Important Information Concerning the Menu of Control Measures

We regard this as a “living documents” and as we use these documents, we expect to make 

ongoing revisions as we receive additional information. We invite users to provide 

suggestions for additional measures, or additional sources of information on measures, that 

they believe should be included.

Before examining control measures, an important step is to identify the nature of the 

PM2.5 and ozone problem in their areas and the sources contributing to that problem. The 

severity, nature and sources of the problem vary in each area, so the measures that are 

effective and cost-effective will also vary by area. Similarly, the geographic area in which 

measures are effectively applied will vary depending on the extent to which pollution sources 

outside the area contribute to the area’s problem. Similarly, the costs of applying a given 

control measure will have case-specific considerations. While the tables here provide overall 

control costs and control efficiency estimates derived from the references, there is inherent 

uncertainty in any estimates of this nature. We do not attempt in these tables to provide any 

rigorous treatment of these uncertainties, but rather provide the control efficiency and cost 

estimates as a rough “ballpark” starting point. These documents also do not provide specific 

emissions monitoring and testing information, such as costs. We encourage the use of sourcespecific assessments which will be more reliable.

This document contains several tabular lists of point source and non-point source (previously 

known as 'area' sources) control measures, organized by pollutant, i.e., NOx, VOC, PM, and 

SO2. The tables also identify reference sources that the user may wish to consult for more 

information. Note that this technical document is focused on identification of measures and 

does not address mechanisms for implementation, such as whether a measure would be 

implemented on a mandatory or voluntary basis.

The Menu of Control Measures (MCM), complied by the State and Local Programs Group 

within U.S. EPA's Office of Air Quality Planning and Standards, was developed to provide 

information useful in the development of local emission reduction and NAAQS SIP scenarios, 

and identifying and evaluating potential control measures. This informational document is 

intended to provide a broad, though not comprehensive, listing of potential emissions 

reduction measures for direct PM2.5 and precursors of ozone and PM2.5. Concerning mobile 

sources, we encourage State air planning agencies to consider these control measures when 

they do an initial screening step to identify the sectors that warrant more detailed analysis as 

part of their control strategy preparation for nonattainment ozone or PM SIPs. It is critical that 

this information be used only as a screening step and that final SIPs should be based on 

mobile source model runs for States' specific geographic areas following guidance from EPA's 

Office of Transportation and Air Quality (OTAQ).
Below are additional important aspects of the MCM:

· The MCM is based on data in reports from the U.S. EPA and other organizations (e.g., 

LADCO, OTC, NACAA, SCAQMD, WRAP, and other Federal agencies).

· The MCM cost and control efficiency information are best characterized as nationallevel averages so care should be used to consider local cost factors for more refined analysis.

· In many cases the accuracy of the MCM cost and control efficiency information is 

limited by the information in the emission inventory to which it is applied. For example, it is 

important to know what control measures currently exist at a source before quantifying the 

cost and increased control efficiency of a more effective control measure. Information on 

existing controls is often very limited in emission inventories and sometimes when it is 

available, it is unreliable.

· VOC Control Measures - This list of measures includes updates for VOC Control 

Measures based in part on the results of a literature review of the current and proposed 

measures of various air quality agencies, including the California Air Resources Board, 

individual California Air Management Districts, the Ozone Transport Commission, and the 

Lake Michigan Air Directors Consortium. In addition, 40 CFR Part 59 addresses Federal 

rules for non-point VOC source categories. We considered these Federal rules as the baseline 

from which additional reductions were measured. The reported control efficiencies are the 

percent reduction from the Federal baseline. Note that control efficiencies involving product 

reformulations are highly uncertain and depend on the geographic region. National average 

reductions are included when possible, but some control efficiencies are based on area specific 

analyses.

· ICI Boiler Control Measures - Control and cost information in the CMC for Industrial, 

Commercial, and Institutional Boilers is outdated and may underestimate the costs of control.

EPA’s Air Economics Group is initiating a project to update control and cost information for 

ICI Boiler NOx control measures. We will follow this up with an update of PM and SO2 

Boiler control measures if resources are available.

· Four Onroad mobile source control measures are included with reduction and cost ranges 

based on recent MOVES runs. Reductions associated with these control measures should 

NOT be applied to MOBILE6-based outputs as these reductions and costs are all based on 

MOVES data. These are:

- Eliminate Long Duration Idling for Long-Haul Heavy Duty Trucks

- Onroad Heavy Duty Diesel Retrofits

- Continuous Inspection and Maintenance

- Onroad use of Low RVP Fuels
Feedback is welcome and encouraged - please send comments to Tom Coda, US EPA (email address: 

coda.tom@epa.gov)
Point & NonPoint NOx

Menu of Control Measures

Updated 4/12/2012

Printed 8/6/2013 4 of 67

Sector Source Category Emission Reduction 

Measure Name Control Efficiency (%)* Cost Effectiveness (2006$/ton reduced)

Other pollutants 

controlled Description/Notes/Caveats References

NonPoint

Commercial/ 

Institutional - Natural 

Gas

Water heater 

replacement 45 $0

This control would replace existing water heaters with new water heaters. New water heaters would be required to emit 

less than or equal to 40 ng NOx per Joule heat output. This control applies to all commercial/institutional natural gas 

burning water heaters. 

EPA 2006b, EPA 1986, 

EPA 1995f, EPA 1996f, 

EPA 2007b

NonPoint Industrial Coal 

Combustion

RACT to 25 tpy (Low 

NOx Burner) 21 $2,167 The RACT control technology used is the addition of a low NOx burner to reduce NOx emissions. This standard applies to 

sources with boilers fueled by coal that emit over 25 tpy NOx.

EPA 2006b, EPA 1986, 

EPA 1998d, EPA 1996f

NonPoint Industrial Coal 

Combustion

RACT to 50 tpy (Low 

NOx Burner) 21 $2,167 The RACT control technology used is the addition of a low NOx burner to reduce NOx emissions. This standard applies to 

sources with boilers fueled by coal that emit over 50 tpy NOx.

EPA 2006b, EPA 1986, 

EPA 1998d, EPA 1996f

NonPoint Industrial Natural Gas 

Combustion

RACT to 25 tpy (Low 

NOx Burner) 31 1NJDEP 2003 The RACT control technology used is the addition of a low NOx burner to reduce NOx emissions. This standard applies to 

sources with boilers fueled by natural gas that emit over 50 tpy NOx.

EPA 2006b, EPA 1986, 

EPA 1998d, EPA 1996f

NonPoint Industrial Natural Gas 

Combustion

RACT to 50 tpy (Low 

NOx Burner) 31 1NJDEP 2003 The RACT control technology used is the addition of a low NOx burner to reduce NOx emissions. This standard applies to 

sources with boilers fueled by natural gas that emit over 50 tpy NOx.

EPA 2006b, EPA 1986, 

EPA 1998d, EPA 1996f

NonPoint Industrial Oil 

Combustion

RACT to 25 tpy (Low 

NOx Burner) 36 $1,894 The RACT control technology used is the addition of a low NOx burner to reduce NOx emissions. This standard applies to 

sources with boilers fueled by oil that emit over 25 tpy NOx.

EPA 2006b, EPA 1986, 

EPA 1998d, EPA 1996f

NonPoint Industrial Oil 

Combustion

RACT to 50 tpy (Low 

NOx Burner) 36 $1,894 The RACT control technology used is the addition of a low NOx burner to reduce NOx emissions. This standard applies to 

sources with boilers fueled by oil that emit over 50 tpy NOx.

EPA 2006b, EPA 1986, 

EPA 1998d, EPA 1996f

NonPoint Open Burning Episodic Ban (Daily 

Only) 100 $0 This is a generic control measure that would ban open burning on days where ozone exceedances were predicted, 

reducing NOx emissions on those days. This measure would not reduce the annual emissions.

EPA 2006b, EPA 1986, 

EPA 2007b, EPA 1996f

NonPoint

Process Heaters - 

Distillate Oil, Residual 

Oil, or Other Fuel

Low NOx Burner and 

Selective Noncatalytic 

Reduction

75

$3,691 for NOx<1 tpd 

and $1,990 for NOx>1 

tpd

This control is the use of low NOx burner (LNB) technology and selective non-catalytic reduction (SNCR) to reduce NOx 

emissions. LNBs reduce the amount of NOx created from reaction between fuel nitrogen and oxygen by lowering the 

temperature of one combustion zone and reducing the amount of oxygen available in another. SNCR controls are postcombustion control technologies based on the chemical reduction of nitrogen oxides (NOx) into molecular nitrogen (N2) 

and water vapor (H2O). This control is applicable to process heaters fired with distillate, residual oil, and other 

unclassified fuels.

EPA 2006b, Pechan 

2001, EPA 1998e, EPA 

2002a, EPA 1993c

NonPoint

Residential/Commercial/ 

Institutional Water 

Heaters and/or Space 

Heaters

Low NOx Water 

Heaters and Low NOx 

Burner Space Heaters

7-75 $928-$1,974

This control is the use of low NOx burner (LNB) technology to reduce NOx emissions. LNBs reduce the amount of NOx 

created from reaction between fuel nitrogen and oxygen by lowering the temperature of one combustion zone and 

reducing the amount of oxygen available in another. The South Coast and Bay Area AQMDs set emission limits for water 

heaters and space heaters. This control is based on the installation of low-NOx space heaters and water heaters in 

residential, commercial and institutional sources for the reduction of NOx emissions.

EPA 2006b, EPA 1986, 

EPA 2007b, SCAQMD 

1996a, Pechan 2006, 

EPA 1996f

NonEGU 

Point

Adipic Acid 

Manufacturing Extended Absorption 86 $144 This control is the use of extended absorption technologies to reduce NOx emissions. This control applies to adipic acid 

manufacturing operations.

EPA 2006b, EPA 

1998e, EPA 1991

NonEGU 

Point

Adipic Acid 

Manufacturing Thermal Reduction 81 $674

This control is the application of Thermal Reduction controls to Adipic Acid Manufacturing sources to reduce NOx 

emissions. Thermal reduction reduces NOx by reaction with excess fuel in a reducing environment. NOx laden stream 

and excess fuel mixture passes through a burner where the mixture is heated above its ignition temperature. The hot 

gases then pass through one or more chambers to provide sufficient residence time to ensure complete combustion.

EPA 2006b

NonEGU 

Point

Ammonia Production - 

Natural Gas-Fired 

Reformers

Low NOx Burner 50

$1,316 for NOx<1 tpd 

and $1,043 for NOx>1 

tpd

This control is the use of low NOx burner (LNB) technology to reduce NOx emissions. LNBs reduce the amount of NOx 

created from reaction between fuel nitrogen and oxygen by lowering the temperature of one combustion zone and 

reducing the amount of oxygen available in another. This control is applicable to natural-gas fired reformers involved in 

the production of ammonia with uncontrolled NOx emissions greater than 10 tons per year.

EPA 2006b, Pechan 

2001, EPA 1998e, EPA 

2002a, EPA 1994g

NonEGU 

Point

Ammonia Production - 

Natural Gas-Fired 

Reformers

Low NOx Burner and 

Flue Gas Recirculation 60 $4,109 for NOx<1 tpd 

and $947 for NOx>1 tpd

This control is the use of low NOx burner (LNB) technology and flue gas recirculation (FGR) to reduce NOx emissions. 

LNBs reduce the amount of NOx created from reaction between fuel nitrogen and oxygen by lowering the temperature of 

one combustion zone and reducing the amount of oxygen available in another. This control is applicable to natural-gas 

fired reformers involved in the production of ammonia with uncontrolled NOx emissions greater than 10 tons per year.

EPA 2006b, Pechan 

2001, EPA 1998e, EPA 

2002a, EPA 1993c

NonEGU 

Point

Ammonia Production - 

Natural Gas-Fired 

Reformers

Oxygen Trim and Water 

Injection 65 $1,091 for NOx<1 tpd 

and $514 for NOx>1 tpd

This control is the use of oxygen trim and water injection to reduce NOx emissions.Water is injected into the gas turbine, 

reducing the temperatures in the NOx-forming regions. The water can be injected into the fuel, the combustion air or 

directly into the combustion chamber. This control is applicable to natural-gas fired reformers involved in the production of 

ammonia with uncontrolled NOx emissions greater than 10 tons per year.

EPA 2006b, Pechan 

2001, EPA 1998e, EPA 

2002a, ERG 2000, EPA 

1994g
Point & NonPoint NOx

Menu of Control Measures

Updated 4/12/2012

Printed 8/6/2013 5 of 67

Sector Source Category Emission Reduction 

Measure Name Control Efficiency (%)* Cost Effectiveness (2006$/ton reduced)

Other pollutants 

controlled Description/Notes/Caveats References

NonEGU 

Point

Ammonia Production - 

Natural Gas-Fired 

Reformers

Selective Catalytic 

Reduction 90 $2,852

This control is the selective catalytic reduction of NOx through add-on controls. SCR controls are post-combustion control 

technologies based on the chemical reduction of nitrogen oxides (NOx) into molecular nitrogen (N2) and water vapor 

(H2O). The SCR utilizes a catalyst to increase the NOx removal efficiency, which allows the process to occur at lower 

temperatures. This control is applicable to natural-gas fired reformers involved in the production of ammonia with 

uncontrolled NOx emissions greater than 10 tons per year.

EPA 2006b, EPA 

2007b, EPA 1998e, 

EPA 2002a, EPA 

2007d, Sorrels 2007

NonEGU 

Point

Ammonia Production - 

Natural Gas-Fired 

Reformers

Selective Non-Catalytic 

Reduction 50

$6,211 for NOx<1 tpd 

and $2,520 for NOx>1 

tpd

This control is the reduction of NOx emission through selective non-catalytic reduction add-on controls. SNCR controls 

are post-combustion control technologies based on the chemical reduction of nitrogen oxides (NOx) into molecular 

nitrogen (N2) and water vapor (H2O). This control is applicable to natural-gas fired reformers involved in the production of 

ammonia with uncontrolled NOx emissions greater than 10 tons per year.

EPA 2006b, Pechan 

2001, EPA 1998e, EPA 

2002a, EPA 1994g

NonEGU 

Point

Ammonia Production - 

Oil-Fired Reformers Low NOx Burner 50 $642 for NOx<1 tpd and 

$690 for NOx>1 tpd

This control is the use of low NOx burner (LNB) technology to reduce NOx emissions. LNBs reduce the amount of NOx 

created from reaction between fuel nitrogen and oxygen by lowering the temperature of one combustion zone and 

reducing the amount of oxygen available in another. This control is applicable to oil-gas fired reformers involved in the 

production of ammonia with uncontrolled NOx emissions greater than 10 tons per year.

EPA 2006b

NonEGU 

Point

Ammonia Production - 

Oil-Fired Reformers

Low NOx Burner and 

Flue Gas Recirculation 60 $1,798 for NOx<1 tpd 

and $626 for NOx>1 tpd

This control is the use of low NOx burner (LNB) technology and flue gas recirculation (FGR) to reduce NOx emissions. 

LNBs reduce the amount of NOx created from reaction between fuel nitrogen and oxygen by lowering the temperature of 

one combustion zone and reducing the amount of oxygen available in another. This control is applicable to oil-gas fired 

reformers involved in the production of ammonia with uncontrolled NOx emissions greater than 10 tons per year.

EPA 2006b

NonEGU 

Point

Ammonia Production - 

Oil-Fired Reformers

Selective Catalytic 

Reduction 80

$2,375 for NOx<1 tpd 

and $1,300 for NOx>1 

tpd

This control is the selective catalytic reduction of NOx through add-on controls. SCR controls are post-combustion control 

technologies based on the chemical reduction of nitrogen oxides (NOx) into molecular nitrogen (N2) and water vapor 

(H2O). The SCR utilizes a catalyst to increase the NOx removal efficiency, which allows the process to occur at lower 

temperatures. This control is applicable to oil-gas fired reformers involved in the production of ammonia with uncontrolled 

NOx emissions greater than 10 tons per year.

EPA 2006b

NonEGU 

Point

Ammonia Production - 

Oil-Fired Reformers

Selective Non-Catalytic 

Reduction 50

$4,141 for NOx<1 tpd 

and $1,685 for NOx>1 

tpd

This control is the reduction of NOx emission through selective non-catalytic reduction add-on controls. SNCR controls 

are post-combustion control technologies based on the chemical reduction of nitrogen oxides (NOx) into molecular 

nitrogen (N2) and water vapor (H2O). This control is applicable to oil-gas fired reformers involved in the production of 

ammonia with uncontrolled NOx emissions greater than 10 tons per year.

EPA 2006b

NonEGU 

Point

Asphalt Plant 

Manufacture

Low NOx Burner and 

Flue Gas Recirculation 30-50 N/A

This control is the use of low NOx burner (LNB) technology and flue gas recirculation (FGR) to reduce NOx emissions. 

LNBs reduce the amount of NOx created from reaction between fuel nitrogen and oxygen by lowering the temperature of 

one combustion zone and reducing the amount of oxygen available in another. This control is applicable to asphalt plant 

manufacturing sources.

STAPPA/ALAPCO 2006

NonEGU 

Point

Asphaltic Concrete - 

Rotary Dryer - 

Conventional Plant

Low NOx Burner 50

$3,531 for NOx<1 tpd 

and $2,889 for NOx>1 

tpd

This control is the use of low NOx burner (LNB) technology to reduce NOx emissions. LNBs reduce the amount of NOx 

created from reaction between fuel nitrogen and oxygen by lowering the temperature of one combustion zone and 

reducing the amount of oxygen available in another. This control is applicable to construction operations with rotary driers 

and uncontrolled NOx emissions greater than 10 tons per year.

EPA 2006b, EPA 

1998e, EPA 2002a, 

EPA 1993c

NonEGU 

Point

By-Product Coke 

Manufacturing - Oven 

Underfiring

Selective Non-Catalytic 

Reduction 60 $2,632

This control is the reduction of NOx emission through selective non-catalytic reduction add-on controls. SNCR controls 

are post-combustion control technologies based on the chemical reduction of nitrogen oxides (NOx) into molecular 

nitrogen (N2) and water vapor (H2O). This control applies to all by-product coke manufacturing operations with oven 

underfiring and uncontrolled NOx emissions greater than 10 tons per year.

EPA 2006b, Pechan 

2001, EPA 1998e, EPA 

2002a, EPA 1994e

NonEGU 

Point Cement Kilns Biosolid Injection Technology 23 $407 This control is the use of biosolid injection to reduce NOx emissions. This control applies to cement kilns. EPA 2006b, EPA 2007c

NonEGU 

Point Cement Kilns Changing feed 

composition 25-40 $587

This control is changing the cement formulation by adding steel slag to lower the clinkering temperatures and supress 

NOx. The patented feed modifi cation technique known as the CemStar Process is a raw feed modifi cation process that 

can reduce NOx emissions by about 30 percent and increase production by approximately 15 percent. It involves the 

addition of a small amount of steel slag to the raw kiln feed. Steel slag has a chemical composition similar to clinker and 

many of the chemical reactions required to convert steel slag to clinker take place in the steel furnace. By substituting 

steel slag for a portion of the raw materials, facilities can increase thermal effi ciency and thereby reduce NOx emissions. 

This control is applicable to wet- and dry-process kilns, as well as those with preheaters or precalciners.

STAPPA/ALAPCO 2006
Point & NonPoint NOx

Menu of Control Measures

Updated 4/12/2012

Printed 8/6/2013 6 of 67

Sector Source Category Emission Reduction 

Measure Name Control Efficiency (%)* Cost Effectiveness (2006$/ton reduced)

Other pollutants 

controlled Description/Notes/Caveats References

NonEGU 

Point Cement Kilns Process Control 

Systems <25 N/A

This control is the modification of the cement production process to improve fuel efficiency, increase capacity and kiln 

operational stability. NOx reductions result from the increase in productivity and reduced energy use. One process control 

that specifically targets NOx emissions is continuousemissions monitoring systems (CEMS). CEMS allow operators to 

continuously monitor oxygen andcarbon monoxide (CO) emissions in cement kiln exhaust gases. The levels of these 

gases indicate the amount of excess air in the combustion zone. At a given excess air level, NOx emissions increase as 

the temperature increases. Knowing the excess air level allows operators to maintain a lower temperature and thereby 

minimize NOx creation. Studies indicate that reducing excess air by half can reduce NOx emissions by about 15 percent 

This control is applicable to wet- and dry-process kilns, as well as those with preheaters or precalciners.

STAPPA/ALAPCO 2006

NonEGU 

Point

Cement Manufacturing - 

Dry Process

Selective Non-Catalytic 

Reduction - Ammonia 50 $1,364

This control is the reduction of NOx emission through ammonia based selective non-catalytic reduction add-on controls. 

SNCR controls are post-combustion control technologies based on the chemical reduction of nitrogen oxides (NOx) into 

molecular nitrogen (N2) and water vapor (H2O). This control applies to dry-process cement manufacturing operations with 

uncontrolled NOx emissions greater than 10 tons per year.

EPA 2006b, Pechan 

2001, EPA 1998e, EPA 

2002a, EPA 1994h

NonEGU 

Point

Cement Manufacturing - 

Dry Process

Selective Non-Catalytic 

Reduction - Urea 50 1NJDEP 2003

This control is the reduction of NOx emission through urea based selective non-catalytic reduction add-on controls. SNCR 

controls are post-combustion control technologies based on the chemical reduction of nitrogen oxides (NOx) into 

molecular nitrogen (N2) and water vapor (H2O). This control applies to dry-process cement manufacturing with 

uncontrolled NOx emissions greater than 10 tons per year.

EPA 2006b, EPA 

1998e, EPA 2002a, 

EPA 1994h

NonEGU 

Point

Cement Manufacturing - 

Dry Process or Wet 

Process

Low NOx Burner 25 $577

This control is the use of low NOx burner (LNB) technology to reduce NOx emissions. LNBs reduce the amount of NOx 

created from reaction between fuel nitrogen and oxygen by lowering the temperature of one combustion zone and 

reducing the amount of oxygen available in another. This control applies to dry-process or wet-process cement 

manufacturing operations with indirect-fired kilns with uncontrolled NOx emissions greater than 10 tons per year.

EPA 2006b, EPA 

1998e, EPA 2002a, 

EPA 1994h, EC/R 2000

NonEGU 

Point

Cement Manufacturing - 

Dry Process or Wet 

Process

Mid-Kiln Firing 30 $72

This control is the use of mid- kiln firing to reduce NOx emissions. Mid-kiln firing is the injection of solid fuel into the 

calcining zone of a long kiln. This allows for part of the fuel to be burned at a lower temperature, reducing NOx formation. 

This control applies to wet-process and dry-process cement manufacturing operations with uncontrolled NOx emissions 

greater than 10 tons per year.

EPA 2006b, EPA 

1998e, EPA 2002a, 

EPA 1994h, EC/R 2000

NonEGU 

Point

Cement Manufacturing - 

Wet Process

Selective Catalytic 

Reduction 90 $4,776

This control is the selective catalytic reduction of NOx through add-on controls. SCR controls are post-combustion control 

technologies based on the chemical reduction of nitrogen oxides (NOx) into molecular nitrogen (N2) and water vapor 

(H2O). The SCR utilizes a catalyst to increase the NOx removal efficiency, which allows the process to occur at lower 

temperatures.This control applies to wet-process cement manufacturing with uncontrolled NOx emissions greater than 10 

tons per year.

EPA 2007b

NonEGU 

Point

Ceramic Clay 

Manufacturing - Drying Low NOx Burner 50 $2,889-$3,531

This control is the use of low NOx burner (LNB) technology to reduce NOx emissions. LNBs reduce the amount of NOx 

created from reaction between fuel nitrogen and oxygen by lowering the temperature of one combustion zone and 

reducing the amount of oxygen available in another. This control is applicable to drying processes at ceramic clay 

manufacturing operations with uncontrolled NOx emissions greater than 10 tons per year.

EPA 2006b, EPA 

1998e, EPA 2002a, 

EPA 1994h

NonEGU 

Point

Coal Cleaning-Thermal 

Dryer - Fluidized Bed Low NOx Burner 50 $222-$1,108

This control is the use of low NOx burner (LNB) technology to reduce NOx emissions. LNBs reduce the amount of NOx 

created from reaction between fuel nitrogen and oxygen by lowering the temperature of one combustion zone and 

reducing the amount of oxygen available in another. This control is applicable to thermal drying processes at coal 

cleaning operations with uncontrolled NOx emissions greater than 10 tons per year.

EPA 2006b, EPA 

1998e, EPA 2002a, 

EPA 1994g

NonEGU 

Point

Combustion Turbine - 

Aeroderivative Gas 

Turbines

Water Injection 74 $2,206

This control is the use of water injection to reduce NOx emissions. Water is injected into the gas turbine, reducing the 

temperatures in the NOx-forming regions. The water can be injected into the fuel, the combustion air or directly into the 

combustion chamber. This control applies to aeroderivative gas-fired turbines.

EPA 1993d

NonEGU 

Point

Combustion Turbines - 

Natural Gas Low NOx Burner 68% for small sources, 

84% for large sources 

$490 for NOx<1 tpd and 

$100 for NOx>1 tpd

This control is the use of low NOx burner (LNB) technology to reduce NOx emissions. LNBs reduce the amount of NOx 

created from reaction between fuel nitrogen and oxygen by lowering the temperature of one combustion zone and 

reducing the amount of oxygen available in another. This control applies to natural gas fired turbines with uncontrolled 

NOx emissions greater than 10 tons per year.

EPA 2006b, Pechan 

2001, EPA 1998e, EPA 

2002a, EPA 1993d

NonEGU 

Point

Combustion Turbines - 

Natural Gas

Selective Catalytic 

Reduction and Low 

NOx Burner

94 $4,125 for NOx<1 tpd 

and $963 for NOx>1 tpd

This control is the selective catalytic reduction of NOx through add-on controls. SCR controls are post-combustion control 

technologies based on the chemical reduction of nitrogen oxides (NOx) into molecular nitrogen (N2) and water vapor 

(H2O). The SCR utilizes a catalyst to increase the NOx removal efficiency, which allows the process to occur at lower 

temperatures.This control applies to natural gas fired turbines with NOx emissions greater than 10 tons per year.

EPA 2006b, Pechan 

2001, EPA 1998e, EPA 

2002a, EPA 1993d

NonEGU 

Point

Combustion Turbines - 

Natural Gas

Selective Catalytic 

Reduction and Steam 

Injection

95

$3,226 for NOx<1 tpd 

and $1,348 for NOx>1 

tpd

This control is the selective catalytic reduction of NOx through add-on controls. SCR controls are post-combustion control 

technologies based on the chemical reduction of nitrogen oxides (NOx) into molecular nitrogen (N2) and water vapor 

(H2O). The SCR utilizes a catalyst to increase the NOx removal efficiency, which allows the process to occur at lower 

temperatures.This control applies to natural gas fired turbines with NOx emissions greater than 10 tons per year.

EPA 2006b, Pechan 

2001, EPA 1998e, EPA 

2002a, EPA 1993d
Point & NonPoint NOx

Menu of Control Measures

Updated 4/12/2012

Printed 8/6/2013 7 of 67

Sector Source Category Emission Reduction 

Measure Name Control Efficiency (%)* Cost Effectiveness (2006$/ton reduced)

Other pollutants 

controlled Description/Notes/Caveats References

NonEGU 

Point

Combustion Turbines - 

Natural Gas

Selective Catalytic 

Reduction and Water 

Injection

95

$4,382 for NOx<1 tpd 

and $1,814 for NOx>1 

tpd

This control is the selective catalytic reduction of NOx through add-on controls in combination with water injection. SCR 

controls are post-combustion control technologies based on the chemical reduction of nitrogen oxides (NOx) into 

molecular nitrogen (N2) and water vapor (H2O). The SCR utilizes a catalyst to increase the NOx removal efficiency, which 

allows the process to occur at lower temperatures. This control applies to natural gas-fired gas turbines with uncontrolled 

NOx emissions greater than 10 tons per year.

EPA 2006b, Pechan 

2001, EPA 1998e, EPA 

2002a, EPA 1993d

NonEGU 

Point

Combustion Turbines - 

Natural Gas Steam Injection 80 $1,669 for NOx<1 tpd 

and $802 for NOx>1 tpd

This control is the use of steam injection to reduce NOx emissions. Steam is injected into the gas turbine, reducing the 

temperatures in the NOx-forming regions. The steam can be injected into the fuel, the combustion air or directly into the 

combustion chamber. This control applies to natural gas-fired gas turbines with uncontrolled NOx emissions greater than 

10 tons per year.

EPA 2006b, Pechan 

2001, EPA 1998e, ERG 

2000, EPA 1993d

NonEGU 

Point

Combustion Turbines - 

Natural Gas Water Injection 76

$2,423 for NOx<1 tpd 

and $1,172 for NOx>1 

tpd

This control is the use of water injection to reduce NOx emissions. Water is injected into the gas turbine, reducing the 

temperatures in the NOx-forming regions. The water can be injected into the fuel, the combustion air or directly into the 

combustion chamber. This control applies to natural gas-fired gas turbines with uncontrolled NOx emissions greater than 

10 tons per year.

EPA 2006b, Pechan 

2001, EPA 1998e, ERG 

2000, EPA 1993d

NonEGU 

Point

Combustion Turbines - 

Oil or Jet Fuel

Selective Catalytic 

Reduction and Water 

Injection

90

$3,691 for NOx<1 tpd 

and $1,621 for NOx>1 

tpd

This control is the selective catalytic reduction of NOx through add-on controls in combination with water injection. SCR 

controls are post-combustion control technologies based on the chemical reduction of nitrogen oxides (NOx) into 

molecular nitrogen (N2) and water vapor (H2O). The SCR utilizes a catalyst to increase the NOx removal efficiency, which 

allows the process to occur at lower temperatures. This control applies to oil-fired and jet fuel-fired turbines with 

uncontrolled NOx emissions greater than 10 tons per year.

EPA 2006b, Pechan 

2001, EPA 1998e, EPA 

2002a, EPA 1993d

NonEGU 

Point

Combustion Turbines - 

Oil or Jet Fuel Water Injection 68

$2,070 for NOx<1 tpd 

and $1,043 for NOx>1 

tpd

This control is the use of water injection to reduce NOx emissions. Water is injected into the gas turbine, reducing the 

temperatures in the NOx-forming regions. The water can be injected into the fuel, the combustion air or directly into the 

combustion chamber. This control applies to oil turbines and jet fuel-fired turbines with uncontrolled NOx emissions 

greater than 10 tons per year.

EPA 2006b, Pechan 

2001, EPA 1998e, ERG 

2000, EPA 1993d

NonEGU 

Point

Commercial/ 

Institutional or Industrial 

Incinerators

Selective Non-Catalytic 

Reduction 45 $1,814

 This control is the reduction of NOx emission through selective non-catalytic reduction add-on controls. SNCR controls 

are post-combustion control technologies based on the chemical reduction of nitrogen oxides (NOx) into molecular 

nitrogen (N2) and water vapor (H2O). This control applies to commercial/institutional incinerators and industrial 

incinerators with uncontrolled NOx emissions greater than 10 tons per year.

EPA 2006b, Pechan 

2001, EPA 1998e, EPA 

2002a, EPA 1994i

NonEGU 

Point

Fluid Catalytic Cracking 

Units - Cracking Unit

Low NOx Burner and 

Flue Gas Recirculation 55

$5,120 for NOx<1 tpd 

and $3,964 for NOx>1 

tpd

This control is the use of low NOx burner (LNB) technology and flue gas recirculation (FGR) to reduce NOx emissions. 

LNBs reduce the amount of NOx created from reaction between fuel nitrogen and oxygen by lowering the temperature of 

one combustion zone and reducing the amount of oxygen available in another. This control is applicable to fluid catalytic 

cracking units with uncontrolled NOx emissions greater than 10 tons per year.

EPA 2006b, EPA 

1998e, EPA 2002a, 

EPA 1993c

NonEGU 

Point

Fluid Catalytic Cracking 

Units - Cracking Unit

Selective Catalytic 

Reduction 90 $4,167

This control is the selective catalytic reduction of NOx through add-on controls. SCR controls are post-combustion control 

technologies based on the chemical reduction of nitrogen oxides (NOx) into molecular nitrogen (N2) and water vapor 

(H2O). The SCR utilizes a catalyst to increase the NOx removal efficiency, which allows the process to occur at lower 

temperatures.This control is applicable to fluid catalytic cracking units with uncontrolled NOx emissions greater than 10 

tons per year.

EPA 2007b

NonEGU 

Point Furnaces - Natural Gas Low NOx Burner 50 $915

This control is the use of low NOx burner (LNB) technology to reduce NOx emissions. LNBs reduce the amount of NOx 

created from reaction between fuel nitrogen and oxygen by lowering the temperature of one combustion zone and 

reducing the amount of oxygen available in another. This control applies to natural gas fired equipment with uncontrolled 

NOx emissions greater than 10 tons per year.

EPA 2006b, EPA 

1998e, EPA 2002a, 

EPA 1994e

NonEGU 

Point

Glass Manufacturing - 

Container Cullet Preheat 25 $1,509 This control is the use of cullet preheat technologies to reduce NOx emissions from glass manufacturing operations. This 

control is applicable to container glass manufacturing operations.

EPA 2006b, EPA 

1998e, EPA 1994f

NonEGU 

Point

Glass Manufacturing - 

Container Electric Boost 10 $11,475 This control is the use of electric boost technologies to reduce NOx emissions from glass manufacturing operations. This 

control applies to container glass manufacturing operations.

EPA 2006b, EPA 

1998e, EPA 1994f

NonEGU 

Point

Glass Manufacturing - 

Container OXY-Firing 85 $7,367

This control is the use of Oxy-firing in container glass manufacturing furnaces to reduce NOx emissions. Oxygen 

enrichment refers to the substitution of oxygen for nitrogen in the combustion air used to burn the fuel in a glass furnace. 

Oxygen enrichment above 90 percent is sometimes called "oxy-firing."

EPA 2006b

NonEGU 

Point

Glass Manufacturing - 

Container

Selective Catalytic 

Reduction 75 $3,531

This control is the selective catalytic reduction of NOx through add-on controls. SCR controls are post-combustion control 

technologies based on the chemical reduction of nitrogen oxides (NOx) into molecular nitrogen (N2) and water vapor 

(H2O). The SCR utilizes a catalyst to increase the NOx removal efficiency, which allows the process to occur at lower 

temperatures. This control applies to glass-container manufacturing processes with uncontrolled NOx emissions greater 

than 10 tons per year.

EPA 2006b, Pechan 

2001, EPA 1998e, EPA 

2002a, EPA 1994f
Point & NonPoint NOx

Menu of Control Measures

Updated 4/12/2012

Printed 8/6/2013 8 of 67

Sector Source Category Emission Reduction 

Measure Name Control Efficiency (%)* Cost Effectiveness (2006$/ton reduced)

Other pollutants 

controlled Description/Notes/Caveats References

NonEGU 

Point

Glass Manufacturing - 

Container

Selective Non-Catalytic 

Reduction 40 $2,841

This control is the reduction of NOx emission through selective non-catalytic reduction add-on controls. SNCR controls 

are post-combustion control technologies based on the chemical reduction of nitrogen oxides (NOx) into molecular 

nitrogen (N2) and water vapor (H2O). This control applies to glass-container manufacturing operations with uncontrolled 

NOx emissions greater than 10 tons per year.

EPA 2006b, Pechan 

2001, EPA 1998e, EPA 

2002a, EPA 1994f, EPA 

1993c

NonEGU 

Point

Glass Manufacturing - 

Container or Flat Glass Low NOx Burner 40 $1,123

This control is the use of low NOx burner (LNB) technology to reduce NOx emissions. LNBs reduce the amount of NOx 

created from reaction between fuel nitrogen and oxygen by lowering the temperature of one combustion zone and 

reducing the amount of oxygen available in another. This control applies to flat glass and container glass manufacturing 

operations with uncontrolled NOx emissions greater than 10 tons per year.

EPA 2006b, EPA 

1998e, EPA 2002a, 

EPA 1994f

NonEGU 

Point

Glass Manufacturing - 

Flat Electric Boost 10 $3,724 This control is the use of electric boost technologies to reduce NOx emissions from glass manufacturing operations. This 

control applies to flat glass manufacturing operations.

EPA 2006b, EPA 

1998e, EPA 1994f

NonEGU 

Point

Glass Manufacturing - 

Flat OXY-Firing 85 $3,049

This control is the use of Oxy-firing in flat glass manufacturing furnaces to reduce NOx emissions. Oxygen enrichment 

refers to the substitution of oxygen for nitrogen in the combustion air used to burn the fuel in a glass furnace. Oxygen 

enrichment above 90 percent is sometimes called "oxy-firing"

EPA 2006b

NonEGU 

Point

Glass Manufacturing - 

Flat

Selective Catalytic 

Reduction 75

$5,409 for NOx<1 tpd 

and $1,140 for NOx>1 

tpd

This control is the selective catalytic reduction of NOx through add-on controls. SCR controls are post-combustion control 

technologies based on the chemical reduction of nitrogen oxides (NOx) into molecular nitrogen (N2) and water vapor 

(H2O). The SCR utilizes a catalyst to increase the NOx removal efficiency, which allows the process to occur at lower 

temperatures. This control applies to flat-glass manufacturing operations with uncontrolled NOx emissions greater than 10 

tons per year.

EPA 2006b, Pechan 

2001, EPA 1998e, EPA 

2002a, EPA 1994f, EPA 

1993c

NonEGU 

Point

Glass Manufacturing - 

Flat

Selective Non-Catalytic 

Reduction 40 $1,188

This control is the reduction of NOx emission through selective non-catalytic reduction add-on controls. SNCR controls 

are post-combustion control technologies based on the chemical reduction of nitrogen oxides (NOx) into molecular 

nitrogen (N2) and water vapor (H2O). This control applies to flat-glass manufacturing operations with uncontrolled NOx 

emissions greater than 10 tons per year.

EPA 2006b, Pechan 

2001, EPA 1998e, EPA 

2002a, EPA 1994f, EPA 

1993c

NonEGU 

Point

Glass Manufacturing - 

General OXY-Firing 85 $5,155

This control is the use of Oxy-firing in glass manufacturing furnaces to reduce NOx emissions. Oxygen enrichment refers 

to the substitution of oxygen for nitrogen in the combustion air used to burn the fuel in a glass furnace. Oxygen 

enrichment above 90 percent is sometimes called "oxy-firing."

EPA 2007b

NonEGU 

Point

Glass Manufacturing - 

Pressed Cullet Preheat 25 $1,300 This control is the use of cullet preheat technologies to reduce NOx emissions from glass manufacturing operations. This 

control is applicable to pressed glass manufacturing operations.

EPA 2006b, EPA 

1998e, EPA 1994f

NonEGU 

Point

Glass Manufacturing - 

Pressed Electric Boost 10

$3,724 for NOx<1 tpd 

and $14,059 for NOx>1 

tpd

This control is the use of electric boost technologies to reduce NOx emissions from glass manufacturing operations. This 

control applies to pressed glass manufacturing operations.

EPA 2006b, EPA 

1998e, EPA 1994f

NonEGU 

Point

Glass Manufacturing - 

Pressed Low NOx Burner 40 $2,407

This control is the use of low NOx burner (LNB) technology to reduce NOx emissions. LNBs reduce the amount of NOx 

created from reaction between fuel nitrogen and oxygen by lowering the temperature of one combustion zone and 

reducing the amount of oxygen available in another. This control is applicable to pressed glass manufactuing operations 

with uncontrolled NOx emissions greater than 10 tons per year.

EPA 1998e, EPA 

2002a, EPA 1994f

NonEGU 

Point

Glass Manufacturing - 

Pressed OXY-Firing 85 $6,259

This control is the use of Oxy-firing in pressed glass manufacturing furnaces to reduce NOx emissions. Oxygen 

enrichment refers to the substitution of oxygen for nitrogen in the combustion air used to burn the fuel in a glass furnace. 

Oxygen enrichment above 90 percent is sometimes called "oxy-firing"

EPA 2006b

NonEGU 

Point

Glass Manufacturing - 

Pressed

Selective Catalytic 

Reduction 75 $4,061

This control is the selective catalytic reduction of NOx through add-on controls. SCR controls are post-combustion control 

technologies based on the chemical reduction of nitrogen oxides (NOx) into molecular nitrogen (N2) and water vapor 

(H2O). The SCR utilizes a catalyst to increase the NOx removal efficiency, which allows the process to occur at lower 

temperatures. This control applies to pressed-glass manufacturing operations, and uncontrolled NOx emissions greater 

than 10 tons per year.

EPA 2006b, Pechan 

2001, EPA 1998e, EPA 

2002a, EPA 1994f, EPA 

1993c

NonEGU 

Point

Glass Manufacturing - 

Pressed

Selective Non-Catalytic 

Reduction 40 $2,632

This control is the reduction of NOx emission through selective non-catalytic reduction add-on controls. SNCR controls 

are post-combustion control technologies based on the chemical reduction of nitrogen oxides (NOx) into molecular 

nitrogen (N2) and water vapor (H2O). This control applies to pressed-glass manufacturing operations with uncontrolled 

NOx emissions greater than 10 tons per year.

EPA 2006b, Pechan 

2001, EPA 1998e, EPA 

2002a, EPA 1994f, EPA 

1993c

NonEGU 

Point Industrial Incinerators Selective Catalytic 

Reduction 90

Unknown, depends on 

the exact source. See 

description.

This control applies to industrial incinerators with uncontrolled NOx emissions greater than 10 tons per year. Although 

listed here as "industrial incinerators", this source is too vague to provide a reasonnable cost effectiveness estimate. It is 

required to more accurately identify the emissions sources to make sure that SCR is an adequate control and assess 

cost. Selective catalytic reduction of NOx through add-on controls is a post-combustion control technology based on the 

chemical reduction of nitrogen oxides (NOx) into molecular nitrogen (N2) and water vapor (H2O). The SCR utilizes a 

catalyst to increase the NOx removal efficiency, which allows the process to occur at lower temperatures. 

EPA 2007b

NonEGU 

Point

Industrial Natural Gas 

Internal Combustion 

Engines - 2cycle (lean)

Low Emission 

Combustion 87 $628 This control is the application of low emission combustion firing techniques to natural gas-fired lean burn internal 

conbustion engines. EPA 2007c
Point & NonPoint NOx

Menu of Control Measures

Updated 4/12/2012

Printed 8/6/2013 9 of 67

Sector Source Category Emission Reduction 

Measure Name Control Efficiency (%)* Cost Effectiveness (2006$/ton reduced)

Other pollutants 

controlled Description/Notes/Caveats References

NonEGU 

Point

Industrial Natural Gas 

Internal Combustion 

Engines - 4cycle (rich)

Non-Selective Catalytic 

Reduction 90 $509

NSCR is achieved by placing a catalyst in the exhaust stream of the engine. The exhaust passes over the catalyst, 

usually a noble metal (platinum, rhodium or palladium) which reduces the reactants to N2, CO2 and H20 (NJDEP, 2003). 

Typical exhaust temperatures for effective removal of NOx are 800-1200 degrees Fahrenheit. An oxidation catalyst using 

additional air can be installed downstream of the NSCR catalyst for additional CO and VOC control. This includes 4-cycle 

naturally aspirated engines and some 4-cycle turbocharged engines. Engines operating with NSCR require air/fuel control 

to maintain high reduction effectiveness.

EPA 2007c

NonEGU 

Point

Industrial/ Commercial/ 

Institutional Boilers - 

Bagasse

Selective Non-Catalytic 

Reduction - Urea 55

$2,311 for NOx<1 tpd 

and $1,493 for NOx>1 

tpd

This control is the reduction of NOx emission through urea based selective non-catalytic reduction add-on controls. SNCR 

controls are post-combustion control technologies based on the chemical reduction of nitrogen oxides (NOx) into 

molecular nitrogen (N2) and water vapor (H2O). This control applies to bagasse IC boilers with uncontrolled NOx 

emissions greater than 10 tons per year.

EPA 2006b

NonEGU 

Point

Industrial/ Commercial/ 

Institutional Boilers - 

Coal

Selective Catalytic 

Reduction 80 $2,373 for NOx<1 tpd 

and $971 for NOx>1 tpd

This control is the selective catalytic reduction of NOx through add-on controls. SCR controls are post-combustion control 

technologies based on the chemical reduction of nitrogen oxides (NOx) into molecular nitrogen (N2) and water vapor 

(H2O). The SCR utilizes a catalyst to increase the NOx removal efficiency, which allows the process to occur at lower 

temperatures. This control applies to coal ICI boilers with NOx emissions greater than 10 tons per year.

EPA 2003b, EPA 1998e

NonEGU 

Point

Industrial/ Commercial/ 

Institutional Boilers - 

Coal

Selective Non-Catalytic 

Reduction 40

$2,297 for NOx<1 tpd 

and $1,424 for NOx>1 

tpd

This control is the reduction of NOx emission through selective non-catalytic reduction add-on controls. SNCR controls 

are post-combustion control technologies based on the chemical reduction of nitrogen oxides (NOx) into molecular 

nitrogen (N2) and water vapor (H2O). This control applies to coal IC boilers with uncontrolled NOx emissions greater than 

10 tons per year.

EPA 2003b, Pechan 

2006

NonEGU 

Point

Industrial/ Commercial/ 

Institutional Boilers - 

Coal or Petroleum Coke

Low NOx Burner 50

Cost effectiveness 

varies by boiler size. 

- 50 MMBTU/hr: 

$3,140 - $12,187.

- 100 MMBTU/hr:

$1,526 - $6,093.

- 250 MMBTU/hr: 

$610 - $2,435.

- 750 MMBTU/hr:

$203 813

This control is the use of low NOx burner (LNB) technology to reduce NOx emissions. LNBs reduce the amount of NOx 

created from reaction between fuel nitrogen and oxygen by lowering the temperature of one combustion zone and 

reducing the amount of oxygen available in another. This control is applicable to coal/wall fired ICI boilers and Petroleum 

coke fired ICI boilers with uncontrolled NOx emissions greater than 10 tons per year. Cost estimates are from the OTC / 

LADCO Workgroup (OTC / LADCO Control Cost Subgroup), for a single burner (for a 66% capacity factor at 8760 

hours/year), and are based on a methodology similar to EPA’s methodology provided in the EPA document “Alternative 

Control Techniques Document – NOx Emissions from Industrial/Commercial/Institutional (ICI) Boilers”.

EPA 2006b, Pechan 

2001, EPA 1998e, EPA 

2002a, EPA 1994g, 

OTC/LADCO 2010

NonEGU 

Point

Industrial/ Commercial/ 

Institutional Boilers - 

Coal or Petroleum Coke 

- Wall Fired

Selective Non-Catalytic 

Reduction 40

Cost effectiveness 

varies by boiler size. 

- 50 MMBTU/hr: 

$7,052 - $9,712.

- 100 MMBTU/hr:

$4,167 - $5,497.

- 250 MMBTU/hr: 

$2,426 - $2,964.

- 750 MMBTU/hr:

$1 653 1 839

This control is the reduction of NOx emission through selective non-catalytic reduction add-on controls to wall fired (coal) 

IC boilers. SNCR controls are post-combustion control technologies based on the chemical reduction of nitrogen oxides 

(NOx) into molecular nitrogen (N2) and water vapor (H2O). This control applies to coal-fired and petroleum coke-fired IC 

boilers with uncontrolled NOx emissions greater than 10 tons per year. Cost estimates are from the OTC / LADCO 

Workgroup (OTC / LADCO Control Cost Subgroup), for a single burner (for a 66% capacity factor at 8760 hours/year), 

and are based on a methodology similar to EPA’s methodology provided in the EPA document “Alternative Control 

Techniques Document – NOx Emissions from Industrial/Commercial/Institutional (ICI) Boilers”.

EPA 2006b, Pechan 

2001, EPA 1998e, EPA 

2002a, EPA 1994g, 

OTC/LADCO 2010

NonEGU 

Point

Industrial/ Commercial/ 

Institutional Boilers - 

Coal/ Bituminous

Low NOx Burner and 

Over Fire Air 51 $1,373 for NOx<1 tpd 

and $434 for NOx>1 tpd

This control is the use of low NOx burner (LNB) technology and Over Fire Air (OFA) to reduce NOx emissions. LNBs 

reduce the amount of NOx created from reaction between fuel nitrogen and oxygen by lowering the temperature of one 

combustion zone and reducing the amount of oxygen available in another. This control applies to bituminous coal 

Industrial/Commercial/Institutional (ICI) boilers.

EPA 2003b, Pechan 

2006

NonEGU 

Point

Industrial/ Commercial/ 

Institutional Boilers - 

Coal/ Subbituminous

Low NOx Burner 51

Cost effectiveness 

varies by boiler size. 

- 50 MMBTU/hr: 

$3,140 - $12,187.

- 100 MMBTU/hr:

$1,526 - $6,093.

- 250 MMBTU/hr: 

$610 - $2,435.

- 750 MMBTU/hr:

$203 813

This control is the use of low NOx burner (LNB) technology to reduce NOx emissions. LNBs reduce the amount of NOx 

created from reaction between fuel nitrogen and oxygen by lowering the temperature of one combustion zone and 

reducing the amount of oxygen available in another. This control is applicable to subbituminous coal 

industrial/commerial/institutional boilers. Cost estimates are from the OTC / LADCO Workgroup (OTC / LADCO Control 

Cost Subgroup), for a single burner (for a 66% capacity factor at 8760 hours/year), and are based on a methodology 

similar to EPA’s methodology provided in the EPA document “Alternative Control Techniques Document – NOx Emissions 

from Industrial/Commercial/Institutional (ICI) Boilers”.

EPA 2003b, Pechan 

2006, OTC/LADCO 

2010

NonEGU 

Point

Industrial/ Commercial/ 

Institutional Boilers - 

Coal/ Cyclone

Coal Reburn 50 $2,520 for NOx<1 tpd 

and $481 for NOx>1 tpd This control reduces NOx emissions through coal reburn. This control is applicable to coal/cyclone ICI boilers.

