with last generation of DLN burners.
(2) These BAT-AELs are expressed for a turbine load of > 70 % when using DLN burners and about 70 % when not
using DLN burners when the monitoring is performed periodically.
(3) This includes single fuel and dual fuel gas turbines.
(4) The higher end of the BAT-AEL range is 250 mg/Nm3 if DLN burners cannot be used, e.g. due to poor quality
fuels.
The associated monitoring is in BAT 3 ter.
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Chapter 10
10.5
BAT conclusions for multi-fuel-fired plants
10.5.1
BAT conclusions for the combustion of process fuels from
the chemical industry industrial process fuels produced by
the chemical industry
R
ES
S
, in addition to the general BAT conclusions given in Section 10.1
Unless otherwise stated, the BAT conclusions presented in this section are generally applicable
apply in addition to the general BAT conclusions given in section 10.1 are generally applicable
to combustion plants using process fuels from gaseous and/or liquid process fuels in the
chemical industry, individually, in combination, or simultaneously including their mixture with
other gaseous and/or liquid fuels.
General environmental performance in the combustion of chemical
process fuels
G
10.5.1.1
PR
O
BAT 62. In order to improve the general environmental performance of the combustion
plants using of process fuels from the chemical industry in boilers process fuels, including
the mixture with other fuels, BAT is to ensure stable and increased combustion conditions
by use a combination of the techniques in BAT 4 and listed below.
Description
NC fuel Pretreatment of
a. process fuel from the
chemical industry
Perform fuel pretreatment at the chemical
installation on and/or off the site of the
combustion
plant
to
improve
the
environmental
performances
of
fuel
combustion
Applicability
Generally applicable
See description in Section 10.8
Generally applicable
Combination of primary measures
Generally applicable
D
R
c. Process control
T
Advanced computerised
control system
AF
b.
IN
Technique
{This BAT conclusion is based on information given in Sections 8.2.3.2 and 5.1.4.2}
W
O
R
KI
N
G
BAT 63. In order to improve the general environmental performance of the combustion
plants using chemical industry process fuels, including the mixture with other fuels, BAT
is to perform fuel characterisation and ultimate analysis with the frequency and elements
indicated in BAT 5. BAT is to integrate the outcome of the characterisation and analysis
into the advanced computerised process control system.
Description
The fuel analysis and characterisation describe the chemical composition and physical
characteristics of fuel, e.g. it gives the low heating value and identifies the substances that
can lead to the formation of the pollutants covered in these BAT conclusions.
Applicability
Applicable within the constraints given by the load variations needed to meet all the
chemical installation operations.
{This BAT conclusion is based on information given in Section 8.2.3}
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Chapter 10
10.5.1.2
Energy efficiency
BAT 64. In order to increase the energy efficiency of the combustion plants using
chemical industry process fuels, including mixtures with other fuels, BAT is to use one or a
combination of the techniques given in BAT 7 and below.
Technique
Heat
recovery
a
cogeneration (CHP)
by
Description
Applicability
See description in Section 10.8
Generally applicable
{This BAT conclusion is based on information given in Section 3.3.4}
R
ES
S
BAT-associated environmental performance levels
The BAT-associated energy efficiency levels infor the combustion of process fuels from the
chemical industry in boilers industrial process fuels, including their mixture with other fuels are
given in Table 10.38.
G
Table 10.38: BAT-associated energy efficiency levels (BAT-AEELs) in the for the combustion
plants using of process fuels from the chemical industry in a boiler process fuels,
including their mixture with other fuels
New
Existing
New
IN
Net total fuel
utilisation
%
Net electrical
efficiency
Existing
> 90
80 to above 96
above 38
30 to above 38
AF
Generating only power or CHP plants whose
recoverable heat generation exceeds the heat
demand
Unit
T
Generating only heat or
CHP plants whose recoverable heat generation
does not exceed the heat demand
BAT-AEPL
(yearly average,
LHV basis)
O
Parameter
PR
Type of plant
Type of combustion
plant
above 38
>37.4
30 to above 38
35.6–37.4
> 90
80–96
80 to above 96
80–96
40–42.5
to above 42
38–40
78–95
78–95
O
R
KI
N
G
Boiler
using
liquid
process fuels from the
chemical
industry,
including when mixed
with HFO, gas oil and/or
other liquid fuels
Boiler using gaseous
process fuels from the
chemical
industry,
including when mixed
with natural gas and/or
other gaseous fuels
D
R
BAT-AEEPLs (1)
(yearly average – LHV basis)
Net electrical efficiency (%) (2)
Net total fuel utilisation (%) (3) (4)
New plant
Existing plant
New plant
Existing plant
W
(1) These BAT-AEELs do not apply in the case of plants operated in peak- or emergency-load modes.
(2) These BAT-AEELs apply to CHP combustion plants and to combustion plants generating only power.
(3) These BAT-AEELs apply to CHP combustion plants and to combustion plants generating only heat.
(4) These BAT-AEELs may not be achievable in the case of an excessively low potential heat demand.
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Chapter 10
10.5.1.3
NOX, NH3 and CO emissions to air
BAT 65. In order to prevent and/or reduce NOX emissions to air while limiting NH3 and
CO emissions to air from combustion plants using process fuels from the chemical
industry process fuels, including the mixtures with other fuels, BAT is to use one or a
combination of the techniques given below:.
b.
Description
See description in
Section 10.8
Air staging combustion
See description in
Section 10.8
Applicability
Generally applicable
Generally applicable for new plants.
Applicable to existing plants within the
constraints given by furnace size and
design.
R
ES
S
a.
Technique
(Advanced) lLow-NOX
burners (LNB)
See description in
Section 10.8.
Flue-gas recirculation
e.
Selective non-catalytic
reduction (SNCR)
See description in
Section 10.8
T
IN
d.
D
R
AF
See description in
Section 10.8.
Generally applicable to new plants.
Applicable to existing plants within the
constraints given byassociated with
furnace size and design, chemical
installation safety
Generally applicable to new plants.
Applicable to existing plants within the
constraints given byassociated with
furnace size and design, chemical
installation safety.
G
N
KI
R
Selective catalytic
reduction (SCR)
Not applicable to combustion plants
operated in emergency-load mode.
The applicability may be limited in the
case of plants operated in peak-load
mode with frequent fuel changes and
frequent load variations
Generally applicable for new plants.
Applicable to existing plants within the
constraints given byassociated with duct
configuration, space availability, as well
as chemical installation safety.
See description in
Section 10.8.
Not applicable to combustion plants
operated in emergency-load mode.
There may be technical and economic
restrictions for retrofitting existing
plants operated in peak-load mode.
W
O
f.
Generally applicable
G
Applying fuel staging when
using liquid fuel mixtures
may require a specific burner
design
O
Fuel staging (reburning)
PR
c.
g.
Fuel choice
See description in
Section 10.8
h.
Water/steam addition
See description in
Section 10.8
i.
Advanced control system
See description in
Section 10.8
TL/JFF/EIPPCB/Revised LCP_Draft 1
April 2015
Not generally applicable to combustion
plants of < 100 MWth
Applicable within the constraints
associated with the availability of
different types of fuel
The applicability may be limited due to
water availability
Generally applicable
85
Chapter 10
{This BAT conclusion is based on information given in Section 8.2.3.1}
BAT-associated emission levels
The BAT-associated emission levels for NOX, NH3 and CO from combustion plants using
process fuels from the chemical industry, including the mixtures with other fuels are presented
given in Table 10.39.
BAT-AEL
Fuel
Pollutant
Mixture of gases and/or
liquids
NOX
NH3
CO
Unit
Yearly average
70–200 (1)(2)
< 1–5 (3)
< 1–20
3
mg/Nm
R
ES
S
Table 10.39: BAT-associated emission levels (BAT-AELs) for NOX and CO emissions to air from
combustion plants using process fuels from the chemical industry process fuels,
including the mixtures with other fuels
Monitoring
Daily
frequency
average
(1)(2)
90–250
Continuous
ND
measurement
ND
PR
O
G
(1) The lower end of the range is associated with the use of gas-prevailing fuel blends (H2 up to 72 % vol in gases).
(2) With the exception of nitrogen-rich liquid-prevailing fuel blends (N up to 24 % w/w in liquids) where the upper
end of the yearly average range is 380 mg/Nm3 and no value is determined for daily average.
(3) Ammonia emissions are associated with the use of SCR and SNCR.
BAT-AELs (mg/Nm3)
NOX
30–85
Gases only
20–80
New or
Existing
existing
plant
plant
100–
50–110
< 1–30 Continuous
330 (1)
measurement
30–100 85–210 < 1–30
T
New
plant
80–290 (1)
70–180
D
R
Mixture of gases and liquids
Existing plant
AF
New plant
Daily average or
Yearly
average over the
Monitoring
average
sampling period
frequency
IN
Yearly average
Fuel phase
CO
(1) For existing plants of < 100 MWth using fuels with a nitrogen content higher than 0.6 % (w/w), the higher end of
the BAT-AEL range is 380 mg/Nm3.
W
O
R
KI
N
G
The associated monitoring is in BAT 3 ter.
