CUMULATIVE COST BURDEN

ANALYSIS OF AIR REGULATIONS 

POTENTIALLY IMPACTING THE 

FOREST PRODUCTS INDUSTRY

Prepared for:

1111 19th St. NW, Suite 800

Washington, DC 20036

Prepared by:

URS Corporation 

1600 Perimeter Park Drive

Morrisville, North Carolina 27560

(919) 461-1100

URS Project No. 31826756

Updated August 2011
TABLE OF CONTENTS

i

1. Introduction/Summary ...................................................................................................1-1

1.1 Introduction .............................................................................................. 1-1

1.2 Conclusions .............................................................................................. 1-1

1.3 Report Organization ................................................................................. 1-2

2. Air Regulations Evaluated .............................................................................................2-1

2.1 Regulations Evaluated ............................................................................. 2-1

2.2 Regulatory Timeline ................................................................................ 2-2

3. Cost Methodology ..........................................................................................................3-1

3.1 Cost Estimate Methodology ..................................................................... 3-1

3.1.1 Boiler Category ............................................................................ 3-2

3.1.2 Boiler Regulatory Cost Scenarios Evaluated for MACT and 

CISWI .......................................................................................... 3-4

3.1.3 Wood Products Category ............................................................. 3-6

3.1.4 Pulp and Paper Category .............................................................. 3-6

3.1.5 Collateral Emissions or Energy Increases for Controls ............... 3-6

3.2 Potential Regulatory Costs not Captured in this Analysis ....................... 3-7

TABLES 

Table 2-1 List of Air Regulations Evaluated and Compounds Regulated 

Table 2-2 Forest Products Industry Regulatory Cost Timeline 

APPENDICES 

Appendix A Cost Estimate Summaries 

Appendix B Cost Estimates by Category and Regulatory Action 

Appendix C Detailed Boiler MACT Cost Spreadsheets 
TABLE OF CONTENTS

ii

List of Acronyms and Abbreviations

AF&PA American Forest and Paper Association

BACT Best Available Control Technology

BART Best Available Retrofit Technology

CAIR Clean Air Interstate Rule

CISWI Commercial or Institutional Solid Waste Incinerator

CO2 Carbon Dioxide

CEMS Continuous Emissions Monitoring System

CPMS Continuous Parameter Monitoring System

EPA Environmental Protection Agency

GACT Generally Available Control Technology

GHG Greenhouse Gas

H2S Hydrogen Sulfide

HAP Hazardous Air Pollutant

HBCA Health Based Compliance Alternative

LAER Lowest Achievable Emission Rate

MACT Maximum Achievable Control Technology

NAAQS National Ambient Air Quality Standards

NCASI National Council for Air and Stream Improvement

NESHAP National Emission Standards for Hazardous Air Pollutants

NHSM Non-Hazardous Secondary Materials 

NOx Nitrogen Oxides

NSPS New Source Performance Standards 

NSR New Source Review

PCWP Plywood and Composite Wood Products

PM Particulate Matter

PM10 Particulate Matter with diameter less than 10 microns

PM2.5 Particulate Matter with diameter less than 2.5 microns

P&P Pulp and Paper

PSD Prevention of Significant Deterioration

RTR Risk and Technology Review
TABLE OF CONTENTS

iii

SO2 Sulfur Dioxide

SSM Startup, Shutdown, or Malfunction

VOC Volatile Organic Compound
SECTIONONE Introduction/Summary

1-1

1. Section 1 ONE Introduction/Summary

1.1 INTRODUCTION

URS Corporation (URS) performed a detailed analysis of the cumulative cost burden of air 

regulations that may potentially impact American Forest and Paper Association (AF&PA)

member companies (e.g., wood products manufacturing facilities and pulp and/or paper 

manufacturing facilities). The purpose of the analysis was to determine a rough order of

magnitude estimate of the cumulative cost burden that would be imposed on the Forest Products 

Industry if EPA implements various air regulatory changes that are currently under 

consideration. The air quality regulations evaluated would impact member company boilers and 

other process equipment. The cost estimates were compiled in a Microsoft Excel workbook;

were based on published information or similar project costs; have been reviewed by member 

company representatives; and have been made available to the US EPA and others for review. 

Note that the Boiler MACT and CISWI costs are based on the March 2011 rules and information 

in EPA’s March 2011 survey and emissions databases, but also take into account the

promulgated solid waste definition rule, that determines whether secondary materials being

burned in boilers are fuels or solid waste and whether boilers are regulated under Boiler 

MACT/GACT or CISWI. This document provides background information on the regulations

included in the analysis and the methodologies used in the analysis. 

1.2 CONCLUSIONS

The following presents a summary of the conclusions from the cost estimate analysis.

