Informal Document 7 EGTEI Guidance-Document On Stationary Sources Tracked Changes Compared With WGSR Version
Informal Document 7 EGTEI Guidance-Document On Stationary Sources Tracked Changes Compared With WGSR Version
Informal Document 7 EGTEI Guidance-Document On Stationary Sources Tracked Changes Compared With WGSR Version
th
50 Working Group on Strategies and Review – 10 to 14 September 2012
Prepared by EGTEI
Ni Nickel
Mn Manganese
Mo Molybdenum
MSW Municipal solid waste
MW Mega Watt
MWth Mega Watt Thermal
MWe Mega Watt Electric
3
µg/Nm Microgramme per normal cubic metre
µm Micrometer
N2 Nitrogen
NaHCO3 Sodium bicarbonate
NOx Nitrogen oxide
NFM Non ferrous metal
NMVOC Non-methane volatile organic compounds
O2 Oxygen
OC Organic Carbon
OFA Over Fire Air
OSK Other shaft kiln
PAH Polycyclic aromatic hydrocarbon
PCDD/F polychlorinated dibenzodioxin/furan
PCDF Polychlorinated dibenzofurans
PFBC Pressurized fluidized bed combustion
PFRK Parallel flow regenerative kiln
PM Particulate matter
PM2,5 Particulate matter (2,5 micrometer)
PM10 Particulate matter (10 micrometer)
ppm Parts per million
PRK Pre-heater rotary kiln
RAINS Regional Air Pollution Information and Simulation
RAP Reduced air preheat
SCR Selective Catalytic Reduction
SG Spark Gas (engines)
SNCR Selective non-catalytic reduction
SRA Sulphur Reducing Additives
SRU Sulphur Recovery Unit
SO2 Sulphur dioxide
TA-LUFT Technische Anleitung zur Reinhaltung der Luft (Technical Instructions on Air
Quality Control)
TCC Thermal catalytic cracking
TOC Total organic carbon
TSP Total Suspended Particles
UNECE United Nations Economic Commission for Europe
UNEP United Nations Environment Programme
VOC Volatile Organic Compound
WMO World Meteorological Organisation
CONTENT
1 Introduction 117
6 General issues for dust (including PM10, PM2,5 and BC). 3935
6.1 General issues 3935
6.2 Fuel switching 4440
6.3 Fuel cleaning 4440
Acronyms used
The following acronyms are used throughout the guidance document:
BAT Best available technique Mis en forme : Taquets de
tabulation : Pas à 1.5 cm + 4 cm
BC Black carbon
BREF Best available technique reference document
Dust Used in the same way as TSP
ELV Emission limit value
ESP Electrostatic precipitator
FF Fabric Filter
FGD Flue gas desulphurisation
IGCC Integrated gasification combined-cycle
3
Nm Cubic meter at standard conditions (101,325 kPa and 273.15 K)
TSP Total Suspended Particles
SCR Selective Catalytic Reduction
SNCR Selective Non-Catalytic Reduction
VOCs In the context of the Gothenburg Protocol, all organic compounds of an Mis en forme : Retrait : Gauche : 0
anthropogenic nature, other than methane, that are capable of producing photochemi cal oxidant by cm, Espace Avant : 3 pt, Taquets de
tabulation : Pas à 1.5 cm + 14.75 cm
reaction with nitrogen oxides in the presence of sunlight
1 Introduction
The aim of this document is to provide the Parties to the Convention on Long-Range Transboundary
Air Pollution with guidance on identifying best abatement options, with particular reference to best
available techniques (BAT) to enable them to meet the obligations of the Protocol to abate
Acidification, Eutrophication, Ground Level Ozone and dust (including PM10, PM2,5 and BC).
This guidance document addresseslists control options for the following pollutants:
the control options for NOx emissions defined as the sum of nitric oxide (NO) and nitrogen
dioxide (NO2) expressed as nitrogen dioxide (NO2),
the control options of sulphur emissions considered including as all sulphur compounds
expressed as sulphur dioxide (SO2).
the control options of VOC emissions considered defined as all organic compounds of an
anthropogenic nature, other than methane, that are capable of producing photochemical oxidant
by reaction with nitrogen oxides in the presence of sunlight.
the control options of particulate matter (PM) emissions consisting of a mixture of particles
suspended in the air including dust or Total Suspended Particulate Matter (TSP) , (including
PM10, PM2.5 and black carbon (BC)) whose definitions are as follows:
- PM2.5 : particles with an aerodynamic diameter equal to or less than 2.5 microns (µm);
- PM10: particles with an aerodynamic diameter equal to or less than 10 microns (µm);
- Dustdust or TSP: for the purpose of the guidance document “dust” and “total suspended
particulate matter” (TSP) means the mass of particles, of any shape, structure or density,
dispersed in the gas phase at the sampling point conditions which may be collected by filtration
under specified conditions after representative sampling of the gas to be analyzed, and which
remain upstream of the filter and on the filter after drying under specified conditions .
- black carbon (BC): carbonaceous particulate matter that absorbs light.
In the context of this guidance document, dust and TSP have the same meaning. As can be seen from
chapter 6, abatement techniques for dust in general also provide high removal efficiency for PM 10, and
in some cases, PM2.5. However, some measures will reduce coarse particles much more efficiently
than finer particles such as PM2.5; therefore, specific measures targeting PM2.5 and BC are necessary.
As monitoring data for specific fractions of particulate matter such as PM 2.5 and PM10 are in general
not presently available, emission levels are defined for dust.
The expression “Best available techniques” means the most effective and advanced stage in the
development of activities and their methods of operation which indicate the practical suitability of
particular techniques for providing the basis for emission limit values and other permit conditions
designed to prevent and, where that is not practicable, to reduce emissions and the impact on the
environment as a whole:
(a) “techniques” includes both the technology used and the way in which the installation is designed,
built, maintained, operated and decommissioned,
(b) “available” techniques means those developed on a scale which allows implementation in the
relevant industrial sector, under economically and technically viable conditions, taking into
consideration the costs and advantages, whether or not the techniques are used or produced inside
the Member State in question, as long as they are reasonably accessible to the operator,
(c) “best” means most effective in achieving a high general level of protection of the environment as a
whole.
Criteria for determining BAT are as follows:
1. the use of low-waste technology;
2. the use of less hazardous substances;
3. the furthering of recovery and recycling of substances generated and used in the process and
of waste, where appropriate;
4. comparable processes, facilities or methods of operation which have been tried with success
on an industrial scale;
5. technological advances and changes in scientific knowledge and understanding;
6. the nature, effects and volume of the emissions concerned;
7. the commissioning dates for new or existing installations;
8. the length of time needed to introduce the best available technique;
9. the consumption and nature of raw materials (including water) used in the process and
energy efficiency;
10. the need to prevent or reduce to a minimum the overall impact of the emissions on
the environment and the risks to it;
11. the need to prevent accidents and to minimize the consequences for the environment;
12. information published by national and international organisations.
This guidance document presents BAT Associated Emission Levels (AELs) which can be described as
follows:
BAT AELs are levels that an operator can expect to achieve when using the BAT, and are
appropriate reference points to assist in the determination of permit conditions,
BAT AELs represent average emission levels achievable during a substantial period of time in
normal operating and/or design conditions (well-proven technology),
BAT AELs are neither emission nor consumption limit values.
BAT AELs are based on normal operating conditions and may vary with changing input materials or
for varying outputs.
The BATAELs are based on a range of averaging periods and represent a typical load situation.
Therefore, when taking account of BATAELs in the context of ELV setting, proper regard must always
be given to the reference period to which the described BATAEL pertains. For peak load, start up and
shut down periods, as well as for operational problems of the flue gas cleaning systems, short-term
peak values, which could be higher, have to be regarded.
Where a level is described as "achievable" using a particular technique or combination of techniques,
this should be understood to mean that the level may be expected to be achieved over a substantial
period of time in a well maintained and operated installation or process using those techniques.
Unless otherwise indicated, the reduction measures listed are considered, on the basis of operational
experience of several years in most cases, to be the most well-established and economically feasible
3
best available techniques. BAT Associated Emission Levels are generally expressed in mg/m (dry
gas, 273.15K and 101.325 kPa except is stipulated different) as daily average. For organic solvent
uses they can be expressed in % of solvents used (solvents purchased + solvents internally recycled).
The continuously expanding experience with low-emission measures and technologies at new plants
as well as with the retrofitting of existing plants will necessitate regular review of this document.
Although this guidance document lists a number of measures and technologies, spanning a wide
range of costs and efficiencies, it cannot be considered as an exhaustive statement of control options.
Moreover, the choice of control measures and technologies for any particular case will depend on a
number of factors, including current legislation and regulatory provisions and, in particular, control
technology requirements, primary energy patterns, industrial infrastructure, economic circumstances
and specific in-plant conditions.
This guidance document provides options and techniques, along with their performance assessment
for emission prevention and reduction of Sulphur, NOx, VOCs, dust (including PM10, PM2,5 and BC).
However, the reduction of a given pollutant cannot be considered without taking into account the risk
of generating other pollutants and/or increasing energy consumption. It is worthwhile to consider them
together along with such other pollutant-specific control options in order to maximize the abatement
effect and minimize the impact on the environment. Respective co-benefit/trade-off between different
pollutants have to be carefully accounted for. This is particularly important for multi-pollutant/multi-
effect approach where positive/negative effects on the reduction of Greenhouse Gases (GHGs) are
possible (For example, measures that improve the efficiency of combustion will generally reduce both
BC and CO2)..
This guidance document provides options and techniques, along with their performance assessment
for emission prevention and reduction of Sulphur, NO x, VOCs, dust (including PM10, PM2,5 and BC).
Performance and costs are documented in a series of documents elaborated by EGTEI, in the draft
background document submitted to the UNECE Task Force on Heavy Metals (TFHM) of 2006, the EU
Commission with the different Best Available Reference documents (BREF) and other recent
publications, US EPA reports and a series of documents acknowledged nationally or internationally.
In this document, both primary and secondary measures are considered. Primary reduction measures
aim at reducing pollutant emissions at their sources of formation. Secondary measures aim at treating
waste gases containing already formed pollutants (add-on or end of pipe technologies).
This guidance document covers the stationary sources emitting Sulphur, NOx, VOCs, dust (including
PM10, PM2,5 and BC) listed in table 1. Mobile sources (road traffic, non road traffic and off road
machineries) are covered by the guidance document on mobile sources. Some stationary sources are
not covered by this guidance document but may be significant sources of BC for some countries, such
as agricultural burning, open biomass burning, flares in gas and petroleum extraction, existing
stationary diesel engines.
Table 1: stationary sources for emissions of sulphur, NOx, VOCs, dust (including PM10, PM2,5
and BC) covered by this guidance document
Table 1: stationary sources for emissions of sulphur, NOx, VOCs, dust (including PM10, PM2,5
and BC) covered by this guidance document
Acronyms used
The following acronyms are used throughout the guidance document:
BAT Best available technique Mis en forme : Taquets de
tabulation : Pas à 1.5 cm + 4 cm
BC Black carbon
BREF Best available technique reference document
Dust Used in the same way as TSP
ELV Emission limit value
ESP Electrostatic precipitator
FF Fabric Filter
FGD Flue gas desulphurisation
IGCC Integrated gasification combined-cycle
3
Nm Cubic meter at standard conditions (101,325 kPa and 273.15 K)
TSP Total Suspended Particles
SCR Selective Catalytic Reduction
SNCR Selective Non-Catalytic Reduction
VOCs In the context of the Gothenburg Protocol, all organic compounds of an anthropogenic Mis en forme : Retrait : Gauche : 0
nature, other than methane, that are capable of producing photochemical oxidant by reaction with cm, Première ligne : 0 cm, Taquets de
tabulation : Pas à 1.5 cm + 4 cm
nitrogen oxides in the presence of sunlight
In the framework of modern automated monitoring systems and process control equipment, reporting
does not create a problem. The collection of data for further use is a state-of-the-art technique.
However, data to be reported to competent authorities differ from case to case. To obtain better
comparability, data sets and prescribing regulations should be harmonized. Harmonization is also
desirable for quality assurance of measuring and monitoring systems. This should be taken into
account when comparing data.
To prevent discrepancies and inconsistencies, key issues and parameters, including the following,
must be well defined:
3
(a) definition of standards expressed as ppmv, mg/Nm , g/GJ, kg/h or kg/Mg of product. Most of
these units need to be calculated and need specification in terms of gas temperature,
humidity, pressure, oxygen content or heat input value;
(b) definition of the period over which standards are to be averaged, expressed as hours, months
or a year, and of the measuring method;
(c) definition of failure times and corresponding emergency regulations regarding bypass of
monitoring systems or shutdown of the installation;
(d) definition of methods for backfilling data missed or lost as a result of equipment failure;
(e) definition of the parameter set to be measured. Depending on the type of industrial process,
the necessary information may differ. This also involves the location of the measurement point
within the system.
Quality control of measurements has to be ensured.
BAT is the optimisation of the combustion and steam systems but also the systems for compressed
air, pumping, heating, cooling, ventilation, lighting, and other physical and chemical processes using a
large number of techniques. Of particular importance are also heat recovery and cogeneration if
reasonable [from [1]].
Besides energy management which focuses more on the demand side, the supply side for energy has
also a large impact on air emissions. Besides fuel switch where one (fossil) fuel is replaced by another
also a change in the energy mix should be considered taking into account country specific conditions
such as infrastructure, energy policy and availability of resources of fossil fuels and renewable energy
like wind power, solar energy, geothermal energy or biomass. Burning more biomass, especially in
stoves, may, however, also lead to increasing air emissions.
SO2 is a major contributor to acidification, via the formation in the atmosphere, of sulphate and
sulphuric acid. SO2 residence time in atmosphere depends on meteorological conditions. The average
residence time is about 3 to 5 days, hence SO 2 can be transported over hundred kilometres.
To achieve the most efficient SOx emission reduction, beyond energy management measures, a
combination of measures should be considered.
Sulphur present in fuels reacts with oxygen contained in combustion air to form SO2. Therefore SO2
emissions arising from combustion are directly related to the sulphur content of fuels used. SO 3 is
produced by oxidation of SO2, during combustion.
Sulphur content of solid fossil fuels ranges from 0.5 % to more than 5 %. Solid fossil fuels are the
largest sources of SO2 [1]. Sulphur content of natural gas is very low as well as sulphur content of
wood. Sulphur content of liquid fossil fuels ranges from 0.001 % to more than 5 %. The availability of
low sulphur content liquid fossil fuels requires the removal of sulphur at the refinery and the adoption
of specific processes.
During the last decade, national and European legislation have toughened the limits required for the
sulphur content of petroleum products. The table 2 presents the typical limit values applied for liquid
fuels in the EU [2].
consumes more energy and requires higher investments. Sulphur content of refinery products needs
to correspond to the restricted value ordered by the EU and provided in table 2. Current technologies
to clean hard coal can remove approximately 50% of the inorganic sulphur (depending on coal
properties) but none of the organic sulphur. More effective technologies are being developed.
However, they require higher specific investments. Thus the efficiency of sulphur removal by coal
cleaning is limited compared to flue gas desulphurisation. There may be a country-specific
optimisation potential for the best combination of fuel cleaning and flue gas cleaning.
Combustion modifications comparable to the measures used for NOx emission control do not exist, as
during combustion the organically and/or inorganically bound sulphur is almost completely oxidized. A
certain percentage, depending on the fuel properties and combustion technology, is retaine d in the
ash. The amount of sulphur retained in ash, can be influenced by added sorbents (e.g. lime/limestone)
and combustion conditions (e.g. temperature). In this guidance document dry additive processes for
conventional boilers are considered as process modifications due to the injection of an agent into the
combustion unit. However, experience has shown that, when applying these processes, thermal
capacity is lowered, and the Ca/S ratio is relatively high and sulphur removal low. In recent years, the
performance of these processes has nevertheless been optimized to the point that SO 2 removal
efficiency reached 50 - 80%. Problems with the further use of the by-product have to be considered.
These processes aim at removing already formed sulphur oxides, and are considered as secondary
measures. Sulphur removal using wet, dry or semi-dry processes are used to treat the flue gases.
Sulphur can also be removed using the recovery of sulphur dioxide from the flue gases. It is then
either extracted (regenerative process) or converted into sulphuric acid (sulphuric acid plant). Flue gas
scrubbing using water or seawater is another available technology to reduce SO 2 emissions.
In wet scrubbing technologies, the flue gas is first dedusted then cleaned by an atomized solution of
alkaline compounds. SO2 reacts with these alkaline compounds to form by products, whose chemical
nature depends on the alkaline compound used. In the case of use CaCO3 or CaO, by products may
be upgraded as gypsum if some technical conditions are achieved. By products can also be upgraded
using other scrubbing agent. With wet FGD, excellent efficiencies can be achieved ranging from 92 to
98% with a near-stoichiometry Ca/S ratio. This process is mainly used for reducing SO 2 emissions
from coal power plants.
In the dry process, a calcium or sodium based sorbent is injected in solid form into the flue gases
before a fabric filter or an ESP. Hydrated lime (Ca(OH) 2) or sodium bicarbonate (NaHCO3) are the
most frequently used sorbents. Sorbents need to be very reactive and are activated for this purpose
(finely ground CA(OH)2 with high activity as example). They react with SO2 to form calcium or sodium Mis en forme : Indice
sulphites and sulphates, which need then to be filtered in order to reduce dust emissions. The dry duct
injection process efficiency is lower than with wet FGD (about 50 % ) and depends on several
parameters such as temperature, SO2 content of the flue gas, Ca/S ratio and residence time.
Furnace sorbent injection is a direct injection of a dry sorbent in the gas stream of the boiler furnace.
Pulverised limestone is used (CaCO3). Calcium sulphites and sulphates formed need to be captured
by FF or ESP. Efficiencies from 70 to 80 % may be obtained according to the arrangement used [4].
The semi-dry process or spray dry scrubbing is similar to the dry process and also produces a solid
residue. It uses moisturised lime or limestone containing about 10% of water to enhance the contact
and the reactions. The removal SO2 efficiency ranges from 85 to 92% with a ratio Ca/S from 1.3 to 2
[4].
In sulphuric acid production, SO2 is first oxidised to SO3 which is absorbed to form sulphuric acid. The
sulphuric acid production process can include a single absorption stage or a double one depending on
the conversion rate to be achieved. Double absorption sulphuric acid plant is more effective.
Flue gas desulphurisation is a high capital cost process best suited to high load factor plant.
The following table presents general results for several flue gas desulphurisation processes.
Table 3: general description and performance for selected flue gas desulphurisation processes
[3]
Acid sulphuric
Regenerative
Wet scrubbing Dry scrubbing plant (double
process
absorption)
Desulphurisation
Desulphurisation rate of 50 % to 80%
rate of 95 % to depending on the
Recovery rate of Conversion rate of
Efficiency 98%) for a Ca/S Ca/S ratio and
95-98 % > 99%
ratio from 1.02 to systems (dry duct
1.1 injection or furnace
injection)
Gypsum can be
obtained under
certain conditions Calcium sulphite
By-product and can be suitable and sulphate not
for use in recoverable
plasterboard
production
Inlet dust
concentration
Not cost effective, 3
< 30 mg/Nm
Possible problem of large amount of
Limits Inlet O2
scaling waste to be treated
accordingly concentrations to be
5 times higher than
SO2 concentrations.
To achieve the most efficient process for sulphur emission reductions beyond the energy management
measures listed above, a combination of technological options identified in the paragraphs above
should be considered. In some cases, options for reducing sulphur emissions may also reduce
emissions of NOx and other pollutants.
Costs are an important issue when selecting SO2 emission reduction techniques. The following
expenses may be relevant:
imputed depreciation allowance and imputed interest,
labour costs,
expenses for auxiliary and operating materials,
energy costs,
maintenance and repair costs, expenditure on monitoring, expenses for external services,
taxes, environmental levies (e.g. charges for waste water), fees, public charges.
Costs increase in general less than the capacity of the reduction technique so that larger units are
often more cost-effective or unit with higher flue gas sulphur content. Dry additive processes are less
cost effective for high sulphur content fuels compared to wet scrubbing processes.
Side effects of emission abatement options/techniques can be positive or negative and should be
accounted for.
Options that lead to usable by-products should be selected, as should options that lead to increased
thermal efficiency and reduced waste whenever possible. Although most by-products such as gypsum,
ammonia salts, sulphuric acid or sulphur, are usable or recyclable products, factors such as market
conditions and quality standards need to be taken into account.
Side effects can generally be limited by properly designing and operating the facilities. Side effects
include
impacts on energy consumption and hence greenhouse gas emissions,
impacts on other air pollutants,
impacts on the use of natural resources such as limestone,
cross-media effects, e.g. on waste or water.
More particularly, the following table presents positive and negative side effects for selected flue gas
desulphurisation processes.
Table 4: positive and negative side effects for selected flue gas desulphurisation processes
In the following paragraphs, an overview on available primary measures is given. Their applicability
depends on the industrial sector and the production process.
Reducing peak temperature: As thermal NOx formation depends largely on the combustion
temperature, a reduction in temperature is one option to reduce NOx formation. Reducing peak
temperature can be achieved by the following methods i) diluting the heat produced during the
combustion process, ii) cooling down, and iii) reducing the oxygen available for combustion [1] but
also by applying other combustion techniques like fluidized bed combustion (FBC) which operates at
lower temperatures and includes an inherent air-staging. Main methods for reducing peak temperature
are:
substoichiometric combustion, i.e. using a fuel-rich mixture so that oxygen is a limiting factor
(fuel acts also as reducing agent),
suprastoichiometric combustion, i.e. using a fuel-lean mixture to dilute combustion heat,
injecting cooled oxygen-depleted fuel gas to dilute combustion heat,
injecting cooled oxygen-depleted fuel gas with added fuel to dilute combustion heat, to reduce
the reaction temperature and to make oxygen a limiting factor,
injecting water or steam to dilute combustion heat and to reduce the reaction temperature.
Reducing residence time at peak temperature: As thermal NOx formation depends largely on the
time the fuel gas remains in the high temperature region, reducing this residence time reduces also
NOx formation. Methods to reduce residence time include [1]:
injection of fuel, steam, re-circulated flue gas or combustion air immediately after combustion,
reducing the extension of the high temperature zone which can be faster left by the flue gas
then.
Chemical reduction of NOx during combustion process: NOx can be reduced to N 2 using a
reducing agent which is itself oxidized. The principle of chemical reduction is widely used in secondary
measures but can be also used as a primary measure when reduction takes already place during the
combustion process. Main methods are:
substoichiometric combustion, i.e. in a fuel rich mixture so that the remaining fuel may act as
reducing agent,
re-burning of the flue gas with fuel added (with the added fuel acting as a reducing agent),
generation of fuel-lean and fuel-rich conditions in the combustion zone.
Reducing nitrogen in the combustion process: Reducing NOx formation by reducing the available
nitrogen can be achieved using nitrogen poor fuels like natural gas (see fuel switch) as well as by
using oxygen instead of air for the combustion process.
The following primary measures which are based on the principles and methods described above are
mainly in use, each with its specific advantages and disadvantages, cf. e.g [1], [11]. Some of the
primary measures are typical for retrofit, others for new installations and others are only applicable in
new installations.
low excess air combustion (LEA): In order to ensure complete combustion air is often added
in large excess which may result in higher thermal NOx formation when air nitrogen is oxidized
[2], [3], [4]. Reducing the excess air reduces also NOx formation.
flue gas recirculation (FGR): Re-circulating cooled flue gas reduces the combustion
temperature in a secondary combustion stage and also oxygen concentration so that thermal
NOx formation is reduced. Heat of the flue gas may be recovered in a heat exchanger [1], [5].
air staging (AS): The principle of air staging is to create two zones, one fuel-rich zone where
initial combustion takes place and a second one where air is added to ensure complete
combustion. This allows reducing thermal NOx formation in the first zone where less nitrogen is
available and in the second where temperature is lower. The zone may be created in different
ways. In Biased Burner Firing (BBF) air and fuel flow rates are varied, in Burners Out of
Service (BOOS) the fuel flow to the burner is cut for a short time and in Overfire Air (OFA) air
is injected above the normal combustion zone [3], [4], [5]. Staged air combustion is frequently
used in conjunction with Low NOx burners (LNB).
fuel staging (FS): Fuel staging is similar to air staging but with fuel instead of air. The first
stage is extremely fuel-lean which reduces the temperature. Fuel added in the second stage
acts as a reducing agent for formed NOx. In a third stage air is added to ensure burnout [6].
fuel re-burning (FR): Fuel re-burning is similar to flue gas recirculation (FGR) but with added
fuel in the flue gas leading to lower temperatures. If added in a second combustion stage fuel
re-burning makes use of the fuel as reducing agent and is similar to fuel staging (FS).
reduced air preheat (RAP): Combustion air is in general preheated by the flue gases to cool
them down in order to improve efficiency. Reducing this preheating reduces also flame
temperature and hence NOx formation but also overall energy efficiency [1], [3].
low NOx burners (LNB): Low NOx burners mix fuel and air/flue gas in a way so that different
zones are created as in staged combustion. The zoning allows lower flame temperature and
oxygen concentration as well as chemical reduction of NOx by fuel in some of the zones [1], [5].
Low NOx burners can be further differentiated into air-staged LNB, flue-gas recirculation LNB
and fuel-staged LNB depending on the principle used for reducing NOx emissions. A further
development is the Ultra low NOx burner.
water/steam injection: Water and steam are injected to cool the flame and to reduce thermal
NOx formation.
oxycombustion: In oxycombustion the combustion air is replaced by oxygen so that no thermal
NOx is produced. So far oxycombustion is to a larger extent only applied for glass production
but its use might become more emerging in future as oxycombustion is one option to achieve
high CO2 concentrations in flue gas which is an advantage for CO2 capture and sequestration
[7].
combustion optimisation: In combustion optimisation the combustion process is actively
controlled, e.g. by making use of specialised software. One option is to slightly decrease
combustion efficiency in order to reduce NOx emissions [1].
catalytic combustion: Using a catalyst to reduce combustion temperature below NOx
formation temperature may reduce NOx emissions very strongly. However, applications are still
rare in practice [1] though gas turbines seem to be an interesting field of application [8].
The techniques reported in § 4.4 are an inventory of available technologies to reduce NOx emissions,
which does not mean that those reported technologies are applicable to each industrial sector or
process of production.
For new stationary gas and diesel engine measures, refer to document 7-41.
down periods due to technical constraints. A SCR unit would not function effectively when the
operating conditions and the consequent catalyst temperature are fluctuating frequently outside
the necessary effective temperature window. As a result, SCR is part of BAT, but no specific
emission levels are associated with BAT in a general sense.
selective Non-Catalytic Reduction (SNCR): Similar to SCR a reducing agent (usually
ammonia, urea or caustic ammonia) is used to reduce NOx but in contrast to SCR, without a
catalyst and at a higher temperature between 850 and 1100°C.
Other secondary NOx control techniques include:
NOXSO Process: The NOXSO process is based on simultaneous adsorption of SO 2 and NOx
from flue gas by a regenerable sorbent, finally leading to liquid SO 2, N2 and O2. Claimed
efficiencies are 98% for SO 2 and 75% for NOx [9].
SOx-NOx-Rox-Box (SNRB): SNRB uses a catalytic baghouse for integrated removal of SOx
(via injection of alkali sorbent), NOx (via ammonia injection and SCR), and dust (cf 10).
Problems with this technique include the production of hazardous waste as by-product and
rather low abatement efficiencies.
limestone Injection Multistage Burner (LIMB): LIMB shows lower reliability and rather low NOx
abatement efficiencies.
In integrated gasification combined cycle (IGCC) the fuel is gasified under reducing conditions to
syngas. The syngas is then cleaned and burnt in either air or oxygen. This enables to achieve very low
NOx emission levels. IGCC is seen as one of several key technologies in the framework of carbon
capture and storage (CCS). So far its application is restricted to few, mostly demonstration plants.
With CCS, IGCC could become commercially available around 2020 .
The selection of the most suitable measure depends on many factors related to e.g. [11]:
fuels used,
combustion technology applied,
operational mode of installation,
process characteristics in industrial processes,
new installation or retrofitting,
flue gas characteristics (NOx concentration, temperature, humidity, dust, other pollutants,
catalyst poisons etc.),
flow rate of flue gas,
emission levels to be achieved,
side and cross media effects,
operational safety and reliability,
costs.
The following table gives a brief overview about the performance of primary and secondary measures
for reducing NOx emissions in large combustion plants; cf. the sectoral chapters for more detailed
information on sector specific issues.
Table 5: average reduction efficiency of selected primary and secondary measures for
reducing NOx emissions in large combustion plants for boilers [11]
Costs increase in general less than the capacity of the reduction technique so that larger units are
often more cost-effective. Retrofitting of existing installations is often possible but in general at higher
costs.
For primary measures, investment related costs are in general relatively low and in new installations
there are often no additional costs. But costs accruing from efficiency decreases may be significant
and have to be accounted for.
For SCR, the cost of retrofitting may be high because of the difficulty of building a catalyst reactor
close to the boiler. In addition, for SCR the following costs are most relevant: investment related costs,
ammonia costs, electricity costs, catalyst replacement costs and labour costs. SNCR generally has
lower costs than SCR as there are no costs for catalysts and catalyst reactor housings. However,
costs for SCR and SNCR depend e.g. on the nature of the waste gas, its temperature and the required
abatement efficiency. As a consequence, the additional costs for catalyst replacement in the case of
SCR may be compensated by a significantly lower ammonia consumption compared to SNCR.
More specifically, the side effects to be considered with different emission reduction techniques are:
Primary measures: possible side effects are lower overall energy efficiency, increased CO and
soot formation and hydrocarbon emissions, corrosion due to reducing atmosphere, increase in
unburnt carbon in fly ash.
FBC: this technique also brings about a considerable reduction in SO x emissions. A possible
drawback in FBC systems may be the increased formation of N2O under certain process
conditions. The handling of the ashes needs consideration in relation to their possible use
and/or disposal.
SCR: some possible side effects are ammonia slip in the exhaust gas, ammonia content in the
fly ash, formation of ammonium salts on downstream facilities, deactivation of the catalyst and
increased conversion of SO2 to SO3 (corrosion and fouling). By the controlled operation of the
plant, the fly ash quality can, however, be guaranteed and the formation of ammonia salt
reduced. In terms of by-products, deactivated catalysts from the SCR process may be the only
relevant products, although this has become a minor problem since catalyst lifetime has been
improved and reprocessing options exist. Biomass and waste burning can reduce catalyst life.
SNCR: side effects to be considered are ammonia in the exhaust gas, formation of ammonium
salts on downstream facilities, the formation of N 2O, when urea, for instance, is used as a
component of the reducing mixture, and CO releases. The ammonia slip from SNCR usually is
much higher than from SCR due to the required over-stoichiometric dosage of the reducing
agent (at the high temperatures required for SNCR, part of the injected ammonia reacts to form
additional NOx).
The production of ammonia and urea for flue gas treatment processes involves a number of
separate steps which require energy and reactants. The storage systems for ammonia are subject to
the relevant safety legislation and such systems are designed to operate as totally closed systems,
with a resultant minimum of ammonia emissions. The use of NH 3 is still considered appropriate, even
when taking into account the indirect emissions related to the production and transport of NH 3.
[6] Zabetta, E.C., M. Hupa and K. Saviharju (2005): Reducing NOx emissions using fuel staging, air
staging, and selective non catalytic reduction in synergy. – Ind. Eng. Chem. Res. 44, 4552-4561.
[7] Results of work of the EGTEI expert sub-group on Emerging Technologies/Techniques. Report by
the Chair of the Expert sub-group on Emerging Technologies/Techniques to the Working Group on
Strategies and Review – 1 – 5 September 2008.
[8] Cocchia, S., G. Nutinia, M.J. Spencerb and S.G. Nickola (2006): Catalytic combustion system for a
10 MW class power generation gas turbine. – Catalysis Today 117, 419-426.
[9] Black, J.B., M.C. Woods, J.J. Friedrich, and J.P. Browning: The NOXSO clean coal project. -
NOXSO Corporation, PA, USA.
[10] Kudlac, G. A., G.A. Farthing, T. Szymanski, and R. Corbett (1992): The SOx-NOx-Rox BoxTM
(SNRB). - Environmental Progress, 11, 33 – 38.
[11] LCP BREF (2006): Reference Document on Best Available Techniques for Large Combustion
Plants. – European Commission, 618 pp.
[12] VDI 3800, Determination of costs for industrial environmental protection measures. Verein
Deutscher Ingenieure, 2001.
[13] EGTEI: Final background document on the sector “glass industry”, DFIU/IFARE 2003.
In order to reduce efficiently VOC emissions, it is of particular importance to consider both the
reduction of stack emissions and fugitive emissions. Stack emissions refer to emissions of which the
source and the direction of gas flow is clearly definable. They enter in the atmosphere by passing
through a stack or a duct designed to direct and control their flow. Sources of fugitive emissions are
not clearly defined. They enter in the atmosphere without passing through a stack or duct designed to
direct or control the emissions. They include uncaptured emissions released to the outside
environment via windows, doors, vents and similar openings [2]. In industrial plants, fugitive emissions
have a diffuse character as they can arise from a lot of sources spatially dispersed.
Instead of applying emission limit values (ELV), e.g. connected to end-of-pipe measures, reduction
schemes can be used. Solvent management plans have to be used as guidance for these reduction
schemes. The purpose of a reduction scheme is to allow a plant operator to achieve emission
reductions similar to those achieved if given limit values were to be applied by other means.
Definitions of solvent management plan and of a reduction scheme are given below. Solvent
management plan and reduction scheme are a key element of annexe VI to the Protocol to Abate
Acidification, Eutrophication and Ground-level Ozone. They help to verify compliance with given
regulations, identify future reduction options, and enable the provision of information on solvent
consumption, emissions and compliance with regulations to the public.
In general, no further subdivision for VOCs is made with regard to specific substances. Performance is
reported where available.
O4 Uncaptured emissions of organic solvents to air. This includes the general ventilation of rooms,
where air is released to the outside environment via windows, doors, vents and similar openings.
O5 Organic solvents and/or organic compounds lost due to chemical or physical reactions (including
for example those which are destroyed, e.g. by incineration or other waste gas or waste water
treatments, or captured, e.g. by adsorption, as long as they are not counted under O6, O7 or O8).
O6 Organic solvents contained in collected waste.
O7 Organic solvents, or organic solvents contained in preparations, which are sold or are intended to
be sold as a commercially valuable product.
O8 Organic solvents contained in preparations recovered for reuse but not as input into the process,
as long as not counted under O7.
O9 Organic solvents released in other ways.