EPA 2006b, Pechan 

2001, EPA 1998e, EPA 

1994g, Cadmus 1995
Point & NonPoint NOx

Menu of Control Measures

Updated 4/12/2012

Printed 8/6/2013 10 of 67

Sector Source Category Emission Reduction 

Measure Name Control Efficiency (%)* Cost Effectiveness (2006$/ton reduced)

Other pollutants 

controlled Description/Notes/Caveats References

NonEGU 

Point

Industrial/ Commercial/ 

Institutional Boilers - 

Coal/ Cyclone

Natural Gas Reburn 55 $2,520 for NOx<1 tpd 

and $481 for NOx>1 tpd

Natural gas reburning (NGR) involves add-on controls to reduce NOx emissions. NGR is a combustion control technology 

in which part of the main fuel heat input is diverted to locations above the main burners, called the reburn zone. As flue 

gas passes through the reburn zone, a portion of the NOx formed in the main combustion zone is reduced by 

hydrocarbon radicals and converted to molecular nitrogen (N2). This control applies to coal/cyclone ICI boilers with 

uncontrolled NOx emissions greater than 10 tons per year.

EPA 2006b, Pechan 

2001, EPA 1998e, EPA 

2002a, ERG 2000, EPA 

1994g

NonEGU 

Point

Industrial/ Commercial/ 

Institutional Boilers - 

Coal/ Cyclone

Selective Catalytic 

Reduction 90

Cost effectiveness is 

variable and based on 

plant size & heat rate: 

total capital cost of 

$145.61/kW for 

1000MW & 

9,000Btu/kWh to 

$255.57/kW for 100MW 

& 11,000Btu/kWh; fixed 

O&M costs of $0.40 per 

kW per year for 

1000MW to $2.48 per 

kW per year for 100MW 

(do not depend on heat 

rate); variable O&M 

costs of $1.14 mills per 

kWh for 9,000Btu/kWh 

to 1.32 mills per kWh 

for 11,000Btu/kWh.

This control is the selective catalytic reduction of NOx through add-on controls. SCR controls are post-combustion control 

technologies based on the chemical reduction of nitrogen oxides (NOx) into molecular nitrogen (N2) and water vapor 

(H2O). The SCR utilizes a catalyst to increase the NOx removal efficiency, which allows the process to occur at lower 

temperatures. This control applies to coal/cyclone ICI boilers with nameplate capacity greater than 25 MW.

EPA 2006b, Pechan 

2001, EPA 1998e, EPA 

2002a, EPA 1994g, 

EPA 2010a

NonEGU 

Point

Industrial/ Commercial/ 

Institutional Boilers - 

Coal/ Cyclone

Selective Non-Catalytic 

Reduction 35

$1,348 for NOx<1 tpd 

and $1,123 for NOx>1 

tpd

This control is the reduction of NOx emission through selective non-catalytic reduction add-on controls. SNCR controls 

are post-combustion control technologies based on the chemical reduction of nitrogen oxides (NOx) into molecular 

nitrogen (N2) and water vapor (H2O). This control applies to coal/cyclone IC boilers with uncontrolled NOx emissions 

greater than 10 tons per year.

EPA 2006b, Pechan 

2001, EPA 1998e, EPA 

2002a, EPA 1994g

NonEGU 

Point

Industrial/ Commercial/ 

Institutional Boilers - 

Coal/ Fluidized Bed 

Combustion

Selective Catalytic 

Reduction 90 $1,397

This control is the selective catalytic reduction of NOx through add-on controls. SCR controls are post-combustion control 

technologies based on the chemical reduction of nitrogen oxides (NOx) into molecular nitrogen (N2) and water vapor 

(H2O). The SCR utilizes a catalyst to increase the NOx removal efficiency, which allows the process to occur at lower 

temperatures. This control applies to fluidized bed combustion coal ICI boilers.

EPA 2007b

NonEGU 

Point

Industrial/ Commercial/ 

Institutional Boilers - 

Coal/ Fluidized Bed 

Combustion

Selective Non-Catalytic 

Reduction - Urea 75

$1,444 for NOx<1 tpd 

and $1,075 for NOx>1 

tpd

This control is the reduction of NOx emission through urea based selective non-catalytic reduction add-on controls. SNCR 

controls are post-combustion control technologies based on the chemical reduction of nitrogen oxides (NOx) into 

molecular nitrogen (N2) and water vapor (H2O). This control applies to coal-fired/fluidized bed combustion IC boilers with 

uncontrolled NOx emissions greater than 10 tons per year.

EPA 2006b, Pechan 

2001, EPA 1998e, EPA 

2002a, EPA 1994g

NonEGU 

Point

Industrial/ Commercial/ 

Institutional Boilers - 

Coal/ Stoker

Selective Catalytic 

Reduction 90 $3,051

This control is the selective catalytic reduction of NOx through add-on controls. SCR controls are post-combustion control 

technologies based on the chemical reduction of nitrogen oxides (NOx) into molecular nitrogen (N2) and water vapor 

(H2O). The SCR utilizes a catalyst to increase the NOx removal efficiency, which allows the process to occur at lower 

temperatures. This control applies to coal/stoker IC boilers with uncontrolled NOx emissions greater than 10 tons per 

year.

EPA 2007b

NonEGU 

Point

Industrial/ Commercial/ 

Institutional Boilers - 

Coal/ Stoker

Selective Non-Catalytic 

Reduction 40

$1,629 for NOx<1 tpd 

and $1,311 for NOx>1 

tpd

This control is the reduction of NOx emission through selective non-catalytic reduction add-on controls to coal/stoker IC 

boilers. SNCR controls are post-combustion control technologies based on the chemical reduction of nitrogen oxides 

(NOx) into molecular nitrogen (N2) and water vapor (H2O). This control applies to coal/stoker IC boilers with uncontrolled 

NOx emissions greater than 10 tons per year.

EPA 2006b, Pechan 

2001, EPA 1998e, EPA 

2002a, EPA 1994g

NonEGU 

Point

Industrial/ Commercial/ 

Institutional Boilers - 

Coal/ Subbituminous

Low NOx Burner and 

Over Fire Air 65 $1,077 for NOx<1 tpd 

and $339 for NOx>1 tpd

This control is the use of low NOx burner (LNB) technology and Over Fire Air (OFA) to reduce NOx emissions. LNBs 

reduce the amount of NOx created from reaction between fuel nitrogen and oxygen by lowering the temperature of one 

combustion zone and reducing the amount of oxygen available in another. This control applies to subbituminous coal 

Industrial/Commercial/Institutional (ICI) boilers.

EPA 2003b, Pechan 

2006
Point & NonPoint NOx

Menu of Control Measures

Updated 4/12/2012

Printed 8/6/2013 11 of 67

Sector Source Category Emission Reduction 

Measure Name Control Efficiency (%)* Cost Effectiveness (2006$/ton reduced)

Other pollutants 

controlled Description/Notes/Caveats References

NonEGU 

Point

Industrial/ Commercial/ 

Institutional Boilers - 

Coal/ Wall

Selective Catalytic 

Reduction 90

Cost effectiveness is 

variable and based on 

plant size & heat rate: 

total capital cost of 

$145.61/kW for 

1000MW & 

9,000Btu/kWh to 

$255.57/kW for 100MW 

& 11,000Btu/kWh; fixed 

O&M costs of $0.40 per 

kW per year for 

1000MW to $2.48 per 

kW per year for 100MW 

(do not depend on heat 

rate); variable O&M 

costs of $1.14 mills per 

kWh for 9,000Btu/kWh 

to 1.32 mills per kWh 

for 11,000Btu/kWh.

This control is the selective catalytic reduction of NOx through add-on controls. SCR controls are post-combustion control 

technologies based on the chemical reduction of nitrogen oxides (NOx) into molecular nitrogen (N2) and water vapor 

(H2O). The SCR utilizes a catalyst to increase the NOx removal efficiency, which allows the process to occur at lower 

temperatures.This control applies to coal/wall IC boilers with nameplate capacity greater than 25 MW.

EPA 2006b, Pechan 

2001, EPA 1998e, EPA 

2002a, EPA 1994g, 

EPA 2010a

NonEGU 

Point

Industrial/ Commercial/ 

Institutional Boilers - 

Distillate Oil

Selective Catalytic 

Reduction 80

Cost effectiveness is 

variable and based on 

plant size. For a 25MW 

plant, capital costs are 

$74.29 per kW, fixed 

O&M costs are $1.07 

per kW per year. 

Variable O&M costs are 

0.12 mills per kWh (do 

not depend on plant 

size). Scaling factor for 

plants between 25MW 

and 500MW (Capital 

Cost and Fixed O&M 

only) = 

(200/capacity)^(0.35). 

After 500MW, costs 

This control is the selective catalytic reduction of NOx through add-on controls. SCR controls are post-combustion control 

technologies based on the chemical reduction of nitrogen oxides (NOx) into molecular nitrogen (N2) and water vapor 

(H2O). The SCR utilizes a catalyst to increase the NOx removal efficiency, which allows the process to occur at lower 

temperatures. This control applies to distillate oil-fired ICI boilers with nameplate capacity greater than 25 MW.

EPA 2006b, EPA 

1998e, EPA 2002a, 

EPA 2007d, Sorrels 

2007, EPA 2010a

NonEGU 

Point

Industrial/ Commercial/ 

Institutional Boilers - 

Distillate Oil or LPG

Low NOx Burner 50

Cost effectiveness 

varies by boiler size. 

- 50 MMBTU/hr: 

$10,661 - $42,644.

- 100 MMBTU/hr:

$5,340 - $21,322.

- 250 MMBTU/hr: 

$2,142 - $8,529.

- 750 MMBTU/hr:

$203 813

This control is the use of low NOx burner (LNB) technology to reduce NOx emissions. LNBs reduce the amount of NOx 

created from reaction between fuel nitrogen and oxygen by lowering the temperature of one combustion zone and 

reducing the amount of oxygen available in another. This control is applicable to Oil and LPG ICI boilers with uncontrolled 

NOx emissions greater than 10 tons per year. Cost estimates are from the OTC / LADCO Workgroup (OTC / LADCO 

Control Cost Subgroup), for a single burner (for a 66% capacity factor at 8760 hours/year), and are based on a 

methodology similar to EPA’s methodology provided in the EPA document “Alternative Control Techniques Document – 

NOx Emissions from Industrial/Commercial/Institutional (ICI) Boilers”.

EPA 2006b, Pechan 

2001, EPA 1998e, EPA 

2002a, EPA 1994g, 

OTC/LADCO 2010

NonEGU 

Point

Industrial/ Commercial/ 

Institutional Boilers - 

Distillate Oil or LPG

Low NOx Burner and 

Flue Gas Recirculation 60

$3,996 for NOx<1 tpd 

and $1,220 for NOx>1 

tpd

This control is the use of low NOx burner (LNB) technology and flue gas recirculation (FGR) to reduce NOx emissions. 

LNBs reduce the amount of NOx created from reaction between fuel nitrogen and oxygen by lowering the temperature of 

one combustion zone and reducing the amount of oxygen available in another. This control is applicable to distillate oilfired ICI boilers and LPG-fired ICI Boilers with uncontrolled NOx emissions greater than 10 tons per year.

EPA 2006b, Pechan 

2001, EPA 1998e, EPA 

2002a, EPA 1993c

NonEGU 

Point

Industrial/ Commercial/ 

Institutional Boilers - 

Distillate Oil or LPG

Selective Non-Catalytic 

Reduction 50

$7,447 for NOx<1 tpd 

and $3,033 for NOx>1 

tpd

This control is the reduction of NOx emission through selective non-catalytic reduction add-on controls. SNCR controls 

are post-combustion control technologies based on the chemical reduction of nitrogen oxides (NOx) into molecular 

nitrogen (N2) and water vapor (H2O). This control applies to distillate oil and LPG-fired IC boilers with uncontrolled NOx 

emissions greater than 10 tons per year.

EPA 2006b, Pechan 

2001, EPA 1998e, EPA 

2002a, EPA 1994g

NonEGU 

Point

Industrial/ Commercial/ 

Institutional Boilers - 

Gas

Low NOx Burner and 

Flue Gas Recirculation 

+ Over Fire Air

80 $1,416 for NOx<1 tpd 

and $408 for NOx>1 tpd

This control is the use of low NOx burner (LNB) technology , flue gas recirculation (FGR), and over fire air (OFA) to 

reduce NOx emissions. LNBs reduce the amount of NOx created from reaction between fuel nitrogen and oxygen by 

lowering the temperature of one combustion zone and reducing the amount of oxygen available in another. This control 

applies to gas Industrial/Commercial/Institutional (ICI) boilers.

EPA 2003b, EPA 1998e
Point & NonPoint NOx

Menu of Control Measures

Updated 4/12/2012

Printed 8/6/2013 12 of 67

Sector Source Category Emission Reduction 

Measure Name Control Efficiency (%)* Cost Effectiveness (2006$/ton reduced)

Other pollutants 

controlled Description/Notes/Caveats References

NonEGU 

Point

Industrial/ Commercial/ 

Institutional Boilers - 

Gas

Low NOx Burner and 

Over Fire Air 60 $1,166 for NOx<1 tpd 

and $310 for NOx>1 tpd

This control is the use of low NOx burner (LNB) technology and Over Fire Air (OFA) to reduce NOx emissions. LNBs 

reduce the amount of NOx created from reaction between fuel nitrogen and oxygen by lowering the temperature of one 

combustion zone and reducing the amount of oxygen available in another. This control applies to gas 

Industrial/Commercial/Institutional (ICI) boilers.

EPA 2003b, Pechan 

2006

NonEGU 

Point

Industrial/ Commercial/ 

Institutional Boilers - 

Gas

Selective Catalytic 

Reduction 80

$3,250 for NOx<1 tpd 

and $1,093 for NOx>1 

tpd

This control is the selective catalytic reduction of NOx through add-on controls. SCR controls are post-combustion control 

technologies based on the chemical reduction of nitrogen oxides (NOx) into molecular nitrogen (N2) and water vapor 

(H2O). The SCR utilizes a catalyst to increase the NOx removal efficiency, which allows the process to occur at lower 

temperatures. This control applies to gas-fired ICI boilers with uncontrolled NOx emissions greater than 10 tons per year.

EPA 2003b, EPA 1998e

NonEGU 

Point

Industrial/ Commercial/ 

Institutional Boilers - 

Gas

Selective Non-Catalytic 

Reduction 40 $1,166 for NOx<1 tpd 

and $310 for NOx>1 tpd

This control is the reduction of NOx emission through selective non-catalytic reduction add-on controls. SNCR controls 

are post-combustion control technologies based on the chemical reduction of nitrogen oxides (NOx) into molecular 

nitrogen (N2) and water vapor (H2O). This control applies to natural gas fired IC boilers with uncontrolled NOx emissions 

greater than 10 tons per year.

EPA 2003b, Pechan 

2006

NonEGU 

Point

Industrial/ Commercial/ 

Institutional Boilers - 

Liquid Waste

Selective Catalytic 

Reduction 90 $1,890

This control is the selective catalytic reduction of NOx through add-on controls. SCR controls are post-combustion control 

technologies based on the chemical reduction of nitrogen oxides (NOx) into molecular nitrogen (N2) and water vapor 

(H2O). The SCR utilizes a catalyst to increase the NOx removal efficiency, which allows the process to occur at lower 

temperatures. This control applies to liquid waste ICI boilers with NOx emissions greater than 10 tons per year.

EPA 2007b

NonEGU 

Point

Industrial/ Commercial/ 

Institutional Boilers - 

LPG

Selective Catalytic 

Reduction 90 $4,747

This control is the selective catalytic reduction of NOx through add-on controls. SCR controls are post-combustion control 

technologies based on the chemical reduction of nitrogen oxides (NOx) into molecular nitrogen (N2) and water vapor 

(H2O). The SCR utilizes a catalyst to increase the NOx removal efficiency, which allows the process to occur at lower 

temperatures. This control applies to LPG ICI boilers with NOx emissions greater than 10 tons per year.

EPA 2007b

NonEGU 

Point

Industrial/ Commercial/ 

Institutional Boilers - 

Municipal Solid Waste/ 

Stoker

Selective Non-Catalytic 

Reduction - Urea 55

$2,712 for NOx<1 tpd 

and $2,006 for NOx>1 

tpd

This control is the reduction of NOx emission through urea based selective non-catalytic reduction add-on controls. SNCR 

controls are post-combustion control technologies based on the chemical reduction of nitrogen oxides (NOx) into 

molecular nitrogen (N2) and water vapor (H2O). This control applies to solid waste/stoker IC boilers with uncontrolled 

NOx emissions greater than 10 tons per year.

EPA 2006b, Pechan 

2001, EPA 1998e, EPA 

2002a, EPA 1994g

NonEGU 

Point

Industrial/ Commercial/ 

Institutional Boilers - 

Natural Gas

Selective Non-Catalytic 

Reduction 50

$6,211 for NOx<1 tpd 

and $2,520 for NOx>1 

tpd

This control is the reduction of NOx emission through selective non-catalytic reduction add-on controls. SNCR controls 

are post-combustion control technologies based on the chemical reduction of nitrogen oxides (NOx) into molecular 

nitrogen (N2) and water vapor (H2O). This control applies to natural gas fired IC boilers with uncontrolled NOx emissions 

greater than 10 tons per year.

EPA 2006b

NonEGU 

Point

Industrial/ Commercial/ 

Institutional Boilers - 

Natural Gas or Process 

Gas

Low NOx Burner 50

Cost effectiveness 

varies by boiler size. 

- 50 MMBTU/hr: 

$10,661 - $42,644.

- 100 MMBTU/hr:

$5,340 - $21,322.

- 250 MMBTU/hr: 

$2,142 - $8,529.

- 750 MMBTU/hr:

$203 813

This control is the use of low NOx burner (LNB) technology to reduce NOx emissions. LNBs reduce the amount of NOx 

created from reaction between fuel nitrogen and oxygen by lowering the temperature of one combustion zone and 

reducing the amount of oxygen available in another. This control is applicable to natural gas and process gas fired ICI 

boilers with uncontrolled NOx emissions greater than 10 tons per year. Cost estimates are from the OTC / LADCO 

Workgroup (OTC / LADCO Control Cost Subgroup), for a single burner (for a 66% capacity factor at 8760 hours/year), 

and are based on a methodology similar to EPA’s methodology provided in the EPA document “Alternative Control 

Techniques Document – NOx Emissions from Industrial/Commercial/Institutional (ICI) Boilers”.

EPA 2006b, Pechan 

2001, EPA 1998e, EPA 

2002a, EPA 1994g, 

OTC/LADCO 2010

NonEGU 

Point

Industrial/ Commercial/ 

Institutional Boilers - 

Natural Gas or Process 

Gas

Low NOx Burner and 

Flue Gas Recirculation 60 $4,109 for NOx<1 tpd 

and $947 for NOx>1 tpd

This control is the use of low NOx burner (LNB) technology and flue gas recirculation (FGR) to reduce NOx emissions. 

LNBs reduce the amount of NOx created from reaction between fuel nitrogen and oxygen by lowering the temperature of 

one combustion zone and reducing the amount of oxygen available in another. This control is applicable to natural gasfired and process gas-fired ICI boilers with uncontrolled NOx emissions greater than 10 tons per year.

EPA 2006b, Pechan 

2001, EPA 1998e, EPA 

2002a, EPA 1993c

NonEGU 

Point

Industrial/ Commercial/ 

Institutional Boilers - 

Natural Gas or Process 

Gas

Oxygen Trim and Water 

Injection 65 $1,091 for NOx<1 tpd 

and $514 for NOx>1 tpd

This control is the use of Oxygen Trim and Water Injection to reduce NOx emissions. Water is injected into the gas 

turbine, reducing the temperatures in the NOx-forming regions. The water can be injected into the fuel, the combustion air 

or directly into the combustion chamber. This control applies to natural gas-fired and process gas-fired ICI boilers with 

uncontrolled NOx emissions greater than 10 tons per year.

EPA 2006b, Pechan 

2001, EPA 1998e, EPA 

2002a, ERG 2000, EPA 

1994g
Point & NonPoint NOx

Menu of Control Measures

Updated 4/12/2012

Printed 8/6/2013 13 of 67

Sector Source Category Emission Reduction 

Measure Name Control Efficiency (%)* Cost Effectiveness (2006$/ton reduced)

Other pollutants 

controlled Description/Notes/Caveats References

NonEGU 

Point

Industrial/ Commercial/ 

Institutional Boilers - 

Natural Gas or Process 

Gas

Selective Catalytic 

Reduction 80

Cost effectiveness is 

variable and based on 

plant size. For a 25MW 

plant, capital costs are 

$74.29 per kW, fixed 

O&M costs are $1.07 

per kW per year. 

Variable O&M costs are 

0.12 mills per kWh (do 

not depend on plant 

size). Scaling factor for 

plants between 25MW 

and 500MW (Capital 

Cost and Fixed O&M 

only) = 

(200/capacity)^(0.35). 

After 500MW, costs 

This control is the selective catalytic reduction of NOx through add-on controls. SCR controls are post-combustion control 

technologies based on the chemical reduction of nitrogen oxides (NOx) into molecular nitrogen (N2) and water vapor 

(H2O). The SCR utilizes a catalyst to increase the NOx removal efficiency, which allows the process to occur at lower 

temperatures. This control applies to natural gas fired and process gas-fired ICI boilers nameplate capacity greater than 

25 MW.

EPA 2006b, EPA 

1998e, EPA 2002a, 

EPA 2007d, Sorrels 

2007, EPA 2010a

NonEGU 

Point

Industrial/ Commercial/ 

Institutional Boilers - Oil

Low NOx Burner and 

Over Fire Air 50 $1,166 for NOx<1 tpd 

and $339 for NOx>1 tpd

This control is the use of low NOx burner (LNB) technology and Over Fire Air (OFA) to reduce NOx emissions. LNBs 

reduce the amount of NOx created from reaction between fuel nitrogen and oxygen by lowering the temperature of one 

combustion zone and reducing the amount of oxygen available in another. This control applies to oil 

Industrial/Commercial/Institutional (ICI) boilers.

EPA 2003b, Pechan 

2006

NonEGU 

Point

Industrial/ Commercial/ 

Institutional Boilers - Oil

Selective Catalytic 

Reduction 80 $2,232 for NOx<1 tpd 

and $842 for NOx>1 tpd

This control is the selective catalytic reduction of NOx through add-on controls. SCR controls are post-combustion control 

technologies based on the chemical reduction of nitrogen oxides (NOx) into molecular nitrogen (N2) and water vapor 

(H2O). The SCR utilizes a catalyst to increase the NOx removal efficiency, which allows the process to occur at lower 

temperatures. This control applies to oil-fired ICI boilers with uncontrolled NOx emissions greater than 10 tons per year.

EPA 2003b, EPA 1998e

NonEGU 

Point

Industrial/ Commercial/ 

Institutional Boilers - Oil

Selective Non-Catalytic 

Reduction 40

$2,623 for NOx<1 tpd 

and $1,646 for NOx>1 

tpd

This control is the reduction of NOx emission through selective non-catalytic reduction add-on controls. SNCR controls 

are post-combustion control technologies based on the chemical reduction of nitrogen oxides (NOx) into molecular 

nitrogen (N2) and water vapor (H2O). This control applies to oil IC boilers with uncontrolled NOx emissions greater than 

10 tons per year.

EPA 2003b, Pechan 

2006

NonEGU 

Point

Industrial/ Commercial/ 

Institutional Boilers - 

Petroleum Coke

Selective Catalytic 

Reduction 90 $1,941

This control is the selective catalytic reduction of NOx through add-on controls. SCR controls are post-combustion control 

technologies based on the chemical reduction of nitrogen oxides (NOx) into molecular nitrogen (N2) and water vapor 

(H2O). The SCR utilizes a catalyst to increase the NOx removal efficiency, which allows the process to occur at lower 

temperatures. This control applies to coke ICI boilers with NOx emissions greater than 10 tons per year.

EPA 2007b

NonEGU 

Point

Industrial/ Commercial/ 

Institutional Boilers - 

Residual Oil or Liquid 

Waste

Low NOx Burner 50

Cost effectiveness 

varies by boiler size. 

- 50 MMBTU/hr: 

$5,340 - $21,322.

- 100 MMBTU/hr:

$2,670 - $10,661.

- 250 MMBTU/hr: 

$1,066 - $4,264.

- 750 MMBTU/hr:

$356 $1 418

This control is the use of low NOx burner (LNB) technology to reduce NOx emissions. LNBs reduce the amount of NOx 

created from reaction between fuel nitrogen and oxygen by lowering the temperature of one combustion zone and 

reducing the amount of oxygen available in another. This control is applicable to residual oil-fired ICI boilers and liquid 

waste fired ICI boilers with uncontrolled NOx emissions greater than 10 tons per year. Cost estimates are from the OTC / 

LADCO Workgroup (OTC / LADCO Control Cost Subgroup), for a single burner (for a 66% capacity factor at 8760 

hours/year), and are based on a methodology similar to EPA’s methodology provided in the EPA document “Alternative 

Control Techniques Document – NOx Emissions from Industrial/Commercial/Institutional (ICI) Boilers”.

EPA 2006b, Pechan 

2001, EPA 1998e, EPA 

2002a, EPA 1994g, 

OTC/LADCO 2010

NonEGU 

Point

Industrial/ Commercial/ 

Institutional Boilers - 

Residual Oil or Liquid 

Waste

Low NOx Burner and 

Flue Gas Recirculation 60 $1,798 for NOx<1 tpd 

and $626 for NOx>1 tpd

This control is the use of low NOx burner (LNB) technology and flue gas recirculation (FGR) to reduce NOx emissions. 

LNBs reduce the amount of NOx created from reaction between fuel nitrogen and oxygen by lowering the temperature of 

one combustion zone and reducing the amount of oxygen available in another. This control is applicable to residual oilfired and liquid waste-fired ICI boilers with uncontrolled NOx emissions greater than 10 tons per year.

EPA 2006b, Pechan 

2001, EPA 1998e, EPA 

2002a, EPA 1993c

NonEGU 

Point

Industrial/ Commercial/ 

Institutional Boilers - 

Residual Oil or Liquid 

Waste

Selective Non-Catalytic 

Reduction 50

$4,141 for NOx<1 tpd 

and $1,685 for NOx>1 

tpd

This control is the reduction of NOx emission through selective non-catalytic reduction add-on controls. SNCR controls 

are post-combustion control technologies based on the chemical reduction of nitrogen oxides (NOx) into molecular 

nitrogen (N2) and water vapor (H2O). This control applies to residual oil and liquid waste-fired IC boilers with uncontrolled 

NOx emissions greater than 10 tons per year.

EPA 2006b, Pechan 

2001, EPA 1998e, EPA 

2002a, EPA 1994g

NonEGU 

Point

Industrial/ Commercial/ 

Institutional Boilers - 

Wood/ Bark/ Fluidized 

Bed Combustion

Selective Non-Catalytic 

Reduction - Ammonia 55

$2,119 for NOx<1 tpd 

and $1,541 for NOx>1 

tpd

This control is the reduction of NOx emission through selective non-catalytic reduction add-on controls. SNCR controls 

are post-combustion control technologies based on the chemical reduction of nitrogen oxides (NOx) into molecular 

nitrogen (N2) and water vapor (H2O). This control applies to wood fired IC boilers with uncontrolled NOx emissions 

greater than 10 tons per year.

EPA 2006b

NonEGU 

Point

Industrial/ Commercial/ 

Institutional Boilers - 

Wood/ Bark/ Stoker

Selective Non-Catalytic 

Reduction - Urea 55

$2,311 for NOx<1 tpd 

and $1,493 for NOx>1 

tpd

This control is the reduction of NOx emission through urea based selective non-catalytic reduction add-on controls. SNCR 

controls are post-combustion control technologies based on the chemical reduction of nitrogen oxides (NOx) into 

molecular nitrogen (N2) and water vapor (H2O). This control applies to wood/bark fired IC boilers with uncontrolled NOx 

emissions greater than 10 tons per year.

EPA 2006b, Pechan 

2001, EPA 1998e, EPA 

2002a, EPA 1994g
Point & NonPoint NOx

Menu of Control Measures

Updated 4/12/2012

Printed 8/6/2013 14 of 67

Sector Source Category Emission Reduction 

Measure Name Control Efficiency (%)* Cost Effectiveness (2006$/ton reduced)

Other pollutants 

controlled Description/Notes/Caveats References

NonEGU 

Point

Industrial/ Commercial/ 

Institutional Boilers - 

Wood/ Bark/ Waste

Regenerative Selective 

Catalytic Reduction 75 $4,500 CO - 50%.

This control is the regenerative selective catalytic reduction of NOx through add-on controls. The RSCR control is a postcombustion control technology that combines a regenerative thermal oxidizer (RTO) (e.g., retention chamber burner) with 

conventional SCR technology (either anhydrous or aqueous ammonia can be used). The primary application of an RSCR 

system is the reduction of NOx emissions especially for tail-end, low temperature applications (where the flue gas is 

typically at 300-400°F). This control applies to industrial/commercial/institutional boilers fired with wood bark or waste.

NESCAUM 2008, WPA 

2008

NonEGU 

Point

Industrial/ Commercial/ 

Institutional Boilers - 

Wood/ Bark/ Waste

Selective Catalytic 

Reduction 90 $3,946

This control is the selective catalytic reduction of NOx through add-on controls. SCR controls are post-combustion control 

technologies based on the chemical reduction of nitrogen oxides (NOx) into molecular nitrogen (N2) and water vapor 

(H2O). The SCR utilizes a catalyst to increase the NOx removal efficiency, which allows the process to occur at lower 

temperatures. This control applies to industrial/commercial/institutional boilers fired with wood bark or waste.

EPA 2007b

NonEGU 

Point

In-Process - Bituminous 

Coal - Cement Kilns or 

Lime Kilns

Selective Catalytic 

Reduction 90 $2,554

This control is the selective catalytic reduction of NOx through add-on controls. SCR controls are post-combustion control 

technologies based on the chemical reduction of nitrogen oxides (NOx) into molecular nitrogen (N2) and water vapor 

(H2O). The SCR utilizes a catalyst to increase the NOx removal efficiency, which allows the process to occur at lower 

temperatures. This control applies to bituminous coal-fired cement kilns and coal-fired lime kilns with uncontrolled NOx 

emissions greater than 10 tons per year.

EPA 2007b

NonEGU 

Point

In-Process - Bituminous 

Coal - Cement Kilns or 

Lime Kilns

Selective Non-Catalytic 

Reduction - Urea 50 $928

This control is the reduction of NOx emission through selective non-catalytic reduction add-on controls. SNCR controls 

are post-combustion control technologies based on the chemical reduction of nitrogen oxides (NOx) into molecular 

nitrogen (N2) and water vapor (H2O). This control applies to bituminous coal-fired cement kilns and lime kilns with 

uncontrolled NOx emissions greater than 10 tons per year.

EPA 2006b, Pechan 

2001, EPA 1998e, EPA 

2002a, EPA 1994h

NonEGU 

Point

In-Process - Process 

Gas - Coke Oven Gas

Selective Catalytic 

Reduction 90 $7,679

This control is the selective catalytic reduction of NOx through add-on controls. SCR controls are post-combustion control 

technologies based on the chemical reduction of nitrogen oxides (NOx) into molecular nitrogen (N2) and water vapor 

(H2O). The SCR utilizes a catalyst to increase the NOx removal efficiency, which allows the process to occur at lower 

temperatures. This control applies to process gas fired ICI boilers with NOx emissions greater than 10 tons per year.

EPA 2007b

NonEGU 

Point

In-Process - Process 

Gas - Coke Oven Gas

Selective Catalytic 

Reduction 90 $5,970

Application: This control is the selective catalytic reduction of NOx through add-on controls. SCR controls are postcombustion control technologies based on the chemical reduction of nitrogen oxides (NOx) into molecular nitrogen (N2) 

and water vapor (H2O). The SCR utilizes a catalyst to increase the NOx removal efficiency, which allows the process to 

occur at lower temperatures. This control is applicable to operations with in-process process gas usage from Coke Oven 

Gas.

EPA 2007b

NonEGU 

Point

In-Process -Process 

Gas -Coke Oven/ Blast 

Furnace

Low NOx Burner and 

Flue Gas Recirculation 55

$5,120 for NOx<1 tpd 

and $3,964 for NOx>1 

tpd

This control is the use of low NOx burner (LNB) technology and flue gas recirculation (FGR) to reduce NOx emissions. 

LNBs reduce the amount of NOx created from reaction between fuel nitrogen and oxygen by lowering the temperature of 

one combustion zone and reducing the amount of oxygen available in another. This control is applicable to in-process 

coke/blast furnaces and uncontrolled NOx emissions greater than 10 tons per year.

EPA 2006b, Pechan 

2001, EPA 1998e, EPA 

2002a, EPA 1993c

NonEGU 

Point

Internal Combustion 

Engines - Gasoline Adjust Air to Fuel Ratio 20 $2,520 for NOx<1 tpd 

and $610 for NOx>1 tpd

This control is the use of air/fuel ratio adjustment to reduce NOx emissions. This control applies to gasoline powered 

internal combustion engines with uncontrolled NOx emissions greater than 10 tons per year.

EPA 2006b, EPA 

1993a, EPA 1998e, 

Pechan 2001

NonEGU 

Point

Internal Combustion 

Engines - Gasoline

Adjust Air to Fuel Ratio 

and Ignition Retard 30 $2,311 for NOx<1 tpd 

and $738 for NOx>1 tpd

This control is the use of air/fuel and ignition retard to reduce NOx emissions. This control applies to gasoline powered 

internal combustion engines with uncontrolled NOx emissions greater than 10 tons per year.

EPA 2006b, Pechan 

2006

NonEGU 

Point

Internal Combustion 

Engines - Gasoline Ignition Retard 20 $1,637 for NOx<1 tpd 

and $883 for NOx>1 tpd This applies to gasoline powered IC engines with uncontrolled NOx emissions greater than 10 tons per year.

EPA 2006b, EPA 

1993a, Pechan 2001, 

EPA 1998e

NonEGU 

Point

Internal Combustion 

Engines - Gasoline, 

Diesel, LPG

Non-Selective Catalytic 

Reduction 90 $412 VOC - 50%, CO - 90%

This control is the application of Non-Selective Catalytic Reduction (NSCR) to reduce NOx emissions. NSCR is achieved 

by placing a catalyst in the exhaust stream of the engine. The exhaust passes over the catalyst, usually a noble metal 

(platinum, rhodium or palladium) which reduces the reactants to N2, CO2 and H20. NSCR is also referred to as three-way 

catalyst because it simultaneously reduces NOx, CO, and HC to water, CO2, and N2. This control applies to Gas-fired, 

Diesel-fired, and LPG-fired Rich Burn Internal Combustion Engines. Note that the RICE MACT will already require NSCR 

for engines above 500 hp

EPA 2006b, EPA 1986, 

EPA 1993a, LADCO 

2006a, NJDEP 2003, 

Pechan 2000

NonEGU 

Point

Internal Combustion 

Engines - Gasoline, 

Diesel, Oil, LPG

Ignition Retard 25

$1,NJDEP 2003 for 

NOx<1 tpd and $786 for 

NOx>1 tpd

This control is the use of ignition retard technologies to reduce NOx emissions. This applies to Gasoline, LPG, Diesel, and 

oil IC engines with NOx emissions greater than 10 tons per year.

EPA 2006b, EPA 

1993a, Pechan 2001, 

EPA 1998e

NonEGU 

Point

Internal Combustion 

Engines - Gasoline, 

Diesel, Oil, LPG

Selective Catalytic 

Reduction 80

$3,756 for NOx<1 tpd 

and $1,477 for NOx>1 

tpd

This control is the selective catalytic reduction of NOx through add-on controls. SCR controls are post-combustion control 

technologies based on the chemical reduction of nitrogen oxides (NOx) into molecular nitrogen (N2) and water vapor 

(H2O). The SCR utilizes a catalyst to increase the NOx removal efficiency, which allows the process to occur at lower 

temperatures. This control applies to gasoline, diesel, oil and LPG-fired IC engines with uncontrolled NOx emissions 

greater than 10 tons per year.

EPA 2006b, EPA 

1993a, Pechan 2001, 

EPA 1998e, EPA 2002a

NonEGU 

Point

Internal Combustion 

Engines - Natural Gas

Low Emissions 

Combustion (Low 

Speed)

87

$2,696 for NOx<1 tpd 

and $1,011 for NOx>1 

tpd

This control is the application of Low Emissions (Low Speed) technology to reduce NOx emissions. This control applies to 

natural gas powered IC engines with uncontrolled NOx emissions greater than 10 tons per year. The low emissions 

combustion modification reduces NOx by increasing the Air-to-Fuel ratio through extensive retrofit of the engines and 

ancillary system. This allows the engine to operate at very lean A/F ratios, which lead to low amounts of NOx formation.

EPA 2006b, EPA 

1993a, Pechan 2001, 

EPA 1998e
Point & NonPoint NOx

Menu of Control Measures

Updated 4/12/2012

Printed 8/6/2013 15 of 67

Sector Source Category Emission Reduction 

Measure Name Control Efficiency (%)* Cost Effectiveness (2006$/ton reduced)

Other pollutants 

controlled Description/Notes/Caveats References

NonEGU 

Point

Internal Combustion 

Engines - Natural Gas

Low Emissions 

Combustion (Medium 

Speed)

87 $610

This control is the application of Low Emissions (Medium Speed) technology to reduce NOx emissions.This control 

applies to natural gas powered IC engines with uncontrolled NOx emissions greater than 10 tons per year. The low 

emissions combustion modification reduces NOx by increasing the Air-to-Fuel ratio through extensive retrofit of the 

engines and ancillary system. This allows the engine to operate at very lean A/F ratios, which lead to low amounts of NOx 

formation.

EPA 2006b, EPA 

1993a, Pechan 2001, 

EPA 1998e

NonEGU 

Point

Internal Combustion 

Engines - Natural Gas

Non-Selective Catalytic 

Reduction 90 $628-$836 VOC - 50%, CO - 90%

NSCR is achieved by placing a catalyst in the exhaust stream of the engine. The exhaust passes over the catalyst, 

usually a noble metal (platinum, rhodium or palladium) which reduces the reactants to N2, CO2 and H20 (NJDEP, 2003). 

Typical exhaust temperatures for effective removal of NOx are 800-1200 degrees Fahrenheit. An oxidation catalyst using 

additional air can be installed downstream of the NSCR catalyst for additional CO and VOC control. This includes 4-cycle 

naturally aspirated engines and some 4-cycle turbocharged engines. Engines operating with NSCR require air/fuel control 

to maintain high reduction effectiveness. This control applies to natural gas-fired IC engines with uncontrolled NOx 

emissions greater than 10 tons per year. Note that the RICE MACT will already require NSCR for engines above 500 hp.

EPA 2006b, EPA 

1993a, NJDEP 2003, 

Pechan 2000

NonEGU 

Point

Internal Combustion 

Engines - Natural Gas

Selective Catalytic 

Reduction 90 $4,444

This control is the selective catalytic reduction of NOx through add-on controls. SCR controls are post-combustion control 

technologies based on the chemical reduction of nitrogen oxides (NOx) into molecular nitrogen (N2) and water vapor 

(H2O). The SCR utilizes a catalyst to increase the NOx removal efficiency, which allows the process to occur at lower 

temperatures. This control applies to natural gas-fired IC engines with uncontrolled NOx emissions greater than 10 tons 

per year.

EPA 2006b, EPA 

1993a, Pechan 2001, 

EPA 1998e, EPA 2002a

NonEGU 

Point

Iron & Steel - InProcess Combustion - 

Bituminous Coal

Selective Catalytic 

Reduction 90 $3,649

This control is the selective catalytic reduction of NOx through add-on controls. SCR controls are post-combustion control 

technologies based on the chemical reduction of nitrogen oxides (NOx) into molecular nitrogen (N2) and water vapor 

(H2O). The SCR utilizes a catalyst to increase the NOx removal efficiency, which allows the process to occur at lower 

temperatures. This control is applicable to operations with in-process combustion (Bituminous Coal) in the Iron & Steel 

industry with uncontrolled NOx emissions greater than 10 tons per year. 

EPA 2010b

NonEGU 

Point

Iron & Steel - InProcess Combustion - 

Natural Gas and 

Process Gas - Coke 

Oven Gas

Low NOx Burner 50

$3,531 for NOx<1 tpd 

and $2,889 for NOx>1 

tpd

This control is the use of low NOx burner (LNB) technology to reduce NOx emissions. LNBs reduce the amount of NOx 

created from reaction between fuel nitrogen and oxygen by lowering the temperature of one combustion zone and 

reducing the amount of oxygen available in another. This control is applicable to operations with in-process combustion 

(Natural Gas or Coke Oven Process Gas) in the Iron & Steel industry with uncontrolled NOx emissions greater than 10 

tons per year.

EPA 2010b

NonEGU 

Point

Iron & Steel - InProcess Combustion - 

Natural Gas and 

Process Gas - Coke 

Oven Gas

Selective Catalytic 

Reduction 90 $5,970

This control is the selective catalytic reduction of NOx through add-on controls. SCR controls are post-combustion control 

technologies based on the chemical reduction of nitrogen oxides (NOx) into molecular nitrogen (N2) and water vapor 

(H2O). The SCR utilizes a catalyst to increase the NOx removal efficiency, which allows the process to occur at lower 

temperatures. This control is applicable to operations with in-process combustion (Natural Gas and Process Gas - Coke 

Oven Gas) in the Iron & Steel industry.

EPA 2010b

NonEGU 

Point

Iron & Steel - InProcess Combustion - 

Process Gas -Coke 

Oven/ Blast Furnace

Low NOx Burner and 

Flue Gas Recirculation 55

$5,120 for NOx<1 tpd 

and $3,964 for NOx>1 

tpd

This control is the use of low NOx burner (LNB) technology and flue gas recirculation (FGR) to reduce NOx emissions. 

LNBs reduce the amount of NOx created from reaction between fuel nitrogen and oxygen by lowering the temperature of 

one combustion zone and reducing the amount of oxygen available in another. This control is applicable to operations 

with in-process combustion (Process Gas - Coke Oven/ Blast Furnace) in the Iron & Steel industry with uncontrolled NOx 

emissions greater than 10 tons per year.

EPA 2010b

NonEGU 

Point

Iron & Steel - InProcess Combustion - 

Residual Oil

Selective Catalytic 

Reduction 90 $5,374

This control is the selective catalytic reduction of NOx through add-on controls. SCR controls are post-combustion control 

technologies based on the chemical reduction of nitrogen oxides (NOx) into molecular nitrogen (N2) and water vapor 

(H2O). The SCR utilizes a catalyst to increase the NOx removal efficiency, which allows the process to occur at lower 

temperatures. This control is applicable to operations with in-process combustion (Residual Oil) in the Iron & Steel 

industry with uncontrolled NOx emissions greater than 10 tons per year.

EPA 2010b

NonEGU 

Point

Iron & Steel Mills - 

Annealing Low NOx Burner 50 $915

This control is the use of low NOx burner (LNB) technology to reduce NOx emissions. LNBs reduce the amount of NOx 

created from reaction between fuel nitrogen and oxygen by lowering the temperature of one combustion zone and 

reducing the amount of oxygen available in another. This control is applicable to iron and steel annealing operations with 

uncontrolled NOx emissions greater than 10 tons per year.

EPA 2006b, Pechan 

2001, EPA 1998e, EPA 

2002a, EPA 1994e

NonEGU 

Point

Iron & Steel Mills - 

Annealing

Low NOx Burner and 

Flue Gas Recirculation 60 $1,204

This control is the use of low NOx burner (LNB) technology and flue gas recirculation (FGR) to reduce NOx emissions. 

LNBs reduce the amount of NOx created from reaction between fuel nitrogen and oxygen by lowering the temperature of 

one combustion zone and reducing the amount of oxygen available in another. This control is applicable to iron and steel 

annealing operations with uncontrolled NOx emissions greater than 10 tons per year.

EPA 2006b, Pechan 

2001, EPA 1998e, EPA 

2002a, EPA 1994e

NonEGU 

Point

Iron & Steel Mills - 

Annealing

Low NOx Burner and 

Selective Catalytic 

Reduction

90 $6,548

This control is the use of low NOx burner (LNB) technology and selective catalytic reduction (SCR) to reduce NOx 

emissions. LNBs reduce the amount of NOx created from reaction between fuel nitrogen and oxygen by lowering the 

temperature of one combustion zone and reducing the amount of oxygen available in another. SCR controls are postcombustion control technologies based on the chemical reduction of nitrogen oxides (NOx) into molecular nitrogen (N2) 

and water vapor (H2O). The SCR utilizes a catalyst to increase the NOx removal efficiency, which allows the process to 

occur at lower temperatures. This control is applicable to iron and steel annealing operations with uncontrolled NOx 

emissions greater than 10 tons per year.

EPA 2006b, Pechan 

2001, EPA 1998e, EPA 

2002a, EPA 1994e
Point & NonPoint NOx

Menu of Control Measures

Updated 4/12/2012

Printed 8/6/2013 16 of 67

Sector Source Category Emission Reduction 

Measure Name Control Efficiency (%)* Cost Effectiveness (2006$/ton reduced)

Other pollutants 

controlled Description/Notes/Caveats References

NonEGU 

Point

Iron & Steel Mills - 

Annealing

Low NOx Burner and 

Selective Non Catalytic 

Reduction

80 $2,761

This control is the use of low NOx burner (LNB) technology and selective catalytic reduction (SCR) to reduce NOx 

emissions. LNBs reduce the amount of NOx created from reaction between fuel nitrogen and oxygen by lowering the 

temperature of one combustion zone and reducing the amount of oxygen available in another. SCR controls are postcombustion control technologies based on the chemical reduction of nitrogen oxides (NOx) into molecular nitrogen (N2) 

and water vapor (H2O). The SCR utilizes a catalyst to increase the NOx removal efficiency, which allows the process to 

occur at lower temperatures. This control is applicable to iron and steel annealing operations with uncontrolled NOx 

emissions greater than 10 tons per year.

EPA 2006b, Pechan 

2001, EPA 1998e, EPA 

2002a, EPA 1994e

NonEGU 

Point

Iron & Steel Mills - 

Annealing

Selective Catalytic 

Reduction 90-99 $6,384

This control is the selective catalytic reduction of NOx through add-on controls. SCR controls are post-combustion control 

technologies based on the chemical reduction of nitrogen oxides (NOx) into molecular nitrogen (N2) and water vapor 

(H2O). The SCR utilizes a catalyst to increase the NOx removal efficiency, which allows the process to occur at lower 

temperatures. This control applies to iron and steel annealing operations with NOx emissions greater than 10 tons per 

year.

EPA 2006b, EPA 

1998e, EPA 2002a, 

EPA 1993c, EPA 

2007d, Sorrels 2007

NonEGU 

Point

Iron & Steel Mills - 

Annealing

Selective Non Catalytic 

Reduction 60 $2,632

This control is the reduction of NOx emission through selective non-catalytic reduction add-on controls. SNCR controls 

are post-combustion control technologies based on the chemical reduction of nitrogen oxides (NOx) into molecular 

nitrogen (N2) and water vapor (H2O). This control applies to iron and steel mill annealing operations with uncontrolled 

NOx emissions greater than 10 tons per year.

EPA 2006b, Pechan 

2001, EPA 1998e, EPA 

2002a, EPA 1994e, 

EPA 1993c

NonEGU 

Point

Iron & Steel Mills - 

Cupola Melt Furnaces

Selective Catalytic 

Reduction 90 $10,000

This control is the selective catalytic reduction of NOx through add-on controls. SCR controls are post-combustion control 

technologies based on the chemical reduction of nitrogen oxides (NOx) into molecular nitrogen (N2) and water vapor 

(H2O). The SCR utilizes a catalyst to increase the NOx removal efficiency, which allows the process to occur at lower 

temperatures. This control applies to NOx emissions from the cupola melt furnaces at iron and steel operations.

RTI 2011

NonEGU 

Point

Iron & Steel Mills - 

Galvanizing Low NOx Burner 50 $786

This control is the use of low NOx burner (LNB) technology to reduce NOx emissions. LNBs reduce the amount of NOx 

created from reaction between fuel nitrogen and oxygen by lowering the temperature of one combustion zone and 

reducing the amount of oxygen available in another. This control is applicable to iron and steel galvanizing operations 

with uncontrolled NOx emissions greater than 10 tons per year.

EPA 2006b, Pechan 

2001, EPA 1998e, EPA 

2002a, EPA 1994e

NonEGU 

Point

Iron & Steel Mills - 

Galvanizing

Low NOx Burner and 

Flue Gas Recirculation 60 $931

This control is the use of low NOx burner (LNB) technology and flue gas recirculation (FGR) to reduce NOx emissions. 

LNBs reduce the amount of NOx created from reaction between fuel nitrogen and oxygen by lowering the temperature of 

one combustion zone and reducing the amount of oxygen available in another. This control is applicable to iron and steel 

galvanizing operations with uncontrolled NOx emissions greater than 10 tons per year.

EPA 2006b, Pechan 

2001, EPA 1998e, EPA 

2002a, EPA 1994e

NonEGU 

Point

Iron & Steel Mills - 

Reheating Low Excess Air 13 $2,119 The reduction in NOx emissions is achieved through the use of low excess air techniques, such that there is less 

available oxygen convert fuel nitrogen to NOx. This control applies to iron & steel reheating furnaces.

EPA 2006b, EPA 

1993a, Pechan 2001, 

EPA 1998e, EPA 

1994e, ERG 2000

NonEGU 

Point

Iron & Steel Mills - 

Reheating Low NOx Burner 66 $481

This control is the use of low NOx burner (LNB) technology to reduce NOx emissions. LNBs reduce the amount of NOx 

created from reaction between fuel nitrogen and oxygen by lowering the temperature of one combustion zone and 

reducing the amount of oxygen available in another. This control is applicable to iron and steel reheating operations with 

uncontrolled NOx emissions greater than 10 tons per year.

EPA 2006b, Pechan 

2001, EPA 1998e, EPA 

2002a, EPA 1994e

NonEGU 

Point

Iron & Steel Mills - 

Reheating

Low NOx Burner and 

Flue Gas Recirculation 77 $610

This control is the use of low NOx burner (LNB) technology and flue gas recirculation (FGR) to reduce NOx emissions. 