 Based on the analysis described in this report, air regulatory actions currently under 

consideration by EPA could result in a Forest Products Industry total estimated initial 

capital cost of $16.5 billion and an estimated annualized cost of $4.3 billion.

 The regulatory action with the most significant economic impact on facilities with 

industrial boilers will be the revised Industrial Boiler Maximum Achievable Control 

Technology (MACT) Standard, combined with the revised CISWI and solid waste 

definition rules. We have estimated costs using a primary scenario that assumes many

secondary materials burned by forest products facilities are determined to be solid waste, 

and also under a secondary scenario that assumes many of these materials are determined 

to be fuels.

 The regulatory action with the most significant economic impact on wood products 

facilities is expected to be the revisions to the wood products MACT standard.

 The regulatory actions with the most significant economic impact on pulp and paper mills 

are considered to be discretionary actions, and not mandated actions, and include

regulation of hydrogen sulfide (H2S) as a hazardous air pollutant (HAP), regulation of 

recovery furnaces under the Clean Air Interstate Rule (CAIR) that currently regulates 

fossil fuel-fired utility boilers, and adding regulated compounds to the pulp and paper 

MACT standards.
SECTIONONE Introduction/Summary

1-2

1.3 REPORT ORGANIZATION

The remainder of this report is divided into the following sections:

Section 2.0: Air Regulations Evaluated

Section 3.0: Cost Methodology and Results

The table of contents contains a detailed listing of tables and appendices. 
SECTIONTWO Air Regulations Evaluated

2-1

2. Section 2 TW O Air R egulations Ev aluated

2.1 REGULATIONS EVALUATED

AF&PA member companies identified several air quality regulations that have the potential to 

significantly impact them economically. Of the regulations identified, some are regulations that 

EPA is required to promulgate or revise and some are regulations that EPA may decide to 

review, revise, or implement. Note that because the regulatory scheme for greenhouse gases 

(GHG) is uncertain, this analysis did not focus on the cost of GHG regulations, which is also 

expected to be significant for the industry.

Table 2-1 presents the potential air regulatory actions considered and the main regulated 

compounds impacted. AF&PA considers the following regulatory actions discretionary on the 

part of EPA: 

 Revisiting the pulp and paper MACT standards outside of the required risk and 

technology review (RTR) requirements;

 Including industrial boilers and recovery furnaces in the Clean Air Interstate Rule (CAIR)

replacement, now termed the Cross State Air Pollution Rule (CSAPR);

 Regulating H2S as a HAP;

 Developing New Source Performance Standards (NSPS) for wood products 

manufacturing; and 

 Revisions to the current Kraft Pulp Mill NSPS under 40 CFR 60, Subpart BB. 

The other non-discretionary regulatory actions include:

 Boiler MACT re-promulgation (will result in significantly lower limits than the 2004

regulation that was vacated);

 Generally Achievable Control Technology (GACT) for boilers located at area sources of 

HAP;

 Regulation of boilers as commercial or industrial solid waste incinerators (CISWI) if

certain materials are deemed waste and not fuel;

 Risk and Technology Review for Pulp and Paper MACT rules (to determine if additional 

HAP emissions controls are needed);

 Reviewing/lowering the National Ambient Air Quality Standard (NAAQS) for Nitrogen 

Oxides, new 1-hour standard (NOx);

 Reviewing/lowering the NAAQS for Sulfur Dioxide, new 1-hour standard (SO2);

 The Continuous Parameter Monitoring System (CPMS) rule specifying quality assurance

procedures for CPMS required by NSPS and MACT standards;

 Full implementation of the NAAQS for particulate matter less than 2.5 microns in 

diameter (PM2.5);

 Revisions to the Plywood and Composite Wood Products (PCWP) MACT due to court 

decisions;
SECTIONTWO Air Regulations Evaluated

2-2

 Changes to the PCWP and Pulp and Paper MACT rules due to the SSM vacatur (sources 

are no longer exempt from compliance during periods of SSM);

 Reviewing/lowering the Ozone NAAQS and increased number of non-attainment areas; 

and

 Further regulation of sources under the Regional Haze rule to meet future progress 

targets.

Estimated regulatory costs are summarized in Appendix A and are presented by rule in 

Appendix B of this document.

2.2 REGULATORY TIMELINE

The air regulations were evaluated in order of expected effective date and efforts were made to 

avoid double counting regulatory impacts. For example, if a boiler installed acid gas controls 

under Boiler MACT for control of hydrogen chloride and other inorganic HAPs, the facility

would presumably not have to install additional controls on the boiler as a result of future

regulations impacting SO2 emissions. 

Table 2-2 presents the regulatory cost impact analysis by year, based on the expected timing. 