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Chapter 10
10.5.1.4
SOX, HCl and HF emissions to air
BAT 66. In order to reduce SOX, HCl and HF emissions to air from the combustion plants
using of process fuels from the chemical industry process fuels in boilers, including their
mixtures with other fuels, BAT is to use one or a combination of the techniques given
below.
Wet flue-gas
desulphurisation
(Wet FGD)
Applicability
See description in
Section 10.8
G
a.
Description
R
ES
S
Technique
PR
O
Generally applicable to new plants.
Applicable to existing plants within the
constraints given byassociated with duct
configuration, space availability, as well
as and as well chemical installation
safety.
See description in
Section 10.8.
b. Wet scrubber
Furnace Boiler sorbent
injection (in-furnace or
in-bed)
D
R
c.
N
G
Duct sorbent injection
d. (DSI) (Dry in-duct
sorbent injection)
See description in
Section 10.8
f.
Seawater FGD
See description in
Section 10.8
Fuel choice
See description in
Section 10.8
R
KI
Spray-dry absorber
(SDA)
O
Wet FGD and seawater FGD are not
applicable to combustion plants operated
in emergency-load mode.
There may be technical and economic
restrictions for applying wet FGD or
seawater FGD to combustion plants of
< 300 MWth,
and
for
retrofitting
combustion plants operated in peak-load
mode with wet FGD or seawater FGD
See
description
in
Section 10.8. The technique
is used in combination with a
dust abatement technique
See description in
Section 10.8
e.
g.
W
AF
T
IN
The wWet scrubbing is used
to removes HCl and HF when
no Wet FGD is used to
removereduce SOX emissions
Applicable within the constraints
associated with the availability of
different types of fuel
{This BAT conclusion is based on information given in Section 8.2.3.2}
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Chapter 10
BAT-associated emission levels
The BAT-associated emission levels for SO2 SOX, HCl and HF emissions from the combustion
plants of process fuels from the chemical industry in boilers process fuels, including when
mixed with other fuels, are given in
Table 10.40 (for SO2) and 10.41 (for HCl and HF).
Table 10.40: BAT-associated emission levels (BAT-AELs) for SO2 SOX, emissions to air from the
combustion plants using of process fuels from the chemical industry in a boiler
process fuels, including the mixtures with other fuels
Unit
Monitoring frequency
SOXSO2
mg/Nm³
Continuous measurement
R
ES
S
Pollutant
BAT-AELs (mg/Nm3)
Daily average or
average over the
Yearly average (1)
sampling period
(2)
10–110
90–200
PR
O
G
(1) The yearly BAT-AELs do not apply to plants operated in peak- or emergency-load modes.
(2) The higher end of the BAT-AEL range may be different on days when auxiliary liquid fuels are used. In this case,
the higher end of the BAT-AEL range may correspond to the higher end of the BAT-AEL range reported in the BAT
conclusions that apply to the combustion of the corresponding auxiliary fuel and to the case of plants operated in
peak- or emergency-load modes.
Unit
Monitoring frequency
mg/Nm³
Periodic measurements
4times/yr
T
Pollutant
IN
Table 10.41: BAT-associated emission levels (BAT-AELs) for HCl and HF emissions to air from the
combustion plants using of process fuels from the chemical industry in a boiler
process fuels, including the mixtures with other fuels
< 0.1–2
D
R
HF
Monitoring
frequency
BAT-AELs (mg/Nm3)
Combustion
plant total
rated
thermal
input
(MWth)
HF
G
HCl
N
Average over the sampling period
KI
New plant
< 1–10
< 1–5
R
< 100
≥ 100
< 1–8
AF
HCl
BAT-AEL
Average of samples taken during
one year
Existing plant
New plant
Existing plant
2–15
< 1–9 (1)
< 0.1–4
< 0.1–2
0.2–10
< 0.1–5 (2)
Continuous
measurement
O
(1) In the case of plants operated in peak- or emergency-load modes, the BAT-AEL range is 2–15 mg/Nm3.
(2) In the case of plants operated in peak- or emergency-load modes, the BAT-AEL range is 0.2–10 mg/Nm3.
W
The associated monitoring is in BAT 3 ter.
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Chapter 10
10.5.1.5
Dust and particulate-bound metals emissions to air
BAT 67. In order to reduce emissions to air of dust, particulate-bound metals, and trace
species from the combustion plants using of process fuels from the chemical industry in
boilers process fuels, including the mixtures with other fuels, BAT is to use one or a
combination of the techniques given below.
Fuel choice
b.
Bag filter
See description in Section 10.8
c.
High-performance
electrostatic
precipitator (ESP)
See description in Section 10.8
d.
Dry, semi-dry or wet
FGD system
Applicable
within
the
constraints associated with the
availability of different types
of fuel, which may be
impacted by the energy policy
of the Member State.
Generally
applicable
Applicable
within
the
constraints given by space
availability.
PR
O
a.
Applicability
R
ES
S
Description
See description in Section 10.8.
By switching to a different fuel or
modulating the fuel blending, the
corresponding emissions are reduced.
Use of a combination of process fuels
from the chemical industry and auxiliary
fuels with low averaged dust or ash
content
G
Technique
IN
See description in Section 10.8
Generally applicable when the
technique is mainly used for
SOX,
HCl
and/or
HF
abatement
T
{This BAT conclusion is based on information given in Section 8.2.3.2}
W
O
R
KI
N
G
D
R
AF
BAT-associated emissions levels
The BAT-associated emission levels emissions of dust as well as particulate-bound metals and
trace species from the combustion plants using of process fuels from the chemical industry in
boilers process fuels, including mixtures with other fuels, are given in
Table
10.42
and
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Chapter 10
Table 10.43.
Table 10.42: BAT-associated emission levels (BAT-AELs) for dust emission to air from the
combustion plants using of process fuels from the chemical industry in a boiler
process fuels, including mixtures with other fuels
BAT-AELs for dust (mg/Nm3)
Daily average or average
over the sampling period
All sizes
New plant
Existing
plant
New plant
Existing
plant
< 1 2–5
< 1 2–15 10
ND 2–10
(1)
< 20 2–25 (1)
Monitoring
frequency
R
ES
S
Yearly average
Combustion
plant total rated
thermal input
(MWth)
Continuous
measurement
G
(1) The upper end of the BAT-AEL range may be higher on days when auxiliary liquid fuels are used. In this case, the
higher end of the BAT-AEL range may correspond to the higher end of the BAT-AEL range reported in the BAT
conclusions that apply to the combustion of the corresponding (auxiliary) fuel and to the case of plants operated in
peak- or emergency-load modes.
W
O
R
KI
N
G
D
R
AF
T
IN
PR
O
The associated monitoring is in BAT 3 ter.
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TL/JFF/EIPPCB/Revised LCP_Draft 1
Chapter 10
Table 10.43: BAT-associated emission levels for particulate-bound metals and trace species
emissions to air from the combustion plants using chemical industry process fuels,
including mixtures with other fuels
Pollutant
Unit
BAT-AEL
average of samples obtained during one year
Sb+As+Pb+Cr+
Co+Cu+Mn+Ni
+V
mg/Nm3
0.05–0.2
Mercury emissions to air
R
ES
S
10.5.1.6
Monitoring
frequency
Periodic
measurement: 4
times/yr
BAT 68.
In order to reduce mercury emissions to air from the combustion plants using
chemical industry process fuels, including the mixtures with other fuels, BAT is to use one
or a combination of the techniques given below.
b.
ESP
c.
SCR
Fuel pretreatment
IN
See description in Section
10.8
Fuel washing, blending and
mixing in order to reduce
the Hg content
D
R
f.
Generally applicable for new plants.
Applicable to existing plants within
the constraints given by duct
configuration, space availability, as
well as chemical installation safety.
T
e.
FGD technique (e.g. wet
limestone scrubbers, spray
dryer scrubbers or dry
sorbent injection)
Carbon sorbent
(e.g. activated
carbon) injection in the fluegas
AF
d.
G
Bag Filter
Applicability
O
a.
Description
See description in Section
10.8
See description in Section
10.8
See description in Section
10.8
See descriptions in Section
10.8
PR
Technique
Applicability requires previous survey
for characterising the fuel and for
estimating the potential effectiveness
of the technique
{This BAT conclusion is based on information given in Section 8.2.3.2}
N
G
BAT-associated emissions levels
The BAT-associated levels for mercury emissions to air from the combustion plants using
chemical industry process fuels, including mixtures with other fuels, are given in Table 10.44.
KI
Table 10.44: BAT-associated emission levels for mercury from the combustion plants using
chemical industry process fuels, including mixtures with other fuels
Unit
BAT-AEL
Average of samples obtained during one
year
Monitoring
frequency
Mercury
µg/Nm3
0.1–8
Periodic
measurement: 4
times/yr
W
O
R
Pollutant
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Chapter 10
10.5.1.7
Emissions of volatile organic compounds and polychlorinated
dibenzo-dioxins and -furans TOC, dioxins and furans emissions to
air
See description in Section 10.8.