LNBs reduce the amount of NOx created from reaction between fuel nitrogen and oxygen by lowering the temperature of 

one combustion zone and reducing the amount of oxygen available in another. This control is applicable to reheating 

processes in iron and steel mills with uncontrolled NOx emissions greater than 10 tons per year.

EPA 2006b, Pechan 

2001, EPA 1998e, EPA 

2002a, EPA 1994e

NonEGU 

Point

Iron Production - Blast 

Furnace - Blast Heating 

Stoves

Low NOx Burner and 

Flue Gas Recirculation 77 $610

This control is the use of low NOx burner (LNB) technology and flue gas recirculation (FGR) to reduce NOx emissions. 

LNBs reduce the amount of NOx created from reaction between fuel nitrogen and oxygen by lowering the temperature of 

one combustion zone and reducing the amount of oxygen available in another. This control is applicable to reheating 

processes in iron production operations with blast heating stoves ant uncontrolled NOx emissions greater than 10 tons 

per year.

EPA 2006b, EPA 

1998e, EPA 2002a, 

EPA 1994e

NonEGU 

Point Lime Kilns Low NOx Burner 30 $899

This control is the use of low NOx burner (LNB) technology to reduce NOx emissions. LNBs reduce the amount of NOx 

created from reaction between fuel nitrogen and oxygen by lowering the temperature of one combustion zone and 

reducing the amount of oxygen available in another. This control is applicable to lime kilns with uncontrolled NOx 

emissions greater than 10 tons per year.

EPA 2006b, EPA 

1998e, EPA 2002a, 

EPA 1994h

NonEGU 

Point

Medical Waste 

Incinerators

Selective Non-Catalytic 

Reduction 45 $7,238

This control is the reduction of NOx emission through selective non-catalytic reduction add-on controls. SNCR controls 

are post-combustion control technologies based on the chemical reduction of nitrogen oxides (NOx) into molecular 

nitrogen (N2) and water vapor (H2O). This control applies to medical waste incinerators with uncontrolled NOx emissions 

greater than 10 tons per year.

EPA 2006b, Pechan 

2001, EPA 1998e, EPA 

2002a, 

STAPPA/ALAPCO 1994

NonEGU 

Point

Natural Gas Production - 

Compressors

Selective Catalytic 

Reduction 80 $4,444 for NOx<1 tpd 

and $855 for NOx>1 tpd

This control is the selective catalytic reduction of NOx through add-on controls. SCR controls are post-combustion control 

technologies based on the chemical reduction of nitrogen oxides (NOx) into molecular nitrogen (N2) and water vapor 

(H2O). The SCR utilizes a catalyst to increase the NOx removal efficiency, which allows the process to occur at lower 

temperatures. This control applies to compressors used in natural gas production operations with NOx emissions greater 

than 10 tons per year.

EPA 2006b, EPA 

1993a, Pechan 2001, 

EPA 1998e, EPA 2002a
Point & NonPoint NOx

Menu of Control Measures

Updated 4/12/2012

Printed 8/6/2013 17 of 67

Sector Source Category Emission Reduction 

Measure Name Control Efficiency (%)* Cost Effectiveness (2006$/ton reduced)

Other pollutants 

controlled Description/Notes/Caveats References

NonEGU 

Point

Nitric Acid 

Manufacturing Extended Absorption 95 $770 This control is the use of extended absorption technologies to reduce NOx emissions. This control applies to nitric acid 

manufacturing operations.

EPA 2006b, EPA 

1998e, EPA 1991

NonEGU 

Point

Nitric Acid 

Manufacturing

Non-Selective Catalytic 

Reduction 98 $883 VOC - 50%, CO - 90%, 

N2O

NSCR is achieved by placing a catalyst in the exhaust stream of the engine. The exhaust passes over the catalyst, 

usually a noble metal (platinum, rhodium or palladium) which reduces the reactants to N2, CO2 and H20 (NJDEP, 2003). 

Typical exhaust temperatures for effective removal of NOx are 800-1200 degrees Fahrenheit. An oxidation catalyst using 

additional air can be installed downstream of the NSCR catalyst for additional CO and VOC control. This includes 4-cycle 

naturally aspirated engines and some 4-cycle turbocharged engines. Engines operating with NSCR require air/fuel control 

to maintain high reduction effectiveness.

EPA 2006b, EPA 1986, 

EPA 1998e, EPA 

2002a, EPA 1991

NonEGU 

Point

Nitric Acid 

Manufacturing

Selective Catalytic 

Reduction 90 $979

This control is the selective catalytic reduction of NOx through add-on controls. SCR controls are post-combustion control 

technologies based on the chemical reduction of nitrogen oxides (NOx) into molecular nitrogen (N2) and water vapor 

(H2O). The SCR utilizes a catalyst to increase the NOx removal efficiency, which allows the process to occur at lower 

temperatures. This control applies to nitric acid manufacturing operations with NOx emissions greater than 10 tons per 

year.

EPA 2007b

NonEGU 

Point

Primary Copper 

Smelters - 

Reverberatory Smelter 

Furnace

Low NOx Burner and 

Flue Gas Recirculation 60 $1,204

This control is the use of low NOx burner (LNB) technology and flue gas recirculation (FGR) to reduce NOx emissions. 

LNBs reduce the amount of NOx created from reaction between fuel nitrogen and oxygen by lowering the temperature of 

one combustion zone and reducing the amount of oxygen available in another. This control is applicable to primary 

copper smelting operations.

EPA 2006b

NonEGU 

Point Process Heaters Low NOx Burner and 

Flue Gas Recirculation 50 $915

This control is the use of low NOx burner (LNB) technology and flue gas recirculation (FGR) to reduce NOx emissions. 

LNBs reduce the amount of NOx created from reaction between fuel nitrogen and oxygen by lowering the temperature of 

one combustion zone and reducing the amount of oxygen available in another. This control is applicable to process 

heaters with uncontrolled NOx emissions greater than 10 tons per year.

EPA 2002a, EPA 1998e

NonEGU 

Point

Process Heaters - 

Distillate Oil

Low NOx Burner and 

Selective Catalytic 

Reduction

90 $10,471

This control is the use of low NOx burner (LNB) technology and selective catalytic reduction (SCR) to reduce NOx 

emissions. LNBs reduce the amount of NOx created from reaction between fuel nitrogen and oxygen by lowering the 

temperature of one combustion zone and reducing the amount of oxygen available in another. SCR controls are postcombustion control technologies based on the chemical reduction of nitrogen oxides (NOx) into molecular nitrogen (N2) 

and water vapor (H2O). The SCR utilizes a catalyst to increase the NOx removal efficiency, which allows the process to 

occur at lower temperatures. This control is applicable to distillate oil-fired process heaters with uncontrolled NOx 

emissions greater than 10 tons per year.

EPA 2006b, EPA 

2007b, Pechan 2001, 

EPA 1998e, EPA 

2002a, EPA 2007d

NonEGU 

Point

Process Heaters - 

Distillate Oil

Selective Catalytic 

Reduction 75

$14,814 for NOx<1 tpd 

and $9,678 for NOx>1 

tpd

This control is the selective catalytic reduction of NOx through add-on controls. SCR controls are post-combustion control 

technologies based on the chemical reduction of nitrogen oxides (NOx) into molecular nitrogen (N2) and water vapor 

(H2O). The SCR utilizes a catalyst to increase the NOx removal efficiency, which allows the process to occur at lower 

temperatures. This control applies to distillate oil-fired process heaters with NOx emissions greater than 10 tons per year.

EPA 2006b, Pechan 

2001, EPA 1998e, EPA 

2002a, EPA 1993c

NonEGU 

Point

Process Heaters - 

Distillate Oil or LPG Low NOx Burner 45

$5,569 for NOx<1 tpd 

and $1,557 for NOx>1 

tpd

This control is the use of low NOx burner (LNB) technology to reduce NOx emissions. LNBs reduce the amount of NOx 

created from reaction between fuel nitrogen and oxygen by lowering the temperature of one combustion zone and 

reducing the amount of oxygen available in another. This control is applicable to distillate oil-fired process heaters and 

LPG fired process heaters with uncontrolled NOx emissions greater than 10 tons per year.

EPA 2006b, Pechan 

2001, EPA 1998e, EPA 

2002a, EPA 1993c

NonEGU 

Point

Process Heaters - 

Distillate Oil or LPG

Low NOx Burner and 

Flue Gas Recirculation 48

$6,821 for NOx<1 tpd 

and $2,696 for NOx>1 

tpd

This control is the use of low NOx burner (LNB) technology and flue gas recirculation (FGR) to reduce NOx emissions. 

LNBs reduce the amount of NOx created from reaction between fuel nitrogen and oxygen by lowering the temperature of 

one combustion zone and reducing the amount of oxygen available in another. This control is applicable to distillate-fired 

process heatersand LPG-fired process heaters with uncontrolled NOx emissions greater than 10 tons per year.

EPA 2006b, Pechan 

2001, EPA 1998e, EPA 

2002a, EPA 1993c

NonEGU 

Point

Process Heaters - 

Distillate Oil or LPG

Low NOx Burner and 

Selective Noncatalytic 

Reduction

78

$5,810 for NOx<1 tpd 

and $3,017 for NOx>1 

tpd

This control is the use of low NOx burner (LNB) technology and selective non catalytic reduction (SNCR) to reduce NOx 

emissions. LNBs reduce the amount of NOx created from reaction between fuel nitrogen and oxygen by lowering the 

temperature of one combustion zone and reducing the amount of oxygen available in another. SNCR controls are postcombustion control technologies based on the chemical reduction of nitrogen oxides (NOx) into molecular nitrogen (N2) 

and water vapor (H2O). This control is applicable to LPG-fired and distillate oil-fired process heaters with uncontrolled 

NOx emissions greater than 10 tons per year.

EPA 2006b, Pechan 

2001, EPA 1998e, EPA 

2002a, EPA 1993c

NonEGU 

Point

Process Heaters - 

Distillate Oil or LPG

Selective Non-Catalytic 

Reduction 60

$5,104 for NOx<1 tpd 

and $2,761 for NOx>1 

tpd

This control is the reduction of NOx emission through selective non-catalytic reduction add-on controls. SNCR controls 

are post-combustion control technologies based on the chemical reduction of nitrogen oxides (NOx) into molecular 

nitrogen (N2) and water vapor (H2O). This control applies to distillate oil-fired and LPG-fired process heaters with 

uncontrolled NOx emissions greater than 10 tons per year.

EPA 2006b, Pechan 

2001, EPA 1998e, EPA 

2002a, EPA 1993c
Point & NonPoint NOx

Menu of Control Measures

Updated 4/12/2012

Printed 8/6/2013 18 of 67

Sector Source Category Emission Reduction 

Measure Name Control Efficiency (%)* Cost Effectiveness (2006$/ton reduced)

Other pollutants 

controlled Description/Notes/Caveats References

NonEGU 

Point

Process Heaters - 

Distillate Oil or LPG Ultra-Low NOx Burner 74 $3,435 for NOx<1 tpd 

and $979 for NOx>1 tpd

This control is the use of ultra-low NOx burner (ULNB) add-on technologies to reduce NOx emissions. LNBs reduce the 

amount of NOx created from reaction between fuel nitrogen and oxygen by lowering the temperature of one combustion 

zone and reducing the amount of oxygen available in another. SCR controls are post-combustion control technologies 

based on the chemical reduction of nitrogen oxides (NOx) into molecular nitrogen (N2) and water vapor (H2O). This 

control applies to distillate oil-fired process heaters and LPG-fired process heaters with uncontrolled NOx emissions 

greater than 10 tons per year.

EPA 2006b, Pechan 

2001, EPA 1998e, EPA 

2002a, EPA 1993c

NonEGU 

Point Process Heaters - LPG Low NOx Burner 50 $6,003

This control is the use of low NOx burner (LNB) technology to reduce NOx emissions. LNBs reduce the amount of NOx 

created from reaction between fuel nitrogen and oxygen by lowering the temperature of one combustion zone and 

reducing the amount of oxygen available in another. This control is applicable to LPG-fired process heaters.

EPA 2006b, EPA 1998e

NonEGU 

Point Process Heaters - LPG Low NOx Burner and 

Flue Gas Recirculation 48

$6,741 for NOx<1 tpd 

and $5,136 for NOx>1 

tpd

This control is the use of low NOx burner (LNB) technology and flue gas recirculation (FGR) to reduce NOx emissions. 

LNBs reduce the amount of NOx created from reaction between fuel nitrogen and oxygen by lowering the temperature of 

one combustion zone and reducing the amount of oxygen available in another. This control is applicable to LPG-fired 

process heaters with uncontrolled NOx emissions greater than 10 tons per year.

EPA 2006b, Pechan 

2006, Pechan 2001, 

EPA 1998e, EPA 

2002a, EPA 1993c

NonEGU 

Point Process Heaters - LPG

Low NOx Burner and 

Selective Catalytic 

Reduction

92

$18,457 for NOx<1 tpd 

and $14,637 for NOx>1 

tpd

This control is the use of low NOx burner (LNB) technology and selective catalytic reduction (SCR) to reduce NOx 

emissions. LNBs reduce the amount of NOx created from reaction between fuel nitrogen and oxygen by lowering the 

temperature of one combustion zone and reducing the amount of oxygen available in another. SCR controls are postcombustion control technologies based on the chemical reduction of nitrogen oxides (NOx) into molecular nitrogen (N2) 

and water vapor (H2O). The SCR utilizes a catalyst to increase the NOx removal efficiency, which allows the process to 

occur at lower temperatures. This control is applicable to LPG-fired process heaters with uncontrolled NOx emissions 

greater than 10 tons per year.

EPA 2006b, Pechan 

2001, EPA 1998e, EPA 

2002a, EPA 1993c

NonEGU 

Point

Process Heaters - 

Natural Gas

Low NOx Burner and 

Selective Catalytic 

Reduction

80 $14,920

This control is the use of low NOx burner (LNB) technology and selective catalytic reduction (SCR) to reduce NOx 

emissions. LNBs reduce the amount of NOx created from reaction between fuel nitrogen and oxygen by lowering the 

temperature of one combustion zone and reducing the amount of oxygen available in another. SCR controls are postcombustion control technologies based on the chemical reduction of nitrogen oxides (NOx) into molecular nitrogen (N2) 

and water vapor (H2O). The SCR utilizes a catalyst to increase the NOx removal efficiency, which allows the process to 

occur at lower temperatures. This control is applicable to natural gas-fired process heaters with uncontrolled NOx 

emissions greater than 10 tons per year.

EPA 2006b, EPA 

2007b, Pechan 2001, 

EPA 1998e, EPA 

2002a, EPA 1993c

NonEGU 

Point

Process Heaters - 

Natural Gas or Process 

Gas

Low NOx Burner 50

$3,531 for NOx<1 tpd 

and $2,889 for NOx>1 

tpd

This control is the use of low NOx burner (LNB) technology to reduce NOx emissions. LNBs reduce the amount of NOx 

created from reaction between fuel nitrogen and oxygen by lowering the temperature of one combustion zone and 

reducing the amount of oxygen available in another. This control is applicable to natural gas-fired and process gas-fired 

process heaters with uncontrolled NOx emissions greater than 10 tons per year.

EPA 2006b, Pechan 

2001, EPA 1998e, EPA 

2002a, EPA 1993c

NonEGU 

Point

Process Heaters - 

Natural Gas or Process 

Gas

Low NOx Burner and 

Selective Catalytic 

Reduction

90 $14,920

This control is the use of low NOx burner (LNB) technology and selective catalytic reduction (SCR) to reduce NOx 

emissions. LNBs reduce the amount of NOx created from reaction between fuel nitrogen and oxygen by lowering the 

temperature of one combustion zone and reducing the amount of oxygen available in another. SCR controls are postcombustion control technologies based on the chemical reduction of nitrogen oxides (NOx) into molecular nitrogen (N2) 

and water vapor (H2O). The SCR utilizes a catalyst to increase the NOx removal efficiency, which allows the process to 

occur at lower temperatures. This control is applicable to natural gas-fired and process gas-fired process heaters with 

uncontrolled NOx emissions greater than 10 tons per year.

EPA 2006b, EPA 

2007b, Pechan 2001, 

EPA 1998e, EPA 

2002a, EPA 1993c

NonEGU 

Point

Process Heaters - 

Natural Gas or Process 

Gas

Low NOx Burner and 

Selective Noncatalytic 

Reduction

80

$5,649 for NOx<1 tpd 

and $4,157 for NOx>1 

tpd

This control is the use of low NOx burner (LNB) technology and selective non-catalytic reduction (SNCR) to reduce NOx 

emissions. LNBs reduce the amount of NOx created from reaction between fuel nitrogen and oxygen by lowering the 

temperature of one combustion zone and reducing the amount of oxygen available in another. SNCR controls are postcombustion control technologies based on the chemical reduction of nitrogen oxides (NOx) into molecular nitrogen (N2) 

and water vapor (H2O). This control is applicable to natural gasfi-red dand process gas-fired process heaters with 

uncontrolled NOx emissions greater than 10 tons per year.

EPA 2006b, Pechan 

2001, EPA 1998e, EPA 

2002a, EPA 1993c

NonEGU 

Point

Process Heaters - 

Natural Gas or Process 

Gas

Selective Non-Catalytic 

Reduction 60

$4,574 for NOx<1 tpd 

and $3,130 for NOx>1 

tpd

This control is the reduction of NOx emission through selective non-catalytic reduction add-on controls. SNCR controls 

are post-combustion control technologies based on the chemical reduction of nitrogen oxides (NOx) into molecular 

nitrogen (N2) and water vapor (H2O). This control applies to natural gas-fired and process gas-fired process heaters with 

uncontrolled NOx emissions greater than 10 tons per year.

EPA 2006b, Pechan 

2001, EPA 1998e, EPA 

2002a, EPA 1993c

NonEGU 

Point

Process Heaters - 

Natural Gas or Process 

Gas

Ultra-Low NOx Burner 75

$2,407 for NOx<1 tpd 

and $1,926 for NOx>1 

tpd

This control is the use of ultra-low NOx burner (ULNB) add-on technologies to reduce NOx emissions. LNBs reduce the 

amount of NOx created from reaction between fuel nitrogen and oxygen by lowering the temperature of one combustion 

zone and reducing the amount of oxygen available in another. SCR controls are post-combustion control technologies 

based on the chemical reduction of nitrogen oxides (NOx) into molecular nitrogen (N2) and water vapor (H2O). This 

control applies to natural gas-fired and process gas-fired process heaters with uncontrolled NOx emissions greater than 

10 tons per year.

EPA 2006b, Pechan 

2001, EPA 1998e, EPA 

2002a, EPA 1993c
Point & NonPoint NOx

Menu of Control Measures

Updated 4/12/2012

Printed 8/6/2013 19 of 67

Sector Source Category Emission Reduction 

Measure Name Control Efficiency (%)* Cost Effectiveness (2006$/ton reduced)

Other pollutants 

controlled Description/Notes/Caveats References

NonEGU 

Point

Process Heaters - 

Natural Gas, Process 

Gas or LPG

Low NOx Burner and 

Flue Gas Recirculation 55

$6,741 for NOx<1 tpd 

and $5,136 for NOx>1 

tpd

This control is the use of low NOx burner (LNB) technology and flue gas recirculation (FGR) to reduce NOx emissions. 

LNBs reduce the amount of NOx created from reaction between fuel nitrogen and oxygen by lowering the temperature of 

one combustion zone and reducing the amount of oxygen available in another. This control is applicable to natural gasfired process heaters, process gas- fired and LPG-fired process heaters with uncontrolled NOx emissions greater than 10 

tons per year.

EPA 2006b, Pechan 

2006, Pechan 2001, 

EPA 1998e, EPA 

2002a, EPA 1993c

NonEGU 

Point

Process Heaters - Other 

Fuel

Low NOx Burner and 

Selective Catalytic 

Reduction

91

$8,699 for NOx<1 tpd 

and $5,072 for NOx>1 

tpd

This control is the use of low NOx burner (LNB) technology and selective catalytic reduction (SCR) to reduce NOx 

emissions. LNBs reduce the amount of NOx created from reaction between fuel nitrogen and oxygen by lowering the 

temperature of one combustion zone and reducing the amount of oxygen available in another. SCR controls are postcombustion control technologies based on the chemical reduction of nitrogen oxides (NOx) into molecular nitrogen (N2) 

and water vapor (H2O). The SCR utilizes a catalyst to increase the NOx removal efficiency, which allows the process to 

occur at lower temperatures. This control is applicable to other (not classified) fuel-fired process heaters with uncontrolled 

NOx emissions greater than 10 tons per year.

EPA 2006b, Pechan 

2001, EPA 1998e, EPA 

2002a, EPA 1993c

NonEGU 

Point

Process Heaters - 

Process Gas

Low NOx Burner and 

Flue Gas Recirculation 55

$5,120 for NOx<1 tpd 

and $3,964 for NOx>1 

tpd

This control is the use of low NOx burner (LNB) technology and flue gas recirculation (FGR) to reduce NOx emissions. 

LNBs reduce the amount of NOx created from reaction between fuel nitrogen and oxygen by lowering the temperature of 

one combustion zone and reducing the amount of oxygen available in another. This control is applicable to process 

heaters with uncontrolled NOx emissions greater than 10 tons per year.

EPA 2006b, Pechan 

2001, EPA 1998e, EPA 

2002a, EPA 1993c

NonEGU 

Point

Process Heaters - 

Process Gas or Natural 

Gas or LPG

Selective Catalytic 

Reduction 75

$19,324 for NOx<1 tpd 

and $13,096 for NOx>1 

tpd

This control is the selective catalytic reduction (SCR) of NOx through add-on controls. SCR controls are post-combustion 

control technologies based on the chemical reduction of nitrogen oxides (NOx) into molecular nitrogen (N2) and water 

vapor (H2O). The SCR utilizes a catalyst to increase the NOx removal efficiency, which allows the process to occur at 

lower temperature. This control applies to natural gas-fired, process gas-fired, or LPG-fired process heaters with NOx 

emissions greater than 10 tons per year.

EPA 2006b, Pechan 

2001, EPA 1998e, EPA 

2002a, EPA 1993c

NonEGU 

Point

Process Heaters - 

Residual Oil

Low NOx Burner and 

Selective Catalytic 

Reduction

90 $6,316

This control is the use of low NOx burner (LNB) technology and selective catalytic reduction (SCR) to reduce NOx 

emissions. LNBs reduce the amount of NOx created from reaction between fuel nitrogen and oxygen by lowering the 

temperature of one combustion zone and reducing the amount of oxygen available in another. SCR controls are postcombustion control technologies based on the chemical reduction of nitrogen oxides (NOx) into molecular nitrogen (N2) 

and water vapor (H2O). The SCR utilizes a catalyst to increase the NOx removal efficiency, which allows the process to 

occur at lower temperatures. This control is applicable to residual oil-fired process heaters with uncontrolled NOx 

emissions greater than 10 tons per year.

EPA 2006b, EPA 

2007b, Pechan 2001, 

EPA 1998e, EPA 

2002a, EPA 1993c

NonEGU 

Point

Process Heaters - 

Residual Oil or Other 

Fuel

Low NOx Burner 37

$4,045 for NOx<1 tpd 

and $1,140 for NOx>1 

tpd

This control is the use of low NOx burner (LNB) technology to reduce NOx emissions. LNBs reduce the amount of NOx 

created from reaction between fuel nitrogen and oxygen by lowering the temperature of one combustion zone and 

reducing the amount of oxygen available in another. This control applies to Residual Oil process heaters and process 

heaters reporting "Other" for fuel use.

EPA 2006b, Pechan 

2001, EPA 1998e, EPA 

2002a, EPA 1993c

NonEGU 

Point

Process Heaters - 

Residual Oil or Other 

Fuel

Low NOx Burner and 

Flue Gas Recirculation 34

$5,601 for NOx<1 tpd 

and $2,215 for NOx>1 

tpd

This control is the use of low NOx burner (LNB) technology and flue gas recirculation (FGR) to reduce NOx emissions. 

LNBs reduce the amount of NOx created from reaction between fuel nitrogen and oxygen by lowering the temperature of 

one combustion zone and reducing the amount of oxygen available in another. This control applies to Residual Oil 

process heaters and process heaters reporting "Other" for fuel use.

EPA 2006b, Pechan 

2001, EPA 1998e, EPA 

2002a, EPA 1993c

NonEGU 

Point

Process Heaters - 

Residual Oil or Other 

Fuel

Selective Catalytic 

Reduction 75

$8,587 for NOx<1 tpd 

and $5,762 for NOx>1 

tpd

This control is the selective catalytic reduction of NOx through add-on controls. SCR controls are post-combustion control 

technologies based on the chemical reduction of nitrogen oxides (NOx) into molecular nitrogen (N2) and water vapor 

(H2O). The SCR utilizes a catalyst to increase the NOx removal efficiency, which allows the process to occur at lower 

temperatures. This control applies to residual oil fired process heaters and process heaters with unclassified fuels with 

NOx emissions greater than 10 tons per year.

EPA 2006b, Pechan 

2001, EPA 1998e, EPA 

2002a, EPA 1993c

NonEGU 

Point

Process Heaters - 

Residual Oil or Other 

Fuel

Selective Non-Catalytic 

Reduction 60

$3,098 for NOx<1 tpd 

and $1,765 for NOx>1 

tpd

This control is the reduction of NOx emission through selective non-catalytic reduction add-on controls. SNCR controls 

are post-combustion control technologies based on the chemical reduction of nitrogen oxides (NOx) into molecular 

nitrogen (N2) and water vapor (H2O). This control applies to residual oil-fired process heaters and process heaters with 

unclassified fuel use with uncontrolled NOx emissions greater than 10 tons per year.

EPA 2006b, Pechan 

2001, EPA 1998e, EPA 

2002a, EPA 1993c

NonEGU 

Point

Process Heaters - 

Residual Oil or Other 

Fuel

Ultra-Low NOx Burner 73 $2,070 for NOx<1 tpd 

and $578 for NOx>1 tpd

This control is the use of ultra-low NOx burner (ULNB) add-on technologies to reduce NOx emissions. LNBs reduce the 

amount of NOx created from reaction between fuel nitrogen and oxygen by lowering the temperature of one combustion 

zone and reducing the amount of oxygen available in another. SCR controls are post-combustion control technologies 

based on the chemical reduction of nitrogen oxides (NOx) into molecular nitrogen (N2) and water vapor (H2O). This 

control applies to residual oil-fired process heaters and process heaters with unclassified fuels with uncontrolled NOx 

emissions greater than 10 tons per year.

EPA 2006b, Pechan 

2001, EPA 1998e, EPA 

2002a, EPA 1993c

NonEGU 

Point

Pulp and Paper - 

Natural Gas - 

Incinerators

Selective Catalytic 

Reduction 90 $3,748

This control is the selective catalytic reduction of NOx through add-on controls. SCR controls are post-combustion control 

technologies based on the chemical reduction of nitrogen oxides (NOx) into molecular nitrogen (N2) and water vapor 

(H2O). The SCR utilizes a catalyst to increase the NOx removal efficiency, which allows the process to occur at lower 

temperatures. This control applies to natural gas incinerators at pulp and paper plants.

EPA 2007b
Point & NonPoint NOx

Menu of Control Measures

Updated 4/12/2012

Printed 8/6/2013 20 of 67

Sector Source Category Emission Reduction 

Measure Name Control Efficiency (%)* Cost Effectiveness (2006$/ton reduced)

Other pollutants 

controlled Description/Notes/Caveats References

NonEGU 

Point Sand/ Gravel - Dryer Low NOx Burner and 

Flue Gas Recirculation 55

$5,120 for NOx<1 tpd 

and $3,964 for NOx>1 

tpd

This control is the use of low NOx burner (LNB) technology and flue gas recirculation (FGR) to reduce NOx emissions. 

LNBs reduce the amount of NOx created from reaction between fuel nitrogen and oxygen by lowering the temperature of 

one combustion zone and reducing the amount of oxygen available in another. This control is applicable to sand and 

gravel drying processes with uncontrolled NOx emissions greater than 10 tons per year.

EPA 2006b, Pechan 

2001, EPA 1998e, EPA 

2002a, EPA 1993c

NonEGU 

Point

Secondary Aluminum 

Production - Smelting 

Furnace/ Reverberatory

Low NOx Burner 50 $915

This control is the use of low NOx burner (LNB) technology to reduce NOx emissions. LNBs reduce the amount of NOx 

created from reaction between fuel nitrogen and oxygen by lowering the temperature of one combustion zone and 

reducing the amount of oxygen available in another. This control is applicable to secondary aluminum production 

operations with smelting furnaces and uncontrolled NOx emissions greater than 10 tons per year.

EPA 2006b, Pechan 

2001, EPA 1998e, EPA 

2002a, EPA 1994e

NonEGU 

Point

Sewage Sludge 

Incinerators

Selective Catalytic 

Reduction 90 $3,748

This control is the reduction of NOx emission through selective non-catalytic reduction add-on controls. SNCR controls 

are post-combustion control technologies based on the chemical reduction of nitrogen oxides (NOx) into molecular 

nitrogen (N2) and water vapor (H2O). This control applies to solid waste disposal operations with uncontrolled NOx 

emissions greater than 10 tons per year.

EPA 2007b

NonEGU 

Point

Space Heaters - 

Distillate Oil Low NOx Burner 50

$1,894 for NOx<1 tpd 

and $3,322 for NOx>1 

tpd

This control is the use of low NOx burner (LNB) technology to reduce NOx emissions. LNBs reduce the amount of NOx 

created from reaction between fuel nitrogen and oxygen by lowering the temperature of one combustion zone and 

reducing the amount of oxygen available in another. This control is applicable to distillate oil-fired space heaters with 

uncontrolled NOx emissions greater than 10 tons per year.

EPA 2006b, Pechan 

2001, EPA 1998e, EPA 

2002a, EPA 1994g

NonEGU 

Point

Space Heaters - 

Distillate Oil

Low NOx Burner and 

Flue Gas Recirculation 60

$4,012 for NOx<1 tpd 

and $1,220 for NOx>1 

tpd

This control is the use of low NOx burner (LNB) technology and flue gas recirculation (FGR) to reduce NOx emissions. 

LNBs reduce the amount of NOx created from reaction between fuel nitrogen and oxygen by lowering the temperature of 

one combustion zone and reducing the amount of oxygen available in another. This control is applicable to residual oilfired process heaters with uncontrolled NOx emissions greater than 10 tons per year.

EPA 2006b, Pechan 

2001, EPA 1998e, EPA 

2002a, EPA 1993c

NonEGU 

Point

Space Heaters - 

Distillate Oil

Selective Catalytic 

Reduction 80

$4,462 for NOx<1 tpd 

and $2,423 for NOx>1 

tpd

This control is the selective catalytic reduction of NOx through add-on controls. SCR controls are post-combustion control 

technologies based on the chemical reduction of nitrogen oxides (NOx) into molecular nitrogen (N2) and water vapor 

(H2O). The SCR utilizes a catalyst to increase the NOx removal efficiency, which allows the process to occur at lower 

temperatures. This control applies to distillate oil-fired space heaters with NOx emissions greater than 10 tons per year.

EPA 2006b, Pechan 

2001, EPA 1998e, EPA 

2002a, EPA 1994g

NonEGU 

Point

Space Heaters - 

Distillate Oil

Selective Non-Catalytic 

Reduction 50

$7,447 for NOx<1 tpd 

and $3,033 for NOx>1 

tpd

This control is the reduction of NOx emission through selective non-catalytic reduction add-on controls. SNCR controls 

are post-combustion control technologies based on the chemical reduction of nitrogen oxides (NOx) into molecular 

nitrogen (N2) and water vapor (H2O). This control applies to distillate oil-fired space heaters with uncontrolled NOx 

emissions greater than 10 tons per year.

EPA 2006b, Pechan 

2001, EPA 1998e, EPA 

2002a, EPA 1994g

NonEGU 

Point

Space Heaters - Natural 

Gas Low NOx Burner 50

$1,316 for NOx<1 tpd 

and $1,043 for NOx>1 

tpd

This control is the use of low NOx burner (LNB) technology to reduce NOx emissions. LNBs reduce the amount of NOx 

created from reaction between fuel nitrogen and oxygen by lowering the temperature of one combustion zone and 

reducing the amount of oxygen available in another. This control is applicable to natural gas-fired space heaters with 

uncontrolled NOx emissions greater than 10 tons per year.

EPA 2006b, Pechan 

2001, EPA 1998e, EPA 

2002a, EPA 1994g

NonEGU 

Point

Space Heaters - Natural 

Gas

Low NOx Burner and 

Flue Gas Recirculation 60 $4,253 for NOx<1 tpd 

and $947 for NOx>1 tpd

This control is the use of low NOx burner (LNB) technology and flue gas recirculation (FGR) to reduce NOx emissions. 

LNBs reduce the amount of NOx created from reaction between fuel nitrogen and oxygen by lowering the temperature of 

one combustion zone and reducing the amount of oxygen available in another. This control is applicable to LPG-fired 

process heaters with uncontrolled NOx emissions greater than 10 tons per year.

EPA 2006b, Pechan 

2001, EPA 1998e, EPA 

2002a, EPA 1994g

NonEGU 

Point

Space Heaters - Natural 

Gas

Oxygen Trim and Water 

Injection 65 $1,091 for NOx<1 tpd 

and $514 for NOx>1 tpd

This control is the use of Oxygen Trim and Water Injection to reduce NOx emissions. Water is injected into the gas 

turbine, reducing the temperatures in the NOx-forming regions. The water can be injected into the fuel, the combustion air 

or directly into the combustion chamber. This control applies to natural gas-fired space heaters with uncontrolled NOx 

emissions greater than 10 tons per year.

EPA 2006b, Pechan 

2001, EPA 1998e, EPA 

2002a, ERG 2000, EPA 

1994g

NonEGU 

Point

Space Heaters - Natural 

Gas

Selective Catalytic 

Reduction 80

$4,590 for NOx<1 tpd 

and $1,942 for NOx>1 

tpd

This control is the selective catalytic reduction of NOx through add-on controls. SCR controls are post-combustion control 

technologies based on the chemical reduction of nitrogen oxides (NOx) into molecular nitrogen (N2) and water vapor 

(H2O). The SCR utilizes a catalyst to increase the NOx removal efficiency, which allows the process to occur at lower 

temperatures. This control applies to natural gas fired space heaters with NOx emissions greater than 10 tons per year.

EPA 2006b, Pechan 

2001, EPA 1998e, EPA 

2002a, EPA 1994g

NonEGU 

Point

Space Heaters - Natural 

Gas

Selective Non-Catalytic 

Reduction 50

$6,211 for NOx<1 tpd 

and $2,520 for NOx>1 

tpd

This control is the reduction of NOx emission through selective non-catalytic reduction add-on controls. SNCR controls 

are post-combustion control technologies based on the chemical reduction of nitrogen oxides (NOx) into molecular 

nitrogen (N2) and water vapor (H2O). This control applies to natural gas fired space heaters with uncontrolled NOx 

emissions greater than 10 tons per year.

EPA 2006b, Pechan 

2001, EPA 1998e, EPA 

2002a, EPA 1994g

NonEGU 

Point

Steel Foundries - Heat 

Treating Furnaces Low NOx Burner 50 $915

This control is the use of low NOx burner (LNB) technology to reduce NOx emissions. LNBs reduce the amount of NOx 

created from reaction between fuel nitrogen and oxygen by lowering the temperature of one combustion zone and 

reducing the amount of oxygen available in another. This control is applicable to heat treating operations at steel 

foundries with uncontrolled NOx emissions greater than 10 tons per year.

EPA 2006b, EPA 

1998e, EPA 2002a, 

EPA 1994e
Point & NonPoint NOx

Menu of Control Measures

Updated 4/12/2012

Printed 8/6/2013 21 of 67

Sector Source Category Emission Reduction 

Measure Name Control Efficiency (%)* Cost Effectiveness (2006$/ton reduced)

Other pollutants 

controlled Description/Notes/Caveats References

NonEGU 

Point

Steel Production - 

Soaking Pits

Low NOx Burner and 

Flue Gas Recirculation 60 $1,204

This control is the use of low NOx burner (LNB) technology and flue gas recirculation (FGR) to reduce NOx emissions. 

LNBs reduce the amount of NOx created from reaction between fuel nitrogen and oxygen by lowering the temperature of 

one combustion zone and reducing the amount of oxygen available in another. This control is applicable to soaking pits at 

steel production operations with uncontrolled NOx emissions greater than 10 tons per year.

EPA 2006b, EPA 

1998e, EPA 2002a, 

EPA 1994e

NonEGU 

Point

Sulfate Pulping - 

Recovery Furnaces Low NOx Burner 50

$1,316 for NOx<1 tpd 

and $1,043 for NOx>1 

tpd

This control is the use of low NOx burner (LNB) technology to reduce NOx emissions. LNBs reduce the amount of NOx 

created from reaction between fuel nitrogen and oxygen by lowering the temperature of one combustion zone and 

reducing the amount of oxygen available in another. This control is applicable to recovery furnaces at sulfate pulping 

operations with uncontrolled NOx emissions greater than 10 tons per year.

EPA 2006b, Pechan 

2001, EPA 1998e, EPA 

2002a, EPA 1994g

NonEGU 

Point

Sulfate Pulping - 

Recovery Furnaces

Low NOx Burner and 

Flue Gas Recirculation 60 $4,109 for NOx<1 tpd 

and $947 for NOx>1 tpd

This control is the use of low NOx burner (LNB) technology and flue gas recirculation (FGR) to reduce NOx emissions. 

LNBs reduce the amount of NOx created from reaction between fuel nitrogen and oxygen by lowering the temperature of 

one combustion zone and reducing the amount of oxygen available in another. This control is applicable to residual oilfired process heaters with uncontrolled NOx emissions greater than 10 tons per year.

EPA 2006b, Pechan 

2001, EPA 1998e, EPA 

2002a, EPA 1994g

NonEGU 

Point

Sulfate Pulping - 

Recovery Furnaces

Oxygen Trim and Water 

Injection 65 $1,091 for NOx<1 tpd 

and $514 for NOx>1 tpd

This control is the use of Oxygen Trim and Water Injection to reduce NOx emissions. Water is injected into the gas 

turbine, reducing the temperatures in the NOx-forming regions. The water can be injected into the fuel, the combustion air 

or directly into the combustion chamber. This control applies to recovery furnaces involved in sulfate pulping operations 

with uncontrolled NOx emissions greater than 10 tons per year.

EPA 2006b, Pechan 

2001, EPA 1998e, EPA 

2002a, ERG 2000, EPA 

1994g

NonEGU 

Point

Sulfate Pulping - 

Recovery Furnaces

Selective Catalytic 

Reduction 80 $2,761

This control is the selective catalytic reduction of NOx through add-on controls. SCR controls are post-combustion control 

technologies based on the chemical reduction of nitrogen oxides (NOx) into molecular nitrogen (N2) and water vapor 

(H2O). The SCR utilizes a catalyst to increase the NOx removal efficiency, which allows the process to occur at lower 

temperatures. This control applies to recovery furnaces in sulfate pulping operations with NOx emissions greater than 10 

tons per year.

EPA 2007b

NonEGU 

Point

Sulfate Pulping - 

Recovery Furnaces

Selective Catalytic 

Reduction 90 $2,852

This control is the selective catalytic reduction of NOx through add-on controls. SCR controls are post-combustion control 

technologies based on the chemical reduction of nitrogen oxides (NOx) into molecular nitrogen (N2) and water vapor 

(H2O). The SCR utilizes a catalyst to increase the NOx removal efficiency, which allows the process to occur at lower 

temperatures. This control applies to recovery furnaces in sulfate pulping operations with NOx emissions greater than 10 

tons per year.

EPA 2007b

NonEGU 

Point

Sulfate Pulping - 

Recovery Furnaces

Selective Non-Catalytic 

Reduction 50

$6,211 for NOx<1 tpd 

and $2,520 for NOx>1 

tpd

This control is the reduction of NOx emission through selective non-catalytic reduction add-on controls. SNCR controls 

are post-combustion control technologies based on the chemical reduction of nitrogen oxides (NOx) into molecular 

nitrogen (N2) and water vapor (H2O). This control applies to sulfate pulping operations with recovery furnaces and 

uncontrolled NOx emissions greater than 10 tons per year.

EPA 2006b, Pechan 

2001, EPA 1998e, EPA 

2002a, EPA 1994g

NonEGU 

Point

Surface Coating 

Operations -Coating 

Oven Heater -Natural 

Gas

Low NOx Burner 50

$3,531 for NOx<1 tpd 

and $2,889 for NOx>1 

tpd

This control is the use of low NOx burner (LNB) technology to reduce NOx emissions. LNBs reduce the amount of NOx 

created from reaction between fuel nitrogen and oxygen by lowering the temperature of one combustion zone and 

reducing the amount of oxygen available in another. This control is applicable to natural gas-fired coating oven heater at 

surface coating operations with uncontrolled NOx emissions greater than 10 tons per year.

EPA 2006b, EPA 

1998e, EPA 2002a, 

EPA 1993c

NonEGU 

Point

Taconite Iron Ore 

Processing - Induration 

- Coal or Gas

Selective Catalytic 

Reduction 90 $6,351

This control is the selective catalytic reduction of NOx through add-on controls. SCR controls are post-combustion control 

technologies based on the chemical reduction of nitrogen oxides (NOx) into molecular nitrogen (N2) and water vapor 

(H2O). The SCR utilizes a catalyst to increase the NOx removal efficiency, which allows the process to occur at lower 

temperatures. This control applies to coal or gas induration in taconite iron ore processing.

EPA 2007b

NonEGU 

Point

Textile-Type Fiberglass 

Manufacturing - 

Recuperative Furnace

Low NOx Burner 40 $2,712

This control is the use of low NOx burner (LNB) technology to reduce NOx emissions. LNBs reduce the amount of NOx 

created from reaction between fuel nitrogen and oxygen by lowering the temperature of one combustion zone and 

reducing the amount of oxygen available in another. This control is applicable to textile-type fiberglass manufacturing 

operations with gas- or oil-fired recuperative furnaces and uncontrolled NOx emissions greater than 10 tons per year.

EPA 2006b, EPA 

1998e, EPA 2002a, 

EPA 1994f

NonEGU 

Point

Waste Incineration - 

Municipal Waste 

Combustors or Solid 

Waste Disposal - 

Sludge Incinerators 

(Government)

Selective Non-Catalytic 

Reduction 45 $1,814

This control is the reduction of NOx emission through selective non-catalytic reduction add-on controls. SNCR controls 

are post-combustion control technologies based on the chemical reduction of nitrogen oxides (NOx) into molecular 

nitrogen (N2) and water vapor (H2O). This control applies to municipal waste combustors and government solid waste 

disposal sludge incineration sources with uncontrolled NOx emissions greater than 10 tons per year.

EPA 2006b, Pechan 

2001, EPA 1998e, EPA 

2002a, EPA 1994i

EGU

External Combustion 

Boilers - Electric 

Generation - Natural 

Gas (Tangential or NonTangential Firing)

Natural Gas Reburn 50 $2,352

Natural gas reburning (NGR) involves add-on controls to reduce NOx emissions. NGR is a combustion control technology 

in which part of the main fuel heat input is diverted to locations above the main burners, called the reburn zone. As flue 

gas passes through the reburn zone, a portion of the NOx formed in the main combustion zone is reduced by 

hydrocarbon radicals and converted to molecular nitrogen (N2). This control applies to Natural Gas external combustion 

boilers used for electricity generation.

EPA 2007c
Point & NonPoint NOx

Menu of Control Measures

Updated 4/12/2012

Printed 8/6/2013 22 of 67

Sector Source Category Emission Reduction 

Measure Name Control Efficiency (%)* Cost Effectiveness (2006$/ton reduced)

Other pollutants 

controlled Description/Notes/Caveats References

EGU

External Combustion 

Boilers - Electricity 

Generation- Anthracite 

Coal or Subbituminous/ 

Bituminous Coal

Selective Non-Catalytic 

Reduction 40 $1,370

This control is the reduction of NOx emission through selective non-catalytic reduction add-on controls to wall fired (coal) 

utility boilers. SNCR controls are post-combustion control technologies based on the chemical reduction of nitrogen 

oxides (NOx) with a nitrogen based reducing reagent, such as ammonia or urea, to reduce the NOx into molecular 

nitrogen (N2) and water vapor (H2O). This control applies to pulverized anthracite coal-fired electricity generation sources 

and bituminous/subbituminous coal-fired electricity generation sources.

EPA 2007c

EGU

External Combustion 

Boilers for Electricity 

Generation - Residual 

Oil or Solid Waste 

Combustion

Selective Non-Catalytic 

Reduction 50 $2,694

This control is the use of selective non-catalytic reduction add-on controls to wall fired (oil/gas) utility boilers for the 

reduction of NOx emissions. SNCR controls are post-combustion control technologies based on the chemical reduction of 

nitrogen oxides (NOx) with a nitrogen based reducing reagent, such as ammonia or urea, to reduce the NOx into 

molecular nitrogen (N2) and water vapor (H2O). The control applies to Residual Oil (Grade 6 oil) burning electricity 

generation sources, excluding tangentially fired sources and solid waste combustors used for electricity generation.

EPA 2007c

EGU

External Combustion 

Boilers, Electricity 

Generation, Distillate Oil

Selective Non-Catalytic 

Reduction 50 $4,868

This control is the reduction of NOx emission through selective non-catalytic reduction add-on controls to wall fired (coal) 

utility boilers. SNCR controls are post-combustion control technologies based on the chemical reduction of nitrogen 

oxides (NOx) with a nitrogen based reducing reagent, such as ammonia or urea, to reduce the NOx into molecular 

nitrogen (N2) and water vapor (H2O). This control applies to distillate oil external combustion boilers.

EPA 2007c

EGU

External Combusion 

Boilers for Electricity 

Generation

Energy Efficiency 

Policies & Programs N/A

The cost effectiveness 

is based on the 

levelized cost of saved 

energy (LCSE) for 

recent utility 

administered energy 

efficiency programs of 

2.5 cents/Kwh. $0/ton 

reduced

SO2, Hg, CO2

This category is a catch-all for energy efficiency (EE) policies, programs and measures which reduce EGU emissions 

indirectly by encouraging energy savings and reducing demand for electricity from EGUs. For more information EE 

policies, programs and measures, see the Roadmap for Incorporating EE/RE Policies and Prograsm in SIPs and TIPs. 

ACEEE 2009, EPA 

2012a, EPA 2012b

EGU

Utility Boiler - 

Bituminous Coal Wall 

Fired

Low NOx Burner and 

Over Fire Air 72

Cost effectiveness is 

variable and based on 

plant size: for a 300MW 

plant, total capital cost 

of $60.43 per kW; the 

fixed O&M costs of 

$0.40 per kW per year; 

and variable O&M costs 

of $0.090 mills per kWh.

The scaling factor for 

plants from 25MW 

(Capital Cost and Fixed 

O&M only) = 

(300/capacity)^(0.359). 

This control is the use of low NOx burner (LNB) technology to reduce NOx emissions. LNBs reduce the amount of NOx 

created from reaction between fuel nitrogen and oxygen by lowering the temperature of one combustion zone and 

reducing the amount of oxygen available in another. This control applies to wall fired coal utility boilers.

EPA 2006b, EPA 

2002a, EPA 2010a

EGU

Utility Boiler - 

Bituminous Coal/ Wall 

Fired 

Low NOx Burner 57

Cost effectiveness is 

variable and based on 

plant size: for a 300MW 

plant, total capital cost 

of $44.58 per kW; the 

fixed O&M costs of 

$0.30 per kW per year; 

and variable O&M costs 

of $0.070 mills per kWh.

The scaling factor for 

plants from 25MW 

(Capital Cost and Fixed 

O&M only) = 

(300/capacity)^(0.359). 

This control is the use of low NOx burner (LNB) technology to reduce NOx emissions. LNBs reduce the amount of NOx 

created from reaction between fuel nitrogen and oxygen by lowering the temperature of one combustion zone and 

reducing the amount of oxygen available in another. This control applies to wall fired coal utility boilers.

EPA 2006b, EPA 

2002a, EPA 2010a

EGU Utility Boiler - Coal/ 

Wall Natural Gas Reburn 50

Cost effectiveness is 

variable and based on: 

plant size, the total 

capital cost of $32.41 

per kW, and the fixed 

O&M of $0.49 per kW 

per year

Natural gas reburning (NGR) involves add-on controls to reduce NOx emissions. NGR is a combustion control technology 

in which part of the main fuel heat input is diverted to locations above the main burners, called the reburn zone. As flue 

gas passes through the reburn zone, a portion of the NOx formed in the main combustion zone is reduced by 

hydrocarbon radicals and converted to molecular nitrogen (N2). This control applies to pulverized-dry bottom coal-fired 

electricity generation sources.

EPA 2006b, ERG 2000, 

EPA 1998b
Point & NonPoint NOx

Menu of Control Measures

Updated 4/12/2012

Printed 8/6/2013 23 of 67

Sector Source Category Emission Reduction 

Measure Name Control Efficiency (%)* Cost Effectiveness (2006$/ton reduced)

Other pollutants 

controlled Description/Notes/Caveats References

EGU Utility Boiler - Coal/ 

Tangential

Low NOx Coal-and-Air 

Nozzles with CrossCoupled and Separated 

Overfire Air

62

Cost effectiveness is 

variable and based on 

plant size: for a 300MW 

plant, total capital cost 

of $37.64 per kW; the 

fixed O&M costs of 

$0.30 per kW per year; 

and variable O&M costs 

of $0.030 mills per kWh.

The scaling factor for 

plants from 25MW 

(Capital Cost and Fixed 

O&M only) = 

(300/capacity)^(0.359). 

This control is the use of low NOx coal and air nozzles coupled with cross-coupled and separated overfire air to reduce 

NOx emissions. Over-fire air stages combustion by diverting combustion air from the burners to create a fuel rich zone in 

the furnace. This inhibits fuel-bound nitrogen conversion in coal fired boilers. This control is applicable to tangentially-fired 

coal utility boilers.