For rules where the majority of the sources are impacted upon the initial promulgation of the rule

(e.g., Boiler MACT), estimated capital costs are phased three years prior to the compliance date 

and annual costs remain constant each year following the compliance date (the number of 

affected sources is assumed to remain relatively constant). For rules where sources are impacted 

over time (e.g., NSPS), annual operating costs increase over time as the number of affected units

increases. Details on how the cost estimates were developed are presented in Section 3.
SECTIONTHREE Cost Methodology

3-1

3. Section 3 THR EE Cost Methodology

3.1 COST ESTIMATE METHODOLOGY

URS estimated air regulatory costs for three categories of forest products industry sources: 

industrial boilers, wood products industry sources (non-boilers), and pulp and paper industry

sources (non-power boilers). The regulations considered in this analysis were assigned to one or 

more of these categories, as shown in Table 2-1, and in general are ordered by expected effective

date.

The three key variables in the analysis were the cost of controls, the number of affected units, 

and the inter-relationship of the regulations. For each category and regulation, potential 

compliance or emissions control scenarios were determined based on the compounds expected to 

require control, and for each of these scenarios, compliance costs and numbers of units included

in the scenario were estimated. Both a capital cost and an annual operating cost were

determined, and the capital cost was annualized using a capital recovery factor to develop the

total estimated annual cost for each scenario. The regulatory costs are driven by selection of the 

compliance method or control technology to achieve significant emission reductions rather than 

to meet any specific limit under a particular regulation.

Capital and operating costs estimates are not intended to represent a worst case analysis. Rather, 

they represent median costs for the various scenarios based on published reports, industry

information on specific project costs, EPA reports or control device fact sheets, or actual BACT 

or BART analyses submitted to permitting agencies. A primary resource was the document 

“Evaluation of Air Pollution Control Costs for the Pulp and Paper Industry,” prepared by

National Economic Research Associates (NERA) in May 2003. Note that costs were not scaled 

from the date of the reference used to 2011 dollars as the intent was to develop an order of 

magnitude estimate for each control scenario. 

Air emissions controls were assigned to the rule with the earliest effective date. For example, if 

a later rule requires the same controls (e.g., industrial boilers are covered by CAIR at a date 

following the implementation Boiler MACT), the control cost is not double counted. However, 

if a cost from an earlier rule does not occur, or if a rulemaking is delayed, later rules could then 

become more expensive than currently estimated. Summaries of the estimated costs for each 

regulatory action and each category are presented in Appendix A.

URS received the following estimates from the National Council for Air and Stream 

Improvement (NCASI) regarding the numbers of each type of forest products industry facility:

700 sawmills (approximately 221 of which are major sources of HAP),

300 wood products mills (approximately 170 of which are major

sources), 

300 converting plants (mostly area sources), and

379 pulp and paper mills (mostly major sources),

including 100 Kraft, 8 semi chemical, 

18 mechanical pulp, 5 sulfite, and 1 soda.
SECTIONTHREE Cost Methodology

3-2

3.1.1 Boiler Category 

The detailed cost estimates for the boiler category are presented in Appendix B. URS received 

the following information from NCASI regarding the number and types of boilers in the forest 

products industry (note that 301 of the 918 pulp and paper mill boilers are at the 100 Kraft mills):

916 pulp and paper mill boilers

83 coal

67 coal/wood

108 wood

658 oil/gas (about half of these are major sources of HAP)

820 wood products mill boilers

600 wood (100 major sources, 500 area sources)

120 gas (most area sources of HAP)

100 oil (most area sources of HAP)

200 boilers at converting plants (probably all area sources)

The EPA collected information during Phase 1 of the Boiler MACT information collection 

request (ICR) on 455 boilers at facilities in NAICS 322xxx (pulp and paper and packaging) and 

369 boilers in NAICS code 321xxx (wood products). 

In the boiler category, all forest products industry boilers (not including pulp mill recovery

boilers) will fall under Boiler MACT, Boiler GACT, or CISWI. URS identified the regulated 

compounds likely to require control, likely control options (sometimes by boiler fuel type), 

typical control costs, and estimated number of units affected for each rule. For the regulatory

actions that may occur after these first three rules, we then estimated additional numbers of

boilers that will also be affected, in an attempt to avoid double counting control costs. However, 

note that an individual unit might be represented more than one time in the table if it has to 

install two different types of controls for different regulated compounds (e.g., fabric filter for PM 

and carbon injection for mercury). Costs of the boiler rules were allocated to the wood products 

and pulp and paper sectors based on information about the numbers, types, and sizes of boilers in 

each category.