Determination of solvent consumption and NMVOC emissions can be done according to equations
presented here after:
Consumption can be calculated according to the following equation:
C = I1 - O8
Total NMVOC emissions are defined as follows:
E = F + O1
Where F is the fugitive emission as defined below:
F = I1 - O1 - O5 - O6 - O7 - O8
or
F = O2 + O3 + O4 + O9
This quantity can be determined by direct measurement of the quantities. Alternatively, an equivalent
calculation can be made by other means, for instance by using the capture efficiency of the process.
The fugitive emission value as well as the total emission can be expressed as a proportion of the
input, which is calculated according to the following equation:
I = I1 + I2
The solvent management plan can be done on a regular basis such as an annual basis, in order to
control progress carried out, take the necessary measures if deviations are observed and be in
position to assess the compliance of the installation with regulation implementing ELVs.
be facilitated by the use of only few organic solvents instead of complex mixtures. Complex mixtures
may be better treated off-site; however, emissions may be caused by distribution, handling, transport
and storage;
(e) Destruction of VOCs by control technologies such as thermal or catalytic incineration, or
biological treatment. For incineration, heat recovery is recommended in order to reduce operating
costs and resource consumption. Another common procedure for destroying non-halogenated VOCs
is to use VOC-laden gas streams as secondary air or fuel in existing energy-conversion units.
techniques enabling possible recovery of VOCs for possible reuse in the process after a specific
treatment carried on site or by external companies:
- adsorption on activated carbon or zeolithe substrates,
- absorption in adapted scrubbing liquors (water, heavy oils),
- condensation and cryogenic condensation,
- membrane separation associated to other processes such as cryogenic condensation and
adsorption.
Processes using thermal oxidation may enable valorisation of the energy content of VOCs. However,
in most cases, this valorisation is difficult due to the low VOC concentrations generally encountered.
Primary thermal energy recovery (for warming inlet gases as example) is indispensable but secondary
thermal energy recovery is often most difficult to be implemented in existing plants. The VOCs
concentrations have to be sufficient for enabling the oxidation unit to run without additional fuel
consumption and to be consequently in autothermal conditions. Lower concentrations require
additional fuel consumption which can be rapidly prohibitive.
Biological destruction: biological destruction can be carried out in bio filters and in bio scrubbers.
Micro organisms are able to destruct biodegradable VOCs in humid conditions and at low
temperature. Warm waste gases (> 35 °C) must be cooled. In bio filter, microorganisms are
maintained at the surface of a moist organic substrate which can be peat, heather or compost. In bio
scrubbing, a combination of wet gas scrubbing and biodegradation is carried out. Microorganisms are
suspended in the scrubbing water. In biofilters, residence time must be sufficient to enable biological
reactions to occur. Accepted inlet VOC concentrations are low. Biological oxidation is used primarily
3
for low concentrations. Output VOC concentrations from 100 to 150 mg/Nm can be achieved. Lower
concentrations are however more difficult to obtain.
Adsorption on activated carbon or zeolithes. In adsorption, VOCs are physically bound to the
surface of a media which can be activated carbon or zeolithes. The adsorption capacity of activated
carbon or zeolithe is limited and consequently they must be regenerated to recover their initial
capacity to adsorb VOCs and recover VOC. Several configurations exist but in most of the cases,
fixed bed adsorption devices are used with 2 or 3 beds. A bed is in adsorption phase, the second one
is in desorption phase. Desorption is carried at high temperature with steam or inert gas. The
adsorption temperature must be below 40 °C because the effectiveness of adsorption improves at low
temperature. Inlet gases must be consequently conditioned. VOCs are recovered after a special
treatment which involves condensation, separation and distillation if several VOCs are present. VOCs
abatement efficiency depends on a lot of parameters such as adsorption temperature, type and
number of VOCs to be eliminated, frequency set point for desorption. Output VOC concentrations from
3
50 to 100 mg/Nm can be achieved. Efficiencies achieved depend on numerous factors such as
correct dimensioning of the installation, the frequency of desorption and the threshold value fro for
desorption….
Condensation and cryogenic condensation: in condensation VOCs are cooled below the stream
dew point. Condensation of VOCs is carried out by chilling and /or pressurisation. Cooling media can
be cooled water, chilled water, refrigerants and liquid nitrogen. Diverse heat exchangers equipment
can be used. Condensation with cooled water, chilled water or refrigerants is often used as pre-
treatment but is not sufficient to achieve high reduction of emissions. Output VOC concentrations from
3
100 to 150 mg/Nm can be achieved. Efficiencies achieved depend on numerous factors such as
correct dimensioning of the installation, the frequency of desorption and the threshold value for
desorption…
Liquid nitrogen is used in cryogenic (temperature less than -160°C) condensation. Cryogenic
condensation is a versatile process that is not VOCs specific. Typically, condensation takes place with
liquid nitrogen as the refrigerant in a straightforward heat exchange process. The VOCs condense on
the shell side of the exchanger then drains into a collection tank, from which it can be recycled,
reclaimed, recovered for reuse or for disposal. During condensation, the presence of water vapour or
VOCs with a high melting point can cause freezing on the external surface of the tubes inside a
cryogenic condenser. Special configuration exists to avoid this problem and especially a series of
condenser can be used with different temperature set points [8]. Cryogenic condensation is best
suited to low waste gas flowrates and/or high VOCs concentrations. Output VOC concentrations from
3
50 to 100mg/Nm can be achieved. Efficiencies achieved depend on numerous factors such as correct
dimensioning of the installation, the volatility of solvents…
Membrane separation: VOC emissions can be concentrated using organic selective (VOCs
permeable) membranes. Air and VOCs permeate through the membrane at rates determined by their
relative permeabilities and the pressure difference across the membrane. Membranes ar e typically 10
to 100 times more permeable to VOCs than air, depending on the specific VOC characteristics. Based
on the system design, the exit membrane stream VOC concentration can be increased five to fifty
times the inlet membrane stream concentration. Concentrated gas streams can be then compressed
and condensed by the use of conventional condensation technology. Membrane separation cannot be
used alone. Subsequent gas cleaning device is necessary.
The choice of a control technique will depend on various parameters, such as the concentration of
VOCs in the raw gas, the gas volume flow, the type and composition of VOCs, and others. Therefore,
some overlap in the fields of application may occur. In that case, the most appropriate technique must
be selected according to case-specific conditions. An overview of the most relevant parameters for the
application of some secondary measures is outlined in table 26. The overall efficiency of secondary
measures in the solvent-using sectors depends to a large extent on the capturing efficiency for the
VOC-laden waste gas flows. Especially for fugitive emissions, capturing is paramount for the overall
efficiency of the system.
Table 6: overview of the most relevant parameters for the application of secondary measures
5.4 Costs
The estimation of investments and operating costs for VOC emission reduction options/techniques is
important when choosing from the wide range of measures and, on a macroeconomic level, when
developing a national or regional emission control strategy. It must be borne in mind that specific
figures are highly dependent on factors such as plant capacity, removal efficiency, VOC concentration
in the raw gas, type of technology, and the choice of new installations as opposed to retrofitting. These
parameters, and thus the costs incurred as well as the resulting ranking of measures in terms of costs,
may be highly case-specific, for instance for retrofit cases, and examples should not be generalised.
EGTEI documents defining the methodologies used to estimate costs for waste gas treatment
techniques are available. Documents on oxidation, carbon adsorption and bio filtration are available at:
http://citepa.org/forums/egtei/egtei_doc-VOC_abattement_tech.htm.
Investments and operating costs depend particularly on flow rates and VOC concentrations to be
treated. Costs are provided in chapter 7.
Reduction technique Positive side effects Negative side effects Mis en forme : Non Surlignage
Besides this size dependent classification, dust is also differentiated according to its origin into primary
and secondary dust. Dust can be natural (sea salts, volcanoes, soil erosion...) , etc) and
anthropogenic (combustrion, processes...). , etc). According to its source, dust has different chemical
compositions. Primary dust is composed of salts (nitrates, sulphates, carbonates...), , etc), of black
carbon (BC), of organic carbon (non-carbonate carbonaceous particles other than elemental carbon
[20]) (OC) and trace elements such as heavy metals. Secondary PM is formed in the atmosphere of
the precursors ammonia, sulphuric acid, nitric acid and NMVOC-related organic oxidation products [1].
Dust affects the radiation balance of the earth. Some components of dust have a cooling effect
(sulphates, OC). Other ones, have a warming effect (BC).
BC means carbonaceous particulate matter that absorbs light. Absorption occurs at all wavelengths of
solar radiation [16], [19]. BC remains in the atmosphere for days to weeks and because of its light
absorbing properties, it contributes significantly to global warming. It also darkens snow and ice after
deposition and thereby reduces the surface albedo, or reflectivity. This albedo effect is particularly
prevalent in the Arctic region. By darkening ice and snow, it contributes to regional warming [16], [17],
[18].
The BC content of dust increases with incomplete combustion of various fossil fuels, biofuels and
biomass [16]. BC is part of a complex particle mixture called soot which primarily consists of BC
(which is a warming agent) and OC (which is a cooling agent). There is a close relationship between
the two compounds. They are always co-emitted, but in different proportions for different sources.
Soot mixtures can vary in composition, having different ratios of OC to BC and usually include
inorganic materials such as metals and sulphates. For example, the average OC/BC ratio of diesel
exhaust could range approximately from 1/4 (heavy duty engine type operating on distillate) according
to reference [19] to 15/1 (large medium speed engine operating on heavy fuel oil) according to
reference [2134]. For biofuel burning, the ratio is approximately 4/1 and for open vegetation fires (or
open biomass burning) it is approximately 9/1 [19]. For all sources, monitoring results are needed to
improve knowledge of BC emissions.
BC forms during combustion, and is emitted when there is insufficient oxygen and heat available for
the combustion process to burn the fuel completely. BC originates as tiny spherules, ranging in size
from 0.001 to 0.005 micrometers (μm), which aggregate to form particles of larger sizes (0.1 to 1 μm).
The characteristic particle size range, in which fresh BC is emitted, also makes it an important
constituent of the ultrafine particles (<100 nanometers (nm)). BC is associated with particles less than
1 µm [19]. When combustion is carried out in optimal O 2 concentrations (optimal excess air) and
optimal temperatures, mainly salts are present in dust. Mitigation techniques for BC are the same as
for PM2,5 as BC is a compound of dust. Only fabric filters and electrostatic precipitators can be
efficiencies on fine particles.
Inhaling dust may cause negative health effects [2] like asthma, lung cancer, cardiovascular issues,
and premature death. Health effects are related to particle size as large particles can be filtered out in
the nose and throat. Particles with a size less than about 10 µm can enter the bronchi and the lungs,
particles less than 2.5 µm in diameter the gas-exchange regions of the lung, and particles less than
0.1 µm can enter via the lungs into other organs. Therefore, the potential for negative health effects
increases with decreasing particle diameter. Besides particle size also the chemical compos ition, e.g.
carcinogenic components, and solubility of the particle in the lung has an impact on the potential
health effects. Health effects are expected to be related to the number of smaller particles whereas
most measurements refer to the particle mass which is in general dominated by the larger particles
within the size fraction.
Furthermore, dust generates haze with effects on visibility.
For dust, there are several natural and anthropogenic sources with differences in the size and the
chemical composition of the generated dust. Dust formation may result from:
mechanical processing of solid matter (crushing, grinding, surface processing, abrasion etc.),
chemical and physical reactions (incomplete combustion, gas-to-particle conversion,
condensation, deposition etc.),
exposure of solid matter (wind erosion etc.)
re-suspension of dust (from roads, stockpiles etc.).
Published measurement data on the share of PM 2.5 and PM10 in waste gas is scarce and/or of limited
quality. Therefore the following tables citing calculated shares as used in the RAINS/GAINS model are
presented.
Table 7: shares of PM2.5 and PM10 in TSP as used in RAINS (2002) [15]
%
Sector Name RAINS-Code(s) Unit PM2.5 PM10 %PM10 TSP
PM2.5
Coal, grate (in industry, raw gas) 7% 20%
Small domestic boilers (wood burning in DOM_SHB_M, 37% - 0,096 - 37% - 0,1 -
kt/PJ 0,093 - 0,23
Eastern Europe) DOM_SHB_A 92% 0,24 96% 0,25
Small domestic boilers (wood burning in DOM_SHB_M, 33% - 0,062 - 34% - 0,065 -
kt/PJ 0,06 - 0,167
Western Europe) DOM_SHB_A 93% 0,17 94% 0,18
Large residential boilers (wood burning in DOM_MB_M, 33% - 0,06 - 40% - 0,065 -
kt/PJ 0,05 - 0,12
Western Europe) DOM_MB_A 80% 0,134 89% 0,15
Table 7: shares of PM2.5 and PM10 in TSP as used in RAINS (2002) [15]
%
Sector Name RAINS-Code(s) Unit PM2.5 PM10 %PM10 TSP
PM2.5
Power plants (stationary combustion of PP_NEW, Mis en forme : Gauche
kt/PJ 0,0093 60% 0,0132 85% 0,0155
heavy fuel oil) PP_EX
Conversion (stationary combustion of Mis en forme : Gauche
CON_COMB kt/PJ 0,0117 60% 0,0166 85% 0,0195
heavy fuel oil)
Industry (stationary combustion of heavy Mis en forme : Gauche
IN_BO, IN_OC kt/PJ 0,0104 60% 0,0147 85% 0,0173
fuel oil)
Residential (stationary combustion of Mis en forme : Gauche
DOM kt/PJ 0,0095 25% 0,0247 65% 0,038
heavy fuel oil)
Power plants (stationary combustion of Mis en forme : Gauche
PP_NEW kt/PJ 0,0004 18% 0,0011 50% 0,0022
light fuel oil), new
Power plants (stationary combustion of Mis en forme : Gauche
PP_EX kt/PJ 0,0007 19% 0,0018 50% 0,0036
light fuel oil), existing
Conversion (stationary combustion of Mis en forme : Gauche
CON_COMB kt/PJ 0,0004 11% 0,0018 50% 0,0036
light fuel oil)
Industry (stationary combustion of light Mis en forme : Gauche
IN_BO, IN_OC kt/PJ 0,0003 14% 0,0011 50% 0,0022
fuel oil)
Residential (stationary combustion of Mis en forme : Gauche
DOM kt/PJ 0,0007 41% 0,0009 53% 0,0017
light fuel oil)
Power plants (stationary combustion of PP_NEW, Mis en forme : Gauche
kt/PJ 0,0001 100% 0,0001 100% 0,0001
natural gas) PP_EX
Conversion (stationary combustion of Mis en forme : Gauche
CON_COMB kt/PJ 0,0001 100% 0,0001 100% 0,0001
natural gas)
Industry (stationary combustion of Mis en forme : Gauche
IN_BO, IN_OC kt/PJ 0,0001 100% 0,0001 100% 0,0001
natural gas)
0,0000
Residential (stationary combustion of 0,00003 - 0,00003 Mis en forme : Gauche
DOM kt/PJ 100% 3- 100%
natural gas) 0,0002 - 0,0002
0,0002
Coke Production PR_COKE kt/ton 1,9971 40% 3,3618 68% 4,976
Pellet plant PR_PELL kg/ton pellet 0,03 100% 0,03 100% 0,03
Pig iron production PR_PIGI kg/ton pig iron 0,15 10% 0,24 16% 1,48
Pig iron production (fugitive) PR_PIGI_F kg/ton pig iron 0,15 6% 0,25 10% 2,5
Open-hearth furnace PR_HEARTH kg/ton steel 6,33 60% 8,76 83% 10,55
Basic oxygen furnace PR_BAOX kg/ton steel 10,45 50% 14,63 70% 20,9
Electric arc furnace PR_EARC kg/ton steel 7,55 43% 10,18 58% 17,55
Iron foundries PR_CAST kg/ton iron 10,68 71% 13,55 90% 15,05
Iron foundries (fugitive) PR_CAST_F kg/ton iron 1,38 24% 2,82 49% 5,75
Aluminium production (primary) PR_ALPRIM kg/ton aluminium 18,5 39% 27,26 58% 47
Aluminium production (secondary) PR_ALSEC kg/ton aluminium 5,195 44% 6,93 58% 11,9
Other Non-ferrous metals PR_OT_NFME kg/ton metal 12,3 82% 13,8 92% 15
Cement production PR_CEM kg/t cement 23,4 18% 54,6 42% 130
Petroleum refining (refineries) PR_REF kg/t crude oil 0,096 79% 0,12 98% 0,122
Carbon Black production PR_CBLACK kg/t 1,44 81% 1,6 90% 1,78
Glass production PR_GLASS kg/t glass 2,96 91% 3,09 95% 3,25
Other production (PVC, gypsum, glass 3% - 11% - Mis en forme : Gauche
PR_OTHER kg/ton product 0,5 - 8 2 - 15 5 - 17,5
fibre) 46% 86%
Major stationary sources of dust emissions are therefore combustion processes, in particular of coal,
fuel oil and biomass but also of black liquor in paper industry, industrial processes like sintering,
cement production etc. as well as storage, handling and mechanical processing of materials.
BC emission inventories are available at the global scale or local level. Reference [21] provides an
overview of available inventories [22], [23], [24], [25] at the global scale. The GAINS model has been
extended to cover BC and OC [27]. A report on emission factor determination is available from IIASA
[26]. Uncertainties are still considerable regarding sources such as combustion, agricultural burning,
and open biomass burning (wild fire and prescribed forest burning), however there is a consensus on
the most important sources of BC. These sources are [17], [19]:
In UNECE regions:
the on-road and off-road diesel engines including marine engines;
the domestic sector due to emissions from domestic heating, primarily wood but also coal
combustion;
the open biomass burning sector, primarily due to emissions from agricultural burning,
prescribed burning in forestry, and wildfires.
Globally, important sources include residential cook stoves in all regions; brick kilns and coke ovens in
Asia; and mobile diesel vehicles and marine engines in all regions; open biomass burning in all
regions. Gas flaring from fossil fuel extraction is also considered as a significant BC emission source
by most publications.
The following graph presents emission sources in the UNECE region according to GAINS [28]. In this
region, residential combustion (biomass and coal), road traffic and off-road machineries are the largest
sources of BC. Off-road sources are very significant as well as open biomass burning in agricultural
activities.
Figure 1: BC and OC emission sources in the UNECE region according to GAINS [28]
abatement measures are applied. To achieve the most efficient dust reduction, beyond energy
management measures, a combination of measures should be considered. To identify the best
combination of measures a site-specific evaluation is needed.
Capture of emissions
A prerequisite for later dust abatement is the capture of fugitive dust emissions, e.g. in the iron and
steel industry, and venting to dust control systems.
1
The following secondary measures are mainly in use, each with its specific advantages and
disadvantages according to the size of particles. Because BC from incomplete combustion is mainly
associated to particles with a diameter less than 1 µm, only reduction techniques able to remove fine
particles will have a significant efficiency on BC emissions:
gravity settling chamber: In gravity settling chambers the flow rate of the air is reduced so that
larger particles sink and settle. Gravity settling chambers are only useful for removing the
largest particles in terms of "pre-cleaning". The minimum particle size removed by gravity
settling chambers is >20 µm [1].Table 8 presents dust removal efficiencies of gravity settling
chamber. This equipment is not suitable for removal of fine particle and BC.
Mis en forme : Police :(Par défaut)
1
The performance data in the following paragraphs mainly refer to boiler installations Arial, 9 pt
cyclone: In cyclones inertia of particles are used for dust removal. In a cyclone the flue gas is
forced (usually via a conical shaped chamber) into a circular motion where particles are forced
by inertia to the cyclone walls where they are collected. Collection efficiency depends strongly
on particle size and increases with the pollutant loading. For conventional single cyclones it is
estimated to be 70-90% for TSP, 30-90% for PM10 and 0-40% for PM2.5 [6]. The minimum
particle size removed by cyclones is 5-25 µm and 5 µm in multicyclones [1]. Conventional
cyclones are therefore referred to as "pre-cleaners". Conventional cyclones alone are not BAT
for industrial installations but could be an option to reduce dust emissions from small
combustion installations, e.g. in households or in the commercial sector. High efficiency
cyclones removing 60-95% of PM10 and 20-70% of PM2.5 have been developed but at the
expense of a high pressure drop leading to high energy and hence operation costs [6].
Achieving higher removal efficiencies in cyclones is mainly a problem of the resulting pressure
drop. High throughput cyclones have been designed on purpose for removing just the larger
dust fraction at the expense of only low pressure drop. In multicyclones many small cyclones
operate in parallel achieving removal efficiencies similar or superior to high efficiency cyclones
(cf. [6]). Application of cyclones as a pre-cleaner to remove abrasive particles may increase the
lifetime of other abatement equipment. Cyclones are also used to recover recycling products,
process materials etc. from the flue gas, e.g. in the ferrous and non-ferrous metals industry.
Advantages of cyclones are: low investments, low operating and maintenance costs relative to
the amount of PM removed, temperature and pressure range only limited by material, collection
of dry material, relatively small in size. Disadvantages include low removal efficiencies for fine
PM (or alternatively high pressure drops) and non-applicability for sticky materials. The
efficiency of cyclones on BC can be assumed similar to the efficiency obtained on PM 2.5,
electrostatic precipitator (ESP): The principle behind ESP is that particles of the flue gas
stream are electrostatically charged when passing through a region with gaseous ions (corona)
generated by electrodes at high voltage (around 20 to 100 kV). The charged particles are then
redirected in an electric field and settle at the collector walls. As large particles absorb more
ions than smaller ones, ESP removal efficiency is higher for larger particles. New ESP typically
may achieve PM removal efficiencies of 99% to about 99.99% if perfectly dimensioned and in
optimal operation conditions, in the range 0.01 to >100 µm, older ones 90 to 99.9% [1], [7], [8].
The minimum particle size removed by ESP is <1 µm [1]. Removal efficiencies are lowest for
particles with a diameter of 0.1 to 1 µm. Efficiency depends on the ESP size (collection area)
but also on dust resistivity, temperature, chemical composition of the dust and gas and particle
size distribution. The electrical conductivity of dust is one of the most relevant properties for
ESP operation. In good and steady combustion conditions, particles are mainly composed of
inorganic compounds such as salts which present ideal conductivity and are removed efficiently
with the ESP. Soot and BC reveal high conductivity thus enabling high precipitation efficiency
but severe re-entrainment of agglomerated particles. Condensable organic compounds (COC)
from wood combustion (which are formed at low temperature from wood pyrolysis with
characteristic compounds depending on residence time, heating rate, temperature and other
operation parameters and at moderate temperatures and local lack of oxygen) exhibit low
conductivity thus leading to back-corona which limits ESP operation [29], [30].
Dust at the collectors can be removed either dry or wet by a spray of usually water (dry or wet
ESP). Dry ESPs are more common as dry collected dust is easier to handle than slurry which
requires after treatment. Wet ESPs need noncorrosive materials. However, removal of particles
with extremely low or high resistivity is difficult in dry ESPs whereas wet ESPs can also collect
particles with high resistivity as well as sticky particles, mists or explosive dusts. Wet ESPs
show also higher efficiencies for smaller particles. Injection of conditioning gases, liquids or
solids, in particular water and SO 3, may improve removal efficiencies [1]. Advantages of ESPs
are in general very low pressure drops, very good removal efficiencies (but less pronounced for
fine particles), low operating costs as well as wide applicability (sticky, glowing, high resistivity
(wet ESP) particles, mists, acids, ammonia, exploding gases (wet ESP)) [1], [7], [8].
Disadvantages are high investments, high space demand, ozone formation due to high voltage,
need for specialised personnel for high voltage, and limited applicability in case of varying flue
gas conditions (flow rate, temperature, dust load, composition of dust) as well as necessary
after treatment of slurry (wet ESPs), but almost closed water loops are achievable [1], [7], [8].
For combustion installations, ESPs can guarantee low dust and BC emissions when stable and
good combustion conditions are achieved. On contrary, during transient conditions, dust
(including PM10, PM2.5 and black carbon) emissions can be increased not only due to increased
raw gas concentrations, but additionally due to reduced precipitation efficiency. All measures to
insure steady state running of combustion installations are unavoidable even if an ESP is
present (refer to chapter 6.4 for optimisation of the combustion).
To achieve high efficiency of dust and BC removal with ESP, the following recommendations
are provided by references [29], [30] for biomass combustion:
1. Optimum design and system integration of combustion and ESP enabling steady operation,
2. Process integrated control of ESP with specific information as indicators for the particle
properties: flue gas temperature (as often carried our presently), excess air ratio, combustion
temperature, water content of the fuel. This increases the range of conditions when the ESP is
effective.
3. Measures to avoid re-entrainment: limitation of gas velocity to < 1.5 m/s, optimised shape of
collecting plates, shorter dedusting interval during re-entrainment regimes.
The lower efficiency of ESPs on sub micrometer particles can be addressed by the use of an
association of an ESP and a FF or the use of an agglomerator (see here after). These two
techniques have been defined as emerging techniques by EGTEI [31].
fabric filter (FF): In a FF the flue gasses pass through a permeable fabric where larger
particles are sieved or adsorbed. The filter cake made up of collected particles supports the
collection of further particles. As pressure drop increases with filter cake thickness the fabric
filter needs to be cleaned from time to time. Three main cleaning mechanisms are applied:
pulse jet filters where filters are cleaned by a pulse of pressurized air from the other side,
shaker mechanisms and reverse gas flow. Pulse jet filters are today the most common type as
they demand less space, are less expensive and applicable for high dust loadings and cause
constant pressure drop [1], [9], [10]. Removal efficiencies are 99 to 99.99% for new and 95 to
99.9% for older installations [1], [9], [10] and depend on filtration velocity, particle and fabrics
characteristics and applied cleaning mechanism. FF is in particular able to remove fine and
ultrafine dust and is consequently efficient to remove BC. Flue gas conditioning using mainly
elemental sulphur, ammonia and SO 3 is applied to achieve higher removal rates, reduce
pressure drop, and reduce re-entrainment of particles [1]. New developments are the addition of
activated carbon or lime to achieve reactions in the filter cake as well as a catalytic filter material
[1]. Flue gas temperature depends on the filter material used and the dew point of the flue gas
and is in general between 120-180°C [1]. Advantages of FF are very low emission levels even
down to ultrafine particles (depending on fabric) and achieved independent from dust loading,
flow rate (e.g. start-ups) and dust type (. (except COC due to their sticky properties [30]),
simple operation and in general no corrosion problems. Disadvantages are relatively high
maintenance and operating costs due to replacement of filter bags (lifetime depends on
temperature and dust) and pressure drop and in particular limitations in applicability in moist
environments and for hygroscopic, glowing and sticky particles as well as for acids and
ammonia and exploding gases [1], [9], [10]. Large particles need to be removed in advance [1].
Bypassing is necessary during failure.
wet scrubber: Injecting water into the flue gas stream leads to formation of water droplets
which with dust, forms a slurry. Scrubbers are mainly used for SOx removal but reduce also
dust. Removal efficiencies are up to 80% for spray towers as well as dynamic and collision
scrubbers and up to 99 % for venturi scrubbers [1]. The minimum particle size removed by
spray towers is >10 µm, by dynamic and collision scrubbers > 2.5 µm and by venturi scrubbers
>0.5 µm. Advantages of wet scrubbers are simultaneous removal of SOx and dust (and even
other pollutants like HCl and HF), low maintenance, rather high removal e fficiencies (in
particular venturi scrubbers), few application limits (flow rate fluctuations, hot or cold, wet and
corrosive gases, mists are uncritical) and reduced explosion risks from dust. Disadvantages are
waste generation (slurry), high maintenance costs due to potentially high pressure drop,
corrosion problems and rather low removal efficiency for very fine particles such as those to
which BC is associated [1].
oxidation techniques (described in chapter 5.3.2) used to abate VOC, PAH and odours can
also be a useful technique to break down organic matter, including BC in some specific
applications. Organic matter like BC can be incinerated indeed. This oxidation takes place in a
thermal oxidation step in an off-gas burner, or in a catalytic oxidation installation. Oxidation
techniques are used to abate anode plant emissions which partially consist of pitch and tar
fumes and are rich in PAHs. Oxidation techniques abate pitch and tar fumes as well as
condensed and volatile PAHs as well [32], [33].
Table 8: Removal efficiencies of dust abatement measures for different particles size for boiler
plants
Removal efficiencies [%]
submicron fine coarse large
Category Type Subtype <1 µm 0-2.5 µm 2.5-6 µm 6-10 µm 2.5-10 µm >10 µm
RAINS* US EPA** RAINS** US EPA** RAINS** RAINS**
high efficiency 3.6 5 6
Gravity Gravity collector medium efficieny 2.9 4 4.8
and low efficiency 1.5 3.2 3.7
centrifugal high efficiency 80 95 95
collector Centrifugal collector medium efficieny 50 75 85
low efficiency 10 35 50
Single cyclone 10 35 50
Multiple cyclone without fly ash
80 95 95
reinjection
Cyclone Multiple cyclone with fly ash
50 75 85
reinjection
Cyclone/Multcyclone unspecified 11 30 70 90
Wet cyclonic separator 50 75 85
ESP high efficiency 98.6 95 99 99 99.5 99.9 99.95
medium efficiency
ESP 95.4 96 99 99,9
(unspecified)
low efficiency
ESP 91.96 93 95 97
(unspecified)
ESP
wet ESP 98.86 99 99.9 99.95
medium efficieny 50 80 94
ESP: boilers
low efficiency 40 70 90
medium efficieny 80 90 97
ESP: other than boilers
low efficiency 70 80 90
high temperature 99 99.5 99.5
Fabric
Fabric filter medium temperature 99 99.5 99.5
Filter
low temperature 99.99 99 99 99.5 99.5 99.9 99.98
Spray tower 20 80 90
high efficiency 95 90 96 95 99 99 99.5
Scrubber Wet scrubber medium efficieny 25 85 95
low efficiency 20 80 90
Venturi scrubber 90 95 99
Process enclosed 1.5 3.2 3.7
Dust suppression by water sprays 40 65 90
Dust suppression by chemical
40 65 90
stabilizer or wetting agents
Other Water curtain 10 45 90
Good practice: industrial processes
stage 1 20 10 15 20
(fugitive)
Good practice: industrial processes
stage 2 65.33 30 50 75
(fugitive)
* Kupiainen, K. & Z. Klimont (2004) Primary emissions of submicron and carbonaceous particles in Europe and the potential for their control. - IIASA Interim Report IR-04-079, 122 pp.
** Klimont, Z. J. Cofala, I. Bertok, M. Amann, C. Heyes & F. Gyarfas (2002): Modelling Particulate Emissions in Europe. - IIASA Interim Report IR-02-076, 179 pp.
*** US EPA (1996): AP 42, Volume I, Fifth Edition, Appendix B.2 Generalized Particle Size Distributions
Because most BC is within the fine or submicron size categories, the removal efficiencies for fine and
especially submicron particles indicated in table 8 can be used as a rough proxy for BC removal
efficiencies.
The selection of the most suitable measure depends on many factors related to e.g.such as the
following ones:
flue gas characteristics (dust concentration and characteristics like particle size distribution,
resistivity, temperature, humidity, other pollutants present like acids, SOx, etc.),
flow rate and fluctuations of flue gas,
operation mode of installation,
process specifics in industrial processes,
new installation or retrofitting, e.g. available space,
emission levels to be achieved,
side and cross media effects,
operational safety and reliability,
site specifics,
costs.
Costs increase in general less than the capacity of the reduction technique so that larger units are
often more cost-effective. Retrofitting of existing installations is often possible but in general at higher
costs.
For ESP investments are relatively high whereas maintenance and operating costs are relatively low,
in particular as a result of the low pressure drop. Other costs are related to personnel specialised for
high voltage and in case of wet ESP costs for slurry treatment.
For fabric filters, investments are lower but maintenance and operating costs are higher as fabrics
have to be changed regularly (depending on flue gas and dust characteristics) and as the pressure
drop is modest to high.
A core side effect of dust emission reduction is the simultaneous reduction of heavy metals (except for
mercury) [14]. Depending on its characteristics and chemical composition collected dust can be
recycled, e.g. in iron and steel industry, or has to be disposed.
More specifically, the side effects to be considered with different PM emission reduction techniques
are:
Electrostatic precipitator (ESP): For ESPs a main side effect is electricity consumption for producing
the corona and the electric field. However, as pressure drop is low in ESPs, overall electricity
consumption is considerably lower than in FF where high pressure drops have to be compensated for.
In wet ESPs treatment of the slurry is necessary but water recirculation reaches almost 100% so that
waste consumption is low. As ESPs have considerably lower removal efficiencies in the size range 0.1
to 1 µm removal of heavy metals in ESPs is far lower than in FF.
Fabric filters (FF): Fabrics have to be changed around every 2 to 4 years (lifetime depends on
various factors) so that waste is generated if reprocessing of the fabrics is not possible. The pressure
drop in FFs has to be compensated for by pumping leading to additional electricity consumption. As
FFs are also very effective in removal of fine particles, they also effectively reduce emissions of heavy
metals which are enriched in the sub-micrometer size range of dust in flue gases.
[23] Van der Gon H., Visschedijk A., Kuenen J, Harrison R., Beddows D., Prior S., Sørensen
L.L.,Janhäll S., Pandis S., Johansson C., Hedberg Larsson E., De Leeuw G., and O‘Dowd C. Progress
in Eucaari Wp 1.3: Anthropogenic and Biogenic Emissions of Aerosols and Precursors. In
Proceedings of 2007 EUCAARI Annual Meeting Helsinki 20.-22.11.2007, Kulmala et al. (Eds.), Report
Series in Aerosol Science, 91. http://www.atm.helsinki.fi/~asmi/EUCAARI/EUCAARI_rs91.pdf.
[24] Bond, T.C., Streets, D.G., Yarber, K.F., Nelson, S.M., Woo, J.-H., Klimont, Z., 2004. A
technology-based global inventory of black and organic carbon emissions from combustion. Journal of
Geophysical Research 109, D14203.
[25] Junker, C and Liousse, C., 2008. A global emission inventory of carbonaceous aerosol from
historic records of fossil fuel and biofuel consumption for the period 1860 –1997. Atmos. Chem. Phys.,
8, 1195–1207.
[26] Kupiainen, K. & Klimont, Z., 2004. Primary Emissions of Submicron and Carbona ceous Particles
in Europe and the Potential for their Control. International Institute for Applied Systems Analysis
(IASA), Interim report IR-04-79, Schlossplatz 1 A-2361 Laxenburg Austria.
[27] Amann, M. - 2008, The Greenhouse Gas – Air Pollution Interactions and Synergies Model
(GAINS). Interim Report on Modelling Technology, European Consortium for Modelling of Air Pollution
and Climate Strategies - EC4MACS. Task 2: Integrated Assessment of Air Pollution and Greenhouse
Gases.
[28] Klimont, Z. - Center for Integrated Assessment Modelling (CIAM) - International Institute for
Applied Systems Analysis (IIASA).
Current Emissions and Baseline Projections of Black Carbon in UNECE area GAINS model – working
progress. UNECE TFEIP Stockholm, May 2-3, 2011.
