emission estimation technique manual in combustion of boilers

National Pollutant Inventory

Emission estimation technique manual

for Combustion in boilers

Version 3.1

June 2008

First published in August 1999

ISBN: 978-0-642-55386-7 © Commonwealth of Australia 2008 This manual may be reproduced in whole or part for study or training purposes subject to the inclusion of an acknowledgment of the source. It may be reproduced in whole or part by those involved in estimating the emissions of substances for the purpose of National Pollutant Inventory (NPI) reporting. The manual may be updated at any time. Reproduction for other purposes requires the written permission of the Department of the Environment, Water, Heritage and the Arts, GPO Box 787, Canberra, ACT 2601, e-mail: [email protected], web: www.npi.gov.au, phone: 1800 657 945. Disclaimer The manual was prepared in conjunction with Australian states and territories according to the National Environment Protection (National Pollutant Inventory) Measure. While reasonable efforts have been made to ensure the contents of this manual are factually correct, the Australian Government does not accept responsibility for the accuracy or completeness of the contents and shall not be liable for any loss or damage that may be occasioned directly or indirectly through the use of, or reliance on, the contents of this manual.

Combustion in boilers Version 3.1 June 2008

i

EMISSION ESTIMATION TECHNIQUES FOR

COMBUSTION IN BOILERS TABLE OF CONTENTS

1 INTRODUCTION................................................................................................... 1

1.1 Information required to produce an annual NPI report ............................ 2 1.2 Additional reporting materials ................................................................. 2

2 PROCESS DESCRIPTION..................................................................................... 3

2.1 Fuel types ................................................................................................. 3 2.2 Expected emissions .................................................................................. 3 2.3 General boiler types ................................................................................. 4

2.3.1 Combustion of solid fuels ........................................................................ 4 2.3.2 Combustion of liquid fuels....................................................................... 6 2.3.3 Combustion of gaseous fuels.................................................................... 7

2.4 Emission controls ..................................................................................... 7

3 EMISSION SOURCES........................................................................................... 8

3.1 Emissions to air ........................................................................................ 8 3.1.1 Fugitive emissions.................................................................................... 8 3.1.2 Point source emissions ............................................................................. 8

3.2 Emissions to water ................................................................................... 8 3.3 Emissions to land ..................................................................................... 9

4 THRESHOLD CALCULATIONS ....................................................................... 10

4.1 Category 2a and 2b thresholds for boiler fuels ...................................... 10

5 TECHNIQUES FOR ESTIMATING EMISSIONS ............................................. 12

5.1 Emission factors ..................................................................................... 13 5.2 Direct measurement................................................................................ 13

5.2.1 Sampling data......................................................................................... 14 5.2.2 Continuous Emission Monitoring System (CEMS) data ....................... 16 5.3 Engineering calculations ........................................................................ 19

5.3.1 Fuel analysis........................................................................................... 19 5.4 Approved alternative technique ............................................................. 20 5.5 Calculating emissions............................................................................. 20

5.5.1 Emission factors for boiler fuel.............................................................. 20

6 TRANSFERS OF NPI SUBSTANCES IN WASTE ............................................ 25

7 NEXT STEPS FOR REPORTING ....................................................................... 26

8 REFERENCES...................................................................................................... 27

APPENDIX A: DEFINITIONS AND ABBREVIATIONS ............................................. 28

APPENDIX B: TABLES .................................................................................................. 29

APPENDIX C: MODIFICATIONS TO THE COMBUSTION IN BOILERS EMISSION ESTIMATION TECHNIQUE (EET) MANUAL (MARCH 2008).................................. 74

Combustion in boilers Version 3.1, June 2008

ii

COMBUSTION IN BOILERS

LIST OF FIGURES, TABLES, EQUATIONS AND EXAMPLES

Figure 1: The process for NPI reporting .................................................................................... 2 Figure 2: Process for combustion in boilers............................................................................... 4 Table 1: Category 2a and 2b substances .................................................................................. 10 Table 2: Stack sample test results ............................................................................................ 16 Table 3: Example CEM output averaged for a boiler firing waste fuel oil .............................. 17 Table 4: Conversion factors for common boiler fuel types...................................................... 29 Table 5: Emission factors for bagasse (kg/t)............................................................................ 30 Table 6: Emission factors for brown coal briquettes (kg/t)...................................................... 30 Table 7: Emission factors for black coal – cyclone furnace (kg/t)........................................... 31 Table 8: Emission factors for black coal – fluidised bed combustion, bubbling bed,

uncontrolled (kg/t) ............................................................................................................ 33 Table 9: Emission factors for black coal – fluidised bed combustion, circulating bed,

uncontrolled (kg/t) ............................................................................................................ 34 Table 10: Emission factors for black coal – overfeed/crossfeed stoker (kg/t) ......................... 35 Table 11: Emission factors for black coal – overfeed/spreader stoker, uncontrolled (kg/t) .... 36 Table 12: Emission factors for black coal – spreader stoker (kg/t).......................................... 37 Table 13: Emission factors for black coal – underfeed stoker, uncontrolled (kg/t) ................. 41 Table 14: Emission factors for black coal – pulverised coal (kg/t).......................................... 42 Table 15: Emission factors for black coal – pulverised fuel, dry bottom boilers (kg/t)........... 43 Table 16: Emission factors for black coal – pulverised fuel, wet bottom boilers (kg/t) .......... 51 Table 17: Emission factors for blast furnace gas – uncontrolled (kg/t) ................................... 55 Table 18: Emission factors for coke oven gas – uncontrolled (kg/t) ....................................... 56 Table 19: Emission factors for landfill gas - uncontrolled (kg/MJ)......................................... 56 Table 20: Emission Factors for natural gas – tangential fired (kg/t)........................................ 57 Table 21: Emission factors for natural gas – wall fired (kg/t) ................................................. 58 Table 22: Emission factors for petroleum refinery gas - uncontrolled (kg/m3) ....................... 62 Table 23: Emission factors for LPG – uncontrolled (kg/t)....................................................... 62 Table 24: Emission Factors for residual oil (kg/t).................................................................... 62 Table 25: Emission factors for distillate (diesel) oil (kg/t) ...................................................... 67 Table 26: Emission factors for waste oil - uncontrolled (kg/t) ................................................ 68 Table 27: Emission factors for tallow (kg/t) ............................................................................ 69 Table 28: Emission factors for wood and wood waste (kg/t)................................................... 69 Table 29: Emission control efficiency rates............................................................................. 73 Equation 1 ................................................................................................................................ 14 Equation 2 ................................................................................................................................ 14 Equation 3 ................................................................................................................................ 15 Equation 4 ................................................................................................................................ 15 Equation 5 ................................................................................................................................ 17 Equation 6 ................................................................................................................................ 17 Equation 7 ................................................................................................................................ 18 Equation 8 ................................................................................................................................ 19 Equation 9 ................................................................................................................................ 20 Example 1: Example of a threshold calculation....................................................................... 11 Example 2: Using stack sampling data .................................................................................... 16


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Example 3: Using CEMS Data................................................................................................. 18 Example 4: Calculating sulfur dioxide emissions using fuel analysis ..................................... 20 Example 5: Reporting on NPI emissions at a facility using steam for its operations .............. 21


iv

1 Introduction The purpose of all emission estimation technique (EET) manuals is to assist Australian manufacturing, industrial and service facilities to report emissions of listed substances to the National Pollutant Inventory (NPI). This manual describes the procedures and recommended approaches for estimating emissions resulting from combustion in boilers. Note that the ANZSIC code is part of NPI reporting requirements. The NPI Guide contains an explanation of the ANZSIC coding system.

EET MANUAL Combustion in boilers ANZSIC 2006 Any industry sector where combustion is used in the

production of steam for energy and/or hot water, i.e. ANZSIC 2006 Divisions A – S.

NPI substances are those that when emitted at certain levels have potential to be harmful. Australian, state and territory governments have agreed, in response to international requirements, that industry will report these emissions on an annual basis. Reportable NPI substances are listed in the NPI Guide and are classified into six categories with different reporting thresholds. If your facility trips a threshold in a reporting year for a substance on the reporting list, all the emissions of that substance from your facility must be reported. The NPI Guide is available on the NPI website at www.npi.gov.au This manual has been developed through a process of national consultation involving state and territory environmental authorities and key industry stakeholders. Particular thanks are due to the HRL Technologies Pty Ltd for their assistance in developing this manual.

Combustion in boilers 1 Version 3.1 June 2008

http://www.npi.gov.au/

Figure 1: The process for NPI reporting The process for NPI reporting can be seen in the following flow chart:

1.1 Information required to produce an annual NPI report Facilities will be required to estimate the type and level of certain emissions that result from the combustion process in boilers. Hence you will need to know the types of fuels, the boiler types and the quantities of fuels used in each boiler. In addition to fuel used in boilers, data will need to be collated for all fuel burning equipment, including any fuel oil or gas used in initial ‘light-off’, on-site vehicles etc.

1.2 Additional reporting materials This manual is written to reflect the common processes employed in boiler use. In many cases it will be necessary to refer to other EET manuals to ensure a complete report of the emissions for the facility can be made. Other applicable EET manuals may include, but are not limited to:

• Fuel and organic liquid storage; • Combustion in engines; and • Fugitive emissions.


2 Process description The first step in estimating emissions of NPI substances from your facility is creating a process flow diagram to highlight points in the process where emissions may occur. In the case of combustion in boilers this involves identifying the fuels burnt on site and the boiler types. When considering the fuel usage on site it is important to note:

• for fuel, ‘usage’ indicates the amount of fuel burnt on site, not ‘usage’ as applies to individual NPI substances (receipt, storage, handling, manufacture, import, processing, coincidental production or other uses); and

• fuels burnt in both boilers and engines need to be considered for the total fuel usage.

2.1 Fuel types The main fuels likely to be used in boilers used in Australia include:

• Diesel; • Petroleum products; • Black coal; • Natural gas; • Bagasse; • Residual fuel oil; • Wood and wood waste; • Coal by-products; • Brown coal briquettes; • Synthetic biofuels; • Tallow; • Various process gasses; and • Waste oil.

2.2 Expected emissions All fuels emit substances when combusted, many of which may be harmful and therefore of interest to the NPI. A large number of industrial processes and facilities make use of industrial boilers for hot water and steam energy. Industrial boilers use a range of fuels depending on boiler size and design characteristics and on the availability/proximity of fuel. In many cases the fuel is a by-product or waste product from other processes. The volume and nature of the emissions from combustion in boilers differs depending on the fuel composition, fuel consumption, boiler design and operation, and the emission and pollution control devices in use. Whatever fuel is used the process of combustion is basically as follows:


Figure 2: Process for combustion in boilers

Combustion

Heat and steam energy

Gaseous emissions

Fuel and oil

When fuels burn they are converted to various substances, some of which are NPI listed substances. The non-combustible portion of the fuel remains as a solid waste. The coarser, heavier waste is called ‘bottom ash’ and is extracted from the burner, and the lighter, finer portion is ‘fly ash’ and is usually emitted as particulates through the stack. Products of incomplete combustion include carbon monoxide, sulfur oxides, oxides of nitrogen, acid gases and organic compounds. Metals and their compounds may also be entrained (carried forward by a stream of gas or vapour of fine liquid droplets). A number of techniques exist to assist complete combustion and to remove some emissions.

2.3 General boiler types

2.3.1 Combustion of solid fuels There are three basic modes of burning solids fuels:

• in suspension; • in a bed at rest on a grate (fuel bed firing) – the fuel bed may be moved slowly

through the furnace by the vibrating action of the grate or by being carried on a travelling grate; and

• in a fluidised bed. Although many variations of the above have been developed, the fundamental characteristics of equipment and procedures are the same. Suspension firing Suspension firing of pulverised coal (PC) is more common than fuel-bed or fluidised bed firing of coarse coal. This mode of firing affords higher steam generation capacity, is independent of the caking characteristics of the coal, and responds quickly to load changes. It is rarely used on boilers of less than 45.4 t/h steam capacity as economic advantage decreases as size decreases. Therefore, suspension fired boilers are more common for power generation or large steam raising boilers rather than for smaller industrial boilers. Fuel-bed firing (stoker) Fuel-bed firing is accomplished with mechanical stokers, which are designed to achieve continuous or intermittent fuel feed, fuel ignition, proper distribution of the


combustion air, free release of the gaseous combustion products, and continuous or intermittent disposal of the unburned residue. An advantage of stoker-fired furnaces is the adaptability to fire almost any unsized solid fuels (e.g. bark, bagasse, refuse). There are two classes of stoker, which are distinguished by the direction of fuel feed: • overfeed stokers; and • underfeed stokers.

Overfeed stokers There are two general types of overfeed stokers, which are distinguished by the relative direction of fuel and air flow, as well as by the manner of fuel feed. • Cross-feed stokers

In cross-feed stokers, the fuel is dumped by gravity from a hopper onto one end of a moving grate, which carries the fuel into the furnace and down its length. Cross-feed stoker boilers are also termed travelling-grate stoker boilers. In the cross-feed stoker the fuel flows at right angles to the air flow. Cross-feed (travelling-grate) boilers are more commonly used with smaller scale industrial boilers

• Spreader stokers

In spreader stokers, the fuel is propelled into the furnace. A portion of the fuel burns in suspension while the rest burns on the grate. In most units, the fuel is pushed off a plate under the storage hopper onto revolving paddles (either overthrow or underthrow), which distribute the fuel on the grate. The largest fuel particles travel the furthest, while the smallest ones become partially consumed during their trajectory and fall on the forward portion of the grate. The grate may be stationary or travelling. The fuel and air flow in opposite directions. Spreader stoker boilers are typically used for larger industrial boilers.

Underfeed stokers For an underfeed stoker, both the fuel and air have the same relative direction. Underfeed stokers can be of single-retort and multiple-retort designs. In the single-retort side-dump stoker, a ram pushes the solid fuel into the retort toward the end of the stoker and upward toward the tuyere blocks (the nozzle that the air is forced through), where the air is admitted to the bed (of fuel). In multiple-retort stokers, the solid fuel is feed by rams to the top of sloping grates between banks of tuyeres. Auxiliary small sloping rams perform the same function as the pusher rods in the single retort. Air is admitted along the top of the banks of tuyeres, and on the largest units the tuyeres are given a slight reciprocating action to agitate the bed further.


Fluidised-bed combustion In fluidised-bed combustion (FBC), fuel is burned in a bed of particles supported in an agitated state by an upward flow of air introduced via an air distributor. The bed may be sand or ash derived from the fuel. In some cases, sulfur sorbent like limestone or dolomite may also be used. Fluidised beds have inherently good heat-transfer characteristics that ensure even temperatures within the combustor and high heat flux rates to steam/water cooling circuits. The good gas-solids contacting promotes effective sulfur capture by sorbents and allows high combustion efficiency to be achieved at significantly lower temperatures than would be required by, for example, for a pulverised coal (PC) fired furnace. These lower temperatures result in reduced slagging and fouling problems and significantly lower NOX formation. There are two types of FBC units, distinguished by their operating flow characteristics:

• bubbling; or • circulating fluidised-beds.

Bubbling FBC units operate with a relatively low gas velocity within the fluidised-bed and have distinct bed and freeboard regions with the majority of the combustion reaction occurring within the bed. By comparison, circulating FBC units operate with a higher gas velocity and combustion occurs throughout the reactor and unburnt particles that are carried out of the reactor are captured and returned to the bottom of the bed. Both types of FBC combustors can be designed to operate at atmospheric pressure or at elevated pressure. An advantage of FBC is fuel flexibility, however, the unit must be designed for the range of fuels. A single FBC unit can burn a wider range of materials that a PC furnace.

2.3.2 Combustion of liquid fuels Oil is typically burned as a suspension of droplets generated by atomising the fuel. As the droplets pass from the atomiser into the flame zone, they are heated both by radiation from the flame and by convection from the hot gases that surround them. The light fuel components vaporise and the vapours mix with surrounding air and ignite. Depending on the fuel type, the fuel droplet may be completely vaporised or it may be partially vaporised, leaving a residual char or coke particle. Atomisers can be classified into two broad groups: pressure atomisers, in which fuel oil is injected at high pressure, and twin-fluid atomisers, in which fuel oil is injected at moderate pressure with a compressible fluid (steam or air) to assist in the atomisation process. Many oil burners are designed as combination gas/oil burners.


2.3.3 Combustion of gaseous fuels Gas burners may be classified as premixed or non-premixed. The flow rate of gas and / or combustion air can be regulated to achieve the required flame characteristics and level of excess air. Many forms of flame stabilisers are employed in gas burners. The use of gaseous fuels with heating values lower than that of natural gas, e.g. coke oven gas, results in a low flame temperature and, therefore, an increased heat transfer surface area to capture an equivalent amount of heat is required.

2.4 Emission controls A number of pollution control techniques are available to reduce emissions from boilers. Primary measures to reduce emissions at the source or during combustion include: switching to fuels with a lower levels of sulfur, nitrogen, metals etc; combustion modifications which could include capacity de-rating, burner and in-furnace modifications, air and fuel modifications; and a range of combustion control mechanisms for the reduction of oxides of nitrogen. These mechanisms are referred to in Appendix B, Table 6 and include:

• low excess air (LEA); • staged combustion (SC) including burner out-of-service (BOOS), biased

burner firing (BBF), over-fire air (OFA) and fuel staging (FS); • flue gas recirculation (FGR); • reduced air preheat (RAP); and • low NOx burners (FGR, RAP, FS).