A detailed spreadsheet was developed to estimate costs for Boiler MACT, based on EPA’s major 

source boiler inventory database table. Because the rule does not include emission limits for

natural gas boilers, boilers less than 10 MMBtu/hr heat input, or limited use units, these units are

not included in the cost analysis. Based on the information in the EPA emissions database on 

boiler size, fuel, existing controls, and emissions, we estimated costs of controls that would 

likely be necessary to comply with the Boiler MACT for coal, biomass, and liquid boilers. Note 

that EPA’s March 2011 rule assumed that landfill gas boilers (formerly in the Gas 2 category)

could comply with MACT using work practices. As some forest products boilers at major 

sources did not receive an ICR from EPA in 2008, we added information for those boilers to the 

detailed spreadsheet based on a database maintained by Fisher International and information

from NCASI. 

Information from various sources was used to determine a base capital cost for a 250 MMBtu/hr

boiler for each PM, CO, and HCl control technology option and then scaled using an 0.6 power 

function based on the size of each boiler in the inventory. For example, the capital cost of a wet 

scrubber on a 100 MMBtu/hr boiler is calculated as the base cost times (100/250)0.6. A fixed 
SECTIONTHREE Cost Methodology

3-3

cost of $1 million was assumed for installation of a carbon adsorption system for Hg and/or 

dioxin control, as these systems do not vary much in cost by boiler size. Base cost assumptions 

are presented below. Operating costs are based on EPA and vendor information.

Base Control Size, MMBtu 250

Fabric Filter Capital Cost $7,000,000

Wet Scrubber Capital Cost $8,000,000

WS/FF/ESP upgrade Capital Cost $4,000,000

Carbon Injection for Hg/dioxin

Capital Cost $1,000,000

Combustion Improvements or

Catalyst for CO Capital Cost $3,000,000

Interest Rate 7 percent

Equipment life, yrs 15

Capital recovery factor 0.110

Activated Carbon rate, lb/mmacf 4

Activated Carbon cost, $/lb $1.00

Wet scrubber annual operating

cost, $/acfm $10

FF annual operating cost $200,000

For the Boiler MACT control costs, we assumed that if emissions information (either sitespecific test data or EPA’s baseline emission factors by boiler type and existing control) 

indicated the boiler would not meet the March 2011 limits, the unit would need MACT, which 

EPA says is a fabric filter (FF) plus carbon injection plus wet scrubber plus combustion 

improvements (or CO catalyst). In their boiler inventory table, EPA put the boiler pollution 

controls into categories. The categories are explained in greater detail in EPA’s baseline

emission factor memo, but basically are as follows: for PM control code, 1=FF, 2=EFB/ESP, 

3=venturi scrubber, 4=wet scrubber, 5=multiclone, 6=none/mist eliminator/unknown. If a unit

did not already have a FF or ESP and there was information that indicated the unit cannot meet 

the limit, we assumed a new FF. If the unit already had a FF or ESP and there was information 

that indicated the unit cannot meet the limit we assumed an upgrade to the existing control 

equipment. For HCl control code, 1=wet scrubber or spray dryer, 2=dry scrubber, 3=sorbent 

injection, 4=venturi scrubber, 5=none/dry PM only. To estimate control costs for HCl, if there

was information that indicated the unit cannot meet the limit, we assumed either a scrubber 

upgrade or new scrubber depending on whether the unit currently had a scrubber. For Hg control 

code, 1=carbon injection, 2=FF plus sorbent injection or spray dryer, 3=FF only, 4=wet scrubber, 
SECTIONTHREE Cost Methodology

3-4

5=venturi scrubber, 6=none/multiclone/EFB/mist eliminator. For Hg and dioxin, if there was 

information that indicated the unit cannot meet the limit, we added carbon injection. For CO, if 

there was information that indicated the unit cannot meet the limit, then we assumed that capital 

would be necessary to either perform combustion/fuel feed improvements or other boiler 

improvement projects to reduce CO or install a CO catalyst.

CISWI rule costs were developed in much the same manner as the Boiler MACT costs, using

EPA’s CISWI database. Control costs for NOx were added if necessary, assuming a base cost 

for SNCR of $4 million.

We assumed that compliance with Boiler GACT will only require tune-ups. Note that many

facilities may choose fuel switching as a compliance option; however, as the cost of fuel 

switching is highly dependent on site specific factors (e.g., whether the boiler can burn the

alternate fuel, what upgrades must be made to the fuel supply system) and the price of fuel is 

likely to change over time due to factors like supply and demand, we did not attempt to quantify

costs for fuel switching. 

For each rule, a total annual cost is presented based on the sum of each line item under the rule 

and represents the first year of implementation of the rule (for some rules the annual operating

cost will increase over time as more sources become subject to the rule, such as NSPS). The

Boiler MACT and CISWI Rules account for the majority of the estimated cost in the boiler

category and are expected to require significant additional control cost for the forest products 

industry. The total estimated annual cost of the boiler regulations examined is $1.3 billion. The

majority of this cost impact will be on the pulp and paper category, primarily impacting Kraft 

mills (it is estimated that Kraft mills will bear around 70 percent of the pulp and paper category’s 

cost, based on the allocation of boilers at Kraft mills versus other mills). We anticipate that the 

Kraft pulp mills would bear the majority of the Boiler MACT cost assigned to the pulp and paper 

category and that non-Kraft mills would bear the majority of the Boiler GACT cost assigned to 

facilities in the pulp and paper category.