The SCR system is adapted and
larger in comparison with an
SCR system only used for NOX
reduction
Selective catalytic reduction
(SCR)
Rapid quenching through wet
c. scrubbing / FGflue-gas
condenser
See description of wet scrubbing
/ FGflue-gas condenser in
Section 10.8
G
See description in Section 10.8
Applicability
Only applicable to combustion
plants using fuels derived from
chemical processes involving
chlorinated substances.
Generally applicable for to new
plants.
Applicable to existing plants
within the constraints given
byassociated
with
duct
configuration, space availability,
as well as chemical installation
safety
PR
b.
Description
O
Technique
Activated carbon injection /
a.
reactor
R
ES
S
BAT 69. In order to reduce emissions to air of volatile organic compounds and
polychlorinated dibenzo-dioxins and -furans TOC, dioxins and furans emissions to air
from the combustion plants using of process fuels from the chemical industry in boilers
process fuels, including the mixtures with other fuels, BAT is to use one or a combination
of the techniques given in BAT 4 and below.
IN
{This BAT conclusion is based on information given in Section 8.2.3.2}
AF
T
BAT-associated emission levels
The BAT-associated emission levels for PCDD/F and TVOC dioxins and furans from the
combustion plants using of process fuels from the chemical industry in boilers process fuels,
including the mixtures with other fuels, are given in Table 10.45.
D
R
Table 10.45: BAT-associated emission levels (BAT-AELs) for PCDD/F and TVOC emissions to air
dioxins and furans from the combustion plants of chemical industry process fuels
from the chemical industry in a boilerthe mixtures
BAT-AELs
Average of samples obtained
during one year Average over the
sampling period
Unit
Dioxins and furans
PCDD/F (1)
pg I-TEQ/Nm3
1–100
TVOC
mg/Nm3
1–24 10
KI
N
G
Pollutant
1
Monitoring frequency
Periodic measurement
2 times/yr
Periodic measurement
2 times/yr
R
( ) These BAT-AELs only apply to combustion plants using fuels derived from chemical processes involving
chlorinated substances.
W
O
The associated monitoring is in BAT 3 ter.
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Chapter 10
10.6
BAT conclusions for the waste co-incineration of waste
Unless otherwise stated, the BAT conclusions presented in this section are generally applicable
to combustion plants firingco-incinerating wasteas part of the combusted feedstock,. They apply
in addition to the general BAT conclusions given in Section 10.1.
Unless otherwise stated, the BAT-AELs in this section apply when waste is co-incinerated.
R
ES
S
When co-incinerating waste, the BAT-AELs set out in the fuel-specific sections apply in
relation to those fuels, as well as in relation to the mix of those fuels and the waste coincinerated, and taking into account BAT 70 bis.
10.6.1.1
General environmental performance in waste co-incineration
O
G
BAT 70. In order to improve the general environmental performance of the combustion
plants co-incinerationg of wastes in combustion plants, to ensure stable combustion
conditions, and to reduce emissions to air, BAT is to use a combination of the techniques
listed in BAT 4 and of the techniques given below.
Description
Implement a procedure for receiving any
waste at the combustion plant according to
the corresponding BAT from the Waste
Treatment Industries BREF. Acceptance
criteria are set for critical parameters such as
heating value, water content, ash content,
chlorine and fluorine content, sulphur
content, nitrogen content, PCB, metals
(volatile (Hg, Tl, Pb, Co and Se) and nonvolatile (e.g. V, Cu, Cd, Cr, Ni)) and
phosphorus and alkaline content (when using
animal by-products).
Apply quality assurance systems for each
waste load to guarantee the characteristics of
the wastes co-incinerated and to control the
values of defined critical parameters
Careful selection of waste type and mass
flow, together with limiting the percentage
of the most polluted waste that can be coincinerated. Limit Hgmercury and chlorine
entering the combustion process as elevated
proportions components of the waste
Applicability
AF
Generally applicable
N
G
D
R
Waste prea. acceptance and
acceptance
T
IN
PR
Technique
O
R
KI
b. Waste choice
W
c. Waste drying
d.
Waste
pretreatment
On-site or off-site pre-drying of the waste
before introducing it into the combustion
chamber, with a view to maintaining the high
performance of the boiler
See techniques described in the Waste
Treatment Industries and Waste Incineratiorn
BREFs, including milling, pre-combustion in
fluidised bed boilers, pyrolysis, gasification,
etc.
TL/JFF/EIPPCB/Revised LCP_Draft 1
April 2015
Generally applicable
The Aapplicability may be
limited
by
insufficient
recoverable heat from the
process, by the required
combustion conditions, or by
the waste moisture content
The Aapplicability may depend
on the combustion plant size
and configuration, on the type
of waste, and on the space
availability
93
Chapter 10
e.
Waste mixing
with the main fuel
Effective mixing between waste and the
main fuel, as an heterogeneous or poorly
mixed fuel stream or an uneven distribution
may influence the ignition and combustion in
the boiler and has to should be prevented
Mixing is only possible when
the grinding behaviour of the
main fuel and waste are similar
more or less the same or when
the amount of waste is very
small compared to the main fuel
flow
{This BAT conclusion is based on information given in Sections 9.1, 9.4.2 and 9.4.3}
R
ES
S
BAT 70 bis.
In order to prevent increased emissions from the co-incineration of waste
in combustion plants, BAT is to take appropriate measures to ensure that the emissions of
polluting substances in the part of the flue-gases resulting from waste co-incineration are
not higher than those resulting from the application of BAT conclusions for the
incineration of waste defined in the WI BREF.
PR
O
G
BAT 71. In order to reduce diffuse emissions to air and odorous substances from the
storage and handling of waste to be co-incinerated, BAT is to use a combination of the
techniques listed in BAT 9 and of the related BAT in the Waste Treatment Industries
BREF.
{This BAT conclusion is based on information given in Sections 9.4.1}
Energy efficiency
D
R
10.6.1.2
AF
T
IN
BAT 72. In order to minimise the impact on by-product and residues recycling from the
waste co-incineration of waste in combustion plants, BAT is to maintain the a good quality
of gypsum, ashes and slags andas well as other residues and by-products at the same level
as those occurring without the co-incineration, in line with the requirements set for their
recycling when the plant is not co-incinerating waste, by using one or a combination of the
techniques listed in BAT 70 and/or by restricting the co-incineration to waste fractions
with pollutant concentrations similar to those in other combusted primary fuels.
{This BAT conclusion is based on information given in Sections 9.4.6}
N
G
BAT 73. In order to increase the energy efficiency of the co-incineration of combustion
plants co-incinerating waste, BAT is to use one or a combination of the techniques listed in
BAT 7, and BAT 18, BAT 24, BAT 25, and BAT 82 depending on the main fuel type(s)
combusted used and on the plant configuration.
O
R
KI
BAT-associated environmental performance levels
The BAT-associated energy efficiency levels (BAT-AEELs) are the ones given in Table 10.10
for the co-incineration of waste with biomass- and/or peat-fired combustion plants coincinerating waste, and the ones given in Table 10.2 for the co-incineration of waste with coaland/or lignite-fired plants co-incinerating waste.
NOX, NH3 and CO emissions to air
W
10.6.1.3
BAT 74. In order to prevent and/or reduce NOX emissions to air while limiting CO and
NH3 emissions from waste co-incineration in coal- and lignite-fired combustion plants,
BAT is to use one or a combination of the techniques given in BAT 19 and of the technique
below.
Technique
a
Circulating fluidised bed
boiler
Description
See description in Section 10.8
Applicability
Applicable for new plants and
when firing waste that can be
fragmented to the fraction size
necessary to create a fluidised bed
{This BAT conclusion is based on information given in Section 9.4.4}
94
April 2015
TL/JFF/EIPPCB/Revised LCP_Draft 1
Chapter 10
The BAT-associated emission levels (BAT-AELs) for NOX and CO and NH3 are given in Table
10.46.
Table 10.46: BAT-associated emission levels for NOX, CO and NH3 emissions to air from waste coincineration in coal- and lignite- fired combustion plants
> 300 FBC
(coal-lignite)
and PC
lignite firing
> 300 PC
coal firing
50–150
50–180
65–100
65–180
BAT-AEL
for CO
(yearly
average mg/Nm3)
BAT-AEL
for NH3 (1)
(yearly
average mg/Nm3)
ND
10–100
<6
ND
10–100
140–220
80–125
<6
12–80
80–220
1
( ) Ammonia emissions are associated with the use of SCR and SNCR.
Monitoring
frequency
R
ES
S
100–300
BAT-AEL for NOX
(daily average mg/Nm3)
New
Existing
plants
plants
<6
Continuous
measurement
G
< 100
BAT-AEL for NOX
(yearly average mg/Nm3)
New
Existing
plants
plants
100–
100–270
200
100–
100–180
150
1–55
<6
O
Combustion
plant rated
thermal
input
(MWth)
IN
PR
BAT 75. In order to prevent and/or reduce NOX emissions to air while limiting CO and
NH3 emissions from the waste co-incineration in biomass- and peat-fired combustion
plants, BAT is to use one or a combination of the techniques given in the BAT 26 and of
the technique given below.