Secondary measures to reduce emissions include a number of processes and physical devices to reduce particulate, sulfur dioxide, oxides of nitrogen and metal emissions. Among the devices used are:

• electrostatic precipitators (ESP) for removal of particulate matter (PM2.5 and PM10);

• fabric filtration (baghouse) for removal of particulate matter (PM2.5 and PM10) and including substances that resist ESPs;

• cyclones and multicyclones for pre-cleaning, generally to remove PM, although it is most effective for particles larger than 10µm;

• wet and dry scrubbers for the removal of a number of pollutants which may include some particulates however this is dependent on the design of the scrubber; and

• techniques for the removal of sulfur dioxide (common flue gas desulfurisation (FGD)); and oxides of nitrogen (selective catalytic reduction (SCR) and selective non-catalytic reduction (SNCR)).


3 Emission sources General information regarding emission sources can be located in the NPI Guide. However, it is important to note that emissions from combustion in boilers will generally be directed through an air stack unless there is a spill.

3.1 Emissions to air Air emissions may be categorised as fugitive emissions or point source emissions.

3.1.1 Fugitive emissions Fugitive emissions are not released through a vent or stack. Examples of fugitive emissions include emissions from vehicles, dust from stockpiles, volatilisation of vapour from vats and open vessels, or spills and materials handling. Emissions emanating from ridgeline roof-vents, louvers, and open doors of a building as well as equipment leaks, such as from valves and flanges are also examples of fugitive emissions. The nature of fugitive emissions does not lend itself to the use of control devices. Emission factor EETs are the usual method for determining losses from fugitive emission sources. It is expected that most emissions from boilers would not be fugitive emissions, although fugitive emission may occur at other parts of a facility such as from fuel storage.

3.1.2 Point source emissions Point source emissions are directed into a vent or stack and emitted through a single point source into the atmosphere. Most boiler emissions would be point source emissions and have the potential for monitoring activities, although these would not be commonly used. Air emission control technologies such as electrostatic precipitators, fabric filters or baghouses, and wet scrubbers are commonly installed to reduce the concentration of particulates in processing off-gases before emission through a stack. The collection efficiency of the abatement equipment needs to be considered where such equipment has been installed, and where emission factors from uncontrolled sources have been used in emission estimations. Guidance on applying collection efficiencies to emission factor equations is provided in Appendix B, Table 29.

3.2 Emissions to water Emissions of substances to water can be categorised as discharges to:

• surface waters (lakes, rivers, dams, estuaries); • costal or marine waters; or • stormwater runoff.


Emissions of toxic substances to waterways may pose environmental hazards. Most facilities emitting NPI-listed substances are required by their state or territory environment agency to closely monitor and measure these emissions. The existing sampling data can be used to calculate annual emissions to the NPI. The discharge of NPI listed substances to a sewer or tailings dam is not regarded as an emission but a transfer and as such is reportable to the NPI as a transfer (refer to Section 6: Transfers of NPI substances in waste, p29).

3.3 Emissions to land Emissions of substances to land include solid wastes, slurries, sediments, spills and leaks, storage and distribution of liquids, and such emissions may contain NPI-listed substances. Emission sources can be categorised as:

• Surface impoundments of liquids and slurries, or • Unintentional leaks and spills.

Some facilities may use treated wastewater for irrigation. This wastewater need only be considered for NPI reporting if it contains an NPI-listed substance. For NPI purposes this is categorised as an emission to land.


4 Threshold calculations The NPI Guide outlines detailed information on thresholds and identifying emission sources. The method involves identifying any NPI substances that may be used by your facility, or are components of materials used by your facility, and then calculating whether the quantity you use exceeds a NPI threshold. If the threshold is exceeded for any NPI substance, then all emissions from your facility of that substance must be reported.

4.1 Category 2a and 2b thresholds for boiler fuels The threshold for Category 2a is the burning of 400 tonnes or more of fuel in the reporting year. If your facility burns 400 or more tonnes of fuel, reporting of emissions of all Category 2a NPI substances listed in Table 1 is required. The threshold for Category 2b is the burning of 2000 tonnes or more of fuel in the reporting year. If your facility burns 2000 or more tonnes of fuel, reporting of emissions of both Category 2a and 2b NPI substances listed in Table 1 is required. Table 1: Category 2a and 2b substances

Category 2a substances Category 2b substances Carbon monoxide Fluoride compounds Hydrochloric acid Oxides of Nitrogen Particulate matter 10 micrometres or less

in diameter (PM10) Particulate matter 2.5 micrometres or less

in diameter (PM2.5) Polycyclic aromatic hydrocarbons (PAHs) Sulfur dioxide Total Volatile Organic Compounds

(TVOCs)

Arsenic and compounds Beryllium and compounds Cadmium and compounds Carbon monoxide Chromium(III) compounds Chromium(VI) and compounds Copper and compounds Fluoride compounds Hydrochloric acid Lead and compounds Magnesium oxide fume Mercury and compounds Nickel and compounds Oxides of Nitrogen Particulate matter 10 micrometres or less

in diameter (PM10) Particulate matter 2.5 micrometres or less

in diameter (PM2.5) Polychlorinated dioxins and furans Polycyclic aromatic hydrocarbons (PAHs) Sulfur dioxide Total Volatile Organic Compounds

(TVOCs)


Example 1: Example of a threshold calculation A facility burns 6000 tonnes of virgin wood products and 300 tonnes of black coal in a year. A volume of 1500 m3 of LPG (butane) is used as a fuel source for onsite forklifts. The process for calculating whether the facility trips NPI thresholds is set out below: Category 2a and 2b threshold calculations As previously outlined at Section 2 in the manual, the combustion of fuel results in the emission of a number of NPI listed substances. For this reason, the NPI Guide indicates that the burning of 400 tonnes or more of any fuel will trigger the Category 2a threshold and 2000 tonnes or more will trigger the Category 2b threshold. For the purpose of threshold calculations, the unit for measuring fuel quantities is tonnes. The first step is to convert the volume of LPG from cubic metres to tonnes. Appendix B, Table 4 indicates that the conversion rate is 0.58kg/litre. To calculate the weight of 1500 m3 of LPG the calculation is: (0.58 ÷1000 (tonnes)) x 1000 (litres per cubic metre) x1500 (cubic metres)) = 870 tonnes. Thus the total fuel usage is 6000 tonnes of wood fuel, 300 tonnes of black coal and 870 tonnes of LPG. This quantity of fuel exceeds the Category 2a and 2b thresholds as set out in the NPI Guide. Hence all NPI Category 2a and 2b emissions must be estimated and reported.


5 Techniques for estimating emissions If you have established under Section 4 that the quantity of fuel burnt at your facility meets or exceeds the Category 2a or Category 2b threshold, you will need to estimate the emissions to air, land and water of each tripped NPI substance. There are five approved approaches to estimating emissions for NPI purposes. These are as follows:

• mass balance, • fuel analysis or engineering calculations, • sampling data or direct measurement, • emission factors, and • an approved alternative.

Generally, facilities that use fuel in boilers would report emissions for NPI substances using the emission factor method. The emission factor method is described in Section 5.1. As outlined above, a range of EETs can be used to calculate emissions. In the case of boiler fuel emissions, local point source measurements (including ‘sampling’, ‘direct measurement’, and ‘fuel analysis’ techniques) have the potential to provide the best results. However these techniques are complex, and rely on consistency and expert assumptions. They are only beneficial when they are science-based and applied rigorously and with expertise. However, you may wish to use either of these techniques in order to report to the NPI, particularly if you already do so in order to meet other regulatory requirements. Information in relation to these techniques is detailed in the manual. Direct measurement is described in Section 5.2 and fuel analysis is described in Section 5.3. You will need to select the EET (or mix of EETs) that is most appropriate for your purposes. You can choose a mix of techniques depending on the application. If you estimate your emission by using any of these EETs, your data will be displayed on the NPI database as being of ‘acceptable reliability’. Similarly, if your relevant environmental authority has approved the use of EETs not outlined in this manual, your data will also be displayed as being of acceptable reliability. This manual seeks to provide the most effective EETs for the NPI substances relevant to combustion in boilers. However, the absence of an EET for a substance in this manual does not imply that an emission should not be reported to the NPI. The obligation to report on all relevant emissions remains wherever reporting thresholds have been exceeded. The obligation to report exists even if, because there is no emission factor, the mass of that emission cannot be calculated and the emission is reported as ‘no data’. If a blank or ‘no data’ emission is included in a report for an NPI substance where usage has tripped the reporting threshold, a reason should be stated. A statement such as ‘no emission factor is available’ is appropriate. You should note that the EETs presented in this manual relate principally to average process emissions. Emissions resulting from non-routine events are rarely discussed in the literature, and there is a general lack of EETs for such events. However, it is


important to recognise that emissions resulting from significant operating excursions and/or accidental situations (e.g. spills) will also need to be estimated. Emissions to land, air and water from spills must be estimated and added to process emissions when calculating total emissions for reporting purposes. The emission resulting from a spill is the net emission (the quantity of the NPI reportable substance spilled, less the quantity recovered or consumed immediately (within 24 hours) during clean up operations).

5.1 Emission factors As discussed previously, the emission factor method is a commonly used tool in industry to estimate emissions to the environment. In this manual, it relates to the quantity of substances emitted from a source to some common activity associated with those emissions. Emission factors are usually expressed as the weight of a substance emitted. To calculate the emission, multiply the substance specific emission by the activity. You should be aware that there is uncertainty associated with emission factors relating to the degree of difference between the equipment/process from which the factor was derived and the equipment/process to which the factor is being applied. An A or B rating indicates a greater degree of certainty than a D or E rating. The EFR system is: A Excellent B Above average C Average D Below average E Poor U Unrated Emission factors applicable to this manual are listed in Appendix B, Table 5. You must ensure that you estimate emissions for all substances for which a threshold has been exceeded. You should also be aware that you can download an emissions calculation tool for Combustion in boilers from the NPI web site http://www.npi.gov.au. This tool can be used in conjunction with the NPI Online Reporting System to upload your substance emissions. Emission factors developed from measurements for a specific process may sometimes be used to estimate emissions at other sites. For example, a company may have several units of similar model and size, if emissions were measured from one facility, an emission factor could be developed and applied to similar sources. If you wish to use a site-specific emission factor, you should first seek approval from your state or territory environment agency before its use for estimating NPI emissions.

5.2 Direct measurement As indicated above, you may wish to use direct measurement in order to report to the NPI, particularly if you already do so in order to meet other regulatory requirements.


http://www.npi.gov.au/

For sampling data to be adequate and able to be used for NPI reporting purposes, it would need to be collected over a period of time and be representative of operations for the whole year.

5.2.1 Sampling data Stack sampling test reports often provide emissions data in terms of kg per hour or grams per cubic metre (dry). Annual emissions for NPI reporting can be calculated from this data. Stack tests for NPI reporting should be performed under representative (i.e. normal) operating conditions. You should be aware that some tests undertaken for a state or territory license condition may require the test be taken under maximum emissions rating, where emissions are likely to be higher than when operating under normal operating conditions. This section shows how to calculate emissions in kg per hour based on stack sampling data, and how to convert this to an annual emissions figure. Calculations involved in determining particulate (PM) emissions are used as an example, although the same calculations are applicable for most of the substances listed on the NPI. Equation 1 indicates how to calculate the concentration of a substance from the weight of the substance and the volume of air sampled: Equation 1

CPM = Cf / Vm, STP where: CPM = concentration of PM or gram loading, g/m3 Cf = filter catch, g Vm,STP = metered volume of sample at STP, m3

Equation 2 can be used to convert the concentration of a substance calculated in Equation 1 to an hourly emission of the substance: Equation 2

EPM = CPM * Qd * 3.6 * [273 / (273 + T)]

where: EPM = hourly emissions of PM, kg/hr CPM = concentration of PM or gram loading, g/m3 Qd = stack gas volumetric flow rate, m3/s, dry 3.6 = 3600 seconds per hour multiplied by 0.001 kilograms per gram T = temperature of the gas sample, °C


The information from some stack tests may be reported in grams of particulate per cubic metre of exhaust gas (wet). Use Equation 4 to calculate the particulate emissions in kg/hr. Equation 3 EPM = Qw * CPM * 3.6 * (1 -– moistR/100) * [273 / (273 + T)] where: EPM = hourly emissions of PM in kilograms per hour, kg/hr Qw = wet cubic metres of exhaust gas per second, m3/s CPM = concentration of PM or gram loading, g/m3 3.6 = 3600 seconds per hour multiplied by 0.001 kilograms per gram moistR = moisture content, % 273 = 273 K (0°C) T = stack gas temperature, °C Total suspended particulates (TSP) are also referred to as total particulate matter (total PM). To determine PM10 from total PM emissions, a size analysis may need to be undertaken. The weight PM10 fraction can then be multiplied by the total PM emission rate to produce PM10 emissions. Alternatively, assume that 100% of PM emissions are PM10; i.e. assume that all particulate matter emitted to air has an equivalent aerodynamic diameter of 10 micrometres or less i.e. ≤10μm. To calculate moisture content use Equation 4: Equation 4 Moisture percentage = 100 % * weight of water vapour per specific

volume of stack gas/ total weight of the stack gas in that volume

( )

( ) ρ STPSTPm

moist

STPm

moist

R

Vg

Vg

moist+

=

,

,

*1000

*1000*%100

where

moistR = moisture content, % gmoist = moisture collected, g Vm, STP = metered volume of sample at STP, m3 ρSTP = dry density of stack gas sample, kg/m3 at STP

{if the density is not known a default value of 1.62 kg/m3 may be used. This assumes a dry gas composition of 50% air, 50% CO2}

An example of test results is summarised in Table 2. The table shows the results of three different sampling runs conducted during one test event. The source parameters measured as part of the test run include gas velocity and moisture content, which are


used to determine exhaust gas flow rates in m3/s. The filter weight gain is determined gravimetrically and divided by the volume of gas sampled, as shown in Equation 1 to determine the PM concentration in grams per m3. Note that this example does not present the condensable PM emissions. Table 2: Stack sample test results

Parameter Symbol Test 1 Test 2 Test 3 Total sampling time (sec) 7 200 7 200 7 200 Moisture collected (g) gMOIST 395.6 372.6 341.4 Filter catch (g) Cf 0.0851 0.0449 0.0625 Average sampling rate (m3/s) 1.67 * 10-4 1.67 * 10-4 1.67 * 10-4 Standard metered volume (m3) Vm, STP 1.185 1.160 1.163 Volumetric flow rate (m3/s), dry Qd 8.48 8.43 8.45 Concentration of particulate (g/m3) CPM 0.0718 0.0387 0.0537

Source: Queensland Department of Environment and Heritage 1998 Example 2: Using stack sampling data PM emissions have been calculated using Equation 1 and Equation 2, and the stack sampling data for Test 1 (presented in Table 2, and an exhaust gas temperature at 25°C {298 K}). This is shown below: CPM = Cf / Vm, STP = 0.0851 / 1.185 = 0.072 g/m3

EPM = CPM * Qd * 3.6 * [273 / (273 + T)] = 0.072 * 8.48 * 3.6 * [273/423K] = 1.42 kg/hr

5.2.2 Continuous Emission Monitoring System (CEMS) data A continuous emission monitoring system provides a continuous record of emissions over time, usually by reporting pollutant concentration. Once the pollutant concentration is known, emission rates are obtained by multiplying the pollutant concentration by the volumetric gas or liquid flow rate of that pollutant. It is important to note that prior to using CEMS to estimate emissions, you should develop a protocol for collecting and averaging the data in order that the estimate satisfies your relevant environmental authority’s requirement for NPI emissions estimations.