3.1.2 Boiler Regulatory Cost Scenarios Evaluated for MACT and CISWI

URS assumed that the health based compliance alternative (HBCA) is no longer an option for 

Boiler MACT. However, the following table shows potential savings that could be realized if 

the HBCA is an option under Boiler MACT. Note that the analysis did not differentiate by fuel, 

so if manganese is the only metal that can be excluded from a TSM limit using HBCA, then coal 

and oil-fired boilers would not benefit from HBCA as much as a wood-fired boiler would, and 

the savings would be less for the industry as a whole.

Potential Cost Savings with HBCA under Boiler MACT

Pulp and Paper Wood Products

Capital Cost Annual Cost Capital Cost Annual Cost

Assuming 50% of mills could comply with

PM/metals and HCl using HBCA instead of

add-on controls:

$830 million $156 million $226 million $30 million

Assuming 90% of mills could comply with

PM/metals and HCl using HBCA instead of

add-on controls:

$1.5 billion $282 million $407 million $54 million
SECTIONTHREE Cost Methodology

3-5

URS examined two regulatory scenarios for Boiler MACT and CISWI. The Non-Hazardous 

Secondary Materials (NHSM) definition rule determines whether boilers are regulated under 

Boiler MACT or CISWI. If a boiler or other combustion unit burns a secondary material that is 

solid waste, it will be regulated under the CISWI rule. The current Boiler MACT database

contains units that burn some types of secondary materials, and only a few forest products boilers 

are in the CISWI database. Even though EPA is contemplating guidance that indicates many

materials traditionally burned as fuels can still be classified as fuels, the current rule language

may result in many materials being classified as solid waste (e.g., wastewater treatment 

residuals, recycling process residuals, TDF, resinated wood, creosote treated wood/rail ties). 

URS evaluated the impacts of having these materials considered solid wastes and having 104 

boilers burning these materials install controls to comply with the CISWI rule instead of the

Boiler MACT. Under this scenario, we estimate that one third of the 500 forest products area

source boilers and 85 wood products facilities burning sanderdust in dryers would also have to 

install controls to comply with the CISWI rule (the average per boiler control cost of the

104 additional boilers of $7.8 million is used for these estimates).

Scenario Boiler MACT CISWI Rule Total Cost

Control Cost When Many

NHSM are Wastes not Fuels

$3.7 Billion $3.3 Billion $7 Billion

Control Cost When Most

NHSM are Fuels not Waste

$4.3 Billion $470 Million $4.8 Billion

If facilities were to stop burning NHSM and replace the fuels with natural gas, operating costs

would increase instead of capital costs. Based on the number of mills known to burn NHSM and 

estimated amounts burned (based on 2005 NCASI survey and supplier estimates), the annual cost 

for forest products industry boilers to stop burning wastewater treatment residuals, recycling

process residuals, TDF, resinated wood, and creosote treated wood/rail ties would be over 

$650 million.

Material # Mills # Boilers 2005 Amount

(Tons)

% of Total 

Boiler Fuel 

Used

Cost to landfill and

replace with natural gas

1

Wastewater Treatment 

Residuals 57 68 1,340,000 1.8 $159,000,000

TDF 21 29 401,500 1.2 $68,582,000

Recycling Process Residuals 211 14 172,200 0.3 $24,200,000

Rail ties 312 550,000 0.10 $57,600,000

Resinated Wood 100+ 2,500,000 73.5 $352,000,000

Total $661,382,000

1 = TDF and Railroad ties costs only include fuel replacement, not landfilling

2 = This is likely to be an underestimate. There are more than 100 mills that recycle, but not all have on-site boilers

3 = This represents an estimate by a major supplier of rail ties used by the FPI in 2011
SECTIONTHREE Cost Methodology

3-6

3.1.3 Wood Products Category 

The detailed cost estimates for the wood products category are presented in Appendix B. Note

that we have not included emissions controls for lumber kilns, although we have assumed that 

there will be some cost to implement the expected work practice requirements. We have

assumed that the level of control for currently controlled wood products MACT sources will not 

change (e.g., EPA will not increase the required control efficiency from 90 percent to 

95 percent). We have also assumed that backup controls will not be required as a result of the

SSM vacatur.

Of the regulatory actions evaluated, the revisions to the PCWP MACT will pose the most

significant cost burden on the wood products industry (non-boiler sources), as additional sources 

are expected to require control under the revised rule. The total estimated annual cost of the 

potential wood products air regulatory actions examined (excluding boiler regulations) is 

$230 million.