[29] Nussbaumer,T. & Lauber, A. - Formation mechanisms and physical properties of particles from
wood combustion for design and operation of electrostatic precipitators - 18th European Biomass
Conference and Exhibition, Lyon, 3–7 May 2010, OA11.3, ETA-Florence 2010.[30] Nussbaumer, T. -
Overview on Technologies for Biomass Combustion and Emission levels of Particulate Matter,
prepared for the Swiss Federal Office for the Environment and EGTEI, 2010.
[31] EGTEI - Expert sub-group on Emerging Technologies/Techniques on Large Combustion Plants
>500 MWth up to 2030 – 2008.
[32] Information from A. Peeters Weem, INFO MIL Netherlands in the scope of the review of the
guidance document for inclusion of information on black carbon emission reduction techniques - June
2012.
th
[33] Mannweiler U. And alls - An anode plant in urban area: fiction or reality? - 12 Arabal, April 2 to
5, 2006.
[34] CIMAC document at
http://www.cimac.com/cimac_cms/uploads/explorer/Working%20groups/black_carbon.pdf
Mis en forme : Français (France)
Gaseous fuels
Gaseous fuel burners are atomizing burners. Atomization increases the surface contact between air
combustion and fuel; it thus improves the combustion process. Atmospheric burners are used as well
as forced air burners.
Gaseous fuel burners can have different operating modes: on-off, 2 loads, modulating load.
On-off burners operate at nominal load.
2 load burners operate at nominal load or 40 – 60 % load depending on the demand.
Graduated load burners operate gradually depending on the demand, with a minimum of 30% load.
This last operating mode permits a better management of the fuel consumption. Hence, emissions are
reduced, especially start-up and shut-down-emissions.[1][1] Code de champ modifié
Different technologies of gaseous fuel burners can be used in domestic appliances. Mis en forme : Anglais (Royaume-Uni)
Low NOx burners limit the formation of NOx emissions. One of the techniques used consists in
recycling combustion flue gases into the burner air inlet. This reduces flame temperature, the oxygen
concentration and thus enables the reduction of NO x emissions.
Premixing type burners mix gaseous fuel and air inside a premixing chamber. The mix is then
distributed on a specific surface where the flame is developing. Different design of surface can be
used. This technique enables control and optimisation of the mixing. It is based on a modular air/fuel
ratio. It avoids air excess during the combustion and thus NO x emissions. This technique can be used
with catalytic combustion.
Radiating burners are only used with gaseous fuel. This technique permits flame temperature
reduction and thus limits NOx emissions during the combustion.
Liquid fuels
Liquid fuel burners are mostly atomizing burners and have the same operating modes as gaseous
fuel burners: on-off; 2 loads; modulating load.
Different technologies of liquid fuel burners can be used in domestic appliances.
Vaporizing burners are burners where liquid fuel is atomized under gaseous form. It enables a more
complete combustion and thus limits pollutant emissions but it is rarely used in boilers.
Low NOx burners are also used for liquid fuel, based on similar techniques as for gaseous fuel.
Biomass fuels
For wood combustion, burners are essentially used for pellets combustion in boilers or stoves.
Pellets are automatically supplied to the burner with a screw conveyor.
Condensing technology is used with gaseous fuel and, increasingly, with liquid fuels. It consists in Code de champ modifié
recovering the latent heat from water contained in the flue gas.
In using the heat exchanger with water at low temperature, the latent heat of the combustion gases
can be recovered. Combustion gases are condensed during the heat exchange. Thus, in using
condensing technology, more heat is recovered with less energy spent than using traditional
technology.
Boiler yield can be increased by 15 to 20 % using this technology compared to the use of recent
standard boilers.[1][1] Mis en forme : Anglais (Royaume-Uni)
The firm Ökofen uses condensing technology in one of its models to diffuse the emitted dust in the Code de champ modifié
condensed water contained in combustion gases. The advantage of this technique is both Mis en forme : Surlignage
improvement of energy efficiency and reduction of dust emissions (-10%). However, atmospheric dust
emissions avoided are contained in condensates. [8] Mis en forme : Surlignage
Flue gases from liquid fuel combustion contain less water to be condensed. Hence, condensing boiler
is less used for liquid fuels.
Condensing boilers are generally associated with low NOx burners.
Boilers
There are different types of wood boilers; mainly log boilers and pellet boilers.
Wood chip boilers can be used but are mainly used in larger installations (thermal output >30 kW).
The same technology is employed for pellet and wood chip boilers: fuel is automatically burnt by a
burner and the flue gases heat a calorific fluid (generally water) in a heat exchanger.
For log wood boilers, logs are loaded on a grate and are burnt using different technologies: vertical,
horizontal or inverted combustion and natural or forced draft.
For natural draft, three combustion techniques are used:
vertical combustion: all the wood logs loaded on the grate catch fire at the same time. This type
of combustion is very difficult to control; hence emissions are high and energy efficiency is low
(10-20%).
horizontal combustion: wood logs don’t catch fire at the same time. Wood logs are first dried
and then burnt. Flames are horizontal. This type of combustion is easier to control than
horizontal combustion and thus performances are higher.
inverted combustion: as in horizontal combustion, wood logs don’t catch fire at the same time
and are dried before being burnt. It is called inverted combustion because instead of going up
as in vertical combustion, flames are going down, through the grate. It is the best controlled
combustion type for natural draft; hence performances are the highest.
Forced draft boilers (also called “turbo” boilers) are more recent and have higher performances than
natural draft. Technique employed is the same as inverted combustion, but in “turbo” boilers,
introduction of combustion air is made by a fan and flue gases are sucked out. These types of boilers
apply staged combustion. Here primary air introduced on top of the fuel is involved in drying the wood
and in a gasification process which occurs in the first stage. In the second stage, gas combustion is
activated by the injection of secondary air. Staged combustion enables the good mixing of combustion
air with the fuel gases formed during the devolatilisation and gasification in the fuel bed [15]. The
control of combustion is improved thus enabling high efficiency and high temperature, key factors for a
complete combustion. and Tthese boilers have higher the highest performances.
In log wood boilers, a heat storage tank can be used to avoid part-load operating conditions. The
boiler can be operated at full load or at steady-state part-load which reduces emissions of combustion
residues. In manually or automatically operated boiler, a heat storage tank is advisable as it helps to
reduce part load emissions.
Low NOx technology as recycling of the combustion flue gases can also be applied to woo d boiler. Self
cleaning option is available for some boilers. It contributes to maintain appliances energy efficiency.
Energy efficiency of appliances depends a lot on heat exchange. Therefore, improvements in heat
exchange are always in development. Longer smoke pipe and the use of fan for convection air can be
used. It transfers more energy from flue gases to indoor air and thus improves energy efficiency and
reduces emissions.
Appliances performances depend also on combustion rateload. When the rate of combustionload is
lower than the nominal rate load (reduced combustion), combustion is bad; : emissions are higher and
energy efficiency is lower. This is due to the low temperature in the combustion chamber.
Automatic appliances, which burn pellets or wood chips, enable to operate at a nominal combustion
rate; therefore better performances are obtained better and dust emissions as well other unburnt
pollutants due to incomplete combustion such as CO and VOCs are lower than with manual
appliances.
Gaseous fuels
Condensing boiler technology combined with the use of a specific burner can be considered as high
efficient technique when gaseous fuels are used. Specific burners enable further re duction especially
low NOx burners for NOx emissions. Micro combustion can also be considered as high efficient
technique with the use of gaseous fuels. [1][1] [2][2]. Mis en forme : Anglais (Royaume-Uni)
Code de champ modifié
Liquid fuels
Mis en forme : Anglais (Royaume-Uni)
Low temperature or condensing boilers combined with the use of specific burners are considered as Code de champ modifié
high efficient technique with the use of liquid fuels. Further NO x emission reductions can also be
achieved by the use of specific burners.
Biomass fuels
For wood logs boilers, inverted combustion with forced draft and recycling of the combustion flue
gases can be considered as high efficient technique. Energy efficiency can be increased and
emissions reduced with the use of a water tank as hydro-accumulator.
The use of pellets as fuel in boilers can also be considered as high efficient technique, so is the use of
condensing technology for solid fuels use.
Dust and VOC emission level mainly depend on the combustion efficiency; the more complete the
combustion is, the lower are the emission levels.
For inserts, the use of catalysts reduces atmospheric emissions of combustion residues by dropping
combustion temperature. This technique is currently used in USA and begins to appear in Europe.
According to measurements reports [10][10] and [11][11], use of catalysts in inserts can divide dust Mis en forme : Anglais (Royaume-Uni)
emissions by two. Code de champ modifié
For stoves, the use of pellets can be considered as a high energy efficiency technique. Mis en forme : Anglais (Royaume-Uni)
Masonry stoves diffuse energy stored during several hours. It allows obtaining a good ambient Code de champ modifié
temperature during several hours without use reduced combustion which produces a lot of pollutants.
However, any technology used to increase energy saving and combustion efficiency, whatever fuel
used, contributes to pollutant emissions reduction by reduction of fuel consumption.
7.1.3.2 Pollutants
SO2
SO2 emissions depend on the sulphur content of the fuel used. Therefore, the main measure to reduce
SO2 emissions is to use sulphur-free fuels or fuels with low sulphur content. For brown coal, the
addition of calcium hydroxide is possible in order to fix sulphur in the ash.
NOx
NOx emissions are influenced by different parameters such as: the type of fuel, the flame temperature,
the air volume, the residence time in the combustion chamber and the nitrogen content of the fuel.
Available techniques to reduce specifically NO x emissions are the use low NOx burners or premixed
modular air/fuel ratio burner. The premixed modular air/fuel ratio burner enables the NO x formation
reduction in controlling the air content in the mix.
The following table gives an overview of achievable NO x emission levels using selected gas firing
domestic combustion appliances at full load.
Table 1: achievable NOx emissions using selected gas firing domestic combustion appliances.
[2][2] Code de champ modifié
Mis en forme : Anglais (Royaume-Uni)
Heat output NOx
(kW) (g/GJ)
Forced air condensing boiler + premixing burner with modular gas/air
24 18
ratio
Forced air boiler + premixed low-NOx burner 24 29
Forced air boiler + conventional burner 24.6 62
Conventional boiler and burner 24.2 85
VOCs
VOC emissions are mainly influenced by the combustion efficiency. There is no technology used to
reduce specifically VOC. Available techniques to reduce VOC emissions are actually the use of
technologies enabling the most complete combustion as possible. These technologies are detailed in
the previous paragraphs concerning wood fuel technologies.
have been described in the previous paragraphs concerning wood fuel technologies. Dust emissions
from existing appliances can be obtained by replacing them with modern appliances showing higher
energy efficiency and better combustion conditions.
Besides those technical measures, especially for manually operated wood stoves and boilers, proper
operation and quality of fuel are essential to avoid high-pollutant emissions in practice. Ignition of the
wood from the top instead of ignition from the bottom significantly reduces e missions from the start-up
phase. Throttling the combustion air leading to low heat loads needs to be strictly avoided . [15]. The
use of untreated wood only and the correct seasoning of wood for moisture content are also very
important prerequisites. Public information programs can help in raising the awareness for these
requirements [15].
Secondary measures to reduce dust emissions can also be considered with the use of solid fuels. The
proven technologies for dust removal are multicyclones, electrostatic precipitators (ESP) and fabric
filters which are described in more detail in paragraphs 6.5 and 7.1.2.3.
Code de champ modifié
Studies have shown that ESP and fabric filters are suited in the range <1 MW down to 100 kW [8][8].
For installations < 500 kW, costs are still relatively high, but there is positive experience with some
3
reference installations in this range. Dust emission reductions below 50 mg/m (13% O2) can be
reached with a simple (1-stage) ESP, while reductions to 10-20 mg/m³ (13% O2) have been
demonstrated with optimized (multi-stage) ESP. Fabric filters can reduce dust emissions to < 10 or
even <5 mg/m³ [8][8], [15]. Mis en forme : Police :10 pt, Anglais
(États Unis)
Small-scale electrostatic precipitators (ESP) have been developed in some countries, e.g. Norway,
Germany and Switzerland [8] [13], [15], [17], and can be considered as available techniques to reduce Code de champ modifié
dust emissions from domestic wood combustion appliances < 50 kW including single-room heaters. Mis en forme : Police :10 pt, Anglais
Under ideal conditions small-scale ESP can reduce 90 % of the dust particles with a diameter superior (Royaume-Uni)
to 0.1 µm [7][7]. However these separators are often based on a design which for cost reasons is Mis en forme : Police :10 pt, Anglais
simplified compared to industrial applications. In some cases only moderate separation efficiencies (Royaume-Uni)
below 50% may be expected, especially when there is re-entrainment after agglomeration of particles. Code de champ modifié
Field tests have shown that small-scale ESP now available on the market are only effective on the
long-term when used with modern combustion installations enabling a rather complete and clean Mis en forme : Police :10 pt, Anglais
(Royaume-Uni)
combustion. Older combustion installations with poor combustion technology and correspondingly high
particulate emissions may quickly lead to overload and clogging [8][18]. In the current state of the art a Mis en forme : Police :10 pt, Anglais
general retrofitting of older installations with small-scale ESP is not recommended. (Royaume-Uni)
Code de champ modifié
More generally, dust is deposited in the stoves, boilers, ducts, stacks, etc. Thus, to limit emissions of
dust, boilers or stoves need to be cleaned regularly. Self cleaning option can also be seen as an Mis en forme : Anglais (Royaume-Uni)
efficient technique for the dust reduction. Code de champ modifié
Table 2: achievable dust emission levels of biomass combustion appliances < 1 MW [2][16] Code de champ modifié
Code de champ modifié
Appliance type 1. Secondary 2. Achievable Mis en forme : Centré, Sans
abatement dust emission numérotation ni puces
technology level
3
3. mg/mn
at 13% O2
Wood stoves and 20 - 40
closed insert
appliances
Log wood boilers 15 -30
(with heat storage
tank)
Pellet stoves & 15 - 30
boilers
Automatic wood multicyclone 75 - 150
boilers
simple ESP 20 - 50
improved ESP < 10 - 20
fabric filter < 10
The investment cost for a wood boiler with inverted combustion and forced draft is from 3 000 to 7 650 Code de champ modifié
euros, for installations from 15kW to 150kW. An investment for heat accumulator is from 1 500 to Mis en forme : Anglais (Royaume-Uni)
2 750 euros [10][10], [12][12].
Code de champ modifié
The investment cost for a pellet boiler is 7 000 to 15 000 euros for installations from 15 kW to a few Mis en forme : Anglais (Royaume-Uni)
MW [12][12].
Code de champ modifié
Mis en forme : Anglais (Royaume-Uni)
Additional cost of catalysts addition in inserts is about 1 000 euros [14][14]. Mis en forme : Anglais (Royaume-Uni)
Code de champ modifié
Table 2: investment per kW heat output for wood heating systems and dust abatement
1
equipment [8][8] Code de champ modifié
Mis en forme : Anglais (Royaume-Uni)
1
Data from 2005/2006, converted to € (1 SFR= 0,64523 €) and rounded ; for calculation details see source report
[17] http://www.ruegg-cheminee.com/ww/de/pub/produkte/partikelabscheider/vorteile.htm
[18] H. Hartmann et al., Electrostatic precipitators for small-scale wood combustion systems –
Results from lab- and field tests, Central European Biomass Conference (CEBC), 26.-
28.January 2011 in Graz,
http://www.biomasseverband.at/uploads/tx_osfopage/WSF_5_Hartmann.pdf.
[19] http://www.econergy.ltd.uk/docs/files/Case%20studies/Greenland.pdf
7.2.1 Coverage
This section covers emissions from boiler installations and gas turbines with a net thermal input
between 1 and 50 MW th. In the following, the term “boilers” is meant in contrast to combustion engi nes
or turbines and includes all kinds of boilers and process heaters.
The following installations are not covered by this section:
plant in which the products of combustion are used for direct heating, drying, or any other
treatment of objects or materials, e.g. reheating furnaces, furnaces for heat treatment;
post-combustion plant, i.e. any technical apparatus designed to purify the waste gases by
combustion that is not operated as an independent combustion plant;
facilities for the regeneration of catalytic cracking catalysts;
facilities for the conversion of hydrogen sulphide into sulphur;
reactors used in the chemical industry;
coke battery furnaces;
cowpers;
waste incinerators;
and
plant powered by diesel, petrol or gas engines, irrespective of the fuel used (For information
about stationary engines see document "New stationary Engines" 7-41)
7.2.3.1 SO2
Table 1: emission sources and selected SO2 control measures with associated range of
emission levels (solid and liquid fuels) resp. upper emission level (gaseous fuels) in
combustion installations between 1 and 50MWth [1]
3
Emission source Control measures SO2 emission level (mg/Nm )
Solid fuel
Use of low-sulphur fuel,
Boilers other than fluidized
Sorbent injection, 50-1000
bed combustion (FBC)
Flue gas desulphurisation,
Use of low-sulphur fuel,
Fluidized bed combustion Sorbent injection, 50-400
Flue gas desulphurisation,
Liquid fuel
Use of low-sulphur fuel,
Boilers Sorbent injection, 50-850
Flue gas desulphurisation
Gaseous fuel
Boilers: Refinery gas Use of low-sulphur fuel, 100
Boilers: Liquefied gas Sorbent injection, 5
Boilers: Other gaseous fuel Flue gas desulphurisation 35
If not stated otherwise, values are daily averages assuming an oxygen content by volume in the waste gas of
3 % in the case of liquid and gaseous fuels, 6 % in the case of solid fuels.
3
If emission reduction measures are regarded, for low sulphur fuels a level of 700 mg/Nm can be
3
reached, for sorbent injection a level of 200 - 400 mg/Nm and for desulphurisation a level of 50 – 200
3
mg/Nm .
7.2.3.2 NOx
Table 2: emission sources and selected NOx control measures with associated upper emission
levels in combustion installations between 1 and 50MW th [1], [2][1], [2]
3
Emission source Control measures NOx emission level (mg/Nm )
Solid fuel
Grate firing Low-NOx burner
Air staging
< 200-400
Flue gas recirculation
Boiler design
Pulverized coal Low-NOx burner
Air staging
< 200-400
Flue gas recirculation
Boiler design
Air staging
Flue gas recirculation < 200-500
Fluidized bed combustion Boiler design
New Gas-Turbines
Dry low-NOx premix burner or SCR
Fuel: natural gas 20-50
If not stated otherwise, values are daily averages assuming an oxygen content by volume in the waste gas of
3 % in the case of liquid and gaseous fuels, 6 % in the case of solid fuels and 15 % in the case of gas
turbines.
3
Emission source Control measures Dust emission level (mg/Nm )
new existing
Cyclone < 50 < 100
Solid fuel, 1- to 5 MWth ESP 5 - 20 5 - 30
FF 5 - 20 5 - 20
ESP 5 - 20 5 - 30
Solid fuel, 5 - to 50 MWth
FF < 5 - 20 < 5 - 20
ESP 5 - 50 5 - 50
Liquid fuels, 1- to 5 MWth FF < 5 – 20 < 5 – 20
Use of low ash fuel < 5 - 50 < 5 - 50
ESP 5 - 20 5 - 50
Liquid fuels, 5 - to 50 MWth
FF < 5 - 20 < 5 - 20
Gaseous fuels 2-5 2-5
If not stated otherwise, values are daily averages at standard conditions assuming an oxygen content by
volume in the waste gas of 3 % in the case of liquid and gaseous fuels, 6 % in the case of mineral solid
fuels, 11 % in the case of wood
Because BC is formed during incomplete combustion. I, it is mainly associated to particles with a
diameter less than 1 µm. In such combustion installations, BC content of dust can increase during
start-up and shut-down periods. A smooth, continuous and optimised combustion reduces dust
(including PM10, PM2.5 and BC) emissions as described in chapter 6.4. OOnly reduction techniques
able to remove fine particles will have a significant efficiency on BC emissions. In such combustion
installations, BC content of dust increases during start-up and shut-down periods. Combustion
technique optimisation reduces dust (including PM10, PM2.5 and BC) emissions as described in chapter
6.4. Chapter 6.5 provides information on the efficiency of ESP and FF for dust (including PM10, PM2.5
and BC).
7.3.1 Coverage
The combustion sector covers a range of different combustion techniques suited to different fuels:
solid fuels, such as coal, lignite, peat, biomass, liquid and gaseous fuels, including low calo rific and
blast furnace gas. This section covers boilers (small: 50 - 100 MW th, medium: 100 - 300 MW th, and
large: > 300 MW th) and gas turbines (> 50 MW el). In the following, the term “boilers” is meant in
contrast to combustion engines or turbines and includes all kinds of boilers and process heaters. The
given capacity classes in terms of rated thermal input refer to the lower heating value (LHV) of the
respective fuel.
The following installations are not covered by this section:
plant in which the products of combustion are used for direct heating, drying, or any other
treatment of objects or materials, e.g. reheating furnaces, furnaces for heat treatment;
post-combustion plant, i.e. any technical apparatus designed to purify the waste gases by
combustion that is not operated as an independent combustion plant;
facilities for the regeneration of catalytic cracking catalysts;
facilities for the conversion of hydrogen sulphide into sulphur;
reactors used in the chemical industry;
coke battery furnaces;
cowpers;
waste incinerators;
and
plant powered by diesel, petrol or gas engines, irrespective of the fuel used (For information
about stationary engines see document "New stationary engines" 7-41)
Fluidized bed combustion (FBC) is a combustion technology for burning hard coal and lignite, but
also low-grade fuels such as waste, peat and wood, which are not regarded in this section. Fuel is
injected into a hot turbulent bed of reactive or inert material while a flow of air passes up through the
bed. Emissions can be further reduced via integrated combustion control in the system. Within the
sector of energy conversion, atmospheric fluidized bed combustion is a well-established commercial
technology. Depending on the velocity of the fluidisation air, two types of atmospheric fluidised bed
combustion do exist, the atmospheric bubbling fluidised bed combustion (BFBC), and the atmospheric
circulating fluidised bed combustion (CFBC). Pressurized fluidized bed combustion (PFBC) operates
at elevated pressures and produces a high-pressure gas stream at temperatures that can drive a gas
turbine.
(b) Turbines
Gas turbines are used for the transformation of thermal energy into mechanical energy. They use a
steady flow of a gas (mostly air), compressed and fired with gaseous or liquid fuel. Gas turbines are
increasingly used for electricity production in base and intermediate load but are also still used for
peaking load in simple cycle (then fired with gas or light oil). In combined cycle power plants a gas
turbine is combined with steam turbine to generate electricity.
Integrated gasification combined cycle (IGCC) process incorporates coal or biomass gasification
and combined cycle plants. The gasified solid fuel is burned in the combustion chamber of the gas
turbine. The technology also exists for heavy oil residue. However, this process is not yet fully
commercialized, a small number of demonstration units, mainly around 250 MWe size are being
operated in Europe and the USA.
7.3.3.1 SO2
This section provides descriptions of the abatement options that are generally used to reduce
emissions of sulphur oxides from combustion installations. Emissions of SO 2 are highly dependent on
the sulphur content in coal burned and the emissions control system employed. In general, techniques
to reduce sulphur oxides are divided into primary and secondary measures.
Primary measures
Use of low sulphur fuel, the SO2 emissions during combustion are directly related to the sulphur
content of the fuel used. Fuel switching (from high- to low-sulphur fuels) leads to lower sulphur
emissions. This measure is widely applied. However there may be certain restrictions, such as the
availability of low-sulphur fuels and the adaptability of existing combustion systems to different fuels.
Fuel switching to natural gas can be sufficient for reducing SO 2, in case of other fuels depending on
the fuel sulphur content it can be used as a supplementary technique.
Secondary measures
Flue gas desulphurisation (FGD) processes. These processes aim at removing already formed
sulphur oxides, and are also referred to as secondary measures. The state -of-the-art technologies for
flue gas treatment are all based on the removal of sulphur by wet or dry processes.
In wet processes, wet slurry waste or by-product is produced, and flue gas leaving the absorber is
saturated with moisture. Seawater scrubbing utilises seawater’s inherent properties to absorb and
neutralise sulphur dioxide in flue-gases. If a large amount of seawater is available near a power plant,
it is most likely to be used as a cooling medium in the condensers. Wet scrubbers, especially the
limestone-gypsum processes, are the leading FGD technologies. They have about 80% of the market
share and are used in large utility boilers. The efficiency of sulphur dioxide removal may be increased
up to 92-98%. In case of retrofitting the efficiencies are lower reaching up to 95%.
In semi-dry processes, a slurry of alkaline reagent is atomized and injected into a vessel where it
reacts with the SO2 in the flue gas to produce calcium sulphate or sulphite products [4]. Sulphur
dioxide removal efficiencies of 80 to 95% have been achieved.
Table 1: emission sources and selected BAT SOx control measures with associated emission
levels in combustion installations (PM is for primary measures)
FGD
If not stated otherwise, values are daily averages assuming an oxygen content by volume in the waste
gas of 3 % in the case of liquid and gaseous fuels, 6 % in the case of solid fuels.
7.3.3.2 NOx
The most important oxides of nitrogen with respect to releases from combustion processes are nitric
oxide (NO), nitrogen dioxide (NO2) and nitrous oxide (N 2O). NO and NO2 are commonly referred to as
NOx. [2]. NOx is formed during most combustion processes by one or more of three chemical
mechanisms: “thermal” NOx resulting form oxidation of atmospheric molecular nitrogen, “fuel” NO x
resulting from oxidation of chemically bound nitrogen in the fuel, and “prompt” NOx resulting from
reaction between atmospheric molecular nitrogen and hydrocarbon radicals [4]. Only the first two
mechanisms are of major importance in combustion plants.
This section provides descriptions of the abatement options that are generally used to reduce
emissions of nitrogen oxides from combustion installations. In general, techniques to reduce nitrogen
oxides are divided into primary and secondary measures. Primary measures have been developed to
reduce NOx emissions at source during the combustion process by regulating flame characteristics
such as temperature and fuel-air mixing. Secondary measures operate downstream of the combustion
process and remove NOx emissions from the flue gas.
The application of primary measures is limited by operational and fuel specific parameters that
influence the safe operation. It is also limited by layout feasibility in existing i nstallations.
reactant used, which can be: ammonia, urea or ammonia solution. The SNCR process has found
application for various types of fossil fuels. The average achievable NO x abatement efficiency is in the
range of 30-50% [3]. SNCR is less costly than SCR because of the absence of catalyst and can be
applied also at small installations. But SNCR is not well suited for plants, which are operated at
variable load (risk of excessive ammonia slip and smell).
Table 2: emission sources and selected BAT NOx control measures with associated emission
levels in combustion installation (PM is for primary measures)
New Gas-Turbines
Dry low-NOx premix burner or
Fuel: natural gas SCR 20-50
Wet controls
Fuel: diesel oil or process gas
SCR
1
The BAT associated emission levels are based on a daily average, standard conditions and represents a typical
load situation. For peak load, start up and shut down periods, as well as for operational problems of the flue gas
cleaning systems, short-term peak values, which could be higher, have to be regarded.
If not stated otherwise, values are daily averages assuming an oxygen content by volume in the waste
gas of 3 % in the case of liquid and gaseous fuels, 6 % in the case of solid fuels and 15 % in the case
of gas turbines.
Dust is emitted from the combustion process, especially from the use of heavy fuel oil, coal and solid
biomass. Dust emissions of solid fuel combustion are higher than dust emissions from fuel oil
combustion. Because In such large combustion, BC content of dust is very low due to very high
combustion efficiency generally achieved. BC is formed during incomplete combustion and is, it is
mainly associated to particles with a diameter less than 1 µm. In such large combustion installations,
BC concentrations in dust can increase during start-up and shut-down periods in which incomplete
combustion conditions can occur. A smooth, continuous and optimised combustion reduces dust
(including PM10, PM2.5 and BC) emissions as described in chapter 6.4. Only reduction techniques able
to remove fine particles have a significant efficiency on BC emissions. In such large combustion
installations, BC concentrations of dust increase during start-up periods. BC content of dust is then
very low due to very high combustion efficiency. The proven technologies for dust removal in power
plants are fabric filters and electrostatic precipitators (ESPs) [6].
Electrostatic precipitators (ESPs) are the dust emissions control technology, which is most widely
used in coal-fired power generating facilities [5]. They remove particles from a flowing gas using
electrical forces. The particles are given an electrical charge by forcing them to pass through a corona,
a region in which gaseous ions flow. The electrical field that forces the charged particles to the walls
comes from electrodes maintained at high voltage in the centre of the flow lane [7].
These control devices remove dust, including particulate matter less than or equal to 10 and 2.5
micrometers and hazardous air pollutants that are in particulate form, such as most met al oxides [7].
Electrostatic precipitators are used in both solid and liquid fired combustion plants and are available
for small and large-scale combustion plants [1]. ESPs provide high dust and fine particulate removal
efficiency (and consequently BC which is a component of fine particulates if present).The efficiency of
ESPs is described in chapter 6.5.
Fabric filters (Baghouses), are widely used worldwide for removing particles. A fabric filter unit
consists of one or more isolated compartments containing rows of fabric bags in the form of round,
flat, or shaped tubes, or pleated cartridges. Particle-laden gas passes up along the surface of the bags
then radially through the fabric. Particles are retained on the upstream face of the bags, and the
cleaned gas stream is vented to the atmosphere [8]. This control devices remove dust, including
particulate matter less than or equal to 10 and 2.5 micrometers and hazardous air pollutants that are
in particulate form, such as most metal oxides [9]. The choice between ESP and fabric filtration
generally depends on coal type, plant size, and boiler type and configuration [ 5]. Fabric filters provide
high dust and fine particulate removal efficiency (and consequently BC which a component of fine
particulates if present). The efficiency of fabric filters is described in chapter 6.5.
Wet scrubbers, are air pollution control devices that remove dust and acid gases from waste gas
streams of stationary point sources provided that the PM level is already within the right range to
guarantee safe operation of the scrubber (if not another PM control technology is required upstream
the FGD). The low capital cost of wet scrubbers compared to that for ESPs and baghouses makes
them potentially attractive for industrial scale use, though this may be offset by a relatively high
pressure drop and operating costs [3]. The pollutants are removed primarily through the absorption of
the pollutant onto droplets of liquid. The liquid containing the pollutant is then collected for disposal.
There are numerous types of wet scrubbers, which remove both acid gas and dust.
< 5 - 20 (new)
Boiler, 5 - 30 (existing)
Fuel: oil ESP or FF
(split view industry: new and existing
plants: 10-50 ESP)
Boilers 100 – 300 MWth
< 5 - 20 (new)
Boiler, ESP or FF in combination with 5 - 25 (existing) (split view industry:
Fuel: oil FGD new plants: 5-30, existing plants: 5-
50)
Boilers >300 MWth
< 5 - 10 (new)
Boiler; 10 –20 (existing)
ESP or FF in combination with
Fuel: coal and lignite FGD (split view industry: new plants: 10-30,
existing plants: 10-100; 10-50 comb.
wet FGD)
< 5 –20 (new)
Circulating FBC; 5-20 (existing)
Fuel: coal, lignite ESP or FF
(split view industry: new plants: 10-30,
existing plants: 10-100; 10-50 comb.
wet FGD)
Boiler; Fuel: biomass and peat
< 5 - 20 (new)
Circulating FBC; Bubbling FBC ESP or FF
Fuel: biomass and peat 5 - 20 (existing)
< 5 - 10 (new)
Boiler; ESP or FF in combination with 5 - 20 (existing)
Fuel: oil FGD
(split view industry: new plants: 5-30,
existing plants: 5-50)
1
The BAT associated emission levels are based on a daily average, standard conditions and represents a typical
load situation. For peak load, start up and shut down periods, as well as for operational problems of the flue gas
cleaning systems, short-term peak values, which could be higher, have to be regarded.
If not stated otherwise, values are daily averages assuming an oxygen content by volume in the waste
gas of 3 % in the case of liquid and gaseous fuels, 6 % in the case of solid fuels.
Table 4: indicative costs of NOx emissions abatement techniques for boiler plants (1999 Euros,
Environment Agency)
Table 5 shows the indicative costs ranges for the sulphur abatement technologies described above.
However, when applying these technologies to individual cases, it should be noted that investment
costs of emission reduction measures will depend among other things on the particular technologies
used, the required control systems, the plant size, the extent of the required reduction and the
timescale of planned maintenance cycles. Operation and maintenance costs for SO 2 scrubbers for
boiler plants increase with increasing sulphur content since more reagent is required to treat the same
volume of gas [11].
Table 5: indicative costs of SO2 emissions abatement techniques for boiler plants (2001 Euros,
EPA)
Table 6: indicative costs of dust emissions abatement techniques for boiler plants (1999 Euros,
Environment Agency)
Indicative Indicative
Typically
Control options achievable Process capacity capital cost Operating cost
emission reduction
€/kW €/kWh
Reduction to below
ESP 3 various 35 0.00042
25 mg/m
Reduction to below
Fabric filters 3 various 14 0.0015
25 mg/m
7.4 Mineral Oil and Gas Refineries for SO2, NOx dust (including PM10,
PM2.5 and balck black carbon) emissions
7.4.1 Coverage
The section covers emissions from combustion processes in refineries burning non-commercial fuels
or a mixture of commercial and non-commercial fuels, Fluidised Catalytic Cracking (FCC) units,
Sulphur Recovery Units (SRU) and flares.
Refinery fuels are highly variable in nature and comprise both liquid and gaseous streams often used
in conjunction. A significant part of the fuel used for process heaters is provided by refinery gas.
Various processes contribute a large variety of compounds to the refinery gas, resulting in varying
emissions. Other fuels in use in mineral oil refineries are natural gas, petroleum coke, heavy fuel oil, or
other gaseous or liquid residues originating from atmospheric and vacuum distillation, fluid catalytic
cracking (FCC) and thermal catalytic cracking (TCC). Refinery processes such as FCC may involve
combustion of coke laid down on the catalyst and CO as well as supplementary fuel for steam raising.
Use of petroleum coke as a gasification feedstock occurs but is not very common
Many refinery units discharge through a common stack. The emissions from refineries associated with
the key processes in this chapter are NOX, SOX and dust (including PM10, PM2.5 and black carbon
(BC)). BC is an inseparable part of fine particles. Its emissions from combustion units are low as these
emissions are linked to may occur during incomplete combustion not frequent in this activity.
Incomplete combustion may occurencountered during start-up, shut-down and soot-blowing periods
and if the installation is not operated in optimised combustion condition . Flares can be a source of BC
emissions.
A work is still progress to revise the BREF document on refineries dated 2003 [3], at the Institute for
Prospective Technological Studies (IPTS) in Seville. The 2003 document is the main reference for
most of the BAT AELs presented in this chapter.
Gas turbine installations are used for the transformation of thermal energy into mechanical energy.