Circulating fluidised bed
boiler
See description in Section 10.8
AF
a.
Description
T
Technique
Applicability
Applicable for new plants and
when firing waste that can be
fragmented to the fraction
necessary to create fluidised bed
D
R
{This BAT conclusion is based on information given in Section 9.4.4}
The BAT-associated emission levels for NOX, CO and NH3 are given in Table 10.47.
N
G
Table 10.47: BAT-associated emission levels for NOX from the co-incineration of waste in biomassand peat-fired combustion plants
W
O
R
KI
Combustion
plant rated
Pollutant
thermal input
(MWth)
50–100
100–300
> 300
BAT-AEL
Unit
Monitoring
frequency
mg/Nm3
Continuous
measurement
NOX
1
New plant
Yearly
Daily
average
average
70–200
120–260
50–130
100–220
40–130
65–150
NH3 ( )
CO
(1) Ammonia emissions are associated with the use of SCR and SNCR.
All
TL/JFF/EIPPCB/Revised LCP_Draft 1
April 2015
Existing plant
Yearly
Daily
average
average
70–250
120–310
50–140
100–220
40–140
95–150
< 1–7
ND
4–80
ND
95
Chapter 10
10.6.1.4
SOX, HCl and HF emissions to air
BAT 76. In order to prevent and/or reduce SOX, HCl and HF emissions to air from the
waste co-incineration of waste with in coal- and/or lignite-fired combustion plants, BAT is
to apply one or a combination of the techniques listed in BAT 21 and of the technique
given below.
Description
Applicability
Generally applicable within the
constraints associated with the
types of waste to be coincinerated, which may be
impacted
by
the
waste
management policy of the local /
national competent authority
Selection of waste streams with
low S, Cl, Fsulphur, chlorine
and/or fluorine content.
Limitation of the amount of
waste to be co-incinerated
a. Waste selection / limitation
R
ES
S
Technique
G
{This BAT conclusion is based on information given in Section 9.4.4}
The BAT-associated emission levels for SOX are the ones given in Table 10.48.
150–200
80–150
10–75
10–130
20–150
20–180
PR
Monitoring
frequency
ND
25–110
AF
50–100
100–300
> 300 (Pulverised
combustion)
> 300 (Fluidised
bed boilers) (1)
Existing
plants
(daily
average)
IN
New plants
(yearly
average)
BAT-AEL (mg/Nm3) (3)
New
Existing
plants
plants (yearly
(daily
average)
average)
150–400
ND
80–200
T
Combustion
plant rated
thermal input
(MWth)
O
Table 10.48: BAT-associated emission levels for SOX emissions to air from waste co-incineration in
coal- and lignite-fired combustion plants with coal and lignite S content < 3 %
25–220
Continuous
measurement (2)
ND
D
R
(1) Lower end of the range is achieved with a highly efficient wet FGD system. The higher end can be achieved with
boiler / in-bed sorbent injection.
(2) Only SO2 is continuously measured, SO3 is periodically measured (e.g. during calibration).
(3) When low-S waste is co-incinerated, the lower SOX emissions should be expected, e.g. a plant co-incinerating
more than 30 % (LHV basis) low-S waste emits at the lower end of the given ranges.
N
G
The BAT-associated emission levels for halogens are given in
Table 10.49.
KI
Table 10.49: BAT-associated emission levels for halogen emissions to air from waste coincineration in coal- and lignite-fired combustion plants
BAT-AEL (mg/Nm3)
< 1–5
< 0.1–2
Monitoring frequency
Continuous measurement
Continuous measurement
W
O
R
Pollutant
HCl
HF
96
April 2015
TL/JFF/EIPPCB/Revised LCP_Draft 1
Chapter 10
BAT 77. In order to prevent and/or reduce SOX, HCl and HF halogen emissions to air
from the waste co-incineration of waste with in biomass and/or peat-fired combustion
plants, BAT is to use one or a combination of the techniques listed in BAT 28 and of the
techniques given below.
Description
a. Waste selection / limitation
b. Semi-dry absorber (SDA)
Selection of waste streams with
low S, Cl, Fsulphur, chlorine
and/or fluorine content.
Limitation of the amount of
waste to be co-incinerated
See description in Section 10.8
Applicability
Generally applicable within the
constraints associated with the
types of waste to be coincinerated, which may be
impacted
by
the
waste
management policy of the
Member State local / national
competent authority
Generally applicable
R
ES
S
Technique
{This BAT conclusion is based on information given in Section 9.4.4}
O
G
BAT-associated emission levels
The BAT-associated emission levels for SOX, HCl, and HF are given in
Table 10.50.
R
KI
N
IN
Monitoring
frequency
T
G
Straw % in the
fuel-waste feed <
25 %
Straw % in the
fuel-waste feed 
100%
mg/N
m³
Continuous
measurement (1)
HCl
All
10.6.1.5
BAT-AEL
Yearly
Daily
average
average
1–50
8–70
100–165
ND
Intermedia
te, within
the ranges
given in
the two
lines above
ND
1–8
3–12
< 18
ND
Intermedia
te, within
the ranges
given in
the two
lines above
< 0.01–0.8
25  Straw % in
the fuel-waste feed
< 100
W
O
Unit
SOX
D
R
20  Peat % in the
fuel-waste feed <
70
Pollut
ant
AF
Fuel
(% in yearly and
LHV basis)
Peat % in the fuelwaste feed < 20%
Peat % in the fuelwaste feed ≥ 70 %
PR
Table 10.50: BAT-associated emission levels for SOX, HCl, and HF emissions to air from the coincineration of waste in biomass- and peat-fired combustion plants
HF
ND
ND
Dust and particulate-bound metals emissions to air
BAT 78. In order to reduce dust and particulate-bound metals emissions to air from the
waste-co-incineration of waste with in coal and/or lignite-fired combustion plants, BAT is
to use one or a combination of the techniques listed in BAT 22.
{This BAT conclusion is based on information given in Section 9.4.4}
TL/JFF/EIPPCB/Revised LCP_Draft 1
April 2015
97
Chapter 10
BAT-associated emission levels
The BAT-associated emission levels for dust emissions to air are the same as the ones given in
Table 10.7.
The BAT-associated emission levels for metals emissions are given in
Table 10.51.
Table 10.51: BAT-associated emission levels (BAT-AELs) for metals emissions to air from the
waste co-incineration of waste with in coal- and/or lignite-fired combustion plants
BAT-AEL (average of samples obtained during one year)
Sb+As+Pb+Cr+Co+Cu+Mn+Ni+V
Cd+Tl (µg/Nm3)
(mg/Nm3)
≥ 300
0.025–0.2
0.0025–0.2
0.1–6 8
O
Monitoring
frequency
Average over the
sampling period
of samples obtained
during one year
Average of samples
obtained during one
year Yearly average
PR
0.1 0.4–6 12
Averaging period
Periodic
measurement
4 times/yr
Periodic
measurements
4 times/yr
T
< 300
0.025–0.2
0.004–0.5
R
ES
S
BAT-AELs (1)
Sb+As+Pb+Cr+
Cd+Tl
Co+Cu+Mn+Ni
(µg/Nm3)
3
+V (mg/Nm )
IN
Combustion plant
total rated thermal
input (MWth)
Periodic
measurements: 4
times/yr
0.1–6
G
0.025–0.2
Monitoring
frequency
AF
The associated monitoring is in BAT 3 ter.
Description
By switching to a different fuel/waste
or modulating the fuel/waste blending
(e.g. lower ash or lower chlorine
fuel/waste)
the
corresponding
emissions can be reduced
N
Technique
G
D
R
BAT 79. In order to reduce dust and particulate-bound metal emissions to air from the
waste co-incineration of waste with in biomass- and/or peat-fired combustion plants, BAT
is to use one or a combination of the techniques in BAT 29 and of the technique given
below.
Fuel / waste choice
e.
Bag filter
O
R
KI
d.
Applicability
Applicable within the constraints
associated with the availability of
different types of fuel/waste,
which may be impacted by the
energy and waste management
policies of the Member State
See description in Section 10.8
Applicable within the constraints
given by space availability
See description in Section 10.8
g.
Activated
carbon
injection / reactor
See description in Section 10.8
Applicable
reduction
See description in Section 10.8
Applicable in combination with
other dedusting devices (e.g. bag
filter or ESP), when used for
desulphurisation
W
f.
High-performance
electrostatic
precipitator
h.
Wet FGD
for
further
metal
{This BAT conclusion is based on information given in Section 9.4.4}
BAT-associated emission levels
98
April 2015
TL/JFF/EIPPCB/Revised LCP_Draft 1
Chapter 10
The BAT-associated emission levels for dust are presented in Table 10.13.
The BAT-associated emission levels for metals are presented given in Table 10.52.