Table 3: Example CEM output averaged for a boiler firing waste fuel oil

Time

O2

Concentration (C)(C) (ppmvd)

Gas flow

Combustion rate (A)

(% by volume)

SO2

NOx

CO

VOC

Rate (Q)

(tonnes /hour)

1 10.3 150.9 142.9 42.9 554.2 8.52 290 2 10.1 144.0 145.7 41.8 582.9 8.48 293 3 11.8 123.0 112.7 128.4 515.1 8.85 270

Source: Queensland Department of Environment and Heritage, 1998. *ppmvd = parts per million volume dry Hourly emissions can be based on concentration measurements as shown in Equation 5. Equation 5 Ei = (C * MW * Q * 3 600) / [22.4 * {(T + 273)/273} * 106] where: Ei = emissions of pollutant i, kg/hr C = pollutant concentration, ppmv,d MW = molecular weight of the pollutant, kg/kg-mole Q = stack gas volumetric flow rate, m3/s 3 600 = conversion factor, s/hr 22.4 = volume occupied by one mole of gas at standard

temperature and pressure (0°C and 101.3 kPa), m3/kg-mole T = temperature of gas sample, °C

Actual annual emissions can be calculated by multiplying the emission rate in kg/hr by the number of actual operating hours per year (OpHrs) as shown in Equation 6 for each typical time period and summing the results. Equation 6 Ekpy,i = ∑ (Ei * OpHrs) where: Ekpy,i = annual emissions of pollutant i, kg/yr Ei = emissions of pollutant i, kg/hr (from Equation 5) OpHrs= operating hours, hr/yr Emissions in kilograms of pollutant per tonne of oil consumed can be calculated by dividing the emission rate in kg per hour, by the oil consumption rate (tonnes per hour) during the same period (Equation 7) as shown below. It should be noted that the emission factor calculated below assumes that the selected time period (i.e. hourly) is representative of annual operating conditions and longer time periods should be used


for NPI reporting where they are available. Use of the calculation is shown in Example 2. Equation 7 Ekpt,i = Ei / A where: Ekpt,i = emissions of pollutant i per tonne of oil consumed, kg/t Ei = hourly emissions of pollutant i, kg/hr A = oil consumption rate, t/hr Example 3 illustrates the application of Equation 5, Equation 6 and Equation 7. Example 3: Using CEMS Data This example shows how SO2 emissions can be calculated using Equation 5 based on the CEMS data for Time Period 1 shown in Table 3, and an exhaust gas temperature of 150°C (423 K). ESO2,1 = (C * MW * Q * 3 600) / [(22.4 * (T+273/273) * 106] = (150.9 * 64 * 8.52 * 3 600) / [22.4 * (423/273) * 106] = 296 217 907 / 34 707 692 = 8.53 kg/hr

For Time Period 2, also at 150°C ESO2,2 = 8.11 kg/hr

For Time Period 3, also at 150°C ESO2,3 = 7.23 kg/hr Say representative operating conditions for the year are: Period 1 = 1500 hr Period 2 = 2000 hr Period 3 = 1800 hr Total emissions for the year are calculated by adding the results of the three Time Periods using Equation 6: Ekpy,SO2 = ESO2,1 * OpHrs + ESO2,2 * OpHrs + ESO2,3 * OpHrs

= (8.53 * 1500) + (8.11 * 2000) + (7.23 * 1800) kg = 42021 kg/yr Emissions, in terms of kg/tonne of oil consumed when operating in the same mode as Time Period 1, can be calculated using Equation 7: Ekpt,SO2 = ESO2 / A = 8.53 / 290 = 2.94 * 10-2 kg SO2 emitted per tonne of oil consumed


When the boiler is operating as in Time Periods 2 or 3, similar calculations can be undertaken for emissions per tonne.

5.3 Engineering calculations An engineering calculation is an estimation method based on physical/chemical properties (egg. vapour pressure) of the substance, and mathematical relationships (e.g. ideal gas law).

5.3.1 Fuel analysis Fuel analysis is a particular type of engineering calculation and can be used to predict SO2, metals, and other emissions based on application of conservation laws, if fuel rate is measured. The presence of certain elements in fuels may be used to predict their presence in emission streams. This includes elements such as sulfur that may be converted into other compounds during the combustion process. The basic equation used in fuel analysis emission calculations is the following: Equation 8

Ekpy,i = Qf * pollutant concentration in fuel/100 * (MWp/EWf) * OpHrs where:

Ekpy,i = annual emissions of pollutant i, kg/yr Qf = fuel use, kg/hr OpHrs= operating hours, hr/yr MWp = molecular weight of pollutant emitted, kg/kg-mole EWf = elemental weight of pollutant in fuel, kg/kg-mole

Concentration of pollutant i in fuel expressed as weight percent, % For instance, SO2 emissions from fuel oil combustion can be calculated based on the concentration of sulfur in the fuel oil. This approach assumes complete conversion of sulfur to SO2. Therefore, for every kilogram of sulfur (EW = 32) burned, two kilograms of SO2 (MW = 64) are emitted. The application of this EET is shown in Example 4.


Example 4: Calculating sulfur dioxide emissions using fuel analysis This example illustrates how SO2 emissions can be calculated from oil combustion based on fuel analysis results and the fuel flow information from a boiler. The boiler is assumed to operate 1500 hours per year. Fuel flow = 2000 kg/hr Weight percent sulfur in fuel = 1.17 Ekpy,SO2 = Qf * pollutant concentration in fuel/100 * (MWp / EWf) = (2000) * (1.17 / 100) * (64 / 32) = (46.8 kg/hr * 1500 hr/yr) = 70 200 kg/yr

5.4 Approved alternative technique You are able to use EETs that are not outlined in this document. You must, however, seek the consent of your state or territory environmental agency. For example, if your company has developed site-specific emission factors as a result of monitoring and testing, you may use these if they have been approved by your local environmental agency.

5.5 Calculating emissions The general equation below uses emission factors to estimate a facility’s emissions. Equation 9

E(s) = A × EF(s) × CE E is the annual emission level for a NPI substance (s) – e.g. Carbon

monoxide in kg/yr A is the activity rate over a year (e.g. operating hours or tonnage

used) EF(s) is the uncontrolled emission factor for the substance as set out in

this manual at Appendix B. CE is the control efficiency of the emission (%) and reflects the

impact of any devices or processes that control the level of emissions

5.5.1 Emission factors for boiler fuel Emission factors for NPI substances that are known to be components of boiler fuel are calculated in terms of kilograms of substances per tonne of fuel. These are set out for most NPI substances at Appendix B. Appendix B, Table 29 sets out control


efficiencies (CEs) for a number of techniques and the devices that can be used to determine emission levels. An example to demonstrate how emission factors and CEs can be used to determine emissions is set out below. Example 5: Reporting on NPI emissions at a facility using steam for its operations The facility has three ‘stoker spreader’ boilers and uses 2500 tonnes of black coal in total per year. The facility uses baghouses in order to reduce emissions of particulate matter. A. Determine whether / what NPI substances are used at the facility and whether they trip NPI thresholds. As set out in Table 1, boiler fuels emit a number of NPI Category 2a and 2b substances when combusted. Section 4.1 indicates that any facility that burns 400 and/or 2 000 tonnes of black coal fuel at the site will exceed the Category 2a and 2b thresholds respectively. In this example, the facility has exceeded both the Category 2a and 2b thresholds and should report emissions for all substances listed in Table 1. B. Determine the level of emissions. In this example, the use of emission factors is suggested for estimating emissions of required substances. As the mass of fuel burnt triggers the Category 2a and 2b thresholds, all Category 2a and 2b should be reported. Appendix B, Table 10-13 provides emission factors in terms of kilograms per tonne for a range of substances. These include: Arsenic and compounds 2.05E-04 Beryllium and compounds 1.05E-05 Cadmium and compounds 2.55E-05 Carbon monoxide 2.50E+00 Chromium (III) compounds 1.30E-04 Chromium (VI) compounds 3.95E-05 Copper and compounds 4.92E-04 Fluoride and compounds 7.50E-02 Hydrochloric acid 6.00E-01 Lead and compounds 2.10E-04 Mercury and compounds 4.15E-05 Nickel and compounds 1.40E-04 Oxides of Nitrogen 4.40E+00 PAH 9.49E-06 PM10 4.00E-02 PM 2.5

4.00E-02 Polychlorinated dioxins and furans 9.12E-10 Sulfur dioxide 5.70E-01 TVOCs 3.00E-02


Section 5.5 indicates that the emission calculation is E(s) = A × EF(s) × CE Example: Oxides of Nitrogen E(s): Emissions (substance) at the facility in a year A: Activity rate (of 2 500 tonnes of black coal burnt) in a year EF: Emission factor CE: Control efficiency factor In this example, the control efficiency has been built into the emission factor, and therefore is not separately considered in the calculation. Arsenic and compounds: EF=2.05E-04 E(Arsenic and compounds) = A × EF(Arsenic and compounds) E(Arsenic and compounds) = 2500 × 2.05E-04(Arsenic and compounds) E(Arsenic and compounds) = 0.5125 kg/yr Beryllium and compounds: 1.05E-05 E(Beryllium and compounds) = A × EF(Beryllium and compounds) E(Beryllium and compounds) = 2500 × 1.05E-05(Beryllium and compounds) E(Beryllium and compounds) = 0.02625 kg/yr Cadmium and compounds: 2.55E-05 E(Cadmium and compounds) = A × EF(Cadmium and compounds) E(Cadmium and compounds) = 2500 × 2.55E-05(Cadmium and compounds) E(Cadmium and compounds) = 0.06375 kg/yr Carbon monoxide: 2.50E+00 E(Carbon monoxide) = A × EF(Carbon monoxide) E(Carbon monoxide) = 2500 × 2.50E+00(Carbon monoxide) E(Carbon monoxide) = 6250 kg/yr Chromium(III) compounds: 0.00013 E(Chromium III) = A × EF(Chromium III) E(Chromium III) = 2500 × 0.00013(Chromium III) E(Chromium III) = 0.325 kg/yr Chromium(VI) compounds: 3.95E-05 E(Chromium (VI)) = A × EF(Chromium(VI)) E(Chromium (VI)) = 2500 × 3.95E-05(Chromium(VI)) E(Chromium(V)I) = 0.09875 kg/yr Copper and compounds: 4.92E-04 E(Copper and compounds) = A × EF(Copper and compounds) E(Copper and compounds) = 2500 × 4.92E-04(Copper and compounds) E(Copper and compounds) = 1.23 kg/yr Fluoride and compounds: 7.50E-02


E(Fluoride and compounds) = A × EF(Fluoride and compounds) E(Fluoride and compounds) = 2500 × 7.50E-02(Fluoride and compounds) E(Fluoride and compounds) = 187.5 kg/yr Hydrochloric acid: 6.00E-01 E(Hydrochloric acid) = A × EF(Hydrochloric acid) E(Hydrochloric acid) = 2500 × 6.00E-01(Hydrochloric acid) E(Hydrochloric acid) = 1500 kg/yr Lead and compounds: 2.10E-04 E(Lead and compounds) = A × EF(Lead and compounds) E(Lead and compounds) = 2500 × 2.10E-04(Lead and compounds) E(Lead and compounds) = 0.525 kg/yr Mercury and compounds: 4.15E-05 E(Mercury and compounds) = A × EF(Mercury and compounds) E(Mercury and compounds) = 2500 × 4.15E-05(Mercury and compounds) E(Mercury and compounds) = 0.10375 kg/yr Nickel and compounds: 1.40E-04 E(Nickel and compounds) = A × EF(Nickel and compounds) E(Nickel and compounds) = 2500 × 1.40E-04(Nickel and compounds) E(Nickel and compounds) = 0.35 kg/yr Oxides of Nitrogen: 4.40E+00 E(Oxides of Nitrogen) = A × EF(Oxides of Nitrogen) E(Oxides of Nitrogen) = 2500 × 4.40E+00(Oxides of Nitrogen) E(Oxides of Nitrogen) = 11 000 kg/yr PAH: 9.49E-06 E(PAH) = A × EF(PAH) E(PAH) = 2500 × 9.49E-06(PAH) E(PAH) = 2.37E-02 kg/yr PM10: 4.00E-02 E(PM10) = A × EF(PM10) E(PM10) = 2500 × 4.00E-02(PM10) E(PM10) = 100 kg/yr PM2.5: 4.00E-02 E(PM2.5) = A × EF(PM2.5) E(PM2.5) = 2500 × 4.00E-02(PM2.5) E(PM2.5) = 100 kg/yr Polychlorinated dioxins and furans: 9.12E-10 E(Polychlorinated dioxins and furans) = A × EF(Polychlorinated dioxins and furans) E(Polychlorinated dioxins and furans) = 2500 × 9.12E-10(Polychlorinated dioxins and furans) E(Polychlorinated dioxins and furans) = 2.28E-06 kg/yr


Sulfur dioxide: 5.70E-01 E(Sulfur dioxide) = A × EF(Sulfur dioxide) E(Sulfur dioxide) = 2500 × 5.70E-01(Sulfur dioxide) E(Sulfur dioxide) = 1 425 kg/yr Total VOC: 3.00E-02 E(Total VOC) = A × EF(Total VOC) E(Total VOC) = 2500 × 3.00E-02(Total VOC) E(Total VOC ) = 75 kg/yr C. What needs to be reported? Threshold data: 2 500 tonnes of black coal Emissions data: Arsenic and compounds = 0.5125 kg/yr Beryllium and compounds = 0.02625 kg/yr Cadmium and compounds = 0.06375 kg/yr Carbon monoxide = 6250 kg/yr Chromium(III) compounds = 0.325 kg/yr Chromium(VI) compounds = 0.09875 kg/yr Copper and compounds = 1.23 kg/yr Fluoride and compounds = 187.5 kg/yr Hydrochloric acid = 1500 kg/yr Lead and compounds = 0.525 kg/yr Mercury and compounds = 0.10375 kg/yr Nickel and compounds = 0.35 kg/yr Oxides of Nitrogen = 11 000 kg/yr PAH = 2.37E-02 kg/yr PM10 = 100 kg/yr PM2.5 = 100 kg/yr Polychlorinated dioxins and furans = 2.28E-06 kg/yr Sulfur dioxide = 1 425 kg/yr Total VOC = 75 kg/yr Pollution Control Equipment Baghouse (including the year installed as well as other supporting information)


6 Transfers of NPI substances in waste The NPI requires the mandatory reporting of NPI substances that are transferred as waste to a final destination. Transfers are required to be reported if a Category 1, Category 1b or Category 3 reporting threshold is exceeded. Refer to the NPI Guide for further details on the various categories and the relevant thresholds. There is no requirement to report transfers of substances that are exclusively Category 2a or 2b in the event that they have been tripped only by the fuel and energy use threshold (i.e. there is no requirement to report transfers of oxides of nitrogen, particulate matter ≤10 μm, particulate matter ≤ 2.5 μm, polychlorinated dioxins and furans, or polycyclic aromatic hydrocarbons). Transfers are reportable in kilograms. In the specific context of combustion in boilers, the quantities of NPI substances contained in waste moved onsite or offsite to landfill or other final destinations will need to be reported as they are considered to be mandatory transfers. As stated previously, the transfer of waste need only be reported if it contains an NPI substance that your facility has triggered in Categories 1, 1b or 3. For example, the waste from combustion in boilers include ‘bottom waste’ from the combustion process as well as sludge and waste from desulfurisation and other boiler cleaning. These wastes are likely to contain unburnt substances similar to the emissions from combustion, and pollutants from the cleaning process. The transfer of NPI substances to a destination for reuse, recycling, reprocessing, purification, partial purification, immobilisation, remediation or energy recovery can be reported voluntarily. This is an opportune way for facilities to promote good news stories to their local community. Further information regarding transfers of waste can be located in the NPI Guide.


7 Next steps for reporting This manual has been written to reflect the common processes employed by facilities using fuel for steam energy and hot water in boilers. To ensure a complete report of the emissions for your facility, it may be necessary to refer to other EET manuals. These include:

• Combustion in engines; • Fuel and organic liquid storage; and • Fugitive emissions.

When you have a complete report of substance emissions from your facility, report these emissions according to the instructions in the NPI Guide.


8 References Australian Bureau of Statistics and Statistics New Zealand, ANZSIC: Australia and New Zealand Standard Industrial Classification, ABS Catalogue 1292.0. Department of Environment and Heritage (now Department of Environment, Water, Heritage and the Arts), Emission Estimation Technique Manual for Combustion in Boilers, Draft Version 2.0, December 2003, Eastern Research Group (US), Preferred Alternative Methods for Estimating Air Emissions from Boilers, January 2001, Paper prepared for the USEPA. HRL Technologies Pty Ltd, NPI Development of Emission Factors for Combustion in Boilers, Report # : HLC/2007/075, August 2007 and references contained therein. United States Environment Protection Agency, Compilation of Air Pollutants and Emission Factors, Stationary Point and Area Sources, Volume 1, fifth edition, USEPA, AP-42, January 1995, Chapters 1 and 13 United States Environment Protection Agency, Technical Background Document for the Report to Congress on Remaining Wastes from Fossil Fuel Combustion: Waste Characterization, March 15, 1999, http://www.epa.gov/epaoswer/other/fossil/ffc2_399.pdf


Appendix A: Definitions and abbreviations AP- 42 USEPA Compilations of Air Pollution Emission Factors BOOS Burning out of service EET Emission estimation technique EF Emission factor EFR Emission factor rating ESP Electrostatic precipitator FBC Fluidised bed combustion FGD Flu gas desulfurisation FGR Flue gas recirculation LEA Low excess air LNB Low NOx burner LPG Liquid petroleum gas PAH Polycyclic aromatic hydrocarbons NG Natural gas NPI National Pollutant Inventory PC Pulverised coal PF Pulverised fuel RAP Reduces air preheat SCR Selective catalytic reduction SDA Spray dryer absorbers SNCR Selective non-catalytic reduction TVOC Total Volatile Organic Compounds U/C Uncontrolled (i.e. no pollution control device used) Desulfurisation The removal of sulfur compounds from petroleum fractions

using hydrogen in the presence of a catalyst.