They use a steady flow of a gas (mostly air), compressed and fired with (sometimes non -commercial)
gaseous or liquid fuel. The energy in the turbine exhaust gas can be recovered in a heat recovery
section downstream of the gas turbine. This heat recovery section comprises of a steam boiler or a
process heater which can be equipped with additional fuel supply. Steam turbines are used to
transform the steam pressure to power. Combined cycle processes combine the gas and steam
turbines processes to produce power at higher efficiency than reached with open-cycle turbines.
(Fluid) Catalytic cracking (FCC) is the most widely used conversion process for upgrading heavier
hydrocarbons into more valuable lower boiling hydrocarbons. It uses heat and a catalyst to break
larger hydrocarbon molecules into smaller, lighter molecules. A catalytic cracking unit is usually part of
a processing complex that includes a gas plant, amine treating of the light (incl. C3/C4) gases and
treatment of various product streams [3].
Sulphur Recovery Units (SRU) typically comprise a Claus unit and a tail gas unit. They recover
elemental sulphur from the H 2S recovered in the acid gas removal section. The tail gas treatment
section is designed to increase the overall sulphur recovery. They work by partial combustion of the
hydrogen sulphide-rich gas stream and then reacting the resulting sulphur dioxide and unburned
hydrogen sulphide in the presence of a catalyst to produce elemental sulphur [3].
Flare-Gas-System consists at least of a flare knock-out drum and a flare stack as well as additional
supporting equipment and is connected through a flare gas pipeline grid to many refinery processes.
The overall goal of a flare gas system is to assure or support a pressure release of a process
equipment (e.g. columns, vessels) if necessary and to keep the refinery processes in a safe condition
even in an emergency case. During shut-down or start-up periods of units, e.g. before and after
maintenance activities, the flare gas system has to collect off-gases for safe discharge. Flare systems
are sources of SO2, NOx and dust (including BC) emissions.
The release of sulphur dioxides is directly linked to the sulphur content of the refinery fuel gas and fuel
oils used for combustion units. Heavy fuel oil residues normally contain significant proportions of
sulphur and nitrogen depending mainly on their source and the crude oil [2].
Various flue gas desulphurisation techniques exist with SO 2 removal efficiencies ranging from 50 to 95
to 98 %. SO2 is removed in general from the flue gas by means of wet scrubbers (lime/limestone,
Wellman-Lord, seawater, wet gas sulphuric acid process WSA), spray dry scrubbers, application of
sorbent injection and regenerative processes. By using wet lime/limestone reduction rates from 90 to
98% are achievable. With additive injection and spray dry scrubbers reduction rates above 92% are
achievable. However, these efficiency figures are dependent on input concentrations, sizes of units
and their specific application.
Improvement of the energy efficiency by enhancing heat integration and recovery throughout the
refinery, applying energy conservation techniques and optimising the energy production/consumption
is considered BAT [3].
The use of low sulphur content for the overall refinery liquid fuel pool achieved for example, by
hydrodesulphurisation, is considered to be BAT and FGD for large boilers/furnaces where it is cost-
effective. Fuel switching is also an option.
For catalytic cracking, SO2 emission reduction by using Sulphur Reducing Additives (SRA), FGD of
the regenerator gas with 95 – 99 % efficiency (emission target depends on uncontrolled level) is
considered BAT if economically viable [3].
Wet scrubbing (for example Wellman Lord scrubbing) is one option for FGD, a suitably well designed
process will normally provide an effective removal efficiency of both SO 2/SO3 and particulates. With
the inclusion of an extra treatment tower, to oxidise the NO to NO 2, NOx can also be removed partially
[3].
Before elemental sulphur can be recovered in the SRU, the fuel gases (primarily methane and ethane)
need to be separated from the hydrogen sulphide. This is typically accomplished by dissolving the
hydrogen sulphide in a chemical solvent (absorption). Solvents most commonly used are amines [3].
For sulphur recovery units (SRU), it is BAT to apply a staged SRU, including tail gas treatment with
the recovery efficiency given below (based on acid gas feed to the SRU), the range depends on cost
effectiveness considerations [3].
Table 1: emission sources and selected BAT SOx control measures with associated emission
levels in mineral oil refineries
7.4.3.2 NOx
Refinery NOX emissions primarily originate from combustion units and catalytic cracking. Besides the
relevance of the fuel type, NOx emissions depend on fuel nitrogen content (for liquid fuels) or
hydrogen content and C3+ content (for gaseous fuels), burners and heaters design, and operating
conditions [4].
In general, the reduction of the fuel consumption and the replacement of existing burners with low -
NOx burners during major scheduled shutdowns is considered to be BAT as far as is possible with
respect to the existing process engineering design.
For heaters and boilers burning gaseous fuel an application of a suitable combination of the following
3
primary and secondary measures allowing to achieve emissions levels from 20 to 150 mg/Nm is
considered to be BAT [3]:
high thermal efficiency furnace/boiler designs with good control systems
jowlow-NOx burners technique
flue gas circulation in boilers
SCR or SNCR
For heaters and boilers burning combinations of gas and liquid fuel (liquid fuel as majority fuel) an
application of a suitable combination of the following primary and secondary measures allowing to
3
achieve emissions levels from 55 to 300 mg/Nm is considered to be BAT [3]:
fuel with low nitrogen content
low-NOx burners technique
flue gas circulation in boilers
reburning technique
SCR or SNCR to liquid fuels heavier than gasoil type (if technically and economically feasible)
For gas turbines an application of a suitable combination of the following primary and secondary
3
measures allowing to achieve emissions levels from 20-75 mg/Nm is considered to be BAT [3]:
diluent injection
dry low NOx combustors
SCR (if technically and economically feasible)
Table 2: emission sources and selected BAT NOx control measures with associated emission
levels in mineral oil refineries
The main emission sources of dust in refining are process heaters and boilers firing liquid heavy fuel
oil, catalytic cracker regenerators, coke plants, incinerators, decoking and soot blowing of heaters and
the flare [3].
The emission levels of dust depend on various parameters such as fuel type, burner design, and
oxygen concentration at the outlet of the radiant section and can vary widely.
The dust emissions from furnace and boilers burning heavy fuel oil consist of a mix of ash, soot and
BC. Mineral matter is a natural component of crude oil and becomes ash during combustion of heavier
fuel oils. Soot and BC result from imperfections in the combustion process. BC content of dust is low
in continuous processes with optimised combustion conditions but can be higher during start-up and
shut-down periods in which imcomplete combustion condition can occur.
The size of the particulate matter from heaters and boilers burning heavy fuel oil is in the order of 1
m. Particulate matter removal techniques mainly used are ESPs. An application of a suitable
combination of the following techniques is considered to be BAT for the reduction of dust [3]:
Reduction of the fuel consumption
Maximizing the use of gas and low ash content liquid fuels
Improved atomisation on the liquid fuels
The use of ESP or filters in the flue gas of heaters and boilers when burning heavy liquid fuel s
[3] if technically and economically feasible.
Table 3: Emission sources and selected BAT dust control measures with associated emission
levels in mineral oil refineries
Dust emission
Emission level associated
One or combination of control measures 1
source with BAT
3
(mg/Nm )
Fuel type: heavy liquid fuel (majority fuel)
By a combination of:
- Reduction of the fuel consumption 5 – 20 [3]
Heaters,
boilers - Maximizing the use of gas and low ash content liquid fuels (split view industry:
- Steam atomisation on the liquid fuels 5-50)
- Use of ESP
By a suitable combination of:
7.5.1 Coverage
This chapter covers activities originating VOC emissions in the oil refineries: fugitive emissions, flare
system, storage tanks, and oil separators. Fugitive VOC emission sources (such as leakages from
flanges, pumps or any pieces of equipment) and losses from the storage facilities of liquid products
may contribute more than 50 % to the total VOC emissions. VOC emissions also occur from
processes linked to combustion and from flares but these are lower emitters of VOCs in refineries.
The refinery petrol dispatch station is covered by chapter 7.20.
The achievable emission reduction for a large tank using an internal floating roof is at least 97 %
(compared to a fixed roof tank without measures), which can be achieved when over at least 95 % of
the circumference of the gap between the roof and wall is less than 3.2 mm and the seals are liquid
mounted, mechanical shoe seals. By applying liquid mounted primary seals and rim mounted
secondary seals, some further improvement in emission reductions can be achieved. However, the
smaller the tank and the smaller the numbers of turnovers are, the less effective the floating roof is.
However, measurements of diffuse sources (e.g. tanks) can only be made over short periods and
extrapolation to provide annual estimates of emissions introduces significant errors due to the
temporal variations in emissions from these types of sources.
Table 1: associated Emission Levels with BAT to reduce VOC emissions from storage
Emission sources Combination of BAT BAT Associated Emissions
Levels for VOCs
Internal floating roof
Storage tanks of volatile External floating roof 97 to 99.5 % compared to a
products Other tank designs and appropriate fixed roof tank without
colours measure*
* If the efficiency cannot be reached because of the specific characteristics of a storage tank (such as small
throughput, small diameter), best available primary and secondary seals have to used.
Table 2: associated Emission Levels with BAT to reduce VOC emissions in refinery loading and
unloading operations
Emission source BAT and reduction efficiency BAT associated
emission levels*
3
kg VOC/m /kPa
[1], [6]
Road tanker filling, bottom or 0.0228 x 0.05 to
top loading and vapour 0.0228 x 0.01
balancing during previous off
loading and VRU
Rail tanker, top loading and 0.0108 x 0.05 to
VRU VRU with 95 to 99 % efficiency [1] 0.0108 x 0.01
Marine tanker, typical cargo 0.004 x 0.05 to
tank condition 0.004 x 0.01
Barge – typical cargo tank 0.007x 0.05 to
conditions 0.007 x 0.01
*Not available in reference [1] but calculated with reference [6].
kPa: True vapour of the volatile product.
[4] VAN DER REST A. and others: Best available techniques to reduce emissions from refineries -
CONCAWE report n°BAT/II – air – February 1999
[5] GOODSELL P.: Information mail to CITEPA of September 8, 2003. Provided in reference [3]
[6] CONCAWE - Air pollutant emission estimation methods for E-PRTR reporting by refineries - Report
n°1/2009 (Amending report 2007)
[7] EGTEI synopsis sheets on NMVOC from refineries – October 2005
[8] EPA - Emission factor documentation for AP42 section 7.1 - Organic liquid storage tanks - Final
report - September 2006
[9] EN15446:2008 Fugitive and diffuse emissions of common concern to industry sectors -
Measurement of fugitive emission of vapours generating from equipment and piping leaks
[10] EPA - Protocol for equipment leak - Emission estimates EPA 453-95-017 – 1995
[11] Edda Hoffmann, UBA Germany: comments on the first version of the guidance document
7.6.1 Coverage
This section deals with emissions originating from coke oven furnaces in iron and steel production.
The further use of coke or coke oven gases is not regarded here, for information see section “Iron and
Steel Production”.
Coke oven plant: Coke is produced via heating of coal mixtures in absence of oxygen. The coke
oven is a chamber made up of heat resistant bricks. A heating wall consists of heating flues with
nozzles for fuel supply and with air intakes. In general, cleaned coke oven gas is used as a fuel as
well as other gases such as blast furnace gas. The coke is afterwards used mainly as a reducing
agent in blast furnaces.
Due to high costs of coke, replacement by pulverized coal, fuel oil, plastics etc. may replace it as
reducing agents in the blast furnace route [2]. This reduction in coke consumption also helps to
reduce total emissions from coke production. Several 'direct' and 'smelting reduction' processes have
been developed for primary iron production without the use of coke (for example Corex).
7.6.3.1 SO2
In general emissions of SO2 can be minimised by reducing the sulphur content of the coal.
During the coking process, this sulphur of the coal is fully converted into H 2S and captured with the
coke oven gas, which is used usually after cleaning of the coke oven gas i.a.for instance as fuel for
coke oven underfiring. Hence, the emissions of SO2 can be minimized by the use of coking coal with
lower sulphur content, as well as by adequate desulphurisation of the coke oven gas. For underfiring
coke oven gas and blast furnace gas can be used.
The use of desulphurised coke oven gas is considered to be BAT. And the desulphurization of coke
oven gas by absorption systems or the oxidative desulphurization is considered to be BAT.
The prevention of leakage between oven chamber and heating chamber by means of regular coke
oven operation is considered to be BAT [2]. Table 1 shows selected BAT H2S control measures with
associated H2S levels of the coke oven gas (to be later used as a fuel i.a. for coke oven underfiring).
Table 1: selected BAT H2S control measures with associated H2S levels of coke oven gas [2]
According to the German IPPC implementation report from 2006 the SOx-emissions from coke oven plants in
Germany - all applying COG desulphurisation - were in the magnitude of 110-250 mg/m3 when using solely COG
(90% percentile values based on half-hourly average values from continuous measurements). When using mixed
gas (a mix mainly consisting of COG and blast furnace gas), the reported emissions were in the range of 80-160
3
mg/m .
7.6.3.2 NOx
Table 2: Emission sources and selected BAT NOx control measures with associated emission
levels in coke ovens [2]
Combination of control NOx emission level associated
Emission source 1 3
measures with BAT mg/Nm
2
Combustion of coke oven gas Combustion modification (at new 500-770 (5% O2)
plants)
1
The BAT associated emission levels may be expected to be achieved over a substantial period of time at
standard conditions and represents a typical load situation. For peak load, start up and shut down periods, as well
as for operational problems of the flue gas cleaning systems, short-term peak values, which could be higher, have
to be regarded.
2
German IPPC implementation report from 2006 the NOx-emissions from coke oven: 322-414 mg as annual
average values from different plants (using both solely COG or mixed gas).
Information on emissions from blast furnaces that use coke oven gas can be found in the section “Iron
and steel production”.
Emissions of dust in coke ovens arise mainly from diffuse dust emission sources at the coking plant,
starting from coal handling and processing, diffuse emissions from charging holes, coke oven doors
and coke pushing, until coke quenching.
Coke ovens are a significant source of BC in developing countries according to references [4] and [5].
In western countries emissions are controlled and limited. Monitoring data are very scarce. Dust
emissions may contain a share of black carbon. Measures reducing dust emissions may consequently
reduce black carbon emissions when those measures are efficient on fine particles. Emissions of dust
(including PM10, PM2.5 and black carbon) should be prevented by minimising charging emissions (cf.
table 3), by sealing the openings efficiently and good maintenance, by minimising leakage between
coke oven chamber and heating chamber and especially by using de-dusting of coke pushing. Dust in
the waste gas from coke oven underfiring can be removed by means of fabric filters or ESP [2], [3].
Table 3: Emission sources and selected BAT dust control measures with associated emission
levels in coke ovens [2]
Charging With double ascension pipes or jumper pipes are the preferred; (< 5 g/t coke)
efficient evacuation and subsequent combustion and fabric
filtration
Due to high costs and environmental impacts from coke use, 'direct' and 'smelting reduction'
processes may replace the blast furnace route and hence make coke production unnecessary [2].
So-called super coke ovens aim at, amongst others, reduced NOX and dust emissions.
Pelletization plants
Pelletization is an alternative process to agglomerate iron-containing materials, with pellets being
produced mainly at the site of the mine or its shipping port. Again, emissions to air dominate the
environmental issues [1], [9].
Pelletization plants are not recognized as a significant source of BC according to references [10], [11]
and [13]. Monitoring data are very scarce.
Coke oven plants are not subject of this part, but are dealt with in chapter 7.6.
Blast furnaces
The blast furnace remains by far the most important process to produce pig iron from iron containing
materials. These are reduced using carbon and hot gas to pig iron, which later acts as a raw material
for steelmaking. Due to the high input of reducing agents (coke, pulverized coal) it consumes most of
the overall energy input in an integrated steelworks [1]. It produces a high volume of process gas,
which needs to be cleaned before being used for internal combustion or for internal/external
generation of energy.
Although the blast furnace route is the main process for iron production, several other production
routes for pig iron are currently being developed. Two main types of alternative iron making are direct
reduction (production of solid primary iron from iron ores and a reducing agent, e.g. natural gas) and
smelting reduction (combining direct reduction in one reactor with smelting in a separate reactor,
without the use of coke). COREX is a commercially successful version of a 'smelting reduction'
process [4]. These techniques use coke, coal or natural gas as the reduction agent. In some of the
new techniques lump ore and pellets by pulverized iron ore as the main feedstock. The solid product is
called Direct Reduced Iron (DRI) and is mainly applied as feedstock in EAFs [4], [9].
Blast furnaces are not recognized as a significant source of BC according to references [10], [11] and
[13]. Monitoring data are very scarce.
7.7.3.1 SO2
For sinter plant emissions, SO2 can be minimised by lowering the sulphur input (use of coke breeze
and iron ore with low sulphur content), emission concentrations of <500 mg SO2/Nm³ can be achieved
in this way. SO2 emissions from sinter plants may also be reduced by dry or semi-dry adsorption
systems in combination with high-efficiency dust filters (as part of a multi-pollutant control technique).
With a wet waste gas desulphurization, reduction of SO 2 emissions >98% and concentrations < 100
mg SO2/Nm³ can be achieved. Due to the high cost wet waste gas desulphurisation should only be
required in circumstances where environmental quality standards are not likely to be met [1]
operational reliability (availability ratio of the equipment) is also questioned.
For pelletization plants, dust, SO2 and other pollutants can be removed from induration strand waste
gas either by scrubbing or semi-dry desulphurization and subsequent de-dusting (e.g. gas suspension
absorber (GSA)) or by any other device with the same removal efficiency [1].
Addition of adsorbents such as hydrated lime, calcium oxide or fly ashes with high calcium oxide
content may be used to further reduce SO 2 emissions, when injected into the exhaust gas outlet before
filtration [9].
Table 1: SO2 emission levels associated with BAT for iron and steel production
Emission Source BAT associated Comments
1
emission levels
3
mg/Nm or (kg/tonne)
< 500
Sinter plants [1] 500 according to BREF
(1)
SO2 as SO2; using system with removal
Pelletization plants [1] < 20
efficiency >80%
Related to an oxygen content of 3%
7.7.3.2 NOx
For sinter plants, NOX emissions should be minimized by, for example waste gas recirculation, waste
gas denitrification using regenerative activated carbon process or selective catalytic reduction.
Regenerative activated carbon and selective catalytic reduction are options for reducing NO X
emissions, but have not yet been applied in the UN-ECE region on full scale due to their high costs
(currently SCR is tested in pilot plant scale at one European steel plant) [1].
For pelletization plants it is considered BAT to optimise plant design for recovery of sensible heat
and low-NOx emissions from all firing sections (induration strand, where applicable and drying at the
grinding mills) [1]. For one pelletization plant, NO X emissions of 175 g/tonne pellet are achieved using
process-integrated measures only, namely by a combination of low energy use, low nitrogen content
in the fuel (coal and oil) and limiting the oxygen excess [5], [6].
The application of modern burners may reduce NOx emissions of to blast furnace cowpers.
Table 2: NOX emission levels associated with BAT for iron and steel production
Emission Source BAT associated Comments
1
emission levels
3
mg/Nm or (kg/tonne)
Related to an oxygen content of 3%
Fabric filters should be used whenever possible, reducing the dust content to less than 20 mg/m³
(hourly average). If conditions make this impossible (due to their tendency to blind and their sensitivity
to fire), advanced ESPs and/or high-efficiency scrubbers may be used, reducing the dust content to 50
mg/m³. Many applications of fabric filters can achieve much lower values [4], [7].
Sinter plants may generate the most significant quantity of dust emissions in integrated steel mills,
they arise primarily from material handling and from the agglomeration reaction on the strand.
Dust (together with PCDD/F) is furthermore the most important pollutant in sinter plants and waste gas
de-dusting is considered BAT, for example by application of advanced electrostatic precipitation
(moving electrode ESP, ESP pulse system, high voltage operation of ESP) or electrostatic
precipitation plus fabric filter or pre-dedusting (e.g., ESP or cyclone) plus high pressure wet scrubbing
system. The presence of fine dust, which mainly contains alkali and lead chlorides may limit the
efficiency of ESPs.
BAT also includes to use enclosure and/or hooding, where appropriate, with emission controls, of the
sinter strand operations that are potential sources of fugitive emissions, as well as to apply operating
practices that minimize fugitive emissions that are not amenable to enclosure or hooding. For reducing
dust emissions from material handling operations indoor or covered stockpiles, when possible, as well
as a simple and linear layout for material handling should be used. Enclosed conveyer transfer points
and enclosed silos to store bulk powder can further reduce emissions from bulk powder materials
(fugitive emissions of coal dust are a major concern here) [1], [4], [9].
BC emission monitoring data are scarce. When present in dust, BC emissions can be removed, at
least partially, by the use of the same BAT measures described just above for dust when those
measures are efficient for the concerned size of particles.
For blast furnace gas treatment, an efficient de-dusting is considered BAT using dry separation
techniques (e.g. deflector) for removing and reusing coarse particulate matter. Subsequently fine
particulate matter is removed by means of a scrubber or a wet electrostatic precipitator or any other
technique achieving the same removal efficiency. For cast house de-dusting, emissions should be
minimized by covering the runners and evacuation of the emission sources (tap-holes, runners,
skimmers, torpedo ladle charging points) and purification by means of fabric filtration or electrostatic
precipitation [1].
BC emission monitoring data are scarce. When present in dust, BC emissions can be removed, at
least partially, by the use of the same BAT measures described just above for dust when those
measures are efficient for the concerned size.
For basic oxygen steelmaking and casting including hot metal pre-treatment, secondary
metallurgical treatment and continuous casting (including hot metal transfer processes,
desulphurization and deslagging), BAT is considered to use particulate matter abatement by means of
efficient evacuation and subsequent purification by means of fabric filtration or electrostatic
precipitation. For basic oxygen steelmaking and casting, the use of a whirl hood for secondary
dedusting aims at reducing dust emissions.
Basic oxygen furnace gas recovery and primary de-dusting is considered BAT applying suppressed
combustion and dry electrostatic precipitation (in new and existing installations) or scrubbing (in
existing installations). Secondary de-dusting is considered BAT applying efficient evacuation during
charging and tapping with subsequent purification by means of fabric filtration or ESP or any other
technique with the same removal efficiency. Efficient evacuation should also be applied during hot
metal handling, deslagging of hot metal and secondary metallurgy with subsequent purification by
means of fabric filtration or any other technique with the same removal efficiency [1].
No BC emissions occur according to reference [12]. When present in dust, BC emissions can be
removed, at least partially, by the use of the same BAT measures described just above for dust when
those measures are efficient for the concerned size.
For electric steelmaking and casting, BAT is considered to achieve dust collection efficiencies with
a combination of direct off gas extraction (4th or 2nd hole) and hood systems or dog -house and hood
systems or total building evacuation of 98% (primary and secondary emissions). Waste gas de -dusting
is considered BAT using well designed fabric filters achieving 5 mg dust/Nm³ for new plants and 15
mg dust/Nm³ for existing ones, both determined as daily mean values [1].
No BC emissions occur according to reference [12]. BC emission monitoring data are however scarce.
When present in dust, BC emissions can be removed, at least partially, by the use of the same BAT
measures described just above for dust when those measures are efficient for the concerned size.
Table 3: Dust emission levels associated with BAT for iron and steel production
[Comment: [9] recommends maximum dust emission levels of 50 mg/Nm³ for all operations in integrated steel
mills, 20 mg/Nm³ when toxic metals are present]
Blast furnaces: fugitive (0.005-0.015) [1] US EPA 1998 [1][8] reports the following
emissions (fully captured) shares of PM1 in dust: Casthouse (older
type): 15%; Furnace with local evacuation:
9%; Hot metal desulphurization: 2%
5-15 [1] Fabric filters
20-30 [1] ESP
Basic oxygen steelmaking
and casting (0.035-0.07) [4] US EPA 1998 [8] [8] reports the following
shares of PM1 in dust: Charging (at source)
12%;Tapping (at source) 11%
2 3
< 5 [1][1]; (0.06) [4] For new plants
2 3
< 15 [1][1]; (0.12) [4] For existing plants
Electric steelmaking and
casting US EPA 1998 [8] [8] reports the following
shares of PM1 in dust for EAF: Melting and
refining (carbon steel, uncontrolled): 23%
1
The BAT associated emission levels may be expected to be achieved over a substantial period of time at
standard conditions and represents a typical load situation. For peak load, start up and shut down periods, as well
as for operational problems of the flue gas cleaning systems, short-term peak values, which could be higher, have
to be regarded.
2
For this value: daily mean
3
Recommended performance indicator
Note:
The International Finance Corporation [9] recommends maximum dust emission levels of 50 mg/Nm³
for all operations in integrated steel mills, 20 mg/Nm³ when toxic metals are present.
In the Iron & Steel Industry BREF document, there is to emphasize that only the air emissions at EAF and the
water data at Blast Furnace are expressed as daily averages when all other BAT AELs have been expressed
under normal operation conditions (e.g. excluding start up and shut down periods) and design, and averaged on a
substantial period of time (there is not yet any consensus reached about this definition)
7.7.3.4 VOC
Volatile organic compounds and polycyclic aromatic hydrocarbons (PAH) may be emitted from various
stages in iron and steel production. These include off gases in the pelletization and sintering
processes due to carbon compounds contained in the solid fuels of sinter or pelletization feed, for
example from the addition of mill scale [9].
As this sector is not considered a major emitter of VOC, no further information is given on emission
levels associated with BAT.
For all mentioned emission reduction and abatement techniques, the cross-media transfer of
pollutants and the full range of environmental effects and improvements should be considered. For
example additional energy consumption and increased quantities of waste or wastewater residuals
may result from individual efforts for pollutant prevention, reduction, or removal.
Especially de-dusting using ESP or FF leads to an additional solid waste flow, which can be recycled
into the process for some cases. If the bags in FF are precoated by injecting slaked lime, significant
abatement of some acidic components (HCl, HF) can also be achieved. In combination with an
injection of lignite coke or activated carbon, FF also help to reduce PCDD/PCDF emissions
3
significantly (to below 0.1 to 0.5 ng/m ). The minimisation of dust emissions correlates with the
minimisation of heavy metal emissions except for heavy metals in the gas phase like mercury [1], [2].
8 Table 4: examples of investments and operating costs of control options for the abatement of
NOx emissions [6]
Mis en forme : Justifié, Espace Après
7.7.5 : 0 pt, Sans numérotation ni puces
a/ b/
Characteristics of Control options Investments Operating costs Abated mass flow
reference installation [EURO] [EURO/year] [Mg NOx/year]
e/1
Travelling grate sinter Flue gas 5,000,000 - 200,000 2,000
machine; Fuel: coke recirculation
breeze; Production
output: 12,000 Mg
sinter/day; SCR 50,000,000 5,300,000 3,200
Operating time: 8,400
h/year
1
Due to reduced coke breeze consumption
[Comment: UNECE 2006 states “Total costs of implementing FFs for one representative sinter plant are 3000 to
16000 Euro p.a.”]
Mis en forme : Espace Avant : 6 pt,
7.7.6 References used in chapter 7.7 Après : 6 pt, Hiérarchisation + Niveau :
3 + Style de numérotation : 1, 2, 3, …
[1] European Commission. 2001: “Integrated Pollution Prevention and Control (IPPC) Best + Commencer à : 6 + Alignement :
Available Techniques Reference Document on the Production of Iron and Steel.” Gauche + Alignement : 2.49 cm +
http://eippcb.jrc.es/pages/FActivities.htm Retrait : 3.76 cm
[2] European Commission. 2008 Draft: “Integrated Pollution Prevention and Control (IPPC) Best
Available Techniques Reference Document on the Production of Iron and Steel.”
http://eippcb.jrc.es/pages/FActivities.htm
[3] IIASA 2004: International Institute for Applied Systems Analysis. Interim Report IR -04-079
”Primary Emissions of Submicron and Carbonaceous Particles in Europe and the Potential for
their Control“.
[4] Kraus, K., S. Wenzel, G. Howland, U. Kutschera, S. Hlawiczka, A. P. Weem and C. French
(2006): Assessment of technological developments: Best available techniques (BAT) and limit
values. Submitted to the Task Force on Heavy Metals, UNECE Convention on Long-range
Transboundary Air Pollution.
[5] The nordic council of ministers 2005: “BAT examples from the Nordic iron and steel industry“
http://www.norden.org/pub/miljo/miljo/uk/TN2006509.pdf.
[6] UNECE 1999. “Draft guidance documents on control techniques and economic instruments to
the protocol to abate acidification, eutrophication and ground level ozone”.
[7] IFC 2007. International Finance Corporation (World Bank Group): “Environmental, Health, and
Safety Guidelines for Base Metal Smelting and Refining”.
th
[8] US EPA 1998: “Compilation of air pollutant emission factors”, 5 edition: EPA AP-42. United
States Environmental Protection Agency.
[9] IFC 2007. International Finance Corporation (World Bank Group): “Environmental, Health, and
Safety Guidelines for Integrated Steel Mills”.
[10] UNEP/WMO – Integrated Assessment of Black Carbon and Tropospheric Ozone – 2011.
[11] UNECE - Ad Hoc Expert Group on Black Carbon - Black carbon - Report by the Co-Chairs of
the Ad Hoc Expert Group on Black Carbon. Executive Body for the Convention on Long-range
Transboundary Air Pollution. Twenty-eighth session Geneva, 13–17 December 2010.
[12] Kupiainen, K. & Klimont, Z., 2004. Primary Emissions of Submicron and Carbonaceous
Particles in Europe and the Potential for their Control. International Institute for Applied Systems
Analysis (IASA), Interim report IR-04-79, Schlossplatz 1 A-2361 Laxenburg Austria.
[13] EPA – Report to congress on black carbon – March 2012.
Cold rolling: HCl-pickling [1] 50-100 Regeneration of the acid by spray roasting
or fluidised bed (or equivalent system)
1
The BAT associated emission levels are based on a daily average, standard conditions and represents a typical
load situation. For peak load, start up and shut down periods, as well as for operational problems of the flue gas
cleaning systems, short-term peak values, which could be higher, have to be regarded.
2
EU-BREF split view if fuel oil <1%S is BAT or additional SO 2 reduction measures are necessary
7.8.3.2 NOX
For re-heating and heat treatment furnaces in hot rolling installations, the use of second generation
low-NOX burners is considered BAT. [comment: BREF2001 split view on whether SCR and SNCR are
BAT for re-heating and heat treatment furnaces in hot rolling installations]
For mixed acid pickling in cold rolling installations, it is considered BAT to use either free acid
reclamation (by side-stream or ion exchange or dialysis) or acid regeneration by spray roasting or acid
regeneration by evaporation process. In general for mixed acid pickling in cold rolling installations,
enclosed equipment/hoods and scrubbing should be used, and additionally for high alloy steels either
scrubbing with H2O2, urea, etc. or NOX suppression by adding H 2O2 or urea to the pickling bath or by
use of SCR. An alternative is to use nitric acid-free pickling plus enclosed equipment or equipment
fitted with hoods and scrubbing. For annealing furnaces in cold rolling installations, it is BAT to use low
NOX burners for continuous furnaces, combustion air preheating by regenerative or recuperative
burners or pre-heating of stock by waste gas.
For continuous hot dip coating, it is considered BAT to use low-NOX burners and regenerative or
recuperative burner for heat treatment furnaces and galvannealing. For heat treatment furnaces, it is
additionally BAT to use pre-heating of the strip and steam production to recover heat from waste gas
where there is a need for steam [1].
Table 2: NOX emission levels associated with BAT for ferrous metals production
Emission Source BAT associated Comments
1
emission levels
3
mg/Nm or (kg/tonne)
10-200 Hot blast cupola
20-70 Cold blast cupola
Foundries: ferrous metal
160-400 Cokeless cupola
melting [2]
10-50 Electric arc furnace
50-250 Rotary arc furnace
Moulding and casting using
lost moulds (regeneration 150
units) [2]
390 Fuel: blast furnace gas; low NOX burner
1100 Fuel: coke oven gas, heavy fuel oil; low NO X
Hot rolling: re-heating and burner
heat treatment furnaces [1]
250-400 Fuel: natural gas, gas oil; low NO X burner
3% O2 for gas, 6% O2 for liquid fuel
3 2
Hot rolling: re-heating and 320 SCR
3 2 3
heat treatment furnaces 205 SNCR , ammonia slip 5 mg/Nm
2 2
using SCR and SNCR [1] 3% O2 for gas, 6% O2 for liquid fuel
Cold rolling: HCl pickling [1] 300-370
200-650
Cold rolling: mixed acid
200 Acid regeneration by spray roasting
pickling [1]
100 Acid regeneration by evaporation process
Cold rolling: annealing Without air pre-heating, 3% O2, reduction
250-400
furnaces [1] rates of 60% for NOX
Hot dip coating: heat
treatment furnaces and 250-400 Without air pre-heating, 3% O2
galvannealing [1]
1
The BAT associated emission levels are based on a daily average, standard conditions and represents a typical
load situation. For peak load, start up and shut down periods, as well as for operational problems of the flue gas
cleaning systems, short-term peak values, which could be higher, have to be regarded.
2
EU-BREF split view if SCR and SNCR are BAT (only one of each installation exists in Europe)
3
These are emission levels reported for the one existing SCR plant (walking beam furnace) and the one existing
SNCR plant (walking beam furnace).
For hot rolling, it is considered BAT to use enclosures for machine scarfing and dust abatement with
fabric filters or electrostatic precipitators, where fabric filters cannot be operated because of wet fume.
For machine grinding operations in hot rolling installations, BAT is to use enclosures for machine
grinding and dedicated booths, equipped with collection hoods for manual grinding and dust
abatement by fabric filters. In the finishing train, exhaust systems with treatment of extracted air by
fabric filters and recycling of collected dust is considered BAT. For levelling and welding, suction
hoods and subsequent abatement by fabric filters are considered BAT.
For cold rolling, it is BAT to use extraction hoods with dust abatement by fabric filters in levelling and
welding operations.
1
For coating of wire, it is considered BAT to use good housekeeping measures for hot dipping [1].
Iron and steel foundries are not recognised as a significant source of BC according to references [7],
[8]. Monitoring data are very scarce. No emission factor is proposed by reference [9]. When present in
dust, BC emissions can be removed, at least partially, by the use of the same BAT measures
described just above for dust when those measures are efficient for the concerned size.
Table 3: dust emission levels associated with BAT for ferrous metals production
Emission Source BAT associated Comments
1
emission levels
3
mg/Nm or (kg/tonne)
daily average, standard conditions
Iron Foundries [2] 5-20
7.8.3.4 VOC
In foundries, various additives are used to bind the sand in the making of moulds and cores; These
include organic and inorganic compounds (solvents, BTEX, phenol, formaldehyde, etc.): the
generation of decomposition products further continues during the casting cooling and de -moulding
operations. As the process involves various emission sources (hot castings, sand, hot metal), a key
issue is not only to treat the off-gas, but also to capture it [5].
Hydrocarbons and misted oil emissions may arise from the cold rolling mill operations, advanced
emission collection and demisting systems like precoated fabric filters can be used to reduce them [6].