Table 10.52: BAT-associated emission levels (BAT-AELs) for particulate-bound metal emissions to
air from the waste co-incineration of waste with in biomass and/or peat-fired
combustion plants
BAT-AELs
(average of samples obtained during one year)
Sb+As+Pb+Cr+Co+Cu+Mn+Ni+V
Cd+Tl
(mg/Nm3)
(µg/Nm3)
R
ES
S
Monitoring
frequency
Periodic
measurements:
4 times/yr
0.8–5 22 (1)
0.075–0.3
G
(1) The higher end of the range is achieved when co-incinerating waste containing high levels
of Cd+Tl (e.g. 5–6 mg/kg) in a high share (e.g. > 60 % - LHV basis)
Mercury emissions to air
PR
10.6.1.6
O
The associated monitoring is in BAT 3 ter.
IN
BAT 80. In order to reduce mercury emissions to air from the waste co-incineration of
waste with in biomass-, peat-, coal- and/or lignite-fired combustion plants, BAT is to use
one or a combination of the techniques listed in BAT 23 and of the technique given below.
Description
Selection of waste with a low
Hgmercury content, blended with
the fuel in order to obtain a
homogeneous mixture, and in a
limited amount in order to avoid
additional Hgmercury emissions
Applicability
Applicable within the constraints
associated with the waste
management policy of the
Member State strategy agreed at
the local / national level
D
R
a. Waste stream control
AF
T
Technique
{This BAT conclusion is based on information given in Section 9.4.4}
KI
N
G
The BAT-associated emission levels for mercury in coal- and/ lignite-fired combustion plants
co-incinerating waste are the ones given in Table 10.8 and in Table 10.9.
W
O
R
Table 10.53: BAT-associated emission levels for mercury emissions to air from waste coincineration in biomass- and peat-fired combustion plants
Pollutant
Unit
BAT-AELs
Average of samples obtained during one
year
Monitoring
frequency
Mercury
µg/Nm3
0.2–10
Periodic
measurements: 4
times/yr
10.6.1.7
Emissions of volatile organic compounds and polychlorinated
dibenzo-dioxins and -furans TOC, dioxins, and furans emissions to
air
BAT 81. In order to reduce emissions of volatile organic compounds and polychlorinated
dibenzo-dioxins and -furans TOC, dioxins, and furans emissions to air from the waste-coincineration of waste with in biomass-, peat-, coal- and/or lignite-fired combustion plants,
TL/JFF/EIPPCB/Revised LCP_Draft 1
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99
Chapter 10
BAT is to use a combination of the techniques listed in BAT 4 and of the techniques given
below.
Technique
a
Description
Activated carbon
injection / reactor
Applicability
Generally Aapplicable to
biomassand
peat-fired
combustion plants
See description in Section 10.8
See description in Section 10.8. The
SCR system is adapted and larger in
comparison with an SCR system only
used for NOX reduction
Generally applicable
Rapid quenching
c through wet scrubbing /
FGflue-gas condenser
See description of wet scrubbing /
FGflue-gas condenser in Section 10.8
Generally applicable
R
ES
S
Selective catalytic
b
reduction (SCR)
{This BAT conclusion is based on information given in Section 9.4.4}
O
G
BAT-associated emission levels
The BAT-associated emission levels for PCDD/F dioxins and furans and TVOC emissions to air
are given in Table 10.54.
Unit
BAT-AELs
PCDD/F
ng ITEQ/Nm3
< 0.002–0.03
TVOC
mg/Nm3
Averaging
period
Periodic
measurement
Average over the
sampling period
IN
Pollutant
T
Type of
combustion plant
Biomass-, peat-,
coal- and/or
lignite-fired
combustion plant
Biomass-, peat-,
coal- and/or
lignite-fired
combustion plant
PR
Table 10.54: BAT-associated emission levels (BAT-AELs) for TOC PCDD/F, dioxins and furans
and TVOC emissions to air from the waste co-incineration of waste with in biomass-,
peat-, coal- and/or lignite-fired combustion plants
Yearly average
0.5–4.5 15
Daily average
Periodic
measurements
2 times/yr
Continuous
measurement
D
R
AF
< 0.1–3 5
Monitoring
frequency
BAT conclusions for gasification and IGCC plants
N
10.7
G
The associated monitoring is in BAT 3 ter.
W
O
R
KI
Unless otherwise stated, the BAT conclusions presented in this section are generally applicable
to all gasification plants directly associated to combustion plants, including IGCC plants. They
apply in addition to the general BAT conclusions given in Section 10.1.
100
April 2015
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Chapter 10
10.7.1.1
Energy efficiency
BAT 82. In order to increase the energy efficiency of the IGCC and gasification plants,
BAT is to use one or a combination of the techniques described in BAT 7 and of the
techniques given below.
Description
As the syngas needs to be
cooled down to be further
cleaned, energy can be
recovered for producing
additional steam to be added
to the steam turbine cycle,
enabling additional electrical
power to be produced
a. Heat recovery from the
gasification process
Applicability
Only aApplicable to IGCC plants
and to gasification plants
connecteddirectly associated to
boilers with syngas pretreatment
requiring cooling down of the
syngas temperature
R
ES
S
Technique
b. Integration of gasification and
combustion processes blocks
The plant can be designed
with full integration of the
air supply unit (ASU) and
the gas turbine, all the air
fed to the ASU being
supplied (extracted) from
the gas turbine compressor
c. Dry feedstock feeding system
Use of a dry system for
feeding the fuel to the
gasifier, in order to improve
the energy efficiency of the
gasification process
Only aApplicable to new plants
Use
of
gasification
technique
with
high
temperature and pressure
operating parameters, in
order
to
enable
the
maximum
carbon
conversion ratemaximise the
efficiency
of
energy
conversion
Only aApplicable to new plants
AF
T
IN
PR
O
G
The aApplicability is limited to
IGCC plants by the flexibility
needs of the integrated plant to
quickly provide the grid with
electricity when the renewable
power plants are not available is
shutting down
Design improvements, such
as:


W
O
R
KI
N
G
D
R
d. High temperature and pressure
gasification
e. Design improvements


geometry modification
of the draught tube dip
tube;
modification of the
system attack serpentine
cooling of the process
burners;
geometry modification
of the neck and throat
gasifier refractory;
installation
of
an
expander to recover
energy from the syngas
pressure drop before
combustion
Generally applicable to existing
IGCC plants
{This BAT conclusion is based on information given in Sections 4.3.4, 4.3.1.1 and 3.3.4}
BAT-associated environmental performance levels
The BAT-associated net electricalenergy efficiency levels for gasification and IGCC plants are
given in Table 10.55.
TL/JFF/EIPPCB/Revised LCP_Draft 1
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101
Chapter 10
Table 10.55: BAT-associated environmental performance levels for the energy efficiency levels
(BAT-AEELs) of for gasification and IGCC plants
BAT-AEPLAEELs (yearly average – LHV basis)
Net electrical efficiency (%) of thean IGCC
Net total fuel utilisation
plant
(%) of thea gasification
plant – New and or
New plants
Existing plants
existing plants
NA
NA
NA
NA
34–46
> 91
> 91
PR
NB: NA = No BAT-AELs
10.7.1.2
> 98
O
IGCC plants
NA
R
ES
S
Gasification plant
connecteddirectly
associated to a boiler
without prior syngas
treatment
Gasification plant
connecteddirectly
associated to a boiler with
prior syngas treatment
G
Type of combustion
plant configuration
NOX, and CO emissions to air
T
IN
BAT 83. In order to prevent and/or reduce NOX emissions to air while limiting CO
emissions to air from IGCC plants, BAT is to use one or a combination of the techniques
given below.
D
R
Dry low-NOX burners
(DLN) for the combinedcycle gas turbine
See
description
Section 10.8
in
Syngas dilution with
waste nitrogen from the
air supply unit (ASU)
W
O
b.
R
KI
N
G
a.
Description
AF
Technique
c.
102
Water/steam addition
Steam injection in the
gas turbine combustion
chamber
The ASU separates the
oxygen from the nitrogen
in the air, in order to
supply
high
quality
oxygen to the gasifier.
The waste nitrogen from
the ASU is reused to cool
down
reduce
the
combustion temperature
in the gas turbine, by
being premixed with the
syngas
before
combustion
See
description
in
Section 10.8.
Some
intermediate
pressure
steam from for the steam
turbine is reused for this
purpose
April 2015
Applicability
Only applicable to gas turbines.
Generally applicable to new plants.
Applicable and on a case-by-case basis for
existing plants, depending on the
availability of a retrofittableing package.
Not applicable for H-syngas content of
> 25 %
Only applicable when an ASU is used for
the gasification process
Generally applicable
Only applicable to gas turbines.
The applicability may be limited due to
water availability
TL/JFF/EIPPCB/Revised LCP_Draft 1
Chapter 10
Generally applicable to new and existing
coal PC plant > 100 MWth, in combination
with other primary techniques
Not applicable in the case of combustion
plants operated in emergency-load mode.
d.
Selective catalytic
reduction (SCR)
See
description
Section 10.8
in
Retrofitting existing plants may be
constrained by the availability of sufficient
space.
in
Generally applicable
G
See
description
Section 10.8
O
e.
Combustion optimisation
Complete combustion,
along with good furnace
design, the use of highperformance monitoring
and automated process
control techniques, and
maintenance
of
the
combustion system.