Appendix B: Tables Table 4: Conversion factors for common boiler fuel types Fuel type Energy to weight/volume Weight to volume (t) Bagasse 18 - 21 MJ/tonne 70 - 200 kg/m3 (1) Brown coal briquettes 22.1 GJ/tonne 0.75 tonnes/m3 Tallow 35 GJ/tonne ND Black coal 15.2 - 23.4 GJ/t (2) Normally measured in

tonnes Residual oil 42.9 MJ/kg 0.97 kg/l Distillate oil 45.6 MJ/kg 0.83 kg/l Light fuel oil 45.5MJ/kg 0.86 kg/l Natural gas 39.7 MJ/m3 0.74 kg/m3 LPG – butane 28.1 MJ/l 0.580 kg/l LPG - propane 25.5 MJ/l 0.510 kg/l Process gas - coke oven 18.1 MJ/m3 0.546 kg/l Process gas - blast furnace 4 MJ/m3 1.25 kg/l Wood fuel products 16.2 GJ/tonne Normally measured in

tonnes Notes: (1) Bagasse 120 – 200 kg/m3, Sugar cane trash 70 – 150 kg/l (2) NSW Coal 23.4 GJ/tonne, Qld 23.4, WA 19.7, Tas 22.8, SA 15.2. Source: HRL Technology Pty Ltd, NPI – Development of Emission Factors for Combustion in Boilers, a report prepared for the Department of Environment, Water, Heritage and the Arts.


The following tables provide emission factors for various fuel, process and control configurations, for certain NPI listed substances. Not all NPI substances are listed, as emission factors have not been developed for all possible combinations of process, fuel and pollution control devices used at Australian facilities. In the event you have a requirement to report on an unlisted NPI substance, you should attempt to estimate the emission using one of the other accepted EET’s. If you have any questions or are in doubt over the approach to take, please contact the NPI office in your state or territory Table 5: Emission factors for bagasse (kg/t) Emission factors for bagasse (kg/t) Control Substance Emission factor Dry scrubber Carbon monoxide 2.61E+00Dry scrubber Oxides of nitrogen 7.60E-01Dry scrubber Particulate Matter 10.0 um 7.50E-01Dry scrubber Sulfur dioxide 2.50E-01U/C Carbon monoxide 2.61E+00U/C Oxides of nitrogen 7.60E-01U/C Particulate Matter 10.0 um 6.15E+00U/C Particulate Matter 2.5 um 3.51E+00U/C Sulfur dioxide 2.50E-01Wet scrubber Carbon monoxide 2.61E+00Wet scrubber Oxides of nitrogen 7.60E-01Wet scrubber Particulate Matter 10.0 um 2.20E-01Wet scrubber Sulfur dioxide 2.50E-01

Source: Table 32, HRL Technology Pty Ltd, NPI – Development of Emission Factors for Combustion in Boilers, a report prepared for the Department of Environment, Water, Heritage and the Arts. Table 6: Emission factors for brown coal briquettes (kg/t) Brown coal briquettes (kg/t) Control Substance Emission factorBaghouse Carbon monoxide 4.79E+00Baghouse Oxides of nitrogen 2.68E+00Baghouse Particulate Matter 10.0 um 3.10E-01Baghouse Particulate Matter 2.5 um 3.00E-02Baghouse Sulfur dioxide 4.79E+00U/C Carbon monoxide 4.79E+00U/C Oxides of nitrogen 2.68E+00U/C Particulate Matter 10.0 um 7.80E-01U/C Particulate Matter 2.5 um 7.00E-02U/C Sulfur dioxide 4.79E+00

Source: Table 33, HRL Technology Pty Ltd, NPI – Development of Emission Factors for Combustion in Boilers, a report prepared for the Department of Environment, Water, Heritage and the Arts.


Table 7: Emission factors for black coal – cyclone furnace (kg/t) Emission factors for black coal – cyclone furnace (kg/t) Process Control Substance Emission

factor Bituminous U/C Arsenic & compounds 2.05E-04Bituminous U/C Beryllium & compounds 1.05E-05Bituminous U/C Cadmium & compounds 2.55E-05Bituminous U/C Carbon monoxide 2.50E-01Bituminous U/C Chromium (III) compounds 1.30E-04Bituminous U/C Chromium (VI) compounds 3.95E-05Bituminous U/C Copper & compounds 4.92E-04Bituminous U/C Fluoride compounds 7.50E-02Bituminous U/C Hydrochloric acid 6.00E-01Bituminous U/C Lead & compounds 2.10E-04Bituminous U/C Mercury & compounds 4.15E-05Bituminous U/C Nickel & compounds 1.40E-04Bituminous U/C Oxides of nitrogen 1.65E+01Bituminous U/C Particulate Matter 10.0 um 1.30E-01Bituminous U/C Particulate Matter 2.5 um 5.50E-02Bituminous U/C Polychlorinated dioxins and

furans 9.12E-10

Bituminous U/C Polycyclic aromatic hydrocarbons

9.49E-06

Bituminous U/C Sulfur dioxide 5.70E-01Bituminous U/C Total volatile organic

compounds 6.00E-02

Cyclone furnace ESP Arsenic & compounds 2.05E-04Cyclone furnace ESP Beryllium & compounds 1.05E-05Cyclone furnace ESP Cadmium & compounds 2.55E-05Cyclone furnace ESP Carbon monoxide 2.50E-01Cyclone furnace ESP Chromium (III) compounds 1.30E-04Cyclone furnace ESP Chromium (VI) compounds 3.95E-05Cyclone furnace ESP Copper & compounds 4.92E-04Cyclone furnace ESP Fluoride compounds 7.50E-02Cyclone furnace ESP Hydrochloric acid 6.00E-01Cyclone furnace ESP Lead & compounds 2.10E-04Cyclone furnace ESP Mercury & compounds 4.15E-05Cyclone furnace ESP Nickel & compounds 1.40E-04Cyclone furnace ESP Oxides of nitrogen 1.65E+01Cyclone furnace ESP Particulate Matter 10.0 um 5.50E-02Cyclone furnace ESP Particulate Matter 2.5 um 3.00E-03Cyclone furnace ESP Polychlorinated dioxins and

furans 9.12E-10

Cyclone furnace ESP Polycyclic aromatic hydrocarbons

9.49E-06

Cyclone furnace ESP Sulfur dioxide 5.70E-01



Emission factors for black coal – cyclone furnace (kg/t) Process Control Substance Emission

factor Cyclone furnace ESP Total volatile organic

compounds 6.00E-02

Cyclone furnace Multiclones Arsenic & compounds 2.05E-04Cyclone furnace Multiclones Beryllium & compounds 1.05E-05Cyclone furnace Multiclones Cadmium & compounds 2.55E-05Cyclone furnace Multiclones Carbon monoxide 2.50E-01Cyclone furnace Multiclones Chromium (III) compounds 1.30E-04Cyclone furnace Multiclones Chromium (VI) compounds 3.95E-05Cyclone furnace Multiclones Copper & compounds 4.92E-04Cyclone furnace Multiclones Fluoride compounds 7.50E-02Cyclone furnace Multiclones Hydrochloric acid 6.00E-01Cyclone furnace Multiclones Lead & compounds 2.10E-04Cyclone furnace Multiclones Mercury & compounds 4.15E-05Cyclone furnace Multiclones Nickel & compounds 1.40E-04Cyclone furnace Multiclones Oxides of nitrogen 1.65E+01Cyclone furnace Multiclones Particulate Matter 10.0 um 5.60E-02Cyclone furnace Multiclones Particulate Matter 2.5 um 5.50E-02Cyclone furnace Multiclones Polychlorinated dioxins and

furans 9.12E-10

Cyclone furnace Multiclones Polycyclic aromatic hydrocarbons

9.49E-06

Cyclone furnace Multiclones Sulfur dioxide 5.70E-01Cyclone furnace Multiclones Total volatile organic

compounds 6.00E-02

Cyclone furnace U/C Arsenic & compounds 2.05E-04Cyclone furnace U/C Beryllium & compounds 1.05E-05Cyclone furnace U/C Cadmium & compounds 2.55E-05Cyclone furnace U/C Carbon monoxide 2.50E-01Cyclone furnace U/C Chromium (III) compounds 1.30E-04Cyclone furnace U/C Chromium (VI) compounds 3.95E-05Cyclone furnace U/C Copper & compounds 4.92E-04Cyclone furnace U/C Fluoride compounds 7.50E-02Cyclone furnace U/C Hydrochloric acid 6.00E-01Cyclone furnace U/C Lead & compounds 2.10E-04Cyclone furnace U/C Mercury & compounds 4.15E-05Cyclone furnace U/C Nickel & compounds 1.40E-04Cyclone furnace U/C Oxides of nitrogen 1.65E+01Cyclone furnace U/C Particulate Matter 10.0 um 1.30E-01Cyclone furnace U/C Particulate Matter 2.5 um 5.50E-02Cyclone furnace U/C Polychlorinated dioxins and

furans 9.12E-10

Cyclone furnace U/C Polycyclic aromatic hydrocarbons

9.49E-06

Cyclone furnace U/C Sulfur dioxide 5.70E-01


Emission factors for black coal – cyclone furnace (kg/t) Process Control Substance Emission

factor Cyclone furnace U/C Total volatile organic

compounds 6.00E-02

Sub-bituminous U/C Arsenic & compounds 2.05E-04Sub-bituminous U/C Beryllium & compounds 1.05E-05Sub-bituminous U/C Cadmium & compounds 2.55E-05Sub-bituminous U/C Carbon monoxide 2.50E-01Sub-bituminous U/C Chromium (III) compounds 1.30E-04Sub-bituminous U/C Chromium (VI) compounds 3.95E-05Sub-bituminous U/C Copper & compounds 4.92E-04Sub-bituminous U/C Fluoride compounds 7.50E-02Sub-bituminous U/C Hydrochloric acid 6.00E-01Sub-bituminous U/C Lead & compounds 2.10E-04Sub-bituminous U/C Mercury & compounds 4.15E-05Sub-bituminous U/C Nickel & compounds 1.40E-04Sub-bituminous U/C Oxides of nitrogen 8.50E+00Sub-bituminous U/C Particulate Matter 10.0 um 1.30E-01Sub-bituminous U/C Particulate Matter 2.5 um 5.50E-02Sub-bituminous U/C Polychlorinated dioxins and

furans 9.12E-10

Sub-bituminous U/C Polycyclic aromatic hydrocarbons

9.49E-06

Sub-bituminous U/C Sulfur dioxide 5.25E-01Sub-bituminous U/C Total volatile organic

compounds 6.00E-02

Source: Table 35-41, HRL Technology Pty Ltd, NPI – Development of Emission Factors for Combustion in Boilers, a report prepared for the Department of Environment, Water, Heritage and the Arts. Table 8: Emission factors for black coal – fluidised bed combustion, bubbling bed, uncontrolled (kg/t) Emission factors for black coal – fluidised bed combustion, bubbling bed, uncontrolled (kg/t) Substance Emission factor Arsenic & compounds 2.05E-04Beryllium & compounds 1.05E-05Cadmium & compounds 2.55E-05Carbon monoxide 9.00E+00Chromium (III) compounds 1.30E-04Chromium (VI) compounds 3.95E-05Copper & compounds 4.92E-04Fluoride compounds 7.50E-02Hydrochloric acid 6.00E-01Lead & compounds 2.10E-04


Emission factors for black coal – fluidised bed combustion, bubbling bed, uncontrolled (kg/t) Substance Emission factor Mercury & compounds 4.15E-05Nickel & compounds 1.40E-04Oxides of nitrogen 7.60E+00Polycyclic aromatic hydrocarbons 9.49E-06Particulate Matter 10.0 um 6.45E+00Polychlorinated dioxins and furans 9.12E-10Sulfur dioxide 5.94E-01Total volatile organic compounds 2.50E-02

Source: Table 35-41, HRL Technology Pty Ltd, NPI – Development of Emission Factors for Combustion in Boilers, a report prepared for the Department of Environment, Water, Heritage and the Arts. Table 9: Emission factors for black coal – fluidised bed combustion, circulating bed, uncontrolled (kg/t) Emission factors for black coal – fluidised bed combustion, circulating bed, uncontrolled (kg/t) Substance Emission factor Arsenic & compounds 2.05E-04Beryllium & compounds 1.05E-05Cadmium & compounds 2.55E-05Carbon monoxide 9.00E+00Chromium (III) compounds 1.30E-04Chromium (VI) compounds 3.95E-05Copper & compounds 4.92E-04Fluoride compounds 7.50E-02Hydrochloric acid 6.00E-01Lead & compounds 2.10E-04Mercury & compounds 4.15E-05Nickel & compounds 1.40E-04Oxides of nitrogen 2.50E+00Polycyclic aromatic hydrocarbons 9.49E-06Particulate Matter 10.0 um 6.45E+00Polychlorinated dioxins and furans 9.12E-10Sulfur dioxide 5.94E-01Total volatile organic compounds 2.50E-02

Source: Table 35-41, HRL Technology Pty Ltd, NPI – Development of Emission Factors for Combustion in Boilers, a report prepared for the Department of Environment, Water, Heritage and the Arts.

Table 10: Emission factors for black coal – overfeed/crossfeed stoker (kg/t) Emission factors for black coal – overfeed/crossfeed stoker (kg/t) Control Substance Emission

factor Multiclones Arsenic & compounds 2.05E-04Multiclones Beryllium & compounds 1.05E-05Multiclones Cadmium & compounds 2.55E-05Multiclones Carbon monoxide 3.00E+00Multiclones Chromium (III) compounds 1.30E-04Multiclones Chromium (VI) compounds 3.95E-05Multiclones Copper & compounds 4.92E-04Multiclones Fluoride compounds 7.50E-02Multiclones Hydrochloric acid 6.00E-01Multiclones Lead & compounds 2.10E-04Multiclones Mercury & compounds 4.15E-05Multiclones Nickel & compounds 1.40E-04Multiclones Oxides of nitrogen 3.80E+00Multiclones Particulate Matter 10.0 um 2.90E+00Multiclones Particulate Matter 2.5 um 1.10E+00Multiclones Polychlorinated dioxins and furans 9.12E-10Multiclones Polycyclic aromatic hydrocarbons 9.49E-06Multiclones Sulfur dioxide 5.70E-01Multiclones Total volatile organic compounds 3.00E-02U/C Arsenic & compounds 2.05E-04U/C Beryllium & compounds 1.05E-05U/C Cadmium & compounds 2.55E-05U/C Carbon monoxide 3.00E+00U/C Chromium (III) compounds 1.30E-04U/C Chromium (VI) compounds 3.95E-05U/C Copper & compounds 4.92E-04U/C Fluoride compounds 7.50E-02U/C Hydrochloric acid 6.00E-01U/C Lead & compounds 2.10E-04U/C Mercury & compounds 4.15E-05U/C Nickel & compounds 1.40E-04U/C Oxides of nitrogen 3.80E+00U/C Particulate Matter 10.0 um 3.40E+00U/C Polycyclic aromatic hydrocarbons 9.49E-06U/C Particulate Matter 2.5 um 1.10E+00U/C Polychlorinated dioxins and furans 9.12E-10U/C Sulfur dioxide 5.70E-01U/C Total volatile organic compounds 3.00E-02



Table 11: Emission factors for black coal – overfeed/spreader stoker, uncontrolled (kg/t) Emission factors for black coal – overfeed/spreader stoker, uncontrolled (kg/t)

Process Substance Emission factor

Bituminous Arsenic & compounds 2.05E-04Bituminous Beryllium & compounds 1.05E-05Bituminous Cadmium & compounds 2.55E-05Bituminous Carbon monoxide 3.00E+00Bituminous Chromium (III) compounds 1.30E-04Bituminous Chromium (VI) compounds 3.95E-05Bituminous Copper & compounds 4.92E-04Bituminous Fluoride compounds 7.50E-02Bituminous Hydrochloric acid 6.00E-01Bituminous Lead & compounds 2.10E-04Bituminous Mercury & compounds 4.15E-05Bituminous Nickel & compounds 1.40E-04Bituminous Oxides of nitrogen 3.80E+00Bituminous Particulate Matter 10.0 um 3.40E+00Bituminous Particulate Matter 2.5 um 1.10E+00Bituminous Polycyclic aromatic hydrocarbons 9.49E-06Bituminous Polychlorinated dioxins and furans 9.12E-10Bituminous Sulfur dioxide 5.70E-01Bituminous Total volatile organic compounds 3.00E-02Sub- bituminous Arsenic & compounds 2.05E-04Sub- bituminous Beryllium & compounds 1.05E-05Sub- bituminous Cadmium & compounds 2.55E-05Sub- bituminous Carbon monoxide 3.00E+00Sub- bituminous Chromium (III) compounds 1.30E-04Sub- bituminous Chromium (VI) compounds 3.95E-05Sub- bituminous Copper & compounds 4.92E-04Sub- bituminous Fluoride compounds 7.50E-02Sub- bituminous Hydrochloric acid 6.00E-01Sub- bituminous Lead & compounds 2.10E-04Sub- bituminous Mercury & compounds 4.15E-05Sub- bituminous Nickel & compounds 1.40E-04Sub- bituminous Oxides of nitrogen 3.80E+00Sub- bituminous Particulate Matter 10.0 um 3.40E+00Sub- bituminous Particulate Matter 2.5 um 1.10E+00Sub- bituminous Polycyclic aromatic hydrocarbons 9.49E-06Sub- bituminous Polychlorinated dioxins and furans 9.12E-10Sub- bituminous Sulfur dioxide 5.25E-01Sub- bituminous Total volatile organic compounds 3.00E-02Overfeed/spreader stoker Arsenic & compounds 2.05E-04Overfeed/spreader stoker Beryllium & compounds 1.05E-05