EPA 2006b, EPA 

2002a, EPA 2010a

EGU Utility Boiler - Coal/ 

Tangential

Low NOx Coal-and-Air 

Nozzles with crossCoupled Overfire Air42

Cost effectiveness is 

variable and based on 

plant size: for a 300MW 

plant, total capital cost 

of $23.77 per kW; the 

fixed O&M costs of 

$0.20 per kW per year; 

and variable O&M costs 

of $0.000 mills per kWh.

The scaling factor for 

plants from 25MW 

(Capital Cost and Fixed 

O&M only) = 

(300/capacity)^(0.359). 

This control is the use of low NOx coal and air nozzles coupled with cross-coupled overfire air to reduce NOx emissions. 

Over-fire air stages combustion by diverting combustion air from the burners to create a fuel rich zone in the furnace. This 

inhibits fuel-bound nitrogen conversion in coal fired boilers. This control is applicable to tangentially-fired coal utility 

boilers.

EPA 2006b, EPA 

2002a, EPA 2010a

EGU Utility Boiler - Coal/ 

Tangential

Low NOx Coal-and-Air 

Nozzles with separated 

Overfire Air

47

Cost effectiveness is 

variable and based on 

plant size: for a 300MW 

plant, total capital cost 

of $32.69 per kW; the 

fixed O&M costs of 

$0.20 per kW per year; 

and variable O&M costs 

of $0.030 mills per kWh.

The scaling factor for 

plants from 25MW 

(Capital Cost and Fixed 

O&M only) = 

(300/capacity)^(0.359). 

This control is the use of low NOx coal and air nozzles coupled with separated overfire air to reduce NOx emissions. Overfire air stages combustion by diverting combustion air from the burners to create a fuel rich zone in the furnace. This 

inhibits fuel-bound nitrogen conversion in coal fired boilers. This control is applicable to tangentially-fired coal utility 

boilers.

EPA 2006b, EPA 

2002a, EPA 2010a

EGU Utility Boiler - Coal/ 

Tangential Natural Gas Reburn 50

Cost effectiveness is 

variable and based on: 

plant size, the total 

capital cost of $32.41 

per kW, and the fixed 

O&M of $0.49 per kW 

per year

Natural gas reburning (NGR) involves add-on controls to reduce NOx emissions. NGR is a combustion control technology 

in which part of the main fuel heat input is diverted to locations above the main burners, called the reburn zone. As flue 

gas passes through the reburn zone, a portion of the NOx formed in the main combustion zone is reduced by 

hydrocarbon radicals and converted to molecular nitrogen (N2). This control applies to bituminous/subbituminous coalfired electricity generation sources, including sources with atmospheric fluidized bed combustion.

EPA 2006b, ERG 2000, 

EPA 2004b, EPA 

1998b, Staudt 1998

EGU Utility Boiler - Coal/ 

Tangential

Selective Catalytic 

Reduction 90 $1550-$2066 Hg - 95%

This control is the use of selective catalytic reduction add-on controls to tangentially coal-fired utility boilers for the 

reduction of NOx emissions. SCR controls are post-combustion control technologies based on the chemical reduction of 

nitrogen oxides (NOx) with a nitrogen based reducing reagent, such as ammonia or urea, to reduce the NOx into 

molecular nitrogen (N2) and water vapor (H2O). The SCR utilizes a catalyst to increase the NOx removal efficiency, which 

allows the process to occur at lower temperatures. This control applies to bituminous/subbituminous coal-fired electricity 

generation sources, including sources with atmospheric fluidized bed combustion with nameplate capacity greater than 

100 MW

EPA 2006b, EPA 

2002a, Massachusetts 

2002, EPA 2004b, EPA 

2001, EPA 1998b
Point & NonPoint NOx

Menu of Control Measures

Updated 4/12/2012

Printed 8/6/2013 24 of 67

Sector Source Category Emission Reduction 

Measure Name Control Efficiency (%)* Cost Effectiveness (2006$/ton reduced)

Other pollutants 

controlled Description/Notes/Caveats References

EGU Utility Boiler - Coal/ 

Tangential

Selective Non-Catalytic 

Reduction

Pulverized Coal: 35%;

Fluidized Bed: 50%

- Pulverized: cost 

effectiveness is variable 

and based on heat rate: 

total capital cost of 

$44.58/kW for 

9,000Btu/kWh to 

$47.55/kW for 

11,000Btu/kWh; fixed 

O&M costs of $0.99 per 

kW per year (do not 

depend on heat rate); 

variable O&M costs of 

$0.87 mills per kWh for 

9,000Btu/kWh to 1.07 

mills per kWh for 

11,000Btu/kWh.

- Fluidized: cost 

effectiveness is variable 

and based on plant size 

& heat rate: capital cost 

of $8.92/kW for 

1000MW & 

9,000Btu/kWh to 

$35.66/kW for 100MW 

& 11,000Btu/kWh; fixed 

O&M costs of $0.99 per 

kW per year for 

1000MW to $0.89per 

kW per year for 100MW 

(do not depend on heat 

rate); variable O&M 

This control is the use of selective non-catalytic reduction add-on controls to reduce NOx emissions from tangentially coalfired utility boilers. SNCR controls are post-combustion control technologies based on the chemical reduction of nitrogen 

oxides (NOx) with a nitrogen based reducing reagent, such as ammonia or urea, to reduce the NOx into molecular 

nitrogen (N2) and water vapor (H2O). This control applies to bituminous/subbituminous coal-fired electricity generation 

sources, including sources with atmospheric fluidized bed combustion.

EPA 2006b, EPA 2010a

EGU Utility Boiler - Coal/ Wall Selective Catalytic 

Reduction 90

Cost effectiveness is 

variable and based on 

plant size & heat rate: 

total capital cost of 

$145.61/kW for 

1000MW & 

9,000Btu/kWh to 

$255.57/kW for 100MW 

& 11,000Btu/kWh; fixed 

O&M costs of $0.40 per 

kW per year for 

1000MW to $2.48 per 

kW per year for 100MW 

(do not depend on heat 

rate); variable O&M 

costs of $1.14 mills per 

kWh for 9,000Btu/kWh 

to 1.32 mills per kWh 

for 11,000Btu/kWh.

This control is the use of selective catalytic reduction add-on controls to coal/wall fired utility boilers for the reduction of 

NOx emissions. SCR controls are post-combustion control technologies based on the chemical reduction of nitrogen 

oxides (NOx) with a nitrogen based reducing reagent, such as ammonia or urea, to reduce the NOx into molecular 

nitrogen (N2) and water vapor (H2O). The SCR utilizes a catalyst to increase the NOx removal efficiency, which allows 

the process to occur at lower temperatures. This control applies to pulverized-dry bottom coal-fired electricity generation 

sources with a nameplate capacity greater than 25 MW.

EPA 2006b, EPA 

2002a, EPA 1998b, 

EPA 2010a
Point & NonPoint NOx

Menu of Control Measures

Updated 4/12/2012

Printed 8/6/2013 25 of 67

Sector Source Category Emission Reduction 

Measure Name Control Efficiency (%)* Cost Effectiveness (2006$/ton reduced)

Other pollutants 

controlled Description/Notes/Caveats References

EGU Utility Boiler - Coal/ Wall Selective Non-Catalytic 

Reduction 35

Cost effectiveness is 

variable and based on 

heat rate: total capital 

cost of $44.58/kW for 

9,000Btu/kWh to 

$47.55/kW for 

11,000Btu/kWh; fixed 

O&M costs of $0.99 per 

kW per year (do not 

depend on heat rate); 

variable O&M costs of 

$0.87 mills per kWh for 

9,000Btu/kWh to 1.07 

mills per kWh for 

11 000Bt /kWh

This control is the reduction of NOx emission through selective non-catalytic reduction add-on controls to wall fired (coal) 

utility boilers. SNCR controls are post-combustion control technologies based on the chemical reduction of nitrogen 

oxides (NOx) with a nitrogen based reducing reagent, such as ammonia or urea, to reduce the NOx into molecular 

nitrogen (N2) and water vapor (H2O). This control applies to pulverized-dry bottom coal-fired electricity generation 

sources with a nameplate capacity greater than 25 MW.

EPA 2006b, EPA 2010a

EGU Utility Boiler - Cyclone Natural Gas Reburn 50

Cost effectiveness is 

variable and based on: 

plant size, the total 

capital cost of $32.41 

per kW, and the fixed 

O&M of $0.49 per kW 

per year

Natural gas reburning (NGR) involves add-on controls to reduce NOx emissions. NGR is a combustion control technology 

in which part of the main fuel heat input is diverted to locations above the main burners, called the reburn zone. As flue 

gas passes through the reburn zone, a portion of the NOx formed in the main combustion zone is reduced by 

hydrocarbon radicals and converted to molecular nitrogen (N2). This control applies to pulverized-dry bottom coal-fired 

electricity generation sources with cyclone furnaces. 

EPA 2006b, ERG 2000, 

EPA 1998b

EGU Utility Boiler - Cyclone Selective Catalytic 

Reduction 90

Cost effectiveness is 

variable and based on 

plant size & heat rate: 

total capital cost of 

$145.61/kW for 

1000MW & 

9,000Btu/kWh to 

$255.57/kW for 100MW 

& 11,000Btu/kWh; fixed 

O&M costs of $0.40 per 

kW per year for 

1000MW to $2.48 per 

kW per year for 100MW 

(do not depend on heat 

rate); variable O&M 

costs of $1.14 mills per 

kWh for 9,000Btu/kWh 

to 1.32 mills per kWh 

for 11,000Btu/kWh.

This control reduces NOx emissions using selective catalytic add-on controls on utility boilers with cyclone burners. SCR 

controls are post-combustion control technologies based on the chemical reduction of nitrogen oxides (NOx) with a 

nitrogen based reducing reagent, such as ammonia or urea, to reduce the NOx into molecular nitrogen (N2) and water 

vapor (H2O). The SCR utilizes a catalyst to increase the NOx removal efficiency, which allows the process to occur at 

lower temperatures. This control applies to bituminous/subbituminous coal-fired electricity generation sources with 

cyclone furnaces and nameplate capacity greater than 25 MW.

EPA 2006b, EPA 

2002a, EPA 1998b, 

EPA 2010a

EGU Utility Boiler - Cyclone Selective Non-Catalytic 

Reduction 35

Cost effectiveness is 

variable and based on 

heat rate: total capital 

cost of $44.58/kW for 

9,000Btu/kWh to 

$47.55/kW for 

11,000Btu/kWh; fixed 

O&M costs of $0.99 per 

kW per year (do not 

depend on heat rate); 

variable O&M costs of 

$0.87 mills per kWh for 

9,000Btu/kWh to 1.07 

mills per kWh for 

11 000Bt /kWh

This control is the use of selective non-catalytic reduction add-on controls to cyclone utility boilers to reduce NOx 

emissions. SNCR controls are post-combustion control technologies based on the chemical reduction of nitrogen oxides 

(NOx) with a nitrogen based reducing reagent, such as ammonia or urea, to reduce the NOx into molecular nitrogen (N2) 

and water vapor (H2O). This control applies to bituminous/subbituminous coal-fired electricity generation sources with 

cyclone furnaces with a nameplate capacity greater than 25 MW.

EPA 2006b, EPA 2010a
Point & NonPoint NOx

Menu of Control Measures

Updated 4/12/2012

Printed 8/6/2013 26 of 67

Sector Source Category Emission Reduction 

Measure Name Control Efficiency (%)* Cost Effectiveness (2006$/ton reduced)

Other pollutants 

controlled Description/Notes/Caveats References

EGU Utility Boiler - Oil-Gas/ 

Tangential Natural Gas Reburn 50

Cost effectiveness is 

variable and based on: 

plant size, the total 

capital cost of $32.41 

per kW, and the fixed 

O&M of $0.49 per kW 

per year

Natural gas reburning (NGR) involves add-on controls to reduce NOx emissions. NGR is a combustion control technology 

in which part of the main fuel heat input is diverted to locations above the main burners, called the reburn zone. As flue 

gas passes through the reburn zone, a portion of the NOx formed in the main combustion zone is reduced by 

hydrocarbon radicals and converted to molecular nitrogen (N2). This control applies to tangentially natural-gas fired 

electricity generation sources.

EPA 2006b, ERG 2000, 

EPA 1998b

EGU Utility Boiler - Oil-Gas/ 

Tangential

Selective Catalytic 

Reduction 80

Cost effectiveness is 

variable and based on 

plant size. For a 25MW 

plant, capital costs are 

$74.29 per kW, fixed 

O&M costs are $1.07 

per kW per year. 

Variable O&M costs are 

0.12 mills per kWh (do 

not depend on plant 

size). The scaling factor 

for plants between 

25MW and 500MW 

(Capital Cost and Fixed 

O&M only) = 

(200/capacity)^(0.35). 

After 500MW, costs 

This control is the selective catalytic reduction of NOx through add-on controls to tangentially fired (oil/gas) utility boilers. 

SCR controls are post-combustion control technologies based on the chemical reduction of nitrogen oxides (NOx) with a 

nitrogen based reducing reagent, such as ammonia or urea, to reduce the NOx into molecular nitrogen (N2) and water 

vapor (H2O). The SCR utilizes a catalyst to increase the NOx removal efficiency, which allows the process to occur at 

lower temperatures. This control applies to tangentially natural-gas fired electricity generation sources with nameplate 

capacity greater than 25 MW.

EPA 2006b, EPA 

2002a, EPA 1998b, 

EPA 2010a

EGU Utility Boiler - Oil-Gas/ 

Tangential

Selective Non-Catalytic 

Reduction 50

Cost effectiveness is 

variable and based on 

plant size. For a 

200MW plant, capital 

costs are $11.5 per kW, 

fixed O&M costs are 

$0.18 per kW per year. 

Variable O&M costs are 

0.53 mills per kWh (do 

not depend on plant 

size). The scaling factor 

for plants between 

25MW and 500MW 

(Capital Cost and Fixed 

O&M only) = 

(200/capacity)^(0.577). 

After 500MW, costs 

This control reduces NOx emissions using selective non-catalytic reduction add-on controls to tangentially fired (oil/gas) 

utility boilers. SNCR controls are post-combustion control technologies based on the chemical reduction of nitrogen 

oxides (NOx) with a nitrogen based reducing reagent, such as ammonia or urea, to reduce the NOx into molecular 

nitrogen (N2) and water vapor (H2O). The control applies to tangentially natural-gas fired electricity generation sources 

with nameplate capacity greater than 25 MW.

EPA 2006b, EPA 2006g

EGU Utility Boiler - Oil-Gas/ 

Wall Natural Gas Reburn 50

Cost effectiveness is 

variable and based on: 

plant size, the total 

capital cost of $32.41 

per kW, and the fixed 

O&M of $0.49 per kW 

per year

Natural gas reburning (NGR) involves add-on controls to reduce NOx emissions. NGR is a combustion control technology 

in which part of the main fuel heat input is diverted to locations above the main burners, called the reburn zone. As flue 

gas passes through the reburn zone, a portion of the NOx formed in the main combustion zone is reduced by 

hydrocarbon radicals and converted to molecular nitrogen (N2). This control applies to natural-gas fired electricity 

generation sources, excluding tangentially fired sources.

EPA 2006b, ERG 2000, 

EPA 1998b
Point & NonPoint NOx

Menu of Control Measures

Updated 4/12/2012

Printed 8/6/2013 27 of 67

Sector Source Category Emission Reduction 

Measure Name Control Efficiency (%)* Cost Effectiveness (2006$/ton reduced)

Other pollutants 

controlled Description/Notes/Caveats References

EGU Utility Boiler - Oil-Gas/ 

Wall

Selective Catalytic 

Reduction 80

Cost effectiveness is 

variable and based on 

plant size. For a 

200MW plant, capital 

costs are $74.29 per 

kW, fixed O&M costs 

are $1.07 per kW per 

year. Variable O&M 

costs are 0.12 mills per 

kWh (do not depend on 

plant size). The scaling 

factor for plants 

between 25MW and 

500MW (Capital Cost 

and Fixed O&M only) = 

(200/capacity)^(0.35). 

After 500MW, costs 

This control is the selective catalytic reduction of NOx through add-on controls to wall fired (oil/gas) utility boilers. SCR 

controls are post-combustion control technologies based on the chemical reduction of nitrogen oxides (NOx) with a 

nitrogen based reducing reagent, such as ammonia or urea, to reduce the NOx into molecular nitrogen (N2) and water 

vapor (H2O). The SCR utilizes a catalyst to increase the NOx removal efficiency, which allows the process to occur at 

lower temperatures. This control applies to large (>100 million Btu/hr) natural-gas fired electricity generation sources with 

nameplate capacity greater than 25 MW, excluding tangentially fired sources.

EPA 2006b, EPA 

2002a, EPA 1998b, 

EPA 2010a

EGU Utility Boiler - Oil-Gas/ 

Wall

Selective Non-Catalytic 

Reduction 50

Cost effectiveness is 

variable and based on 

plant size. For a 

200MW plant, capital 

costs are $11.5 per kW, 

fixed O&M costs are 

$0.18 per kW per year. 

Variable O&M costs are 

0.53 mills per kWh (do 

not depend on plant 

size). The scaling factor 

for plants between 

25MW and 500MW 

(Capital Cost and Fixed 

O&M only) = 

(200/capacity)^(0.577). 

After 500MW, costs 

This control is the use of selective non-catalytic reduction add-on controls to wall fired (oil/gas) utility boilers for the 

reduction of NOx emissions. SNCR controls are post-combustion control technologies based on the chemical reduction of 

nitrogen oxides (NOx) with a nitrogen based reducing reagent, such as ammonia or urea, to reduce the NOx into 

molecular nitrogen (N2) and water vapor (H2O). The control applies to natural-gas fired electricity generation sources with 

nameplate capacity greater than 25 MW, excluding tangentially fired sources.

EPA 2006b, EPA 2006g

EGU

Utility Boiler - 

Subbituminous Coal -

Wall Fired

Low NOx Burner and 

Over Fire Air 72

Cost effectiveness is 

variable and based on 

plant size. For a 

300MW plant, total 

capital cost of $60.43 

per kW; fixed O&M 

costs of $0.40 per kW 

per year; and variable 

O&M costs of $0.09 

mills per kW per year. 

Scaling factor for plants 

from 25MW (Capital 

Cost and Fixed O&M 

only) = 

(300/ it )^(0 359) 

This control is the use of low NOx burner (LNB) technology to reduce NOx emissions. LNBs reduce the amount of NOx 

created from reaction between fuel nitrogen and oxygen by lowering the temperature of one combustion zone and 

reducing the amount of oxygen available in another. This control applies to wall fired (coal) utility boilers with nameplate 

capacity greater than 25 MW.

EPA 2006b, EPA 

2002a, EPA 2010a
Point & NonPoint NOx

Menu of Control Measures

Updated 4/12/2012

Printed 8/6/2013 28 of 67

Sector Source Category Emission Reduction 

Measure Name Control Efficiency (%)* Cost Effectiveness (2006$/ton reduced)

Other pollutants 

controlled Description/Notes/Caveats References

EGU

Utility Boiler - 

Subbituminous Coal/ 

Wall Fired 

Low NOx Burner 57

Cost effectiveness is 

variable and based on 

plant size. For a 

300MW plant, total 

capital cost of $44.58 

per kW; fixed O&M 

costs of $0.30 per kW 

per year; and variable 

O&M costs of $0.07 

mills per kW per year. 

Scaling factor for plants 

from 25MW (Capital 

Cost and Fixed O&M 

only) = 

(300/ it )^(0 359) 

This control is the use of low NOx burner (LNB) technology to reduce NOx emissions. LNBs reduce the amount of NOx 

created from reaction between fuel nitrogen and oxygen by lowering the temperature of one combustion zone and 

reducing the amount of oxygen available in another. This control applies to wall fired coal utility boilers with nameplate 

capacity greater than 25 MW.

EPA 2006b, EPA 

2002a, EPA 2010a

* control efficiencies were rounded up to the closest whole number.
Point & NonPoint VOC

Menu of Control Measures

Updated 4/12/2012

Printed 8/6/2013 29 of 67

Sector Source Category Emission Reduction 

Measure Name Control Efficiency (%)* Cost Effectiveness (2006$/ton reduced) Description/Notes/Caveats References

NonPoint Adhesives - Industrial Reformulation 73 $3,534

This control is the use of product reformulation and product substitution for industrial adhesives to achieve VOC emissions 

reductions. It is based on SCAQMD rule 1168, which requires the use of waterborne, hot melt, UV cured or reactive diluent 

adhesives. Add-on controls such as carbon absorption and afterburners are more costly for this source category and 

generally not used.

Pechan 1997, SCAQMD 

1996a

NonPoint Aerosol Coatings 19

EPA promulgated national VOC emission standards for aerosol coatings during 2008. EPA estimated that the aerosol 

coatings rule will achieve the equivalent of a 19 percent reduction in mass VOC emissions from the 1990 baseline. The year 

1990 represents the baseline, since there has been no previous Federal rulemaking for aerosol coatings. The creditable 

reduction that may be claimed is 0.114 pounds per capita. To estimate equivalent VOC mass reductions for credit purposes, 

EPA computed the VOC reductions that would have been achieved by a mass-based rule equivalent in ozone formation 

reduction to the reactivity-based rule. This calculation was based in work done by the California ARB. ARB had previously 

developed a mass-based rule whose limits were later determined to be technically infeasible. The California reactivity-based 

rule was developed by ARB as an equivalent replacement for the mass-based rule's VOC limits.

NonPoint

Architectural, Traffic, and 

Industrial Maintenance 

Coatings

OTC Model Rule 31 $6,612

The baseline against which the control efficiencies are listed for this source category comes from the existing Federal AIM 

rule 40CFR Part 59 from 2002, which is estimated to provide a 20 percent VOC reduction from the uncontrolled (1990 

baseline) emissions. The OTC developed a Model Rule for AIM Coatings that requires manufacturers to reformulate coatings 

to meet specified VOC content limits, which are based on the SCM adopted by ARB and the STAPPA/ALAPCO model rule for 

AIM Coatings. 

LADCO 2006b, OTC 

2001b

NonPoint

Architectural, Traffic, and 

Industrial Maintenance 

Coatings

OTC Model Rule and 

South Coast -Rule 1113 

Phase III VOC limits

40 $20,664

This control is the adoption of SCAQMD Rule 1113 Phase III VOC Emission Limits in addition to the Architectural, Traffic, and 

Industrial Maintenance (AIM) coatings OTC Model Rule limits. Phase III relies on near-zero or zero VOC formulations for 

several architectural coating categories including, but not limited to, cleanup and thinning solvents, clear wood finishes, 

exterior opaque stains, semi-transparent stains, sanding sealers, and waterproofing sealers. 

OTC 2001a, LADCO 

2006b

NonPoint Bakery Products Catalytic Incineration 40 $2,359

The control measure is based on the regulation adopted by the BAAQMD, which assumes emissions reductions from the use 

of catalytic incinerators. These incinerators use a catalyst to achieve very high control efficiencies at relatively low operating 

temperatures (320 to 650 °C). The BAAQMD control requirements affect only large, commercial bread bakeries. The 

equivalent SCAQMD Rule is 1153.

EPA 1990a, EPA 1992c, 

EPA 1995c, M&S 1991, 

Schultz 1997

NonPoint

Coating Operations at 

Aerospace 

Manufacturing and 

Rework Operations

Control Technology 

Guidelines 18-50

This CTG identifies presumptive RACT for controlling VOC emissions from aerospace coatings and cleaning solvents. The 

baseline against which the control efficiencies are listed for this source category comes from the aerospace manufacturing 

and rework operations NESHAP federal rule (60 FR 45948). Aerospace manufacturing and rework operations typically 

consist of the following basic operations: materials receiving, machining and mechanical processing, coating application, 

chemical milling, heat treating, cleaning, metal processing and finishing, coating removal (depainting), composite processing, 

and testing. Of these operations, coating application and

cleaning are the significant sources of VOC emissions and are the processes covered by this CTG. The principal technique 

used by the aerospace industry to control VOC emissions is product substitution, which eliminates or reduces the generation 

of emissions (waterborne and high solids materials used as coating substitution). Several equipment changes can also 

directly reduce the level of VOC emissions (high transfer efficiency spray guns, spray gun cleaners, and conventional high 

transfer efficiency methods). The control efficiency range provided if for equipment change.

EPA 1997f

NonPoint Cold Cleaning 

Degreasing Process Modification 95 $15,703 This control is modifications to the cold cleaning process to reduce the fugitive VOC emissions. This is based on SCAQMD 

Rule 1122, which was most recently amended in 2009.

SCAQMD 1996a, 

SCAQMD 1997

NonPoint Cold Cleaning 

Degreasing

Reformulation-Process 

Modification (OTC Rule) 8 $1,688

The baseline against which the control efficiencies are listed for this source category comes from the MACT standard for Cold 

Cleaning processes. This control establishes hardware and operating requirements for specified vapor cleaning machines, as 

well as solvent volatility limits and operating practices for cold cleaners.

SCAQMD 1997, OTC 

2001a
Point & NonPoint VOC

Menu of Control Measures

Updated 4/12/2012

Printed 8/6/2013 30 of 67

NonPoint Consumer Products

California Consumer 

Products Rules 

Cumulative through 2010 

Proposed Amendments

50 $3,498

Over the last 20 years, the California Air Resources Board has taken numberous actions to reduce VOC from consumer 

products. Five regulations have been adopted which have resulted in a cumulative 50% reduction from VOC projections from 

1990 levels. Each of the individual changes to the consumer products rules in California that have been enacted since 2006 

have been in pursuit of the long-term committment to reduce emissions from this category by 80 percent.

This control is the use of 

low NOx burner (LNB) 

technology and selective 

non-catalytic reduction 

(SNCR) to reduce NOx 

emissions. LNBs reduce 

the amount of NOx 

created from reaction 

between fuel nitrogen 

and oxygen by lowering 

the temperature of one 

combustion zone and 

reducing the amount of 

oxygen available in 

another. SNCR controls 

are post-combustion 

control technologies 

based on the chemical 

reduction of nitrogen 

oxides (NOx) into 

molecular nitrogen (N2) 

and water vapor (H2O). 

This control is applicable 

to process heaters fired 

with distillate, residual 

oil, and other 

unclassified fuels.

NonPoint Consumer Products Reformulation (2001 

OTC Model Rule) 14 $1,244

The baseline against which the control efficiencies for this category are listed comes from Clean Air Act Section 183(e) VOC 

Rules, which is considered a 9.7 percent reduction from uncontrolled levels (20% reduction for products covered by the rule; 

only 48.6% of products are covered.) The OTC model rule regulates approximately 80 consumer product categories, and 

uses more stringent VOC content limits then the Federal rule. Examples include aerosol adhesives, floor wax strippers, dry 

cleaning fluids, and general purpose cleaners. It also contains administrative requirements for labeling, reporting, codedating, 

and a most restrictive limit scenario. There is a reporting requirement, such that manufacturers may be required to submit 

information to the State upon written notice. 

OTC 2001a, ARB 1999

NonPoint Consumer Products Reformulation (2006 

OTC Model Rule) 16 $4,820 This control was based on a 2% improvement to the 2001 OTC Model rule for this source category. It consists of lower VOC content limits than the 2001 Model Rule. OTC 2007

NonPoint Cutback Asphalt Reformulation-Process 

Modification 100 $24 This control includes the use of reformulated products and the modification of processes associated with cutback asphalt 

manufacturing to reduce the fugitive VOC emissions. EPA 1997c

NonPoint Flexographic Printing Permanent Total 

Enclosure (PTE) 90 $15,074

A permanent total enclosure (PTE) completely surrounds a source of emissions such that all VOC emissions are captured 

and contained for discharge to a control device. 

Flexographic printing is classified into two categories: wide-web and narrow-web flexographic printing. Wide-web flexographic 

printing is used to print flexible and rigid paper, plastic and aluminum foil packaging, newspapers, magazines, directories, 

paper towels, etc. Narrow-web flexographic printing is primarily used for printing and adhesive application on paper, foil and 

film tags and labels. The EPA evaluated VOC emission control options for the flexographic printing industry including the use 

of a PTE in conjunction with a thermal oxidizer in the MACT standard-setting process for this source category. The option 

presented here has applicability to flexographic printing that uses "high" VOC content materials.

EPA 2006b

NonPoint Metal Can Surface 

Coating Incineration 84 $14,344

This control measure based on the use of incineration to reduce VOC emissions from metal can coating facilities .Coatings 

are applied to metal cans to improve appearance and prevent corrosion. This rule is assumed to cover both two and three 

piece can coating. This control applies to area source VOC emissions for the metal can coating source category. The option 

presented here has applicability to processes that use "high" VOC content materials (solvent-borne materials).

EPA 1998d
Point & NonPoint VOC

Menu of Control Measures

Updated 4/12/2012

Printed 8/6/2013 31 of 67

NonPoint Metal Can Surface 

Coating

Permanent Total 

Enclosure (PTE) 92 $9,621

A permanent total enclosure (PTE) completely surrounds a source of emissions such that all VOC emissions are captured 

and contained for discharge to a control device. 

A metal can is defined as a usually cylindrical metal container, but governmental agencies and industry groups use differing 

criteria to identify cans including shape, materials, capacity, phase of product contained, and material thickness (gauge). 

Decorative tins, bottle caps and jar lids are also included in the can coating category since many of these items are coated on 

the same line where can coating takes place. Cans consist of can bodies and can ends. Metal can surface coating facilities 

include two-piece beverage can body facilities, twopiece food can body facilities, one-piece aerosol can body facilities, 

sheetcoating facilities, three-piece food can body assembly facilities, three-piece non-food can body assembly facilities, and 

end lining facilities. EPA evaluated VOC emission control options for the two-piece beverage can, twopiece food can and 

sheetcoating facilities using a PTE in conjunction with a thermal oxidizer in the MACT standard-setting process for this source 

category. The option presented here has applicability to processes that use "high" VOC content materials (solvent-borne 

materials).

EPA 2006b

NonPoint Metal Can Surface 

Coating Process Modification 9 $3,221

The baseline against which the control efficiencies are listed for this source category comes from the Metal Can Surface 

Coating NESHAP federal rule (68 FR 64432). This control includes modifications to the metal can coating process to reduce 

the fugitive VOC emissions. This control measure is based on the 1997 amendment to the San Francisco Bay Area AQMD 

rule which defined VOC content limits for body spray coatings for both two and three piece cans and set VOC limits for end 

sealing compounds for non-food products; and set limits for interior and exterior body sprays used on drums, pails, and lids 

(BAAQMD, 1999).

BAAQMD 1999

NonPoint Metal Coil Surface 

Coating Incineration 84 $14,344

This control measure based on the use of incineration to reduce VOC emissions from metal coil coating facilities. Coatings 

are applied to metal coils to improve appearance and prevent corrosion. This rule is assumed to cover both two and three 

piece coil coating. This control applies to area source VOC emissions for the metal coil coating source category. The option 

presented here has applicability to processes that use "high" VOC content materials (solvent-borne materials).

EPA 1998d

NonPoint Metal Coil Surface 

Coating

Permanent Total 

Enclosure (PTE) 92 $9,621

A permanent total enclosure (PTE) completely surrounds a source of emissions such that all VOC emissions are captured 

and contained for discharge to a control device. 

A metal can is defined as a usually cylindrical metal container, but governmental agencies and industry groups use differing 

criteria to identify cans including shape, materials, capacity, phase of product contained, and material thickness (gauge). 

Decorative tins, bottle caps and jar lids are also included in the can coating category since many of these items are coated on 

the same line where can coating takes place. Cans consist of can bodies and can ends. Metal can surface coating facilities 

include two-piece beverage can body facilities, twopiece food can body facilities, one-piece aerosol can body facilities, 

sheetcoating facilities, three-piece food can body assembly facilities, three-piece non-food can body assembly facilities, and 

end lining facilities. EPA evaluated VOC emission control options for the two-piece beverage can, twopiece food can and 

sheetcoating facilities using a PTE in conjunction with a thermal oxidizer in the MACT standard-setting process for this source 

category. The option presented here has applicability to processes that use "high" VOC content materials (solvent-borne 

materials).

EPA 2006b

NonPoint Metal Coil Surface 

Coating Process Modification 9 $3,221

The baseline against which the control efficiencies are listed for this source category comes from the Metal Coil Surface 

Coating NESHAP federal rule (68 FR 39793). This control includes modifications to the metal coil coating process to reduce 

the fugitive VOC emissions. This control measure is based on the 1997 amendment to the San Francisco Bay Area AQMD 

rule which defined VOC content limits for body spray coatings for both two and three piece cans and set VOC limits for end 

sealing compounds for non-food products; and set limits for interior and exterior body sprays used on drums, pails, and lids 

(BAAQMD, 1999).

BAAQMD 1999

NonPoint Metal Furniture Surface 

Coating

Reduced Solvent 

Utilization 84 $118

The baseline against which the control efficiencies are listed for this source category comes from the Metal Furniture Surface 

Coating NESHAP federal rule (68 FR 28605). This control is the implementation of reduced solvent utilization to reduce VOC 

emissions from metal furniture surface coating.

STAPPA/ALAPCO 1993, 

CDPR 1999

NonPoint Metal Furniture, 

Appliances, Parts

Reformulation-Process 

Modification 36 $4,043

The SCAQMD amended rule 1107 sets stringent VOC emission limits for metal coatings. VOC emissions can be reduced by 

using reformulated low-VOC content compliant coatings, powder coating for both general and high gloss coatings, UV curable 

coatings, high transfer efficiency coating applications, and increased effectiveness of add-on control equipment. The metal 

coating source category classifies emissions that result from the coating of metal parts and products including machinery and 

equipment and railroad rolling stock. In 2006, this rule was amended again, ratcheting down the VOC limits on certain 

categories of coatings and making HVLP sprayers mandatory for all end users.

SCAQMD 1996a, EPA 

1995h, SCAQMD 2005b
Point & NonPoint VOC

Menu of Control Measures

Updated 4/12/2012

Printed 8/6/2013 32 of 67

NonPoint Metal part and Products 

coating

Reformulation-Process 

Modification 36 $4,043

The baseline against which the control efficiencies are listed for this source category comes from the Miscellaneous Metal 

Parts and Products Surface Coating NESHAP federal rule (69 FR 22601). The SCAQMD amended rule 1107 sets stringent 

VOC emission limits for metal coatings. VOC emissions can be reduced by using reformulated low-VOC content compliant 

coatings, powder coating for both general and high gloss coatings, UV curable coatings, high transfer efficiency coating 

applications, and increased effectiveness of add-on control equipment. The metal coating source category classifies 

emissions that result from the coating of metal parts and products including machinery and equipment and railroad rolling 

stock. In 2006, this rule was amended again, ratcheting down the VOC limits on certain categories of coatings and making 

HVLP sprayers mandatory for all end users.

SCAQMD 1996a, 

SCAQMD 2001, 

SCAQMD 2005b

NonPoint Mobile Equipment 

Repair and Refinishing

California Air Resources 

Board - Suggested 

Control Measures for 

Automotive Coatings

89 $6,400

This control is the implementation of suggested control measures developed by ARB for the various air districts. The SCM 

proposes VOC limit standards for various coating categories. Any coating that can be used in more than one category is 

subject ot the most restrictive VOC content limit. The proposed SCM also prohibits anyone from applying, manufacturing, 

blending, repackaging for sale, supplying, offering for sale, distributing, possessing (at an automotive refinishing facility) or 

selling any coating that does not meet the VOC limits. It also specifies the manner in which coatings may be applies, 

restricting application to brushing, dipping, rolling, electrostatic spraying, or spraying with a high-volume, low-pressure spray 

gun or an approved equivalent.

OTC 2001a, ARB 2005b

NonPoint Mobile Equipment 

Repair and Refinishing OTC Model Rule 38 $1,850

The baseline against which the control efficiencies are listed for this source category come from the EPA's published 

standards limiting VOC content in coatings sold for automobile refinishing published in 1998, which represent a 37% 

reduction from uncontrolled levels. In 2001, the Ozone Transport Commission (OTC) developed a model rule based on the 

use of high transfer-efficiency painting methods (e.g., high volume low pressure spray guns), and controls on emissions from 

equipment (e.g., spray gun) cleaning, housekeeping activities (e.g., use of sealed containers for clean-up rags), and operator 

training. The OTC model rule has the same VOC content limits as the federal rule except for slightly more stringent limits for 

primer/surfacer coatings and three- or four-stage topcoats. An incremental control effectiveness of 38 percent was estimated 

for the OTC model rule relative to the National Rule (or 60 percent reduction from uncontrolled levels). This estimate includes 

a 35 percent reduction from the use of high transfer efficiency spray guns and another 3 percent from the use of enclosed 

spray gun cleaners.

OTC 2001a, LADCO 

2006c, OTC 2007

NonPoint Municipal Solid Waste 

Landfill Gas Recovery 70 $1,089 This control is the application of gas capture systems to cappable landfills to reduce the VOC emissions from decaying organic matter. The majority of the VOC captured is methane. CDPR 1999

NonPoint Open Top Degreasing Process Modification 97 $15,711 This control is modifications to the open top degreasing process to reduce the fugitive VOC emissions. SCAQMD 1996a, 

SCAQMD 1997

NonPoint Open Top Degreasing Reformulation-Process 

Modification 65 $2,003

VOC emissions from degreasing operations can be reduced by the use of low-VOC content solvents, and by changes in 

operating practices. This rule was originally adopted in 1979, but has since been amended to specify maximum ventilating 

conditions, minimize drag-out losses, eliminate some rule exemptions, expand the rule to smaller cold degreasers, and further 

limit the solvent content of waste materials.

SCAQMD 1996a, 

SCAQMD 1997

NonPoint Pesticide Application Reformulation 20 $14,926

The California Federal Implementation Plan (FIP) rule intends to reach the VOC limits by switching to and/or encouraging the 

use of low-VOC pesticides and better Integrated Pest Management (IPM) practices. All types of pesticide applications are 

affected by this rule.

Radian 1994b

NonPoint Petroleum Refinery 

Fugitives Process Modification 78 $1,290 This control is modifications to the petroleum refining process to reduce the fugitive VOC emissions. EPA 2006b

NonPoint

Pharmaceutical and 

Cosmetic Manufacturing 

Operations

SCAQMD Rule 1103 90

This rule applies to the manufacture of pharmaceutical and cosmetic products by chemical

processes including medicinal chemicals such as antibiotics and vitamins, botanical and biological products. VOC emissions 

reduction is achieved through a combination of Equipment Requirements and Operating Requirements. Equipment 

Requirements include limits on VOC emissions from reactors, distillation columns, crystallizers, or centrifuges and/or requires 

control devices to be used in combination with these pieces of equipment. Operating Requirements focus on VOC emissions 

limits for production equipment such as air dryers, or during transfers from trucks into storage tanks, as well as requires 

repairing all liquid leaks within 24 hours of detection.

SCAQMD 1999c

NonPoint Polystyrene Foam 

Manufacturing

Control Technology 

Guidelines 95-99

$2,070-$10,898 for 

carbon adsorption

$6,500-$17,815 for 

incinerators

This CTG identifies measures for controlling VOC emissions from Polystyrene Foam Manufacturing. Controls include 

incineration and carbon adsorption. For the range of VOC concentrations encountered in Polystyrene Foam Manufacturing, 

thermal incinerators can achieve 99% efficiency while catalytic incinerators can achieve 95% efficiency. As for carbon 

adsorption devices, the expected removal efficiency is 99%.

EPA 1990b

NonPoint Rubber/Plastics Coating Reformulation-Process 

Modification 60 $7,350

SCAQMD Rule 1145 - Plastic, Rubber, and Glass Coatings was adopted to reduce VOC emissions from plastic, rubber, and 

glass operations. Since its adoption, this rule has been amended numerous times incorporating more stringent VOC limits as 

the technology and low VOC coatings have become available. The last amendment in March 1996 was to exempt aerosol 

coatings and to provide rule consistency with the recently adopted ARB Aerosol Coating Products Rule. There are a variety of 

control methods to reduce VOCs from plastic, rubber, and glass coatings operations. VOC emissions can be reduced by 

using reformulated low-VOC content compliant coatings, UV curable coatings, high transfer efficiency coating applications 

and increased effectiveness of add-on control equipment.

SCAQMD 1996a
Point & NonPoint VOC

Menu of Control Measures

Updated 4/12/2012

Printed 8/6/2013 33 of 67

NonPoint

Shipbuilding and Ship 

Repair (Surface 

Coating) 

Incineration 87 $14,344

Four California air quality districts have adopted more stringent VOC marine coating emission limits than those specified in 

the 1995 Shipbuilding and Ship Repair (Surface Coating) MACT standard. However, the California limits are not uniformly 

applied across each coating category or in each of the four districts. Since the California limits do not allowances for cold 

weather coating limits that are less strinegnt than the warm weather ones, the ability to apply coatings effectively could be 

compromised in areas of the country with colder climates if the more stringent California limits are applied as is. 

EPA 1998d

NonPoint

Stage II Service Stations 

- Underground Tanks 

(Breathing and 

Emptying)

LPV Relief Valve 73 $1,736

This control measure is the addition of low pressure/vacuum (LP/V) relief valves to underground gasoline storage tanks at 

service stations with Stage II control systems. LP/V relief valves prevent breathing emissions from gasoline storage tank vent 

pipes. This control measure applies to all gasoline service stations with underground gasoline storage tanks.

EPA 1995e, SCAQMD 

1995b

NonPoint Storage Tanks at 

Petroleum Facilities SCAQMD Rule 1178 95 $10,387 - $12,695 per ton ROG

Large storage tanks of high volatile VOC compounds having true vapor pressure greater or equal to 3 psia at refineries are 

major source of ROG. The purpose of this rule is to reduce emissions of volatile organic compounds (VOC) from storage 

tanks located at petroleum facilities. Geodesic doming is an achieved-in-practice control option. Cost effectiveness for 

doming is about $9,000 - $11,000 per ton (2001$, DCF, ROG). The lower end cost effectiveness is without foam 

suppressant, and the upper end is with foam suppressant. Rule 1178 also includes other control options for seals, 

guidepoles etc. to reduce evaporation losses from external floating roof tanks, internal floating roof tanks, and fixed roof 

tanks. The tank emissions are vented to an emission control system with an overall control efficiency of at least 95% by

weight.

SCAQMD 2012

NonPoint Wood Furniture Surface 

Coating Add-On Controls 64 $32,099

This control measure is generic in that it represents potential add-on controls available for this source category. Add-on 

controls include thermal incinerators, catalytic incinerators, and a combination of carbon absorbers and catalytic incinerators. 

This control applies to all wood furniture coating applications.

EPA 1999e, EPA 1996c

NonPoint Wood Furniture Surface 

Coating

Control Technology 

Guidelines 24 $1,552

The baseline against which the control efficiencies are listed for this source category comes from the Wood Furniture Surface 

Coating NESHAP federal rule (40 CFR 63,subpart JJ). The Wood Furniture Coating CTG, published in 1996, applies to 

ozone nonattainment areas and the Ozone Transport Region (OTR). This will affect facilities emitting 25 tons per year or 

more. The Wood furniture coating industry covers 10 SIC codes including: Wood Kitchen Cabinets; Wood Household 

Furniture (except upholstered); Wood Household Furniture (upholstered); Wood Television, Radios, Phonograph, and 

Sewing Machine Cabinets; Household Furniture Not Classified Elsewhere; Wood Office Furniture; Public Building and 

Related Furniture; Wood Office and Store Fixtures; Furniture and Fixtures Not Elsewhere Classified; and Custom Kitchen 

Cabinets.

EPA 1996c

NonPoint Wood Product Surface 

Coating Incineration 80

ARB estimates 

$2,219/ton, Others 

estimate $6,340 to 

$16,840/ton)

This is a generic control measure based on the use of incineration to reduce VOC emissions from wood product surface 

coating facilities. This control measure applies to sources classified as factory finished wood producers. EPA 2006b

NonPoint Wood Product Surface 

Coating Reformulation 33 $1,414 This control is the use of product reformulation and product substitution for wood product surface coatings to achieve VOC emissions reductions.

SCAQMD 1996b, 

SCAQMD 1999b

Non-EGU 

Point

Auto and Light-Duty 

Truck Assembly 

Coatings

Control Technology 

Guidelines 0 0

EPA issued a CTG during 2008 for automobile and light-duty truck assembly coatings. Auto and light--duty truck coating 

facilities have reduced the VOC emission from their coating operations to comply with the NSPS, NESHAP and State rules. 

The CTG recommended VOC emission limits are already being implemented in these facilities in order to meet existing 

requirements. Therefore, there are not quantifiable VOC emission reductions or costs associated with implementing the CTG 

recommendations. However, the CTG also recommends work practices for reducing VOC emissions from both coatings and 

cleaning materials. EPA estimates that its work practice recommendations will save costs. Implementing these work practices, 

such as covering open containers, reduces the amount of coating and cleaning materials used by decreasing evaporation.

EPA 2008c

Non-EGU 

Point

Fiberglass Boat 

Manufacturing

Solvent substitution, nonatomized resin 

application methods

35 $4,200 

EPA issued a CTG during 2008 that provides control recommendations for reducing VOC emissions from the use of gel coats, 

resins, and materials used to clean application equipment in fiberglass boat manufacturing operations. The CTG recommends 

the use of low-VOC content (monomer and non-monomer VOC) resin and gel coats with specified application methods. The 

CTG recommends the use of covers on mixing containers to further reduce VOC emissions from gel coats and resins. The 

CTG also recommends the use of low-VOC and low vapor pressure cleaning materials. Because the CTG recommendations 

are based on the 2001 NESHAP for boat manufacturing, those facilities that are major sources of HAP are already complying 

with the 2001 NESHAP and have already adopted these control measures. Because the 2001 NESHAP does not apply to 

area sources, area source fiberglass boat manufacturing facilities are not currently required to implement the measures 

provided in the NESHAP and recommended in the CTG. There are boat manufacturing facilities in ozone nonattainment areas 

that meet the applicability threshold in the CTG and would provide VOC emission reductions when the CTG recommended 

controls are applied. These control approaches are recommended for all fiberglass boat manufacturing facilities where total 

actual VOC emissions from all fiberglass boat manufacturing operations are equal to or exceed 15 lb/day. 

EPA 2008d
Point & NonPoint VOC

Menu of Control Measures

Updated 4/12/2012

Printed 8/6/2013 34 of 67

Non-EGU 

Point

Flat Wood Paneling 

Coatings

Low-VOC materials 

coatings 60-91 $1,900-2,600

EPA issued a new CTG for flat wood paneling coating facilities in 2006. The 2006 CTG recommends emission limits for the 

inks, coatings and adhesives used by the flat wood paneling coating facilities and work practices for cleaning materials used. 

The low-VOC materials recommendation for inks, coatings and adhesives include an emission limit of 2.1 lbs. per gallon of 

materials. Should product performance requirements or other needs dictate the use of higher-VOC Coatings than this, a 

facility could choose to use add-on control equipment to meet an overall control efficiency of 90 percent. Add-on devices 

include oxidizers and solvent recovery systems. The CTG also recommends work practices for use in all flat wood paneling 

coating facilities meeting the 15 lb per day threshold. The new CTG emission limits for this source category are based on the 

rules in Placer County (Rule 238) and SCAQMD (Rule 1104) in California. 

EPA 2006i

Non-EGU 

Point

Flexible Package 

Printing

Add-on controls, work 

practices, and material 

reformulation / 

substitution.

67 $2,800 

EPA issued a CTG for Flexible Package Printing in 2006 that includes recommended control techniques. EPA's 

recommended emission limits are based on the 1978 CTG for graphic arts (which included rotogravure printing and 

flexographic printing) and on the 1996 NESHAP. 

This CTG provides control recommendations for reducing VOC emissions from (1) inks, coatings, adhesives and (2) cleaning 

materials used in flexible packaging printing. EPA recommends applying the recommendations for operations that emit at 

least (1) 25 tpy of VOC from inks, coatings and adhesives combined, and (2) 15 lb/day of VOC due to cleaning materials 

(before consideration of controls). 

The approach to reducing VOC emissions from inks, coatings, and adhesives includes adding/improving add-on controls with 

an overall emission reduction of 65 to 80 percent (depending on the first installation date of the equipment) and material 

reformulation/substitution (low- and no-VOC inks, coatings, and adhesives) with an 80 percent overall emissions reduction 

level. The recommended approach to reduce VOC emissions from cleaning materials includes use of work practices (keeping 

solvent containers closed, conducting cleaning operations, conveying cleaning materials in closed containers, etc.)

EPA 2006k

Non-EGU 

Point

Industrial Cleaning 

Solvents

Work practice standards, 

solvent substitution, and 

add-on controls

94 ($1,134)

EPA issued a CTG for industrial cleaning solvents in 2006 that includes recommended control techniques. This category 

includes the industrial cleaning solvents used by many industries. It includes a variety of products that are used to remove 

contaminants such as adhesives, inks, paint, dirt, soil, oil and grease. The recommended measures for controlling VOC 

emissions from the use, storage and disposal of industrial cleaning solvents includes work practice standards, limitations on 

VOC content of the cleaning materials, and an optional alternative limit on composite vapor pressure of the cleaning 

materials. They also include the use of add-on controls with an overall emission reduction of at least 85 percent by mass. The 

first two recommendations and the last one are based on the Bay Area AQMD rule.

EPA 2006h

Non-EGU 

Point

Large Appliance Surface 

Coating

Low-VOC coating 

materials 30 $500 

In 2007, EPA issued a CTG for large appliance coatings. EPA developed this new CTG after considering the 1977 CTG, the 

1982 NSPS, the 2002 NESHAP, and existing State and local VOC emission reduction approaches for this category. The new 

CTG applies the facilities with 15 lbs per day or more of VOC emissions from large appliance coating operations. There are 

two main sources of VOC emissions from large appliance coating operations: (1) evaporation of VOC from the coatings; and 

(2) evaporation of VOC from the cleaning materials. To control VOC emissions from large appliance coatings, EPA 

recommended three alternatives: (1) emission limits that can be achieved through the use of low-VOC coatings; (2) equivalent 

emission limits that can be achieved through the use of low-VOC coatings or a combination of coatings and add-on controls; 

and (3) an overall control efficiency of 90 percent for add-on controls. EPA expects that in practice, facilities will choose the 

low-VOC coating materials alternative. EPA recommends work practices to reduce VOC emissions. The recommendations in 

this CTG are similar to the South Coast regulations for this source category (SCAQMD Rule 1107).