1
Cf. EIPPCB BREF 2001, Chapter B.4
Table 4: VOC emission levels associated with BAT for ferrous metal processing
Emission Source BAT associated Comments
1
emission levels
3
mg/Nm or (kg/tonne)
Foundries: Ferrous metal 10-20 Cold blast cupola
melting
1
The BAT associated emission levels are based on a daily average, standard conditions and represents a typical
load situation. For peak load, start up and shut down periods, as well as for operational problems of the flue gas
cleaning systems, short-term peak values, which could be higher, have to be regarded.
1
The information included in this subchapter is based on the NFM BREF [1], which is currently under revision in
June 2009 at the Institute for Prospective Technological Studies in Sevile (IPTS)..
a/
Table 1: associated SO2 emission levels with BAT to reduce emissions in aluminium industry
[1] [10]
Associated
emission level
Emission source Techniques
with BAT
3
(mg/Nm )
Holding and degassing of molten metal in primary < 50 – 200
and secondary aluminium production
a/ The information included in Tab. 1 is currently under discussion in the context of the NFM BREF revision, .
whose conclusion is anticipated in Q1 2010. It would be advisable not to include this table to avoid possible
confusion once the new NFM BREF is adopted or, at least, to clarify that this information, including BAT-AELs, is
under revision.
NOx:
In aluminium production NOx emissions come from the combustion processes used to melt the raw
materials. Emissions are influenced by different parameters: the type of fuel, the type of combustion,
the combustion air-ratio and the flame temperature. Oxy-fuel burner and low NOx burners are the
measures considered BAT to reduce NOx emission in aluminium production. [1].
The following table gives an overview of achievable NOx emission levels in aluminium production.
Table 2: associated NOx emission levels with BAT to reduce emissions in aluminium industry
[1][1] Mis en forme : Police :Non Gras,
Anglais (États Unis)
Associated
emission level
Emission source Techniques
with BAT
3
(mg/Nm )
furnaces from primary
Low NOx burner < 100
and secondary aluminium
Oxy-fuel burner < 100 - 300
and swarf drying
In secondary aluminium production, pre-treatment, secondary smelting and holding are sources of
dust emissions. Ceramic or fabric filters can be used to remove dust from the collected gases of
secondary smelting process. For the other processes, flue gases need to be collected and can be
filtered using a fabric filter when it is needed. [1].
The collected dust from the filters has to be reused when it is possible.
The material reception, handling and storage are sources of fugitive d ust emissions. These emissions
have to be minimized by a good handling and protections from the wind of raw material.
The following table gives an overview of achievable dust emission levels in aluminium production. [3]
The preferred technique for dust abatement is the use of a fabric filter or a ceramic filter.
If present in dust, BC emissions can be removed, at least partially, by the use of the same BAT
measures described in table 3 for dust which are also efficient for fine particles.
Table 3: associated dust emission levels with BAT to reduce emissions in aluminium industry
[1][1], [4][4] Mis en forme : Police :Non Gras,
Anglais (États Unis)
Associated emission level with
Mis en forme : Police :Non Gras,
Emission source Techniques BAT
3 Anglais (États Unis)
(mg/Nm )
Electrolysis, Pre-treatment Fabric filter
Dust: 1 – 5
Primary & secondary smelting Ceramic or fabric filter
7.9.2 Copper
7.9.2.1 Coverage
Copper is largely used for its very high thermal and electrical conductivity, its relative resistance to
corrosion and its easiness to be recycled. This category covers copper production from primary and
secondary processing.
Secondary production
The secondary copper is produced using pyrometallurgical processes. The steps of these processes
depend on the copper content of the secondary feed material. It can contain othe r organic material like
coatings. Therefore, secondary smelting and secondary refining are designed depending on the feed
material. [1].
SO2:
In copper production, SO2 emissions cause the greatest concern. Sulphur comes mainly from the ores
used to produce copper. Hence SO2 emissions are more concerning during primary production than
during secondary production. Roasting, smelting and converting are the major sources of sulphur
dioxide. SO2 comes from the copper sulphides used to produce copper. The roasting and smelting
steps are realised in the same furnace. It needs to be sealed to enable a better collection of the gases.
Oxygen enrichment is used to produce high sulphur dioxide concentration. It enables the reduction of
the flue gas volumes. Sulphuric acid plants are used to convert these gases.
The converting process is also a source of SO 2 emissions, but the gas collection is not totally efficient
when using batch processes, due to the variation of sulphur dioxide concentration. Then SO 2 removal
systems need to be designed consequently. [1].
The sulphur dioxide emissions from the roasting, smelting and converting process are removed from
the flue gases using a sulphuric acid plant.
The following table gives an overview of achievable SO 2 emissions levels in copper production.
Table 4: associated SO2 emission levels with BAT to reduce emissions in copper industry [1]
[11]
Associated
emission level
Emission source Techniques
with BAT
3
(mg/Nm )
SO2-rich off-stream gas (> 5 %)
99.7 – 99.92 %
Primary roasting, smelting and Double contact sulphuric acid plant
(conversion factor)
converting
Alkali semi-dry scrubber and fabric filter.
Wet alkali or double alkali scrubbers using
Secondary smelting and lime, magnesium hydroxide, sodium
converting, primary and secondary hydroxide.
< 50 – 200
fire-refining, electric slag cleaning Combinations of sodium or
and melting. alumina/aluminium sulphate in combination
with lime to regenerate the reagent and
form gypsum
Fabric filter with dry lime injection into a cool
gas < 500
Secondary fume collection
systems and drying processes Alkaline wet scrubber for SO2 collection
from hot gases (from dryer gases after dust < 50 – 200
removal)
NOx:
In copper production, the use of oxygen and the high temperature processes are responsible for NO x
emissions. During the primary production, nitrogen oxides are mainly absorbed in the sulphuric acid
produced. Thus NOx emissions are not a major issue. BAT to reduce these emissions are the use of
oxy-fuel burners and low NOx burners. [1].
The following table gives an overview of achievable NO x emissions levels in copper production. [1]
Table 5: associated NOx emission levels with BAT to reduce emissions in copper industry
Associated
emission level
Emission source Techniques with BAT
3
(mg/Nm )
Secondary lead is produced from recycled lead wastes and scraps. Battery is a major source of lead.
Batteries can be crushed and separated into different fractions before going to the furnace . The lead
recovery process from automotive batteries starts with the drainage of the acid of the batteries before
further processing [10].
Lead contained in other material can be recovered using simple smelting processes [1].
There are 2 refining process for lead: the electrolytic refining and the pyrometallurgical refining.
The electrolytic refining is a high cost process, hence it is used where electricity is cheap (e.g.
hydroelectricity).
During the pyrometallurgical refining cells are heated, it enables the removal of the impurities. First
copper is removed by mechanical skimming, then arsenic, antimony and tin are removed by oxidation
associated with mechanical skimming [1].
The primary zinc obtained during the primary lead production is refined using a distillation process. It
enables during a first step the separation of zinc and cadmium from lead and during a second step the
separation of zinc from cadmium is realised. Finally zinc is treated with sodium to remove arsenic and
antimony.
In Europe, primary zinc is marginally produced from the primary lead process (~5%), it is essentially
produced from hydrometallurgical process. This process is used principally for treating zinc
sulphides, but also oxides, carbonates or silicates. It involves first the roasting of materials in fluidised
bed roasters, which produces sulphur dioxide and a calcine (zinc oxide). The Zinc calcine is then
cooled and leached by sulphuric acid. This process is similar to the copper hydrometallurgical
process. The Zinc solution obtained is then purified, refined and sent to the cellhouse. Here zinc is
extracted by means electrowinning [6].
Secondary zinc production, when treating metallic scrap, consists in physical separation, melting and
other high temperature treatment [1]. End-of-life galvanized products are recycled for steel recovery
and zinc oxide reports to fumes (Electric Arc Furnace (EAF)-dust) that are further treated
pyrometallurgically ( Waelz kilns or other furnaces) to recover a ‘Zinc oxide’ -rich fraction that is further
processed for zinc or zinc oxide recovery [6].
If not stated otherwise, emission levels given in this section are given as daily average based on
continuous monitoring and standard conditions of 273 K, 101.3 kPa, measured oxygen content and
dry gas without dilution of the gases with air.
SO2:
During lead and zinc production process, the sulphur contained in materials is oxidised and sulphur
dioxide is emitted. Flue gases need then to be desulphurized. Sulphuric acid plants can be used,
where there is no pre-treatment of sulphur compounds, to convert these gases. Depending on the flue
gas SO2 content, a single or double contact sulphuric acid plant is considered as BAT to reduce
emission levels. Emissions from refining, material pre-treatment and secondary smelting are reduced
with SO2 scrubber. Wet alkaline scrubber or Alkali semi-dry scrubber and fabric filter is considered
BAT [1].
For secondary lead plants furnace feed materials can be desulphurized before smelting to reduce SO2
emissions and enable the plant to meet its emission limits [6].
The following table gives an overview of achievable SO 2 emissions levels in zinc and lead production.
Table 7: associated SO2 emission levels with BAT to reduce emissions in lead and zinc
industry [1] [11]
Associated
emission level
Emission source Techniques
with BAT
3
(mg/Nm )
Low SO2 off-stream gas (< 5 %)
Single contact sulphuric acid plant or wet > 99.1 %
Primary roasting, smelting and
gas sulphuric acid plant. (conversion factor
sintering
SO2-rich off-stream gas (> 5 %)
99.7 – 99.92 % %
Primary roasting, smelting and Double contact sulphuric acid plant
(conversion factor)
sintering
Pre-treatment, secondary
smelting, thermal refining, melting Wet alkali scrubbers
< 50-200
secondary zinc processes and
slag fuming [9] Alkali semi-dry scrubber and fabric filter.
NOx:
In zinc and lead production, the roasting and the smelting processes are the main sources of NO x
emissions. Nitrogen oxides are mainly absorbed in the sulphuric acid produced during the primary
roasting, smelting and sintering flue gas treatment. Thus NO x emissions are not a major issue. BAT to
reduce NOx emissions at other process steps are the use of oxy-fuel burners and low NOx burners [1].
The following table gives an overview of achievable NO x emissions levels in zinc and lead production.
Table 8: associated NOx emission levels with BAT to reduce emissions in lead and zinc
industry [1]
Associated
emission level
Emission source Techniques
with BAT
3
(mg/Nm )
Low NOx burner < 100
Lead and zinc production
Oxy-fuel burner < 100 - 300
Table 9: associated dust emission levels with BAT to reduce emissions in lead and zinc
industry [1] [5]
Associated emission level with
Emission source Techniques BAT
3
(mg/Nm )
Fabric filters
Roasting and smelting Dust: 1 – 5
ESP
[1] Reference document on Best Available Techniques in the non ferrous metal industries,
December 2001.
[2] Assessments of technological developments BAT and limit value, non ferrous metal processing
industry, draft background document.
[3] UK fine particulate emissions from industrial processes, AEAT, August 2000.
[4] AP 42, Fifth edition, volume 1 chapter 12: metallurgical industry, EPA, January 1995.
[5] Characterization of particulate emissions from non-ferrous smelters, R.L Bennet and K.T
Knapp, JAPCA -February 1989
[6] Comments from Lynette Chung, EUROMETAUX, 02/2009.
[7] “Compilation of the answers-to-questions-and proposal of EGTEI secretariat.doc”,EGTEI,
02/2009.
[8] Comments from Aldo Zucca, PORTOVESME, 03/2009.
[9] Comments from Thomas Krutzler, UBA Austria, 03/2009.
[10] Comments from Ines Flügel, UBA Germany, 03/2009.
[11] Reference document on Best Available Techniques for the manufacture of large volume
Inorganic Chemicals – Ammonia, Acids and Fertilisers.
[12] EGTEI-State of progress.doc”, for WGSR, March 2009.
[13] Comments from Lynette Chung, EUROMETAUX, 05/2009
[14] Comments from André Peteers Weem, INFOMIL, 05/2009
[15] UNEP/WMO - Integrated Assessment of Black Carbon and Tropospheric Ozone – 2011
[16] UNECE - Ad Hoc Expert Group on Black Carbon - Black carbon - Report by the Co-Chairs of
the Ad Hoc Expert Group on Black Carbon. Executive Body for the Convention on Long -range
Transboundary Air Pollution. Twenty-eighth session Geneva, 13–17 December 2010
[17] Kupiainen, K. & Klimont, Z., 2004. Primary Emissions of Submicron and Carbonaceous
Particles in Europe and the Potential for their Control. International Institute for Applied S ystems
Analysis (IASA), Interim report IR-04-79, Schlossplatz 1 A-2361 Laxenburg Austria.
The exhaust gases finally go through different cleaning devices to be dedusted and/or desulphurized.
[12].
Cogeneration can now be applied in cement plants. The excess heat from the cement production can
be used to generate electrical power [12].
SO2:
In cement production, SO2 emissions are mainly influenced by content of volatile sulphur in the raw
materials. Thus the main measure to reduce SO 2 emissions is the use of sulphur free fuel or fuel with
low sulphur content. SO2 emissions of cement kiln may be very low without any treatment of waste
gases: simply when low sulphur raw material and low sulphur fuels are used [10].
However, different flue gas cleaning systems can be used when initial SO2 emission levels are not
very low.
The addition of absorbents such as slaked lime (Ca(OH)2), quicklime (CaO) or activated fly ash with
high CaO content to the flue gas can absorb a portion of the SO 2, it is BAT. This injection can be
carried out under dry or wet form. The use of Ca(OH)2 based absorbents with a high specific surface
area and high porosity is recommended. The low reactivity of these absorbents implies to apply a
Ca/S molar ratio of between 3 and 6.
Wet scrubbing is BAT for desulphurization. In wet scrubbing technologies, the flue gas is first
dedusted then cleaned by an atomized solution of alkali compounds. SO 2 reacts with this solution to
form different by-products, which can be upgraded as sulphuric acid, sulphur, gypsum or scrubbing
agent. A SO2 reduction of more than 90 % can be expected.[12]
The BAT AEL can be met by applying absorbent addition or wet scrubber.
Regarding the absorbent addition it should be taken into account that the cost of
absorbents implies increasing operational costs for increasing SO2 concentrations, so that
this measure might not be cost effective anymore for initial SO2 emissions levels above 1.200 mg/m³.
3
In cement industry values in the range of 50-400 mg/Nm are expected when using adapted
technologies. The following table gives an overview of BAT associated SO2 emission levels for cement
manufacturing.
Table 1: BAT Associated SO2 emission levels to reduce emissions in cement Industry [12]
Associated
emission level
1
Parameters Techniques with BAT
3
(mg/Nm ) (daily
average value)
Absorbent addition
Sulphur in fuel SO2: <50 – <400
Wet scrubbing system
1
these values are daily average values and the range takes into account the sulphur content in the raw material
NOx:
In cement production, NOx emissions are influenced by different parameters: the type of fuel, the type
of combustion, the combustion air-ratio and the flame temperature. Thus, to reduce NOx emissions,
several measures can be taken.
Among primary measures, flame cooling, low NO x burners, staged combustion, mid kiln firing and
addition of mineralisers to the raw material are the main techniques used in cement plants :
Flame cooling can be achieved by an addition of water to the fuel or directly to the flame. It drops the
temperature and so limits NOx formation.
The addition of mineralisers, such as fluorine, to the raw material enables also the reduction of the
sintering zone temperature and thus NOx formation.
Low NOx burners enable to reduce NOx emissions during combustion processes. Combustion with
low NOx burner consists in a cold combustion with an internal or external flue gas recirculation. NO x
reductions up to 30% are achievable in successful installations and emission levels of 600-1000
3
mg/Nm have been reported with the use of this technology. Erreur ! Source du renvoi
introuvable.[12].
In staged combustion; the first combustion stage takes place in the rotary kiln. The second
combustion stage is a burner at the kiln inlet; it decomposes nitrogen oxides generated in the first
stage. In the third combustion stage the fuel is fed into the calciner with an amount of tertiary air. This
system reduces the generation of NOx from the fuel, and also decreases the NOx coming out of the
kiln. In the fourth and final combustion stage, the remaining tertiary air is fed into the system as 'top air'
for residual combustion. Staged firing technology can in general only be used with kilns equipped with
a precalciner [12].
Mid-kiln firing is applied in long wet or dry kilns. It creates a reducing zone by injecting fuel at an
intermediate point in the kiln system. In some installations using this technique, NO x reductions of 20 –
40% have been achieved.
Primary measures are efficient nevertheless secondary measures can be used to achieve larger NOx
emission reductions. Among them, selective catalytic reduction (SCR) and selective non-catalytic
reduction (SNCR) are the main techniques considered in cement plants [6]. In SNCR, the conversion
rate is lower: 10 – 50 % is obtained in cement plants.
In cement industry, the BAT for NOx emissions reduction are primary measures combined with staged
3
combustion or a SNCR. Emission values in the range of 200-500 mg/Nm are achievable when using
these technologies.
Selective Catalytic Reduction (SCR) is BAT, subject to appropriate catalyst and process developments
in the cement industry. Large reduction (85 – 95 %) can be expected. At least 2 suppliers in Europe
3
guarantee emissions in the range of 100-200 mg/Nm , when using this technique. However,
investment for this technique is still significantly higher than for SNCR [12].
The following table gives an overview of BAT associated NOx emission levels for cement
manufacturing [12].
If co-incineration waste is used, the requirements of the Waste Incineration Directive (WID) have to be
met [12].
Table 2: BAT Associated NOx emission levels to reduce emissions in cement industry [12]
Associated
emission level
Emission source Techniques
with BAT
3
(mg/Nm )
Combination of: primary measures (flame cooling,
12
Preheater kilns low NOx burner, mid kiln firing, addition of <200 – 450
mineralisers...), staged combustion (also in
combination with a precalciner and the use of
optimised fuel mix), SNCR, SCR subject to
Lepol and long rotary 3
appropriate catalyst and process development in the 400 – 800
kilns
cement industry.
1
BAT-AEL is 500 mg/Nm3, where after primary measures techniques the initial NOx level is <1000mg/Nm3
2
Existing kiln system design, fuel mix properties including waste, raw material burnability can influence the ability to be in the
range. Levels below 350 mg/Nm3 are achieved at kilns with favourable conditions. The lower value of 200 mg/Nm3 has only
been reported as monthly average for three plants (easy burning mix used);
3
Depending on initial levels and ammonia slip.
individually isolated in case of bag failure and they should be sufficiently designed to allow adequate
performance to be maintained if a compartment is taken off line. As the dust is collected the resistance
to the gas flow increases and so does the pressure inside the filter. There should be 'burst bag
detectors' on each compartment to indicate the need for maintenance when this happens.
3
Emissions below 5 mg/m can be achieved by well designed and well maintained fabric filters.
Sufficiently dimensioned electrostatic filters, with both good air conditioning and optimised ESP
3
cleaning regime, can reduce dust emission levels below 10 mg/Nm (daily average value).
Control of CO level is necessary for the use of ESP. Concentration of CO has to be kept below the
lower explosive limit to avoid any critical problem.
Roads used by lorries needs to be paved and periodically cleaned to avoid diffuse dust emissions. In
addition, spraying water at the installation site is used to avoid dust emissions. Chemical agents can
also be added to water to improve the efficiency of the agglomeration of dust. As far as possible,
material handling should be conducted in closed area, where air need to be collected and cleaned
through fabric filters [12].
In cement industry the BAT for dust emissions reduction are ESP and fabric filters. Concentration
3
values in the range of 5 – 50 mg/Nm of dust are achieved when using these technologies. With the
3
use of hybrid filters (combination of both FF and ESP), values in the range of 10 – 30 mg/Nm of dust
are achieved. The following table gives an overview of BAT associated dust emission levels for
cement manufacturing.
Table 3: BAT Associated dust emission levels to reduce emissions in cement Industry [4], [12]
Associated emission level with
Emission source Techniques BAT
3
(mg/Nm )
All kiln system
Clinker cooler
Fabric filters or ESP Dust: <10 – 20
Cement mills
1
It has be noted that for small sources (<10000 Nm 3/h) a priority approach has to be taken into account.
2
spot measurement, at least half an hour.
1
Reported costs
Kiln systems Reduction Operating
Technique Investment
applicability efficiency 6 (euros/tonne of
(in 10 euros)
clinker)
Flame cooling All 0-35 % Up to 0.2 Up to 0.5
Low-NOx burner All 0-35 % Up to 0.45 0.07
Precalciner 0.1 – 2 0
Staged combustion 10-50 %
Preheater 1–4 0
Preheater and
30 – 90 % 0.5 – 1.2 0.1 – 1.7
SNCR Precalciner
Grate preheater 35 % 0.5 0.84
6
SCR Possibly all 43 – 95 % 2.2 – 4.5 0.33 – 3.0
1
Investment cost and operating cost in, referring to a kiln capacity of 3000 tonne clinker/day and initial emission up to 2000 mg
NOx/m3
6
Costs data based on a kiln capacity of 1500 tonne clinker/day
Reported costs
Kiln systems Reduction Operating
Technique Investment
applicability efficiency (euros/tonne of
(in 106 euros)
clinker)
Absorbent addition All 60-80 % 0.2 – 0.3 0.1 – 0.4
Wet scrubber All > 90 % 5.8 – 23 0.5 – 2
2
Activated carbon Dry up to 95 % 15 No info.
2
This cost also includes an SNCR process, referring to a kiln capacity of 2000 tonne clinker/day and initial emission of 50-600
mg SO2/m3
Table 6: cost of techniques for controlling dust emissions in cement Industry [12].
1
Costs
Technique Applicability Investment Operating
6
(in 10 euros) (euros/tonne of clinker)
All kiln systems 2.1 – 6.0 0.1 – 0.2
Electrostatic clinker coolers 0.8 – 1.2 0.09 – 0.18
precipitators
cement mills 0.8 – 1.2 0.09 – 0.18
All kiln systems 2.1 – 6.0 0.15 – 0.35
Fabric filters clinker coolers 1.0 – 1.4 0.1 – 0.15
cement mills 0.3 – 0.5 0.03 – 0.04
1
Investment cost and operating cost to reduce the emission to 10-50 mg/m3, normally referring to a kiln capacity of 3000 tonne
clinker per day and initial emission up to 500 g dust/m3
[1] Aerosol size distribution determination from stack emissions: the case of a cement plant,
Fraboulet, 2007. Dust conference in Maastricht. April 2007.
[2] Background document: cement production, EGTEI, 2003.
[3] Assements of technological developments BAT and limit value, cement industry, draft
background document.
[4] Options for updating BAT from a technical point of view and implications for other annexes, M.
Suhr, FEA Germany, Task Force on Heavy Metal, june 2008.
th
[5] Ministère de l’écologie – France - “Arrêté du 3 mai 1993”, JO 15 june 1993.
[6] Comments from André Peeters Weem, Cees Braams, InfoMil, the Dutch Ministry of
Environment, 12/2008.
[7] Comments from Maja Bernicke, Federal Environment Agency Germany, 12/2008.
[8] Comments from Gaston Theis, Swiss Federal Office for the Environment, 11/2008.
[9] “Compilation of the answers-to-questions-and proposal of EGTEI secretariat.doc”,EGTEI,
02/2009.
[10] Comments from Thomas Krutzler, UBA Austria, 03/2009.
[11] “EGTEI-State of progress.doc”, for WGSR, March 2009.
[12] European Commission - Reference document on Best Available Techniques in the cement, lime
and magnesium oxide manufacturing industries, May 2010.
[13] Comments from CEMBUREAU, May 2010.
[14] Comments from EULA, May 2009
[15] Comments from Andre Peteers Weem, INFOMIL, May 2009
[16] Comments from Maja Bernicke, UBA, May 2009
[17] UNEP/WMO - Integrated Assessment of Black Carbon and Tropospheric Ozone – 2011
[18] UNECE - Ad Hoc Expert Group on Black Carbon - Black carbon - Report by the Co-Chairs of
the Ad Hoc Expert Group on Black Carbon. Executive Body for the Convention on Long -range
Transboundary Air Pollution. Twenty-eighth session Geneva, 13–17 December 2010
[19] Kupiainen, K. & Klimont, Z., 2004. Primary Emissions of Submicron and Carbonaceous
Particles in Europe and the Potential for their Control. International Institute for Applied Systems
Analysis (IASA), Interim report IR-04-79, Schlossplatz 1 A-2361 Laxenburg Austria.
[20] EPA – Report to congress on black carbon – March 2012
SO2:
In lime production, SO2 emissions are influenced by the sulphur content of the fuel used during the
combustion process. SO2 emissions also depend on the design of kiln and the required sulphur
content of the lime produced. The main measure to reduce SO2 emissions is the use of free sulphur
fuel or fuel with low sulphur content. There is no secondary measure considered in the current BAT to
reduce SO2 emissions. Absorbent addition techniques are available, but not currently applied.
SO2 from the flue-gases of kiln firing processes can be reduced by using process optimisation
measures/techniques to ensure an efficient absorption of sulphur dioxide, i.e. efficient contact between
the kiln gases and the quicklime.
As no BAT emission levels are available, Ttypical SO2 emissions associated with the use of BAT from
lime production are presented in the following table [7].
Table 1: associated SO2 emission levels with BAT to reduce emissions in lime Industry [7]
Associated emission
Emission source Techniques level with BAT
3 1, 2
(mg/Nm )
1
The level depends on the initial SOX level in the exhaust gas and on the reduction measure technique used
2
For the production of sintered dolime using the “double pass process”, SOx emissions might be higher than the upper end of
the range.
NOx:
In lime production, NOx emissions are influenced by different parameters: the type of fuel, the type of
combustion, the combustion air-ratio and the flame temperature. Those parameters depend on the
quality of lime to be produced and the design of kiln.
Both primary and secondary measures can be used in order to reduce NO x emissions. Primary
measures include:
process optimization: smoothing and optimising the plant operation and/or homogenisation of
the fuel and raw material feedings.
burner design: NOx emissions can be minimised by the operation of special low NO x burners.
These burners are useful for reducing the flame temperature and thus reducing thermal and (to
some extent) fuel derived NOx. The NOx reduction is achieved by supplying rinsing air for
lowering the flame temperature or pulsed operation of the burners. Low NO x burners are only
applied to rotary kilns.
Table 2: associated NOX emission levels with BAT to reduce emissions in lime Industry [7]
Associated emission
Emission source Techniques level with BAT
3
(mg/Nm )
Table 3: Associated dust emission levels with BAT to reduce emissions in lime Industry [7]
2
Fabric filter Dust: <10
1
Dusty operations
Wet scrubbers 2
Dust: < 10 – 20
(mainly used in hydrating plants)
1
It has be noted that for small sources (<10000 Nm3/h) a priority approach has to be taken into account.
2
Values are given as the average over the sampling period (spots measurements, for at least half an hour)
3
In exceptional cases where resistivity of dust is high, the BAT AEL could be higher, up to 30 mg/Nm3, as the daily average
value.
4
Daily average values.
Regenerative furnaces utilize regenerative systems for heat recovery and usually burners in or below
combustion air / waste gas ports. Waste gas heat is used to preheat combustion air by passing the
waste gas through a heat absorbing chamber. The furnace fires on one side at a time and after about
twenty minutes, the firing is reversed and the combustion air is passed through the previously heated
chamber. Preheat temperatures up to 1400°C and very high thermal efficiencies may be reached.
Regenerative furnaces are either cross-fired (combustion ports and burners along the sides of the
furnace, chambers on either side) for rather large installations or end-fired (burners and chambers on
one side).
Recuperative furnaces utilize heat exchangers for heat recovery, which continuously preheat the
combustion air by the waste gases. Temperatures are limited to around 750°C for metallic
recuperators and the specific melting capacity of recuperative furnaces is around 30% lower than for
regenerative furnaces. The burners are located along each side of the furnace and fire continuously
from both sides. Recuperative furnaces are primarily used when high flexibility of operation is required
with minimum initial capital, and when regenerators are not economically viable due to small capacity.
Oxy fuel melting involves the replacement of combustion air with oxygen (>90% purity), by which the
volume of waste gas is reduced by about two thirds. As the atmospheric nitrogen has not to be heated
to the flame temperature, energy savings are possible, as well as reduction of NO X formation. This
kind of furnace generally has the same design as unit melters (multiple lateral bur ners, a single waste
gas exhaust port), but does not utilize heat recovery systems to pre-heat the oxygen supply.
Electric melting uses a refractory lined box with electrodes inserted either from the top, the sides or,
more usually the bottom of the furnace. Energy is provided by resistive heating, as the current passes
through the molten glass. The technique is commonly applied in small furnaces (especially for special
glass), the upper size limit for the economic viability is determined by the cost of ele ctricity compared
to fossil fuels. The replacement of fossil fuels in the furnace eliminates the formation of combustion by-
products.
Combined fossil fuel and electric melting can be either fossil fuel firing with electrical boost or (less
common) predominantly electrical heating with a fossil fuel support.
Discontinuous batch melting is used when smaller amounts of glass are required, particularly if the
glass formulation changes regularly. Pot furnaces or day tanks are used to melt specific batches of
raw material, most of them are below the sector threshold of 20 tonnes/day. A pot furnace uses a
lower section to preheat the combustion air and an upper section, which holds the pots, serves as the
melting chamber. Day tanks are larger and resemble a conventional furnace, but are refilled with batch
each day.
Special melter designs were developed to improve efficiency and environmental performance[1][1].
The major environmental challenges for the glass industry are emissions to air and energy
consumption. Glass making is a high temperature, energy intensive activity, resulting in the emission
of combustion products and the high temperature oxidation of atmospheric nitrogen, i.e. in particular
sulphur dioxide, carbon dioxide, and oxides of nitrogen. Furnace emissions also contain dust, which
arises mainly from the volatilisation and subsequent condensation of volatile batch materials [4].
For container glass, flat glass, domestic glass and special glass, secondary abatement for dust
with dry or semi-dry acid gas scrubbing where appropriate is considered as BAT. Different values are
given for BAT depending on the fuel and (for container glass and flat glass) on the emission reduction
priority of the installation, as waste minimisation by filter dust and cullet recycling may lead to higher
SO2 emissions.
For frits, BAT for SO2 is considered to be fuel selection (where practicable) and control of batch
composition [1] [1].
Table 1: SO2 emission levels associated with BAT for furnaces in glass production [1][1]
1
BAT associated emission levels
3
Emission source mgSO2/Nm or (kg/tonne) Comments
gas-firing oil-firing
Container glass with SO2 200 – 500 500 – 1200
reduction as priority (0.3-0.75) (0.75-1.8)
Container glass with Where mass balance does not allow
< 800 < 1500
waste minimisation as the figures above to be achieved.
priority (1.2) (2.25)
For combustion gases: dry, 8 % oxygen by volume (continuous melters), 13 % oxygen by volume (discontinuous
melters). For oxy-fuel fired systems the expression of the emissions corrected to 8 % oxygen is of little value, and
emissions from these systems should be discussed in terms of mass.
7.12.3.2 NOx
In glass production, nitrogen oxides are mainly generated as thermal NO X caused by high furnace
temperatures, as a product from decomposition of compounds in the batch materials, and from the
nitrogen contained in the used fuels. Thus several parameters have a significant influence on the NOX
emission levels: the type and amount of fuel used (natural gas, heavy fuel oil), the furnace t ype (cross-
fired, end-fired furnaces; regenerative, recuperative air preheating), the melting temperature and the
type of glass produced [1], [2]. The most appropriate techniques for controlling NO X emissions are in
general: primary measures, oxy-fuel melting, chemical reduction by fuel, selective catalytic reduction
(SCR) and selective non-catalytic reduction (SNCR) . When using oxycombustion, special care has to
be taken with regard to energy efficiency so as not to reduce the NO X emission abatement potential
[1],[1], [6].
Primary process modifications are based on the following techniques or combinations: reduction of the
1
air/fuel ratio (near stoichiometric combustion), staged combustion , low NOX and sealed burners and
fuel change. Further measures include the running of furnaces under slightly reducing conditions and
to minimize the combustion air supply. The latter is done in order to enhance energy efficiency and to
prevent NOX formation. It is generally recommended to maintain 0,7-1 % O2 in unit melters and 1-2%
O2 in end-port furnaces (measured at combustion chamber exit) and to keep the CO level as low as
possible (200-300 to 1000 ppm CO maximum)[8], [9].
Secondary techniques for reducing NOX emissions in glass manufacturing should be implemented
where primary measures do not achieve necessary NO X levels. They include the chemical reduction
by fuel, the use of selective catalytic reduction (SCR) and, not widely adopted, the use of selective
non-catalytic reduction (SNCR), [9].
For container glass, the main techniques likely to be considered BAT are primary measures
(combustion modifications), oxy-fuel firing, SNCR or SCR (other techniques that achieve the emission
levels may also represent BAT). Technically, low NO X levels can be achieved using for example the
special melters or electric melting. However, these techniques may only be economically applicable i n
certain circumstances. More widely applicable but options, which may not represent the most
appropriate option in all circumstances are oxy-fuel firing and batch/cullet preheating.
Where these secondary techniques require a delay until the next rebuild, many air fuel fired furnaces
are expected to achieve emission levels of 600-850 mg/Nm³ with primary measures only.
For flat glass BAT are primary measures. When other techniques (e.g., SCR,) can be used to achieve
the given levels, they can also be considered BAT. Where these techniques require a delay until the
next rebuild, many air fuel fired furnaces are expected to achieve emission levels of <850 mg/Nm³ with
combustion modifications only.
For domestic glass, BAT statements are more difficult, as in the sector high product quality
requirements, lower production volumes and more oxidising conditions (higher levels of nitrate)
increase the potential for NO X emissions. For smaller installations, electrically heated furnaces are an
option and are considered BAT for lead crystal, crystal glass and opal glass.
In the short time, using primary combustion measures, emission reductions of up to 40% compared to
the current levels are expected. As a medium term proposal, values in the range of 500 -700 mg/Nm³
are expected using the following measures (or combinations thereof) that are considered BAT: primary
measures, oxy-fuel-firing or SCR (if costs are acceptable).
For special glass, the BAT values are based primarily on the use of oxy-fuel melting and SNCR or
SCR. The sector is very diverse and the appropriate technique will depend on site-specific issues.
For frits, BAT is the use of oxy-fuel melting or alternatively the use of air-gas systems and primary or
secondary measures that are able to achieve the given levels [1].[1].
1
This measure is expected to be phased out with the installation of new low-NOx burners
Table 2: NOX emission levels associated with BAT for furnaces in glass production [1]. [1]
BAT associated
Combination of emission levels
1
Emission source Comments
control measures 3
mg/Nm (kg/tonne)
BAT techniques (see Transition until next rebuild
500-700 (1.5-1.75)
Flat glass text) or substantial use of nitrate
compounds: < 850 (2.2)
BAT techniques (see Transition until next rebuild:
Container glass 500-700 (0.5-1.1)
text) 500-850 (0.9-1.3)
Short term
Domestic Glass (Lead modifications: Air-fuel 1000-1500 (2.5-3.5)
crystal, crystal glass, opal fired
glass) Medium term limit
values: Primary
500-700 (0.5-1.75)
measures, oxy-fuel,
SNCR, SCR
Oxy-fuel melting (0.5-1.5)
Frits Air-gas systems and
primary / secondary 500-700
measures
1
The BAT associated emission levels are based on a daily average, standard conditions and represents a typical load
situation. For peak load, start up and shut down periods, as well as for operational problems of the flue gas cleaning
systems, short-term peak values, which could be higher, have to be regarded.