Emission factors for black coal – overfeed/spreader stoker, uncontrolled (kg/t)

Process Substance Emission factor

Overfeed/spreader stoker Cadmium & compounds 2.55E-05Overfeed/spreader stoker Carbon monoxide 3.00E+00Overfeed/spreader stoker Chromium (III) compounds 1.30E-04Overfeed/spreader stoker Chromium (VI) compounds 3.95E-05Overfeed/spreader stoker Copper & compounds 4.92E-04Overfeed/spreader stoker Fluoride compounds 7.50E-02Overfeed/spreader stoker Hydrochloric acid 6.00E-01Overfeed/spreader stoker Lead & compounds 2.10E-04Overfeed/spreader stoker Mercury & compounds 4.15E-05Overfeed/spreader stoker Nickel & compounds 1.40E-04Overfeed/spreader stoker Oxides of nitrogen 3.80E+00Overfeed/spreader stoker Particulate Matter 10.0 um 3.40E+00Overfeed/spreader stoker Particulate Matter 2.5 um 1.10E+00Overfeed/spreader stoker Polycyclic aromatic hydrocarbons 9.49E-06Overfeed/spreader stoker Polychlorinated dioxins and furans 9.12E-10Overfeed/spreader stoker Sulfur dioxide 5.70E-01Overfeed/spreader stoker Total volatile organic compounds 3.00E-02

Source: Table 35-41, HRL Technology Pty Ltd, NPI – Development of Emission Factors for Combustion in Boilers, a report prepared for the Department of Environment, Water, Heritage and the Arts. Table 12: Emission factors for black coal – spreader stoker (kg/t) Black coal emission factors – spreader stoker (kg/t) Process Control Substance Emission

factor Bituminous U/C Arsenic & compounds 2.05E-04Bituminous U/C Beryllium & compounds 1.05E-05Bituminous U/C Cadmium & compounds 2.55E-05Bituminous U/C Carbon monoxide 2.50E+00Bituminous U/C Chromium (III) compounds 1.30E-04Bituminous U/C Chromium (VI) compounds 3.95E-05Bituminous U/C Copper & compounds 4.92E-04Bituminous U/C Fluoride compounds 7.50E-02Bituminous U/C Hydrochloric acid 6.00E-01Bituminous U/C Lead & compounds 2.10E-04Bituminous U/C Mercury & compounds 4.15E-05Bituminous U/C Nickel & compounds 1.40E-04Bituminous U/C Oxides of nitrogen 5.50E+00Bituminous U/C Particulate Matter 10.0 um 6.60E+00Bituminous U/C Particulate Matter 2.5 um 2.30E+00Bituminous U/C Polychlorinated dioxins and

furans 9.12E-10

Black coal emission factors – spreader stoker (kg/t) Process Control Substance Emission

factor Bituminous U/C Polycyclic aromatic hydrocarbons 9.49E-06Bituminous U/C Sulfur dioxide 5.70E-01Bituminous U/C Total volatile organic compounds 3.00E-02Spreader stoker Baghouse Arsenic & compounds 2.05E-04Spreader stoker Baghouse Beryllium & compounds 1.05E-05Spreader stoker Baghouse Cadmium & compounds 2.55E-05Spreader stoker Baghouse Carbon monoxide 2.50E+00Spreader stoker Baghouse Chromium (III) compounds 1.30E-04Spreader stoker Baghouse Chromium (VI) compounds 3.95E-05Spreader stoker Baghouse Copper & compounds 4.92E-04Spreader stoker Baghouse Fluoride compounds 7.50E-02Spreader stoker Baghouse Hydrochloric acid 6.00E-01Spreader stoker Baghouse Lead & compounds 2.10E-04Spreader stoker Baghouse Mercury & compounds 4.15E-05Spreader stoker Baghouse Nickel & compounds 1.40E-04Spreader stoker Baghouse Oxides of nitrogen 4.40E+00Spreader stoker Baghouse Particulate Matter 10.0 um 4.00E-02Spreader stoker Baghouse Particulate Matter 2.5 um 4.00E-02Spreader stoker Baghouse Polychlorinated dioxins and

furans 9.12E-10

Spreader stoker Baghouse Polycyclic aromatic hydrocarbons 9.49E-06Spreader stoker Baghouse Sulfur dioxide 5.70E-01Spreader stoker Baghouse Total volatile organic compounds 3.00E-02Spreader stoker ESP Arsenic & compounds 2.05E-04Spreader stoker ESP Beryllium & compounds 1.05E-05Spreader stoker ESP Cadmium & compounds 2.55E-05Spreader stoker ESP Carbon monoxide 2.50E+00Spreader stoker ESP Chromium (III) compounds 1.30E-04Spreader stoker ESP Chromium (VI) compounds 3.95E-05Spreader stoker ESP Copper & compounds 4.92E-04Spreader stoker ESP Fluoride compounds 7.50E-02Spreader stoker ESP Hydrochloric acid 6.00E-01Spreader stoker ESP Lead & compounds 2.10E-04Spreader stoker ESP Mercury & compounds 4.15E-05Spreader stoker ESP Nickel & compounds 1.40E-04Spreader stoker ESP Oxides of nitrogen 4.40E+00Spreader stoker ESP Particulate Matter 10.0 um 2.20E-01Spreader stoker ESP Particulate Matter 2.5 um 1.50E-01Spreader stoker ESP Polychlorinated dioxins and

furans 9.12E-10

Spreader stoker ESP Polycyclic aromatic hydrocarbons 9.49E-06Spreader stoker ESP Sulfur dioxide 5.70E-01Spreader stoker ESP Total volatile organic compounds 3.00E-02Spreader stoker Multiclones Arsenic & compounds 2.05E-04



factor Spreader stoker Multiclones Beryllium & compounds 1.05E-05Spreader stoker Multiclones Cadmium & compounds 2.55E-05Spreader stoker Multiclones Carbon monoxide 2.50E+00Spreader stoker Multiclones Chromium (III) compounds 1.30E-04Spreader stoker Multiclones Chromium (VI) compounds 3.95E-05Spreader stoker Multiclones Copper & compounds 4.92E-04Spreader stoker Multiclones Fluoride compounds 7.50E-02Spreader stoker Multiclones Hydrochloric acid 6.00E-01Spreader stoker Multiclones Lead & compounds 2.10E-04Spreader stoker Multiclones Mercury & compounds 4.15E-05Spreader stoker Multiclones Nickel & compounds 1.40E-04Spreader stoker Multiclones Oxides of nitrogen 4.40E+00Spreader stoker Multiclones Particulate Matter 10.0 um 3.90E+00Spreader stoker Multiclones Particulate Matter 2.5 um 1.60E+00Spreader stoker Multiclones Polychlorinated dioxins and

furans 9.12E-10

Spreader stoker Multiclones Polycyclic aromatic hydrocarbons 9.49E-06Spreader stoker Multiclones Sulfur dioxide 5.70E-01Spreader stoker Multiclones Total volatile organic compounds 3.00E-02Spreader stoker Multiclones

with fly ash reinjection

Arsenic & compounds 2.05E-04

Spreader stoker Multiclones with fly ash reinjection

Beryllium & compounds 1.05E-05


Cadmium & compounds 2.55E-05


Carbon monoxide 2.50E+00


Chromium (III) compounds 1.30E-04


Chromium (VI) compounds 3.95E-05


Copper & compounds 4.92E-04


Fluoride compounds 7.50E-02

Spreader stoker Multiclones with fly ash

Hydrochloric acid 6.00E-01



factor reinjection


Lead & compounds 2.10E-04


Mercury & compounds 4.15E-05


Nickel & compounds 1.40E-04


Oxides of nitrogen 4.40E+00


Particulate Matter 10.0 um 6.00E+00


Particulate Matter 2.5 um 7.00E-01


Polychlorinated dioxins and furans

9.12E-10


Polycyclic aromatic hydrocarbons 9.49E-06


Sulfur dioxide 5.70E-01


Total volatile organic compounds 3.00E-02

Spreader stoker U/C Arsenic & compounds 2.05E-04Spreader stoker U/C Beryllium & compounds 1.05E-05Spreader stoker U/C Cadmium & compounds 2.55E-05Spreader stoker U/C Carbon monoxide 2.50E+00Spreader stoker U/C Chromium (III) compounds 1.30E-04Spreader stoker U/C Chromium (VI) compounds 3.95E-05Spreader stoker U/C Copper & compounds 4.92E-04Spreader stoker U/C Fluoride compounds 7.50E-02Spreader stoker U/C Hydrochloric acid 6.00E-01Spreader stoker U/C Lead & compounds 2.10E-04Spreader stoker U/C Mercury & compounds 4.15E-05Spreader stoker U/C Nickel & compounds 1.40E-04Spreader stoker U/C Oxides of nitrogen 4.40E+00Spreader stoker U/C Particulate Matter 10.0 um 6.60E+00



factor Spreader stoker U/C Particulate Matter 2.5 um 2.30E+00Spreader stoker U/C Polychlorinated dioxins and

furans 9.12E-10

Spreader stoker U/C Polycyclic aromatic hydrocarbons 9.49E-06Spreader stoker U/C Sulfur dioxide 5.70E-01Spreader stoker U/C Total volatile organic compounds 3.00E-02Sub-bituminous U/C Arsenic & compounds 2.05E-04Sub-bituminous U/C Beryllium & compounds 1.05E-05Sub-bituminous U/C Cadmium & compounds 2.55E-05Sub-bituminous U/C Carbon monoxide 2.50E+00Sub-bituminous U/C Chromium (III) compounds 1.30E-04Sub-bituminous U/C Chromium (VI) compounds 3.95E-05Sub-bituminous U/C Copper & compounds 4.92E-04Sub-bituminous U/C Fluoride compounds 7.50E-02Sub-bituminous U/C Hydrochloric acid 6.00E-01Sub-bituminous U/C Lead & compounds 2.10E-04Sub-bituminous U/C Mercury & compounds 4.15E-05Sub-bituminous U/C Nickel & compounds 1.40E-04Sub-bituminous U/C Oxides of nitrogen 4.40E+00Sub-bituminous U/C Particulate Matter 10.0 um 6.60E+00Sub-bituminous U/C Particulate Matter 2.5 um 2.30E+00Sub-bituminous U/C Polychlorinated dioxins and

furans 9.12E-10

Sub-bituminous U/C Polycyclic aromatic hydrocarbons 9.49E-06Sub-bituminous U/C Sulfur dioxide 5.25E-01Sub-bituminous U/C Total volatile organic compounds 3.00E-02

Source: Table 35-41, HRL Technology Pty Ltd, NPI – Development of Emission Factors for Combustion in Boilers, a report prepared for the Department of Environment, Water, Heritage and the Arts. Table 13: Emission factors for black coal – underfeed stoker, uncontrolled (kg/t) Black coal emission factors – underfeed stoker, uncontrolled (kg/t) Substance Emission factor Arsenic & compounds 2.05E-04Beryllium & compounds 1.05E-05Cadmium & compounds 2.55E-05Carbon monoxide 5.50E+00Chromium (III) compounds 1.30E-04Chromium (VI) compounds 3.95E-05Copper & compounds 4.92E-04Fluoride compounds 7.50E-02Hydrochloric acid 6.00E-01



Black coal emission factors – underfeed stoker, uncontrolled (kg/t) Substance Emission factor Lead & compounds 2.10E-04Mercury & compounds 4.15E-05Nickel & compounds 1.40E-04Oxides of nitrogen 4.80E+00Polycyclic aromatic hydrocarbons 9.49E-06Particulate Matter 10.0 um 3.10E+00Particulate Matter 2.5 um 1.90E+00Polychlorinated dioxins and furans 9.12E-10Sulfur dioxide 4.65E-01Total volatile organic compounds 6.50E-01

Source: Table 35-41, HRL Technology Pty Ltd, NPI – Development of Emission Factors for Combustion in Boilers, a report prepared for the Department of Environment, Water, Heritage and the Arts. Table 14: Emission factors for black coal – pulverised coal (kg/t) Emission factors for black coal – pulverised coal (kg/t) Process Control Substance Emission

factor Dry bottom U/C Arsenic & compounds 2.05E-04Dry bottom U/C Beryllium & compounds 1.05E-05Dry bottom U/C Cadmium & compounds 2.55E-05Dry bottom U/C Carbon monoxide 2.50E-01Dry bottom U/C Chromium (III) compounds 1.30E-04Dry bottom U/C Chromium (VI) compounds 3.95E-05Dry bottom U/C Copper & compounds 4.92E-04Dry bottom U/C Fluoride compounds 7.50E-02Dry bottom U/C Hydrochloric acid 6.00E-01Dry bottom U/C Lead & compounds 2.10E-04Dry bottom U/C Mercury & compounds 4.15E-05Dry bottom U/C Nickel & compounds 1.40E-04Dry bottom U/C Oxides of nitrogen 1.10E+01Dry bottom U/C Particulate Matter 10.0 um 1.15E+00Dry bottom U/C Particulate Matter 2.5 um 3.00E-01Dry bottom U/C Polycyclic aromatic

hydrocarbons 9.49E-06

Dry bottom U/C Polychlorinated dioxins and furans

9.12E-10

Dry bottom U/C Sulfur dioxide 5.70E-01Dry bottom U/C Total volatile organic

compounds 3.00E-02

Wet bottom U/C Arsenic & compounds 2.05E-04Wet bottom U/C Beryllium & compounds 1.05E-05Wet bottom U/C Cadmium & compounds 2.55E-05


Emission factors for black coal – pulverised coal (kg/t) Process Control Substance Emission

factor Wet bottom U/C Carbon monoxide 2.50E-01Wet bottom U/C Chromium (III) compounds 1.30E-04Wet bottom U/C Chromium (VI) compounds 3.95E-05Wet bottom U/C Copper & compounds 4.92E-04Wet bottom U/C Fluoride compounds 7.50E-02Wet bottom U/C Hydrochloric acid 6.00E-01Wet bottom U/C Lead & compounds 2.10E-04Wet bottom U/C Mercury & compounds 4.15E-05Wet bottom U/C Nickel & compounds 1.40E-04Wet bottom U/C Oxides of nitrogen 1.55E+01Wet bottom U/C Particulate Matter 10.0 um 1.30E+00Wet bottom U/C Particulate Matter 2.5 um 7.40E-01Wet bottom U/C Polycyclic aromatic


Wet bottom U/C Polychlorinated dioxins and furans

9.12E-10

Wet bottom U/C Sulfur dioxide 5.70E-01Wet bottom U/C Total volatile organic

compounds 2.00E-02

Source: Table 35-41, HRL Technology Pty Ltd, NPI – Development of Emission Factors for Combustion in Boilers, a report prepared for the Department of Environment, Water, Heritage and the Arts. Table 15: Emission factors for black coal – pulverised fuel, dry bottom boilers (kg/t) Emission factors for black coal – pulverised fuel, dry bottom boilers (kg/t) Process Control Substance Emission

factor Bituminous U/C Arsenic & compounds 2.05E-04Bituminous U/C Beryllium & compounds 1.05E-05Bituminous U/C Cadmium & compounds 2.55E-05Bituminous U/C Carbon monoxide 2.50E-01Bituminous U/C Chromium (III) compounds 1.30E-04Bituminous U/C Chromium (VI) compounds 3.95E-05Bituminous U/C Copper & compounds 4.92E-04Bituminous U/C Fluoride compounds 7.50E-02Bituminous U/C Hydrochloric acid 6.00E-01Bituminous U/C Lead & compounds 2.10E-04Bituminous U/C Mercury & compounds 4.15E-05Bituminous U/C Nickel & compounds 1.40E-04Bituminous U/C Oxides of nitrogen 1.09E+01Bituminous U/C Particulate Matter 10.0 um 1.50E-01Bituminous U/C Particulate Matter 2.5 um 1.50E-01


Emission factors for black coal – pulverised fuel, dry bottom boilers (kg/t) Process Control Substance Emission

factor Bituminous U/C Polychlorinated dioxins and

furans 9.12E-10

Bituminous U/C Polycyclic aromatic hydrocarbons

9.49E-06

Bituminous U/C Sulfur dioxide 5.70E-01Bituminous U/C Total volatile organic

compounds 3.00E-02

Dry bottom Baghouse Arsenic & compounds 2.05E-04Dry bottom Baghouse Beryllium & compounds 1.05E-05

Dry bottom Baghouse Cadmium & compounds 2.55E-05Dry bottom Baghouse Carbon monoxide 2.50E-01Dry bottom Baghouse Chromium (III) compounds 1.30E-04