3.1.4 Pulp and Paper Category

The detailed cost estimates for the pulp and paper category are presented in Appendix B. Note

again that we have attempted to avoid double counting in the cost analysis, but one facility might 

have control costs under different regulations. URS received the following information from 

NCASI regarding the number of existing recovery furnaces and lime kilns at pulp and paper 

mills:

53 Direct contact evaporator (DCE) recovery furnaces

108 Non-direct contact evaporator (NDCE) recovery furnaces

140 Lime kilns

The highest potential cost impacts for the pulp and paper industry (non-power boiler sources) are

from regulatory actions that are not required to be implemented: regulating H2S as a HAP, 

including recovery furnaces in CAIR, and making significant revisions to the pulp and paper 

MACT rules (e.g., adding regulated compounds). 

The regulation of H2S as a HAP is expected to cause significant regulatory burden as it would 

likely require H2S emission reductions from wastewater treatment systems. This could require

conversion of systems with aerated stabilization basins to activated sludge systems at a capital 

cost of approximately $35 million for each of 67 mills. Based on the items in a Sierra Club 

petition to add regulated compounds to the pulp and paper MACT standards, we have estimated 

control scenarios and control costs that amount to over $1 billion per year for the pulp and paper 

industry. The total estimated annual cost of the potential pulp and paper air regulatory actions 

examined is $1.9 billion. 

3.1.5 Collateral Emissions or Energy Increases for Controls

The detailed cost estimates in Appendix B also present information on whether a collateral 

emissions or energy increase can be expected with implementation of a control technology. 
SECTIONTHREE Cost Methodology

3-7

Where a control is expected to significantly increase electricity or fuel consumption, or will

convert CO to CO2 (e.g., a catalyst installed on a boiler), we have estimated the CO2 emissions 

increase in metric tons per year. The notes column in the detailed cost estimates included in 

Appendix B provides the assumptions used to estimate CO2. CO2 emissions from combustion of 

additional biomass are not estimated, as these emissions are considered carbon neutral. 

Increased electricity and fuel consumption due to implementation of certain control strategies 

will also lead to higher NOx emissions, which would not be favorable in an ozone non-attainment 

area. An impact of reducing CO and THC emissions through combustion controls and fuel 

switching may be increases in NOx emissions, but the impact would be dependent on the

operating conditions at each boiler before and after the change.

3.2 POTENTIAL REGULATORY COSTS NOT CAPTURED IN THIS ANALYSIS

The forest products industry faces other non-Clean Air Act regulatory costs under the Clean 

Water Act and the Resource Conservation and Recovery Act. There are also significant costs 

expected to be incurred by any future GHG regulatory scheme. For example, electricity may

become very expensive for facilities that buy power from coal-fired power plants and facilities 

that operate coal-fired boilers may be financially impacted if a carbon tax or cap and trade

program is enacted. Renewable energy legislation is also expected to significantly increase the 

cost of biomass, the forest products industry’s raw material. This analysis only captured costs

that will potentially be incurred as a result of non-GHG air regulatory actions currently being

considered by EPA. We were also unable to predict the impact of the Electric Utility MACT on 

fuel and operating costs (e.g., increased electricity cost due to increased utility control costs or 

increased natural gas cost due to increase in Utility conversions of coal-fired units to natural gas 

and decrease in industrial availability).

Note that originally, we had developed cost estimates for the impact of EPA rolling back NSR

reform (e.g., reverting to the “actual to potential” PSD applicability test instead of the “baseline

actual to projected actual” applicability test). However, recent information indicates that EPA 

does not intend to go forward with this action. We originally estimated a capital cost for

industrial boilers of $308 million due to a large number of projects triggering PSD review that 

would not have under the NSR reform rule, with an estimated annual cost of $38.8 million. The

estimated costs for pulp and paper mills were approximately $115 million in capital and 

$28 million in annual costs, and for wood products facilities were $101 million in capital and 

$16 million in annual costs.
Tables
Table 2-1. List of Air Regulations Evaluated and Compounds Regulated

Wood Products - 

srcs already 

controlled

Wood Products - 

uncontrolled 

srcs

Pulp and Paper - pulp 

mill srcs already 

controlled

PM/metals Hg NOx SO2/acid gas VOHAP/CO Dioxin GHG VOC VOC VOC VOC TRS VOC TRS VOC TRS VOC TRS PM/metals NOx SO2/acid gas TRS Hg VOHAP/CO dioxin GHG PM/metals acid gas TRS Hg VOHAP/CO

Boiler MACT 1 x x x x x

Boiler GACT 2 x x x

CISWI 3 x x x x x x

CAIR for industrial 

boilers 4 x x x x x x

Regional Haze 5 x x x x x

CO2 regulated 6 x x

NOx NAAQS 

lowered 7 x x x

SO2 NAAQS 

lowered 8 x x

Ozone NAAQS 

lowered 9 x x x x x x x x x x x

PM2.5 NAAQS 

fully implemented 10 x x x x x x x x

SSM goes away 

under MACT 11 x x x x x x x x

NSR reform 12 x x x x x x x x x x x x x x x x x x x x x x x x x x

PCWP MACT 

revisions 13 x

PCWP MACT 

residual risk 14 x x

NSPS for wood 

products 20 PM/NOx? PM/NOx?

