### 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 specificemissions 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 59addresses 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

NonPointCommercial/ 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

NonPointIndustrial 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

NonPointIndustrial 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

NonPointIndustrial 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

NonPointIndustrial 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

NonPointIndustrial 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

NonPointIndustrial 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

NonPointOpen 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

NonPointProcess 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 thetemperature 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

NonPointResidential/Commercial/ Institutional Water Heaters and/or Space Heaters Low NOx Water Heaters and Low NOx Burner Space Heaters7-75 $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 Recirculation60 $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 Recirculation60 $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 Recirculation30-50 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 - Ammonia50 $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 - DryingLow 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 Recirculation55 $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 GasLow 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 GlassLow 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 IncineratorsSelective 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 CokeLow 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/ SubbituminousLow 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 Recirculation60 $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 ofone 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 Recirculation60 $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 ofone 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 - OilLow 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 - OilSelective 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 - OilSelective 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 Recirculation60 $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 ofone 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 - Ammonia55 $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 GasSelective 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 GasSelective 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 Recirculation55 $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 Ratio20 $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 GasLow 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 GasLow 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 GasNon-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 GasSelective 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 Recirculation55 $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 Recirculation60 $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 thetemperature 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 thetemperature 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 FurnacesSelective 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 Recirculation60 $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 Recirculation77 $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 Recirculation77 $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 Recirculation60 $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 Recirculation50 $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 thetemperature 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 Recirculation48 $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 thetemperature 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 Burner74 $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 - LPGLow 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 - LPGLow NOx Burner and Flue Gas Recirculation48 $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 - LPGLow 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 thetemperature 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 thetemperature 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 thetemperature 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 thetemperature 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 Burner75 $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 Recirculation55 $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 ofone 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 thetemperature 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 Recirculation55 $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 thetemperature 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 Recirculation34 $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 Burner73 $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 Recirculation55 $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/ ReverberatoryLow 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 Recirculation60 $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 ofone 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 Recirculation60 $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 Recirculation60 $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 Recirculation60 $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 ofone 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 FurnaceLow 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 - NaturalGas (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 OilSelective 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-AirNozzles 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-AirNozzles with crossCoupled Overfire Air 42 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 byhydrocarbon 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/ WallSelective 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/ WallSelective 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 - CycloneNatural 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 - CycloneSelective 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 - CycloneSelective 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

NonPointAdhesives - 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

NonPointAerosol 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.

NonPointArchitectural, 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

NonPointArchitectural, 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 Amendments50 $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 RefinishingCalifornia 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 RefinishingOTC 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 DegreasingProcess 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 DegreasingReformulation-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 CoatingReformulation-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 CoatingsLow-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 CoatingsCoating Reformulation35 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 CleaningSolvents - 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 anoverall 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 CleaningSolvents - 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 anoverall 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 1148.114 $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 WastewaterWastewater 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 UnitsVenturi 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 UnitsSCAQMD Rule 1105.180 $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 ManufacturingPaper/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, grindingSCAQMD 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 SourcesDust 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 ManufactureCEM 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 ManufactureIncreased 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 ManufactureWet 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 ManufactureWet 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 ActivitiesDust 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 15 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 210 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 320 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 11 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 22 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 35 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 112 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 225 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 350 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 StovesCurtailment 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 StovesBurn 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 StovesNo 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 StovesOpacity 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, PMVOC, 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 subbituminous21 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 variousmechanical 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 OperationsDry 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 OperationsDry 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 OperationsFabric 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 OperationsPaper/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 OperationsWet 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 OperationsWet 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 - AluminumDry 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 - AluminumDry 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 - AluminumFabric 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 - AluminumWet 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 - AluminumWet 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. Forthe 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 subbituminous21 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 Program60 $9,900 (2010$) 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 Program100 $7,200 (2010$) 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 Absorber90 $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 KilnSpray Dryer Absorber90 $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 KilnWet 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 Absorber90 $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 Absorber90-95 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 OilFuel switch from 3% sulfur residual oil to 0.2% sulfur distillate oil94 $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 OilFuel 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 OilFuel switch from 1% sulfur residual oil to 0.5% sulfur residual oil50 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 OilFuel switch from 0.3% sulfur distillate oil to 0.05% sulfur distillate oil84 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 OilSpray Dryer Absorber90-95 $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 OilWet 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 OperationsFlue 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 FurnacesWet 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 UnitsIncrease 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 RegionalClean 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 ControlTechnology 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 IndustryFlue 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 Cleaning50-85 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 subbituminous73 $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 Cleaning10-40 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, VOCThis 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, acroleinA 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 campaignsPotential to reduce both NOx and VOC. Low VOC, PM10, PM2.5, COThese 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 equipmentPM10, 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 dieselGas: $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 VesselsShore 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 imp**roved 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 ti**mes 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 campaignsPotential to reduce both NOx and VOC. Low NOx, PM10, PM2.5, COThese 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, acroleinThis 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 VesselsShore 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

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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.