Dry bottom Baghouse Chromium (VI) compounds 3.95E-05Dry bottom Baghouse Copper & compounds 4.92E-04Dry bottom Baghouse Fluoride compounds 7.50E-02Dry bottom Baghouse Hydrochloric acid 6.00E-01Dry bottom Baghouse Lead & compounds 2.10E-04Dry bottom Baghouse Mercury & compounds 4.15E-05Dry bottom Baghouse Nickel & compounds 1.40E-04Dry bottom Baghouse Oxides of nitrogen 1.09E+01Dry bottom Baghouse Particulate Matter 10.0 um 1.10E-02Dry bottom Baghouse Particulate Matter 2.5 um 5.00E-03Dry bottom Baghouse Polychlorinated dioxins and

furans 9.12E-10

Dry bottom Baghouse Sulfur dioxide 5.70E-01Dry bottom Baghouse Total volatile organic

compounds 3.00E-02

Dry bottom ESP Arsenic & compounds 2.05E-04Dry bottom ESP Beryllium & compounds 1.05E-05Dry bottom ESP Cadmium & compounds 2.55E-05Dry bottom ESP Carbon monoxide 2.50E-01Dry bottom ESP Chromium (III) compounds 1.30E-04Dry bottom ESP Chromium (VI) compounds 3.95E-05Dry bottom ESP Copper & compounds 4.92E-04Dry bottom ESP Fluoride compounds 7.50E-02Dry bottom ESP Hydrochloric acid 6.00E-01Dry bottom ESP Lead & compounds 2.10E-04Dry bottom ESP Mercury & compounds 4.15E-05Dry bottom ESP Nickel & compounds 1.40E-04Dry bottom ESP Oxides of nitrogen 1.09E+01Dry bottom ESP Particulate Matter 10.0 um 2.70E-01Dry bottom ESP Particulate Matter 2.5 um 1.20E-02



factor Dry bottom ESP Sulfur dioxide 5.70E-01Dry bottom ESP Total volatile organic

compounds 3.00E-02

Dry bottom LNB Arsenic & compounds 2.05E-04Dry bottom LNB Beryllium & compounds 1.05E-05Dry bottom LNB Cadmium & compounds 2.55E-05Dry bottom LNB Carbon monoxide 2.50E-01Dry bottom LNB Chromium (III) compounds 1.30E-04Dry bottom LNB Chromium (VI) compounds 3.95E-05Dry bottom LNB Copper & compounds 4.92E-04Dry bottom LNB Fluoride compounds 7.50E-02Dry bottom LNB Hydrochloric acid 6.00E-01Dry bottom LNB Lead & compounds 2.10E-04Dry bottom LNB Mercury & compounds 4.15E-05Dry bottom LNB Nickel & compounds 1.40E-04Dry bottom LNB Oxides of nitrogen 5.50E+00Dry bottom LNB Particulate Matter 10.0 um 1.50E-01Dry bottom LNB Particulate Matter 2.5 um 3.00E-02Dry bottom LNB Polychlorinated dioxins and

furans 9.12E-10

Dry bottom LNB Sulfur dioxide 5.70E-01Dry bottom LNB Total volatile organic

compounds 3.00E-02

Dry bottom Multiclones Arsenic & compounds 2.05E-04Dry bottom Multiclones Beryllium & compounds 1.05E-05Dry bottom Multiclones Cadmium & compounds 2.55E-05Dry bottom Multiclones Carbon monoxide 2.50E-01Dry bottom Multiclones Chromium (III) compounds 1.30E-04Dry bottom Multiclones Chromium (VI) compounds 3.95E-05Dry bottom Multiclones Copper & compounds 4.92E-04Dry bottom Multiclones Fluoride compounds 7.50E-02Dry bottom Multiclones Hydrochloric acid 6.00E-01Dry bottom Multiclones Lead & compounds 2.10E-04Dry bottom Multiclones Mercury & compounds 4.15E-05Dry bottom Multiclones Nickel & compounds 1.40E-04Dry bottom Multiclones Oxides of nitrogen 1.09E+01Dry bottom Multiclones Particulate Matter 10.0 um 2.90E-01Dry bottom Multiclones Particulate Matter 2.5 um 3.00E-02Dry bottom Multiclones Polychlorinated dioxins and

furans 9.12E-10

Dry bottom Multiclones Sulfur dioxide 5.70E-01Dry bottom Multiclones Total volatile organic

compounds 3.00E-02



factor Dry bottom OFA/LEA Arsenic & compounds 2.05E-04Dry bottom OFA/LEA Beryllium & compounds 1.05E-05Dry bottom OFA/LEA Cadmium & compounds 2.55E-05Dry bottom OFA/LEA Carbon monoxide 2.50E-01Dry bottom OFA/LEA Chromium (III) compounds 1.30E-04Dry bottom OFA/LEA Chromium (VI) compounds 3.95E-05Dry bottom OFA/LEA Copper & compounds 4.92E-04Dry bottom OFA/LEA Fluoride compounds 7.50E-02Dry bottom OFA/LEA Hydrochloric acid 6.00E-01Dry bottom OFA/LEA Lead & compounds 2.10E-04Dry bottom OFA/LEA Mercury & compounds 4.15E-05Dry bottom OFA/LEA Nickel & compounds 1.40E-04Dry bottom OFA/LEA Oxides of nitrogen 3.60E+00Dry bottom OFA/LEA Particulate Matter 10.0 um 1.50E-01Dry bottom OFA/LEA Particulate Matter 2.5 um 3.00E-02Dry bottom OFA/LEA Polychlorinated dioxins and

furans 9.12E-10

Dry bottom OFA/LEA Sulfur dioxide 5.25E-01Dry bottom OFA/LEA Total volatile organic

compounds 3.00E-02

Dry bottom Scrubber Arsenic & compounds 2.05E-04Dry bottom Scrubber Beryllium & compounds 1.05E-05Dry bottom Scrubber Cadmium & compounds 2.55E-05Dry bottom Scrubber Carbon monoxide 2.50E-01Dry bottom Scrubber Chromium (III) compounds 1.30E-04Dry bottom Scrubber Chromium (VI) compounds 3.95E-05Dry bottom Scrubber Copper & compounds 4.92E-04Dry bottom Scrubber Fluoride compounds 7.50E-02Dry bottom Scrubber Hydrochloric acid 6.00E-01Dry bottom Scrubber Lead & compounds 2.10E-04Dry bottom Scrubber Mercury & compounds 4.15E-05Dry bottom Scrubber Nickel & compounds 1.40E-04Dry bottom Scrubber Oxides of nitrogen 1.09E+01Dry bottom Scrubber Particulate Matter 10.0 um 2.10E-01Dry bottom Scrubber Particulate Matter 2.5 um 1.50E-01Dry bottom Scrubber Polychlorinated dioxins and

furans 9.12E-10

Dry bottom Scrubber Sulfur dioxide 5.70E-01Dry bottom Scrubber Total volatile organic

compounds 3.00E-02

Dry bottom U/C Arsenic & compounds 2.05E-04Dry bottom U/C Beryllium & compounds 1.05E-05Dry bottom U/C Cadmium & compounds 2.55E-05



factor Dry bottom U/C Carbon monoxide 2.50E-01Dry bottom U/C Chromium (III) compounds 1.30E-04Dry bottom U/C Chromium (VI) compounds 3.95E-05Dry bottom U/C Copper & compounds 4.92E-04Dry bottom U/C Fluoride compounds 7.50E-02Dry bottom U/C Hydrochloric acid 6.00E-01Dry bottom U/C Lead & compounds 2.10E-04Dry bottom U/C Mercury & compounds 4.15E-05Dry bottom U/C Mercury & compounds 4.15E-05Dry bottom U/C Nickel & compounds 1.40E-04Dry bottom U/C Oxides of nitrogen 1.09E+01Dry bottom U/C Particulate Matter 10.0 um 1.50E-01Dry bottom U/C Particulate Matter 2.5 um 3.00E-02Dry bottom U/C Polychlorinated dioxins and

furans 9.12E-10

Dry bottom U/C Polycyclic aromatic hydrocarbons

9.49E-06

Dry bottom U/C Sulfur dioxide 5.70E-01Dry bottom U/C Total volatile organic

compounds 3.00E-02

Tangential fired, bituminous

LNB Arsenic & compounds 2.05E-04


LNB Beryllium & compounds 1.05E-05


LNB Cadmium & compounds 2.55E-05


LNB Carbon monoxide 2.50E-01


LNB Chromium (III) compounds 1.30E-04


LNB Chromium (VI) compounds 3.95E-05


LNB Copper & compounds 4.92E-04


LNB Fluoride compounds 7.50E-02


LNB Hydrochloric acid 6.00E-01


LNB Lead & compounds 2.10E-04


LNB Mercury & compounds 4.15E-05


LNB Nickel & compounds 1.40E-04

Tangential fired, LNB Oxides of nitrogen 4.85E+00



factor bituminous Tangential fired, bituminous

LNB Particulate Matter 10.0 um 1.50E-01




LNB Polychlorinated dioxins and furans

9.12E-10


LNB Sulfur dioxide 5.70E-01


LNB Total volatile organic compounds

3.00E-02


OFA/LEA Arsenic & compounds 2.05E-04




OFA/LEA Beryllium & compounds 1.05E-05


OFA/LEA Cadmium & compounds 2.55E-05


OFA/LEA Carbon monoxide 2.50E-01


OFA/LEA Chromium (III) compounds 1.30E-04


OFA/LEA Chromium (VI) compounds 3.95E-05


OFA/LEA Copper & compounds 4.92E-04


OFA/LEA Fluoride compounds 7.50E-02


OFA/LEA Hydrochloric acid 6.00E-01


OFA/LEA Lead & compounds 2.10E-04


OFA/LEA Mercury & compounds 4.15E-05


OFA/LEA Nickel & compounds 1.40E-04


OFA/LEA Oxides of nitrogen 5.00E+00


OFA/LEA Particulate Matter 10.0 um 1.50E-01




OFA/LEA Polychlorinated dioxins and furans

9.12E-10



factor Tangential fired, bituminous

OFA/LEA Sulfur dioxide 5.70E-01


OFA/LEA Total volatile organic compounds

3.00E-02


U/C Arsenic & compounds 2.05E-04


U/C Beryllium & compounds 1.05E-05


U/C Cadmium & compounds 2.55E-05


U/C Carbon monoxide 2.50E-01


U/C Chromium (III) compounds 1.30E-04


U/C Chromium (VI) compounds 3.95E-05


U/C Copper & compounds 4.92E-04


U/C Fluoride compounds 7.50E-02


U/C Hydrochloric acid 6.00E-01


U/C Lead & compounds 2.10E-04


U/C Mercury & compounds 4.15E-05


U/C Nickel & compounds 1.40E-04


U/C Oxides of nitrogen 7.50E+00


U/C Particulate Matter 10.0 um 1.50E-01




U/C Polychlorinated dioxins and furans

9.12E-10


U/C Polycyclic aromatic hydrocarbons

9.49E-06


U/C Sulfur dioxide 5.70E-01


U/C Total volatile organic compounds

3.00E-02

Wall fired, sub-bituminous


Wall fired, sub- OFA/LEA Beryllium & compounds 1.05E-05



factor bituminous Wall fired, sub-bituminous




























9.12E-10





3.00E-02















factor Wall fired, sub-bituminous




















9.12E-10



9.49E-06





3.00E-02

Source: Table 35-41, HRL Technology Pty Ltd, NPI – Development of Emission Factors for Combustion in Boilers, a report prepared for the Department of Environment, Water, Heritage and the Arts. Table 16: Emission factors for black coal – pulverised fuel, wet bottom boilers (kg/t) Emission factors for black coal – pulverised fuel, wet bottom boilers (kg/t) Process Control Substance Emission

factor Tangential fired, bituminous








Tangential fired, U/C Chromium (III) compounds 1.30E-04


Emission factors for black coal – pulverised fuel, wet bottom boilers (kg/t) Process Control Substance Emission

factor bituminous


















U/C Particulate Matter 10.0 um 1.30E+00





9.12E-10



9.49E-06





2.00E-02

Wall fired, bituminous


















factor Wall fired, bituminous











U/C Particulate Matter 10.0 um 1.30E+00





9.12E-10



9.49E-06





2.00E-02




OFA/LEA Beryllium & compounds 1.05E-05





















factor Wall fired, sub-bituminous





OFA/LEA Particulate Matter 10.0 um 1.30E+00





9.12E-10





2.00E-02

Wet bottom ESP Arsenic & compounds 2.05E-04Wet bottom ESP Beryllium & compounds 1.05E-05Wet bottom ESP Cadmium & compounds 2.55E-05Wet bottom ESP Carbon monoxide 2.50E-01Wet bottom ESP Chromium (III) compounds 1.30E-04Wet bottom ESP Chromium (VI) compounds 3.95E-05Wet bottom ESP Copper & compounds 4.92E-04Wet bottom ESP Fluoride compounds 7.50E-02Wet bottom ESP Hydrochloric acid 6.00E-01Wet bottom ESP Lead & compounds 2.10E-04Wet bottom ESP Mercury & compounds 4.15E-05Wet bottom ESP Nickel & compounds 1.40E-04Wet bottom ESP Oxides of nitrogen 1.55E+01Wet bottom ESP Particulate Matter 10.0 um 2.10E-02Wet bottom ESP Particulate Matter 2.5 um 1.10E-02Wet bottom ESP Polychlorinated dioxins and

furans 9.12E-10

Wet bottom ESP Sulfur dioxide 5.70E-01Wet bottom ESP Total volatile organic

compounds 2.00E-02

Wet bottom Multiclones Arsenic & compounds 2.05E-04Wet bottom Multiclones Beryllium & compounds 1.05E-05Wet bottom Multiclones Cadmium & compounds 2.55E-05Wet bottom Multiclones Carbon monoxide 2.50E-01Wet bottom Multiclones Chromium (III) compounds 1.30E-04Wet bottom Multiclones Chromium (VI) compounds 3.95E-05Wet bottom Multiclones Copper & compounds 4.92E-04Wet bottom Multiclones Fluoride compounds 7.50E-02Wet bottom Multiclones Hydrochloric acid 6.00E-01Wet bottom Multiclones Lead & compounds 2.10E-04


factor Wet bottom Multiclones Mercury & compounds 4.15E-05Wet bottom Multiclones Nickel & compounds 1.40E-04Wet bottom Multiclones Oxides of nitrogen 1.55E+01Wet bottom Multiclones Particulate Matter 10.0 um 6.50E-01Wet bottom Multiclones Particulate Matter 2.5 um 4.30E-01Wet bottom Multiclones Polychlorinated dioxins and

furans 9.12E-10

Wet bottom Multiclones Sulfur dioxide 5.70E-01Wet bottom Multiclones Total volatile organic

compounds 2.00E-02

Wet bottom U/C Arsenic & compounds 2.05E-04Wet bottom U/C Beryllium & compounds 1.05E-05Wet bottom U/C Cadmium & compounds 2.55E-05Wet bottom U/C Carbon monoxide 2.50E-01Wet bottom U/C Chromium (III) compounds 1.30E-04Wet bottom U/C Chromium (VI) compounds 3.95E-05Wet bottom U/C Copper & compounds 4.92E-04Wet bottom U/C Fluoride compounds 7.50E-02Wet bottom U/C Hydrochloric acid 6.00E-01Wet bottom U/C Lead & compounds 2.10E-04Wet bottom U/C Mercury & compounds 4.15E-05Wet bottom U/C Nickel & compounds 1.40E-04Wet bottom U/C Oxides of nitrogen 1.55E+01Wet bottom U/C Particulate Matter 10.0 um 1.30E+00Wet bottom U/C Particulate Matter 2.5 um 7.40E-01Wet bottom U/C Polychlorinated dioxins and

furans 9.12E-10

Wet bottom U/C Polycyclic aromatic hydrocarbons

9.49E-06

Wet bottom U/C Sulfur dioxide 5.70E-01Wet bottom U/C Total volatile organic

compounds 2.00E-02

Source: Table 35-41, HRL Technology Pty Ltd, NPI – Development of Emission Factors for Combustion in Boilers, a report prepared for the Department of Environment, Water, Heritage and the Arts. Table 17: Emission factors for blast furnace gas – uncontrolled (kg/t) Blast furnace gas emission factors – uncontrolled (kg/t) Substance Emission factor Carbon monoxide 1.60E-01Mercury & compounds 5.00E-08Oxides of nitrogen 1.10E+00Particulate Matter 10.0 um 2.50E-02


Blast furnace gas emission factors – uncontrolled (kg/t) Substance Emission factor Particulate Matter 2.5 um 2.50E-02Polychlorinated dioxins and furans 1.00E-11Sulfur dioxide 2.50E-03Total volatile organic compounds 9.00E-03

Source: Table 55, HRL Technology Pty Ltd, NPI – Development of Emission Factors for Combustion in Boilers, a report prepared for the Department of Environment, Water, Heritage and the Arts. Table 18: Emission factors for coke oven gas – uncontrolled (kg/t) Coke oven gas emission factors – uncontrolled (kg/t) Substance Emission factor Carbon monoxide 6.40E-01Mercury & compounds 9.90E-07Oxides of nitrogen 6.90E-01Particulate Matter 10.0 um 1.10E-02Particulate Matter 2.5 um 1.10E-02Polychlorinated dioxins and furans 2.00E-11Sulfur dioxide 2.50E-03Total volatile organic compounds 9.00E-03

Source: Table 56, HRL Technology Pty Ltd, NPI – Development of Emission Factors for Combustion in Boilers, a report prepared for the Department of Environment, Water, Heritage and the Arts. Table 19: Emission factors for landfill gas - uncontrolled (kg/MJ) Landfill gas emission factors - uncontrolled (kg/MJ) Substance Emission factor Arsenic & compounds 1.86E-09Cadmium & compounds 2.61E-09Chromium (III) compounds 1.03E-08Copper & compounds 3.44E-09Lead & compounds 2.86E-09Manganese & compounds 1.02E-07Mercury & compounds 3.56E-11Nickel & compounds 3.44E-08Total volatile organic compounds 8.67E-07

Source: Table 58, HRL Technology Pty Ltd, NPI – Development of Emission Factors for Combustion in Boilers, a report prepared for the Department of Environment, Water, Heritage and the Arts.