H2S listed as HAP 15 x x x x x x

P&P MACT I 

revisions 16 x x x

P&P MACT II 

revisions 17 x x x x x x x x x x

P&P MACT 

residual risk 18 x x x x x x x x x x x x x

NSPS BB 

revisions 19 ? x ? ? x ? x ?

Notes

1. Boilers covered by MACT would not be covered by GACT. Many boilers will need control upgrades under MACT.

2. Boilers covered by GACT will not be covered by MACT. Costs under GACT will likely be lower than costs to comply with MACT, since work practices are allowed for existing biomass and liquid (coal has Hg limit).

3. Boilers covered by CISWI will not be covered by MACT or GACT. This will affect boilers burning materials deemed to be waste.

4. CAIR rule may be revised to cover fossil fuel-fired industrial boilers >250 MMBtu, and this could possibly include recovery boilers.

5. Sources close to Class I areas may be required to control SO2/NOx/PM to improve Regional Haze. 

6. Regulation of CO2 would require emissions and control analyses for projects resulting in emissions increases, a cap and trade program may result in required reductions. BACT may be fuel switching.

7. Lowering of NOx ambient standard could result in NOx controls where a major project requires NAAQS modeling. New 1-hour standard difficult to comply with. States using modeling for attainment designations.

8. Lowering of SO2 ambient standard could result in SO2 controls where a major project requires NAAQS modeling. New 1-hr standard difficult to comply with. States using modeling for attainment designations.

9. Further lowering of ozone NAAQS puts more sources in non-attainment areas and may have to do RACT or install LAER for projects.

10. Full implementation of PM2.5 NAAQS may result in additional controls if a project cannot demonstrate compliance (not much room between background and standard).

11. Sources subject to MACT may not be allowed control device downtime or venting allowance. Will need backup controls, better controls, or more frequent process shutdowns.

12. Note that EPA has denied the petition for reconsideration of NSR reform at present, but if NSR reform were rolled back, more projects may trigger PSD review and BACT controls.

13. More sources may require control at PCWP plants (expand oxidizers or add additional oxidizers or biofilters)

14. Residual risk review may result in lower emission limits or additional regulated sources.

15. If H2S is listed as a HAP, EPA would have to revisit pulp and paper MACT and add H2S emission standards/possible additional controls (e.g., WWTP).

16. Sierra Club has sued because some pollutants not required to be controlled, some unregulated sources can be traded for regulated sources, some sources can be overcontrolled instead of controlling a regulated source further.

17. Sierra Club has sued because some pollutants not required to be controlled, some unregulated sources can be traded for regulated sources, some sources can be overcontrolled instead of controlling a regulated source further.

18. Residual risk review may result in lower emission limits or additional regulated sources.

19. EPA conducting a review/possible update of NSPS BB.

20. Not sure what this regulation would include - maybe standards for new dryers.

Pulp and Paper - CCA mills Pulp and Paper - Smelt Tanks

Pulp and Paper - 

Wastewater 

Treatment Systems Pulp and Paper - BLOX Pulp and Paper - Recovery Boilers/Lime Kilns

Rule Notes

Boilers/Process Heaters at Wood Products and Pulp and Paper

Pulp and Paper - Paper 

Machines
Table 2-2. Forest Products Industry Regulatory Cost Timeline

Year --> 2010 2011 2012 2013 2014 2015 2016 2017 

Rule

$370,000,000 $925,000,000 $2,405,000,000

$290,000,000 $290,000,000 $290,000,000 $

$700,000,000 $700,000,000 $700,000,000 $700,000,000 $700,000,000 $

$1,000,000 $2,500,000 $6,500,000

$9,000,000 $9,000,000 $9,000,000 $9,000,000 $9,000,000 

$109,795 $9,000,000 $9,000,000 $9,000,000 $9,000,000 $9,000,000 

$325,000,000 $812,500,000 $2,112,500,000

$805,000,000 $805,000,000 $805,000,000 $

$1,160,000,000 $1,160,000,000 $1,160,000,000 $1,160,000,000 $1,160,000,000 $1,

$62,000,000 $62,000,000

$7,000,000 $7,000,000 $7,000,000 $7,000,000 $7,000,000 

$21,000,000 $21,000,000 $21,000,000 $21,000,000 $21,000,000 

$620,500,000

$142,000,000 $142,000,000 $142,000,000 $142,000,000 $

$68,127,565 $211,000,000 $211,000,000 $211,000,000 $211,000,000 $

$140,000,000

$28,000,000 $28,000,000 $28,000,000 $28,000,000 

$15,371,247 $43,000,000 $43,000,000 $43,000,000 $43,000,000 

CPMS Rule

$60,000,000 $120,000,000 $120,000,000 $120,000,000 $120,000,000 $$60,000,000 $120,000,000 $120,000,000 $120,000,000 $120,000,000 $$47,000,000 $117,500,000 $305,500,000