For combustion gases: dry, 8 % oxygen by volume (continuous melters), 13 % oxygen by volume (discontinuous
melters). For oxy-fuel fired systems the expression of the emissions corrected to 8 % oxygen is of little value, and
emissions from these systems should be discussed in terms of mass.
with a filter to clean the transport air before release. To reduce dust during conveying and "carry-over"
of fine particles out of the furnace, a percentage of water can be maintained in the batch, usually 3 -
4 % [2].
During the melting cycle using discontinuous furnaces, the dust emission varies greatly. The dust
emissions from crystal glass tanks (<5 kg/tonne melted glass) are higher than from other tanks (<1
kg/tonne melted soda and potash glass). Oxy-fuel burners can reduce waste gas volume and flue dust
production by 60%. The most significant means for reducing dust emissions from furnaces is the use
of either an electrostatic precipitator or a bag filter system, were appropriate in combination with a dry
or semi-dry acid gas scrubbing system. Installation of electrostatic precipitators (ESP) can reduce dust
3 3
emissions to 30 mg/m and fabric (baghouse) filters can reduce the emissions below 10 mg/m . The
BAT emission level with these techniques is 5-30 mg/Nm³ (equates to 0.1 kg/tonne of glass melted),
based on a typical averaging period between 30 minutes and 24 hours. In some cases, BAT for metal
emissions may result in lower emission levels for dust [1],[1], [2].
For container glass, flat glass, domestic glass, special glass, frits BAT for dust is considered the
use of an electrostatic precipitator or bag filter operating, where appropriate, in conjunction with a dry
or semi-dry acid gas scrubbing system. The application of BAT for metals may in some cases result in
lower emission levels for dust [1]. [1].
The production of glass is not identified as a major source of black carbon, according to references
[12], [13] and [15]. However BC emission data are scarce. BC emissions are linked to incomplete
combustion. This type of situation does not occur in glass production which is a continuous process
with high level of energy efficiency. Reference [14] provides an emission factor of 0.06 % of TSP. If
BC is present in dust, BAT measures described just above, efficient for fine particles, are also efficient
for BC.
Table 3: dust emission levels associated with BAT for furnaces in glass production [1][1]
1
BAT associated emission levels
Emission source 3 Comments Commentaire [CITEPA1]: Colunm to
mg/Nm or (kg/tonne) be deleted
For combustion gases: dry, 8 % oxygen by volume (continuous melters), 13 % oxygen by volume (discontinuous
melters). For oxy-fuel fired systems the expression of the emissions corrected to 8 % oxygen is of little value, and
emissions from these systems should be discussed in terms of mass.
7.12.3.4 VOC
VOC emissions from the production of mineral fibres are subject of the section on “man -made fibres”
(chapter 7-13). For other glass manufacturing operations, minor emissions of VOCs could also arise
for example from cold coating operations. These emissions are not considered to be very significant
and are not discussed further.
Abatement Capital Costs [k€] Annual Operating Costs Specific cost [€/Tonne
Technique @ 100/300/600 [k€] @ 100/300/600 molten glass]
[Tonnes/d] [Tonnes/d] @ 100/300/600 [Tonnes/d]
Values for a capacity of 100 [tonnes/day] Container (11120 m³ flue/h), 300 [tonnes/day] Container
(23000 m³ flue/h), 600 [tonnes/day] Float (70000 m³ flue/h)
Table 5: efficiencies of different NOX reduction technologies in Glassmaking [5]
Table 6: specific cost for different combinations of filters (dust) and scrubbers (SOX) for glass furnaces [11]
ESP & dry ESP & dry ESP & dry ESP & dry Bag filter & Bag filter & Bag filter & Bag filter &
Production scrubber scrubber scrubber scrubber dry dry semi dry semi dry
scrubber Wet
Type of (CaOH)2 (CaOH)2 (NaHC03) (NaHC03) scrubber scrubber scrubber
(Tons melt scrubber
glass Filter dust
per day) Filter dust Filter dust Filter dust Filter dust Filter dust Filter dust Filter dust [€/t]
disposal
recycle [€/t] disposal [€/t] recycle [€/t] disposal [€/t] recycle [€/t] [€/t] recycle [€/t] disposal [€/t]
9.6 (gas)-13
Float 500 4.8 6.51 6 7-7.35
(oil)
Float 700 4.27 5.87 4.39 7.75 6.98
Float 900 3.88 5.44 5.82 8.33
Container 100-150 11 14
Container 200 6.7 4.63-5.9 4.8-7
Container
200 6.4 9.25
(oil)
Container
300-350 4.52-6 6.31-7.5 7.38-8.33 3.86-5 4.11-7.3 5.3 6.54
(oil)
Container 450 3.96-5.2 4.77-6.5 2.9 3.6
Container
600 3.58 5.1 2.7 3.37
(oil)
Container
740 4 5.1
(gas)
Container
1240 3.4 4.6
(gas)
Container
1240 3.7 6.2
(oil)
Tableware 30-35 15.65 16.7 12.85 13.84
Tableware 180-200 7.66 3.75-4.35
E-glass oxy 100-120 11 14.4-21.5*
E-glass air 100-120 15.7-20.5*
* higher value for filter dust disposal 400 Euro/ton
5 July24 September 2012 Page 149
Guidance document on control techniques for emissions of sulphur, NOx, VOCs and dust (including PM10, PM2,5 and black carbon) from stationary sources
Table 7: specific cost for different DeNOx methods for glass furnaces [11]
General References:
US Environmental Protection Agency (US EPA). 1995. “AP-42 Section 11.15, Glass Manufacturing.”
Washington, DC.
US Environmental Protection Agency (US EPA). Standards of Performance for New Stationary
Sources. Subpart CC – Standards of Performance for Glass Manufacturing Plants, 40 CFR Part 60.
Washington, DC.
US EPA 1995 Glass Manufacturing Point Source Category. Subpart E – Float Glass Manufacturing
Subcategory40 CFR Part 426. Washington, DC.
Continuous Filament Glass Fibre is produced using recuperative or oxy-fuel fired furnaces. The
glass flows from the furnace to the forehearths where is passes through bushings on the base. The
glass is drawn through the brushing tips to form continuous filaments. The filaments are drawn
together and pass over a roller or belt, which applies an aqueous coating to each filament. The coated
filaments are gathered together into bundles (strands) for further processing.
Glass wool furnaces are usually electric melters, gas fired recuperative furnaces, or oxy-fuel
furnaces. Glass flows along a forehearth and through single orifice bushings into rotary centrifugal
spinners. Fiberising is by centrifugal action with attenuation by hot flame gases. An aqueous phenolic
resin solution is sprayed onto the fibres. The resin-coated fibre is drawn under suction onto a moving
conveyor and then passes through an oven to dry and cure the product.
Stone wool is usually produced with a coke fired hot blast cupola. The molten material gathers in the
bottom of the furnace and flows out along the spinning machine. Air is used to attenuate the fibres and
to direct them onto the collection belts. An aqueous phenolic resin solution is prayed onto the fibres by
a series of spray nozzles. The remainder of the process is essentially as for glass wool.
Ceramic fibre is produced using electric furnaces. The melt is fiberised either by high -speed wheels
or high pressure air jet, and the fibres are drawn onto a collection belt. The product can either be
baled at this point or processed into blanket to be baled as product or needle felted.
Mineral wool
In the mineral wool sector, mainly recuperative and electrical furnaces are used, besid e also oxy-gas-
fired furnaces for glass wool production.
As in the glass industry, the main environmental issues are emissions to air (fossil fuelled furnaces
and high-temperature oxidation of atmospheric nitrogen lead to emissions of SO 2, NOX, CO2 and Dust)
and energy consumption.
In addition to the emissions found in the glass manufacturing sector, two further important emission
sources exist: the forming area (application of binder to the fibres) and the curing oven (drying and
curing of binder). In the forming area, dust, phenol, formaldehyde and ammonia are emitted, in the
curing oven volatile binder components, breakdown products and combustion products are emitted.
For the production of high temperature insulation glass wools, only electrically hea ted furnaces are
used. Thus only dust emissions are relevant and to a minor extent some organic compounds [1], [2].
1
BAT associated emission levels
3
Emission source mg/Nm (kg/tonne) Comments
gas-firing oil-firing
If sulphates in batch, gas-firing values
3
Continuous filament glass could be up to 800 mg/Nm (3.6
500 – 1000 kg/tonne).
fibre < 200; (0.9)
(2.25-4.5) For oil-firing, upper end of range
relates to dust recycling.
generally < 50 300 – 1000
Glass wool Generally low sulphate glass.
(0.1) (0.6-2.0)
(a) Stone charge
Stone wool (coke fired) < 600 (1.5)
(b) 45 % cement bound briquettes
with waste minimisation < 1100 (2.7)
(c) Cement briquettes inc. filter dust
and recycling as priority. < 1400 (3.4)
7.13.3.2 NOx
For continuous filament glass fibres, BAT is considered likely to be oxy-fuel melting, however this is
no firm conclusion. SCR is considered unlikely to be applicable in the near future due to fears of
borate condensation in the catalyst. When using oxycombustion, special care has to be taken with
regard to energy efficiency so as not to reduce the NO X emission abatement potential.
For glass wool production, BAT for NOX is considered to be oxy-firing or predominantly electrical
melting, conventional firing combined with primary or secondary measures may also be judged BAT if
emissions within the ranges are achieved.
Stone wool cupolas do not generally give rise to substantial NO X emissions, however where tank
furnaces are used, the NOX BAT levels correspond to the one of glass wool production [2].
Table 2: NOX emission levels associated with BAT for furnaces in fibres production [2]
BAT associated
1
Emission source emission levels Comments
3
mg/Nm or (kg/tonne)
Continuous filament glass (0.5-1.5)
fibre, oxycombustion
Sector in a transition period concerning NO X
Continuous filament glass control, emissions generally higher than
fibre, other than 500-700 1000 mg/Nm³ (4.5 kg/tonne), with
oxycombustion conventional combustion 800 mg/Nm³ (3.6
kg/tonne) possible
500-700
Glass wool
(0.5-1.4)
Stone wool (0.5) For tank furnaces: see level for glass wool
Ceramic fibre (<0.1-0.5)
1
The BAT associated emission levels are based on a daily average, standard conditions and represents a typical
load situation. For peak load, start up and shut down periods, as well as for operational problems of the flue gas
cleaning systems, short-term peak values, which could be higher, have to be regarded.
For combustion gases: dry, 8 % oxygen by volume (continuous melters), 13 % oxygen by volume (discontinuous
melters). For oxy-fuel fired systems the expression of the emissions corrected to 8 % oxygen is of little value, and
emissions from these systems should be discussed in terms of mass.
For continuous filament glass fibres, BAT for dust is the use of an electrostatic precipitator or bag
filter operating, where appropriate, in conjunction with a dry or semi-dry acid gas scrubbing system.
For this sector, cooling the waste gas and the positioning of the abatement system are very important
for optimising efficiency. If existing equipment can achieve emission levels of 50 mg/Nm³, costs of
replacement prior to the next rebuild could be disproportionate to the advantages gained [2].
For mineral wool (glass and stone wool) production, the use of an electrostatic precipitator or bag
filter is considered BAT, while acid gas scrubbing systems are not considered necessary due to
prevalence of electric or gas heating). For downstream processes, the use of either a wet electrostatic
scrubber, a packed bed scrubber, or a stone wool filter (stone wool processes only) is considered
BAT.
In the glass wool production, the cooling of the waste gas and the positioning of the abatement
system are very important for optimising the efficiency. If existing equipment can achieve emission
levels of 50 mg/Nm³, costs of replacement prior to the next rebuild could be disproportionate to the
advantages gained.
For ceramic fibre production, electric melting with a bag filter system is considered BAT [1].
The production of man made fibers is not identified as a major source ob black carbon, according to
references [4], [5] and [6]. However BC emission data are scarce. If BC is present in dust, BAT
measures described just above efficient for fine particles, are also efficient for BC.
Table 3: dust emission levels associated with BAT for furnaces in fibres production [2]
7.13.3.4 VOC
In the production of man-made mineral fibres, VOC emissions can be reduced by switching to low
organic solvent containing binding agents and/or by VOC adsorption and incineration.
For stone wool processes, BAT is considered the use of a thermal incineration unit to reduce curing
oven emissions.
Mis en forme : Normal, Interligne :
simple
Table 4
Table 4 shows emission levels achievable by switching from conventional to reformulated binding
agents and by destructing the emissions generated in the forming and the curing steps (catalytic
incineration or adsorption preceded by precipitation of dust) [1].
Table 4: VOC emission levels associated with BAT for fibres production [2]
BAT associated emission
1
Emission Source levels Comments
3
mg/Nm or (kg/tonne)
10-50 [Erreur ! Signet non
défini.] forming area and combined forming and
Glass wool
curing emissions
(0.12) [1]
curing ovens: Thermal incineration unit
Stone wool < 10
considered BAT
Ceramic fibre 10-20
1
The BAT associated emission levels are based on a daily average, standard conditions and represents a typical
load situation. For peak load, start up and shut down periods, as well as for operational problems of the flue gas
cleaning systems, short-term peak values, which could be higher, have to be regarded.
cyclone
+PBS
Stone wool 150000-
20 (0.7) 25 (1.0) 1.3+30 % 1.5+30 % 0.2+0.1
slab filter 250000
150000-
Incinerator 200 (0.6) 20 (0.1) 10 (0.04) 1.3+40 % 1.6+30 % 0.2+0.1
300000
150000-
Stack 0.7+40 % 0.8+40 %
300000
General References:
US Environmental Protection Agency (US EPA). 1995. “AP-42 Section 11.15, Glass Manufacturing.”
Washington, DC.
US Environmental Protection Agency (US EPA). Standards of Performance for New Stationary
Sources. Subpart CC – Standards of Performance for Glass Manufacturing Plants, 40 CFR Part 60.
Washington, DC.
US EPA. 1995 .Glass Manufacturing Point Source Category. Subpart E – Float Glass Manufacturing
Subcategory40 CFR Part 426. Washington, DC.
Technical background documents for the actualisation and assessment of UN/ECE protocols related
to the abatement of the transboundary Transport of nitrogen oxides from stationary sources, DFIU,
1999.
7.14 Ceramics
7.14.1 Coverage
The sector addresses industrial installations for the manufacture of ceramic products by firing, in
particular roofing tiles, bricks, refractory bricks, tiles, stoneware or porcelain, with a production
capacity exceeding 75 tonnes per day and/or with a kiln capacity exceeding 4 m³ and with a setting
density per kiln exceeding 300 kg/m³ [1].
7.14.3.1 SO2
The emissions of SO2 in ceramic kiln exhaust gas depend on the sulphur content of the fuel and
certain raw materials (gypsum, pyrite, etc). The presence of carbonates in raw material s however may
reduce sulphur emissions. In general, techniques for reducing SO 2 emissions include the use of low
sulphur content fuels (such as natural gas or LPG), of low-sulphur raw materials and low sulphur
body-additives. Further reductions are possible by optimising the heating process and lowering the
firing temperature and the use of dry or wet scrubbers [4].
Table 1: SO2 emission levels associated with BAT for ceramics production [1]
BAT associated
1
Emission Source emission levels Comments
3
mg/Nm
< 500 Sulphur content in raw material <0.25%
7.14.3.2 NOx
The techniques for reducing emissions of gaseous compounds in ceramics manufacturing can be
summarized as reducing the input of pollutant precursors (raw materials and additives) and heating
curve optimisation (optimal peak flame temperatures, computerized control of kiln firing).
For expanded clay aggregates, it is BAT to keep the emissions from rotary kiln firing below the given
BAT value by applying a combination of primary measures/techniques [1], [4].
Table 2: NOX emission levels associated with BAT for flue gas from kiln firing in ceramics
production [1]
BAT associated
1
Emission source emission levels Comments
3
mg/Nm
< 250 Daily average value stated as NO2 for kiln
gas temperatures below 1300 °C
Daily average value stated as NO2 for kiln
Flue gas from kiln firing < 500
gas temperatures of 1300 °C or above
[Comment: IFC guideline gives a general
value of 600 for kiln operations at 10% O 2]
Flue gas from kiln firing
< 500 Daily average value
(expanded clay aggregates)
1
The BAT associated emission levels are based on a daily average, standard conditions and represents a typical
load situation. For peak load, start up and shut down periods, as well as for operational problems of the flue gas
cleaning systems, short-term peak values, which could be higher, have to be regarded.
Reference conditions: Oxygen content 18 %
3
IFC guideline [4] gives a general value of 600 mg/Nm for kiln operations in ceramic tile production at
3
10% O2 or 164 mg/Nm at 18% O2.
fuels also contribute to these emissions. While diffuse dust emissions should be minimized by
appropriate measures (use of silos for all bulk storage of dusty materials or use of confined storage
areas within buildings or use of enclosed containers/packaging), for channelled dust emissions, it is
BAT to use fabric filters.
For drying processes, it is BAT to clean the dryer, to avoid the accumulation of dust residues in the
dryer and to adopt adequate maintenance protocols.
For kiln firing, it is considered BAT to use low ash fuels, to minimise dust formation caused by the
charging of the ware to be fired in the kiln and to use flue-gas cleaning by filters or packed bed
absorbers [1], [2].
The production of ceramics is not identified as a major source of black carbon, according to references
[6] and [7]. However BC emission data are scarce. As presented in chapter 6.1, BC emissions occur
during incomplete combustion phases and during start-up periods. If BC is present in dust, BAT
measures described just above, efficient fine particles, are also efficient for BC.
Spray drying
1-30 Half hourly average; fabric filters
(For wall and floor tiles,
household ceramics, 1-50 Cyclones in combination with wet dust
technical ceramics) separators for existing installations, if the
rinsing water can be reused
Expanded clay aggregates 5-50 Daily average
Kiln firing
1-5 Daily average
(for wall and floor tiles)
1
The BAT associated emission levels are based on a daily average, standard conditions and represents a typical
load situation. For peak load, start up and shut down periods, as well as for operational problems of the flue gas
cleaning systems, short-term peak values, which could be higher, have to be regarded.
Reference conditions: Oxygen content 18 %
7.14.3.4 VOC
Emissions of volatile organic compounds (VOC) result from incomplete combustion and from the
organic material in the raw materials (e.g., binders, plasticizers, lubricants).
For bricks and roof tiles, refractory products, technical ceramics, inorganic bonded abrasives it is
considered BAT to reduce the emissions of VOCs from the flue-gases of firing processes – with raw
gas concentrations of more than 100 to 150 mg/m³, depending on the raw gas characteristics, e.g.,
composition, temperature – to the given BAT value by applying thermal afterburning either in a one or
a three chamber thermo-reactor.
For refractory products treated with organic compounds it is BAT to reduce the emissions in low off -
gas volumes from the treatment with organic compounds by applying activated carbon filters. For h igh
off-gas volumes it is BAT to reduce the emissions of VOCs from the treatment with organic
compounds by applying thermal afterburning [1], [5].
Table 4: VOC emission levels associated with BAT for ceramics production [1]
BAT associated
1
Emission source emission levels Comments
3
mg/Nm
Flue gases of firing
For raw gas concentrations of more than
processes for bricks and roof
5-20 100-150 mg/m³; as daily average (total C);
tiles, refractory products,
by application of afterburning, in a 1 or 3
technical ceramics, inorganic
chamber thermo-reactor
bonded abrasives
Refractory products 5-20 Thermal afterburning
1
The BAT associated emission levels are based on a daily average, standard conditions and represents a typical
load situation. For peak load, start up and shut down periods, as well as for operational problems of the flue gas
cleaning systems, short-term peak values, which could be higher, have to be regarded.
Dust abatement
Complete areas in the
6000 – 150000
Fabric filter/bag plant, preparation,
house conveying, storage, 900 to 70000 (Depending on 0.03 – 0.1
size and amount
forming area, handing
of ductwork)
over locations, etc.
Complete areas in the
plant, preparation, 25000 – 65000
Central vacuum conveying, storage, (Depending on
forming area, 900 to 1000
cleaner amount of
handing over locations, ductwork/pipes)
Kiln cars etc.
Kiln car cleaning
system
(In different 40000 –200000
execution: Fixed Kiln cars 8000 to 30000 (Depending on
nozzle, moving size and
nozzle, lifting and execution)
adjusting of the
plateau)
Dust abatement for hot
Electrostatic 1000000 –
and large offgas Up to 100000 0.1 – 0.2
precipitator 3000000
streams
Inorganic gaseous compounds abatement
Ca(OH)2
Module system Mainly HF reduction Very low flowrates 45000 – 100000 ~500 ~46000 EUR/yr
Honeycomb
30 – 55
2500 to 140000
EUR/tonne
Cascade type (no lower or upper 23400 – 4800
Mainly HF reduction CaCO3 40000 – 500000 ~2000 (delivered)
packed bed absorber limit)
4000 – 30000
EUR/yr
95 – 110
2500 to 140000 EUR/tonne
Cascade type Mainly HF, HCl and SO2 Modified/fabricat 40000 – 500000
(no lower or upper ~2000 (delivered)
packed bed absorber reduction ed absorbent
limit) up to 60000
EUR/yr
30 – 55
EUR/tonne
Countercurrent type CaCO3
2500 to 140000 (delivered)
packed bed Mainly HF, HCl, and and modified/ 80000 – 800000
(no lower or upper ~2500 respectively 95
absorber/ series SO2 reduction fabricated
modules limit) – 110
absorbent
EUR/tonne
(delivered)
95 – 110
Dry sorption with Ca(OH)2 2500 to 140000 EUR/tonne
Mainly HF, HCl, SO2 ~4000 107500 –
fabric filter (fly in different (no lower or upper 80000-1000000 (delivered)
Particulate reduction 130700
stream system) qualities limit) 8000 – 45000
EUR/yr
95 – 110
2500 to 140000 EUR/tonne
Mainly HCl and SO2 400000 –
Wet scrubber Alkali water (no lower or upper up to 8000 (delivered)
reduction 2000000
limit) 8000 – 45000
EUR/yr +water
VOC abatement
Thermal afterburning
180000 –
in a thermoreactor VOC reduction 10000 – 50000 500 – 4500
420000
(external)
Internal
carbonization gas VOC reduction 42000 – 300000 500 – 8000
combustion
Note: In the column ‘common sizes/flowrates’ and in the column ‘rough investment guideline’ there are ranges. It is reasonable to assume that the small Am3/h-figures correspond to the low
investment figure in EUR and that the high Am3/h figure corresponds to the high investment figure in EUR. In between the increase is not linear, normally the more Am 3/h are treated, and the lower
the investment per Am3 is.
1
) The flowrates are given in ‘actual m3’ (Am3, as opposed to normal m3, standard condition) because actual flue-gas has to be treated.
Mis en forme
General References
US Environmental Protection Agency (US EPA). Standards of Performance for New Stationary
Sources. Subpart CC – Standards of Performance for Glass Manufacturing Plants, 40 CFR Part 60.
Washington, DC.
US EPA 1995 .Glass Manufacturing Point Source Category. Subpart E – Float Glass Manufacturing
Subcategory40 CFR Part 426. Washington, DC.
Beerkens 2007 Evaluation of costs associated with air pollution control for glass melting furnaces – A
study to support the revision of the IPPC reference document on best available techniques in the glass
manufacturing industry 2008, Ordered by CPIV, Brussels, Belgium.
European Commission. 2007: Proposal for a Directive of the European Parliament and of the Council
on Industrial Emissions (Integrated Pollution Prevention and Control) (Recast)
The sulphate or Kraft process is the most used pulping process, due to the quality of the produced
pulp and to its applicability to all wood species.
During the cooking stage of the Kraft process, fibres are liberated from the screened chips using a
solution of white liquor to dissolve the lignin. White liquor is composed of sodium hydroxide and
sodium sulphide.
The pulp formed in the cooking plant contains fibres and spent cooking liquor; black liquor. Black
liquor is removed from the pulp during washing steps and is led to the recovery process. During this
recovery process, chemicals and energy are recovered. The recovery system normally enables the
whole production process to be self-sufficient in heat and energy.
After the cooking step, delignification can be continued by an oxygen delignification. Then the pulp is
purified.
The next step of the process is the bleaching, it is only necessary to obtain brighter Kraft pulp. The
bleaching is generally composed of a sequence of separate bleaching stages (4-5). During those
stages, chlorine dioxide, oxygen, ozone and peroxide can be used as bleaching agent.
After the bleaching, pulp is purified.
Depending on the type of plant; pulp mill or integrated pulp and pap er mill, the final pulp is dried to be
transported or directly used as it is [1], [5].
After the cooking step, black liquor is removed and led to a recovery process. To be used as
performing fuel, recovered black liquor needs to be concentrated. It is concentrated by evaporation to
65-75% dry-solids content. During the evaporation, non condensable gases and condensates are
recovered. Non condensable gases are burnt with malodorous gases while condensates are purified
and used as chemicals during the washing of the pulp.
The concentrated black liquor is burnt in a recovery boiler to recover the sodium and sulphur content
in a suitable chemical form to regenerate the pulping chemicals and recover energy from the flue
gases [1], [5].
The recovery system also enables the regeneration of chemicals; the smelt from recovery boiler are
recovered and dissolved in water or white liquor. The solution is then clarified and caus ticized with
lime to form sodium hydroxide, which is then used to produce white liquor.
The calcium carbonate recovered from the causticizing is used in a lime kiln to regenerate lime.
Air emissions from this process come mainly from recovery boiler, lime kiln, auxiliary boilers and pulp
drying.
The recovery boiler is the main source of emissions in the Kraft process. The boiler is fed with
concentrated black liquor. NOx, SO2, and dust emissions occur, and the rate of these emissions are Mis en forme : Indice
influenced by the combustion efficiency and the sulphur content of the black liquor.The recovery
boiler is however the main source of emissions in the Kraft process. The boiler is fed wi th
concentrated black liquor, which is the cause of NO x, SO2 and dust emissions. These emissions are
influenced by the efficiency of the combustion and the sulphur content of the black liquor.
The lime kiln is also responsible of similar emissions as in lime production (refer to chapter 7.11.2).
A bark boiler and other boilers are used in the Kraft process as auxiliary boilers to cover the energy
demand of the pulp production. These boilers can be fed with solid, liquid or gaseous fuel [1].
The sulphite process is less used than the Kraft process, due to the lower quality of the produced
pulp and to its non applicability to certain wood species. Environmental issues are in most cases more
expensive to solve than in the Kraft process.
In the sulphite process, the same processes are used, only the chemicals used are different. Hence,
recovering and regenerating steps are slightly different.
The white liquor used in the cooking plant is composed of magnesium sulphite and magnesium
bisulphite. The cooking step is most of the time a batch process.
As in the Kraft process, chemicals and energy are recovered to enable the whole production process
to be self-sufficient in heat and energy.
Air emissions from this process come from the same sources as in the Kraft process and recovery
boiler is also the main source of emissions [1].
SO2:
Kraft process
The recovery boiler is the major source of SO 2 emissions. Therefore BAT to reduce SO2 emission
levels in pulp industry is first of all reducing emissions from this boiler.
Malodorous gases from cooking plant, delignification step or evaporation of the black liquor need to be
collected and incinerated in the lime kiln, the recovery boiler or the auxiliary boilers. Emissions from
incineration need to be controlled.
In the recovery boiler, the use of high dry solids content of black liquor is a primary measure to reduce
SO2 emissions. A high dry solid content >75% permits to reduce significantly emissions.
In order to reduce SO2 emissions from the recovery boiler, a flue gas wet scrubber can be installed as
secondary measures. The scrubbing enables the removal of SO 2 and dust. The pH is controlled and
regulated by addition of liquor or sodium hydroxide. SO 2 reacts with the scrubbing liquor to form
sodium sulphite (Na 2SO3) or sodium sulphate (Na 2SO4). The usual removal efficiency of this scrubbing
3 3
is > 90 %. From initial concentration levels of 50-200 mg/Mm , levels of 10-50 mg/m can be Mis en forme : Exposant
3 3
reachedFor initial concentration levels of 50 – 200 mg/Nm , levels of 10 - 50 mg/m can be reached. Mis en forme : Exposant
The reduction of SO2 emissions from other boilers involves the use of low sulphur content fuels or the
use of scrubber to control emissions [1].
The following table gives an overview of BAT associated SO2 emission levels for Kraft pulping process
using different techniques.
Table 1: associated SO2 emission levels with BAT to reduce emissions in Kraft pulping process
[1]
Associated
emission level
Emission source Techniques
with BAT
3
(mg S/Nm )
Recovery boiler SO2 scrubbing system 10 – 50
(5% O2) If with High dry solids content of black liquor (>75%) it goes to 5 – 10
1
Auxiliary boilers Use of fuel with low sulphur content 100 – 200
2
25 – 50
3
<5
4
<15
Sulphite process
As for Kraft pulping process, the recovery boiler is responsible for the major part of SO2 emissions in
the sulphite pulping process.
Similar primary measures can be applied to reduce emissions.
In order to reduce SO2 emissions from the recovery boiler, a flue gas multi staged scrubber can be
used. SO2 emissions from the other boilers can be reduced using the same reduction techniques as
for Kraft process.
The following table gives an overview of BAT associated SO2 emission levels for sulphite pulping
process using different techniques.
Table 2: associated SO2 emission levels with BAT to reduce emissions in sulphite pulping
process [1]
Associated
emission level with
Emission source Techniques
BAT
3
(mgS/Nm )
Recovery boiler SO2 multi-staged scrubber 50 – 150
(5% O2)
1
Auxiliary boilers Use of fuel with low sulphur content 100 – 200
2
25 – 50
3
<5
4
<15
3
feed with gas
4
feed with biofuel
Mis en forme : Légende, Gauche
NOx:
Kraft process
The main sources of NOx emissions in the Kraft process are the lime kiln and the recovery boiler. The
recovery boiler is responsible for the largest part of NOx emission due to the amount of black liquor
burnt. Low NOx burners and modified combustion conditions with staged air feed system can reduce
the emission levels.
The high combustion temperature in the lime kiln is also responsible of NO x emissions. The level of
emissions is influenced by the type of fuel used. Primary measures such as adjusting functioning
parameters like flame shape or air distribution, can control the NOx emissions.
Auxiliary boilers within the pulp industry are of a very large range size (from 10 to above 200 MW).
Therefore, different measures can be applied from small boiler to large boilers. In smaller boilers,
structural and primary measures are cost effective while in larger boilers, secondary measures can
also be applied [1].
The following table gives an overview of BAT associated NOx emission levels for Kraft pulping
process.
Table 3: associated NOx emission levels with BAT to reduce emissions in Kraft pulping
process [1]
Associated
emission level
Emission source Techniques
with BAT
3
(mg/Nm )
Recovery boiler (5% O2) Low NOx burner, staged air feed system 80 – 120
Table 4: associated NOx emission levels with BAT to reduce emissions in sulphite pulping
process [1]
Associated
emission level
Emission source Techniques
with BAT
3
(mg/Nm )
Recovery boiler
Low NOx burner, staged air feed system 200 - 300
(5% O2)
1
80 - 110
2
45 - 60
Structural and primary measures 3
Auxiliary boiler 30 - 60
4
60 - 100
1
50 - 80
SNCR 4
40 - 70
1
feed with coal or heavy fuel oil
2
feed with gas oil
3
feed with gas
4
feed with biofuel
Kraft process
In kraft pulp mills, dust emissions come from different sources, mainly the lime kiln, the auxiliary boiler
and the recovery boiler. Emissions can be controlled by electrostatic precipitator and/or SO 2 scrubbers
depending on the emission source process. Bag filters can also be used [7].
The SO2 scrubbers used on boilers also enable the control of the dust emissions.
For new boilers, only the use of ESP is considered to be BAT to reduce dust emission levels. For
existing boilers, the combination of ESP and scrubbers is necessary. SO 2 scrubber combined with an
3
ESP can achieve about 15 mg/Nm of dust emissions.
The following table gives an overview of BAT associated dust emission levels for Kraft pulping
process.
Paper pulp production is not identified as a large emitter of BC according to references [9], [10] and
[12]. However BC emission data are scarce. If BC is present in dust, BAT measures described just
above for dust which are efficient for fine particles, are also efficient for BC.
Table 5: associated dust emission levels with BAT to reduce emissions in the Kraft pulping
process [1], [2]
Associated emission level with
Emission source Techniques BAT
3
(mg/Nm )
Recovery boilers
ESP and SO2 scrubbers dust: 30 – 50
(5% O2)
1
dust: 10 – 30
2
Auxiliary boilers ESP dust: 10 – 40
3
dust: < 5
1
feed with coal or biofuel or gas oil
1
feed with heavy fuel oil
3
feed with gas
Sulphite process
In sulphite pulp mills, dust emissions come from different sources, mainly the lime kiln, the auxiliary
boiler and the recovery boiler. Emissions can be controlled using the same systems as for the Kraft
process.
The following table gives an overview of BAT associated dust emission levels for sulphite pulping
process.
Paper pulp production is not identified as a large emitter of BC according to references [9], [10] and
[12]. However BC emission data are scarce. If BC is present in dust, BAT measures described just
above which are efficient for fine particles, are also efficient for BC.
Table 6: associated dust emission levels with BAT to reduce emissions in the sulphite pulping
process [1], [2]
Recovery boilers
ESP and SO2 scrubbers dust: 5 - 20
(5% O2)
1
dust: 10 – 30
2
Auxiliary boilers ESP dust: 10 – 40
3
dust: < 5
1
feed with coal or biofuel
1
feed with heavy fuel oil
3
feed with gas
SO2 scrubbers on recovery boilers come usually as a package from the supplier. Investment for a
bleached Kraft mill with a production capacity of 250,000 and 500,000 t/y amount to 7.2 Meuros and
10.4 Meuros respectively. They include scrubber, scrubber liquor pumps, circulation pumps,
electrification and instrumentation. Operating costs amount to 0.58 Meuros/y and 0.92 Meuros/y
respectively [1][1]. Mis en forme : Anglais (États Unis)
The investment to add a SNCR process to the bark boiler for the same production capacit y plant is
about 0.7-1.15 Meuros. The investment costs include injection equipment, pipes, pumps, tanks and
rebuild/adoption of the boiler. The operating costs are mainly due to urea consumption, about 1-2 kg
urea is required per kg NOx removed [1][1]. Mis en forme : Anglais (États Unis)
The installation of electrostatic precipitator costs about 3-4 Meuros for the bark boiler (auxiliary boiler)
and 5-6 Meuros for the lime kiln. Operating costs are less than 0.3 Meuros/y in both cases [1][1]. Mis en forme : Anglais (États Unis)
Investments for low NOx technology in auxiliary boilers or lime kilns are 0.5 - 0.8 Meuros.