R
ES
S
There may be technical and economic
restrictions for retrofitting existing plants
operated in peak-load mode
PR
{This BAT conclusion is based on information given in Section 4.3.1.1}
IN
BAT-associated emission levels
The BAT-associated emission levels for NOX and CO are presented given in Table 10.56.
Table 10.56: BAT-associated emission levels (BAT-AELs) for NOX and CO emissions to air from
IGCC plants
≥ 100
T
AF
New
plants
Existing
plants
New
plants
Existing
plants
12–45
1–35
1– 60
D
R
Combustion
plant total
rated thermal
input
(MWth)
BAT-AELs (mg/Nm3)
NOX
NOX
(daily average or average
(yearly average)
over the sampling period)
< 1–5
Monitoring
frequency
Continuous
measurement
G
10–25
CO
(yearly
average)
New or
existing
plant
W
O
R
KI
N
The associated monitoring is in BAT 3 ter.
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Chapter 10
10.7.1.3
SOX emissions to air
BAT 84. In order to prevent and/or reduce SOX emissions to air from IGCC plants, BAT
is to use the technique given below.
a. Acid gas removal (AGR)
Applicability
Generally
applicable
The applicability may be limited
in the case of biomass IGCC
plants due to the very low
sulphur content in biomass
R
ES
S
Description
Sulphur compounds from the
feedstock of a gasification
process are removed from the
syngas via an AGR, e.g.
including
a
(HCN/)COS
hydrolysis reactor and the
absorption of H2S using a solvent
such as MDEA amine. Sulphur is
then recovered as either liquid or
solid elemental sulphur (e.g.
through a Claus unit), or as
sulphuric acid, depending on
market demands
O
{This BAT conclusion is based on information given in Section 4.3.1.1}
G
Technique
PR
BAT-associated emission levels
The BAT-associated emission levels (BAT-AELs) for SO2 SOX emissions to air are 3–
16 mg/Nm3, expressed as a yearly averages. Only SO2 is continuously measured, SO3 is
periodically measured (e.g. during calibration).
Dust, particulate-bound metals, ammonia and halogen emissions to
air
AF
T
10.7.1.4
IN
The associated monitoring is in BAT 3 ter.
D
R
BAT 85. In order to prevent or reduce dust, particulate-bound metals, ammonia and
halogen emissions to air from IGCC plants, BAT is to use one or a combination of the
techniques given below.
R
KI
N
a. Syngas filtration
Description
Dedusting using Filters used are fly
ash cyclones, bag filters, ESPs
and/or candle filters to remove fly
ash and unconverted carbon. Bag
filters and ESPs are used in the case
of syngas temperatures up to 400 °C
Tars and ashes with a high carbon
content generated in the raw syngas
are separated in cyclones and
recirculated to the gasifier, in the
case of low syngas temperature at
the gasifier outlet (<1100°C)
Syngas passes through a water
scrubber, downstream of other
dedusting
technique(s),
where
chlorides, ammonia, particles and
halides are separated
G
Technique
W
O
Syngas tars and ashes
b. recirculation to the
gasifier
c. Syngas washing
Applicability
Generally applicable for dust
removal. Bag filters and ESP are
applicable for syngas temperature
up to 400 °C
Generally applicable for dust
removal, in the case of a low
syngas temperature at the gasifier
outlet (1100 ºC)
Generally applicable, downstream
of other dedusting technique(s)
{This BAT conclusion is based on information given in Section 4.3.1.1}
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Chapter 10
BAT-associated emission levels
The BAT-associated emission levels for dust and particulate-bound metal emissions to air are
given in Table 10.57.
Table 10.57: BAT-associated emission levels (BAT-AELs) for dust and particulate-bound metals
emissions to air from IGCC plants
BAT-AELs
Hg (µg/Nm3)
(Average over the
sampling period
of samples
obtained during
one year)
Dust (mg/Nm3)
(yearly average)
Monitoring
frequency
R
ES
S
Combustion plant
total rated
thermal input
(MWth)
Sb+As+Pb+Cr+C
o+Cu+Mn+Ni+V
(mg/Nm3)
(Average over the
sampling period
of samples
obtained during
one year)
Dust: continuous
measurement
<1
< 0.12
0.4– < 2.5
Metals: periodic
measurements
once/yr
PR
O
< 0.025
G
≥ 100
W
O
R
KI
N
G
D
R
AF
T
IN
The associated monitoring is in BAT 3 ter.
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Chapter 10
10.8
Description of techniques
10.8.1
General techniques
Technique
Description
By switching to a different biomass The use of fuel with a low content
of potential pollution-generating compounds (e.g. lower sulphur, ash,
nitrogen, mercury, fluorine or chlorine content in the fuel), the
corresponding emissions are reduced
The replacement of part of a fuel with another fuel with a better
environmental profile (e.g. syngas from biomass gasification instead of
coal)
The use of a computer-based automatic system to control the
combustion efficiency and support the prevention and/or reduction of
emissions. This also includes the use of high-performance monitoring
Combination of primary measures: complete combustion, along with
good furnace design, fuel choice, multi-fuel firing, the use of high
performance monitoring and automated process control techniques, and
maintenance of the combustion system
Measures taken to maximise the efficiency of energy conversion, e.g. in
the furnace/boiler, while minimising emissions (in particular of CO).
This is achieved by a combination of techniques including good design
of the combustion equipment, optimisation of the temperature (e.g.
efficient mixing of the fuel and combustion air) and residence time in
the combustion zone, and/or use of advanced control system
Complete combustion, going along with good furnace design, the use of
high-performance monitoring and automated process control techniques,
and maintenance of the combustion system
Fuel choice
R
ES
S
Multi-fuel firing
PR
O
G
Process Advanced control
system
Techniques to increase energy efficiency
AF
10.8.2
T
IN
Complete combustion
Combustion optimisation
Ultra-supercritical steam
parameters
N
G
Supercritical steam parameters
Description
The uUse of a steam circuit, including double or triple steam reheat
systems, in which steam can reach pressures about 300 above 250–
300 bar and temperatures about 600 above 580–600 °C
The uUse of a steam circuit, including steam reheating systems, in
which steam can reach pressures above 220.6 bar and temperatures of
above 374 > 540°C
Recovery of heat mainly from the steam cooling for producing hot
water/steam which is used in industrial activities or in district heating.
Additional recovery are possible from:
 flue-gas
 grate cooling
 circulating bed
A CHP-ready plant will includeThe provisionmeasures taken to allow
the later export of a useful quantity of heat to an off-site heat load in a
way that will achieve at least a 10 % reduction in primary energy
usage when compared to the separate generation of the heat and
power produced. ItThis includes identifying and retaining access to
specific points in the steam system from which steam can be
extracted, as well as making sufficient space available to allow the
later fitting of items such as pipework, heat exchangers, extra water
demineralisation capacity, standby boiler plant and back-pressure
turbines. Balance of plant systems and control/instrumentation
systems are suitable for upgrade. Later connection of back-pressure
turbine(s) is also possible
Preheating water in the steam circuit with recovered heat from the
plant
Preheating combustion air by reusing part of the recovered heat
D
R
Technique
W
O
R
KI
Heat recovery by cogeneration
(CHP)
CHP readiness
Regenerative feed-water heating
Preheating of combustion air
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Advanced computerised control
system
Cooling tower discharge
Wet stack
Fuel specification in supplier
contract or internal document
Fuel drying (lignite, biomass,
peat)
Preheating of fuel by using recovered heat
G
Fuel preheating (gaseous, liquid
fuels)
Increased temperature and pressure of medium-pressure steam,
addition of low-pressure turbine, modification of blade geometry
See Section 10.8.1
Computerised control of the main combustion parameters in order to
improve the combustion efficiency and completeness
Air emission release through a cooling tower and not via a dedicated
stack
The dDesign of the stack in order to enable water vapour
condensation from the saturated flue-gas and thus to avoid using a
flue-gas reheater after the wet FGD
The fuel supplier or the internal management adheres to the moisture
(and size) specification in the contract or internal document
The moisture is reduced by means of recovered heat (steam or
flue-gas) or mechanical means (Press) to the level required (e.g. 40–
45 %) to achieve the optimal functioning of equipment (boiler, ESP),
improve combustion conditions, increase the overall energy efficiency
and avoid VOC direct emissions from the dryer
R
ES
S
Steam turbine upgrades
O
IN
Steam double reheat
PR
Flue-gas condenser
The flue-gas condenser is aA heat exchanger where water is preheated
by the flue-gases before it is heated in the steam condensers. The
vapour content in the flue-gases thus condenses as it is cooled by the
heating water. The flue-gas condenser is used both to increase the
energy efficiency of the combustion plant and to remove dust and SOX
from the flue-gas
Improved plant performance is possible by employing a double, rather
than single, steam reheat cycle
Combination of two or more thermodynamic cycles, e.g. a Brayton
cycle (gas turbine/combustion engine) with a Rankine cycle (steam
turbine/boiler), to convert heat loss from the flue-gas of the first cycle
to useful energy by subsequent cycle(s)
Process gas managementA systems that enables directing the fuel iron
and steel process gases that can be used as fuels (e.g. blast furnace,
coke oven, basic oxygen furnace gases) to be directed to the
combustion plants, depending on the availability of these fuels and on
the type of combustion plants in an integrated steelworks
See Section 10.8.1
D
R
Process gases management
system
AF
T
Combined cycle
W
O
R
KI
N
G
Combustion optimisation
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Chapter 10
Techniques to reduce emissions of NOX and/or CO to air
Technique
Fuel choice
Combustion
optimisation
Description
The useChoice of a fuel with low Nnitrogen content
See Section 10.8.1
O
T
IN
Flue-gas or exhaust-gas
recirculation
(FGR/EGR)
G
R
ES
S
Air staging (OFA)
The cCreation of several combustion zones in the combustion chamber with
different oxygen contents for controllingreducing NOX emissions and
ensuring complete an optimised combustion. The technique involves
sub-stoichiometric firing (i.e. with deficiency of air) into a primary
combustion zone and a second reburn combustion zone (running with excess
air) the addition of the remaining air or oxygen into the furnace to complete
improve combustion. Some old small boilers may require a capacity reduction to
allow the space for air staging.