EPA 2007e

Non-EGU 

Point

Lithographic Printing & 

Letterpress Printing

Add-on controls, work 

practices, and material 

reformulation/substitutio

n.

75 $155 

EPA issued a CTG for Lithographic Printing & Letterpress Printing in 2006 that includes recommended control techniques 

(although offset lithographic printing and letterpress printing are two distinct product categories, they have many similarities in 

the types of materials used, sources of VOC emissions, and controls available). EPA's recommended emission limits are 

based on the 1993 draft CTG and 1994 ACT. 

This CTG provides control recommendations for reducing VOC emissions from (1) evaporation of VOC from the inks, (2) 

evaporation of VOC from the fountain solution (offset lithographic printing only), and (3) evaporation of VOC from the cleaning 

materials. EPA recommends applying the recommendations for operations that emit at least (1) 25 tpy of VOC from inks, and 

(2) 15 lb/day of VOC due to fountain solutions and cleaning materials (before consideration of controls).

The approach to reducing VOC emissions from heatset web offset lithographic and heatset letterpress inks and dryers 

consists of installing control devices with an overall emission reduction of 90 to 95 percent (depending on the first installation 

date of the equipment). The recommended approach to reduce VOC emissions from the fountain solution focuses on 

controlling the concentration of alcohol in the fountain solution at less than 5% (weight) of alcohol. Finally, EPA recommends 

using cleaning materials with a VOC composite vapor pressure less than 10 mm Hg at 20 oC and proposes using work 

practices (keeping cleaning materials and used shop towels in closed containers).

EPA 2006j
Point & NonPoint VOC

Menu of Control Measures

Updated 4/12/2012

Printed 8/6/2013 35 of 67

Non-EGU 

Point Metal Furniture Coatings Low-VOC coating materials 35 $200 

EPA issued a 2007 CTG for metal furniture coatings. Previous federal actions that affected this source category include a 

1977 CTG, a 1982 NSPS and a 2003 NESHAP (Surface Coating of Metal Furniture). In the 2007 CTG, EPA recommended 

three alternatives: (1) emission limits that can be achieved through the use of low VOC Coatings; (2) equivalent emission 

limits that can be achieved through the use of low-VOC coatings and add-on controls, (3) an overall control efficiency of 90 

percent for add-on controls. The low-VOC coatings recommendation consists of emission limits in terms of mass of VOC per 

volume of coating, excluding water and exempt compounds, as applied and the use of specified application methods. the 

equivalent emission limit recommendation consists of emission limits in terms of mass of VOC per volume of coating solids, 

as applied, and the use of specific. The CTG recommendations are similar to the South Coast regulations governing metal 

furniture surface coating operations.

EPA 2007f

Non-EGU 

Point

Miscellaneous Industrial 

Adhesives Solvent substitution 64 $265 

EPA issued a CTG for miscellaneous industrial adhesives in 2008. This provides information for states to consider in 

determining RACT. EPA's recommended emission limits are based on the OTC Model Rule for Adhesives and Sealants. The 

emission limits in the OTC rule were the same as California ARB RACT standards, which were based on numerous California 

district rules. EPA recommends that the control approaches suggested apply to each miscellaneous industrial adhesive 

application process at a facility where the total actual VOC emissions from all application processes, including related 

cleaning activities at that facility are equal to or exceed 15 lbs per day before consideration of controls. EPA recommends 

specific VOC emission limits based on application processes. There are two options for achieving recommended emission 

limits: (1) through the use of low-VOC content adhesives and specified application methods with good adhesive transfer 

efficiency; or (2) through the use of a combination of low-VOC adhesives, specified methods and add-on controls. As an 

alternative to the emission limits, an overall 85 percent control efficiency is recommended.

EPA 2008a

Non-EGU 

Point

Miscellaneous Metal and 

Plastic Parts Coatings Coating Reformulation 35 1,758

In the 2008 EPA CTG for miscellaneous metal and plastic parts coatings three options were recommended for controlling 

VOC emissions: (1) VOC content limits for each coating category based on the use of low-VOC content coatings and 

specified application methods to achieve good transfer efficiency; (2) equivalent VOC emission rate limits based on the use of 

a combination of low-VOC coatings, specified application methods, and add-on controls; or (3) an overall VOC control 

efficiency of 90 percent for facilities that choose to use add-on controls instead of low-VOC Content coatings and specified 

application methods. In addition, EPA recommended work practices to further reduce VOC emissions from coatings as well as 

to minimize emissions from cleaning materials used in miscellaneous metal product and plastic part surface coating 

processes. The recommendations in this CTG are similar to the South Coast regulations governing miscellaneous metal 

product and plastic part surface coating operations, and Michigan Rule 336.1632. 

EPA 2008b

Non-EGU 

Point

Paper Film and Foil 

Coatings

Low-VOC coating 

materials and/or add-on 

controls

90 1,200

EPA issued a 2007 CTG for paper, film and foil coatings. Previous federal actions that affected this source category included 

a 1977 CTG for controlling VOC emissions from surface coating of paper, the 1983 NSPS for surface coating of pressure 

sensitive tape and labels (a subset of this category), and a 2002 NESHAP for paper and other web coating. EPA recommends 

applying the control recommendations for coatings only o individual paper, film and foil surface coating lines with the potential 

to emit at least 25 tpy of VOC from coatings, prior to controls. EPA recommends an overall VOC control efficiency of 90% as 

RACT for each coating line. This level of control is based on current rules in San Diego and Ventura air districts in California, 

as well as the NSPS. The CTG does not recommend the 95 percent control level that is currently required by the NESHAP 

and seven State's regulations. 

EPA 2007g

NonEGU 

Point

Fabric Printing and 

Coating

Permanent Total 

Enclosure (PTE) 97 $1,761

A permanent total enclosure (PTE) completely surrounds a source of emissions such that all VOC emissions are captured 

and contained for discharge to a control device. 

Fabric printing and coating is performed in the textile manufacturing industry in order to:

--prepare fiber and subsequently manufacture yarn, threads, braids, twine, and cordage

--manufacture broadwoven fabrics, narrow woven fabrics, knit fabrics, and carpets and rugs from yarn

-- finish fiber, yarn, fabrics, and knit apparel 

--coat, waterproof, or otherwise treat fabrics

--perform integrated manufacturing of knit apparel and other finished articles from yarn

--manufacture felt goods, lace goods, nonwoven fabrics, and miscellaneous textiles.

The EPA evaluated VOC emission control options for the fabric printing and coating industry including the use of a PTE in 

conjunction with a thermal oxidizer in the MACT standard-setting process for this source category. The option presented here 

has applicability to fabric printing/coating processes that use "high" VOC content materials.

EPA 2006b

NonEGU 

Point

Industrial Cleaning 

Solvents - NonHalogenated Solvent - 

Parts Cleaners

Low VOC Cleaning 

Materials and Improved 

Work Practices

<85 $2,082 

This control includes work practice standards, limitations on VOC content of the cleaning materials, and an optional 

alternative limit on composite vapor pressure of the cleaning materials. They also include the use of add-on controls with an 

overall emission reduction of at least 85 percent by mass. It applies to industrial solvent cleaning operations using nonhalogenated solvents, identified as either degreasing or cold cleaning. Though the efficiency from this control is 85%, there 

are exceptions for a number of sources within the category.

EPA 2006h

NonEGU 

Point

Industrial Cleaning 

Solvents - Other NonHalogenated Solvent 

Cleaning Operations

Low VOC Cleaning 

Materials and Improved 

Work Practices

<85 ($1,657)

This control includes work practice standards, limitations on VOC content of the cleaning materials, and an optional 

alternative limit on composite vapor pressure of the cleaning materials. They also include the use of add-on controls with an 

overall emission reduction of at least 85 percent by mass. It applies to industrial solvent cleaning operations using nonhalogenated solvents, not identified as either degreasing or cold cleaning. Though the efficiency from this control is 85%, 

there are exceptions for a number of sources within the category.

EPA 2006h
Point & NonPoint VOC

Menu of Control Measures

Updated 4/12/2012

Printed 8/6/2013 36 of 67

NonEGU 

Point

Metal Furniture Surface 

Coating

Permanent Total 

Enclosure (PTE) 95 $24,325

A permanent total enclosure (PTE) completely surrounds a source of emissions such that all VOC emissions are captured 

and contained for discharge to a control device. 

Metal furniture surface coating operations involve:

--Surface preparation of the metal furniture prior to coating application

--Preparation of a coating for application (e.g., mixing in additives, dissolving resins)

--Application of a coating to metal furniture

--Flashoff, drying, and curing following coating application

--Cleaning of equipment used in the coating application operation

--Storage of coatings, additives, and cleaning materials

--Conveyance of coatings, additives, and cleaning materials from storage areas to mixing areas or to coating application 

areas, either manually or by automated means

--Handling and conveyance of waste materials generated by the surface coating operation.

The EPA evaluated VOC emission control options for the metal furniture coating industry including the use of a PTE in 

conjunction with a thermal oxidizer in the MACT standard-setting process for this source category. The option presented here 

has applicability to processes that use "high" VOC content materials (solvent-borne materials).

EPA 2006b

NonEGU 

Point

Miscellaneous Industrial 

Adhesives

Low VOC Adhesives and 

Improved Application 

Methods

64 $263 

This control is based on EPA's 2008 Control Techniques Guidelines for Miscellaneous Industrial Adhesives. It recommends 

85 percent VOC reduction through the use of low-VOC content adhesives and specified application methods with good 

adhesive transfer

efficiency; or through the use of a combination of low-VOC adhesives, specified application

methods, and add-on controls. The control efficiency is not 85 percent because there are a number of exceptions for certain 

types of adhesives and adhesives primer application processes.

EPA 1995a, EPA 2008a

NonEGU 

Point

Oil and Natural Gas 

Production - Fugitive 

Emissions

SCAQMD Rule 1148.1 14 $2,648

 The purpose of this rule is to reduce emissions of volatile organic compounds (VOCs) from the wellheads, the well cellars 

and the handling of produced gas at oil and gas production facilities. This rule applies to onshore oil producing wells, well 

cellars and produced gas handling activities at onshore facilities where petroleum and processed gas are produced, 

gathered, separated, processed and stored. This rule was adopted March 5, 2004.

EPA 2006b

NonEGU 

Point Petroleum Flare Flare 98 $3,255 This control is the application of improved flaring technology to reduce VOC emissions at petroleum flares. EPA 2007c

NonEGU 

Point Petroleum Wastewater Wastewater 65 $3,315 This control is the application of wastewater treatment controls to petroleum wastewater sources to reduce VOC emissions. EPA 2007c

NonEGU 

Point

Semi-Conductor 

Manufacturing

Reformulation-Process 

Modification 53 $9,591

The baseline against which the control efficiencies for this category are listed comes from the federal MACT rule (NESHAP 

rule 69 FR 129). SCAQMD Rule 1164 requires: a fully covered area, low/no-VOC solvents, or an approved emissions control 

system for solvent cleaning operations, photoresist operations and solvent clean-up operations. This control applies to the 

miscellaneous electronic equipment coating source category, including VOC emissions resulting from the manufacture of 

circuit boards and components, including resistors, transistors, semiconductors, coils, and transformers. 

Pechan 1997, SCAQMD 

1996a, EPA 1994d, 

SCAQMD 1998, 

SCAQMD 1995a

NonEGU 

Point

Shipbuilding and Ship 

Repair (Surface Coating) 

Reformulation-Process 

Modification 49 $3,054

EPA's 2010 (FR Vol. 75, No. 244) proposed rule identified an add-on control device, a concentrator/Regenerative Thermal 

Oxidizer (RTO), recently installed at one shipbuilding and ship repair facility in California. The control device consists of 

rotary concentrators followed by RTOs on five large, custom-built spray booths to control volatile organic emissions from 

some of the coating operations. The system is capable of achieving 95 percent control efficiency for volatile organic HAP 

emissions captured by the spray booths (which are estimated to capture 90 percent of the VOHAP emissions). For this type 

of add-on control to be effective, a facility must perform regular or continuous modular (ship sections or components) coating 

operations, a process that is normally performed at large shipyards during new ship construction. Due to the size of the 

booths required to handle large ship modules, a facility would also require a large physical land space to build or retrofit the 

spray booths. Such spray booths must be located near the final ship assembly area (e.g., dry-dock or graving dock) to 

facilitate the logistics of moving the ship modules into place and attaching them to other modules. Large coating booths 

would not be effective at shipyards that perform repairs on finished vessels or during dockside coating, since only a small 

amount of the total coating could be applied in such spray booths.

OTC 2001a

* control efficiencies were rounded up to the closest whole number.
Point & NonPoint PM

Menu of Control Measures

Updated 8/6/2013

Printed 8/6/2013 37 of 67

Source Category Emission Reduction 

Measure Name Control Efficiency (%)* Cost Effectiveness (2006$/ton)**

Other Pollutants 

Controlled Description/Notes/Caveats References

Asphalt Manufacture

CEM Upgrade and 

Increased Monitoring 

Frequency of PM 

Controls

8 $5,763 per ton PM

This measure examines the impacts of improving the PM monitoring technique at units currently using an ESP, scrubber, 

or fabric filter. In this improved technique scenario, the monitoring technique is upgraded to a PM continuous emission 

monitor. This improved monitoring technique also results in an increase to the monitoring frequency

because a PM CEMS can make a measurement every 7.5 minutes. The monitoring frequency increases from once per 

day to eight times per hour.

Barr and Schaffner, 

2003, EPA 2000a

Asphalt Manufacture Fabric Filter 99 $147-$186 per ton 

PM10

A fabric filter, or baghouse, consists of a number of fabric bags placed in parallel inside of an enclosure. Particulate matter 

is collected on the surface of the bags as the gas stream passes through them. The particulate is periodically removed 

from the bags and collected in hoppers located beneath the bags. A number of methods are employed to facilitate the 

removal of particulate from the bags, including shaking, reverse air flow, and pulse air flow. The only potential drawback to 

a fabric filter would be when used in conjunction with a high moisture flue gas stream or with extremely high temperatures. 

If moisture levels in the flue gas stream are too high then filter caking can occur. Cost-effectiveness varies depending on 

the type of filter (Reverse-Air Cleaned Type, Mech. Shaker Type, Pulse Jet Type) and is based on EPA’s cost-estimating 

spreadsheet for fabric filters. 

EPA 1998a; EPA 

2000b; 

EPA 2000c; EPA 

2000d; 

Asphalt Manufacture

Increased Monitoring 

Frequency (IMF) of PM 

Controls

7 $687 per ton PM

This measure is to conduct improved monitoring for PM2.5 emissions at stationary sources. Improved monitoring in this 

case means increasing the monitoring frequency of electrostatic precipitators, scrubbers, and fabric filters from once per 

day to four times per hour, with no change in monitoring technique.

The incremental costs included a one-time cost for development of the improved monitoring and recurring annual burden 

costs for incremental record keeping, reporting, and certification activities.

Barr and Schaffner, 

2003, EPA 2000a

Catalytic Cracking Units Venturi scrubber 90 $1,567

In a Venturi scrubber, water is injected into the flue gas stream at the Venturi throat to form droplets. Fly ash particles 

impact with the droplets to form a wet by-product which is then disposed of. The forceful contact resulting from the droplet 

dispersal (spray tower), contraction of the gas stream (Venturi) or counter current flow (collision), removes PM as well as 

SO2 from the flue gas. Condensation scrubbers are designed to control PM with a diameter of 0.25–1.0 μm. Venturi 

scrubbers are effective in controlling both PM10 and PM2.5. 

EPA 2007a

Catalytic Cracking Units SCAQMD Rule 1105.1 80 $5,805 per ton PM10 SO2

Rule 1105.1 for Fluid Catalytic Cracking Units sets emission limits for filterable PM10 at 0.005 grain/dscf, 2.8 lbs/1000 

barrels of fresh feed, or 3.6 lbs/hour. The rule uses ammonia as a surrogate for condensable PM10, and sets the ammonia 

slip limit at 10 ppmv. Dry ESPs and wet gas scrubber are the control options to meet the rule emission limits (the wet gas 

scrubber is also used to control SO2.) The overall control efficiency for both filterable and condensable PM10 is 80%. The 

cost effectiveness is $5,238 per ton (2003$, DCF, Filterable & Condensable PM10), which was converted to 2006$. 

SCAQMD 2012

Cement Manufacturing

Paper/Nonwoven Filters 

- Cartridge Collector 

Type

99 $179 per ton PM10

This control is the use of paper or non-woven filters (cartridge collector type) to reduce PM emissions. The waste gas 

stream is passed through the fibrous filter media causing PM in the gas stream to be collected on the media by sieving and 

other mechanisms. In general, the filter media is pleated to provide a larger surface area to volume flow rate. There are 

variety of cartridge designs and dimensions. Typical designs include flat panels, V-shaped packs or cylindrical packs. For 

certain applications, two cartridges may be placed in series. This control measure applies to cement manufacturing 

operations.

STAPPA/ALAPCO 

2006; EPA 1998a; EPA 

2000e

Cement Manufacturing - 

Internal roadways / 

areas

SCAQMD Rule 1156 50 - 80 for PM10

The purpose of this rule is to further reduce PM emissions from cement manufacturing facilities. This rule applies to all 

operations, materials handling, and transport at a cement manufacturing facility, including, but not limited to, kiln and 

clinker cooler, material storage, crushing, drying, screening, milling, conveying, bulk loading and unloading systems, 

internal roadways, material transport, and track-out. R1156 establishes opacity performance standards for all operations, 

and future PM emission limits for process equipment vented to baghouses. Additional features of the proposed rule are to 

specify compliance options for open storage piles, primary crushing operations, conveying systems, and a method of 

verifying and assuring compliance with the rule requirements. There are various control options to reduce track-out and 

fugitive dust (e.g. chemical suppressant).

STAPPA/ALAPCO 

2006; SCAQMD 2005a, 

SCAQMD 2012

Cement Manufacturing - 

Primary crusher SCAQMD Rule 1156 50 - 80 for PM10

The purpose of this rule is to further reduce PM emissions from cement manufacturing facilities. This rule applies to all 

operations, materials handling, and transport at a cement manufacturing facility, including, but not limited to, kiln and 

clinker cooler, material storage, crushing, drying, screening, milling, conveying, bulk loading and unloading systems, 

internal roadways, material transport, and track-out. R1156 establishes opacity performance standards for all operations, 

and future PM emission limits for process equipment vented to baghouses. Additional features of the proposed rule are to 

specify compliance options for open storage piles, primary crushing operations, conveying systems, and a method of 

verifying and assuring compliance with the rule requirements. For this specific source, the control options used in the 

SCAQMD rule include a wind fence and wetting.

STAPPA/ALAPCO 

2006; SCAQMD 2005a, 

SCAQMD 2012

Cement Manufacturing - 

rushing, milling, grinding SCAQMD Rule 1156 80 - 99.5 for PM10

The purpose of this rule is to further reduce PM emissions from cement manufacturing facilities. This rule applies to all 

operations, materials handling, and transport at a cement manufacturing facility, including, but not limited to, kiln and 

clinker cooler, material storage, crushing, drying, screening, milling, conveying, bulk loading and unloading systems, 

internal roadways, material transport, and track-out. R1156 establishes opacity performance standards for all operations, 

and future PM emission limits for process equipment vented to baghouses. Additional features of the proposed rule are to 

specify compliance options for open storage piles, primary crushing operations, conveying systems, and a method of 

verifying and assuring compliance with the rule requirements. For this specific source, the control options used in the 

SCAQMD rule include enclosing and venting emissions to baghouses.

This control is the use of 

low NOx burner (LNB) 

technology and 

selective non-catalytic 

reduction (SNCR) to 

reduce NOx emissions. 

LNBs reduce the 

amount of NOx created 

f ti b t 
Point & NonPoint PM

Menu of Control Measures

Updated 8/6/2013

Printed 8/6/2013 38 of 67

Source Category Emission Reduction 

Measure Name Control Efficiency (%)* Cost Effectiveness (2006$/ton)**

Other Pollutants 

Controlled Description/Notes/Caveats References

Cement Manufacturing - 

Storage piles SCAQMD Rule 1156 95 - 99.5 for PM10

The purpose of this rule is to further reduce PM emissions from cement manufacturing facilities. This rule applies to all 

operations, materials handling, and transport at a cement manufacturing facility, including, but not limited to, kiln and 

clinker cooler, material storage, crushing, drying, screening, milling, conveying, bulk loading and unloading systems, 

internal roadways, material transport, and track-out. R1156 establishes opacity performance standards for all operations, 

and future PM emission limits for process equipment vented to baghouses. Additional features of the proposed rule are to 

specify compliance options for open storage piles, primary crushing operations, conveying systems, and a method of 

verifying and assuring compliance with the rule requirements. For this specific source, the control options used in the 

SCAQMD rule include enclosing and venting emissions to baghouses.

STAPPA/ALAPCO 

2006; SCAQMD 2005a, 

SCAQMD 2012

Cement Manufacturing - 

Storage piles SCAQMD Rule 1156 50 - 80 for PM10

The purpose of this rule is to further reduce PM emissions from cement manufacturing facilities. This rule applies to all 

operations, materials handling, and transport at a cement manufacturing facility, including, but not limited to, kiln and 

clinker cooler, material storage, crushing, drying, screening, milling, conveying, bulk loading and unloading systems, 

internal roadways, material transport, and track-out. R1156 establishes opacity performance standards for all operations, 

and future PM emission limits for process equipment vented to baghouses. Additional features of the proposed rule are to 

specify compliance options for open storage piles, primary crushing operations, conveying systems, and a method of 

verifying and assuring compliance with the rule requirements. For this specific source, the control options used in the 

SCAQMD rule include chemical suppressant, three-sided barriers with roof, or tarp

STAPPA/ALAPCO 

2006; SCAQMD 2005a, 

SCAQMD 2012

Cement Manufacturing - 

Kilns/Clinker Coolers SCAQMD Rule 1156 95 - 99.5 for PM10 $2,066 per ton PM10

The purpose of this rule is to further reduce PM emissions from cement manufacturing facilities. This rule applies to all 

operations, materials handling, and transport at a cement manufacturing facility, including, but not limited to, kiln and 

clinker cooler, material storage, crushing, drying, screening, milling, conveying, bulk loading and unloading systems, 

internal roadways, material transport, and track-out. R1156 establishes opacity performance standards for all operations, 

and future PM emission limits for process equipment vented to baghouses. Additional features of the proposed rule are to 

specify compliance options for open storage piles, primary crushing operations, conveying systems, and a method of 

verifying and assuring compliance with the rule requirements. For this specific source, the control option used in the 

SCAQMD rule is a baghouse

STAPPA/ALAPCO 

2006; SCAQMD 2005a, 

SCAQMD 2012

Cement Manufacturing - 

Cement Kiln

ESP (Electrostatic 

Precipitator) 90-99 $27-$86 Hg

An electrostatic precipitator applies electrical forces to separate suspended particles from the flue gas stream. The 

suspended particles are given an electrical charge by passing through a high voltage DC corona region in which gaseous 

ions flow. There are two general types of ESP: wire/plate and wire/pipe types. Further, ESPs come in both wet and dry 

configurations. Given the high pollutant loadings associated with cement operations, ESPs must be relatively large 

compared to the same technology used for utility boilers, and are more cost-effective. 

STAPPA/ALAPCO 

2006; LADCO 2005b

Cement Manufacturing - 

Cement Kiln Fabric Filter 95-99.9 $34-$74

A fabric filter, or baghouse, consists of a number of fabric bags placed in parallel inside of an enclosure. Particulate matter 

is collected on the surface of the bags as the gas stream passes through them. The particulate is periodically removed 

from the bags and collected in hoppers located beneath the bags. A number of methods are employed to facilitate the 

removal of particulate from the bags, including shaking, reverse air flow, and pulse air flow. The only potential drawback to 

a fabric filter would be when used in conjunction with a high moisture flue gas stream or with extremely high temperatures. 

If moisture levels in the flue gas stream are too high then filter caking can occur. Given the high pollutant loadings 

associated with cement operations, fabric filters must be relatively large compared to the same technology used for utility 

boilers, and are more cost-effective.

STAPPA/ALAPCO 

2006; LADCO 2005b

Cement Manufacturing - 

Non-Kiln PM Sources Dust Collector 99

In order to capture fugitive PM emissions, material handling, grinding and storage operations must be enclosed and 

vented to the control device. Dust collectors are similar to fabric filters but have temperature restrictions (a limit of 200°F or 

400°F, depending on the filter media) and are effective only on low-flow applications. However, dust collectors require less 

room than fabric filters or ESPs and are therefore useful for areas with space restrictions. For Portland cement facilities, 

dust cartridges are likely to only be technically feasible for lower temperature operations such as finish grinding mill weigh 

hoppers and air separators, coal kiln feed units, cement silos, clinker grinding, and primary and secondary crushing 

operations.

STAPPA/ALAPCO 

2006; LADCO 2005b

Chemical Manufacture

CEM Upgrade and 

Increased Monitoring 

Frequency of PM 

Controls

8 $5,763 per ton PM

This measure examines the impacts of improving the PM monitoring technique at units currently using an ESP, scrubber, 

or fabric filter. In this improved technique scenario, the monitoring technique is upgraded to a PM continuous emission 

monitor. This improved monitoring technique also results in an increase to the monitoring frequency

because a PM CEMS can make a measurement every 7.5 minutes. The monitoring frequency increases from once per 

day to eight times per hour.

Barr and Schaffner, 

2003, EPA 2000a

Chemical Manufacture

Increased Monitoring 

Frequency (IMF) of PM 

Controls

7 $687 per ton PM

This measure is to conduct improved monitoring for PM2.5 emissions at stationary sources. Improved monitoring in this 

case means increasing the monitoring frequency of electrostatic precipitators, scrubbers, and fabric filters from once per 

day to four times per hour, with no change in monitoring technique.

The incremental costs included a one-time cost for development of the improved monitoring and recurring annual burden 

costs for incremental record keeping, reporting, and certification activities.

Barr and Schaffner, 

2003, EPA 2000a
Point & NonPoint PM

Menu of Control Measures

Updated 8/6/2013

Printed 8/6/2013 39 of 67

Source Category Emission Reduction 

Measure Name Control Efficiency (%)* Cost Effectiveness (2006$/ton)**

Other Pollutants 

Controlled Description/Notes/Caveats References

Chemical Manufacture

Wet Electrostatic 

Precipitator (ESP) - 

Wire Plate Type

95 $313 per ton PM10

An electrostatic precipitator applies electrical forces to separate suspended particles from the flue gas stream. The 

suspended particles are given an electrical charge by passing through a high voltage DC corona region in which gaseous 

ions flow. There are two general types of ESP: wire/plate and wire/pipe types. Further, ESPs come in both wet and dry 

configurations. This control is the use of Wet ESP Wire Plate Type. Unlike dry ESPs, resistivity of the collected material is 

not a major factor in performance. Because of the high humidity in a wet ESP, the resistivity of particles is lowered, 

eliminating the "back corona" condition. The frequent washing of the plates also limits particle buildup on the collectors. 

This control applies to various chemical manufacturing operations, including (but not limited to) adipic acid, ammonia, 

carbon black, charcoal, cleaners, phosphoric acids, plastics, sulfuric acid, sodium carbonate, ammonium nitrate, rubbers, 

ammonium phosphates, and inorganic pigments.

EPA1998a; EPA 1999a

Chemical Manufacture

Wet Electrostatic 

Precipitator (ESP) - 

Wire Plate Type

99.5 This control measure is the same as the dry ESP for this source category with a control efficiency of 95%. It is expected 

that by 2020, the control efficiency for this sytem will increase to 99.5% for PM2.5. EPA1998a; EPA 1999a

Commercial Cooking Catalytic Oxidizer 83 $3,252 per ton 

PM+VOC VOC

This measure focuses on the control of PM (and VOC) emissions from chain driven charbroilers. The use of a catalytic 

oxidizer, placed above the charbroiler in the stack and activated by heat from the cooking, appears to be the best and 

most costeffective emission control device for chain-driven charbroilers. Testing in the South Coast has shown that the 

majority of PM10 emissions from charbroilers are measured at 2.5 microns and below.

Ventura County 2004; 

CE-CERT 2002; ARB 

2005

Construction Activities Dust Control Plan 37 (PM10 mainly) $5,778 per ton PM10 The dust control plan includes chemical suppression and water treatment of disturbed soil at construction sites. EPA 1974; Pechan 

1997

Electric Generation

CEM Upgrade and 

Increased Monitoring 

Frequency of PM 

Controls

8 $5,763 per ton PM

This measure examines the impacts of improving the PM monitoring technique at units currently using an ESP, scrubber, 

or fabric filter. In this improved technique scenario, the monitoring technique is upgraded to a PM continuous emission 

monitor. This improved monitoring technique also results in an increase to the monitoring frequency

because a PM CEMS can make a measurement every 7.5 minutes. The monitoring frequency increases from once per 

day to eight times per hour.

Barr and Schaffner, 

2003, EPA 2000a

Electric Generation

Increased Monitoring 

Frequency (IMF) of PM 

Controls

7 $687 per ton PM

This measure is to conduct improved monitoring for PM2.5 emissions at stationary sources. Improved monitoring in this 

case means increasing the monitoring frequency of electrostatic precipitators, scrubbers, and fabric filters from once per 

day to four times per hour, with no change in monitoring technique.

The incremental costs included a one-time cost for development of the improved monitoring and recurring annual burden 

costs for incremental record keeping, reporting, and certification activities.

Barr and Schaffner, 

2003, EPA 2000a

Electric Generation - 

Coal Indigo Agglomerator 40

Cost effectiveness is 

variable and based on 

plant size:

- total capital cost of 

$12.8 per kW

- fixed O&M costs of $0 

per kW per year

- variable O&M costs of 

$0.03 mills

per kW per year

This device is installed in the high velocity duct ahead of an ESP and agglomerates the smaller particles with the larger 

particles, increasing the collection efficiency of the ESP for PM2.5. The estimate of control efficiency 40%, incremental to 

ESP controls. The capital and O&M costs are proportional to the capacity of the controlled unit. 

Sorrels 2006

Electric Generation - 

Coal - bituminous ESP upgrade - Level 1 5

Cost effectiveness is 

variable and based on 

plant size. Capital Cost: 

$55/kW.

The PM2.5 collection efficiency of an ESP can be increased by increasing the specific collecting area (SCA). The key 

technologies employed in the ESP level 1 upgrade include High Frequency transformer-rectifier (TR) sets. The capital 

costs associated with this control measure var depending on the capacity of the controlled unit. Costs listed here assume 

upgrading the specific collection area (SCA) to 250 square-feet/1000 afm (actual feet per minute). The percentage 

improvements in collection efficiency are additive in the sense that the values are added to the pre-upgrade collection 

efficiency to obtain the after-upgrade collection efficiency.

EPA 2011c

Electric Generation - 

Coal - bituminous ESP upgrade - Level 2 10

Cost effectiveness is 

variable and based on 

plant size. Capital Cost: 

$80/kW.

The PM2.5 collection efficiency of an ESP can be increased by increasing the specific collecting area (SCA). The key 

technologies employed in the ESP level 2 upgrade include High Frequency transformer-rectifier (TR) sets and new 

internals (rigid electrodes, increased plate spacing, increased plate height). The capital costs associated with this control 

measure var depending on the capacity of the controlled unit. Costs listed here assume upgrading the specific collection 

area (SCA) to 300 square-feet/1000 afm (actual feet per minute). The percentage improvements in collection efficiency are 

additive in the sense that the values are added to the pre-upgrade collection efficiency to obtain the after-upgrade 

collection efficiency.

EPA 2011c

Electric Generation - 

Coal - bituminous ESP upgrade - Level 3 20

Cost effectiveness is 

variable and based on 

plant size. Capital Cost: 

$100/kW.

The PM2.5 collection efficiency of an ESP can be increased by increasing the specific collecting area (SCA). The key 

technologies employed in the ESP level 3 upgrade include High Frequency transformer-rectifier (TR) sets, new internals 

(rigid electrodes, increased plate spacing, increased plate height), and an additional field. The capital costs associated with 

this control measure var depending on the capacity of the controlled unit. Costs listed here assume upgrading the existing 

specific collection area (SCA) by 100 square-feet/1000 afm (actual feet per minute), a 20% height increase, and an

additional field. The percentage improvements in collection efficiency are additive in the sense that the values are added to 

the pre-upgrade collection efficiency to obtain the after-upgrade collection efficiency.

EPA 2011c
Point & NonPoint PM

Menu of Control Measures

Updated 8/6/2013

Printed 8/6/2013 40 of 67

Source Category Emission Reduction 

Measure Name Control Efficiency (%)* Cost Effectiveness (2006$/ton)**

Other Pollutants 

Controlled Description/Notes/Caveats References

Electric Generation - 

Coal - lignite ESP upgrade - Level 1 1

Cost effectiveness is 

variable and based on 

plant size. Capital Cost: 

$55/kW.

The PM2.5 collection efficiency of an ESP can be increased by increasing the specific collecting area (SCA). The key 

technologies employed in the ESP level 1 upgrade include High Frequency transformer-rectifier (TR) sets. The capital 

costs associated with this control measure var depending on the capacity of the controlled unit. Costs listed here assume 

upgrading the specific collection area (SCA) to 250 square-feet/1000 afm (actual feet per minute). The percentage 

improvements in collection efficiency are additive in the sense that the values are added to the pre-upgrade collection 

efficiency to obtain the after-upgrade collection efficiency

EPA 2011c

Electric Generation - 

Coal - lignite ESP upgrade - Level 2 2

Cost effectiveness is 

variable and based on 

plant size. Capital Cost: 

$80/kW.

The PM2.5 collection efficiency of an ESP can be increased by increasing the specific collecting area (SCA). The key 

technologies employed in the ESP level 2 upgrade include High Frequency transformer-rectifier (TR) sets and new 

internals (rigid electrodes, increased plate spacing, increased plate height). The capital costs associated with this control 

measure var depending on the capacity of the controlled unit. Costs listed here assume upgrading the specific collection 

area (SCA) to 300 square-feet/1000 afm (actual feet per minute). The percentage improvements in collection efficiency are 

additive in the sense that the values are added to the pre-upgrade collection efficiency to obtain the after-upgrade 

collection efficiency.

EPA 2011c

Electric Generation - 

Coal - lignite ESP upgrade - Level 3 5

Cost effectiveness is 

variable and based on 

plant size. Capital Cost: 

$100/kW.

The PM2.5 collection efficiency of an ESP can be increased by increasing the specific collecting area (SCA). The key 

technologies employed in the ESP level 3 upgrade include High Frequency transformer-rectifier (TR) sets, new internals 

(rigid electrodes, increased plate spacing, increased plate height), and an additional field. The capital costs associated with 

this control measure var depending on the capacity of the controlled unit. Costs listed here assume upgrading the existing 

specific collection area (SCA) by 100 square-feet/1000 afm (actual feet per minute), a 20% height increase, and an

additional field. The percentage improvements in collection efficiency are additive in the sense that the values are added to 

the pre-upgrade collection efficiency to obtain the after-upgrade collection efficiency.

EPA 2011c

Electric Generation - 

Coal - subbituminous ESP upgrade - Level 1 12

Cost effectiveness is 

variable and based on 

plant size. Capital Cost: 

$55/kW.

The PM2.5 collection efficiency of an ESP can be increased by increasing the specific collecting area (SCA). The key 

technologies employed in the ESP level 1 upgrade include High Frequency transformer-rectifier (TR) sets. The capital 

costs associated with this control measure var depending on the capacity of the controlled unit. Costs listed here assume 

upgrading the specific collection area (SCA) to 250 square-feet/1000 afm (actual feet per minute). The percentage 

improvements in collection efficiency are additive in the sense that the values are added to the pre-upgrade collection 

efficiency to obtain the after-upgrade collection efficiency

EPA 2011c

Electric Generation - 

Coal - subbituminous ESP upgrade - Level 2 25

Cost effectiveness is 

variable and based on 

plant size. Capital Cost: 

$80/kW.

The PM2.5 collection efficiency of an ESP can be increased by increasing the specific collecting area (SCA). The key 

technologies employed in the ESP level 2 upgrade include High Frequency transformer-rectifier (TR) sets and new 

internals (rigid electrodes, increased plate spacing, increased plate height). The capital costs associated with this control 

measure var depending on the capacity of the controlled unit. Costs listed here assume upgrading the specific collection 

area (SCA) to 300 square-feet/1000 afm (actual feet per minute). The percentage improvements in collection efficiency are 

additive in the sense that the values are added to the pre-upgrade collection efficiency to obtain the after-upgrade 

collection efficiency.

EPA 2011c

Electric Generation - 

Coal - subbituminous ESP upgrade - Level 3 50

Cost effectiveness is 

variable and based on 

plant size. Capital Cost: 

$100/kW.

The PM2.5 collection efficiency of an ESP can be increased by increasing the specific collecting area (SCA). The key 

technologies employed in the ESP level 3 upgrade include High Frequency transformer-rectifier (TR) sets, new internals 

(rigid electrodes, increased plate spacing, increased plate height), and an additional field. The capital costs associated with 

this control measure var depending on the capacity of the controlled unit. Costs listed here assume upgrading the existing 

specific collection area (SCA) by 100 square-feet/1000 afm (actual feet per minute), a 20% height increase, and an

additional field. The percentage improvements in collection efficiency are additive in the sense that the values are added to 

the pre-upgrade collection efficiency to obtain the after-upgrade collection efficiency.

EPA 2011c

External Combustion 

Boilers Fuel Switching 80 SO2

This control transfers a home-heating oil fuel control to industrial boilers by substituting "red dye" distillate oil for high-sulfur 

fuel. Distillate has 500 ppm versus 2,500 to 3,000 ppm for high-sulfur diesel.The control applies to external combustion 

boilers.

EPA 2007a

Fabricated Metal 

Products - Abrasive 

Blasting

Paper/Nonwoven Filters 

- Cartridge Collector 

Type

99 $311 per ton PM10

This control is the use of paper or non-woven filters (cartridge collector type) to reduce PM emissions. The waste gas 

stream is passed through the fibrous filter media causing PM in the gas stream to be collected on the media by sieving and 

other mechanisms. In general, the filter media is pleated to provide a larger surface area to volume flow rate. There are 

variety of cartridge designs and dimensions. Typical designs include flat panels, V-shaped packs or cylindrical packs. For 

certain applications, two cartridges may be placed in series. This control measure applies to abrasive blasting operations 

as a part of fabricated metal products processing and production. 

STAPPA/ALAPCO 

2006; EPA 1998a; EPA 

2000e

Fabricated Metal 

Products - Machining

Paper/Nonwoven Filters 

- Cartridge Collector 

Type

99 $244 per ton PM10

This control is the use of paper or non-woven filters (cartridge collector type) to reduce PM emissions. The waste gas 

stream is passed through the fibrous filter media causing PM in the gas stream to be collected on the media by sieving and 

other mechanisms. In general, the filter media is pleated to provide a larger surface area to volume flow rate. There are 

variety of cartridge designs and dimensions. Typical designs include flat panels, V-shaped packs or cylindrical packs. For 

certain applications, two cartridges may be placed in series. This control measure applies to machining operations as a 

part of fabricated metal products processing and production. 

STAPPA/ALAPCO 

2006; EPA 1998a; EPA 

2000e
Point & NonPoint PM

Menu of Control Measures

Updated 8/6/2013

Printed 8/6/2013 41 of 67

Source Category Emission Reduction 

Measure Name Control Efficiency (%)* Cost Effectiveness (2006$/ton)**

Other Pollutants 

Controlled Description/Notes/Caveats References

Fabricated Metal 

Products - Welding

Paper/Nonwoven Filters 

- Cartridge Collector 

Type

99 $244 per ton PM10

This control is the use of paper or non-woven filters (cartridge collector type) to reduce PM emissions. The waste gas 

stream is passed through the fibrous filter media causing PM in the gas stream to be collected on the media by sieving and 

other mechanisms. In general, the filter media is pleated to provide a larger surface area to volume flow rate. There are 

variety of cartridge designs and dimensions. Typical designs include flat panels, V-shaped packs or cylindrical packs. For 

certain applications, two cartridges may be placed in series. This control measure applies to welding operations as a part 

of fabricated metal products processing and production. 

STAPPA/ALAPCO 

2006; EPA 1998a; EPA 

2000e

Ferrous Metals 

Processing

CEM Upgrade and 

Increased Monitoring 

Frequency of PM 

Controls

8 $5,763 per ton PM

This measure examines the impacts of improving the PM monitoring technique at units currently using an ESP, scrubber, 

or fabric filter. In this improved technique scenario, the monitoring technique is upgraded to a PM continuous emission 

monitor. This improved monitoring technique also results in an increase to the monitoring frequency

because a PM CEMS can make a measurement every 7.5 minutes. The monitoring frequency increases from once per 

day to eight times per hour.

Barr and Schaffner, 

2003, EPA 2000a

Ferrous Metals 

Processing

Increased Monitoring 

Frequency (IMF) of PM 

Controls

7 $687 per ton PM

This measure is to conduct improved monitoring for PM2.5 emissions at stationary sources. Improved monitoring in this 

case means increasing the monitoring frequency of electrostatic precipitators, scrubbers, and fabric filters from once per 

day to four times per hour, with no change in monitoring technique.

The incremental costs included a one-time cost for development of the improved monitoring and recurring annual burden 

costs for incremental record keeping, reporting, and certification activities.

Barr and Schaffner, 

2003, EPA 2000a

Ferrous Metals 

Processing - Coke Fabric Filter 99 $159-$186 per ton PM10

A fabric filter, or baghouse, consists of a number of fabric bags placed in parallel inside of an enclosure. Particulate matter 

is collected on the surface of the bags as the gas stream passes through them. The particulate is periodically removed 

from the bags and collected in hoppers located beneath the bags. A number of methods are employed to facilitate the 

removal of particulate from the bags, including shaking, reverse air flow, and pulse air flow. The only potential drawback to 

a fabric filter would be when used in conjunction with a high moisture flue gas stream or with extremely high temperatures. 

If moisture levels in the flue gas stream are too high then filter caking can occur. Cost-effectiveness varies depending on 

the type of filter (Reverse-Air Cleaned Type or Mech. Shaker Type) and is based on EPA’s cost-estimating spreadsheet for 

fabric filters.

EPA 1998a; EPA 

2000b; EPA 2000c

Ferrous Metals 

Processing - Coke Venturi Scrubber 89 $1067 per ton PM10

In a Venturi scrubber, water is injected into the flue gas stream at the Venturi throat to form droplets. Fly ash particles 

impact with the droplets to form a wet by-product which is then disposed of. The forceful contact resulting from the droplet 

dispersal (spray tower), contraction of the gas stream (Venturi) or counter current flow (collision), removes PM as well as 

SO2 from the flue gas. Condensation scrubbers are designed to control PM with a diameter of 0.25–1.0 μm. Venturi 

scrubbers are effective in controlling both PM10 and PM2.5. 

STAPPA/ALAPCO 

2006; EPA 1998a; EPA 

1999b

Ferrous Metals 

Processing - Ferroalloy 

Production

Dry Electrostatic 

Precipitator (ESP) - 

Wire Plate Type

95 $156 per ton PM10

An electrostatic precipitator applies electrical forces to separate suspended particles from the flue gas stream. The 

suspended particles are given an electrical charge by passing through a high voltage DC corona region in which gaseous 

ions flow. There are two general types of ESP: wire/plate and wire/pipe types. Further, ESPs come in both wet and dry 

configurations. This control is the use of Dry ESP Wire Plate Type. In dry ESPs, the collectors are knocked by various 

mechanical means to dislodge the particulate, which slides downward into a hopper. This control applies to ferroalloy 

production operations, including (but not limited to) several processes within this industry were selected for control, basic 

oxygen process furnace (SCC 30300914) and EAF argon O2 decarb vessels (SCC 30300928).

EPA 1998a; EPA 1999c

Ferrous Metals 

Processing - Ferroalloy 

Production

Dry Electrostatic 

Precipitator (ESP) - 

Wire Plate Type

99.5 This control measure is the same as the dry ESP for this source category with a control efficiency of 95%. It is expected 

that by 2020, the control efficiency for this sytem will increase to 99.5% for PM2.5. EPA 1998a; EPA 1999c

Ferrous Metals 

Processing - Ferroalloy 

Production

Fabric Filter 99 $159-$186 per ton 

PM10

A fabric filter, or baghouse, consists of a number of fabric bags placed in parallel inside of an enclosure. Particulate matter 

is collected on the surface of the bags as the gas stream passes through them. The particulate is periodically removed 

from the bags and collected in hoppers located beneath the bags. A number of methods are employed to facilitate the 

removal of particulate from the bags, including shaking, reverse air flow, and pulse air flow. The only potential drawback to 

a fabric filter would be when used in conjunction with a high moisture flue gas stream or with extremely high temperatures. 

If moisture levels in the flue gas stream are too high then filter caking can occur. Cost-effectiveness varies depending on 

the type of filter (Reverse-Air Cleaned Type or Mech. Shaker Type) and is based on EPA’s cost-estimating spreadsheet for 

fabric filters.

EPA 1998a; EPA 

2000b; EPA 2000c

Ferrous Metals 

Processing - Gray Iron 

Foundaries

Fabric Filter 99 $159-$186 per ton 

PM10

A fabric filter, or baghouse, consists of a number of fabric bags placed in parallel inside of an enclosure. Particulate matter 

is collected on the surface of the bags as the gas stream passes through them. The particulate is periodically removed 

from the bags and collected in hoppers located beneath the bags. A number of methods are employed to facilitate the 

removal of particulate from the bags, including shaking, reverse air flow, and pulse air flow. The only potential drawback to 

a fabric filter would be when used in conjunction with a high moisture flue gas stream or with extremely high temperatures. 

If moisture levels in the flue gas stream are too high then filter caking can occur. Cost-effectiveness varies depending on 

the type of filter (Reverse-Air Cleaned Type or Mech. Shaker Type) and is based on EPA’s cost-estimating spreadsheet for 

fabric filters.

EPA 1998a; EPA 

2000b; EPA 2000c
Point & NonPoint PM

Menu of Control Measures

Updated 8/6/2013

Printed 8/6/2013 42 of 67

Source Category Emission Reduction 

Measure Name Control Efficiency (%)* Cost Effectiveness (2006$/ton)**

Other Pollutants 

Controlled Description/Notes/Caveats References

Ferrous Metals 

Processing - Gray Iron 

Foundaries

Impingement-Plate 

Scrubber 64 $613 per ton PM10

This control is the use of an impingement-plate scrubber to reduce PM emissions. An impingement-plate scrubber is a 

vertical chamber with plates mounted horizontally inside a hollow shell. Impingement-plate scrubbers operate as 

countercurrent PM collection devices. The scrubbing liquid flows down the tower while the gas stream flows upward. 

Contact between the liquid and the particle-laden gas occurs on the plates. The plates are equipped with openings that 

allow the gas to pass through. Some plates are perforated or slotted, while more complex plates have valve-like openings.

EPA 1998a; EPA 1999d

Ferrous Metals 

Processing - Gray Iron 

Foundaries

Venturi Scrubber 94 $1067 per ton PM10

In a Venturi scrubber, water is injected into the flue gas stream at the Venturi throat to form droplets. Fly ash particles 

impact with the droplets to form a wet by-product which is then disposed of. The forceful contact resulting from the droplet 

dispersal (spray tower), contraction of the gas stream (Venturi) or counter current flow (collision), removes PM as well as 

SO2 from the flue gas. Condensation scrubbers are designed to control PM with a diameter of 0.25–1.0 μm. Venturi 

scrubbers are effective in controlling both PM10 and PM2.5. 

STAPPA/ALAPCO 

2006; EPA 1998a; EPA 

1999b

Ferrous Metals 

Processing - Iron & 

Steel Production

Dry Electrostatic 

Precipitator (ESP) - 

Wire Plate Type

95 $156 per ton PM10

An electrostatic precipitator applies electrical forces to separate suspended particles from the flue gas stream. The 

suspended particles are given an electrical charge by passing through a high voltage DC corona region in which gaseous 

ions flow. There are two general types of ESP: wire/plate and wire/pipe types. Further, ESPs come in both wet and dry 

configurations. This control is the use of Dry ESP Wire Plate Type. In dry ESPs, the collectors are knocked by various 

mechanical means to dislodge the particulate, which slides downward into a hopper.

EPA 1998a; EPA 1999c

Ferrous Metals 

Processing - Iron & 

Steel Production

Dry Electrostatic 

Precipitator (ESP) - 

Wire Plate Type

99.5 This control measure is the same as the dry ESP for this source category with a control efficiency of 95%. It is expected 

that by 2020, the control efficiency for this sytem will increase to 99.5% for PM2.5. EPA 1998a; EPA 1999c

Ferrous Metals 

Processing - Iron & 

Steel Production

Fabric Filter 99 $147-$186 per ton 

PM10

A fabric filter, or baghouse, consists of a number of fabric bags placed in parallel inside of an enclosure. Particulate matter 

is collected on the surface of the bags as the gas stream passes through them. The particulate is periodically removed 

from the bags and collected in hoppers located beneath the bags. A number of methods are employed to facilitate the 

removal of particulate from the bags, including shaking, reverse air flow, and pulse air flow. The only potential drawback to 

a fabric filter would be when used in conjunction with a high moisture flue gas stream or with extremely high temperatures. 

If moisture levels in the flue gas stream are too high then filter caking can occur. Cost-effectiveness varies depending on 

the type of filter (Reverse-Air Cleaned Type, Mech. Shaker Type, Pulse Jet Type) and is based on EPA’s cost-estimating 

spreadsheet for fabric filters.

EPA 1998a; EPA 

2000b; 

EPA 2000c; EPA 

2000d; 

Ferrous Metals 

Processing - Iron & 

Steel Production

Venturi Scrubber 25 $1067 per ton PM10

In a Venturi scrubber, water is injected into the flue gas stream at the Venturi throat to form droplets. Fly ash particles 

impact with the droplets to form a wet by-product which is then disposed of. The forceful contact resulting from the droplet 

dispersal (spray tower), contraction of the gas stream (Venturi) or counter current flow (collision), removes PM as well as 

SO2 from the flue gas. Condensation scrubbers are designed to control PM with a diameter of 0.25–1.0 μm. Venturi 

scrubbers are effective in controlling both PM10 and PM2.5.