Secondary measures
NOx emissions can be reduced by a tail gas treatment, such as a combined N2O and NOx abatement
technique or a SCR can also be used.
The combined N2O and NOx abatement technique consists of 2 catalyst layers. In the first layer, N 2O
is reduced in N2 and O2. In the second layer, NOx is reduced by addition of NH 3 (comparable to a
SCR) and N2O further decomposition is also taking place. This process can lead to a NOx abatement
of 99 %.The process is applicable for nitric acid plants with a tail gas temperature of more than 400
degree Celsius [1].
For installations with a tail gas temperature of more than 340 degree Celsius N 2O and NOx emissions
can be reduced in a combined N2O and NOx abatement system with the addition of hydrocarbons. [4].
As in the combined N 2O and NOx abatement process, there are 2 catalyst layers. In the first one, NO x
is removed in reacting with NH 3 and N2O is removed by a catalytic reduction with hydrocarbon (natural
gas or propane) in the second step. Similar emission levels as in the N 2O and NOx combined
abatement technique can be expected. [1].
The following table gives an overview of BAT associated NOx emission levels for nitric acid production.
Table 1: associated NOx emission levels with BAT to reduce emissions in nitric acid
production.
Associated
emission level
Emission source Techniques
with BAT
3 1
(mg/Nm )
New plants
Optimisation of the absorption stage, 10 - 154
Nitric acid production Combined NOx and N2O abatement technique ,
SCR, Addition of H2O2 to the last absorption stage Existing plants
2
10 – 185
1
emissions were converted from ppmv to mg / Nm3 using: 1ppmv = 2.05 mg NO2 / Nm3.
2
up to 307 mg/Nm3, where safety aspects due to deposits of AN restrict the effect of SCR or with addition of H 2O2 instead of
applying SCR.
Associated
emission level with
Emission source Techniques
BAT
3 1, 2
(mg/Nm )
Existing installations :
30-680
Sulphur burning, double contact/double absorption
New installations :
30-340
Sulphuric acid production
Other double contact/double absorption 200-680
Other 14-170
1
This level might include the effect of tail gas scrubbing.
2
Expressed as daily average value.
The following table gives an overview of the costs and SO 2 conversion rate for different abatement
techniques in sulphuric acid production [8].
Table 2: cost and operational data of techniques used to control SO2 emissions in sulphuric acid production.
18 4 bed DC/DA + TGS (alkaline) 99.60 99.94 4 591 10.19 389 1 783 465
4 bed DC/DA Base Case C2 99.60 - 0 0 0 0 914
19 4 bed DC/DA + Cs in bed 4 99.60 99.70 356 0.23 228 81 023
20 1000 9 - 12 4 bed DC/DA 5 bed DC/DA + Cs in bed 5 99.60 99.80 1 020 1.33 455 464 258
21 4 bed DC/DA + TGS Peracidox 99.60 99.94 1 359 3.02 777 1 055 922
22 4 bed DC/DA + TGS (alkaline) 99.60 99.94 3 432 7.62 777 2 667 020
Hypothesis:
the conversion rate depends on specifications (design, installations, concentration, source of SO2). Precision 0,1%.
SO2 content: 5 - 7%: calculated with 5% and 9 - 12% calculated with 10%,
O2 content: 5 - 7% SO2 + 6 - 9% O2 and 9 - 12% SO2 + 8 - 11% O2,
lifetime for all installations: 10 years,
fixed operation costs: 3%,
interest rate: 4%,
price H2SO4: 20 €/t ex works
labour costs: 37 k€/man-year
utilities for TGS Peracidox and alkaline Absorptions: +30% capital investment costs
warranted SO2-content after TGS: < 200 mg SO2/Nm³ = < 70 ppm SO2
steam price: 10 €/t
SC = single contact ,SA = single absorption, DC = double contact, DA = double absorption
7.18.1 Coverage
This section addresses the incineration of municipal (or domestic) solid waste, hazardous and medical
wastes as well as the incineration of sludges from wastewater treatment.
Municipal solid waste (MSW) mainly consists of paper and paperboard, glass, metals, plastics, rubber,
leather, textiles, wood, food waste, yard waste, and miscellaneous inorganic waste [1].
Hazardous waste is mainly generated in industrial production processes (e.g. ashes, sludges, and
other production waste), energy generation, civil engineering and building activities (e.g. demolition
waste, construction site waste, and road construction waste) and by waste incineration (fly ashes) [1].
Municipal solid waste can be incinerated via several main combustion systems including moving
grate and fluidized bed [1]. Fluidized bed technology requires MSW to be of a certain particle size
range - this usually requires some degree of pre-treatment and/or the selective collection of the waste
[3].
For the incineration of hazardous and medical waste, rotary kilns and grate incinerators are most
commonly used, but fluidized bed incinerators are also applied.
Incineration of sewage sludge takes place in rotary kilns, multiple hearth, or fluidized bed
incinerators, but co-combustion in grate firing systems, coal combustion plants and industrial
processes is also applied [1], [2], [3]. Sewage sludge has to be dried or mechanically dehydrated
before combustion and often additional firing is required to ensure stable combustion.
Grate technology. Municipal waste is the main application for these incinerators, which can be
designed to handle large volumes of waste [2]. In Europe approximately 90% of installations treating
MSW uses grates.
Different grate firing systems such as rocking grates, reciprocating grates, travelling grates, roller
grates (each of them and water cooled or not) have been developed and can be distinguished by the
way the waste is conveyed through the different zones in the combustion chamber. The different grate
systems have to fulfill special requirements regarding primary air feeding, conveying velocity and
raking, as well as mixing of the waste. Main additional features are good control characteristics and a
robust construction to withstand the severe conditions in the combustion chamber [1].
Fluidized bed Incinerators are suitable only for reasonably homogeneous materials and are
therefore the main designs for the incineration of sewage sludge, but also for mechanically or
mechanically-biologically pre-treated waste streams [2].
Preheated air is introduced into the combustion chamber via openings in the bed plate forming a
fluidized bed with the sand contained in the combustion chamber. The waste is fed to the reactor via a
pump, a star feeder or a screw-tube conveyor. In the fluidized bed, drying, volatilisation, ignition, and
combustion take place at a temperature between 850 and 950 °C. Above the fluidized bed, a
secondary combustion zone is created to ensure a retention time of more than two seconds at a
temperature above 850 °C. When the air supply to the fluidized bed is under-stoichiometrical (lambda
<1), the bed temperature is significantly lower, e.g. 650°C. In this case, only gasification takes place in
the bed itself, and most of the heat is being generated in the secondary combustion zone, i.e. above
the fluidized bed, by gas phase oxidation reactions [1].
Fluidized bed incineration systems have the advantage of easy and quick stop of waste supply and
hot start behaviour and the advantage of a lower temperature which leads to lower NOx formation [1],
[2]. However, in case of a complete shut-down (e.g. with the aim of bed material removal or
maintenance work to be done) or a cold start, it takes significantly longer for a fluidized bed system to
cool down or to heat up than for a grate system, as the whole sand load has to be cooled down or
heated up to operation temperature
Rotary kiln. In rotary kilns, almost any waste, regardless of type and composition, can be incinerated
and temperature restrictions for operation are not as stringent as in the case of fluidized bed or
multiple hearth incinerators [1]. They have the benefit of good waste agitation and achieve good
burnout, provided waste residence time in the furnace is adequate. They can be used in combination
with other designs to provide additional ash burnout [2]. The rotary kiln consists of a cylindrical vessel
slightly inclined on its horizontal axis. The waste is conveyed through the kiln by gravity as it rotates. In
order to ensure complete destruction of toxic compounds, a secondary combustion chamber is
generally necessary [Erreur ! Signet non défini.1].
Multiple hearth furnaces are mainly applied to the incineration of suldges. Sewage sludge is fed at
the top of the furnace and moves downwards through the different hearths counter-current to the
combustion air, which is fed at the bottom of the furnace. The upper hearths of the furnace provide a
drying zone, where the sludge gives up moisture while the hot flue gases are cooled. The central
hearths are in charge of the incineration, and the lower hearths ensure complete burnout. The
incineration temperature is limited to 980 °C, because above this temperature the sludge ash fusion
temperature will be reached and clinker will be formed. In order to prevent leakage of hot toxic flue
gases, multiple hearth furnaces are always operated at a slight vacuum pressure [8]
Other processes have been developed that are based on the decoupling of the phases which also
take place in an incinerator: drying, volatilisation, pyrolysis, carbonisation and oxidation of the waste;
gasification using gasifying agents such as steam, air, carbon-oxides or oxygen is also applied.
7.18.3.1 SO2
Sulphur dioxide as well as HCL and HF is formed during combustion of sulphur-(chloride- and
fluoride)-containing compounds which are found in waste. Their amount is mainly determined by the
amount of sulphur-(chloride- and fluoride) containing compounds present in the waste but operation
conditions and incineration technology applied may also have a minor impact.
Raw gas concentrations of SO2 typically are in a range from 400 to 1000 mg/Nm³, clean gas
concentrations are mostly required to be considerably lower [1], [3], making flue gas treatment
indispensable.
SO2 is removed in general from the flue gas by means of wet scrubbers, spray-dry scrubbers and dry
scrubbers.
The use of primary measures such as fuel selection, waste selection or segregation techniques, are
considered to be BAT [2].
The three main techniques, web scrubbing, semi-dry and dry scrubbing are considered to be BAT for
the removal of SO2 in the incineration of sewage sludges, municipal and medical waste [2].
3
For wet scrubbers and semi-wet FGTsemi-dry scrubbers, concentration < 20 mg/m can be achieved
and water consumption is needed (and effluent may be generated). Reduction rates of 96-98.4 % are
3
achievable. For dry scrubbers, concentration achieved can be < 40 20 or to < 420 mg/m can be
achieved depending on the reagent used.
Table 1: Emission sources and selected BAT SOx control measures with associated emission
levels in waste incineration
Operational SOx emission level
Combination of control 12
Emission source associated with BAT
measures 3
(mg/Nm )
Domestic or municipal waste incineration
Grate incinerator Dry scrubber 1- 40 [3][3]
Rotary kiln Spray dry scrubber 1 - 40
Fluidized bed combustion Wet Scrubber 1 - 40
Industrial waste incineration (hazardous and medical waste)
Grate incinerator Dry scrubber 1 - 40
Rotary kiln Spray dry scrubber 1 - 40
Fluidized bed combustion Wet Scrubber 1 - 40
Incineration of sludges from waste-water treatment
Rotary kiln Dry scrubber 1 - 40
Multiple hearth furnace Spray dry scrubber 1 - 40
Fluidized bed combustion Wet Scrubber 1 - 40
1
The BAT associated emission levels are based on a daily average, standard conditions and represents a typical
load situation. For peak load, start up and shut down periods, as well as for operational problems of the flue gas
cleaning systems, short-term peak values, which could be higher, have to be regarded.
2
The ELV of the EU waste incineration directive for SO2 is 50 mg/m³
7.18.3.2 NOx
Nitrogen oxides are emitted from incineration plants. In many cases they are measured using
continuous emission monitors. Emissions at modern plants are reported to be generally in the range
3
between 30 and 200 mg/Nm . (clean gas, daily average, 11% O2 [3]).
Emissions of NOx can generally be lowered by reducing the amount of incinerated waste. This can be
accomplished through various waste management strategies, including recycling programmes and
composting of organic materials.
Nitrogen oxides are formed predominantly as NO and NO2. Contrary to high temperature processes,
most Most of the nitrogen oxides generated during waste incineration (furnace temperature between
800 and 1200 °C) originate from the nitrogen contained in the waste (fuel- NOx) [1]. Thermal NOx
concentrations are lower than fuel NOx concentrations. Therefore, the reduction efficiency of primary
measures mainly aimed at limiting fuel NOx formation is generally limited, as a majority of nitrogen
oxidesNOx originates from fuel bound nitrogen and as the amount of fuel bound nitrogen converted to
nitrogen oxides can only be influenced to a limited extent through changes in plant design and
operation [1]. However, primary measures are generally of great importance for reducing the formation
of NOx at the combustion stage. They mainly relate to the management and preparation of wastes,
and particularly to the thermal treatment applied [3].
Primary measures (limiting emissions at the source in opposition to secondary measures reducing end
of pipe emissions) have been developed to reduce NOx emissions at source during the combustion
process by regulating flame characteristics such as temperature and fuel-air mixing. Secondary
measures operate downstream of the combustion process and remove NOx emissions from the flue
gas.
For the incineration of sewage sludges as well as municipal and medical waste the use of primary
measures such as flue-gas recirculation, air-staged combustion, fuel selection, low NOx burners in
combination with secondary measures (e.g., SCR, SNCR) is considered to be BAT.
In general SCR is considered BAT where higher NOx reduction efficiencies are required (i.e. raw flue
gas NOx levels are high) and where low final flue-gas emission concentrations of NOx are desired.
Actually, SCR is a proven technology in the waste incineration sector, which allow to achieve high NOx
3
reduction rates (typically over 90%) [1] [3] [1], [3] and NOx emission of below 50 mg/m [11].
For SNCR ammonia and urea injection are suitable and considered to be BAT. Reducing NOx by
SNCR to 75% requires a higher addition of the reducing agent. With application of SNCR NOx
3
emission concentrations of 70 mg/m (daily average) [1], [3] can be reached.
An effective emission control of NOx via SCR or SNCR can result in increased NH3-emissions (NH3-
slip), which again can be converted to NOX. To achieve a low level of total nitrogen emissions also a
3
NH3-emission control (NH3 emissions < 10 mg/m are achievable) is necessary [3].
Table 2: Emission sources and selected BAT NOx control measures with associated emission
levels in waste incineration
Dust emissions from waste incineration plants mainly consist of the fine ashes from the incineration
process that are entrained in the gas flow [3].[3]. Dust is normally measured continuously with
3
reported emissions after treatment of between <0.05 and 15 mg/Nm (11% O2) [3]).
Dust removal techniques can be divided into pre-dedusting and end-dedusting. Whereas the main
purpose of pre-dedusting is to collect residues of different composition separately and to avoid
operational problems in down-stream equipment, the main purpose of end-dedusting is to reduce final
dust emissions
Dry and wet electrostatic precipitator and fabric filters are the mainly used three types for removing of
particulate matter in flue gases. ESPs are effective in collecting dust with particle size in the range of
0.1 µm to 10 µm, and their overall collection efficiency can be 95 to 99 percent [1].
Fabric filters (FF) are considered to be BAT for the incineration of sewage sludge as well as municipal
and medical waste. They are a proven technology and when correctly operated and maintained
3
provide reliable abatement of particulate matter to below 5 mg/m . Removal efficiencies are very high
for a large range of particle size.
In general, electrostatic precipitators (ESPs) either wet or dry are not capable of abating particulate
matter to the same extent as fabric filters [2]. In combination with wet scrubbers they are considered to
be BAT. Depending on the design system and the place in the flue gas treatment system (pre- or end-
3
dedusting), particulate emission concentration values of 5 to 25 mg/m can be reached [Erreur !
Signet non défini.3]. With a wet ESP which is a specific version of the ESP the cleaning takes place
continuously by a water flow. This version is applied as end-dedusting after a wet scrubber. Very low
3
particulate matter of below 5 mg/m can be reached [3].
Waste incineration is not identified as a large emitter of BC according to references [12], [13] and [14].
However BC emission data are scarce. If BC is present in dust, BAT measures described just above
efficient for fine particles, are also efficient for BC.
Table 3: Emission sources and selected BAT dust control measures with associated emission
levels in waste incineration
Table 1: wood processing activities (sources of dust emissions) associated to types of wood
used
Moist
Process Dry wood Timber Panel
wood
Wood harvest cut X X
Slicing X X
Primary cut X X
Storage of fine sawdust and chips X X
Defibration, milling and chipping X X X
Drying of laminations, particles and sawdust X X X
Screening
Seasoning of timber and drying of panels X X
Pressing of panels X X
Cutting X X X
Sanding X X X
Other machining (edging, planning, etc.) X X X
Workshop cleaning X X X X
Techniques used to reduce dust emission levels depend on particle sizes, which themselves depend
on the process applied and the wood used. Therefore, it is necessary to distinguish primary
processing from secondary processing.
Table 2: associated dust emission levels with available techniques to reduce emissions in
panel production industry [1]
1
Technique Investment ( Euros/1000m² of board)
Cyclone 5.4
Wet Cyclone 7.2
Fabric Filters 21.6
Dry ESP 28.8
Wet ESP 32.3
1
Conversion rate used: 1 C$/1000m² = 7.19 €/1000m².
7.20 Petrol distribution (from the mineral oil refinery dispatch station
(petrol) to service stations including transport and depots (petrol))
7.20.1 Coverage
Activities covered relate to the transport and distribution of petrol from mineral oil refinery dispatch
stations or terminals, to service-stations often via intermediate storages. The terminal is any facility
which is used for the storage and loading of petrol onto road tankers, rail tankers, or vessels, including
all storage installations on the site of the facility. A refinery may have its own terminal fed by pipeline in
close proximity but external to the refinery site or a dispatch station which is located on the refinery.
The service-station is an installation where petrol is dispensed to motor vehicle fuel tanks from
stationary underground storage tanks [1].
Petrol is delivered to service-stations where it is transferred into underground storage tanks and sub-
sequently dispensed into automobile fuel tanks. At service-stations, filling of underground tanks is
carried out via a fixed vertical pipe installed within the tank to which the road tanker is connected using
a hose. VOC emissions occur from the storage tank loading and breathing although the latter is
minimal as the tank is underground and hence not subject to diurnal changes in solar heating.
At service-stations, in addition to the emissions arising from fuel deliveries, there are emissions
released from the refuelling of vehicles.
Vehicle-refuelling operations are considered to be a major source of VOC emissions. These emissions
are attributable to vapour displaced from the automobile tank by dispensed petrol. The major factors
affecting the quantity of emissions are the volume of petrol dispensed, petrol temperature, vehicle tank
temperature, petrol vapour pressure, and dispensing rates. Especially, the vehicle tank temperature is
nowadays of major importance for refuelling emissions of modern gasoline injection cars. These VOC
emissions can be controlled by vapour balancing systems, so-called Stage II controls which have
been legislated for on a national basis in a large number of EU countries or by an enlarge d carbon
canister system which is mandated in the USA.
To reduce VOC emissions from vehicle tank filling at service stations, active vapour recovery systems
can be used. They are based on the following principle: the petrol air vapour mixture escaping from
the tank during filling is sucked off at the vapour spout of the nozzle and vapours are returned back to
the storage tank. The air/vapour mixture has to be returned proportionally to the flow rate of petrol
delivered. Components of an open active petrol vapour recovery system include:
a vapour recovery nozzle,
a hose through which vapours are collected and a pipe through which the vapours are returned
to the underground tank
a vacuum pump and a system to control the ratio of the volume of vapour recovered to the
volume of petrol dispensed in the vehicle tank.
The ratio Vapour/Petrol (V/P) has to range from 95 % to 105/110 % vol. Greater V/P ratio cannot be
used to avoid excessive pressure built up and consequent VOC release through the pressure relief
valves of the storage tank.
The control of the ratio can be achieved by a proportional valve controlled either hydraulically or
electronically. Electronic regulation systems are the most widely used. However two systems can be
distinguished: the Electronic Controlled Vapour Recovery (ECVR) – open loop – without regulation
and the Electronic Controlled Vapour Recovery – Self Calibrating Gas – with regulation.
With active systems ECVR without regulation, VOC recovery efficiency cannot be maintained
effectively during the entire life time of the system. If maintenance and checks are not operated
carefully and periodically, efficiency decreases as the V/P ratio rapidly deviates from the optimal
values. A leak on the vapour line will reduce the volume of vapour returned and hence the recovery
efficiency.
With active systems ECVR with regulation, the control of vapour recovery is adjusted after each filling
operation. Each deviation from the optimum value is compensated electronically. The efficiency is
consequently stable during the life time of the system.
In both cases, theoretical VOC emission recovery efficiency is about 85 to 92 % wt. However in real
life, the efficiency of the ECVR with regulation is constant and consequently larger than the efficiency
of the ECVR without regulation. Faults can be detected and alarms can be installed to prevent
operations outside optimal values. If a fault is detected, the petrol delivery can be de-activated until the
fault is rectified [3]. This type of demand is presently implemented in some countries such as
Germany, Switzerland and UK.
Although experience with the first generation of Stage II systems was poor, the combination of routine
dry-tests (which electronically simulate the liquid flow and measure the air sucked in), regular visual
inspection by the service station personnel and the installation of a 'fault code' system (which check
that the equipment is working properly e.g. that the vapour pump is functional and that the vapour
control valves are operating within defined limits) can achieve consistently high recovery efficiencies at
approximately one tenth of the cost of the automatic monitoring system.
To achieve an overall VOC recovery efficiency of about 95 % wt, the V/P ratio has to be increased by
a factor 1.3 to 1.5 [4]. However, vapour recovery systems with V/P ratio larger than 100-110 % can
only be used if additional types of systems able to prevent any excessive pressure and consequent
VOC release through the pressure relief valves of the storage tank, are used. These systems are
based on membranes or compression and condensation [4], [6]. As example, the membrane unit is
installed in parallel to the vent stack of the petrol underground tank. The vapour sucked during car
refuelling is always returned to the storage by an active system. However the V/P ratio used is higher.
Consequently the surplus of vapours generates an over pressure in the storage tank. The pressure
gauge of the vacuum pump of the membrane unit controls the pressure. At a certain pressure, the
vacuum pump is activated and the tank pressure relieves over the membrane module to the
atmosphere. A global efficiency of 95% is obtained according to reference 4.
Other vapour recovery systems can be used, in which petrol vapours are recovered at the dispenser
and returned directly for sale. The equipment includes an active system to suck vapours with the
vacuum pump, a heat exchanger and a compressor which condenses the petrol vapours and a tank in
which water is separated from recovered petrol. The petrol recovered is conducted to the dispenser for
refilling a vehicle.
Table 1: associated emission levels with BAT to reduce VOC emissions in refinery petrol
dispatch station
Emission source BAT and reduction efficiency BAT associated
emission levels*
3
kg VOC/m /kPa
[2], [9]
Road tanker filling, bottom or 0.0228 x 0.05 to
top loading and vapour 0.0228 x 0.01
balancing during previous off
loading and VRU
Rail tanker, top loading and 0.0108 x 0.05 to
VRU VRU with 95 to 99 % efficiency [9] 0.0108 x 0.01
Marine tanker, typical cargo 0.004 x 0.05 to
tank condition 0.004 x 0.01
Barge – typical cargo tank 0.007x 0.05 to
conditions 0.007 x 0.01
*Not available in reference [9] but calculated with reference [2].
Table 2: associated emission levels with BAT to reduce VOC emissions in intermediate petrol
storages
Intermediate depot
Emission source BAT and reduction efficiency BAT associated
emission level
3
kg VOC /m /kPa*
[2], [9]
Petrol storage Internal floating roof Refer to the
External floating roof efficiency provided
Other tank designs and appropriate colours
97 to 99.5 % compared to a fixed roof tank
without measure [12]
Road tanker filling, bottom or VRU with 95 to 99 % efficiency [9] 0.0228 x 0.01 to
top loading and vapour 0.0228 x 0.05
balancing during previous off
loading and VRU
*Not available in reference [9] but calculated with reference [2].
Table 3: emission levels of available techniques to reduce VOC emissions from service-
stations
Service-stations
VOC source Available techniques Reduction Emission level
3
efficiency kg VOC /m /kPa
[2] and [6]
Underground Vapour return to the mobile Vapour return 0.0011
storage tank filling container (breathing losses not efficiency > 95 %
covered)
Car refuelling Well controlled and maintained Vapour recovery 0.0367 x 0.15
active systems with common efficiency > 85% w/w
vapour/petrol ratio of 95 to 105
% v/v
kPa is the true vapour pressure of the product delivered, m3 of petrol
No reduction 588
RI02
Stage I 382 206 9 800 1 208 5 879
100 to 500 m3 / an
Stage I and II 107 481 22 600 200 2 986 6 213
No reduction 1 582 0
RI03
3 Stage I 1 028 553 12 600 1 553 2 807
500 to 1000 m / an
Stage I and II 288 1 294 30 200 400 4 123 3 186
No reduction 4 067
RI04
Stage I 2 645 1 423 15 200 1 874 1 317
1000 to 2000 m3 / an
Stage I and II 740 3 328 37 900 600 5 273 1 584
No reduction 5 197
RI05
Stage I 3 379 1 818 17 500 2 158 1 187
2000 to 3000 m3/an
Stage I and II 945 4 252 45 000 800 6 348 1 493
No reduction 7 909
RI06
Stage I 5 142 2 767 19 800 2 441 882
3000 to 4500 m3 / an
Stage I and II 1 438 6 471 52 100 1 000 7 423 1 147
No reduction 19 208
RI07
Stage I 12 488 6 719 27 000 3 329 495
> 4500 m3 / an
Stage I and II 3 493 15 714 79 000 2 000 11 740 747
For active systems, the cost efficiency ratio depends on the size of stations and decreases with the
3
decrease of the size. Costs range from 900 to 1 350 € / t VOC abated for stations larger than 3 000 m
3
per year, 1 700 – 1 800 € / t VOC abated for stations from 1 000 to 3 000 m per year and become
3
larger for smaller stations : 3 500 € / t VOC abated for stations from 500 to 1000 m per year, 6 500 € /
3
t VOC abated for stations from 100 to 500 m per year and 25 400 € / t VOC abated for stations
3
delivering less than 100 m per year.
[1] European Parliament and Council Directive 94/63/EC of 20 December 1994 on the control of
volatile organic compound (NMVOC) emissions resulting from the storage of petrol and its distribution
from terminals to service stations
[2] CONCAWE
Air pollutant emission estimation methods for E-PRTR reporting by refineries
Report n°1/2009 – 2009 edition
[3] VDI 4205 Part 5
Measurement and test methods for the assessment of vapour recovery systems on filling station
System test of automatic monitoring systems of active vapour recovery systems - September 2006
[4] Klaus Ohlrogge and Jim Wind
Membrane based vapour recovery at petrol stations - GKSS forchungszentrum
[5] EGTEI - Distribution of gasoline – Service stations - 2003
http://www.citepa.org/forums/egtei/egtei_doc-Fuel_distribution.htm
[6] NMVOC emissions from service stations – ADEME 2007- Not publicly available
VOC emissions from service stations – Synthesis – ADEME 2007 -
[7] TOKHEIM data provided to CITEPA – July 2006
[8] Data from Total - 2007
[9] European Commission - Reference document on best available techniques for mineral oil and gas
refineries - BREF – February 2003 – European commission – Available at: http://eipccb.jrc.es
[10] EPA - Emission factor documentation for AP42 section 7.1 - Organic liquid storage tanks
Final report - September 2006
[11] Proposal for a European Parliament and Council Directive on Stage II petrol vapour recovery
during refueling of passenger cars at service stations, {SEC(2008) 2937}, {SEC(2008) 2938}
4.12.2008, COM(2008) 812 final
[12] European Commission - reference document on BAT on emissions from storage – February 2003
– Available at: http://eipccb.jrc.es
Storage
Tank design
BAT for a proper design is to take into account at least as follows:
the physico-chemical properties of the substance being stored
how the storage is operated, what level of instrumentation is needed, how many operators are
required, and what their workload will be
how the operators are informed of deviations from normal process conditions (alarms)
how the storage is protected against deviations from normal process conditions (safety
instructions, interlock systems, pressure relief devices, leak detection and containment, etc.)
what equipment has to be installed, largely taking account of past experiences of the product
(construction materials, valve quality, etc.)
which maintenance and inspection plan needs to be implemented and how to ease the
maintenance and inspection work (access, layout, etc.)
how to deal with emergency situations (distances to other tanks, facilities and to the boundary,
fire protection, access for emergency services such as the fire brigade, etc.).
BAT is to apply a tool to determine proactive maintenance plans and to develop risk -based inspection
plans such as the risk and reliability based maintenance approach.
Inspection work can be divided into routine inspections, in-service external inspections and outof-
service internal inspections.
Tank colour
BAT is to apply either a tank colour with a reflectivity of thermal or light radiation of at least 70 %, or a
solar shield on aboveground tanks which contain volatile substances.
Emissions minimization principle in tank storage
BAT is to abate emissions from tank storage, transfer and handling.
shoe seals. By installing liquid mounted primary seals and rim mounted secondary seals, a reduction
in air emissions of up to 99.5 % (compared to a fixed roof tank without measures) can be achieved.
However, the choice of seal is related to reliability, e.g. shoe seals are preferred for longevity and,
therefore, for high turnovers.
BAT is to apply direct contact floating roofs (double-deck), however, existing non-contact floating roofs
(pontoon) are also BAT.
Additional measures to reduce emissions are:
applying a float in the slotted guide pole
applying a sleeve over the slotted guide pole, and/or
applying ‘socks’ over the roof legs.
Piping
BAT is to apply aboveground closed piping in new situations. For existing underground piping it is BAT
to apply a risk and reliability based maintenance approach.
Bolted flanges and gasket-sealed joints are an important source of fugitive emissions. BAT is to
minimise the number of flanges by replacing them with welded connections, within the limitation of
operational requirements for equipment maintenance or transfer system flexibilit y,
Internal corrosion may be caused by the corrosive nature of the product being transferred, BAT is to
prevent corrosion by:
• selecting construction material that is resistant to the product
• applying proper construction methods
• applying preventive maintenance, and
• where applicable, applying an internal coating or adding corrosion inhibitors.
To prevent the piping from external corrosion, BAT is to apply a one, two, or three layer coating
system depending on the site-specific conditions (e.g. close to sea). Coating is normally not applied to
plastic or stainless steel pipelines.
Vapour treatment
BAT is to apply vapour balancing or treatment on significant emissions from the loading and unloading
of volatile substances to (or from) trucks, barges and ships. The significance of the emission depends
on the substance and the volume that is emitted, and has to be decided on a case-by-case basis.
Valves
BAT for valves include:
• correct selection of the packing material and construction for the process application
• with monitoring, focus on those valves most at risk (such as rising stem control valves in
continual operation)
• applying rotating control valves or variable speed pumps instead of rising stem control valves
• where toxic, carcinogenic or other hazardous substances are involved, fit diaphragm, bellows,
or double walled valves
• route relief valves back into the transfer or storage system or to a vapour treatment system.
Mis en forme
7.22 Manufacture of organic chemicals (Except production of organic
fine chemicals, chapter 7.23)
7.22.1 Coverage
In this chapter, the organic chemical industry is the industry aiming at producing the following types of
products :
lower olefins such as ethylene and propylene produced mainly by the steam cracking route,
aromatics compounds such as benzene and toluene,
oxygenated compounds,
nitrogened compounds,
halogenated compounds,
polymers (polyethylene, polypropylene, PVC, polyesters, polystyrene...).
Process modification, including changes of feedstock and products, can in selected cases help to
reduce VOC emissions. New chemical reactions or principles may be applied to reduce the quantity of
undesired by-products. Process improvements must also aim at recovery and recycling of by-products
as well as at enclosing open process equipment as far as possible.
An efficient measure to reduce waste gas flow rates and VOC emissions from oxidation and
oxychlorination processes (e.g. production of vinyl chloride) is the use of pure oxygen instead of air.
New oxidation and oxychlorination plant usually uses only pure oxygen.
Flare emissions:
for preventing flare emissions, BAT is:
- minimise the need for hydrocarbon disposal to flare through good plant design and good plant
management
- BAT for elevated flare design and operation includes the provision of permanent pilots and
pilots flame detection, efficient mixing, ratio controlled to the hydrocarbon flow and remote
monitoring by closed circuit television
- destruction efficiency larger than 99% for elevated flare and 99.5 % for ground flares.
Plants having an annual solvent consumption ranging from 900 to 1 500 t may have from 10 to 50
VOC emission vent stacks in the atmosphere.
A large number of discharge points are equipped with condensers to trap VOCs. To trap corrosive or
toxic gases, several vents are related to abatement absorption columns. W hen secondary abatement
techniques are applied, collecting the vents proves to be necessary.
VOC discharges present a very high variability over time: high variability over time when there is a
discharge and non-permanent discharges.
This situation leads to more significant costs for emission treatment: the gas-cleaning device should
be able to accept emission peaks. Abatement technique dimensioning must be based on the peak
discharge (the frequency of peaks should be considered as well). Investments are thus higher than for
more regular emissions in time.
without dilution by, e.g. volume flows from building or room ventilation. Thermal
oxidation/incineration and catalytic oxidation are proven techniques for destroying VOCs with
highest efficiency but show considerable cross-media effects. In direct comparison, Catalytic
oxidation consumes less energy and creates less NOx and hence is preferred where technically
possible. Thermal oxidation is advantageous where support fuel can be replaced by organic
liquid waste (e.g. waste solvents which are technically/economically available on-site and non-
recoverable) or where autothermal operation can be enabled by stripping of organic compounds
from waste water streams. Where exhaust gases also contain high loads of other pollutants
besides VOCs, thermal oxidation can enable, e.g. the recovery of marketable HCl or, if the
thermal oxidiser is equipped with a DeNOx unit or is designed as two stage combustion, the
efficient abatement of NOx.Thermal oxidation/incineration and catalytic oxidation can also be a
suitable technique to reduce odour emissions.
Table 1: selected VOC control measures with BAT associated VOC emission levels for organic
fine chemicals
Emission source Combination of control measures BAT associated
emission levels for VOC
New plants Mix of BAT defined above (primary measures ≤ 3 % of solvent input*
and use of secondary measures (both oxidation,
adsorption and / or condensation))
Existing plants Mix of BAT defined above (primary measures ≤ 5% of solvent input*
and use of secondary measures (both oxidation,
adsorption and / or condensation))
* Sum of I1 the quantity of organic solvents or their quantity in preparations purchased which are used as input into the process
in the time frame over which the mass balance is being calculated + I2 the quantity of organic solvents or their quantity in
preparations recovered and reused as solvent input into the process. (The recycled solvent is counted every time it is used to
carry out the activity.)
*The averaging time relates to the emission profile, the levels relate to dry gas and Nm3
**The concentration level relates to volume flows without dilution by, e.g. volume flows from room or
building ventilation
Table 3: BAT associated emission levels for total organic C for thermal oxidation/incineration
or catalytic oxidation [2]
Process step Average emission level from point sources*
Thermal oxidation/incineration Average mass flow or Average
or catalytic oxidation < 0.05 kg C/h** concentration**
3
< 5 mg C/m
3
* The averaging time relates to the emission profile, levels relate to dry gas and Nm
**
These values are technically demanding and attention has to be carried out on energy efficiency
which might be not acceptable
Costs vary in a large range. Average investments to achieve best performance levels on an existing
plant are about 6700 k€ and the total costs per kg of abated VOC of 2.3 €/kg [8].