Table 20: Emission Factors for natural gas – tangential fired (kg/t) Natural gas emission factors – tangential fired (kg/t) Control Substance Emission factor FGR Arsenic & compounds 4.33E-06 FGR Beryllium & compounds 2.60E-08 FGR Cadmium & compounds 2.38E-05 FGR Carbon monoxide 2.12E+00 FGR Chromium (III) compounds 3.03E-05 FGR Cobalt & compounds 1.76E-06 FGR Copper & compounds 1.84E-05 FGR Lead & compounds 1.08E-05 FGR Manganese & compounds 8.24E-06 FGR Mercury & compounds 5.62E-06 FGR Nickel & compounds 4.54E-05 FGR Oxides of nitrogen 1.64E+00 FGR Particulate Matter 10.0 um 1.60E-01 FGR Particulate Matter 2.5 um 1.60E-01 FGR Polychlorinated dioxins and furans 1.07E-10 FGR Polycyclic aromatic hydrocarbons 1.38E-05 FGR Selenium & compounds 5.13E-07 FGR Sulfur dioxide 0.035(1) FGR Total volatile organic compounds 1.19E-01 FGR Zinc & compounds 6.21E-04 U/C Arsenic & compounds 4.33E-06 U/C Beryllium & compounds 2.60E-08 U/C Cadmium & compounds 2.38E-05 U/C Carbon monoxide 5.20E-01 U/C Chromium (III) compounds 3.03E-05 U/C Cobalt & compounds 1.76E-06 U/C Copper & compounds 1.84E-05 U/C Lead & compounds 1.08E-05 U/C Manganese & compounds 8.24E-06 U/C Mercury & compounds 5.62E-06 U/C Nickel & compounds 4.54E-05 U/C Oxides of nitrogen 3.68E+00 U/C Particulate Matter 10.0 um 1.60E-01 U/C Particulate Matter 2.5 um 1.60E-01 U/C Polychlorinated dioxins and furans 1.07E-10 U/C Polycyclic aromatic hydrocarbons 1.38E-05 U/C Selenium & compounds 4.54E-05 U/C Sulfur dioxide 0.035(1) U/C Total volatile organic compounds 1.19E-01 U/C Zinc & compounds 6.21E-04



(1) Averaged emission factors for Australian facilities based on 76 tests (Table 30, NPI – Development of emission

factors for Combustion in Boilers, HRL 2007)

Table 21: Emission factors for natural gas – wall fired (kg/t) Natural gas emission factors – wall fired (kg/t) Process Control Substance Emission

factor <30MW heat input LNB Arsenic & compounds 4.33E-06<30MW heat input LNB Beryllium & compounds 2.60E-08<30MW heat input LNB Cadmium & compounds 2.38E-05<30MW heat input LNB Carbon monoxide 1.82E+00<30MW heat input LNB Chromium (III) compounds 3.03E-05<30MW heat input LNB Cobalt & compounds 1.76E-06<30MW heat input LNB Copper & compounds 1.84E-05<30MW heat input LNB Lead & compounds 1.08E-05<30MW heat input LNB Manganese & compounds 8.24E-06<30MW heat input LNB Mercury & compounds 5.62E-06<30MW heat input LNB Nickel & compounds 4.54E-05<30MW heat input LNB Oxides of nitrogen 1.08E+00<30MW heat input LNB Particulate Matter 10.0 um 1.60E-01<30MW heat input LNB Particulate Matter 2.5 um 1.60E-01<30MW heat input LNB Polychlorinated dioxins and

furans 1.07E-10

<30MW heat input LNB Polycyclic aromatic hydrocarbons

1.38E-05

<30MW heat input LNB Selenium & compounds 4.54E-05<30MW heat input LNB Sulfur dioxide 0.035(1)

<30MW heat input LNB Total volatile organic compounds

1.19E-01

<30MW heat input LNB Zinc & compounds 6.21E-04<30MW heat input LNB+FGR Arsenic & compounds 4.33E-06<30MW heat input LNB+FGR Beryllium & compounds 2.60E-08<30MW heat input LNB+FGR Cadmium & compounds 2.38E-05<30MW heat input LNB+FGR Carbon monoxide 1.82E+00<30MW heat input LNB+FGR Chromium (III) compounds 3.03E-05<30MW heat input LNB+FGR Cobalt & compounds 1.76E-06<30MW heat input LNB+FGR Copper & compounds 1.84E-05<30MW heat input LNB+FGR Lead & compounds 1.08E-05<30MW heat input LNB+FGR Manganese & compounds 8.24E-06<30MW heat input LNB+FGR Mercury & compounds 5.62E-06<30MW heat input LNB+FGR Nickel & compounds 4.54E-05<30MW heat input LNB+FGR Oxides of nitrogen 6.90E-01<30MW heat input LNB+FGR Particulate Matter 10.0 um 1.60E-01<30MW heat input LNB+FGR Particulate Matter 2.5 um 1.60E-01



Natural gas emission factors – wall fired (kg/t) Process Control Substance Emission

factor <30MW heat input LNB+FGR Polychlorinated dioxins and

furans 1.07E-10

<30MW heat input LNB+FGR Polycyclic aromatic hydrocarbons

1.38E-05

<30MW heat input LNB+FGR Selenium & compounds 4.54E-05<30MW heat input LNB+FGR Sulfur dioxide 0.035(1)

<30MW heat input LNB+FGR Total volatile organic compounds

1.19E-01

<30MW heat input LNB+FGR Zinc and compounds 6.21E-04<30MW heat input U/C Arsenic & compounds 4.33E-06<30MW heat input U/C Beryllium & compounds 2.60E-08<30MW heat input U/C Cadmium & compounds 2.38E-05<30MW heat input U/C Carbon monoxide 1.82E+00<30MW heat input U/C Chromium (III) compounds 3.03E-05<30MW heat input U/C Cobalt & compounds 1.76E-06<30MW heat input U/C Copper & compounds 1.84E-05<30MW heat input U/C Lead & compounds 1.08E-05<30MW heat input U/C Manganese & compounds 8.24E-06<30MW heat input U/C Mercury & compounds 5.62E-06<30MW heat input U/C Nickel & compounds 4.54E-05<30MW heat input U/C Oxides of nitrogen 2.16E+00<30MW heat input U/C Particulate Matter 10.0 um 1.60E-01<30MW heat input U/C Particulate Matter 2.5 um 1.60E-01<30MW heat input U/C Polychlorinated dioxins and

furans 1.07E-10

<30MW heat input U/C Polycyclic aromatic hydrocarbons

1.38E-05

<30MW heat input U/C Selenium & compounds 4.54E-05<30MW heat input U/C Sulfur dioxide 0.035(1)

<30MW heat input U/C Total volatile organic compounds

1.19E-01

<30MW heat input U/C Zinc & compounds 6.21E-04>30MW heat input LNB Arsenic & compounds 4.33E-06>30MW heat input LNB Beryllium & compounds 2.60E-08>30MW heat input LNB Cadmium & compounds 2.38E-05>30MW heat input LNB Carbon monoxide 1.82E+00>30MW heat input LNB Chromium (III) compounds 3.03E-05>30MW heat input LNB Cobalt & compounds 1.76E-06>30MW heat input LNB Copper & compounds 1.84E-05>30MW heat input LNB Lead & compounds 1.08E-05>30MW heat input LNB Manganese & compounds 8.24E-06>30MW heat input LNB Mercury & compounds 5.62E-06>30MW heat input LNB Nickel & compounds 4.54E-05>30MW heat input LNB Oxides of nitrogen 3.03E+00



factor >30MW heat input LNB Particulate Matter 10.0 um 1.60E-01>30MW heat input LNB Particulate Matter 2.5 um 1.60E-01>30MW heat input LNB Polychlorinated dioxins and

furans 1.07E-10

>30MW heat input LNB Polycyclic aromatic hydrocarbons

1.38E-05

>30MW heat input LNB Selenium & compounds 4.54E-05>30MW heat input LNB Sulfur dioxide 0.035(1)

>30MW heat input LNB Total volatile organic compounds

1.19E-01

>30MW heat input LNB Zinc and compounds 6.21E-04>30MW heat input LNB+FGR Arsenic & compounds 4.33E-06>30MW heat input LNB+FGR Beryllium & compounds 2.60E-08>30MW heat input LNB+FGR Cadmium & compounds 2.38E-05>30MW heat input LNB+FGR Carbon monoxide 1.82E+00>30MW heat input LNB+FGR Chromium (III) compounds 3.03E-05>30MW heat input LNB+FGR Cobalt & compounds 1.76E-06>30MW heat input LNB+FGR Copper & compounds 1.84E-05>30MW heat input LNB+FGR Lead & compounds 1.08E-05>30MW heat input LNB+FGR Manganese & compounds 8.24E-06>30MW heat input LNB+FGR Mercury & compounds 5.62E-06>30MW heat input LNB+FGR Nickel & compounds 4.54E-05>30MW heat input LNB+FGR Oxides of nitrogen 2.16E+00>30MW heat input LNB+FGR Particulate Matter 10.0 um 1.60E-01>30MW heat input LNB+FGR Particulate Matter 2.5 um 1.60E-01>30MW heat input LNB+FGR Polychlorinated dioxins and

furans 1.07E-10

>30MW heat input LNB+FGR Polycyclic aromatic hydrocarbons

1.38E-05

>30MW heat input LNB+FGR Selenium & compounds 4.54E-05>30MW heat input LNB+FGR Sulfur dioxide 0.035(1)

>30MW heat input LNB+FGR Total volatile organic compounds

1.19E-01

>30MW heat input LNB+FGR Zinc and compounds 6.21E-04>30MW heat input OFA/LEA Arsenic & compounds 4.33E-06>30MW heat input OFA/LEA Beryllium & compounds 2.60E-08>30MW heat input OFA/LEA Cadmium & compounds 2.38E-05>30MW heat input OFA/LEA Carbon monoxide 1.82E+00>30MW heat input OFA/LEA Chromium (III) compounds 3.03E-05>30MW heat input OFA/LEA Cobalt & compounds 1.76E-06>30MW heat input OFA/LEA Copper & compounds 1.84E-05>30MW heat input OFA/LEA Lead & compounds 1.08E-05>30MW heat input OFA/LEA Manganese & compounds 8.24E-06>30MW heat input OFA/LEA Mercury & compounds 5.62E-06



factor >30MW heat input OFA/LEA Nickel & compounds 4.54E-05>30MW heat input OFA/LEA Oxides of nitrogen 4.11E+00>30MW heat input OFA/LEA Particulate Matter 10.0 um 1.60E-01>30MW heat input OFA/LEA Particulate Matter 2.5 um 1.60E-01>30MW heat input OFA/LEA Polychlorinated dioxins and

furans 1.07E-10

>30MW heat input OFA/LEA Polycyclic aromatic hydrocarbons

1.38E-05

>30MW heat input OFA/LEA Selenium & compounds 4.54E-05>30MW heat input OFA/LEA Sulfur dioxide 0.035(1)

>30MW heat input OFA/LEA Total volatile organic compounds

1.19E-01

>30MW heat input OFA/LEA Zinc and compounds 6.21E-04>30MW heat input U/C Arsenic & compounds 4.33E-06>30MW heat input U/C Beryllium & compounds 2.60E-08>30MW heat input U/C Cadmium & compounds 2.38E-05>30MW heat input U/C Carbon monoxide 1.82E+00>30MW heat input U/C Chromium (III) compounds 3.03E-05>30MW heat input U/C Cobalt & compounds 1.76E-06>30MW heat input U/C Copper & compounds 1.84E-05>30MW heat input U/C Lead & compounds 1.08E-05>30MW heat input U/C Manganese & compounds 8.24E-06>30MW heat input U/C Mercury & compounds 5.62E-06>30MW heat input U/C Nickel & compounds 4.54E-05>30MW heat input U/C Oxides of nitrogen 5.95E+00>30MW heat input U/C Particulate Matter 10.0 um 1.60E-01>30MW heat input U/C Particulate Matter 2.5 um 1.60E-01>30MW heat input U/C Polychlorinated dioxins and

furans 1.07E-10

>30MW heat input U/C Polycyclic aromatic hydrocarbons

1.38E-05

>30MW heat input U/C Selenium & compounds 4.54E-05>30MW heat input U/C Sulfur dioxide 0.035(1)

>30MW heat input U/C Total volatile organic compounds

1.19E-01

>30MW heat input U/C Zinc and compounds 6.21E-04Source: Table 51-53, HRL Technology Pty Ltd, NPI – Development of Emission Factors for Combustion in Boilers, a report prepared for the Department of Environment, Water, Heritage and the Arts.

(1) Averaged emission factors for Australian facilities based on 76 tests (Table 30, NPI – Development of emission

factors for Combustion in Boilers, HRL 2007)

Table 22: Emission factors for petroleum refinery gas - uncontrolled (kg/m3) Petroleum refinery gas emission factors - uncontrolled (kg/m3) Substance Emission factor Carbon monoxide 5.61E-04Oxides of nitrogen 2.24E-03Particulate Matter 10.0 um 4.81E-05Particulate Matter 2.5 um 4.81E-05Sulfur dioxide 4.56E-03Total volatile organic compounds 4.49E-05

Source: Table 57, HRL Technology Pty Ltd, NPI – Development of Emission Factors for Combustion in Boilers, a report prepared for the Department of Environment, Water, Heritage and the Arts. Table 23: Emission factors for LPG – uncontrolled (kg/t) LPG emission factors – uncontrolled (kg/t) Process Substance Emission factor Industrial butane Carbon monoxide 7.60E-01 Industrial butane Mercury & compounds 4.96E-07 Industrial butane Oxides of nitrogen 4.43E+00 Industrial butane Particulate Matter 10.0 um 2.40E-01 Industrial butane Particulate Matter 2.5 um 1.30E-01 Industrial butane Polychlorinated dioxins and furans 9.92E-11 Industrial butane Sulfur dioxide 1.05E-04 Industrial butane Total volatile organic compounds 5.00E-02 Industrial propane Carbon monoxide 7.50E-01 Industrial propane Mercury & compounds 4.96E-07 Industrial propane Oxides of nitrogen 4.46E+00 Industrial propane Particulate Matter 10.0 um 2.60E-01 Industrial propane Particulate Matter 2.5 um 8.00E-02 Industrial propane Polychlorinated dioxins and furans 9.92E-11 Industrial propane Sulfur dioxide 1.23E-04 Industrial propane Total volatile organic compounds 6.00E-02

Source: Table 54, HRL Technology Pty Ltd, NPI – Development of Emission Factors for Combustion in Boilers, a report prepared for the Department of Environment, Water, Heritage and the Arts. Table 24: Emission Factors for residual oil (kg/t) Residual oil emission factors (kg/t) Process Control Substance Emission

factor <30MW U/C Antimony & compounds 6.99E-04<30MW U/C Arsenic & compounds 1.76E-04<30MW U/C Beryllium & compounds 3.70E-06