STAPPA/ALAPCO 

2006; EPA 1998a; EPA 

1999b

Ferrous Metals 

Processing - Iron & 

Steel Production

Wet Electrostatic 

Precipitator (ESP) - 

Wire Plate Type

95 $313 per ton PM10

An electrostatic precipitator applies electrical forces to separate suspended particles from the flue gas stream. The 

suspended particles are given an electrical charge by passing through a high voltage DC corona region in which gaseous 

ions flow. There are two general types of ESP: wire/plate and wire/pipe types. Further, ESPs come in both wet and dry 

configurations. This control is the use of Wet ESP Wire Plate Type. Unlike dry ESPs, resistivity of the collected material is 

not a major factor in performance. Because of the high humidity in a wet ESP, the resistivity of particles is lowered, 

eliminating the "back corona" condition. The frequent washing of the plates also limits particle buildup on the collectors.

EPA1998a; EPA 1999a

Ferrous Metals 

Processing - Iron & 

Steel Production

Wet Electrostatic 

Precipitator (ESP) - 

Wire Plate Type

99.5 This control measure is the same as the dry ESP for this source category with a control efficiency of 95%. It is expected 

that by 2020, the control efficiency for this sytem will increase to 99.5% for PM2.5. EPA1998a; EPA 1999a

Ferrous Metals 

Processing - Iron and 

Steel Production

Capture Hood Vented to 

a Baghouse 85 Not available

This control is the addition of a capture hood to a preinstalled baghouse. The cost effectiveness is variable depending on 

the emissions. Uncertainty relatively high. Based on engineering judgments and MACT data which for some plants may be 

outdated.

Pechan 2008

Ferrous Metals 

Processing - Iron and 

Steel Production

Secondary Capture and 

Control System 85 Not available

This control is the addition of a secondary capture and control system for PM. The cost effectiveness is variable depending 

on the emissions. Uncertainty relatively high. Based on engineering judgments and MACT data which for some plants may 

be outdated.

Pechan 2008

Ferrous Metals 

Processing - Iron and 

Steel Production

Sinter Cooler 99 $5,771 The cost effectiveness is variable depending on the emissions. Uncertainty relatively high. Based on engineering 

judgments and MACT data which for some plants may be outdated. Pechan 2008

Ferrous Metals 

Processing - Steel 

Foundaries

Venturi Scrubber 25 $1067 per ton PM10

In a Venturi scrubber, water is injected into the flue gas stream at the Venturi throat to form droplets. Fly ash particles 

impact with the droplets to form a wet by-product which is then disposed of. The forceful contact resulting from the droplet 

dispersal (spray tower), contraction of the gas stream (Venturi) or counter current flow (collision), removes PM as well as 

SO2 from the flue gas. Condensation scrubbers are designed to control PM with a diameter of 0.25–1.0 μm. Venturi 

scrubbers are effective in controlling both PM10 and PM2.5.

STAPPA/ALAPCO 

2006; EPA 1998a; EPA 

1999b
Point & NonPoint PM

Menu of Control Measures

Updated 8/6/2013

Printed 8/6/2013 43 of 67

Source Category Emission Reduction 

Measure Name Control Efficiency (%)* Cost Effectiveness (2006$/ton)**

Other Pollutants 

Controlled Description/Notes/Caveats References

Ferrous Metals 

Processing - Steel 

Foundries

Fabric Filter 99 $147-$186 per ton 

PM10

A fabric filter, or baghouse, consists of a number of fabric bags placed in parallel inside of an enclosure. Particulate matter 

is collected on the surface of the bags as the gas stream passes through them. The particulate is periodically removed 

from the bags and collected in hoppers located beneath the bags. A number of methods are employed to facilitate the 

removal of particulate from the bags, including shaking, reverse air flow, and pulse air flow. The only potential drawback to 

a fabric filter would be when used in conjunction with a high moisture flue gas stream or with extremely high temperatures. 

If moisture levels in the flue gas stream are too high then filter caking can occur. Cost-effectiveness varies depending on 

the type of filter (Reverse-Air Cleaned Type, Mech. Shaker Type, Pulse Jet Type) and is based on EPA’s cost-estimating 

spreadsheet for fabric filters.

EPA 1998a; EPA 

2000b; 

EPA 2000c; EPA 

2000d; 

Fireplaces Install EPA Phase 2 

Qualified Units 70 $9,500 (2012$) CO2, VOC's,CO CH4, Toxics

If new wood-burning fireplace construction is allowed, only allow EPA Phase 2 qualified models. A Partnership Agreement 

(PA) is in place between EPA and wood-burning fireplace manufacturers. Under this PA, cleaner wood-burning fireplaces 

are qualified when their PM2.5 emissions are at or below the Phase 2 PM2.5 emissions level. Control effeciency (%) 

applies to an individual fireplace. Cost effectiveness is based on the incremental cost of installing a Phase 2 qualified 

fireplace instead of a non-Phase 2 fireplace. For a list of EPA Phase 2 qualified fireplaces go to: 

http://www.epa.gov/burnwise/fireplacelist.html.

http://epa.gov/burnwise/

resources.html

Fireplaces

Install Gas Logs in 

Existing Wood-burning 

Fireplaces

100 $11,000 (2012$) CO2, VOC's,CO CH4, 

Toxics, BC

Incentives by various air districts in CA have helped retrofit thousands of wood-burning fireplaces to gas log sets. Control 

efficiency (%) applies to an individual fireplace. Cost-effectiveness reflects converrting a wood-burning fireplace to a gas 

log burning fireplace. http://epa.gov/burnwise/

resources.html

Fireplaces

Install Retrofit Devices 

into Wood-burning 

Fireplaces

70 $9,500 (2012$) CO2, VOC's,CO CH4, 

Toxics

Provide incentives to encourage the installation of fireplace retrofit devices. Under the EPA Woodburning fireplace PA, a retrofit devices is qualified when it lowers fireplace PM2.5 emissions to 

at or below the program Phase 2 PM2.5 emissions level. Conntrol efficiency (%) applies to an individual fireplace retrofit 

device. For a list of EPA Phase 2 qualified fireplace retrofit devices go to: http://www.epa.gov/burnwise/fireplacelist.html. http://epa.gov/burnwise/

resources.html

Fireplaces, Hydronic 

Heaters, Wood Stoves

Curtailment Program 

( "Burn Ban") 75 $8,700 (2010$) CO2, VOC's,CO CH4, Toxics, BC

State and local air quality agencies forecast next day air quality levels. When it is expected

to be near or above the 24-hr PM2.5 NAAQS, limited (e.g., wood pellet only) or full

curtailment of wood burning is required. A public awareness campaign and enforcement are critical. 

Control efficiency (%) applies to the entire local area where the cutailment program is implemented. 

http://epa.gov/burnwise/

resources.html

Fireplaces, Hydronic 

Heaters, Wood Stoves

Burn Dry Seasoned 

Wood n/a n/a CO2, VOC's,CO CH4, Toxics, BC

Implement a program to only allow the sale of and/or burning of dry seasoned wood (e.g., <20% moisture content) in 

wood-burning appliances. http://epa.gov/burnwise/

resources.html

Fireplaces, Hydronic 

Heaters, Wood Stoves No visible Emissions n/a n/a CO2, VOC's,CO CH4, Toxics, BC

Implement a local program that allows no visible wood smoke. This option is typically easier to enforce/implement than an 

opacity program http://epa.gov/burnwise/

resources.html

Fireplaces, Hydronic 

Heaters, Wood Stoves Opacity Program n/a n/a CO2, VOC's,CO CH4, Toxics, BC

Implement a local program that limits opacity from individual residential wood combustion appliances.

http://epa.gov/burnwise/

resources.html

Grain Milling Fabric Filter 99 (PM10 mainly) $147-$186 per ton 

PM10

A fabric filter, or baghouse, consists of a number of fabric bags placed in parallel inside of an enclosure. Particulate matter 

is collected on the surface of the bags as the gas stream passes through them. The particulate is periodically removed 

from the bags and collected in hoppers located beneath the bags. A number of methods are employed to facilitate the 

removal of particulate from the bags, including shaking, reverse air flow, and pulse air flow. The only potential drawback to 

a fabric filter would be when used in conjunction with a high moisture flue gas stream or with extremely high temperatures. 

If moisture levels in the flue gas stream are too high then filter caking can occur. Cost-effectiveness varies depending on 

the type of filter (Reverse-Air Cleaned Type, Pulse Jet Type) and is based on EPA’s cost-estimating spreadsheet for fabric 

filters. This control applies to grain milling operations, including (but not limited to), wheat, dry corn, wet corn, rice, and 

soybean operations.

EPA 1998a; EPA 

2000b; 

EPA 2000d; 

Grain Milling

Paper/Nonwoven Filters 

- Cartridge Collector 

Type

99 (PM10 mainly) $179 per ton PM10

This control is the use of paper or non-woven filters (cartridge collector type) to reduce PM emissions. The waste gas 

stream is passed through the fibrous filter media causing PM in the gas stream to be collected on the media by sieving and 

other mechanisms. In general, the filter media is pleated to provide a larger surface area to volume flow rate. There are 

variety of cartridge designs and dimensions. Typical designs include flat panels, V-shaped packs or cylindrical packs. For 

certain applications, two cartridges may be placed in series. This control measure applies to machining operations as a 

part of fabricated metal products processing and production. This control applies to grain milling operations, including (but 

not limited to) wheat dry corn wet corn rice and soybean operations

STAPPA/ALAPCO 

2006; EPA 1998a; EPA 

2000e

 Hydronic Heaters 

(OWHH, OWB)

Install Cleaner Woodburning Hydronic 

Heaters vs. Old 

Technology

90 $740 (2012) CO2, VOC's,CO CH4, 

Toxics

If hydronic heaters are allowed, only allow EPA Phase 2 qualified models. A Partnership Agreement (PA) is in place 

between EPA and wood-burning hydronic heater manufacturers. Under this PA, cleaner burning hydronic heaters are 

qualified at or below the Phase 2 particulate emissions level. Control effeciency (%) applies to an individual hydronic 

heater. Cost effectiveness is based on the incremental cost of installing a Phase 2 qualified hydronic heater instead of a 

non-Phase 2 hydronic heater. For a list of Phase 2 qualified hydronic heaters, go to: 

http://www.epa.gov/burnwise/owhhlist.html.

http://epa.gov/burnwise/

resources.html
Point & NonPoint PM

Menu of Control Measures

Updated 8/6/2013

Printed 8/6/2013 44 of 67

Source Category Emission Reduction 

Measure Name Control Efficiency (%)* Cost Effectiveness (2006$/ton)**

Other Pollutants 

Controlled Description/Notes/Caveats References

 Hydronic Heaters 

(OWHH, OWB)

Install Retrofit Devices 

in Existing Hydronic 

Heaters

60 $980 (2012) CO2, VOC's,CO CH4, 

Toxics

Provide incentives to encourage the installation of hydronic heater retrofit devices. Retrofits may significantly reduce and 

even eliminate visible smoke emissions. Control efficiency (%) applies to an individual hydronic heater. http://epa.gov/burnwise/

resources.html

IC Engine- diesel 

generator

Diesel Oxidation 

Catalyst (DOC) 20 for PM2.5

$1,108-$2,216 per ton 

combined CO, HC, 

NOx, PM 

VOC, CO

The principle behind oxidation catalysts is that they reduce emissions by causing chemical reactions without themselves 

being changed or consumed. A DOC system typically consists of a steel housing that contains a metal or ceramic structure 

which acts as a catalyst support or substrate. Catalysts transform pollutants into harmless gases by causing chemical 

reactions in the exhaust stream. Diesel oxidation catalysts serve to reduce PM, CO, HC and toxic HC emissions. PM 

emissions are reduced by the chemical transformation of their soluble organic fraction to carbon dioxide and water.

NESCAUM 2003a

IC Engine- diesel 

generator

Diesel Oxidation 

Catalyst (DOC) 20 for PM10

$1,108-$2,216 per ton 

combined CO, HC, 

NOx, PM 

VOC, CO

The principle behind oxidation catalysts is that they reduce emissions by causing chemical reactions without themselves 

being changed or consumed. A DOC system typically consists of a steel housing that contains a metal or ceramic structure 

which acts as a catalyst support or substrate. Catalysts transform pollutants into harmless gases by causing chemical 

reactions in the exhaust stream. Diesel oxidation catalysts serve to reduce PM, CO, HC and toxic HC emissions. PM 

emissions are reduced by the chemical transformation of their soluble organic fraction to carbon dioxide and water.

NESCAUM 2003a

IC Engine- diesel 

generator

Diesel Particulate Filter 

(DPF) 80-90 $5,540-$21,055 per ton combined CO, HC, PM VOC, CO

Diesel particulate filters remove particulate matter in diesel exhaust by filtering exhaust from the engine. Since a filter can 

fill up over time, these systems must provide a means of burning off or removing accumulated particulate matter. A 

convenient means of accomplishing this is to burn or oxidize accumulated particulate matter on the filter when exhaust 

temperatures are adequate. By burning off trapped material, the filter is cleaned or “regenerated.” Filters that regenerate in 

this fashion cannot be used in all situations. Both exhaust gas temperature and fuel sulfur level must be taken into 

consideration. DPFs can only be used with engines using ultra low sulfur diesel and thus do not apply to all vintage 

engines

NESCAUM 2003a

IC Engine- diesel 

generator

DPF + SCR (Selective 

Catalytic Reduction) 80-90

$25,488-$99,736 per 

ton combined CO, HC, 

NOx, PM 

VOC, NOx, CO

This measure is the combination of a DPF and a Selective Catalytic Reduction (SCR) system, which reduces NOx 

emissions (as well as HC, CO, and PM emissions). DPFs can only be used with engines using ultra low sulfur diesel and 

thus do not apply to all vintage engines.

NESCAUM 2003a

ICI Boilers - Coal, 

Wood, Oil

CEM Upgrade and 

Increased Monitoring 

Frequency of PM 

Controls

8 $5,763 per ton PM

This measure examines the impacts of improving the PM monitoring technique at units currently using an ESP, scrubber, 

or fabric filter. In this improved technique scenario, the monitoring technique is upgraded to a PM continuous emission 

monitor. This improved monitoring technique also results in an increase to the monitoring frequency

because a PM CEMS can make a measurement every 7.5 minutes. The monitoring frequency increases from once per 

day to eight times per hour.

Barr and Schaffner, 

2003, EPA 2000a

ICI Boilers - Coal, 

Wood, Oil

Increased Monitoring 

Frequency (IMF) of PM 

Controls

7 $687 per ton PM

This measure is to conduct improved monitoring for PM2.5 emissions at stationary sources. Improved monitoring in this 

case means increasing the monitoring frequency of electrostatic precipitators, scrubbers, and fabric filters from once per 

day to four times per hour, with no change in monitoring technique.

The incremental costs included a one-time cost for development of the improved monitoring and recurring annual burden 

costs for incremental record keeping, reporting, and certification activities.

Barr and Schaffner, 

2003, EPA 2000a

ICI Boilers-Coal ESP (Electrostatic 

Precipitator) 96-99 $40-$591 Hg

An electrostatic precipitator applies electrical forces to separate suspended particles from the flue gas stream. The 

suspended particles are given an electrical charge by passing through a high voltage DC corona region in which gaseous 

ions flow. There are two general types of ESP: wire/plate and wire/pipe types. Further, ESPs come in both wet and dry 

configurations. Efficiency and cost-effectiveness are based on utility boiler estimates.

STAPPA/ALAPCO 

2006; LADCO 2005b

ICI Boilers-Coal Fabric Filter 95-99.9 $42-$383

A fabric filter, or baghouse, consists of a number of fabric bags placed in parallel inside of an enclosure. Particulate matter 

is collected on the surface of the bags as the gas stream passes through them. The particulate is periodically removed 

from the bags and collected in hoppers located beneath the bags. A number of methods are employed to facilitate the 

removal of particulate from the bags, including shaking, reverse air flow, and pulse air flow. The only potential drawback to 

a fabric filter would be when used in conjunction with a high moisture flue gas stream or with extremely high temperatures. 

If moisture levels in the flue gas stream are too high then filter caking can occur. Efficiency and cost-effectiveness are 

based on utility boiler estimates.

STAPPA/ALAPCO 

2006; LADCO 2005b

ICI Boilers-Coal

Fuel switching away 

from coal: bituminous 

coal to distillate oil

99 SO2, NOx

Development measure from PM NAAQS RIA.

Fuel substitution involves replacing the current fuel with a fuel which emits less of a given pollutant when burned. For many 

older boilers, fuel switching is an especially attractive option because the capital investment is usually small when 

compared to that of control devices. This control measure involves switching from bituminous coal to distillate oil (Distillate 

Oil is No 2 fuel oil)

EPA 1998a

ICI Boilers-Coal

Fuel switching away 

from coal: bituminous 

coal to natural gas

93 SO2, NOx

Development measure from PM NAAQS RIA.

Fuel substitution involves replacing the current fuel with a fuel which emits less of a given pollutant when burned. For many 

older boilers, fuel switching is an especially attractive option because the capital investment is usually small when 

compared to that of control devices. This control measure involves switching from bituminous coal to natural gas.

EPA 1998a

ICI Boilers-Coal

Fuel switching away 

from coal: bituminous 

coal to residual oil

7 SO2, NOx

Development measure from PM NAAQS RIA.

Fuel substitution involves replacing the current fuel with a fuel which emits less of a given pollutant when burned. For many 

older boilers, fuel switching is an especially attractive option because the capital investment is usually small when 

compared to that of control devices. This control measure involves switching from bituminous coal to residual oil (Residual 

Oil includes No. 4, 5, and 6 fuel oil.)

EPA 1998a
Point & NonPoint PM

Menu of Control Measures

Updated 8/6/2013

Printed 8/6/2013 45 of 67

Source Category Emission Reduction 

Measure Name Control Efficiency (%)* Cost Effectiveness (2006$/ton)**

Other Pollutants 

Controlled Description/Notes/Caveats References

ICI Boilers-Coal

Fuel switching away 

from coal: bituminous 

coal to subbituminous

21 SO2, NOx

Development measure from PM NAAQS RIA.

Fuel substitution involves replacing the current fuel with a fuel which emits less of a given pollutant when burned. For many 

older boilers, fuel switching is an especially attractive option because the capital investment is usually small when 

compared to that of control devices. This control measure involves switching from bituminous coal to subbituminous.

EPA 1998a

ICI Boilers-Coal

Fuel switching away 

from coal: residual oil to 

distillate oil

99 SO2, NOx

Development measure from PM NAAQS RIA.

Fuel substitution involves replacing the current fuel with a fuel which emits less of a given pollutant when burned. For many 

older boilers, fuel switching is an especially attractive option because the capital investment is usually small when 

compared to that of control devices. This control measure involves switching from residual oil to distillate oil.

EPA 1998a

ICI Boilers-Coal

Fuel switching away 

from coal: residual oil to 

natural gas

93 SO2, NOx

Development measure from PM NAAQS RIA.

Fuel substitution involves replacing the current fuel with a fuel which emits less of a given pollutant when burned. For many 

older boilers, fuel switching is an especially attractive option because the capital investment is usually small when 

compared to that of control devices. This control measure involves switching from residual oil to natural gas.

EPA 1998a

ICI Boilers-Coal

Fuel switching away 

from coal: 

subbituminous coal to 

distillate oil

99 SO2, NOx

Development measure from PM NAAQS RIA.

Fuel substitution involves replacing the current fuel with a fuel which emits less of a given pollutant when burned. For many 

older boilers, fuel switching is an especially attractive option because the capital investment is usually small when 

compared to that of control devices. This control measure involves switching from subbituminous coal to distillate oil.

EPA 1998a

ICI Boilers-Coal

Fuel switching away 

from coal: 

subbituminous coal to 

natural gas

91 SO2, NOx

Development measure from PM NAAQS RIA.

Fuel substitution involves replacing the current fuel with a fuel which emits less of a given pollutant when burned. For many 

older boilers, fuel switching is an especially attractive option because the capital investment is usually small when 

compared to that of control devices. This control measure involves switching from subbituminous coal to natural gas.

EPA 1998a

ICI Boilers-Wood ESP (Electrostatic 

Precipitator) 95-99 $118-$614

An electrostatic precipitator applies electrical forces to separate suspended particles from the flue gas stream. The 

suspended particles are given an electrical charge by passing through a high voltage DC corona region in which gaseous 

ions flow. There are two general types of ESP: wire/plate and wire/pipe types. Further, ESPs come in both wet and dry 

configurations.

STAPPA/ALAPCO 2006

ICI Boilers-Wood Fabric Filter 95-99.9 $94-$990

A fabric filter, or baghouse, consists of a number of fabric bags placed in parallel inside of an enclosure. Particulate matter 

is collected on the surface of the bags as the gas stream passes through them. The particulate is periodically removed 

from the bags and collected in hoppers located beneath the bags. A number of methods are employed to facilitate the 

removal of particulate from the bags, including shaking, reverse air flow, and pulse air flow. The only potential drawback to 

a fabric filter would be when used in conjunction with a high moisture flue gas stream or with extremely high temperatures. 

If moisture levels in the flue gas stream are too high then filter caking can occur.

STAPPA/ALAPCO 2006

ICI Boilers-Wood Wet Scrubber 90 $41-$1,270 SO2

The two most frequently utilized wet scrubbers for PM control are condensation scrubbers and venturi scrubbers. In a 

Venturi scrubber, water is injected into the flue gas stream at the Venturi throat to form droplets. Fly ash particles impact 

with the droplets to form a wet by-product which is then disposed of. The forceful contact resulting from the droplet 

dispersal (spray tower), contraction of the gas stream (Venturi) or counter current flow (collision), removes PM as well as 

SO2 from the flue gas. Condensation scrubbers are designed to control PM with a diameter of 0.25–1.0 μm. Venturi 

scrubbers are effective in controlling both PM10 and PM2 5

STAPPA/ALAPCO 2006

Industrial Boilers - 

Liquid Waste

Dry Electrostatic 

Precipitator (ESP) - 

Wire Plate Type

95 $156 per ton PM10

An electrostatic precipitator applies electrical forces to separate suspended particles from the flue gas stream. The 

suspended particles are given an electrical charge by passing through a high voltage DC corona region in which gaseous 

ions flow. There are two general types of ESP: wire/plate and wire/pipe types. Further, ESPs come in both wet and dry 

configurations. This control is the use of Dry ESP Wire Plate Type. In dry ESPs, the collectors are knocked by various 

mechanical means to dislodge the particulate, which slides downward into a hopper. This control applies operations that 

have industrial boilers fired with liquid waste, including waste oil.

EPA 1998a; EPA 1999c

Industrial Boilers - 

Liquid Waste

Dry Electrostatic 

Precipitator (ESP) - 

Wire Plate Type

99.5 This control measure is the same as the dry ESP for this source category with a control efficiency of 95%. It is expected 

that by 2020, the control efficiency for this sytem will increase to 99.5% for PM2.5. EPA 1998a; EPA 1999c

Industrial Boilers - Oil

Dry Electrostatic 

Precipitator (ESP) - 

Wire Plate Type

95 $156 per ton PM10

An electrostatic precipitator applies electrical forces to separate suspended particles from the flue gas stream. The 

suspended particles are given an electrical charge by passing through a high voltage DC corona region in which gaseous 

ions flow. There are two general types of ESP: wire/plate and wire/pipe types. Further, ESPs come in both wet and dry 

configurations. This control is the use of Dry ESP Wire Plate Type. In dry ESPs, the collectors are knocked by various 

mechanical means to dislodge the particulate, which slides downward into a hopper. This control applies operations with oilfired boilers

EPA 1998a; EPA 1999c

Industrial Boilers - Oil

Dry Electrostatic 

Precipitator (ESP) - 

Wire Plate Type

99.5 This control measure is the same as the dry ESP for this source category with a control efficiency of 95%. It is expected 

that by 2020, the control efficiency for this sytem will increase to 99.5% for PM2.5. EPA 1998a; EPA 1999c

Industrial Boilers - Oil Venturi Scrubber 25 $1067 per ton PM10

In a Venturi scrubber, water is injected into the flue gas stream at the Venturi throat to form droplets. Fly ash particles 

impact with the droplets to form a wet by-product which is then disposed of. The forceful contact resulting from the droplet 

dispersal (spray tower), contraction of the gas stream (Venturi) or counter current flow (collision), removes PM as well as 

SO2 from the flue gas. Condensation scrubbers are designed to control PM with a diameter of 0.25–1.0 μm. Venturi 

scrubbers are effective in controlling both PM10 and PM2.5. This control applies operations with oil-fired boilers.

STAPPA/ALAPCO 

2006; EPA 1998a; EPA 

1999b
Point & NonPoint PM

Menu of Control Measures

Updated 8/6/2013

Printed 8/6/2013 46 of 67

Source Category Emission Reduction 

Measure Name Control Efficiency (%)* Cost Effectiveness (2006$/ton)**

Other Pollutants 

Controlled Description/Notes/Caveats References

Mineral Products

CEM Upgrade and 

Increased Monitoring 

Frequency of PM 

Controls

8 $5,763 per ton PM

This measure examines the impacts of improving the PM monitoring technique at units currently using an ESP, scrubber, 

or fabric filter. In this improved technique scenario, the monitoring technique is upgraded to a PM continuous emission 

monitor. This improved monitoring technique also results in an increase to the monitoring frequency

because a PM CEMS can make a measurement every 7.5 minutes. The monitoring frequency increases from once per 

day to eight times per hour.

Barr and Schaffner, 

2003, EPA 2000a

Mineral Products

Increased Monitoring 

Frequency (IMF) of PM 

Controls

7 $687 per ton PM

This measure is to conduct improved monitoring for PM2.5 emissions at stationary sources. Improved monitoring in this 

case means increasing the monitoring frequency of electrostatic precipitators, scrubbers, and fabric filters from once per 

day to four times per hour, with no change in monitoring technique.

The incremental costs included a one-time cost for development of the improved monitoring and recurring annual burden 

costs for incremental record keeping, reporting, and certification activities.

Barr and Schaffner, 

2003, EPA 2000a

Mineral Products - Coal 

Cleaning Fabric Filter 99 $147-$186 per ton PM10

A fabric filter, or baghouse, consists of a number of fabric bags placed in parallel inside of an enclosure. Particulate matter 

is collected on the surface of the bags as the gas stream passes through them. The particulate is periodically removed 

from the bags and collected in hoppers located beneath the bags. A number of methods are employed to facilitate the 

removal of particulate from the bags, including shaking, reverse air flow, and pulse air flow. The only potential drawback to 

a fabric filter would be when used in conjunction with a high moisture flue gas stream or with extremely high temperatures. 

If moisture levels in the flue gas stream are too high then filter caking can occur. Cost-effectiveness varies depending on 

the type of filter (Reverse-Air Cleaned Type, Mech. Shaker Type, Pulse Jet Type) and is based on EPA’s cost-estimating 

spreadsheet for fabric filters. This control applies to coal cleaning at coal mining operations. Coal mining, cleaning and 

material handling (305010) consists of the preparation and handling of coal to upgrade its value.

EPA 1998a; EPA 

2000b; 

EPA 2000c; EPA 

2000d; 

Mineral Products - Coal 

Cleaning

Paper/Nonwoven Filters 

- Cartridge Collector 

Type

99 $179 per ton PM10

This control is the use of paper or non-woven filters (cartridge collector type) to reduce PM emissions. The waste gas 

stream is passed through the fibrous filter media causing PM in the gas stream to be collected on the media by sieving and 

other mechanisms. In general, the filter media is pleated to provide a larger surface area to volume flow rate. There are 

variety of cartridge designs and dimensions. Typical designs include flat panels, V-shaped packs or cylindrical packs. For 

certain applications, two cartridges may be placed in series. This control measure applies to machining operations as a 

part of fabricated metal products processing and production. This control applies to coal cleaning at coal mining 

operations. Coal mining, cleaning and material handling (305010) consists of the preparation and handling of coal to 

upgrade its value

STAPPA/ALAPCO 

2006; EPA 1998a; EPA 

2000e

Mineral Products - Coal 

Cleaning Venturi Scrubber 98 $1067 per ton PM10

In a Venturi scrubber, water is injected into the flue gas stream at the Venturi throat to form droplets. Fly ash particles 

impact with the droplets to form a wet by-product which is then disposed of. The forceful contact resulting from the droplet 

dispersal (spray tower), contraction of the gas stream (Venturi) or counter current flow (collision), removes PM as well as 

SO2 from the flue gas. Condensation scrubbers are designed to control PM with a diameter of 0.25–1.0 μm. Venturi 

scrubbers are effective in controlling both PM10 and PM2.5. This control applies to coal cleaning processes at coal mining 

operations. Coal mining, cleaning and material handling (305010) consists of the preparation and handling of coal to 

upgrade its value. For the purpose of this study, thermal dryers, pneumatic coal cleaning and truck/vehicle travel are the 

sources considered.

STAPPA/ALAPCO 

2006; EPA 1998a; EPA 

1999b

Mineral Products - 

Miscellaneous Mineral 

Production Operations

Dry Electrostatic 

Precipitator (ESP) - 

Wire Plate Type

95 $156 per ton PM10

An electrostatic precipitator applies electrical forces to separate suspended particles from the flue gas stream. The 

suspended particles are given an electrical charge by passing through a high voltage DC corona region in which gaseous 

ions flow. There are two general types of ESP: wire/plate and wire/pipe types. Further, ESPs come in both wet and dry 

configurations. This control is the use of Dry ESP Wire Plate Type. In dry ESPs, the collectors are knocked by various 

mechanical means to dislodge the particulate, which slides downward into a hopper. This control applies to miscellaneous 

mineral production operations including (but not limited to) brick manufacture, calcium carbide operations, clay and fly ash 

sintering, concrete batching, gypsum manufacturing, lime production, phosphate rock operations, sand production, 

fiberglass manufacturing and glass manufacturing operations. Materials handling operations including crushing, grinding, 

and screening, can produce significant PM emissions.

EPA 1998a; EPA 1999c

Mineral Products - 

Miscellaneous Mineral 

Production Operations

Dry Electrostatic 

Precipitator (ESP) - 

Wire Plate Type

99.5 This control measure is the same as the dry ESP for this source category with a control efficiency of 95%. It is expected 

that by 2020, the control efficiency for this sytem will increase to 99.5% for PM2.5. EPA 1998a; EPA 1999c

Mineral Products - 

Miscellaneous Mineral 

Production Operations

Fabric Filter 99 $147-$186 per ton 

PM10

A fabric filter, or baghouse, consists of a number of fabric bags placed in parallel inside of an enclosure. Particulate matter 

is collected on the surface of the bags as the gas stream passes through them. The particulate is periodically removed 

from the bags and collected in hoppers located beneath the bags. A number of methods are employed to facilitate the 

removal of particulate from the bags, including shaking, reverse air flow, and pulse air flow. The only potential drawback to 

a fabric filter would be when used in conjunction with a high moisture flue gas stream or with extremely high temperatures. 

If moisture levels in the flue gas stream are too high then filter caking can occur. Cost-effectiveness varies depending on 

the type of filter (Reverse-Air Cleaned Type, Mech. Shaker Type, Pulse Jet Type) and is based on EPA’s cost-estimating 

spreadsheet for fabric filters. This control applies to miscellaneous mineral production operations including (but not limited 

to) brick manufacture, calcium carbide operations, clay and fly ash sintering, concrete batching, gypsum manufacturing, 

lime production, phosphate rock operations, sand production, fiberglass manufacturing and glass manufacturing 

operations. Materials handling operations including crushing, grinding, and screening, can produce significant PM 

emissions.

EPA 1998a; EPA 

2000b; 

EPA 2000c; EPA 

2000d; 
Point & NonPoint PM

Menu of Control Measures

Updated 8/6/2013

Printed 8/6/2013 47 of 67

Source Category Emission Reduction 

Measure Name Control Efficiency (%)* Cost Effectiveness (2006$/ton)**

Other Pollutants 

Controlled Description/Notes/Caveats References

Mineral Products - 

Miscellaneous Mineral 

Production Operations

Paper/Nonwoven Filters 

- Cartridge Collector 

Type

99 $179 per ton PM10

This control is the use of paper or non-woven filters (cartridge collector type) to reduce PM emissions. The waste gas 

stream is passed through the fibrous filter media causing PM in the gas stream to be collected on the media by sieving and 

other mechanisms. In general, the filter media is pleated to provide a larger surface area to volume flow rate. There are 

variety of cartridge designs and dimensions. Typical designs include flat panels, V-shaped packs or cylindrical packs. For 

certain applications, two cartridges may be placed in series. This control measure applies to machining operations as a 

part of fabricated metal products processing and production. This control applies to miscellaneous mineral production 

operations including (but not limited to) brick manufacture, calcium carbide operations, clay and fly ash sintering, concrete 

batching, gypsum manufacturing, lime production, phosphate rock operations, sand production, fiberglass manufacturing 

and glass manufacturing operations. Materials handling operations including crushing, grinding, and screening, can 

produce significant PM emissions

STAPPA/ALAPCO 

2006; EPA 1998a; EPA 

2000e

Mineral Products - 

Miscellaneous Mineral 

Production Operations

Wet Electrostatic 

Precipitator (ESP) - 

Wire Plate Type

95 $313 per ton PM10

An electrostatic precipitator applies electrical forces to separate suspended particles from the flue gas stream. The 

suspended particles are given an electrical charge by passing through a high voltage DC corona region in which gaseous 

ions flow. There are two general types of ESP: wire/plate and wire/pipe types. Further, ESPs come in both wet and dry 

configurations. This control is the use of Wet ESP Wire Plate Type. Unlike dry ESPs, resistivity of the collected material is 

not a major factor in performance. Because of the high humidity in a wet ESP, the resistivity of particles is lowered, 

eliminating the "back corona" condition. The frequent washing of the plates also limits particle buildup on the collectors. 

This control applies to miscellaneous mineral production operations including (but not limited to) brick manufacture, 

calcium carbide operations, clay and fly ash sintering, concrete batching, gypsum manufacturing, lime production, 

phosphate rock operations, sand production, fiberglass manufacturing and glass manufacturing operations. Materials 

handling operations including crushing grinding and screening can produce significant PM emissions

EPA1998a; EPA 1999a

Mineral Products - 

Miscellaneous Mineral 

Production Operations

Wet Electrostatic 

Precipitator (ESP) - 

Wire Plate Type

99.5 This control measure is the same as the dry ESP for this source category with a control efficiency of 95%. It is expected 

that by 2020, the control efficiency for this sytem will increase to 99.5% for PM2.5. EPA1998a; EPA 1999a

Mineral Products - 

Stone Quarrying & 

Processing

Dry Electrostatic 

Precipitator (ESP) - 

Wire Plate Type

95 (PM10 mainly) $156 per ton PM10

An electrostatic precipitator applies electrical forces to separate suspended particles from the flue gas stream. The 

suspended particles are given an electrical charge by passing through a high voltage DC corona region in which gaseous 

ions flow. There are two general types of ESP: wire/plate and wire/pipe types. Further, ESPs come in both wet and dry 

configurations. This control is the use of Dry ESP Wire Plate Type. In dry ESPs, the collectors are knocked by various 

mechanical means to dislodge the particulate, which slides downward into a hopper. This control applies to stone quarrying 

and processing operations. Nonmetallic Mineral Processing (305020) - ore crushing, grinding, and screening, and 

Calciners (SCC 305150) and Dryers (SCC 30502012) are considered in this category. Materials handling operations 

including crushing, grinding, and screening, can produce significant PM emissions.

EPA 1998a; EPA 1999c

Mineral Products - 

Stone Quarrying & 

Processing

Dry Electrostatic 

Precipitator (ESP) - 

Wire Plate Type

99.5 (PM10 mainly) This control measure is the same as the dry ESP for this source category with a control efficiency of 95%. It is expected 

that by 2020, the control efficiency for this sytem will increase to 99.5% for PM2.5. EPA 1998a; EPA 1999c

Mineral Products - 

Stone Quarrying & 

Processing

Fabric Filter 99 (PM10 mainly) $147-$186 per ton 

PM10

A fabric filter, or baghouse, consists of a number of fabric bags placed in parallel inside of an enclosure. Particulate matter 

is collected on the surface of the bags as the gas stream passes through them. The particulate is periodically removed 

from the bags and collected in hoppers located beneath the bags. A number of methods are employed to facilitate the 

removal of particulate from the bags, including shaking, reverse air flow, and pulse air flow. The only potential drawback to 

a fabric filter would be when used in conjunction with a high moisture flue gas stream or with extremely high temperatures. 

If moisture levels in the flue gas stream are too high then filter caking can occur. Cost-effectiveness varies depending on 

the type of filter (Reverse-Air Cleaned Type, Mech. Shaker Type, Pulse Jet Type) and is based on EPA’s cost-estimating 

spreadsheet for fabric filters. This control applies to stone quarrying and processing operations. Nonmetallic Mineral 

Processing (305020) - ore crushing, grinding, and screening, and Calciners (SCC 305150) and Dryers (SCC 30502012) 

are considered in this category. Materials handling operations including crushing, grinding, and screening, can produce 

significant PM emissions.

EPA 1998a; EPA 

2000b; 

EPA 2000c; EPA 

2000d; 

Mineral Products - 

Stone Quarrying & 

Processing

Paper/Nonwoven Filters 

- Cartridge Collector 

Type

99 (PM10 mainly) $179 per ton PM10

This control is the use of paper or non-woven filters (cartridge collector type) to reduce PM emissions. The waste gas 

stream is passed through the fibrous filter media causing PM in the gas stream to be collected on the media by sieving and 

other mechanisms. In general, the filter media is pleated to provide a larger surface area to volume flow rate. There are 

variety of cartridge designs and dimensions. Typical designs include flat panels, V-shaped packs or cylindrical packs. For 

certain applications, two cartridges may be placed in series. This control applies to stone quarrying and processing 

operations. Nonmetallic Mineral Processing (305020) - ore crushing, grinding, and screening, and Calciners (SCC 

305150) and Dryers (SCC 30502012) are considered in this category. Materials handling operations including crushing, 

grinding, and screening, can produce significant PM emissions.

STAPPA/ALAPCO 

2006; EPA 1998a; EPA 

2000e

Mineral Products - 

Stone Quarrying & 

Processing

Venturi Scrubber 90 (PM10 mainly) $1067 per ton PM10

In a Venturi scrubber, water is injected into the flue gas stream at the Venturi throat to form droplets. Fly ash particles 

impact with the droplets to form a wet by-product which is then disposed of. The forceful contact resulting from the droplet 

dispersal (spray tower), contraction of the gas stream (Venturi) or counter current flow (collision), removes PM as well as 

SO2 from the flue gas. Condensation scrubbers are designed to control PM with a diameter of 0.25–1.0 μm. Venturi 

scrubbers are effective in controlling both PM10 and PM2.5. This control applies to stone quarrying and processing 

operations. Nonmetallic Mineral Processing (305020) - ore crushing, grinding, and screening, and Calciners (SCC 

305150) and Dryers (SCC 30502012) are considered in this category. Materials handling operations including crushing, 

grinding, and screening, can produce significant PM emissions.

STAPPA/ALAPCO 

2006; EPA 1998a; EPA 

1999b
Point & NonPoint PM

Menu of Control Measures

Updated 8/6/2013

Printed 8/6/2013 48 of 67

Source Category Emission Reduction 

Measure Name Control Efficiency (%)* Cost Effectiveness (2006$/ton)**

Other Pollutants 

Controlled Description/Notes/Caveats References

Mineral Products - 

Stone Quarrying & 

Processing

Wet Electrostatic 

Precipitator (ESP) - 

Wire Plate Type

95 (PM10 mainly) $313 per ton PM10

An electrostatic precipitator applies electrical forces to separate suspended particles from the flue gas stream. The 

suspended particles are given an electrical charge by passing through a high voltage DC corona region in which gaseous 

ions flow. There are two general types of ESP: wire/plate and wire/pipe types. Further, ESPs come in both wet and dry 

configurations. This control is the use of Wet ESP Wire Plate Type. Unlike dry ESPs, resistivity of the collected material is 

not a major factor in performance. Because of the high humidity in a wet ESP, the resistivity of particles is lowered, 

eliminating the "back corona" condition. The frequent washing of the plates also limits particle buildup on the collectors. 

This control applies to stone quarrying and processing operations. Nonmetallic Mineral Processing (305020) - ore 

crushing, grinding, and screening, and Calciners (SCC 305150) and Dryers (SCC 30502012) are considered in this 

category. Materials handling operations including crushing, grinding, and screening, can produce significant PM emissions.

EPA1998a; EPA 1999a

Mineral Products - 

Stone Quarrying & 

Processing

Wet Electrostatic 

Precipitator (ESP) - 

Wire Plate Type

99.5 (PM10 mainly) This control measure is the same as the dry ESP for this source category with a control efficiency of 95%. It is expected 

that by 2020, the control efficiency for this sytem will increase to 99.5% for PM2.5. EPA1998a; EPA 1999a

Municipal Waste 

Incineration

Dry Electrostatic 

Precipitator (ESP) - 

Wire Plate Type

95 $156 per ton PM10

An electrostatic precipitator applies electrical forces to separate suspended particles from the flue gas stream. The 

suspended particles are given an electrical charge by passing through a high voltage DC corona region in which gaseous 

ions flow. There are two general types of ESP: wire/plate and wire/pipe types. Further, ESPs come in both wet and dry 

configurations. This control is the use of Dry ESP Wire Plate Type. In dry ESPs, the collectors are knocked by various 

mechanical means to dislodge the particulate, which slides downward into a hopper. This control applies to municipal 

waste incineration operations classified under SCCs: 50100101, 50100102, 50100103, 50100105, and 50100107.

EPA 1998a; EPA 1999c

Municipal Waste 

Incineration

Dry Electrostatic 

Precipitator (ESP) - 

Wire Plate Type

99.5 This control measure is the same as the dry ESP for this source category with a control efficiency of 95%. It is expected 

that by 2020, the control efficiency for this sytem will increase to 99.5% for PM2.5. EPA 1998a; EPA 1999c

Non-Ferrous Metals 

Processing

CEM Upgrade and 

Increased Monitoring 

Frequency of PM 

Controls

8 $5,763 per ton PM

This measure examines the impacts of improving the PM monitoring technique at units currently using an ESP, scrubber, 

or fabric filter. In this improved technique scenario, the monitoring technique is upgraded to a PM continuous emission 

monitor. This improved monitoring technique also results in an increase to the monitoring frequency

because a PM CEMS can make a measurement every 7.5 minutes. The monitoring frequency increases from once per 

day to eight times per hour.

Barr and Schaffner, 

2003, EPA 2000a

Non-Ferrous Metals 

Processing

Increased Monitoring 

Frequency (IMF) of PM 

Controls

7 $687 per ton PM

This measure is to conduct improved monitoring for PM2.5 emissions at stationary sources. Improved monitoring in this 

case means increasing the monitoring frequency of electrostatic precipitators, scrubbers, and fabric filters from once per 

day to four times per hour, with no change in monitoring technique.

The incremental costs included a one-time cost for development of the improved monitoring and recurring annual burden 

costs for incremental record keeping, reporting, and certification activities.

Barr and Schaffner, 

2003, EPA 2000a

Non-Ferrous Metals 

Processing - Aluminum

Dry Electrostatic 

Precipitator (ESP) - 

Wire Plate Type

95 $156 per ton PM10

An electrostatic precipitator applies electrical forces to separate suspended particles from the flue gas stream. The 

suspended particles are given an electrical charge by passing through a high voltage DC corona region in which gaseous 

ions flow. There are two general types of ESP: wire/plate and wire/pipe types. Further, ESPs come in both wet and dry 

configurations. This control is the use of Dry ESP Wire Plate Type. In dry ESPs, the collectors are knocked by various 

mechanical means to dislodge the particulate, which slides downward into a hopper. This control applies to aluminum 

processing operations.

EPA 1998a; EPA 1999c

Non-Ferrous Metals 

Processing - Aluminum

Dry Electrostatic 

Precipitator (ESP) - 

Wire Plate Type

99.5 This control measure is the same as the dry ESP for this source category with a control efficiency of 95%. It is expected 

that by 2020, the control efficiency for this sytem will increase to 99.5% for PM2.5. EPA 1998a; EPA 1999c

Non-Ferrous Metals 

Processing - Aluminum Fabric Filter 99 $159-$186 per ton PM10

A fabric filter, or baghouse, consists of a number of fabric bags placed in parallel inside of an enclosure. Particulate matter 

is collected on the surface of the bags as the gas stream passes through them. The particulate is periodically removed 

from the bags and collected in hoppers located beneath the bags. A number of methods are employed to facilitate the 

removal of particulate from the bags, including shaking, reverse air flow, and pulse air flow. The only potential drawback to 

a fabric filter would be when used in conjunction with a high moisture flue gas stream or with extremely high temperatures. 

If moisture levels in the flue gas stream are too high then filter caking can occur. Cost-effectiveness varies depending on 

the type of filter (Reverse-Air Cleaned Type or Mech. Shaker Type) and is based on EPA’s cost-estimating spreadsheet for 

fabric filters This control applies to aluminum processing operations

EPA 1998a; EPA 

2000b; EPA 2000c

Non-Ferrous Metals 

Processing - Aluminum

Wet Electrostatic 

Precipitator (ESP) - 

Wire Plate Type

95 $313 per ton PM10

An electrostatic precipitator applies electrical forces to separate suspended particles from the flue gas stream. The 

suspended particles are given an electrical charge by passing through a high voltage DC corona region in which gaseous 

ions flow. There are two general types of ESP: wire/plate and wire/pipe types. Further, ESPs come in both wet and dry 

configurations. This control is the use of Wet ESP Wire Plate Type. Unlike dry ESPs, resistivity of the collected material is 

not a major factor in performance. Because of the high humidity in a wet ESP, the resistivity of particles is lowered, 

eliminating the "back corona" condition. The frequent washing of the plates also limits particle buildup on the collectors. 

This control applies to aluminum processing operations.

EPA1998a; EPA 1999a

Non-Ferrous Metals 

Processing - Aluminum

Wet Electrostatic 

Precipitator (ESP) - 

Wire Plate Type

99.5 This control measure is the same as the dry ESP for this source category with a control efficiency of 95%. It is expected 

that by 2020, the control efficiency for this sytem will increase to 99.5% for PM2.5. EPA1998a; EPA 1999a
Point & NonPoint PM

Menu of Control Measures

Updated 8/6/2013

Printed 8/6/2013 49 of 67

Source Category Emission Reduction 

Measure Name Control Efficiency (%)* Cost Effectiveness (2006$/ton)**

Other Pollutants 

Controlled Description/Notes/Caveats References

Non-Ferrous Metals 

Processing - Copper

Dry Electrostatic 

Precipitator (ESP) - 

Wire Plate Type

95 $156 per ton PM10

An electrostatic precipitator applies electrical forces to separate suspended particles from the flue gas stream. The 

suspended particles are given an electrical charge by passing through a high voltage DC corona region in which gaseous 

ions flow. There are two general types of ESP: wire/plate and wire/pipe types. Further, ESPs come in both wet and dry 

configurations. This control is the use of Dry ESP Wire Plate Type. In dry ESPs, the collectors are knocked by various 

mechanical means to dislodge the particulate, which slides downward into a hopper. This control applies to copper alloy 

processing operations

EPA 1998a; EPA 1999c

Non-Ferrous Metals 

Processing - Copper

Dry Electrostatic 

Precipitator (ESP) - 

Wire Plate Type

99.5 This control measure is the same as the dry ESP for this source category with a control efficiency of 95%. It is expected 

that by 2020, the control efficiency for this sytem will increase to 99.5% for PM2.5. EPA 1998a; EPA 1999c

Non-Ferrous Metals 

Processing - Copper Fabric Filter 99 $159-$186 per ton PM10

A fabric filter, or baghouse, consists of a number of fabric bags placed in parallel inside of an enclosure. Particulate matter 

is collected on the surface of the bags as the gas stream passes through them. The particulate is periodically removed 

from the bags and collected in hoppers located beneath the bags. A number of methods are employed to facilitate the 

removal of particulate from the bags, including shaking, reverse air flow, and pulse air flow. The only potential drawback to 

a fabric filter would be when used in conjunction with a high moisture flue gas stream or with extremely high temperatures. 

If moisture levels in the flue gas stream are too high then filter caking can occur. Cost-effectiveness varies depending on 

the type of filter (Reverse-Air Cleaned Type or Mech. Shaker Type) and is based on EPA’s cost-estimating spreadsheet for 

fabric filters This control applies to copper alloy processing operations

EPA 1998a; EPA 

2000b; EPA 2000c

Non-Ferrous Metals 

Processing - Copper

Wet Electrostatic 

Precipitator (ESP) - 

Wire Plate Type

95 $313 per ton PM10

An electrostatic precipitator applies electrical forces to separate suspended particles from the flue gas stream. The 

suspended particles are given an electrical charge by passing through a high voltage DC corona region in which gaseous 

ions flow. There are two general types of ESP: wire/plate and wire/pipe types. Further, ESPs come in both wet and dry 

configurations. This control is the use of Wet ESP Wire Plate Type. Unlike dry ESPs, resistivity of the collected material is 

not a major factor in performance. Because of the high humidity in a wet ESP, the resistivity of particles is lowered, 

eliminating the "back corona" condition. The frequent washing of the plates also limits particle buildup on the collectors. 

This control applies to copper alloy processing operations.