Boosted OFA systems such as high pressure or multi-direction injection
systems enhance the effect of this technique by preventing the formation of
stratified laminar flow and enabling the entire furnace volume to be used
more effectively for the combustion process
Recirculation of part of the flue-gas to the combustion chamber to replace
part of the fresh combustion air, with the dual effect of cooling the flame
temperature and limiting the O2 content for nitrogen oxidation, thus limiting
the NOX generation. It implies the reinjection supply of waste flue-gas from
the furnace into the flame to reduce the oxygen content and therefore the
temperature of the flame. The use of special burners or other provisions is
based on the internal recirculation of combustion gases which cool the root of
the flames and reduce the oxygen content in the hottest part of the flames
The technique (including ultra- or advanced-low-NOX burners) is based on
the principles of reducing peak flame temperatures; boiler burners are
designed to delay but complete improve the combustion and increase the heat
transfer (increased emissivity of the flame). The air/fuel mixing, reduces the
availability of oxygen, and reduces the peak flame temperature thus retarding
the conversion of fuel-bound nitrogen to NOX and the formation of thermal
NOX, while maintaining high combustion efficiency. It may be associated
with a modified design of the furnace combustion chamber. The design of
ultra- or advanced-low-NOX burners (ULNB) includes combustion staging
(air/fuel) and flue-gas recirculation. Dry low-NOX burners (DLN) are used in
gas turbines The performance of the technique may be influenced by the
boiler design when retrofitting old plants
Gas turbine burners that include the pre-mixing of the air and fuel before
entering the combustion zone. By mixing air and fuel before combustion, a
homogeneous temperature distribution and a lower flame temperature are
achieved, resulting in lower NOX emissions
The technique consists of a combination of internal engine modifications, e.g.
combustion and fuel injection optimisation (In diesel engines, the central
element of the ‘low NOX combustion’ concept is the very late fuel injection
timing in combination with early inlet air valve closing), cycle
optimisation.turbo-charging or Miller cycle
The control of the peak flame temperature through lean-burn conditions is the
primary combustion approach to limiting NOX formation in gas engines. Lean
combustion decreases the fuel/air ratio in the zones where NO X is
producedgenerated so that the peak flame temperature is less than the
stoichiometric adiabatic flame temperature, therefore suppressingreducing
thermal NOX formation. The optimisation of this concept is called 'advanced
lean-burn concept' and is still not applicable to dual fuel engines due to
misfiring problems
The technique is based on the reduction of the flame temperature or localised
hot spots by creation of several combustion zones in the combustion chamber
with different injection levels of fuel and air. The retrofit may be less efficient
in the case of smaller plants than in larger plants : a low impulse primary
flame is developed in the port neck; a secondary flame covers the root of the
primary flame reducing its core temperature
PR
10.8.3
N
Dry low-NOX burners
(DLN)
G
D
R
AF
Low-NOX burners
(LNB)
O
R
KI
Low-NOX combustion
concept in diesel
engines
W
Lean-burn concept and
advanced lean-burn
concept
Fuel staging
(reburning)
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Combined SNCR +
SCR
Water or steam is are used as a diluents for reducing the combustion
temperature in gas turbines, engines or boilers and the thermal NOX
formation, either by being premixed with the fuel prior to its combustion (fuel
emulsion, humidification or saturation) or directly injected in the combustion
chamber (water/steam injection)
The technique is mainly based on the following features:
 minimisation of air leakages into the furnace
 careful control of air used for combustion
 modified design of the furnace combustion chamber
The uUse of complex and integrated abatement techniques for combined
reduction of NOX, SOX, and often other pollutants, from the flue-gas, e.g.
activated carbon, DESONOX processes
T
See Ssection 10.8.2
In diesel engines, the central element of the ‘low NOX combustion’ concept is
the very late fuel injection timing in combination with cycle optimisation, e.g.
thanks to late exhaust valve closing in new two-stroke engine
The uUse of catalystscatalytic converter (that contain precious metals in
general such as palladium or platinum) where anto oxidising reaction converts
oxidise carbon monoxide (CO) and unburnt hydrocarbons (HC) with oxygen
to form CO2 and water vapour, using the O2 contained in the flue-gas
Fluidised bed combustion takes place with the injection of fuel into a hot
turbulent bed, where combustion air has also been injected from the bottom of
the fluidised bed boiler by fluidisation of the bed. The bed (sand) of particles,
including fuel (between 1 and 3 % of the bed material), ash and sorbents, is
fluidised by upwards flowing air in a furnace, and the bed temperature allows
the fuel to burn. Due to the combustion temperatures of about 750–950 ºC
and the long residence time, the burnout of the fuel is very high and,
therefore, the related emissions of combustion products are relatively low. In
CFB boilers, the small size of the bed particles induces their transportation
through the furnace to the second pass of the boiler. These particles exiting
the furnace are separated from the flue-gas flow by a cyclone or by other
separation methods, and recirculated back to the fluidised bed
D
R
Combined techniques
for NOX and SOX
reduction
Advanced
computerised process
control system
AF
Low excess air
IN
PR
Water/steam addition
Combination of the SNCR and SCR techniques
R
ES
S
Selective non-catalytic
reduction (SNCR)
Selective reduction of nitrogen oxides with ammonia or urea in the presence
of a catalyst. The technique is based on the reduction of NO X to nitrogen in a
catalytic bed by reaction with ammonia (in general aqueous solution) at an
optimum operating temperature of around 300–450 °C. Several One or two
layers of catalyst may be applied. A higher NOX reduction is achieved with
the use of higher amounts of catalystseveral layers of catalyst (two layers).
The technique design can be modular, special catalyst can be used and/or
preheating can be used to cope with low loads or with a broad flue-gas
temperature window. 'In-duct' or 'slip' SCR is a technique that combines
SNCR with downstream SCR which reduces ammonia slip from the SNCR
unit
Selective reduction of nitrogen oxides with ammonia or urea without catalyst.