Residual oil emission factors (kg/t) Process Control Substance Emission

factor <30MW U/C Cadmium & compounds 5.29E-05<30MW U/C Carbon monoxide 6.70E-01<30MW U/C Chlorine 4.62E-02<30MW U/C Chromium (III)

compounds 1.12E-04

<30MW U/C Chromium (VI) compounds

3.30E-05

<30MW U/C Cobalt & compounds 8.01E-04<30MW U/C Copper & compounds 2.34E-04<30MW U/C Fluoride compounds 4.96E-03<30MW U/C Lead & compounds 2.01E-04<30MW U/C Manganese & compounds 4.00E-04<30MW U/C Mercury & compounds 1.50E-05<30MW U/C Nickel & compounds 1.12E-02<30MW U/C Oxides of nitrogen 7.32E+00<30MW U/C Particulate Matter 10.0 um 5.42E-02<30MW U/C Particulate Matter 2.5 um 3.27E-02<30MW U/C Polychlorinated dioxins

and furans 2.34E-10

<30MW U/C Polycyclic aromatic hydrocarbons

1.58E-04

<30MW U/C Selenium & compounds 9.10E-05<30MW U/C Sulfur dioxide 6.27E-01<30MW U/C Total volatile organic

compounds 4.00E-02

<30MW U/C Zinc and compounds 3.87E-03>30MW, tangential firing

LNB Antimony & compounds 6.99E-04

>30MW, tangential firing

LNB Arsenic & compounds 1.76E-04


LNB Beryllium & compounds 3.70E-06


LNB Cadmium & compounds 5.29E-05


LNB Carbon monoxide 6.70E-01


LNB Chlorine 4.62E-02


LNB Chromium (III) compounds

1.12E-04


LNB Chromium (VI) compounds

3.30E-05


LNB Cobalt & compounds 8.01E-04

>30MW, tangential LNB Copper & compounds 2.34E-04



factor firing >30MW, tangential firing

LNB Fluoride compounds 4.96E-03


LNB Lead & compounds 2.01E-04


LNB Manganese & compounds 4.00E-04


LNB Mercury & compounds 1.50E-05


LNB Nickel & compounds 1.12E-02


LNB Oxides of nitrogen 3.46E+00






LNB Polychlorinated dioxins & furans

2.34E-10


LNB Polycyclic aromatic hydrocarbons

1.58E-04


LNB Selenium & compounds 9.10E-05


LNB Total volatile organic compounds

4.00E-02


LNB Zinc & compounds 3.87E-03


U/C Antimony & compounds 6.99E-04










U/C Chlorine 4.62E-02


U/C Chromium (III) compounds

1.12E-04


U/C Chromium (VI) compounds

3.30E-05


U/C Cobalt & compounds 8.01E-04



factor >30MW, tangential firing







U/C Manganese & compounds 4.00E-04













2.34E-10



1.58E-04


U/C Selenium & compounds 9.10E-05



4.00E-02


U/C Zinc & compounds 3.87E-03

>30MW, wall firing LNB Antimony & compounds 6.99E-04>30MW, wall firing LNB Arsenic & compounds 1.76E-04>30MW, wall firing LNB Beryllium & compounds 3.70E-06>30MW, wall firing LNB Cadmium & compounds 5.29E-05>30MW, wall firing LNB Carbon monoxide 6.70E-01>30MW, wall firing LNB Chlorine 4.62E-02>30MW, wall firing LNB Chromium (III)

compounds 1.12E-04

>30MW, wall firing LNB Chromium (VI) compounds

3.30E-05

>30MW, wall firing LNB Cobalt & compounds 8.01E-04>30MW, wall firing LNB Copper & compounds 2.34E-04>30MW, wall firing LNB Fluoride compounds 4.96E-03>30MW, wall firing LNB Lead & compounds 2.01E-04>30MW, wall firing LNB Manganese & compounds 4.00E-04>30MW, wall firing LNB Mercury & compounds 1.50E-05>30MW, wall firing LNB Nickel & compounds 1.12E-02



factor >30MW, wall firing LNB Oxides of nitrogen 5.32E+00>30MW, wall firing LNB Particulate Matter 10.0 um 5.42E-02>30MW, wall firing LNB Particulate Matter 2.5 um 3.27E-02>30MW, wall firing LNB Polychlorinated dioxins

and furans 2.34E-10

>30MW, wall firing LNB Polycyclic aromatic hydrocarbons

1.58E-04

>30MW, wall firing LNB Selenium & compounds 9.10E-05>30MW, wall firing LNB Total volatile organic

compounds 4.00E-02

>30MW, wall firing LNB Zinc & compounds 3.87E-03>30MW, wall firing U/C Antimony & compounds 6.99E-04>30MW, wall firing U/C Arsenic & compounds 1.76E-04>30MW, wall firing U/C Beryllium & compounds 3.70E-06>30MW, wall firing U/C Cadmium & compounds 5.29E-05>30MW, wall firing U/C Carbon monoxide 6.70E-01>30MW, wall firing U/C Chlorine 4.62E-02>30MW, wall firing U/C Chromium (III)

compounds 1.12E-04

>30MW, wall firing U/C Chromium (VI) compounds

3.30E-05

>30MW, wall firing U/C Cobalt & compounds 8.01E-04>30MW, wall firing U/C Copper & compounds 2.34E-04>30MW, wall firing U/C Fluoride compounds 4.96E-03>30MW, wall firing U/C Lead & compounds 2.01E-04>30MW, wall firing U/C Manganese & compounds 4.00E-04>30MW, wall firing U/C Mercury & compounds 1.50E-05>30MW, wall firing U/C Nickel & compounds 1.12E-02>30MW, wall firing U/C Oxides of nitrogen 6.25E+00>30MW, wall firing U/C Particulate Matter 10.0 um 5.42E-02>30MW, wall firing U/C Particulate Matter 2.5 um 3.27E-02>30MW, wall firing U/C Polychlorinated dioxins

and furans 2.34E-10

>30MW, wall firing U/C Polycyclic aromatic hydrocarbons

1.58E-04

>30MW, wall firing U/C Selenium & compounds 9.10E-05>30MW, wall firing U/C Total volatile organic

compounds 4.00E-02

>30MW, wall firing U/C Zinc & compounds 3.87E-03Source: Table 42-45, HRL Technology Pty Ltd, NPI – Development of Emission Factors for Combustion in Boilers, a report prepared for the Department of Environment, Water, Heritage and the Arts.

Table 25: Emission factors for distillate (diesel) oil (kg/t) Distillate (diesel) oil emission factors (kg/t) Process Control Substance Emission

factor <30MW U/C Arsenic & compounds 7.72E-05<30MW U/C Beryllium & compounds 5.79E-05<30MW U/C Cadmium & compounds 5.79E-05<30MW U/C Carbon monoxide 6.80E-01<30MW U/C Chromium (III)

compounds 5.79E-05

<30MW U/C Copper & compounds 1.16E-04<30MW U/C Lead & compounds 1.74E-04<30MW U/C Manganese & compounds 1.16E-04<30MW U/C Mercury & compounds 5.79E-05<30MW U/C Nickel & compounds 5.79E-05<30MW U/C Oxides of nitrogen 2.72E+00<30MW U/C Polycyclic aromatic


<30MW U/C Particulate Matter 10.0 um 1.40E-01<30MW U/C Particulate Matter 2.5 um 3.00E-02<30MW U/C Polychlorinated dioxins

and furans 4.49E-10

<30MW U/C Selenium & compounds 2.92E-04<30MW U/C Sulfur dioxide 5.79E-01<30MW U/C Total volatile organic

compounds 2.72E-02

<30MW U/C Zinc & compounds 5.79E-02>30MW LNB Arsenic & compounds 5.79E-02>30MW LNB Beryllium & compounds 5.79E-05>30MW LNB Cadmium & compounds 5.79E-02>30MW LNB Carbon monoxide 6.80E-01>30MW LNB Chromium (III)

compounds 5.79E-02

>30MW LNB Copper & compounds 5.79E-02>30MW LNB Lead & compounds 5.79E-02>30MW LNB Manganese & compounds 5.79E-02>30MW LNB Mercury & compounds 5.79E-05>30MW LNB Nickel & compounds 5.79E-02>30MW LNB Oxides of nitrogen 1.36E+00>30MW LNB Polycyclic aromatic


>30MW LNB Particulate Matter 10.0 um 1.40E-01>30MW LNB Particulate Matter 2.5 um 3.00E-02>30MW LNB Polychlorinated dioxins

and furans 4.90E-10

>30MW LNB Selenium & compounds 5.79E-02


>30MW LNB Sulfur dioxide 5.79E-01>30MW LNB Total volatile organic

compounds 2.72E-02

>30MW LNB Zinc and compounds 5.79E-02>30MW U/C Arsenic & compounds 5.79E-02>30MW U/C Beryllium & compounds 5.79E-05>30MW U/C Cadmium & compounds 5.79E-02>30MW U/C Carbon monoxide 6.80E-01>30MW U/C Chromium (III)

compounds 5.79E-02

>30MW U/C Copper & compounds 5.79E-02>30MW U/C Lead & compounds 5.79E-02>30MW U/C Manganese & compounds 5.79E-02>30MW U/C Mercury & compounds 5.79E-05>30MW U/C Nickel & compounds 5.79E-02>30MW U/C Oxides of nitrogen 3.26E+00>30MW U/C Polycyclic aromatic


>30MW U/C Particulate Matter 10.0 um 1.40E-01>30MW U/C Particulate Matter 2.5 um 3.00E-02>30MW U/C Polychlorinated dioxins

and furans 4.90E-10

>30MW U/C Selenium & compounds 5.79E-02>30MW U/C Sulfur dioxide 5.79E-01>30MW U/C Total volatile organic

compounds 2.72E-02

>30MW U/C Zinc & compounds 7.72E-05Source: Table 46-49, HRL Technology Pty Ltd, NPI – Development of Emission Factors for Combustion in Boilers, a report prepared for the Department of Environment, Water, Heritage and the Arts. Table 26: Emission factors for waste oil - uncontrolled (kg/t) Waste oil emission factors - uncontrolled (kg/t) Substance Emission factor Cadmium & compounds 1.17E-03Chromium (III) compounds 2.52E-03Carbon monoxide 6.30E-01Hydrochloric acid 8.30E+00Lead & compounds 6.92E-02Nickel & compounds 1.38E-03Oxides of nitrogen 2.39E+00Particulate Matter 10.0 um 6.42E+00Particulate Matter 2.5 um 3.62E+00Polycyclic aromatic hydrocarbons 3.70E-05Sulfur dioxide 1.67E-01


Total volatile organic compounds 1.30E-01Source: Table 50, HRL Technology Pty Ltd, NPI – Development of Emission Factors for Combustion in Boilers, a report prepared for the Department of Environment, Water, Heritage and the Arts. Table 27: Emission factors for tallow (kg/t) Tallow emission factors (kg/t) Control Substance Emission factor Flue gas recirculation Carbon monoxide 2.70E-01 Flue gas recirculation Oxides of nitrogen 1.52E+00 Flue gas recirculation Particulate Matter 10.0 um 1.90E-01 Flue gas recirculation Sulfur dioxide 1.10E-01 Flue gas recirculation Particulate Matter 2.5 um 2.00E-02 U/C Carbon monoxide 1.80E-01 U/C Oxides of nitrogen 1.77E+00 U/C Particulate Matter 10.0 um 1.90E-01 U/C Particulate Matter 2.5 um 2.00E-02 U/C Sulfur dioxide 3.00E-02

Source: HRL Technology Pty Ltd, NPI – Development of Emission Factors for Combustion in Boilers, a report prepared for the Department of Environment, Water, Heritage and the Arts. Table 28: Emission factors for wood and wood waste (kg/t) Wood and wood waste emission factors (kg/t) Process Control Substance Emission

factor Bark fired Multiclones w/o fly

ash reinjection Particulate Matter 10.0 um 1.62E+00

Bark fired Multiclones w/o fly ash reinjection




2.75E-07



Bark fired Multiclones with fly ash reinjection






2.75E-07



Bark fired U/C Particulate Matter 10.0 um 8.40E+00Bark fired U/C Particulate Matter 2.5 um 5.00E+00Bark fired U/C Polychlorinated dioxins and

furans 2.75E-07



Wood and wood waste emission factors (kg/t) Process Control Substance Emission

factor Bark fired U/C Sulfur dioxide 1.70E-01Bark fired Wet scrubber Particulate Matter 10.0 um 1.25E+00Bark fired Wet scrubber Particulate Matter 2.5 um 8.10E-01Bark fired Wet scrubber Polychlorinated dioxins and

furans 2.75E-07

Bark fired Wet scrubber Sulfur dioxide 1.70E-01FBC U/C Carbon monoxide 7.00E-01FBC U/C Oxides of nitrogen 1.00E+00FBC U/C Sulfur dioxide 1.70E-01Fuel cell/Dutch oven

U/C Carbon monoxide 3.30E+00

Fuel cell/Dutch oven

U/C Oxides of nitrogen 1.90E-01

Fuel cell/Dutch oven


Wood/bark fired Dry electrostatic granular filter
























1.45E-08


Polycyclic aromatic hydrocarbons

1.78E-03



Wood/bark fired Multiclones w/o fly ash reinjection




factor Wood/bark fired Multiclones w/o fly

ash reinjection Beryllium & compounds 1.64E-07





















1.45E-08



1.78E-03



Wood/bark fired Multiclones with fly ash reinjection


















Wood/bark fired Multiclones with fly Particulate Matter 10.0 um 2.73E+00



factor ash reinjection





1.45E-08



1.78E-03

Wood/bark fired U/C Arsenic & compounds 1.49E-04 Wood/bark fired U/C Beryllium & compounds 7.47E-06 Wood/bark fired U/C Cadmium & compounds 2.79E-05Wood/bark fired U/C Carbon monoxide 4.08E+00Wood/bark fired U/C Chromium (III) compounds 1.43E-04Wood/bark fired U/C Chromium (VI) compounds 2.38E-05Wood/bark fired U/C Copper & compounds 3.33E-04Wood/bark fired U/C Lead & compounds 3.26E-04Wood/bark fired U/C Mercury & compounds 2.38E-05Wood/bark fired U/C Nickel & compounds 2.24E-04Wood/bark fired U/C Oxides of nitrogen 1.49E+00Wood/bark fired U/C Particulate Matter 10.0 um 3.24E+00Wood/bark fired U/C Particulate Matter 2.5 um 2.74E+00Wood/bark fired U/C Polychlorinated dioxins and

furans 1.45E-08

Wood/bark fired U/C Polycyclic aromatic hydrocarbons

8.94E-04

Wood/bark fired U/C Sulfur dioxide 1.70E-01Wood/bark fired U/C Total volatile organic

compounds 1.20E-01

Wood/bark fired Wet scrubber Arsenic & compounds 4.27E-05Wood/bark fired Wet scrubber Beryllium & compounds 1.64E-07Wood/bark fired Wet scrubber Cadmium & compounds 1.06E-05Wood/bark fired Wet scrubber Chromium (III) compounds 7.80E-05Wood/bark fired Wet scrubber Chromium (VI) compounds 2.30E-05Wood/bark fired Wet scrubber Copper & compounds 1.87E-04Wood/bark fired Wet scrubber Lead & compounds 2.23E-04Wood/bark fired Wet scrubber Mercury & compounds 2.58E-06Wood/bark fired Wet scrubber Nickel & compounds 3.45E-05Wood/bark fired Wet scrubber Particulate Matter 10.0 um 2.20E-01Wood/bark fired Wet scrubber Particulate Matter 2.5 um 2.20E-01Wood/bark fired Wet scrubber Polychlorinated dioxins and

furans 1.45E-08

Wood/bark fired Wet scrubber Polycyclic aromatic hydrocarbons

1.78E-03

Source: Table 59-63, HRL Technology Pty Ltd, NPI – Development of Emission Factors for Combustion in Boilers, a report prepared for the Department of Environment, Water, Heritage and the Arts. Notes: The Australian average for sulfur in fuels is 6.64 kg/t. The following are typical Australian fuel properties: Fuel Specific Volume Natural gas 1.35 (m3/kg) Coke oven gas 1.83 (m3/kg) Blast furnace gas 0.80 (m3/kg) LPG (propane) 1960 (litres/tonne) LPG (butane) 1760 (litres/tonne) Diesel 1135 (litres/tonne) Oil 1050 (litres/tonne) Source: HRL Technology Pty Ltd, NPI – Development of Emission Factors for Combustion in Boilers, a report prepared for the Department of Environment, Water, Heritage and the Arts. Table 29: Emission control efficiency rates Substance Control Efficiency rate (%) Oxides of nitrogen SCR 70 - 90 Oxides of nitrogen SNCR 30 - 50 Oxides of nitrogen SNCR with LNB 65 - 75 Oxides of nitrogen LEA 10 - 44 Oxides of nitrogen LNB (Air staged) 25 - 35 Oxides of nitrogen LNB (Flue gas

recirculation) 0 - 20

Oxides of nitrogen LNB (fuel staged) 50 - 60 Sulfur dioxide Wet scrubber 90 - 98 Sulfur dioxide Semi-dry scrubber 80 - 90 Sulfur dioxide Dry scrubber 50 - 80 PM10 ESP 90 – 99.9 (new equipment

99 and above) PM10 Fabric filter 95 – 99.9 (new equipment

99 and above) PM10 Single high throughput

cyclone 10 - 40

PM10 Single conventional cyclone

30 - 90

PM10 Single high efficiency cyclone

60 - 95

PM10 Multi cyclones 80 - 92.5 PM10 Venturi scrubber 70 - 99 PM10 Condensation scrubber 99 - 99.9 PM10 Impingement scrubber 50 - 99 PM10 Orifice scrubber 80 - 99


PM2.5 ESP 90 – 99.9 (new equipment 99 and above)

PM2.5 Fabric filter 95 – 99.9 (new equipment 99 and above)

PM2.5 Single high throughput cyclone

0 - 10

PM2.5 Single conventional cyclone

0 - 40

PM2.5 Single high efficiency cyclone

60 - 95

PM2.5 Venturi scrubber 20 - 70 PM2.5 Condensation scrubber 70 - 99 PM2.5 Impingement scrubber 50 - 99 PM2.5 Orifice scrubber 80 - 99 Source: HRL Technology Pty Ltd, NPI – Development of Emission Factors for Combustion in Boilers, a report prepared for the Department of Environment, Water, Heritage and the Arts. Appendix C: Modifications to the Combustion in boilers emission estimation technique (EET) manual (March 2008)

Page Outline of alteration throughout Version 3.1 follows the new standard format for Emission Estimation

Techniques Manuals. Version 3.1 makes use of new emission factors which are additional or

modifications of those used in earlier versions of the manual, based on further research reports. Published emission factors have either been developed based on Australian data, or have been drawn from USEPA AP42, where that data has been accessed as acceptable for Australian industrial applications.

Emission factors for sulfur dioxide for Natural Gas combustion purposes have been updated to correct an anomaly in version 3.0 of the manual.

Version 3.1 incorporates the changes to the National Environmental Protection Measure (NEPM) by state and federal Ministers from June 2007.


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