EPA1998a; EPA 1999a

Non-Ferrous Metals 

Processing - Copper

Wet Electrostatic 

Precipitator (ESP) - 

Wire Plate Type

99.5 This control measure is the same as the dry ESP for this source category with a control efficiency of 95%. It is expected 

that by 2020, the control efficiency for this sytem will increase to 99.5% for PM2.5. EPA1998a; EPA 1999a

Non-Ferrous Metals 

Processing - Lead

Dry Electrostatic 

Precipitator (ESP) - 

Wire Plate Type

95 $156 per ton PM10

An electrostatic precipitator applies electrical forces to separate suspended particles from the flue gas stream. The 

suspended particles are given an electrical charge by passing through a high voltage DC corona region in which gaseous 

ions flow. There are two general types of ESP: wire/plate and wire/pipe types. Further, ESPs come in both wet and dry 

configurations. This control is the use of Dry ESP Wire Plate Type. In dry ESPs, the collectors are knocked by various 

mechanical means to dislodge the particulate, which slides downward into a hopper. This control applies to lead 

processing operations

EPA 1998a; EPA 1999c

Non-Ferrous Metals 

Processing - Lead

Dry Electrostatic 

Precipitator (ESP) - 

Wire Plate Type

99.5 This control measure is the same as the dry ESP for this source category with a control efficiency of 95%. It is expected 

that by 2020, the control efficiency for this sytem will increase to 99.5% for PM2.5. EPA 1998a; EPA 1999c

Non-Ferrous Metals 

Processing - Lead Fabric Filter 99 $159-$186 per ton PM10

A fabric filter, or baghouse, consists of a number of fabric bags placed in parallel inside of an enclosure. Particulate matter 

is collected on the surface of the bags as the gas stream passes through them. The particulate is periodically removed 

from the bags and collected in hoppers located beneath the bags. A number of methods are employed to facilitate the 

removal of particulate from the bags, including shaking, reverse air flow, and pulse air flow. The only potential drawback to 

a fabric filter would be when used in conjunction with a high moisture flue gas stream or with extremely high temperatures. 

If moisture levels in the flue gas stream are too high then filter caking can occur. Cost-effectiveness varies depending on 

the type of filter (Reverse-Air Cleaned Type or Mech. Shaker Type) and is based on EPA’s cost-estimating spreadsheet for 

fabric filters. This control applies to lead processing operations.

EPA 1998a; EPA 

2000b; EPA 2000c

Non-Ferrous Metals 

Processing - Lead

Wet Electrostatic 

Precipitator (ESP) - 

Wire Plate Type

95 $313 per ton PM10

An electrostatic precipitator applies electrical forces to separate suspended particles from the flue gas stream. The 

suspended particles are given an electrical charge by passing through a high voltage DC corona region in which gaseous 

ions flow. There are two general types of ESP: wire/plate and wire/pipe types. Further, ESPs come in both wet and dry 

configurations. This control is the use of Wet ESP Wire Plate Type. Unlike dry ESPs, resistivity of the collected material is 

not a major factor in performance. Because of the high humidity in a wet ESP, the resistivity of particles is lowered, 

eliminating the "back corona" condition. The frequent washing of the plates also limits particle buildup on the collectors. 

This control applies to lead processing operations.

EPA1998a; EPA 1999a

Non-Ferrous Metals 

Processing - Lead

Wet Electrostatic 

Precipitator (ESP) - 

Wire Plate Type

99.5 This control measure is the same as the dry ESP for this source category with a control efficiency of 95%. It is expected 

that by 2020, the control efficiency for this sytem will increase to 99.5% for PM2.5. EPA1998a; EPA 1999a

Non-Ferrous Metals 

Processing - Other

Dry Electrostatic 

Precipitator (ESP) - 

Wire Plate Type

95 $156 per ton PM10

An electrostatic precipitator applies electrical forces to separate suspended particles from the flue gas stream. The 

suspended particles are given an electrical charge by passing through a high voltage DC corona region in which gaseous 

ions flow. There are two general types of ESP: wire/plate and wire/pipe types. Further, ESPs come in both wet and dry 

configurations. This control is the use of Dry ESP Wire Plate Type. In dry ESPs, the collectors are knocked by various 

mechanical means to dislodge the particulate, which slides downward into a hopper. This control applies to miscellaneous 

non-ferrous metals processing operations, including molybdenum, titanium, gold, barium ore, lead battery, magnesium, 

nickel, electrode manufacture and metal heat treating operations.

EPA 1998a; EPA 1999c
Point & NonPoint PM

Menu of Control Measures

Updated 8/6/2013

Printed 8/6/2013 50 of 67

Source Category Emission Reduction 

Measure Name Control Efficiency (%)* Cost Effectiveness (2006$/ton)**

Other Pollutants 

Controlled Description/Notes/Caveats References

Non-Ferrous Metals 

Processing - Other

Dry Electrostatic 

Precipitator (ESP) - 

Wire Plate Type

99.5 This control measure is the same as the dry ESP for this source category with a control efficiency of 95%. It is expected 

that by 2020, the control efficiency for this sytem will increase to 99.5% for PM2.5. EPA 1998a; EPA 1999c

Non-Ferrous Metals 

Processing - Other Fabric Filter 99 $159-$186 per ton PM10

A fabric filter, or baghouse, consists of a number of fabric bags placed in parallel inside of an enclosure. Particulate matter 

is collected on the surface of the bags as the gas stream passes through them. The particulate is periodically removed 

from the bags and collected in hoppers located beneath the bags. A number of methods are employed to facilitate the 

removal of particulate from the bags, including shaking, reverse air flow, and pulse air flow. The only potential drawback to 

a fabric filter would be when used in conjunction with a high moisture flue gas stream or with extremely high temperatures. 

If moisture levels in the flue gas stream are too high then filter caking can occur. Cost-effectiveness varies depending on 

the type of filter (Reverse-Air Cleaned Type or Mech. Shaker Type) and is based on EPA’s cost-estimating spreadsheet for 

fabric filters. This control applies to miscellaneous non-ferrous metals processing operations, including molybdenum, 

titanium, gold, barium ore, lead battery, magnesium, nickel, electrode manufacture and metal heat treating operations.

EPA 1998a; EPA 

2000b; EPA 2000c

Non-Ferrous Metals 

Processing - Other

Wet Electrostatic 

Precipitator (ESP) - 

Wire Plate Type

95 $313 per ton PM10

An electrostatic precipitator applies electrical forces to separate suspended particles from the flue gas stream. The 

suspended particles are given an electrical charge by passing through a high voltage DC corona region in which gaseous 

ions flow. There are two general types of ESP: wire/plate and wire/pipe types. Further, ESPs come in both wet and dry 

configurations. This control is the use of Wet ESP Wire Plate Type. Unlike dry ESPs, resistivity of the collected material is 

not a major factor in performance. Because of the high humidity in a wet ESP, the resistivity of particles is lowered, 

eliminating the "back corona" condition. The frequent washing of the plates also limits particle buildup on the collectors. 

This control applies to miscellaneous non-ferrous metals processing operations, including molybdenum, titanium, gold, 

barium ore, lead battery, magnesium, nickel, electrode manufacture and metal heat treating operations.

EPA1998a; EPA 1999a

Non-Ferrous Metals 

Processing - Other

Wet Electrostatic 

Precipitator (ESP) - 

Wire Plate Type

99.5 This control measure is the same as the dry ESP for this source category with a control efficiency of 95%. It is expected 

that by 2020, the control efficiency for this sytem will increase to 99.5% for PM2.5. EPA1998a; EPA 1999a

Non-Ferrous Metals 

Processing - Zinc

Dry Electrostatic 

Precipitator (ESP) - 

Wire Plate Type

95 $156 per ton PM10

An electrostatic precipitator applies electrical forces to separate suspended particles from the flue gas stream. The 

suspended particles are given an electrical charge by passing through a high voltage DC corona region in which gaseous 

ions flow. There are two general types of ESP: wire/plate and wire/pipe types. Further, ESPs come in both wet and dry 

configurations. This control is the use of Dry ESP Wire Plate Type. In dry ESPs, the collectors are knocked by various 

mechanical means to dislodge the particulate, which slides downward into a hopper. This control applies to zinc processing 

operations.

EPA 1998a; EPA 1999c

Non-Ferrous Metals 

Processing - Zinc

Dry Electrostatic 

Precipitator (ESP) - 

Wire Plate Type

99.5 This control measure is the same as the dry ESP for this source category with a control efficiency of 95%. It is expected 

that by 2020, the control efficiency for this sytem will increase to 99.5% for PM2.5. EPA 1998a; EPA 1999c

Non-Ferrous Metals 

Processing - Zinc Fabric Filter 99 $159-$186 per ton PM10

A fabric filter, or baghouse, consists of a number of fabric bags placed in parallel inside of an enclosure. Particulate matter 

is collected on the surface of the bags as the gas stream passes through them. The particulate is periodically removed 

from the bags and collected in hoppers located beneath the bags. A number of methods are employed to facilitate the 

removal of particulate from the bags, including shaking, reverse air flow, and pulse air flow. The only potential drawback to 

a fabric filter would be when used in conjunction with a high moisture flue gas stream or with extremely high temperatures. 

If moisture levels in the flue gas stream are too high then filter caking can occur. Cost-effectiveness varies depending on 

the type of filter (Reverse-Air Cleaned Type or Mech. Shaker Type) and is based on EPA’s cost-estimating spreadsheet for 

fabric filters. This control applies to zinc processing operations.

EPA 1998a; EPA 

2000b; EPA 2000c

Non-Ferrous Metals 

Processing - Zinc

Wet Electrostatic 

Precipitator (ESP) - 

Wire Plate Type

95 $313 per ton PM10

An electrostatic precipitator applies electrical forces to separate suspended particles from the flue gas stream. The 

suspended particles are given an electrical charge by passing through a high voltage DC corona region in which gaseous 

ions flow. There are two general types of ESP: wire/plate and wire/pipe types. Further, ESPs come in both wet and dry 

configurations. This control is the use of Wet ESP Wire Plate Type. Unlike dry ESPs, resistivity of the collected material is 

not a major factor in performance. Because of the high humidity in a wet ESP, the resistivity of particles is lowered, 

eliminating the "back corona" condition. The frequent washing of the plates also limits particle buildup on the collectors. 

This control applies to zinc processing operations

EPA1998a; EPA 1999a

Non-Ferrous Metals 

Processing - Zinc

Wet Electrostatic 

Precipitator (ESP) - 

Wire Plate Type

99.5 This control measure is the same as the dry ESP for this source category with a control efficiency of 95%. It is expected 

that by 2020, the control efficiency for this sytem will increase to 99.5% for PM2.5. EPA1998a; EPA 1999a

Open Burning

Substitution of chipping, 

shredding, and 

landfilling for open 

burning

50-100 $4,219 NOx

Development measure from PM NAAQS RIA.

This measure requires residents to either landfill or chip and shred yard waste instead of burning it (this is related to open 

burning of land clearing debris for developments). This substitution can substantially reduce directly-emitted PM2.5. 

Landfill costs based upon limited cost information. Average landfill costs, and average debris/acre, may not well represent 

costs in some locations. Significant uncertainties exist in emissions factors for open burning.

EPA 2006a

Paved Roads

Limit the purchase of 

new street sweepers to 

PM10 efficient units

31 $37 per ton PM10

This control measure requires that all purchases of new or replacement street sweepers be limited to PM10-efficient units. 

Efficiency is incremental to the use of sweepers failing to qualify to certification standards and the cost-effectiveness is for 

purchasing and operating a certified unit instead of a non-certified unit. Efficiency and cost-effectiveness calculations are 

based on San Joaquin Valley Rule 8061.

San Joaquin Valley 

UAPCD 2003
Point & NonPoint PM

Menu of Control Measures

Updated 8/6/2013

Printed 8/6/2013 51 of 67

Source Category Emission Reduction 

Measure Name Control Efficiency (%)* Cost Effectiveness (2006$/ton)**

Other Pollutants 

Controlled Description/Notes/Caveats References

Paved Roads

Require 4 foot 

paved/stabilized 

shoulders

42-98

If required on all new 

paved roads: $15,677-

$629,336 per ton PM10.

If required on 50% of 

highest ADVT existing 

paved roads: $8,281-

$12,837 per ton PM10.

This control measure requires that all new or modified paved roads be constructed with paved shoulders that vary in width 

between 4 and 8 feet

depending on projected traffic levels,or the construction of paved or stabilized shoulders on existing paved roads with dirt 

shoulders (the 50% of road mileage that carried the most traffic). Efficiency and cost-effectiveness calculations are based 

on San Joaquin Valley Rule 8061.

San Joaquin Valley 

UAPCD 2003

Paved Roads

Require wind- and waterborne deposition to be 

removed within 24 

hours of discovery

8 $3,238 per ton PM10

Under this control measure, counties and cities would be required to respond within 24 hours to any deposition of soil onto 

public paved roads carried by wind or water erosion. Efficiency and cost-effectiveness calculations are based on San 

Joaquin Valley Rule 8061.

San Joaquin Valley 

UAPCD 2003

Paved Roads Street Sweeping 25 (PM10 mainly) $1,216 per ton PM10

Vacuum sweeping is a road surface cleaning operation that removes loose material from the roadway, preventing it from 

becoming airborne particulate when vehicles travel over the road surface. This control measure requires municipalities to 

sweep streets at least once per month with PM10 efficient units. Cost-effectiveness calculations are based on San Joaquin 

Valley Rule 8061.

San Joaquin Valley 

UAPCD 2003; Pechan 

2008

Residential Home 

Heating

Switch to Low Sulfur 

Fuel 80 $2,670 NOx, SO2, CO2

This measure will be a switch from high-sulfur (2,500 ppm sulfur content) to low-sulfur (500 ppm) home heating oil for 

residential users.

SO2 co-control - 75%.

NOx co-control - 10%.

CO2 co-control - 1-2%.

NESCAUM 2005

Unpaved Roads

Chemical Stabilization / 

Dust Suppressant 

Application

40-80 (PM10 mainly) $4,418 per ton PM

Chemical stabilization is a surface treatment option for unpaved roads (Dust Suppressant Application). Chemical 

suppressants used in road dust control may be either wetting or binding agents.The primary types of these suppressants 

are fresh or salt water in combination with a wetting agent; hygroscopic and deliquescent chemicals; organic binders; 

petroleum derived binders; and some waste products.

EPA 1986; WRAP 2006

Unpaved Roads

Limit maximum speed 

on unpaved roads to 

25mph

1 $1,227 per ton PM10

Under this proposed measure, a maximum speed limit would be set for unpaved roads of 25 miles per hour. 

Implementation of this measure would require signing of unpaved roads and enforcement of the limit. Efficiency and costeffectiveness calculations are based on San Joaquin Valley Rule 8061 and assumes that compliance with the speed limit 

will be no greater than 25%.

San Joaquin Valley 

UAPCD 2003

Unpaved Roads

Limit visible dust 

emissions to 20% 

opacity and require 

stabilized surfaces on 

unpaved parking areas 

receiving up to 100 trips 

per day

85 $5,941-$34,648 per ton 

PM10

Under this proposed control measure, unpaved parking areas would have to be sufficiently treated to prevent visible 

emissions greater than 20% opacity and to establish a surface that would comply with stability requirements specified in 

San Joaquin Valley Rule 8011. 

San Joaquin Valley 

UAPCD 2003

Unpaved Roads

Pave unpaved roads 

and unpaved parking 

lots (in urban areas)

99 $2,454-$6,725 per ton 

PM10

Under this proposed measure, no new unpaved roads would be constructed. Also, existing public unpaved roads and 

parling areas in urban areas would be required to be paved. Baseline and controlled PM10 emissions were computed 

using the CARB statewide emissions factor for unpaved and paved roads. Cost-effectiveness calculations are based on 

San Joaquin Valley Rule 8061.

San Joaquin Valley 

UAPCD 2003

Unpaved Roads

Require paving, 4 

inches gravel, or dust 

suppressant at special 

event parkings

84 $6,793-$67,932 per ton 

PM10

Under this proposed measure, watering of special event unpaved parking areas would not be deemed an acceptable 

control option, and one of several alternatives (paving, 4 inches of gravel, or dust suppressants) would be required. For 

the purposes of this analysis, the use of polymer emulsion dust suppressants was modeled. Efficiency and costeffectiveness calculations are based on San Joaquin Valley Rule 8071 and assumes event parking involving more than 

1,000 vehicles.

San Joaquin Valley 

UAPCD 2003

Utility Boilers ESP (Electrostatic 

Precipitator) 96-99 $40-$591 Hg

An electrostatic precipitator applies electrical forces to separate suspended particles from the flue gas stream. The 

suspended particles are given an electrical charge by passing through a high voltage DC corona region in which gaseous 

ions flow. There are two general types of ESP: wire/plate and wire/pipe types. Further, ESPs come in both wet and dry 

configurations. 

STAPPA/ALAPCO 2006

Utility Boilers Fabric Filter 95-99.9 $42-$383

A fabric filter, or baghouse, consists of a number of fabric bags placed in parallel inside of an enclosure. Particulate matter 

is collected on the surface of the bags as the gas stream passes through them. The particulate is periodically removed 

from the bags and collected in hoppers located beneath the bags. A number of methods are employed to facilitate the 

removal of particulate from the bags, including shaking, reverse air flow, and pulse air flow. The only potential drawback to 

a fabric filter would be when used in conjunction with a high moisture flue gas stream or with extremely high temperatures. 

If moisture levels in the flue gas stream are too high then filter caking can occur. 

STAPPA/ALAPCO 2006
Point & NonPoint PM

Menu of Control Measures

Updated 8/6/2013

Printed 8/6/2013 52 of 67

Source Category Emission Reduction 

Measure Name Control Efficiency (%)* Cost Effectiveness (2006$/ton)**

Other Pollutants 

Controlled Description/Notes/Caveats References

Utility Boilers Wet Scrubber 70-99 $80-$2,726 SO2

The two most frequently utilized wet scrubbers for PM control are condensation scrubbers and venturi scrubbers. In a 

Venturi scrubber, water is injected into the flue gas stream at the Venturi throat to form droplets. Fly ash particles impact 

with the droplets to form a wet by-product which is then disposed of. The forceful contact resulting from the droplet 

dispersal (spray tower), contraction of the gas stream (Venturi) or counter current flow (collision), removes PM as well as 

SO2 from the flue gas. Condensation scrubbers are designed to control PM with a diameter of 0.25–1.0 μm. Venturi 

scrubbers are effective in controlling both PM10 and PM2.5.

STAPPA/ALAPCO 2006

Utility Boilers - Coal

Fuel switching away 

from coal: bituminous 

coal to natural gas

98 SO2, NOx

Fuel substitution involves replacing the current fuel with a fuel which emits less of a given pollutant when burned. For many 

older boilers, fuel switching is an especially attractive option because the capital investment is usually small when 

compared to that of control devices. This control measure involves switching from bituminous coal to natural gas.

EPA 1998a

Utility Boilers - Coal

Fuel switching away 

from coal: bituminous 

coal to residual oil

15 SO2, NOx

Fuel substitution involves replacing the current fuel with a fuel which emits less of a given pollutant when burned. For many 

older boilers, fuel switching is an especially attractive option because the capital investment is usually small when 

compared to that of control devices. This control measure involves switching from bituminous coal to residual oil.

EPA 1998a

Utility Boilers - Coal

Fuel switching away 

from coal: bituminous 

coal to subbituminous

21 SO2, NOx

Fuel substitution involves replacing the current fuel with a fuel which emits less of a given pollutant when burned. For many 

older boilers, fuel switching is an especially attractive option because the capital investment is usually small when 

compared to that of control devices. This control measure involves switching from bituminous coal to subbituminous.

EPA 1998a

Utility Boilers - Coal

Fuel switching away 

from coal: 

subbituminous coal to 

natural gas

97 SO2, NOx

Fuel substitution involves replacing the current fuel with a fuel which emits less of a given pollutant when burned. For many 

older boilers, fuel switching is an especially attractive option because the capital investment is usually small when 

compared to that of control devices. This control measure involves switching from subbituminous coal to natural gas.

EPA 1998a

Utility Boilers - Coal 

Fired Coal Washing 45 $420 per ton SO2 SO2, Hg

Coal washing (or coal cleaning) is a pre-combustion process that improves the quality of coal by removing impurities and 

increasing its heat content. It decreases PM emissions as well as SO2 emissions. Coal washing can also be effective in 

removing mercury (Hg) from the coal and the utility plants emissions. This control is applicable to electricity generating 

sources powered by pulverized dry-bottom and bituminous/subbituminous coal.

ERG 2000; EPA 1997a; 

SIU 1997

Utility Boilers - Oil

Fuel switching away 

from oil: residual oil to 

natural gas

97 SO2, NOx

Fuel substitution involves replacing the current fuel with a fuel which emits less of a given pollutant when burned. For many 

older boilers, fuel switching is an especially attractive option because the capital investment is usually small when 

compared to that of control devices. This control measure involves switching from residual oil to natural gas.

EPA 1998a

Wood Pulp & Paper

Dry Electrostatic 

Precipitator (ESP) - 

Wire Plate Type

95 $156 per ton PM10

An electrostatic precipitator applies electrical forces to separate suspended particles from the flue gas stream. The 

suspended particles are given an electrical charge by passing through a high voltage DC corona region in which gaseous 

ions flow. There are two general types of ESP: wire/plate and wire/pipe types. Further, ESPs come in both wet and dry 

configurations. This control is the use of Dry ESP Wire Plate Type. In dry ESPs, the collectors are knocked by various 

mechanical means to dislodge the particulate, which slides downward into a hopper. This control applies to wood pulp and 

paper product operations including Evaporators, Recovery Furnaces, Lime Kiln, Calciners, or Liquor Oxidation Towers.

EPA 1998a; EPA 1999c

Wood Pulp & Paper

Dry Electrostatic 

Precipitator (ESP) - 

Wire Plate Type

99.5 This control measure is the same as the dry ESP for this source category with a control efficiency of 95%. It is expected 

that by 2020, the control efficiency for this sytem will increase to 99.5% for PM2.5. EPA 1998a; EPA 1999c

Wood Pulp & Paper

Wet Electrostatic 

Precipitator (ESP) - 

Wire Plate Type

95 $313 per ton PM10

An electrostatic precipitator applies electrical forces to separate suspended particles from the flue gas stream. The 

suspended particles are given an electrical charge by passing through a high voltage DC corona region in which gaseous 

ions flow. There are two general types of ESP: wire/plate and wire/pipe types. Further, ESPs come in both wet and dry 

configurations. This control is the use of Wet ESP Wire Plate Type. Unlike dry ESPs, resistivity of the collected material is 

not a major factor in performance. Because of the high humidity in a wet ESP, the resistivity of particles is lowered, 

eliminating the "back corona" condition. The frequent washing of the plates also limits particle buildup on the collectors. 

This control applies to wood pulp and paper product operations including Evaporators, Recovery Furnaces, Lime Kiln, 

Calciners, or Liquor Oxidation Towers.

EPA1998a; EPA 1999a

Wood Pulp & Paper

Wet Electrostatic 

Precipitator (ESP) - 

Wire Plate Type

99.5 This control measure is the same as the dry ESP for this source category with a control efficiency of 95%. It is expected 

that by 2020, the control efficiency for this sytem will increase to 99.5% for PM2.5. EPA1998a; EPA 1999a

Wood Combustion 

Appliances Education Campaign n/a n/a CO2, VOC's,CO CH4, Toxics, BC

Focus the Education Campaign on Best Burning Practices, such as those contained on the EPA Burn 

Wise web site: http://www.epa.gov/burnwise/burnwisekit.html. http://epa.gov/burnwise/

resources.html

Wood Stoves Wood to Wood 

Replacement Program 60 $9,900 (2010$) CO2, VOC's,CO CH4, Toxics

Implement a program and provide incentives to replace old uncertified wood stoves with new EPA-certified wood stoves. 

Control efficiency applies to an individual wood stove. 

Education on proper residentiall wood combustion (rwc) stove use (e.g., burn only dry wood) and maintenance is critical. 

See for more info: http://www.epa.gov/burnwise/burnwisekit.html. 

http://epa.gov/burnwise/

resources.html

Wood Stoves Wood to Gas 

Replacement Program 100 $7,200 (2010$) CO2, VOC's,CO CH4, Toxics, BC

Implement an incentive program to replace old, uncertified wood stoves with new gas stoves. Control efficiency (%) 

applies to an individual wood stove. Cost-effectiveness reflects converting from a wood stove to a gas stove. See for 

more info: http://www.epa.gov/burnwise/how-to-guide.html. http://epa.gov/burnwise/

resources.html
Point & NonPoint PM

Menu of Control Measures

Updated 8/6/2013

Printed 8/6/2013 53 of 67

Source Category Emission Reduction 

Measure Name Control Efficiency (%)* Cost Effectiveness (2006$/ton)**

Other Pollutants 

Controlled Description/Notes/Caveats References

Wood Stoves

Remove Old Wood 

Stoves for Money or 

"Bounty"

70 $5,300 (2012$) CO2, VOC's,CO CH4, 

Toxics, BC

Implement an incentive program (usually voluntary) where cash (e.g., $250) is given in return for turning in a wood stove. 

Control efficiency (%) based on estimate provided by Washington State Department of Ecology of wood stoves turned in 

that were actually being used. http://epa.gov/burnwise/

resources.html

* when less than 99%, control efficiencies were rounded up to the closest whole number. They are for PM2.5, unless specified otherwise

** cost-effectiveness numbers are per ton PM2.5 reduced, unless specified otherwise
Point & NonPoint SO2

Menu of Control Measures

Updated 4/12/2012

Printed 8/6/2013 54 of 67

Source Category Emission Reduction 

Measure Name Control Efficiency (%)* Cost Effectiveness (2006$/ton reduced)

Other Pollutants 

Controlled Description/Notes/Caveats References

By-Product Coke 

Manufacturing

Coke Oven Gas 

Desulfurization 90

Cost effectiveness is 

variable depending on 

stack flow rate.

This measure examines the impacts of improving the PM monitoring technique at units currently using an ESP, scrubber, 

or fabric filter. In this improved technique scenario, the monitoring technique is upgraded to a PM continuous emission 

monitor. This improved monitoring technique also results in an increase to the monitoring frequency

because a PM CEMS can make a measurement every 7.5 minutes. The monitoring frequency increases from once per 

day to eight times per hour.

Pechan 2008

Cement Kilns Absorbent Addition 60-80 $2,000-$7,400

A fabric filter, or baghouse, consists of a number of fabric bags placed in parallel inside of an enclosure. Particulate matter 

is collected on the surface of the bags as the gas stream passes through them. The particulate is periodically removed 

from the bags and collected in hoppers located beneath the bags. A number of methods are employed to facilitate the 

removal of particulate from the bags, including shaking, reverse air flow, and pulse air flow. The only potential drawback to 

a fabric filter would be when used in conjunction with a high moisture flue gas stream or with extremely high temperatures. 

If moisture levels in the flue gas stream are too high then filter caking can occur. Cost-effectiveness varies depending on 

the type of filter (Reverse-Air Cleaned Type, Mech. Shaker Type, Pulse Jet Type) and is based on EPA’s cost-estimating 

spreadsheet for fabric filters. 

LADCO 2006a

Cement Kilns Advanced Flue Gas 

Desulfurization 95-99.5 $2,000-$4,000

This measure is to conduct improved monitoring for PM2.5 emissions at stationary sources. Improved monitoring in this 

case means increasing the monitoring frequency of electrostatic precipitators, scrubbers, and fabric filters from once per 

day to four times per hour, with no change in monitoring technique.

The incremental costs included a one-time cost for development of the improved monitoring and recurring annual burden 

costs for incremental record keeping, reporting, and certification activities.

LADCO 2006a

Cement Kilns Wet Gas Scrubber 90-99.9 $2,200-$7,000 HCl, Metals, NH3

Wet scrubbing techniques are used to control both particulate and SO2 emissions. Wet scrubbing processes used to 

control SO2 are generally termed flue-gas desulfurization (FGD) processes. FGD utilizes gas absorption technology, the 

selective transfer of materials from a gas to a contacting liquid, to remove SO2 in the waste gas. Caustic, crushed 

limestone, or lime are used as scrubbing agents. Wet scrubbers also significantly reduce the HCl, residual dust, metal and 

NH3 emissions. In 2008-2010, the SCAQMD conducted a BARCT assessment to capture advancement in SO2 control 

technology, identified the BARCT levels for seven source categories, determined the associated cost-effectiveness values, 

and amended the Regional Clean Air Incentives Market Program (RECLAIM) to reflect the BARCT levels. For cement 

kilns, the cost-effectiveness of achieving a SO2 Performance Standard of 5ppmv (or 0.04 lbs/ton clinker) is $26,800 (in 

2010$). The control efficiency and cost effectiveness listed in this table are from the LADCO 2006 reference.

LADCO 2006a, 

SCAQMD 2012

Cement Kilns - Long 

Dry Process Spray Dryer Absorber 90 $3,400-$5,700

Spray dryer absorption (SDA) systems spray lime slurry into an absorption tower where SO2 is absorbed by the slurry, 

forming CaSO3/CaSO4. The liquid-to-gas ratio is such that the water evaporates before the droplets reach the bottom of 

the tower. The dry solids are carried out with the gas and collected with a fabric filter or ESP. When used to specifically 

control SO2, the term dry flue-gas desulfurization (dry FGD) may also be used.

NESCAUM 2002

Cement Kilns - Long 

Dry Process Wet Gas Scrubber 90 $3,400-$5,700 HCl, Metals, NH3

Wet scrubbing techniques are used to control both particulate and SO2 emissions. Wet scrubbing processes used to 

control SO2 are generally termed flue-gas desulfurization (FGD) processes. FGD utilizes gas absorption technology, the 

selective transfer of materials from a gas to a contacting liquid, to remove SO2 in the waste gas. Caustic, crushed 

limestone, or lime are used as scrubbing agents. Wet scrubbers also significantly reduce the HCl, residual dust, metal and 

NH3 emissions.

NESCAUM 2002

Cement Kilns - 

Preheater Process Kiln Spray Dryer Absorber 90 $23,000-$57,000

Spray dryer absorption (SDA) systems spray lime slurry into an absorption tower where SO2 is absorbed by the slurry, 

forming CaSO3/CaSO4. The liquid-to-gas ratio is such that the water evaporates before the droplets reach the bottom of 

the tower. The dry solids are carried out with the gas and collected with a fabric filter or ESP. When used to specifically 

control SO2, the term dry flue-gas desulfurization (dry FGD) may also be used.

NESCAUM 2002

Cement Kilns - 

Preheater Process Kiln Wet Gas Scrubber 90 $23,000-$57,000 HCl, Metals, NH3

Wet scrubbing techniques are used to control both particulate and SO2 emissions. Wet scrubbing processes used to 

control SO2 are generally termed flue-gas desulfurization (FGD) processes. FGD utilizes gas absorption technology, the 

selective transfer of materials from a gas to a contacting liquid, to remove SO2 in the waste gas. Caustic, crushed 

limestone, or lime are used as scrubbing agents. Wet scrubbers also significantly reduce the HCl, residual dust, metal and 

NH3 emissions.

NESCAUM 2002

Cement Kilns - 

Preheater/Precalciner 

Kiln

Spray Dryer Absorber 90 $23,000-$34,000

Spray dryer absorption (SDA) systems spray lime slurry into an absorption tower where SO2 is absorbed by the slurry, 

forming CaSO3/CaSO4. The liquid-to-gas ratio is such that the water evaporates before the droplets reach the bottom of 

the tower. The dry solids are carried out with the gas and collected with a fabric filter or ESP. When used to specifically 

control SO2, the term dry flue-gas desulfurization (dry FGD) may also be used.

This control is the use of 

low NOx burner (LNB) 

technology and 

selective non-catalytic 

 

Cement Kilns - 

Preheater/Precalciner 

Kiln

Wet Gas Scrubber 90 $23,000-$34,000 HCl, Metals, NH3

Wet scrubbing techniques are used to control both particulate and SO2 emissions. Wet scrubbing processes used to 

control SO2 are generally termed flue-gas desulfurization (FGD) processes. FGD utilizes gas absorption technology, the 

selective transfer of materials from a gas to a contacting liquid, to remove SO2 in the waste gas. Caustic, crushed 

limestone, or lime are used as scrubbing agents. Wet scrubbers also significantly reduce the HCl, residual dust, metal and 

NH3 emissions.

NESCAUM 2002
Point & NonPoint SO2

Menu of Control Measures

Updated 4/12/2012

Printed 8/6/2013 55 of 67

Cement Kilns - Wet 

Process Wet Gas Scrubber 90 $6,800-$9,100 HCl, Metals, NH3

Wet scrubbing techniques are used to control both particulate and SO2 emissions. Wet scrubbing processes used to 

control SO2 are generally termed flue-gas desulfurization (FGD) processes. FGD utilizes gas absorption technology, the 

selective transfer of materials from a gas to a contacting liquid, to remove SO2 in the waste gas. Caustic, crushed 

limestone, or lime are used as scrubbing agents. Wet scrubbers also significantly reduce the HCl, residual dust, metal and 

NH3 emissions.

NESCAUM 2002

ICI Boilers - Coal Spray Dryer Absorber 90-95

Cost effectiveness 

varies by boiler size. 

- 100 MMBTU/hr:

$1,555 - $7,521.

- 250 MMBTU/hr: 

$1,448 - $3,922.

- 750 MMBTU/hr:

$1 389 2 328

Spray dryer absorption (SDA) systems spray lime slurry into an absorption tower where SO2 is absorbed by the slurry, 

forming CaSO3/CaSO4. The liquid-to-gas ratio is such that the water evaporates before the droplets reach the bottom of 

the tower. The dry solids are carried out with the gas and collected with a fabric filter or ESP. When used to specifically 

control SO2, the term dry flue-gas desulfurization (dry FGD) may also be used. Cost estimates are from the OTC / LADCO 

Workgroup (OTC / LADCO Control Cost Subgroup), for a 66% capacity factor at 8760 hour/year, and are based on a 

methodology similar to EPA’s methodology provided in the EPA document “Alternative Control Techniques Document – 

NOx Emissions from Industrial/Commercial/Institutional (ICI) Boilers”. 

NESCAUM 2009, 

OTC/LADCO 2010

ICI Boilers - Coal Wet Gas Scrubber 90-99

Cost effectiveness 

varies by boiler size. 

- 100 MMBTU/hr:

$2,592 - $7,545.

- 250 MMBTU/hr: 

$1,369 - $3,746.

- 750 MMBTU/hr:

$1 262 2 171

Hg

Wet scrubbing techniques are used to control both particulate and SO2 emissions. Wet scrubbing processes used to 

control SO2 are generally termed flue-gas desulfurization (FGD) processes. FGD utilizes gas absorption technology, the 

selective transfer of materials from a gas to a contacting liquid, to remove SO2 in the waste gas. Caustic, crushed 

limestone, or lime are used as scrubbing agents. Cost estimates are from the OTC / LADCO Workgroup (OTC / LADCO 

Control Cost Subgroup), for a 66% capacity factor at 8760 hour/year, and are based on a methodology similar to EPA’s 

methodology provided in the EPA document “Alternative Control Techniques Document – NOx Emissions from 

Industrial/Commercial/Institutional (ICI) Boilers”. 

NESCAUM 2009, 

OTC/LADCO 2010

ICI Boilers - Coal--High 

Sulfur

In Duct Dry Sorbent 

Injection 40 $700-$1,400

As opposed to spray dryer absorption, in duct sorbent injection technology does not require a dedicated reactor and 

instead uses the existing boiler and duct system as the “reactor,” and several configurations are possible based on the 

temperature window desired. DSI technologies include calcium (lime) and sodium (trona) reagents and are currently being 

tested or demonstrated within the ICI boiler sector.

EPA 2003a; NESCAUM 

2009

ICI Boilers - Coal--Low 

Sulfur

In Duct Dry Sorbent 

Injection 40 $770-$1,700

As opposed to spray dryer absorption, in duct sorbent injection technology does not require a dedicated reactor and 

instead uses the existing boiler and duct system as the “reactor,” and several configurations are possible based on the 

temperature window desired. DSI technologies include calcium (lime) and sodium (trona) reagents and are currently being 

tested or demonstrated within the ICI boiler sector.

EPA 2003a; NESCAUM 

2009

ICI Boilers - Oil Fuel Switching 75 $2,800 PM

This control transfers a home-heating oil fuel control to industrial boilers by substituting "red dye" distillate oil for high-sulfur 

fuel. Distillate has 500 ppm versus 2,500 to 3,000 ppm for high-sulfur diesel.The control applies to ICI external combustion 

boilers.

EPA 2007a

ICI Boilers - Residual Oil

Fuel switch from 3% 

sulfur residual oil to 

0.2% sulfur distillate oil

94 $5,300 PM2.5

Fuel substitution involves replacing the current fuel with a fuel which emits less of a given pollutant when burned. For many 

older boilers, fuel switching is an especially attractive option because the capital investment is usually small when 

compared to that of control devices. This control measure involves switching from 3% sulfur residual oil to 0.2% sulfur 

distillate oil

NESCAUM 2009

ICI Boilers - Residual Oil

Fuel switch from 3% 

sulfur residual oil to 1% 

sulfur residual oil

67 $760 PM2.5

Fuel substitution involves replacing the current fuel with a fuel which emits less of a given pollutant when burned. For many 

older boilers, fuel switching is an especially attractive option because the capital investment is usually small when 

compared to that of control devices. This control measure involves switching from 3% to 1% sulfur content in residual fuel 

oil.

NESCAUM 2009

ICI Boilers - Residual Oil

Fuel switch from 1% 

sulfur residual oil to 

0.5% sulfur residual oil

50

Cost effectiveness 

varies by boiler size; 

$1,858 - $3,717.

PM2.5

Fuel substitution involves replacing the current fuel with a fuel which emits less of a given pollutant when burned. For many 

older boilers, fuel switching is an especially attractive option because the capital investment is usually small when 

compared to that of control devices. This control measure involves switching from 1% sulfur residual oil to 0.5% sulfur 

residual oil. Cost estimates are from the OTC / LADCO Workgroup (OTC / LADCO Control Cost Subgroup), for a 66% 

capacity factor at 8760 hour/year, and are based on a methodology similar to EPA’s methodology provided in the EPA 

document “Alternative Control Techniques Document – NOx Emissions from Industrial/Commercial/Institutional (ICI) 

Boilers”. The estimated price differential between residual oil at 1.0% S and low sulfur residual oil at 0.5%S used in these 

cost

estimates ranged from 7 5 to 15 0 cents per gallon

OTC/LADCO 2010

ICI Boilers - Distillate Oil

Fuel switch from 0.3% 

sulfur distillate oil to 

0.05% sulfur distillate oil

84

Cost effectiveness 

varies by boiler size; 

$1,174 - $1,956.

PM2.5

Fuel substitution involves replacing the current fuel with a fuel which emits less of a given pollutant when burned. For many 

older boilers, fuel switching is an especially attractive option because the capital investment is usually small when 

compared to that of control devices. This control measure involves switching from 0.3% to 0.05 sulfur content in distillate 

fuel oil. Cost estimates are from the OTC / LADCO Workgroup (OTC / LADCO Control Cost Subgroup), for a 66% capacity 

factor at 8760 hour/year, and are based on a methodology similar to EPA’s methodology provided in the EPA document 

“Alternative Control Techniques Document – NOx Emissions from Industrial/Commercial/Institutional (ICI) Boilers”. The 

estimated price differential between distillate oil at 0.30% S and low sulfur distillate oil at 0.05%S used in these

cost estimates ranged from 2.1 to 3.5 cents per gallon.

OTC/LADCO 2010

ICI Boilers - Residual Oil Spray Dryer Absorber 90-95 $1,900-$5,400

Spray dryer absorption (SDA) systems spray lime slurry into an absorption tower where SO2 is absorbed by the slurry, 

forming CaSO3/CaSO4. The liquid-to-gas ratio is such that the water evaporates before the droplets reach the bottom of 

the tower. The dry solids are carried out with the gas and collected with a fabric filter or ESP. When used to specifically 

control SO2, the term dry flue-gas desulfurization (dry FGD) may also be used.

NESCAUM 2009
Point & NonPoint SO2

Menu of Control Measures

Updated 4/12/2012

Printed 8/6/2013 56 of 67

ICI Boilers - Residual Oil Wet Gas Scrubber 90-99 $2,000-$5,400 Hg

Wet scrubbing techniques are used to control both particulate and SO2 emissions. Wet scrubbing processes used to 

control SO2 are generally termed flue-gas desulfurization (FGD) processes. FGD utilizes gas absorption technology, the 

selective transfer of materials from a gas to a contacting liquid, to remove SO2 in the waste gas. Caustic, crushed 

limestone, or lime are used as scrubbing agents. 

NESCAUM 2009

Inorganic Chemical 

Manufacture Operations

Flue Gas 

Desulfurization 90

Cost effectiveness is 

variable depending on 

stack flow rate and 

concentration.

Flue Gas Desulfurization scrubbers can be either wet or dry systems. In wet systems, a liquid sorbent is sprayed into the 

flue gas in an absorber vessel. Limestone and lime-based reagents are most frequently used in scrubbers in the United 

States. Dry and semi-dry Flue Gas Desulfurization systems include spray dryers, and dry injection into a duct or a 

combustion zone.

Pechan 2008

In-process Fuel Use - 

Bituminous Coal

Flue Gas 

Desulfurization 90

Cost effectiveness is 

variable depending on 

stack flow rate and 

concentration.

Flue Gas Desulfurization scrubbers can be either wet or dry systems. In wet systems, a liquid sorbent is sprayed into the 

flue gas in an absorber vessel. Limestone and lime-based reagents are most frequently used in scrubbers in the United 

States. Dry and semi-dry Flue Gas Desulfurization systems include spray dryers, and dry injection into a duct or a 

combustion zone. This control applies to operations with in-process bituminous coal use. Emissions from these sources 

are classified under SCCs 39000288, 39000289, and 39000299.

EPA 1981; Pechan 

1997

Mineral Products 

Industry

Flue Gas 

Desulfurization 90

Cost effectiveness is 

variable depending on 

stack flow rate and 

concentration.

Flue Gas Desulfurization scrubbers can be either wet or dry systems. In wet systems, a liquid sorbent is sprayed into the 

flue gas in an absorber vessel. Limestone and lime-based reagents are most frequently used in scrubbers in the United 

States. Dry and semi-dry Flue Gas Desulfurization systems include spray dryers, and dry injection into a duct or a 

combustion zone.

EPA 1981; Pechan 

1997

Petroleum Refining--

Catalytic Cracking Catalyst Additives 35-50 $495-$872

DeSOx additives are typically metal oxide catalysts that convert SO2 to SO3 inside the catalyst regenerator. The SO3 is 

adsorbed to a sulfate and then recycled back to the reactor with the FCCU catalyst, where it is reduced in the reactor to 

H2S, which is controlled by the refinery’s sulfur recovery plant. 

MARAMA 2007

Petroleum Refining--

Catalytic Cracking Wet Gas Scrubber 95-99.9 $500-$3,000 PM2.5

Wet scrubbing techniques are used to control both particulate and SO2 emissions. Wet scrubbing processes used to 

control SO2 are generally termed flue-gas desulfurization (FGD) processes. FGD utilizes gas absorption technology, the 

selective transfer of materials from a gas to a contacting liquid, to remove SO2 in the waste gas. Caustic, crushed 

limestone, or lime are used as scrubbing agents. In 2008-2010, the SCAQMD conducted a BARCT assessment to 

capture advancement in SO2 control technology, identified the BARCT levels for seven source categories, determined the 

associated cost-effectiveness values, and amended the Regional Clean Air Incentives Market Program (RECLAIM) to 

reflect the BARCT levels. For Petroleum Refining--Catalytic Cracking, the cost-effectiveness of achieving a SO2 

Performance Standard of 5ppmv is $21,200 (in 2010$). The control efficiency and cost effectiveness listed in this table are 

from the Mid-Atlantic Regional Air Management Association "Assessment of Control Technology Options For Petroleum 

Refineries in the Mid-Atlantic Region, Final Report".

MARAMA 2007, 

SCAQMD 2012

Coke Calciner Wet Gas Scrubber Achieve a performance 

level of 10ppmv SO2. $22,563

In 2008-2010, the SCAQMD conducted a BARCT assessment to capture advancement in SO2 control technology, 

identified the BARCT levels for seven source categories, determined the associated cost-effectiveness values, and 

amended the Regional Clean Air Incentives Market Program (RECLAIM) to reflect the BARCT levels. For coke calciners, 

the cost-effectiveness of achieving a SO2 Performance Standard of 10ppmv is $23,036 (in 2010$). 

SCAQMD 2012

Glass Melting Furnaces Wet Gas Scrubber 95 $5,091

In 2008-2010, the SCAQMD conducted a BARCT assessment to capture advancement in SO2 control technology, 

identified the BARCT levels for seven source categories, determined the associated cost-effectiveness values, and 

amended the Regional Clean Air Incentives Market Program (RECLAIM) to reflect the BARCT levels. For Glass Melting 

Furnaces, the cost-effectiveness of achieving a SO2 Performance Standard of 5ppmv (95% efficiency) is $5,198 (in 

2010$) 

SCAQMD 2012

Petroleum Refining--

Flares BAAQMD Rule 12 65-86 $800-$1,600 PM2.5, CO, NOx

This control measure is the application of the requirement in BAAQMD Rule 12. Requirement include the development and 

implementation of flare minimization plan, continuous monitoring of knock-out drum water seal for leaks, determine and 

report the causes of each reportable flaring incident.

MARAMA 2007

Petroleum Refining--

Flares

Flare Gas Recovery 

Unit

$0 (actually, cost 

savings). PM2.5, CO, NOx

Emissions from flaring events are released due to oxidation of vent gases and incomplete combustion of fuel. Flare gas 

recovery units reduce emissions from flares by recycling the gases vented during emergency releases instead of 

combusting them in flare. The vent gases are collected in the flare header, compressed, cooled, and returned for re-use in 

the refinery as fuel gas or process feedstock.

MARAMA 2007

Petroleum Refining--

Flares SCAQMD Rule 1118 53 $4,500-$8,600 PM2.5, CO, NOx

This control measure is the application of the requirement in SCAQMD Rule 1118. Requirement include the prohibition of 

flaring except for emergencies, shutdowns and startups, turnarounds, and specific essential operational needs; 

establishes operational practices to minimize flaring events, sets annual SO2 performance targets, requires operation in a 

smokeless manner; increased inspections and monitoring.

MARAMA 2007

Petroleum Refining--

Process Heaters

Flue Gas 

Desulfurization 90-99.9 $7,600-$45,000

Flue Gas Desulfurization scrubbers can be either wet or dry systems. In wet systems, a liquid sorbent is sprayed into the 

flue gas in an absorber vessel. Limestone and lime-based reagents are most frequently used in scrubbers in the United 

States. Dry and semi-dry Flue Gas Desulfurization systems include spray dryers, and dry injection into a duct or a 

combustion zone.

MARAMA 2007
Point & NonPoint SO2

Menu of Control Measures

Updated 4/12/2012

Printed 8/6/2013 57 of 67

Petroleum Refining--

Sulfur Recovery Units

Increase Claus Unit 

Capacity & Tail Gas 

Scrubber Efficiency

Variable depending on 

current efficiency. Up to 

97-99.9%.

$170-$450

Typical sulfur recovery configurations at petroleum refineries entail the use of the Claus sulfur recovery process followed 

by a tail gas clean-up unit (TGCU) to maximize removal of H2S. Several process modifications are available to increase 

sulfur recovery from this process (they result in increased emissions of CO2 to the atmosphere). In 2008-2010, the 

SCAQMD conducted a BARCT assessment to capture advancement in SO2 control technology, identified the BARCT 

levels for seven source categories, determined the associated cost-effectiveness values, and amended the Regional 

Clean Air Incentives Market Program (RECLAIM) to reflect the BARCT levels. For Sulfur Recovery Units, the costeffectiveness of achieving a SO2 Performance Standard of 5ppmv is $44,500 (in 2010$). The control efficiency and cost 

effectiveness listed in this table are from the Mid-Atlantic Regional Air Management Association "Assessment of Control 

Technology Options For Petroleum Refineries in the Mid-Atlantic Region, Final Report" (the control efficiency and costeffectiveness ranges are for various technologies described in the reference.)

MARAMA 2007, 

SCAQMD 2012

Primary Lead Smelters - 

Sintering Dual Absorption 99

Cost effectiveness is 

variable depending on 

stack flow rate.

The dual-absorption process for making sulfuric acid from waste gas containing SO2 is essentially the same as the singlecontact process with the addition of an interpass absorption tower. The waste gas is cleaned and dried as in the singlecontact process before entering the process. Upon leaving the second or third catalyst bed, the gas is cooled and 

introduced to a packed-bed, counter-current absorption tower where it contacts 98-99% sulfuric acid. After the absorbing 

tower, the gas is reheated and passed to the third or fourth catalyst bed, where approximately 97% of the remaining SO2 

is converted to SO3 and passed to the final absorption tower for conversion to sulfuric acid as in the single-contact 

process.

Pechan 2008

Primary Metals Industry Flue Gas 

Desulfurization 90

Cost effectiveness is 

variable depending on 

stack flow rate.

Flue Gas Desulfurization scrubbers can be either wet or dry systems. In wet systems, a liquid sorbent is sprayed into the 

flue gas in an absorber vessel. Limestone and lime-based reagents are most frequently used in scrubbers in the United 

States. Dry and semi-dry Flue Gas Desulfurization systems include spray dryers, and dry injection into a duct or a 

combustion zone.

EPA 2002a

Primary Zinc Smelters - 

Sintering Dual Absorption 99

Cost effectiveness is 

variable depending on 

stack flow rate and 

concentration.

The dual-absorption process for making sulfuric acid from waste gas containing SO2 is essentially the same as the singlecontact process with the addition of an interpass absorption tower. The waste gas is cleaned and dried as in the singlecontact process before entering the process. Upon leaving the second or third catalyst bed, the gas is cooled and 

introduced to a packed-bed, counter-current absorption tower where it contacts 98-99% sulfuric acid. After the absorbing 

tower, the gas is reheated and passed to the third or fourth catalyst bed, where approximately 97% of the remaining SO2 

is converted to SO3 and passed to the final absorption tower for conversion to sulfuric acid as in the single-contact 

process.

Pechan 2008

Process Heaters - Oil 

and Gas Production 

Industry

Flue Gas 

Desulfurization 90

Cost effectiveness is 

variable depending on 

stack flow rate.