[1] Speciality organic chemical industry. EGTEI background document – 24 may 2005
http://www.citepa.org/forums/egtei/speciality_chemistry_290405.pdf
[2] European commission - reference document on BAT for the manufacture of organic fine chemicals
August 2006
[3] Council Directive 1999/13/EC of 11 March 1999 on the limitation of emissions of volatile organic
compounds due to the use of organic solvents in certain activities and installations
http://eur-lex.europa.eu/LexUriServ/LexUriServ.do?uri=CELEX:31999L0013:EN:HTML
[4] Regulation (EC) No 166/2006 of the European Parliament and of the Council of 18 January 2006
concerning the establishment of a European Pollutant Release and Transfer Register and amending
Council Directives 91/689/EEC and 96/61/EC
[5] Arrêté du 31 janvier 2008 relatif au registre et à la déclaration annuelle des émissions polluantes et
des déchets - (JO n° 62 du 13 mars 2008)
[6] Comments from André Peeters Weem, Cees Braams from InfoMil, the Dutch Ministry of
Environment on GD 7-26 Manufacture of organic fine chemical - version 1
[7] Comments from Johannes Drotleff, German Umweltbundesamt on GD 7-26 Manufacture of organic
fine chemical - version 1
[8] Speciality organic chemical industry. Synopsis sheet – 3 October 2005
http://www.citepa.org/forums/egtei/31-Synopsis-sheet-Speciality-organic-chemical-industry-03-10-
05.pdf
Mis en forme
7.24 Adhesive coating (including footwear manufacture)
7.24.1 Coverage
Sectors using adhesives are very diverse. Production processes and application techniques are also
very different. Relevant sectors are: the production of adhesive tapes, composite foils, the
transportation sector (passenger cars, commercial vehicles, mobile homes, rail vehicles, aircrafts), the
manufacture of shoes and leather goods and the wood material and furniture industry. The non-
industrial use of adhesives is a large sector but it is studied separately.
Table 1: Emission sources and selected VOC control measures with associated emission
levels for adhesive coating and shoe manufacturing
Type of installation Combination of control Associated emission levels
measures for VOC
[Defined for the following
averaging period: (yearly
average for total AEL])
Manufacturing of adhesive tape Use of condensation, adsorption, Total emission of 5 wt-% or
oxidation or a combination of less of the solvent input [1]
these techniques
Manufacturing of adhesive tape Use of non-solvent based 0 g/kg adhesive
Adhesive coating in other sectors adhesives [2]
Use of condensation, adsorption, < 150 g/kg adhesive [5]
oxidation or a combination of
these techniques
Use of water-based adhesives 20 g/kg adhesive [2]
Shoe industry Use of water-based adhesives 20 – 30 g / pair [3]
Use of biofiltration
Mis en forme
7.25 Coating processes 1: coating of cars, truck cabins, trucks and
buses
7.25.1 Coverage
This sector covers the coating of passenger cars, truck cabins, trucks and buses.
Table 1: emission sources and selected VOC control measures with associated emission levels
for coating processes
Type of installation Combination of control measures BAT associated emission levels
[4] for VOC
[Defined for the following
averaging period:( yearly average
for total AEL)]
Manufacture of cars Electrocoat: water-based (5 wt.-% 10 – 35 g VOC/m² or 0.3 kg/body +
(M1, M2) solvent content) 8 g/m² to 1 kg/body + 26 g/m²
Primer: water-based (8 wt.-%
solvent content) - electrostatic
application
Topcoat :
- High solid coat (45 wt.-%
solvent content) - electrostatic
application, and
- water-based basecoat (15 wt.-
% solvent content) –
electrostatic application – and
solvent-based clear coat (45 –
55 wt.-% solvent content) -
electrostatic application
Solvent management plan, recovery
of purge solvent
Manufacture of truck WB enamels 10 – 55 g VOC/m²
cabins (N1, N2, N3) HS clearcoat
Improved solvent recovery / solvent
consumption reduction
Oxidation on ovens
Mis en forme
7.26 Coating processes 2: Winding wire coating
7.26.1 Coverage
Only the coating of metallic conductors used for winding the coils in transformers, motors, etc. is
considered in this section.
Mis en forme
7.27 Coating processes 3: Coil coating
7.27.1 Coverage
Coil coating (of metal coil surface) is a linear process by which protective and/or decorative organic
coatings are applied to flat metal sheets or strips packaged in rolls or coils.
Mis en forme
7.28 Coating processes 4: coating of metal, wood, plastic and other
surfaces (fabric, leather, paper…etc)
7.28.1 Coverage
Only industrial uses of paints are considered in this section. The use of domestic and architectural
paints is studied in another paragraph. Coating of cars and other vehicles, coil coating and coating of
winding wire are defined in other sections as abatement techniques applied are very specific.
a/ General issues
The typical exhaust air from the coating industry has a high flow rate and a low organic solvent
content, which means that energy costs for end-of-pipe measures can be significant. Therefore, if this
option is chosen, processes should be used that have low energy consumption and/or high energy
recovery rates. A further solution is to use a preceding concentration step via adsorption/desorption
processes. The use of low and no organic solvent paints and cleaning methods is in many cases the
most effective means of reducing organic solvent emissions in industrial painting.
Furthermore, for industrial applications, emission reduction technologies exist, such as improvement
of the application processes: e.g. electrostatic guns and other spray techniques instead of
conventional pneumatic application, low solvent-based coating systems, and sometimes
automatisation of application. Also, paint recovery (e.g. overspray recovery) is a proven VOC
abatement option in the wood- and metal-coating sectors.
7.28.4 Costs
Costs are defined in the EGTEI documents concerning “paint in the general industry“ [4] and “wood
coating” [5].
For the coating in the industry (general industry, continuous processes, plastic coating), abatement
costs vary between 2 and 18 k€/tonne of VOC abated depending on the size of the installation and are
negative for primary measures (higher application process efficiencies lead to the reduction of solvent
consumptions so less products are used).
For the coating of wood, abatement costs vary from 2 to 16 k€/tonne of VOC abated depending on the
size of the installation and are negative if emissions are reduced by primary measures.
Caution: these documents are susceptible to evolve if new updated data are available.
Mis en forme
7.29 Solvent content in products 1: Decorative coatings
7.29.1 Coverage
Decorative paints are applied in situ to buildings.
With the exceptions of solvent based interior wall paints, the European Decorative paints industry
believes that in practice these VOC's should be achievable.
Interior wall paints will become entirely water based as the 30g/l and 100g/l limits will not be practically
achievable with solvent based products [3].
Mis en forme
7.30 Manufacturing of coatings, varnishes, inks and adhesives
7.30.1 Coverage
This sector covers the manufacturing of all types of paints, varnishes, stains as well as inks and
adhesives. A wide number of products, formulated to meet a variety of service requirements, are
available. These products are destined among others to aircrafts, automobiles, ships, wooden and
metal furniture, packaging, textile fibres, domestic uses etc.
Table 1: emission sources and selected VOC control measures with associated emission levels
for manufacturing of paints and adhesives
Emission Combination of control measures Associated emission
source levels for VOC
[Defined for the
following averaging
period:( yearly average
for total AEL])
Large
installations
with an annual 1 wt-% of solvent input
organic solvent [1]
consumption >
1000 t
All other plants Good practices such as:
Recovery of solvent vapours during raw material
distribution,
Unloading of the barrels with fork lifts to avoid
leakages,
Coverage of mobile vessels, 2.5 wt-% of solvent input
Use of solvents with lower volatility to reduce fugitive
emissions,
Use of cleaning agents containing less solvents,
Use of automatic cleaning devices whenever possible,
Recycling of cleaning solutions,
Good practices and upgrading of the condensation or
1.75 wt-% of solvent input
carbon adsorption units and solvent recovery
Mis en forme
7.31 Printing processes
7.31.1 Coverage
The most important techniques in the printing sector are heatset offset, flexography and rotogravure in
the packaging sector, publication gravure and rotary screen printing.
According to Intergraf [10], sheetfed and coldset have very limited VOC emissions. These emissions
are also difficult to measure since there is no forced drying process producing waste gasses. There is
a trend towards the use of low volatility cleaning agents and the avoidance of isopropanol in
dampening solutions. The applicability of these emission reduction measures however depends very
much on locally determined circumstances and cannot be translated in any kind of emission limit
value. For this reason, these processes cannot be covered in the system used for the other printing
processes and should be left out of this document.
components adhesives. Water-based inks in flexography printing are in regular production use in
some packaging applications such as paper bags and plastic carrier bags [1].
a/ Heatset Offset
NMVOC emissions from heatset printing consist of isopropanol (IPA) emitted from the dampening
solutions, from cleaning agents and the stack emissions from dryers. BAT is to reduce the sum of
fugitive emissions and to treat stack VOC emissions with thermal, catalytic or regenerative oxidation.
It is then BAT to reduce:
the emission of IPA by using low IPA or free-IP dampening solution,
fugitive emissions from the cleaning process by a combination of the following techniques:
substitution and control of NMVOC used in cleaning, automatic cleaning systems for printing
and blanket cylinders.
b/ Publication gravure
In the publication rotogravure sector, more than 90% of the organic solvent consumption can be
recovered, if activated carbon adsorption is used, due to the small number of components in the
organic solvent (mainly toluene). The recycling of these organic solvents is possible and has long
been practiced.
It is BAT to reduce fugitive emissions remaining after gas treatment:
Mis en forme
7.32 Rubber processing
7.32.1 Coverage
This sector concerns the production of tyres as well as the production of all other rubber goods.
Adhesives used in the production of some rubber goods are considered in the section on adhesive
coating. Reduction techniques are not the same as the one defined below.
Table 1: emission sources and selected VOC control measures with associated emission levels
for the production of natural or synthetic rubber goods
Emission source Combination of control measures VOC emission levels
[Defined for the
following averaging
period:( yearly average
for total AEL)]
Rubber goods production
Plant with a solvent Partly switch from solvent-based to water- 1 kg/tonne rubber
consumption ≥ 15 tonnes based agents and cleaning systems produced [2]
/year or
waste gas treatment such as oxidation
Tyre production
All plants New processes (example: adhesive rubber 2.5 kg/t of tyre
band use – New type of building machine [1]
(1)
Table 1: emission sources and selected available techniques with associated emission levels
Available Technique
Associated
Combination of control Emission Levels for
Emission source VOCs
measures
(yearly average for
total AEL)
[1] Institute for health and consumer protection European Chemical Bureau. Risk assessment report
for tetrachloroethylene. Final report 2005 – EUR 21680 EN
[2] Directive 1999/13/EC of 11 March 1999 on the limitation of emissions of volatile organic
compounds due to the use of organic solvents in certain activities and installations
[3] EGTEI background document: Dry cleaning – 2005
[4] Siloxanes in the Nordic Environment, TemaNord 2005 : 593 Nordic Council of Ministers,
Copenhagen 2005 - ISBN 92-893-1268-8
[5] EPA study on siloxanes
[6] INERIS – rapport d’étude ERSA 05 9 – Note sur les produits de substitution du perchloroéthylène.
[7] Birgit Mahrwald UBA Comments on GD 7-36 dry cleaning version 1
[8] AEA energy and environment, OKOPOL and BIPRO: Guidance on VOC substitution and reduction
for activities covered by the VOC solvent emissions directive – Guidance 11 - Dry cleaning –
European commission 2008
Mis en forme
7.34 Surface cleaning
7.34.1 Coverage
This chapter covers stack and fugitive VOC emissions from cleaning processes using solvents carried
out in industry. The metalworking industries are the major users of solvent cleaning, i. e. automotive,
electronic, plumbing, aircraft, refrigeration and business machine industries. Solvent cleaning is also
used in activities such as printing, chemical industry, plastic processing, rubber processing, textile
processing, mirror manufacturing, paper industry and electric power and solvents are used for paint.
Most repair stations for road vehicles and electronic tools use solvent cleaning at least part of the time.
Solvent cleaning is most often used when the metallic part has to be dried after degreasing.
The following parameters have a great influence on the choice of the surface cleaning process:
the medium to be cleaned,
the type of impurity to be removed,
the manufacturing process,
the requirements induced by subsequent process steps.
The degreasing methodologies surface cleaning techniques can be summarized as followsin the
following table:
Table 1: main surface cleaning techniques
For cold cleaners, bath evaporation can be controlled by covering the bath regularly, by using an
adequate freeboard height, and by avoiding excessive drafts in the workshop.
For open-top vapour systems, most emissions are due to diffusion and convection, which can be
reduced by covering the bath automatically or manually, by spraying below the vapour level, by
optimising work loads, or by using a refrigerated freeboard chillers (which may be replaced, on larger
units, by a carbon adsorption device).
Vapour cleaning can be carried out in closed sealed machines.
These types of machines prevent direct exposure between the solvent and the atmosphere by a series
of interlocks, and by the use of a vapour extraction and/or refrigeration system which recycles the
vapour back into the solvent sump. This provides an extremely high degree of solvent containment
and reduces fugitive emissions. These machines can work either with chlorinated solvents or with
other solvents like A3 class hydrocarbons, HFC or HFE. As an option, the complete cleaning device
can be operated under a vacuum. This enables distillation at lower temperatures and allows a
permanent control of the vapour emissions [3].
Examples of emission reduction measures and performances in surface cleaning are presented in
table 12
Table 12: emission sources and selected VOC control measures with associated emission
levels for surface cleaning [2]
Associated
emission levels
Emission source Available techniques for VOCs
(yearly average for
total AEL)
0 g/kg solvent
Vapour cleaning using Water-based degreasing systems
used*
halogenated solvents or
hydrocarbons Less than 0.1 %
Hermetically sealed machines
solvent used*
* sum of I1 the quantity of organic solvents or their quantity in preparations purchased which are used as input
into the process in the time frame over which the mass balance is being calculated and I2 the quantity of organic
solvents or their quantity in preparations recovered and reused as solvent input into the process. (The recycled
solvent is counted every time it is used to carry out the activity).
Plasma degreasing
This technology is already applied in some specific production sectors and can be applied to a large
variety of substrates leading partly to even better cleaning results than former solvent systems. This
effect is especially related to further processing of the substrate, such as coating of certain plastics
with water-based paints. Thus, a double emission reduction may be achieved in some cases. Within
the plasma degreasing process, surface cleaning is carried out at temperatures below 100 °C and a
-3
pressure between 0.1 and 2.10 hPa. The vacuum chamber is filled with process gas, such as noble
gases (e. g. argon, helium), fluorine containing gases (e. g. tetrafluoromethane) or oxygen. An electric
field conveys energy to the system, resulting in ionised gas particles. Oxygen is mostly used as
process gas. Radicals generated via excitation aim at cutting the hydrocarbon chains and oxidise
them to form carbon dioxide and water. The cleaning effect of the plasma is based on this chemical
reaction. Organic impurities can be removed by this degreasing process, but plasma technique is not
adapted to inorganic impurities such as shavings, mineral dust or salts.
[4] AEA energy and environment, OKOPOL and BIPRO: Guidance on VOC substitution and reduction
for activities covered by the VOC solvent emissions directive – Guidance 4/5 – Surface cleaning –
European commission 2008
[5] A compilation of technical information on the new GHG gases and groups included in the Fourth
Assessment Report (AR4) of the Intergovernmental Panel on Climate Change
http://unfccc.int/national_reports/annex_i_ghg_inventories/items/4624.php
Mis en forme
7.35 Vegetable oil and animal fat extraction and vegetable oil refining
7.35.1 Coverage
Activities covered relate to the vegetable oil and animal fat extraction and vegetable oil refining
activities. The definition is as follows [1]: Any activity to extract vegetable oil from seeds and other
vegetable matter, the processing of dry residues to produce animal feed, the purification of fats and
vegetable oils derived from seeds, vegetable matter and/or animal matter.
However, presently, due to the problem of bovine spongiform encephalopathy, the solvent extraction
of animal fat from dead cows and other animals, for producing animal meals is not more carried out
according to [4]. This chapter consequently covers only vegetable oil extraction.
Process optimisation: the counter current flow Desolventizer-Toaster (DT) allowing to minimize the
solvent losses and steam consumption, the heat integration of DT vapour stream with miscella
distillation in the extraction process leading to an optimisation of the energy consumption, the mineral
oil scrubbing system to reduce VOC emissions and the reboiler minimising solvent losses.
Table 1: control measures with VOC associated emission levels for extraction of vegetable oil
Emission source Combination of control measures BAT associated
emission levels for
VOC
[Defined for the
following averaging
period: (yearly
averagefor total
AELfor total AEL)]
Extraction of oil from seed, Process optimization and counter flow 0.5 g/kg seed
continuous process from desolventizer-toaster-dryer-cooler and processed
rapeseeds, sunflower seeds condensation with further absorption (mineral oil
and soya beans. scrubbing system) and other techniques [2]
Extraction of oil from other described above
3 g/kg seed
seeds such as safflower processed
seed, mustard seed, cotton
seed and vegetable material [as in [3]]
Extraction of seeds in batch 4.0 g/kg seed
process processed
All fractionation processes : 1.5 g/kg seed
excl. degumming: processed
Degumming:
4.0 g/kg seed
processed
[as in [3]]
Mis en forme
7.36 Vehicle refinishing
7.36.1 Coverage
This sector covers the coating of road vehicles, or part of them, carried out as part of vehicle repair,
conservation or decoration outside manufacturing installations as considered in annexe IX.
Vehicle refinishing comprises coating and surface cleaning activities.
Mis en forme
7.37 Wood impregnation
7.37.1 Coverage
This sector covers the wood impregnation in organic solvent-based preservatives, creosote and water-
based preservatives. Wood preservatives may be supplied for both industrial and domestic use. Only
industrial applications are treated in this section.
Table 1: emission sources and selected VOC control measures with associated emission levels
for impregnation of wooden surfaces
Emission source Combination of control measures BAT associated
emission levels for
VOC [2]
[Defined for the
following averaging
period:( yearly
average for total
AEL)]
3
All installations 100% of solvent based preservatives ~ 6 kg/m
vacuum impregnation system and waste gas wood treated
treatment such as activated carbon or
condensation* (adsorption on cartridges with
off-site recovery or disposal may also be
considered)
3
Process optimisation 11 kg/m wood
100% of more concentrated solvent based treated
preservatives
vacuum impregnation system
3
100% of water based preservatives ~ 0.2 kg/m
vacuum impregnation system wood treated
* According to the STS BREF [1], treatment of emissions is carried out in large installations when, in small plants,
abatement equipment may not be economically viable.
Mis en forme
7.38 Solvent content in products 2: Domestic uses of solvent (other than
paints)
7.38.1 Coverage
This source category covers the domestic application of glues, use of car care products, cleaning
agents, leather and furniture care products, pesticides, and cosmetics and pharmaceuticals.
Table 1: maximum allowed VOC content for each type of domestic products
7.41.1.1 SO2
7.41.1.2 NOx
As a measure to reduce NOX emissions, the use of low NOX burners and regular maintenance of the
boiler is recommended [5].
However, these emissions are not considered to be very significant for the sector of beer production
and are not discussed further; information on emissions from energy generation can be found in the
part on industrial boiler plants.
7.41.1.3 Dust
If necessary, cyclones, fabric filters or electrostatic precipitators should be used on exhaust air to
remove particulates [3], [5].
However, these emissions are not considered to be very significant for the sector of beer production
and are not discussed further; information on emissions from energy generation can be found in the
1
part on small combustion plants [6] .
[comment: Corinair 2006 : “These activities are not believed to be a significant source of PM 2.5 (as of
December 2006)“]
7.41.1.4 VOC
Beer production is generally responsible for odorous emissions. Considerable emissions of VOCs can
be released from larger breweries, appropriate abatement techniques for odour and VOC should be
used and exhaust gases should be reused where possible. VOC emissions are partly controlled as a
result of odour reduction requirements and can be reduced by working in closed cycles , e.g. by CO2
recirculation. If the exhausted air from the brewhouse is condensed and the gas from fermentation is
recovered, there is no need for further emission abatement like biofiltration. If not, Biofiltration is a very
useful control measure and is particularly suitable for low VOC concentrations in the exhaust air and
for odorous emissions. Biofilters reduce odour and VOC emissions by absorbing the pollutants onto
the filter material and degrading them by the microorganisms located on the fixed filt er medium. They
are applicable for a wide range of airflows (up to >100000 m³/h), but airborne temperature may not
exceed 40°C. The investments and operating costs of biofiltration in this case are lower than those of
conventional control techniques (e.g. activated carbon adsorption). Alternatively, the organic odour
components can be removed by condensing the vapour from boiling vessels combined with energy
recovery.
VOC emissions generated by certain process steps may be reduced by applying control techniques
like condensation, activated carbon adsorption, or incineration. Selected applicable abatement options
and their respective achievable emission factors are given in Table 1 for beer production [1], [2], [4].
Table 1: VOC emission levels associated with BAT for beer production [2]
[comment: EMEP/Corinair
guidebook 2007 : 0.035 kg/hl
beer; no value given in BREF]
1
The BAT associated emission levels are based on a daily average, standard conditions and represents a typical
load situation. For peak load, start up and shut down periods, as well as for operational problems of the flue gas
cleaning systems, short-term peak values, which could be higher, have to be regarded.
For all mentioned emission reduction and abatement techniques, the cross-media transfer of
pollutants and the full range of environmental effects and improvements should be considered. For
example additional energy consumption and increased quantities of waste or wastewater residuals
may result from individual efforts for pollutant prevention, reduction, or removal.
Operating
Characteristics of reference Investmentsa/ Abated mass flow
Control options costsb/
installation [EURO] [Mg VOC/year]
[EURO/year]
0.225-0.3 €/1000m³
(including 0.15-0.225 €/1000m³ energy cost,
Larger plants Down to 10-15 €/m³ calculated with electricity costs at 0.15 €/kWh)
1 European Commission. 2006: “Integrated Pollution Prevention and Control (IPPC) Reference
Document on Best Available Techniques in the Food, Drink and Milk Industries.”
http://eippcb.jrc.es/pages/FActivities.htm
2 Old version of the Gguidance document on control techniques for emissions of sulphur, NOx and
VOCs from stationary sources - 1999
3 Environmental Protection Agency Ireland. 2006: Draft BAT Guidance Note on Best Available
Techniques for the Brewing, Malting & Distilling Sector (Final draft)
4 IFC 2007. International Finance Corporation (World Bank Group): Environmental, Health, and Safety
Guidelines for Breweries
5 The Brewers of Europe 2006: Guidance Note for establishing BAT in the brewing industry
6 EMEP/CORINAIR Emission Inventory Guidebook (Activities 040606-040608), December 2006
high-speed engines are mostly used in peak load applications. High-speed stationary engine types
are usually small (unit size output up to a 5 MW e) and mostly operate on natural gas, biogas, landfill
Typical classification of
Operating Ignition and Unit electric power
engines based on Mode of operation Fuels
principle combustion output
engine speed
One fuel operation Liquid distillate fuel (diesel oil),
Compression & HFO, residual, emulsified fuel
2-stroke Low speed (< 300 rpm) Dual fuel (GD) Up to 90 MW e
Open chamber oil, refinery vacuum residuals,
(high pressure natural gas) natural gas
Ignition Liquid fuels, gas (Spark ignited Depending on engine type (see
type, SG) Chapter 2):
-Compression Up to
-Pilot Liquid distillate fuel (diesel oil),
Medium speed Dual fuel operation HFO, liquid residual fuel oil, - 25 MWe (diesel)
-Spark (300 – 1200 rpm) High pressure natural gas (Gas emulsified fuel oils, refinery - 17 MWe (DF)
-Hot body Diesel, GD) vacuum residuals, liquid
Low pressure natural gas (Dual biofuels - 10 MWe (SG)
4 –stroke Fuel, DF) Natural gas, biogas, landfill gas
Combustion
Back-up-mode: liquid fuel
-Open chamber
-Pre-chamber
One fuel operation Natural gas, biogas, landfill gas,
-Lambda 1 High speed
Liquid fuels, gas (Spark ignited liquid biofuels, liquid distillate Up to 5 MW e
-Lean-burn (> 1200 rpm) fuel oil (diesel oil),
type)
BAT for controlling NO x emissions from lean burn type gas engines
For gas-fired stationary engine plants, the lean-burn approach to reduce NO x emissions is BAT, it is
analogous to the dry low NOx technique used in gas turbines. This is a primary measure that requires
no extra reagents or water additions to achieve low NO x levels. For spark plug or by other device
3
ignited (SG) natural gas fired lean-burn engines, a NOx level of 95-190 mg/Nm at 15% O2 and 190-
3
380 mg/Nm at 15% O2 for low pressure gas dual fuel engines are achievable by primary measures.
Because gas engines can be equipped with a SCR this is also considered as BAT. For engines using
natural gas oxidation catalysts are BAT for CO emissions control. Fuel gas cleaning will be needed in
1
most cases when using oxidation and SCR catalysts when burning other gaseous fuels, such as
2
biogas or landfill gases, that might contain catalyst poisons . Engine optimization is a compromise
between NOx emissions, engine efficiency (fuel consumption and thus CO 2 emission) and other
emissions (such as CO and hydrocarbons). With the application of SCR (secondary measure) NOx
3 3
emissions levels in range of 5 -19 mg NOx /Nm in 15 % O2 have been measured.
A Dual Fuel (DF) engine is not part of the current Protocol. A DF engine in liquid/back-up mode has
higher NOx emissions than a modern diesel engine due to the lower compression ratio, a DF engine is
optimized for natural gas mode operation.
The emission of NOx depends on the engine speed. Fuel efficient, large bore, low speed engines tend
to have higher NO x emissions than faster running smaller engines. When the engine speed is lower,
NOx concentrations are higher in the combustion chamber because of the longer residence time
during which to form NOx.
Options for reducing emissions to air from liquid fuel-fired (diesel) engines
The main pollutants emitted in the exhaust of a typical (compression ignition) diesel engine burning
heavy fuel oil include nitrogen oxides (NO x), particulate matter (PM) and sulphur oxides (SO x). SOx
and PM are mainly fuel related emissions. Due to the high efficiency resulting from the high
temperature of combustion in stationary diesel engines, emissions of unburned emissions such as
carbon monoxide and unburned hydrocarbons are low.
4
CIMAC – The International Council on Combustion Engines – Background information on black carbon from large marine and stationary
diesel engines – definition, measurement methods, emission factors and abatement techniques -2012
5 LCP BREF 2006, page 356
The applicable secondary method for diesel engines is the use of SCR (Selective Catalytic
Reduction).
Technical measures to reduce NOx emissions can be divided into primary and secondary abatement
techniques:
Primary methods for liquid fuel-fired diesel engines, such as a base engine optimized for low NO x
(using the Miller concept - a “dry method”), fuel injection retards, the addition of water (such as water
injection directly into the combustion space, water-in-fuel emulsion, or humidification of the
combustion air, water emulsion, etc. depending on the application and engine manufacturer). “Dry
methods” are preferred in those areas where there is limited access to suitable water supplies.
Mechanical, thermal loading and fuel consumption limitation, etc. aspects are factors to consider when
applying primary NO x reduction methods.
By using a low NOx combustion concept in combination with the Miller concept the NO x emissions of
modern engines is up to 40 % lower than that of a similar engine type from the beginning of 1990s
whilst maintaining the same, high, efficiency. The development work is continuing but the turbocharger
is the technical bottleneck; higher pressure ratios are needed in order to enhance the “Miller-concept”,
otherwise the fuel consumption will increase and power output of the engines might decrease. A new
generation of turbochargers is needed if lower NO x emissions are to be achieved.
Secondary method: the only applicable secondary method for diesel engines is exhaust gas treatment
with SCR (Selective Catalytic Reduction). SCR is an efficient NO x abatement technique in cases
where it is possible to take into account the following issues related to installation and operation
6
ensuring that the techniques works properly :
a minimum flue-gas temperature needs to be maintained, depending on the sulphur content of
the fuel;
some trace metals (such as Na, K, Ca, Mg, As, Se, P) might act as catalyst poisons
if heavy fuel oil or other residual fuels are used, a soot blowing system needs to be installed
in the SCR reactor to keep the elements clean and avoid pressure drop increases
regular maintenance and inspection in order to maintain low ammonia slips that are harmful
for components situated after the SCR reactor
disposal of used elements
supply of reagents (pure ammonia, aqueous ammonia or urea) needs to be ensured
(infrastructure exists)
installation, operation and maintenance costs to be covered
Achievable NOx emissions ranges for existing diesel engines with primary measures and secondary
measures are described in Table 3 (measurement results from selected references around the world,
note ambient relative humidity has a big impact on the resulting NO x emissions from a diesel engine).
As mentioned above the achievable NO X emissions for new diesel engines are now below 2000
mg/Nm³ in case of primary measures (WB EHS guidelines: 1460 - 1850 mg/Nm³ at 15 % O2),
depending on the bore size.
Table 3: examples of achievable NOx emissions with emission reduction measures for diesel
7
engines
6
LCP BREF 2006, page 360
7
LCP BREF 2006, page 379
The fuel quality also has impact on the primary NO x abatement methods that can be used. In small
high speed applications e.g. EGR (Exhaust Gas Recirculation) and high pressure, electronically
controlled injection can be used and lower NO x levels achieved compared to the bigger engine types.
The “Miller concept” (early closing timing of the air inlet valves, which suppresses the in-cylinder
temperatures reducing NO x formation) and advanced fuel injection equipment are applicable to bigger
modern engine types.
Reducing NOx emissions by primary measures may increase other emissions such as CO, CO 2 and
particulate matter as shown in Figure 1. Oxidation catalysts may be applied to abate emissions from
high speed light fuel oil fired engines but not for engines using heavy fuel oil.
Figure 1: Typical emission trends for a diesel engine as a function of efficiency (cylinder
temperature)
CO
Control of NOx emissions from gas engines, spark-ignited (SG) and dual fuel (DF) (gas mode)
Spark, or otherwise, ignited 4-stroke lean-burn gas engines (SG) are “pure gas” engines, they operate
on low pressure natural gas and (depending on engine type) also biogases such as landfill, digester
and mine gases. Dual fuel (DF) engines are designed to operate in gas mode on low-pressure natural
gas as the main fuel.
By primary engine measures in natural gas mode following NO x emissions can be achieved: for lean-
3
burn SG engines 95-190 mg/Nm at 15% O2 and for low pressure gas dual fuel engines 190-380
3
mg/Nm at 15% O2. For other gases than natural gas levels of 95-190 mg/Nm³ can also be achieved
with lean burn SG engines, but possible fluctuations of gas composition and contaminations may have
to be considered when defining emission limit values.
The combustion temperature is the most important parameter governing the rate of NO x formation in
internal combustion engines: the higher the temperature the higher the NO x content of the exhaust
gases. One method to reduce the combustion temperature is to lower the fuel/air ratio, the same
specific heat quantity released by the combustion of the fuel is then used to heat up a larger ma ss of
exhaust gases, resulting in a lower maximum combustion temperature. This primary measure called
the lean-burn approach in gas-fired stationary engines is analogous to dry low-NOx combustors in gas
turbines. Gas fired stationary engine (SG and DF types) installations have low NO x levels due to the
lean-burn approach.
As the lean-burn engine operates in a leaner mode (enhanced lean-burn) at lower set NO x levels with
higher specific fuel consumption, the flue gas temperature gets colder and as a consequence the
useful heat energy in the flue gas decreases.
In some special applications stationary gas engines are equipped with SCR for additional NO x
9
reduction . The driving force for application of SCR is the need to improve local air quality. Strict NO x
9
In 2008 in the Netherlands there were about 1000 stationary gas engines using SCR (such as CHP production and CO2 fertilization in
greenhouses). However it should be noted that the feasible investment costs when comparing a power plant to a greenhouse gas
application differ considerably."
reduction targets are also needed for some countries with a polluted air-shed in order to meet the
obligations of international agreements or EU Directives. In Table 4 achievable NO x emission levels for
gas fired engines with reduction measures are given.
In some special applications stationary gas engines are equipped with SCR for additional NO x
reduction. The driving force for application of SCR is the need to improve local air quality. Strict NO x
reduction targets are also needed for come countries with a polluted air-shed in order to meet the
obligations of international agreements or EU directives. For instance, one country has taken action
3
for applying stricter NO x ELVs such as 35 mg/Nm for stationary engines with obligation of using SCR,
due to the need to take in use all possible reduction measures for different sectors in order to be able
to comply with the NO x ceiling of the Gothenburg Protocol.
Table 4: achievable NOx emissions for gas engines (at steady state engine load) according to
10
the EU LCP BREF Document
NOx emissions,
Engine type 3
Measure Remarks
mg/Nm (Dry, 15 % O2)
10
Tables 7.9 (p.438) and 7.26 (p.466)
11 This NOx value can be reached under ideal conditions using a new and fresh catalyst but will not be met during normal operation.
3
Based on the information from the engine industry, emission levels around 100 mg/Nm , are only
applicable for gas engines (equipped with oxidation catalysts) burning natural gas and not for gas
engines burning renewable gases like landfill gas, biogas or purification gas. For them the CO
3 14
associated level should be at a level of 110 – 380 mg/Nm (15 % O2) in order to represent BAT , due
to technical reasons (fuel composition impact).
As the lean-burn engine operates in a leaner mode at lower set NO x levels with higher specific fuel
consumption, the flue gas temperature gets colder and as a consequence the useful heat energy in
15
the flue gas decreases (detrimental for e.g. steam production in a CHP plant) .
SCR has a high initial purchase price and, depending on the quality of the fuel used the catalysts will
need to be replaced periodically – and used catalyst disposed of in a proper manner. In addition, SCR
requires good technical support including spare parts and expertise to operate and maintain. For
typical costs of SCR as a function of NO x reduction, see Figure 2. Note that the cost and availability of
reagent might vary from location to location.
12Field Experience and Laboratory Analysis of Oxidation Catalyst on Dual Fuel Fuel Engines”, by Shazam Williams; Mojghan Naseri; Joe
Aleixo; Kristoffer Sandelin, published May, 7, 2006
13 LCP BREF, page 480
14 subheader 3 in Table 7.36 of LCP BAT BREF
15
Due to deposits formed inside the combustion chamber of biogas (landfill gas, anaerobic fermenter gases) fired engines, NOx levels far
below 190 mg/Nm3 at 15% O2 can not be achieved over the operation life of the engine because of a drift of the emissions caused by
isolation effects and change in combustion chamber geometry (Annex 7).
Figure 2: typical costs of SCR as a function of NO x reduction rate, heavy fuel oil fired medium
speed diesel engine power plant, reagent handling not included. Urea 40% solution 200
euros/ton, aqueous 25% ammonia solution 225 euros/ton)
Euro / MWh
6
30
4
20
10 2
0 0
0 20 40 60 80 100 20 40 60 80 100