The technique is based on the reduction of NOX to nitrogen by reaction with
ammonia or urea at a high temperature. The operating temperature window is
maintained between 900850 °C and 10501000 °C for optimal reaction
G
Selective catalytic
reduction (SCR)
Combination of primary techniques: e.g. air staging including boosted
overfire air, fuel staging, flue-gas recirculation, LNB
O
Combination of
primary techniques for
NOX reduction
G
Low-NOX combustion
concept in engines
Circulating fluidised
bed boiler (CFB
boilers)
W
O
R
KI
N
Oxidation catalysts
Reduction of the
combustion air
temperature
Use combustion air at ambient temperature. The combustion air is not
preheated in a regenerative air preheater
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Chapter 10
Techniques to reduce emissions of SOX, HCl and/or HF to
air
Technique
Fuel choice
Multi-fuel firing
Duct Dry sorbent injection
(DSI)
PR
Circulating fluidised bed (CFB)
dry scrubber
G
R
ES
S
Boiler sorbent injection
(in-furnace or in-bed)
Description
The useChoice of a fuel with low S, Cl and F sulphur, chlorine and/or
fluorine content
The rReplacement of part of a fuel with another fuel with a better
environmental profile (e.g. coal – biomass, coal – syngas from
biomass gasification, instead of coal only)
Boiler sorbent injection consists of tThe direct injection of a dry
sorbent into the gas stream of the combustion chamber, or of the
adjunction of magnesium- or calcium-based adsorbents to the bed of a
fluidised bed boiler. The surface of the sorbent particles reacts with
the SO2 in the flue-gas or in the fluidised bed boiler
The injection and dispersion of a dDry powder sorbent is introduced
and dispersed in the flue-gas stream. The materialsorbent (e.g. trona,
sodium bicarbonate, hydrated lime) reacts with acid gases (e.g. the
sulphur gaseous sulphur species, HCl) to form a solid which has to be
is removed by filtration (bag filter or electrostatic precipitator)
Flue-gas from the boiler air preheater enters the CFB absorber at the
bottom and flows vertically upwards through a venturi section where
a solid sorbent and water are injected separately within the flue-gas
stream
A suspension/solution of alkaline reagent is introduced and dispersed
in the flue-gas stream. The material reacts with the sulphur gaseous
sulphur species to form a solid which has to beis removed by filtration
(bag filter or electrostatic precipitator)
Technique or ensemblecombination of scrubbing techniques where by
which sulphur is removed from flue-gases through various processes
generally involving an alkaline sorbent for capturing SO2 and
transforming it into solid sulphur. In the wet scrubbing process,
gaseous compounds are dissolved in a suitable liquid (water or
alkaline solution). Simultaneous removal of solid and gaseous
compounds may be achieved. Downstream of the wet scrubber, the
flue-gases are saturated with water and thea separation of the droplets
is required before discharging the flue-gases. The resulting liquid has
to be is treated by a waste water process and the insoluble matter is
collected by sedimentation or filtration
A specific non-regenerative type of scrubbing using the alkalinity of
the seawater as a solvent where a large amount of seawater is
available. Requires Generally requires an upstream abatement of dust
Use of complex and integrated abatement techniques for combined
reduction of NOX, SOX, and often other pollutants, from the flue-gas,
e.g. activated carbon, DESONOX processes
Use of a liquid, typically water or a water-based solution, to capture
the acidic gas by absorption from the flue-gas
Replacement of the gas-gas heater downstream of the wet FGD by a
multi-pipe heat extractor in order to avoid SOX leakage, or remove it
and discharge the flue-gas via a cooling tower or a wet stack
See Section 10.8.2
See Section 10.8.2
O
10.8.4
G
D
R
Wet flue-gas desulphurisation
(Wet FGD)
AF
T
IN
Spray-dry absorber (SDA)
N
Seawater FGD
KI
Combined techniques for NOX
and SOX reduction
O
R
Wet scrubbing
W
Retrofit gas/gas heater
Flue-gas (FG) condenser
Process gas management system
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Techniques to reduce emissions of dust and/or metals
including mercury to air
Technique
Fuel choice
Cyclones
R
ES
S
Electrostatic precipitator
(ESP)
G
Bag of Fabric filter
See general description in Section 10.8.4. There are Cco-benefits in the
form of dust/ and metals emissions reduction
Mercury absorption by carbon sorbents, such as activated carbon, with or
without chemical treatment. The sorbent injection system can be
enhanced by the addition of a supplementary bag filter
AF
Dry or semi-dry FGD system
(e.g. SDA, DSI)
Wet flue-gas
desulphurisation (FGD)
Wet FGD (WFGD)
Carbon sorbent (e.g.
activated carbon) injection in
the flue-gas
IN
Boiler sorbent injection
PR
O
Activated carbon injection
Techniques to reduce emissions to water
D
R
10.8.6
Description
The useChoice of a fuel with low ash or metals (e.g. mercury) content
Dust control system using gravitational forces and which is able to
process all types of flue-gases, in dry conditions
Electrostatic precipitators operate such that particles are charged and
separated under the influence of an electrical field. Electrostatic
precipitators are capable of operating under a wide range of conditions.
Abatement efficiency may depend on the number of fields, residence time
(size), catalyst properties, and upstream particle removal devices. They
include in general between two to five fields for an improved efficiency.
Most modern (high-performance) ESPs have up to seven fields
Bag or fabric filters are constructed from porous woven or felted fabric
through which gases are flowed passed to remove particles. The use of a
bag filter requires a fabric materialthe selection of a fabric suitable
adequate to for the characteristics of the flue-gas and the maximum
operating temperature
This process is based on the adsorption of pollutant molecules by the
activated carbon. When the surface has adsorbed as much as it can, the
adsorbed content is desorbed as part of the regeneration of the adsorbent
See general description in Section 10.8.4. There are Cco-benefits in the
form of dust/ and metals emissions reduction
See general description in Section 10.8.4. There are Cco-benefits in the
form of dust/ and metals emissions reduction
T
10.8.5
G
Technique
R
KI
N
Adsorption on activated carbon
W
O
Aerobic biological treatment
Anoxic/anaerobic biological
treatment
Description
The removal of soluble substances (solutes) from the waste water by
transferring them to the surface of solid, highly porous particles (the
adsorbent). Activated carbon is typically used for the adsorption of
organic compounds and mercury
The biological oxidation of dissolved organic substances with oxygen
using the metabolism of microorganisms. In the presence of dissolved
oxygen – injected as air or pure oxygen – the organic components are
mineralised into carbon dioxide, water or other metabolites and
biomass. Under certain conditions, aerobic nitrification also takes
place whereby microorganisms oxidise ammonium (NH 4+) to the
intermediate nitrite (NO2-), which is then further oxidised to nitrate
(NO3-)
The biological reduction of pollutants using the metabolism of
microorganisms (e.g. nitrate (NO3-) is reduced to elemental gaseous
nitrogen, oxidised species of mercury are reduced to elemental
mercury).
The anoxic/anaerobic treatment of waste water from the use of wet
abatement systems is typically carried out in fixed-film bioreactors
using activated carbon as a carrier
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Chapter 10
R
ES
S
Coagulation and flocculation
Flocculation, sedimentation,
precipitation, neutralisation
Coagulation and flocculation are used to separate suspended solids
from waste water and are often carried out in successive steps.
Coagulation is carried out by adding coagulants with charges opposite
to those of the suspended solids. Flocculation is carried out by adding
polymers, so that collisions of microfloc particles cause them to bond
thereby producing larger flocs
The suspended matter can consist of large solids, settleable by gravity
alone without any external aids, and non-settleable material, often
colloidal in nature. Removal is then generally accomplished by
coagulation, flocculation, and sedimentation. Precipitation is the
formation of insoluble substances from dissolved matter and the
chemicals added
The removal of ionic pollutants from waste water by crystallising them
on a seed material such as sand or minerals, working in a fluidised bed
process. Some combustion plants use crystallisation after evaporation
(see BAT 10)
Evaporation of waste water is a distillation process where water is the
volatile substance, leaving the concentrate as bottom residue to be
disposed of. Crystallisation is closely related to precipitation. In
contrast to precipitation, the precipitate is not formed by chemical
reaction in the waste water, but is produced on seed material such as
sand or minerals, working in a fluidised-bed process
The separation of solids from waste water by passing them through a
porous medium. It includes different types of techniques, e.g. sand
filtration, microfiltration and ultrafiltration
The separation of solid or liquid particles from waste water by
attaching them to fine gas bubbles, usually air. The buoyant particles
accumulate at the water surface and are collected with skimmers
Flotation techniques are used to separate large flocs or floating
particles from the effluent by bringing them to the surface of the
suspension
The removal of ionic pollutants from waste water and their
replacement by more acceptable ions by transferring them to an ion
exchange resin. The pollutants are temporarily retained and afterwards
released into a regeneration or backwashing liquid
The adjustment of the pH of the waste water to the neutral pH level
(approximately 7) by adding chemicals. Sodium hydroxide (NaOH) or
calcium hydroxide (Ca(OH)2) is generally used to increase the pH;
whereas, sulphuric acid (H2SO4), hydrochloric acid (HCl) or carbon
dioxide (CO2) is used to decrease the pH. The precipitation of some
substances may occur during neutralisation
The removal of free oil from waste water by mechanical treatment
using devices such as the American Petroleum Institute separator, a
corrugated plate interceptor, or a parallel plate interceptor. Oil/water
separation is normally followed by flotation, supported by
coagulation/flocculation. In some cases, emulsion-breaking may be
needed prior to oil/water separation
The conversion of pollutants by chemical oxidising agents to similar
compounds that are less hazardous and/or easier to abate. In the case
of waste water from the use of wet abatement systems, air may be used
to oxidise sulphite (SO32-) to sulphate (SO42-)
The conversion of dissolved pollutants into insoluble compounds by
adding chemical precipitants. The solid precipitates formed are
subsequently separated by sedimentation, flotation, or filtration. If
necessary, this may be followed by microfiltration or ultrafiltration.
Typical chemicals used for metal precipitation are lime, dolomite,
sodium hydroxide, sodium carbonate, sodium sulphide and
organosulphides. Calcium salts (other than lime) are used to
precipitate sulphate or fluoride
PR
O
G
Crystallisation Softening,
evaporation, crystallization
IN
Filtration
AF
T
Flotation
D
R
Ion exchange
N
G
Neutralisation
O
R
KI
Oil/water separation
W
Oxidation
Precipitation
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Chapter 10
Sedimentation
W
O
R
KI
N
G
D
R
AF
T
IN
PR
O
G
R
ES
S
Stripping, precipitation
The separation of suspended solids by gravitational settling
Sedimentation is a solid-liquid separation technique that utilises
gravity to separate the insoluble metal complexes and solid particles
from the liquid effluent
The removal of volatile pollutants (e.g. ammonia) from waste water by
bringing them into contact with a high flow of a gas current in order to
transfer them to the gas phase. The pollutants are removed from the
stripping gas in a downstream treatment and may potentially be
reusedWaste water stripping is an operation in which waste water is
brought into contact with a high flow of a gas current in order to
transfer volatile pollutants from the water phase to the gas phase. The
pollutants are removed from the stripping gas so it can be recycled into
the process and reused
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