Flue Gas Desulfurization scrubbers can be either wet or dry systems. In wet systems, a liquid sorbent is sprayed into the 

flue gas in an absorber vessel. Limestone and lime-based reagents are most frequently used in scrubbers in the United 

States. Dry and semi-dry Flue Gas Desulfurization systems include spray dryers, and dry injection into a duct or a 

combustion zone. This control applies to processes heaters involved in oil and gas production. Emissions from these 

sources are classified under SCCs beginning with 310004.

EPA 1981; Pechan 

1997

Pulp and Paper - Acid 

Sulfite Pulping Alkaline Scrubber 97 Acid sulfite pulping is used at a declining number of pulping operations, but it can emit large amounts of SO2 per ton of pulp. SO2 can be scrubbed out using an alkaline solution (with recovery of up to 97 percent). STAPPA/ALAPCO 2006

Pulp and Paper - Acid 

Sulfite Pulping Raise pH of Digester Acid sulfite pulping is used at a declining number of pulping operations, but it can emit large amounts of SO2 per ton of pulp. Raising the pH of the digester before releasing excess gas reduces the amount of SO2 released. STAPPA/ALAPCO 2006

Pulp and Paper - 

Recovery Furnaces

Reduce Sulfur Content 

of Black Liquor &/or 

Regulate Temperatures 

in the Furnace

Pulp facilities burn concentrated black liquor in recovery furnaces to produce energy and recover sodium and sulfur. 

Compared to the more traditional fuels burned in power boilers (i.e., natural gas, coal, wood and oil), the black liquor solids 

burned in the recovery furnace can have widely varying sulfur content. This results in variable SO2 emissions, making 

control difficult. Despite this difficulty, some facilities have successfully lowered SO2 emissions by reducing the sulfur 

content of the black liquor before combustion and by regulating temperatures in the furnace to minimize SO2 formation.

STAPPA/ALAPCO 2006

Pulp and Paper Industry 

- Sulfate Pulping

Flue Gas 

Desulfurization 90

Cost effectiveness is 

variable depending on 

stack flow rate.

Flue Gas Desulfurization scrubbers can be either wet or dry systems. In wet systems, a liquid sorbent is sprayed into the 

flue gas in an absorber vessel. Limestone and lime-based reagents are most frequently used in scrubbers in the United 

States. Dry and semi-dry Flue Gas Desulfurization systems include spray dryers, and dry injection into a duct or a 

combustion zone. This control applies to sulfate pulping processes involved in the pulp and paper industry. Emissions from 

these sources are classified under SCCs beginning with 307001.

EPA 2002a

Residential Fuel 

Combustion - Oil

Fuel switch from high 

sulfur to low sulfur home 

heating oil

75 $2,600 PM2.5, PM10, NOx This measure will be a switch from high-sulfur (2,500 ppm sulfur content) to low-sulfur (500 ppm) home heating oil for 

residential users. NESCAUM 2005

Steam Generating Unit - 

Coal/Oil

Flue Gas 

Desulfurization 90

Cost effectiveness is 

variable depending on 

stack flow rate.

Flue Gas Desulfurization scrubbers can be either wet or dry systems. In wet systems, a liquid sorbent is sprayed into the 

flue gas in an absorber vessel. Limestone and lime-based reagents are most frequently used in scrubbers in the United 

States. Dry and semi-dry Flue Gas Desulfurization systems include spray dryers, and dry injection into a duct or a 

combustion zone. This control applies to coal and oil-fired steam generating units.

EPA 2002a
Point & NonPoint SO2

Menu of Control Measures

Updated 4/12/2012

Printed 8/6/2013 58 of 67

Sulfur Recovery Plants - 

Elemental Sulfur Process Modification 97-98

Cost effectiveness is 

variable depending on 

stack flow rate.

The Claus process is the most widely used method of producing sulfur from refinery H2S. The modified Claus process is 

based on producing elemental sulfur by first converting one-third of the H2S feed by precise combustion with air. The 

combustion products are then allowed to react thermally with the remaining two-thirds of the H2S feed in the presence of a 

suitable catalyst to form sulfur vapor. This control usually employs a high-energy liquid amine spray such as 

monoethanolamine (MEA), diethanolamine (DEA), methyldiethanolamine (MDEA), or diisopropylamine (DIPA) to increase 

the efficiency of the process to emit less SO2.

EPA 2002a; EPA 1983

Sulfuric Acid Plants Flue Gas 

Desulfurization 90

Cost effectiveness is 

variable depending on 

stack flow rate.

Flue Gas Desulfurization scrubbers can be either wet or dry systems. In wet systems, a liquid sorbent is sprayed into the 

flue gas in an absorber vessel. Limestone and lime-based reagents are most frequently used in scrubbers in the United 

States. Dry and semi-dry Flue Gas Desulfurization systems include spray dryers, and dry injection into a duct or a 

combustion zone. In 2008-2010, the SCAQMD conducted a BARCT assessment to capture advancement in SO2 control 

technology, identified the BARCT levels for seven source categories, determined the associated cost-effectiveness values, 

and amended the Regional Clean Air Incentives Market Program (RECLAIM) to reflect the BARCT levels. For Sulfuric Acid 

Manufacturing , the cost-effectiveness of achieving a SO2 Performance Standard of 10ppmv (or 0.14 lbs/ton acid 

produced) is $3,400 (in 2010$). The control efficiency listed in this table is from the Pechan 2008 reference.

Pechan 2008, SCAQMD 

2012

Sulfuric Acid Plants

Increase Absorption 

Efficiency from Existing 

to NSPS Level (99.7%)

75-95

Cost effectiveness is 

variable depending on 

stack flow rate.

This control is to increase adsorption efficiency from existing to NSPS level (99.7%), using technologies such as Dual 

Absorption. The dual-absorption process for making sulfuric acid from waste gas containing SO2 is essentially the same 

as the single-contact process with the addition of an interpass absorption tower. This control applies to sulfuric acid plants 

with contact absorption processes at 93% to 99% sulfur conversion efficiency. The control efficiency varies depending on 

the existing sulfur conversion.

Pechan 2008

Utility Boiler - Coal Chemical Coal Cleaning 50-85 Uses chemical processes to remove pyrites (inorganic sulfur compounds) and organic sulfur in coal. LADCO 2005a

Utility Boiler - Coal Coal Washing 35 $420 Hg, PM

Coal washing (or coal cleaning) is a pre-combustion process that improves the quality of coal by removing impurities and 

increasing its heat content, thus reducing SO2 emissions. Coal washing can also be effective in removing mercury (Hg) 

from the coal and the utility plants emissions.

ERG 2000; EPA 1997a; 

SIU 1997

Utility Boiler - Coal

Fuel switching away 

from coal: bituminous 

coal to lignite

80 $160-$240 PM, NOx

Fuel substitution involves replacing the current fuel with a fuel which emits less of a given pollutant when burned. For many 

older boilers, fuel switching is an especially attractive option because the capital investment is usually small when 

compared to that of control devices. Cost effectiveness varies depending on the ranks of the old and new fuels and is 

estimated based on the emission factors.

LADCO 2005a; DOE 

1994; Pechan 2008; 

EPA 1998a

Utility Boiler - Coal

Fuel switching away 

from coal: bituminous 

coal to natural gas

99.9 PM, NOx

Fuel substitution involves replacing the current fuel with a fuel which emits less of a given pollutant when burned. For many 

older boilers, fuel switching is an especially attractive option because the capital investment is usually small when 

compared to that of control devices. Cost effectiveness varies depending on the ranks of the old and new fuels and is 

estimated based on the emission factors.

LADCO 2005a; DOE 

1994; Pechan 2008; 

EPA 1998a

Utility Boiler - Coal

Fuel switching away 

from coal: bituminous 

coal to No.2 oil

91 PM, NOx

Fuel substitution involves replacing the current fuel with a fuel which emits less of a given pollutant when burned. For many 

older boilers, fuel switching is an especially attractive option because the capital investment is usually small when 

compared to that of control devices. Cost effectiveness varies depending on the ranks of the old and new fuels and is 

estimated based on the emission factors.

LADCO 2005a; DOE 

1994; Pechan 2008; 

EPA 1998a

Utility Boiler - Coal

Fuel switching away 

from coal: bituminous 

coal to No.4 oil

47 PM, NOx

Fuel substitution involves replacing the current fuel with a fuel which emits less of a given pollutant when burned. For many 

older boilers, fuel switching is an especially attractive option because the capital investment is usually small when 

compared to that of control devices. Cost effectiveness varies depending on the ranks of the old and new fuels and is 

estimated based on the emission factors.

LADCO 2005a; DOE 

1994; Pechan 2008; 

EPA 1998a

Utility Boiler - Coal

Fuel switching away 

from coal: bituminous 

coal to subbituminous

73 $160-$240 PM, NOx

Fuel substitution involves replacing the current fuel with a fuel which emits less of a given pollutant when burned. For many 

older boilers, fuel switching is an especially attractive option because the capital investment is usually small when 

compared to that of control devices. Cost effectiveness varies depending on the ranks of the old and new fuels and is 

estimated based on the emission factors.

LADCO 2005a; DOE 

1994; Pechan 2008; 

EPA 1998a

Utility Boiler - Coal

Fuel switching away 

from coal: 

subbituminous coal to 

lignite

27 $160-$240 PM, NOx

Fuel substitution involves replacing the current fuel with a fuel which emits less of a given pollutant when burned. For many 

older boilers, fuel switching is an especially attractive option because the capital investment is usually small when 

compared to that of control devices. Cost effectiveness varies depending on the ranks of the old and new fuels and is 

estimated based on the emission factors.

LADCO 2005a; DOE 

1994; Pechan 2008; 

EPA 1998a

Utility Boiler - Coal

Fuel switching away 

from coal: 

subbituminous coal to 

natural gas

99.9 PM, NOx

Fuel substitution involves replacing the current fuel with a fuel which emits less of a given pollutant when burned. For many 

older boilers, fuel switching is an especially attractive option because the capital investment is usually small when 

compared to that of control devices. Cost effectiveness varies depending on the ranks of the old and new fuels and is 

estimated based on the emission factors.

LADCO 2005a; DOE 

1994; Pechan 2008; 

EPA 1998a

Utility Boiler - Coal

Fuel switching away 

from coal: 

subbituminous coal to 

No.2 oil

70 PM, NOx

Fuel substitution involves replacing the current fuel with a fuel which emits less of a given pollutant when burned. For many 

older boilers, fuel switching is an especially attractive option because the capital investment is usually small when 

compared to that of control devices. Cost effectiveness varies depending on the ranks of the old and new fuels and is 

estimated based on the emission factors.

LADCO 2005a; DOE 

1994; Pechan 2008; 

EPA 1998a

Utility Boiler - Coal

Fuel switching away 

from No.2 oil: No.2 oil to 

natural gas

99.7 PM, NOx

Fuel substitution involves replacing the current fuel with a fuel which emits less of a given pollutant when burned. For many 

older boilers, fuel switching is an especially attractive option because the capital investment is usually small when 

compared to that of control devices. Cost effectiveness varies depending on the ranks of the old and new fuels and is 

estimated based on the emission factors.

LADCO 2005a; DOE 

1994; Pechan 2008; 

EPA 1998a
Point & NonPoint SO2

Menu of Control Measures

Updated 4/12/2012

Printed 8/6/2013 59 of 67

Utility Boiler - Coal

Fuel switching away 

from No.4 oil: No.4 oil to 

natural gas

99.9 PM, NOx

Fuel substitution involves replacing the current fuel with a fuel which emits less of a given pollutant when burned. For many 

older boilers, fuel switching is an especially attractive option because the capital investment is usually small when 

compared to that of control devices. Cost effectiveness varies depending on the ranks of the old and new fuels and is 

estimated based on the emission factors.

LADCO 2005a; DOE 

1994; Pechan 2008; 

EPA 1998a

Utility Boiler - Coal

Fuel switching away 

from No.4 oil: No.4 oil to 

No.2 oil

84 PM, NOx

Fuel substitution involves replacing the current fuel with a fuel which emits less of a given pollutant when burned. For many 

older boilers, fuel switching is an especially attractive option because the capital investment is usually small when 

compared to that of control devices. Cost effectiveness varies depending on the ranks of the old and new fuels and is 

estimated based on the emission factors.

LADCO 2005a; DOE 

1994; Pechan 2008; 

EPA 1998a

Utility Boiler - Coal

Fuel switching away 

from No.6 oil: No.6 oil to 

natural gas

99.9 PM, NOx

Fuel substitution involves replacing the current fuel with a fuel which emits less of a given pollutant when burned. For many 

older boilers, fuel switching is an especially attractive option because the capital investment is usually small when 

compared to that of control devices. Cost effectiveness varies depending on the ranks of the old and new fuels and is 

estimated based on the emission factors.

LADCO 2005a; DOE 

1994; Pechan 2008; 

EPA 1998a

Utility Boiler - Coal

Fuel switching away 

from No.6 oil: No.6 oil to 

No.2 oil

92 PM, NOx

Fuel substitution involves replacing the current fuel with a fuel which emits less of a given pollutant when burned. For many 

older boilers, fuel switching is an especially attractive option because the capital investment is usually small when 

compared to that of control devices. Cost effectiveness varies depending on the ranks of the old and new fuels and is 

estimated based on the emission factors.

LADCO 2005a; DOE 

1994; Pechan 2008; 

EPA 1998a

Utility Boiler - Coal

Fuel switching away 

from No.6 oil: No.6 oil to 

No.4 oil

46 PM, NOx

Fuel substitution involves replacing the current fuel with a fuel which emits less of a given pollutant when burned. For many 

older boilers, fuel switching is an especially attractive option because the capital investment is usually small when 

compared to that of control devices. Cost effectiveness varies depending on the ranks of the old and new fuels and is 

estimated based on the emission factors.

LADCO 2005a; DOE 

1994; Pechan 2008; 

EPA 1998a

Utility Boiler - Coal Lime Spray Dryer 

System (LSD) 70-96 $160-$300

The LSD system utilizes a fine spray of slaked lime (Ca(OH)2) to absord SO2 in the scrubber resulting in the formation of 

calcium sulfate or calcium sulfite. The resulting calcium sulfate/sulfite is then removed, along with fly ash, in a fabric filter or 

ESP. LSD is one of the preferred technology worldwide. The cost per ton listed is for units larger than 200 megawatts. The 

cost per ton for smaller units is $517-$4,133 dollars per ton. Control efficiency ranges between 70%-96% with a median 

reduction of 90%; EPA used 90% for CAIR analysis.

LADCO 2005a

Utility Boiler - Coal

Limestone Forced 

Oxidation System 

(LSFO)

52-98 $200-$500

LSFO is a process based on wet limestone scrubbing which reduces scaling and eliminates need for landfilling of the 

waste product. It is one of the preferred technology worldwide. The cost per ton listed is for units larger than 400 

megawatts. The cost per ton for smaller units is $517-$5,166 dollars per ton. Control efficiency ranges between 52%-98% 

with a median reduction of 90%; EPA used 95% for CAIR analysis.

LADCO 2005a

Utility Boiler - Coal Magnesium Enhanced 

Lime System (MEL) 52-98 $200-$500

In the MEL process, slaked lime, containing calcium hydroxide [Ca(OH)2] and a portion of magnesium hydroxide 

[Mg(OH)2], is used to react with SO2. It is one of the preferred technology worldwide. The cost per ton listed is for units 

larger than 400 megawatts. The cost per ton for smaller units is $517-$5,166 dollars per ton. Control efficiency ranges 

between 52%-98% with a median reduction of 90%; EPA used 96% for CAIR analysis.

LADCO 2005a

Utility Boiler - Coal Physical Coal Cleaning 10-40 Uses physical processes to remove pyrites (inorganic sulfur compounds) in coal. LADCO 2005a

Utility Boiler - Coal Repowering to IGCC 99

Cost effectiveness is 

variable depending on 

nameplate capacity: 

- capital cost = $1,027 

per kW

- fixed O&M cost = 

$33.37 per kW per year

- variable O&M cost = 

$3 17 mills per kW

Hg, NOx

Repowering improves power plant efficiencies and implies significant waste reduction. Typical repowering entails steps in 

which the coal handling system and the boiler are replaced with new combustion turbines and a heat recovery boiler. The 

only significant part of the plant that is maintained is the original turbine generator. The IGCC is a repowering option that 

requires extensive gasification equipment to generate synthetic gas from coal in order to feed the gas turbines. IGCC 

plants offer the capability of removing the Hg from the compressed syngas prior to combustion where the gas volume 

treated is much less than the low pressure, post-combustion flow volume. 

EPA 1998b

* when less than 99%, control efficiencies were rounded up to the closest whole number. Cost rounded to 2 significant figures.
Mobile Controls NOx

Menu of Control Measures

Updated 4/12/2012

Printed 8/6/2013 60 of 67

Source Category Emission Reduction 

Measure Name Control Efficiency (%) Cost Effectiveness (2006$/ton reduced)

Other pollutants 

controlled Description/Notes/Caveats References

Onroad 

Heavy Duty Diesel 

Vehicles (Class 6 and 

above)

Diesel Retrofit

NOx: 16-34% for Class 

6&7;15-43% for Class 8

VOC: 35-59% for Class 

6&7;32-68% for Class 8

- Class 8: $4,284-

$12,157 per ton NOx 

- Class 6&7: $23,192-

$62,873 per ton NOx

PM10, PM2.5, CO, VOC

This measure examines the impacts of improving the PM monitoring technique at units currently using an ESP, scrubber, 

or fabric filter. In this improved technique scenario, the monitoring technique is upgraded to a PM continuous emission 

monitor. This improved monitoring technique also results in an increase to the monitoring frequency

because a PM CEMS can make a measurement every 7.5 minutes. The monitoring frequency increases from once per 

day to eight times per hour.

EPA 2011a

Onroad 

Heavy Duty Diesel 

Vehicles (Class 8)

Eliminate Long Duration 

Idling

Exhaust NOx: 10-33%

Exhaust VOC: 21-60%

- Class 8: from a cost of 

$46,506 to savings of 

$16,001 per ton NOx

- Class 6&7: from a cost 

of $68,323 to savings of 

$15,501 per ton NOx

PM10, PM2.5, CO, 

SO2, VOC, benzene, 

naphthalene, 1,3-

butadiene, 

formaldehyde, 

acetaldehyde, acrolein

A fabric filter, or baghouse, consists of a number of fabric bags placed in parallel inside of an enclosure. Particulate matter 

is collected on the surface of the bags as the gas stream passes through them. The particulate is periodically removed 

from the bags and collected in hoppers located beneath the bags. A number of methods are employed to facilitate the 

removal of particulate from the bags, including shaking, reverse air flow, and pulse air flow. The only potential drawback to 

a fabric filter would be when used in conjunction with a high moisture flue gas stream or with extremely high temperatures. 

If moisture levels in the flue gas stream are too high then filter caking can occur. Cost-effectiveness varies depending on 

the type of filter (Reverse-Air Cleaned Type, Mech. Shaker Type, Pulse Jet Type) and is based on EPA’s cost-estimating 

spreadsheet for fabric filters. 

EPA 2011a

Onroad 

Light Duty Vehicles

Continuous Inspection 

and Maintenance

NOx: 1-3% (if biennial 

I/M in place).

VOC: 1-5% (if biennial 

I/M in place).

$0 

PM10, PM2.5, CO, 

Benzene, Ethanol, 

Naphtalene, Methanol, 

Formaldehyde

This measure is to conduct improved monitoring for PM2.5 emissions at stationary sources. Improved monitoring in this 

case means increasing the monitoring frequency of electrostatic precipitators, scrubbers, and fabric filters from once per 

day to four times per hour, with no change in monitoring technique.

The incremental costs included a one-time cost for development of the improved monitoring and recurring annual burden 

costs for incremental record keeping, reporting, and certification activities.

EPA 2011a, I/M 

Workgroup 2008, EPA 

1992a

Onroad 

Light Duty Gasoline 

Vehicles and Trucks

Travel Efficiency 

Strategies NOx: 2-5% VOC, CO, PM

These types of measures can achieve 2-5% reduction by 2020 if the "low cost" bundle of strategies from the "Moving 

Cooler" report is implemented either aggressively or to the maximum extent. The "Low Cost" bundle represents the best 

combination of strategies based on cost, likelihood of success, and accuracy of the research results. This bundle includes 

strategies like smart growth/transit, commuter strategies, system operations (e.g., eco-driving, ramp metering), pricing 

(e.g., parking taxes, congestion pricing, intercity tolls), speed limit restrictions, and multimodal freight strategies. 

Additionally EPA has released the Transportation Efficiency Assessment Method (TEAM) for assessing emissions 

reductions from travel efficiency strategies. For more information see references.

Cambridge 2009, EPA 

2011d

Onroad and Nonroad 

Vehicles

Ozone Action Days - 

Education and 

promotion campaigns 

Potential to reduce both 

NOx and VOC. Low VOC, PM10, PM2.5, CO

These controls encompass several sources of public awareness programs, whether employer-based, school-based, or 

public education based. For instance, in Arkansas, the Ozone Action Days program emphasis is on providing notification 

about the predicted high ozone episodes with suggestions for voluntary actions to protect public health, especially those 

populations identified as most at risk and ways in which individuals and groups can work to reduce the production of 

nitrogen oxides and volatile organic compounds released into our air. State and local agencies should consult the VMEP 

policy to determine how to include emissions reductions from these types of programs in a SIP.

ADEQ 2011, EPA 

1997g

Nonroad 

Heavy Duty Diesel 

Equipment 

Diesel Retrofits and 

Engine Rebuilds

NOx: 0-37% by 

equipment type

VOC: 0-49% by 

equipment type

$4500 per ton NOx for 

most, $3,245-$5,164 

per ton NOx for some 

construction equipment

PM10, PM2.5, CO, 

Benzene, Methanol, 

Formaldehyde

This measure achieves substantial NOx emission reductions from the use of selective catalytic reduction (SCR) 

technology and engine rebuilds for various types of nonroad equipment such as construction equipment, airport support 

equipment, and commercial generators. Can be combined with diesel particulate filters.

Nonroad 

Aircraft Ground Support 

Equipment

Alternative Fuels - 

CNG/LPG 

NOx: 25% for gas

NOx: 65% for diesel

NMHC: 50-70% for gas

NMHC: 30% for diesel

Gas: $0 (savings)

Diesel: $1,110-$3,325 

per ton VOC/CO/NOx 

combined 

CO

Conversion or replacement of conventionally-fueled GSE machines with LPG or CNG can provide significant emissions 

benefits. For gasoline-powered equipment, conventional engines are able to use alternative fuels by replacing the existing 

carburetor or fuel injection system with a new system capable of handling CNG/LPG. Existing fuel tanks are replaced with 

high pressure tanks for CNG or low pressure tanks for liquefied natural gas (LNG). Modifications are also made to the 

engine controls. Since diesel engines cannot be converted entirely to alternative fuels (as they do not have spark plugs) 

they are generally converted to dual fuel vehicles, which run 20 percent of the time on diesel and 80 percent of the time on 

alternative fuels.

Midwest RPO 2005, 

NESCAUM 2003b

Nonroad 

Aircraft Ground Support 

Equipment

Alternative Fuels - 

Electric NOx: 100%

Varies depending on 

the GSE

Gas: savings to $1,900 

per ton NOx

Diesel: savings to 

$5,800 per ton NOx

CO

In electric GSE, conventional engines are substituted with electric motors and fuel tanks are replaced with lead acid 

batteries. Electric aircraft tugs, potable water carts, baggage conveyor belts, and other machines are commercially 

available. The benefits of electric GSE include the elimination of onairport GSE emissions, noise, and the odor associated 

with gasoline or diesel machines. The costs associated with the use of electric equipment include installation of recharging 

units, incremental costs associated with the purchase of purpose-built electric GSE or conversion of conventional 

equipment, battery replacement, and mechanics and operator training.

Midwest RPO 2005, 

NESCAUM 2003b
Mobile Controls NOx

Menu of Control Measures

Updated 4/12/2012

Printed 8/6/2013 61 of 67

Nonroad 

Commercial Marine - 

Ocean Going Vessels

Shore Based Electrical 

Power - Cold Ironing NOx: 90%

$6,500-$18,000 ton of 

NOx + diesel PM 

reduced.

PM Cost effectiveness is based on the 2006 ARB Emission Reduction Plan for Ports and Goods Movement and is based on a 

mix of strategies and approaches (it was calculated based on various ARB programs).

This control is the use of 

low NOx burner (LNB) 

technology and 

selective non-catalytic 

reduction (SNCR) to 

reduce NOx emissions. 

LNBs reduce the 

amount of NOx created 

from reaction between 

fuel nitrogen and 

oxygen by lowering the 

temperature of one 

combustion zone and 

reducing the amount of 

oxygen available in 

another. SNCR controls 

are post-combustion 

control technologies 

based on the chemical 

reduction of nitrogen 

oxides (NOx) into 

molecular nitrogen (N2) 

and water vapor (H2O). 

This control is 

applicable to process 

heaters fired with 

distillate, residual oil, 

and other unclassified 

Nonroad 

Locomotives Idling Reduction

Variable depending on 

technology and 

application

PM, VOC, SO2, CO, 

Toxics

Idle reduction technologies such as SmartStart and Diesel Driven Heating Systems can reduce idling up to 90 percent, 

depending on which technology is employed in which application. This can significantly reduce overall emissions as EPA 

estimates that idling accounts for about 60 percent of switch yard locomotive operating time and 12.5 percent of line-haul 

locomotive operating time. A specific control efficiency is not provided since EPA has recently adopted new more stringent 

emissions standards and mandated the application of idle-emission controls on newly manufactured and remanufactured 

locomotives. This control measure will thus be most efficient as a retrofit to older locomotives. The new EPA rule consists 

of a three-part emission control strategy: first, there are new standards for existing locomotives that take effect as soon as 

certified remanufacture systems are available. Second, the rule sets near-term emission standards, referred to as Tier 3 

standards, for newly-built locomotive (phase-in starting in 2009). Third, the final long-term emissions standards, referred to 

as Tier 4, apply to newly-built locomotives (phase-in beginning in 2015). EPA estimates this final rule will result in PM 

reductions of about 90 percent and NOx reductions of about 80 percent from engines meeting these standards, compared 

to engines meeting the current standards. More information is available at: http://www.epa.gov/otaq/locomotives.htm and 

http://www epa gov/otaq/regs/nonroad/locomotv/420f08014 pdf 

EPA 2005, EPA 1998h, 

EPA 2008e

Nonroad

Locomotives

Upgrade Engines in 

Switcher Locomotives - 

Diesel-electric hybrid 

locomotives

NOx: 80%

$6,500-$18,000 ton of 

NOx + diesel PM 

reduced.

PM

Diesel-electric hybrid switch locomotives (e.g. Green Goats) are a proven technology that use the same basic concept as 

a gas-electric hybrid automobile – a battery pack powers the locomotive, while a small diesel engine runs as needed to 

keep the batteries charged. Hybrid switch locomotives have significantly reduced diesel PM and NOx emissions, idling 

time, and fuel use compared to conventional switchers. These can reduce PM and NOx emissions generated by a switcher 

locomotive by up to 80 percent. Cost effectiveness is based on the 2006 ARB Emission Reduction Plan for Ports and 

Goods Movement and is based on a mix of strategies and approaches (it was calculated based on various ARB 

programs).

ARB 2006
Mobile Controls VOC

Menu of Control Measures

Updated 4/12/2012

Printed 8/6/2013 62 of 67

Source Category Emission Reduction 

Measure Name Control Efficiency (%) Cost Effectiveness (2006$/ton reduced)

Other pollutants 

controlled Description/Notes/Caveats References

Federal Fuel Programs

This measure examines the impacts of improving the PM monitoring technique at units currently using an ESP, scrubber, 

or fabric filter. In this improved technique scenario, the monitoring technique is upgraded to a PM continuous emission 

monitor. This improved monitoring technique also results in an increase to the monitoring frequency

because a PM CEMS can make a measurement every 7.5 minutes. The monitoring frequency increases from once 

per day to eight times per hour.

Onroad and Nonroad 

Gasoline Vehicles

Opt into Reformulated 

Gasoline (RFG) 

standards

NOx: 2%

(HC total ~ 0.1%)

$2,625 - $4,600 per ton 

NOx Toxics

A fabric filter, or baghouse, consists of a number of fabric bags placed in parallel inside of an enclosure. Particulate matter 

is collected on the surface of the bags as the gas stream passes through them. The particulate is periodically removed 

from the bags and collected in hoppers located beneath the bags. A number of methods are employed to facilitate the 

removal of particulate from the bags, including shaking, reverse air flow, and pulse air flow. The only potential drawback to 

a fabric filter would be when used in conjunction with a high moisture flue gas stream or with extremely high temperatures. 

If moisture levels in the flue gas stream are too high then filter caking can occur. Cost-effectiveness varies depending on 

the type of filter (Reverse-Air Cleaned Type, Mech. Shaker Type, Pulse Jet Type) and is based on EPA’s cost-estimating 

spreadsheet for fabric filters. 

ARB 2007c

State Fuel Programs *

This measure is to conduct improved monitoring for PM2.5 emissions at stationary sources. Improved monitoring in this 

case means increasing the monitoring frequency of electrostatic precipitators, scrubbers, and fabric filters from once per 

day to four times per hour, with no change in monitoring technique.

The incremental costs included a one-time cost for development of the improved monitoring and recurring annual 

burden costs for incremental record keeping, reporting, and certification activities.

Onroad 

Heavy Duty Vehicles

Alternative Fuel 

Programs

NOx: 0%-60%

VOC: 0%-13% PM, CO, SO2, CO2

These programs encompass a number of different programs, including alternative fuel refuse trucks programs, alternative 

fuel vehicle conversion, alternative fuel or hybrid school/transit bus programs, public sector clean fuel fleets, private sector 

clean fuel fleets, and alternative fuels tax credit programs. The control efficiencies listed are ranges for biodiesel, CNG, 

LPG, and E85. For heavy duty vehicles, LPG may actually increase VOC emissions by up to 78% compared to diesel.

EPA 2002f, NREL 2006, 

NREL 2003, ANL 1999

Onroad 

Gasoline Vehicles Low RVP Gasoline

Exhaust VOC: 

1-4%, varies by source 

type and season.

Evaporative VOC: 

1-13%, varies by source 

type and season.

$5,700 NOx, CO, SO2

Lower Reid Vapor Pressure (RVP) helps to reduce VOCs, which are a precursor to ozone formation. This control measure 

represents the use of gasoline with a RVP limit of 7.0 psi from May through September in counties with an ozone season 

RVP value greater than 7.0 psi. 

NOTE: Application limited by the Energy Policy Act and CAA section 211(c) requirements for a state waiver to 

require lower RVP fuels. 

This control measure was modeled with MOVES. Since efficiency and cost effectiveness of this control measure are based 

on MOVES runs, reductions associated with this control measures should NOT be applied to MOBILE6-based data.

EPA 2011a, EPA 2011b

Onroad and Nonroad 

Gasoline Vehicles

Petition EPA to remove 

the 1 psi allowance for 9-

10% ethanol blends

NOx, CO for onroad.

Refueling VOC for some 

nonroad source types.

The Energy Policy Act amended CAA section 211(h) to allow areas to petition EPA to remove the 1 psi allowance for 9-

10% ethanol blends. 

NOTE: Such a petition requires documentation showing that the 1 psi allowance will increase emissions that 

contribute to air pollution. 

Nonroad

Gasoline Vehicles Low RVP Gasoline

Evaporative VOC: 

1-50%, varies by source 

type and season. 

$5,700 Refueling VOC for some 

source types

Lower Reid Vapor Pressure (RVP) helps to reduce VOCs, which are a precursor to ozone formation. This control measure 

represents the use of gasoline with a RVP limit of 7.0 psi from May through September in counties with an ozone season 

RVP value greater than 7.0 psi. 

NOTE: Application limited by the Energy Policy Act and CAA section 211(c) requirements for a state waiver to 

require lower RVP fuels. 

EPA 2011b

Other Measures
Mobile Controls VOC

Menu of Control Measures

Updated 4/12/2012

Printed 8/6/2013 63 of 67

Onroad 

Light Duty Vehicles

Continuous Inspection 

and Maintenance

NOx: 7-18% (if no I/M 

program), or 1-3% (if 

biennial I/M in place).

VOC: 4-25% (if no I/M 

program), or 1-5% (if 

biennial I/M in place).

$0 

PM10, PM2.5, CO, 

Benzene, Ethanol, 

Naphtalene, Methanol, 

Formaldehyde

Continuous Inspection and Maintenance (I&M) uses onboard diagnostics and continuous cellular data transmission to 

provide more rapid identification of emission control failures. This technology can offer substantial emission reductions and 

major cost-savings for consumers.

This control measure was modeled with MOVES. Since efficiency and cost effectiveness of this control measure are based 

on MOVES runs, reductions associated with this control measures should NOT be applied to MOBILE6-based data.

This control is the use of 

low NOx burner (LNB) 

technology and 

selective non-catalytic 

reduction (SNCR) to 

reduce NOx emissions. 

LNBs reduce the 

amount of NOx created 

from reaction between 

fuel nitrogen and 

oxygen by lowering the 

temperature of one 

combustion zone and 

reducing the amount of 

oxygen available in 

another. SNCR controls 

are post-combustion 

control technologies 

based on the chemical 

reduction of nitrogen 

oxides (NOx) into 

molecular nitrogen (N2) 

and water vapor (H2O). 

This control is 

applicable to process 

heaters fired with 

distillate, residual oil, 

and other unclassified 

Onroad 

Light Duty Gasoline 

Vehicles and Trucks

Travel Efficiency 

Strategies VOC: 2-5% NOx, CO, PM

These types of measures can achieve 2-5% reduction by 2020 if the "low cost" bundle of strategies from the "Moving 

Cooler" report is implemented either aggressively or to the maximum extent. The "Low Cost" bundle represents the best 

combination of strategies based on cost, likelihood of success, and accuracy of the research results. This bundle includes 

strategies like smart growth/transit, commuter strategies, system operations (e.g., eco-driving, ramp metering), pricing 

(e.g., parking taxes, congestion pricing, intercity tolls), speed limit restrictions, and multimodal freight strategies. 

Additionally EPA has released the Transportation Efficiency Assessment Method (TEAM) for assessing emissions 

reductions from travel efficiency strategies. For more information see references.

Cambridge 2009, EPA 

2011d

Onroad and Nonroad 

Vehicles

Ozone Action Days - 

Education and 

promotion campaigns 

Potential to reduce both 

NOx and VOC. Low NOx, PM10, PM2.5, CO

These controls encompass several sources of public awareness programs, whether employer-based, school-based, or 

public education based. For instance, in Arkansas, the Ozone Action Days program emphasis is on providing notification 

about the predicted high ozone episodes with suggestions for voluntary actions to protect public health, especially those 

populations identified as most at risk and ways in which individuals and groups can work to reduce the production of 

nitrogen oxides and volatile organic compounds released into our air. State and local agencies should consult the VMEP 

policy to determine how to include emissions reductions from these types of programs in a SIP.

ADEQ 2011, EPA 

1997g

* In SIPs, State Fuel programs have been identified by Congress as control measures of last resort and are subject to certain hurdles; notably, the requirement for a necessity determination that the measure is needed to meet a NAAQS and no other non-fuel programs exist 

and/or are practicable to implement. If such a necessity demonstration can be made, then there is a second hurdle of the fuel being listed on the boutique fuel list and in a SIP in the PADD in question. The CAA section 211(c) approval hurdles remove the option of many of 

these fuel programs for many areas.
Mobile Controls PM, SO2, NH3

Menu of Control Measures

Updated 4/12/2012

Printed 8/6/2013 64 of 67

Source Category Emission Reduction 

Measure Name Control Efficiency (%) Cost Effectiveness (2006$/ton reduced)

Other pollutants 

controlled Description/Notes/Caveats References

Onroad 

Heavy Duty Diesel 

Vehicles (Class 8)

Eliminate Long Duration 

Idling

Exhaust PM2.5: 2%-5%

Exhaust SO2: 1%-4%

- Class 8: from a cost of 

$46,506 to savings of 

$16,001 per ton NOx

- Class 6&7: from a cost 

of $68,323 to savings of 

$15,501 per ton NOx

NOx, VOC, CO, SO2, 

benzene, naphthalene, 

1,3-butadiene, 

formaldehyde, 

acetaldehyde, acrolein

This measure examines the impacts of improving the PM monitoring technique at units currently using an ESP, scrubber, 

or fabric filter. In this improved technique scenario, the monitoring technique is upgraded to a PM continuous emission 

monitor. This improved monitoring technique also results in an increase to the monitoring frequency

because a PM CEMS can make a measurement every 7.5 minutes. The monitoring frequency increases from once per 

day to eight times per hour.

EPA 2011a

Onroad 

Heavy Duty Diesel 

Vehicles (Class 8)

Intermodal - shift of 

transportation of goods 

from truck to rail 

transport.

PM: 1%

SO2: 1%

NH3: 1%

$0 NOx, VOC

A fabric filter, or baghouse, consists of a number of fabric bags placed in parallel inside of an enclosure. Particulate matter 

is collected on the surface of the bags as the gas stream passes through them. The particulate is periodically removed 

from the bags and collected in hoppers located beneath the bags. A number of methods are employed to facilitate the 

removal of particulate from the bags, including shaking, reverse air flow, and pulse air flow. The only potential drawback to 

a fabric filter would be when used in conjunction with a high moisture flue gas stream or with extremely high temperatures. 

If moisture levels in the flue gas stream are too high then filter caking can occur. Cost-effectiveness varies depending on 

the type of filter (Reverse-Air Cleaned Type, Mech. Shaker Type, Pulse Jet Type) and is based on EPA’s cost-estimating 

spreadsheet for fabric filters. 

EPA 2006d

Onroad 

Heavy Duty Diesel 

Vehicles (Class 6 and 

above)

Diesel Retrofit PM: 53-56% for Class 

6&7; 52-61% for Class 8

- Class 8: $4,284-

$12,157 per ton NOx 

- Class 6&7: $23,192-

$62,873 per ton NOx

NOx, VOC, CO

This measure is to conduct improved monitoring for PM2.5 emissions at stationary sources. Improved monitoring in this 

case means increasing the monitoring frequency of electrostatic precipitators, scrubbers, and fabric filters from once per 

day to four times per hour, with no change in monitoring technique.

The incremental costs included a one-time cost for development of the improved monitoring and recurring annual burden 

costs for incremental record keeping, reporting, and certification activities.

EPA 2011a

Onroad 

Heavy Duty Diesel 

Vehicles (Class 5 and 

above)

Truck Replacement PM: 90%-98% $17,267-$35,475 NOx, VOC

Applies to 1990-2006 model years. This control measure involves replacing older trucks with model year 2007 and later 

heavy-duty highway trucks. The new stringent emission standards (for MY 2007+) impose a limit of 0.01g/bhp-hr PM, while 

previous regulations imposed limits of 0.1g/bhp-hr PM, 0.25g/bhp-hr PM, and 0.6g/bhp-hr PM for model years 1994, 1991, 

and 1990 respectively. Replacing a 1990 truck would yield a 98% reduction, while replacing a 2006 truck would yield a 

90% reduction.

EPA 2006d

Onroad 

Heavy Duty Diesel 

Vehicles

Alternative Fuel 

Programs

PM: 11%-99%

SO2: 19%-71%

No cost-effectiveness 

available

NOx, VOC, CO, SO2, 

CO2

These programs encompass a number of different programs, including alternative fuel refuse trucks programs, alternative 

fuel vehicle conversion, alternative fuel or hybrid school/transit bus programs, public sector clean fuel fleets, private sector 

clean fuel fleets, and alternative fuels tax credit programs. The control efficiencies listed are ranges for biodiesel, CNG, 

LPG, and E85. For heavy duty vehicles, LPG may actually increase VOC emissions by up to 78% compared to diesel.

EPA 2002f, NREL 2006, 

NREL 2003, ANL 1999

Onroad 

Light Duty Gasoline 

Vehicles

Alternative Fuel 

Programs

PM: 34%-80%

SO2: 19%-77%

No cost-effectiveness 

available

NOx, VOC, CO, SO2, 

CO2

These programs encompass a number of different programs, including alternative fuel vehicle conversion, public sector 

clean fuel fleets, private sector clean fuel fleets, and alternative fuels tax credit programs. The control efficiencies listed are 

ranges for CNG and E85.

EPA 2002f, NREL 2006, 

JAWMA 2009, ANL 

1999

Onroad 

Light Duty Gasoline 

Vehicles and Trucks

Travel Efficiency 

Strategies VOC: 2-5% NOx, CO, VOC

These types of measures can achieve 2-5% reduction by 2020 if the "low cost" bundle of strategies from the "Moving 

Cooler" report is implemented either aggressively or to the maximum extent. The "Low Cost" bundle represents the best 

combination of strategies based on cost, likelihood of success, and accuracy of the research results. This bundle includes 

strategies like smart growth/transit, commuter strategies, system operations (e.g., eco-driving, ramp metering), pricing 

(e.g., parking taxes, congestion pricing, intercity tolls), speed limit restrictions, and multimodal freight strategies. 

Additionally EPA has released the Transportation Efficiency Assessment Method (TEAM) for assessing emissions 

reductions from travel efficiency strategies. For more information see references.

Cambridge 2009, EPA 

2011d

Nonroad

Commercial Marine - 

Ocean Going Vessels

Shore Based Electrical 

Power - Cold Ironing PM: 90%

$6,500-$18,000 ton of 

NOx + diesel PM 

reduced.

NOx

Cost effectiveness is based on the 2066 ARB Emission Reduction Plan for Ports and Goods Movement and is based on a 

mix of strategies and approaches (it was calculated based on various

ARB programs).

ARB 2006

Nonroad 

Locomotives Idling Reduction

Variable depending on 

technology and 

application

PM, VOC, SO2, CO, 

Toxics

Idle reduction technologies such as SmartStart and Diesel Driven Heating Systems can reduce idling up to 90 percent, 

depending on which technology is employed in which application. This can significantly reduce overall emissions as EPA 

estimates that idling accounts for about 60 percent of switch yard locomotive operating time and 12.5 percent of line-haul 

locomotive operating time. A specific control efficiency is not provided since EPA has recently adopted new more stringent 

emissions standards and mandated the application of idle-emission controls on newly manufactured and remanufactured 

locomotives. This control measure will thus be most efficient as a retrofit to older locomotives. The new EPA rule consists 

of a three-part emission control strategy: first, there are new standards for existing locomotives that take effect as soon as 

certified remanufacture systems are available. Second, the rule sets near-term emission standards, referred to as Tier 3 

standards, for newly-built locomotive (phase-in starting in 2009). Third, the final long-term emissions standards, referred to 

as Tier 4, apply to newly-built locomotives (phase-in beginning in 2015). EPA estimates this final rule will result in PM 

reductions of about 90 percent and NOx reductions of about 80 percent from engines meeting these standards, compared 

to engines meeting the current standards. More information is available at: http://www.epa.gov/otaq/locomotives.htm and 

http://www epa gov/otaq/regs/nonroad/locomotv/420f08014 pdf 

This control is the use of 

low NOx burner (LNB) 

technology and 

selective non-catalytic 

reduction (SNCR) to 

reduce NOx emissions. 

LNBs reduce the 

amount of NOx created 

from reaction between 

fuel nitrogen and 

oxygen by lowering the 

temperature of one 

combustion zone and 
Mobile Controls PM, SO2, NH3

Menu of Control Measures

Updated 4/12/2012

Printed 8/6/2013 65 of 67

Nonroad

Locomotives

Upgrade Engines in 

Switcher Locomotives - 

Diesel-electric hybrid 

locomotives

PM: 80%

$6,500-$18,000 ton of 

NOx + diesel PM 

reduced.

NOx

Diesel-electric hybrid switch locomotives (e.g. Green Goats) are a proven technology that use the same basic concept as 

a gas-electric hybrid automobile – a battery pack powers the locomotive, while a small diesel engine runs as needed to 

keep the batteries charged. Hybrid switch locomotives have significantly reduced diesel PM and NOx emissions, idling 

time, and fuel use compared to conventional switchers. These can reduce PM and NOx emissions generated by a switcher 

locomotive by up to 80 percent. Cost effectiveness is based on the 2066 ARB Emission Reduction Plan for Ports and 

Goods Movement and is based on a mix of strategies and approaches (it was calculated based on various ARB 

programs).

ARB 2006

Nonroad 

Diesel Industrial

ARB Cargo Handling 

Equipment Rule - 

Application of Best 

Available Control 

Technology 

PM: 25%-85% $6,500-$18,000 NOx

The range of control efficiency values represents Level 1, 2 and 3, which are three benchmarks that control systems can 

be verified to. Cost effectiveness is based on the 2006 ARB Emission Reduction Plan for Ports and Goods Movement and 

is based on a mix of strategies and approaches (it was calculated based on various ARB programs).

ARB 2006

Nonroad 

Heavy Duty Diesel 

Diesel Retrofit - 

DOC/DPF/Rebuild PM: 20%-90% $18,100 - $33,900 NOx, VOC, CO

This measure achieves substantial PM emission reductions from the use of diesel particulate filter technology or engine 

rebuilds for various types of nonroad equipment such as construction equipment, airport support equipment, and 

commercial generators. PM cost effectiveness values apply for all retrofit measures combined (DOC, DPF, and rebuild).

EPA 2006l, EPA 2006m
References

Menu of Control Measures

Updated 4/12/2012

Printed 8/6/2013 66 of 67

Key Reference

ACEEE 2009 ACEEE, 2009: "Saving Energy Cost Effectively: A National Review of the Cost of Energy Saved Through Utility-Sector Energy Efficiency Programs." ACEEE Report U092 

al. 2009. Washington, D.C,: American Council for an Energy Efficiency Economy. 

ADEQ 2011 ADEQ, 2011: "Ozone Action Days". Arkansas Department of Environmental Quality, Air Division Planning & Air Quality Analysis Branch, available at: 

http://www.adeq.state.ar.us/air/ozone/ozonedays.asp (browsed on August 17, 2011).

ANL 1999 ANL, 1999: "A Full Fuel-Cycle Analysis of Energy and Emissions Impacts of Transportation Fuels Produced from Natural Gas", ANL/ESD-40. Argonne National Laboratory 

ARB 1989 CARB, 1989: California Air Resources Board, Stationary Source Division, "ARB-CAPCOA Suggested Control Measure for Architectural Coatings, Technical Support Docu 

ARB 1990 CARB, 1990: California Air Resources Board, Stationary Source Division, "Proposed Regulation to Reduce Volatile Organic Compound Emissions from Consumer Produc 

Document," August 1990.

ARB 1991 CARB, 1990: California Air Resources Board, Stationary Source Division, "Proposed Regulation to Reduce Volatile Organic Compound Emissions from Consumer Produc 

Document," August 1990.

ARB 1999 ARB, 1999: California Air Resources Board, "Initial Statement of Reasons for Proposed Amendments to the California Consumer Products Regulation," Stationary Source 

ARB 2000 ARB, 2000: California Air Resources Board, "Staff Report for the Proposed Suggested Control Measure for the Architectural Coatings, Volume II, Technical Support Docum 

Economic Impacts," June 2000.

ARB 2005a ARB, 2005: California Environmental Protection Agency, Air Resources Board, "Final Staff Report, SB656, Assessment and Control Measure Evaluation", July 28, 2005.

ARB 2005b ARB, 2005: California Environmental Protection Agency Air Resources Board, "Staff Report for the Proposed Suggested Control Measure for Automotive Coatings," Octob 

ARB 2006 CARB, 2006: "Emission Reduction Plan for Ports and Goods Movement in California". April 2006.

ARB 2007a ARB, 2007: California Environmental Protection Agency Air Resources Board, "Staff Report For Proposed Amendments to the Suggested Control Measure for Architectur 

2007.

ARB 2007b ARB, 2007: Technical Support Document for Regulation for Reducing the Ozone Formed from Aerosol Coating Product Emissions, .

ARB 2007c ARB, 2007: "Proposed 2007 Amendments to Phase 3 California Reformulated Gasoline Regulations Staff Report: Initial Statement of Reasons". April 2007

ARB 2010 ARB, 2010: California Air Resources Board, "Initial Statement of Reasons: Proposed Amendments to the California Regulation for Reducing Emissions from Consumer Pr 

310: Determination of Volatile Organic Compounds in Consumer Products and Reactive Organic Compounds in Aerosol Coating Products," September 2010.

AWMA 1992 AWMA, 1992: Air & Waste Management Association, "Air Pollution Engineering Manual," edited by A. Buonicore and W. Davis, Van Nostrand Reinhold, NY, NY, 1992.

AXE 1999 Axe, 1999: D. Axe, IMC Agrico Feed Ingredients, personal communication with S. Roe, E.H. Pechan & Associates, Inc., June 1999.

BAAQMD 1999 BAAQMD, 1999: Bay Area Air Quality Management District, "San Francisco Bay Area Ozone Attainment Plan for the 1-Hour National Ozone Standard, Appendix B - Contr 

June 1999.
References

Menu of Control Measures

Updated 4/12/2012

Printed 8/6/2013 67 of 67

Key Reference

Barr and Schaffner 2003 Barr, Leigh and Karen Schaffner, “Impact of Improved Monitoring on PM2.5 Emissions,” RTI International, memorandum to Barrett Parker, U.S. Environmental Protection A 

Park, NC, December 8, 2003.

Berry 1997 Berry, 1997: N. Berry, South Coast Air Quality Management District, personal communication with D. Crocker, E.H. Pechan & Associates, Inc., March 4, 1997.

BLS 1996 BLS, 1996: Bureau of Labor Statistics, U.S. Department of Labor, "Producer Price Indices," Washington, DC, 1996.

Cadmus 1995 Cadmus, 1995: The Cadmus Group, Inc., Investigation and Performance and Cost of NOx Controls as Applied to Group 2 Boilers, Draft Report, prepared for U.S. Environ 

Acid Rain Division, Washington, DC, August 1995.

Cambridge 2009 Cambridge Systematics, Inc. 2009: "Moving Cooler: An Analysis of Transportation Strategies for Reducing Greenhouse Gas Emissions". Urban Land Institute: Washingt 

CDPR 1999 CDPR, 1999: California Department of Pesticide Regulation website: www.cdpr.ca.gov.