$80,000,000 $80,000,000 $80,000,000 

$5,160,347 $18,061,216 $46,443,126 $130,000,000 $130,000,000 $

$318,000,000

$42,000,000 $42,000,000 $42,000,000 

$34,914,691 $77,000,000 $77,000,000 $77,000,000 

$100,000,000

$3,000,000 $3,000,000 $3,000,000 $3,000,000 $3,000,000 

$10,979,462 $14,000,000 $14,000,000 $14,000,000 $14,000,000 $14,000,000 

$780,000,000

$360,000,000 $360,000,000 $360,000,000 $360,000,000 $

$85,639,807 $450,000,000 $450,000,000 $450,000,000 $450,000,000 $

$330,000,000 $825,000,000 $2,145,000,000

$300,000,000 $300,000,000 $300,000,000 $300,000,000 $

$36,232,226 $710,000,000 $710,000,000 $710,000,000 $710,000,000 $$83,000,000 $83,000,000 $83,000,000 $83,000,000 $83,000,000 

$8,000,000 $16,000,000 $24,000,000 $32,000,000 

$9,112,954 $18,000,000 $36,000,000 $54,000,000 $72,000,000 

$270,000,000 $675,000,000 $1,

$180,000,000 $

$470,000,000 $470,000,000 $

$78,000,000 $195,000,000 $507,000,000

$100,000,000 $100,000,000 $

$8,563,981 $29,973,933 $180,000,000 $180,000,000 $

$28,000,000 $28,000,000 $28,000,000 

$4,000,000 $8,000,000 

$3,074,249 $7,000,000 $14,000,000 

Initial Capital Cost $0 $0 $160,000,000 $2,800,000,000 $3,200,000,000 $7,270,000,000 $950,000,000 $790,000,000 $1,Annual O&M Cost $0 $0 $0 $80,000,000 $1,000,000,000 $2,200,000,000 $2,300,000,000 $2,500,000,000 $2,Total Annual Cost $0 $0 $10,000,000 $2,200,000,000 $3,500,000,000 $3,600,000,000 $4,300,000,000 $4,400,000,000 $4,

= Expected Final Rule Timing

Capital costs for rules with 3-year compliance windows (e.g., MACT) spread out assuming 10% in Year 1, 25% in Year 2, 65% in Year 3.

Boiler GACTBoiler MACTP&P MACT II revisions/RTR

(assume variable applicability timing per proposed rule)

CISWICAIR for industrial boilers/ recovery boilersPM2.5 NAAQS fully implementedSSM goes away under MACTRegional HazeNSPS Subpart BB updateH2S listed as HAPOzone NAAQS loweredWood Products NSPSP&P MACT I revisions/RTRSO2 NAAQS loweredNOx NAAQS loweredPCWP MACT revisions/RTR
Appendix A

Cost Estimate Summaries
Combined Summary of Forest Products Industry Air Regulatory Cost Impacts

Updated 8/17/2011

Rule

Initial Capital 

Cost

Initial Annual 

Operating Cost

Total Annual 

Cost

Reopen Pulp and Paper MACTs $4,080,000,000 $660,000,000 $1,200,000,000

CAIR for Industrial Boilers/ Recovery 

Furnaces $470,000,000 $80,000,000 $130,000,000

Boiler MACT/CISWI/Boiler GACT $7,000,000,000 $1,100,000,000 $1,900,000,000

H2S HAP listing $2,700,000,000 $180,000,000 $470,000,000

Wood Products MACT revsions $780,000,000 $100,000,000 $180,000,000

SSM revisions $100,000,000 $3,000,000 $14,000,000

NAAQS revisions $1,200,000,000 $49,000,000 $100,000,000

Other Rules $180,000,000 $310,000,000 $410,000,000

Total $16,500,000,000 $2,500,000,000 $4,400,000,000

Capital Annual Capital Annual

Assuming 50% of mills could comply with 

PM and HCl using HBCA: $829,726,380 $156,451,238 $226,211,712 $29,727,589

Assuming 90% of mills could comply with 

PM and HCl using HBCA: $1,493,507,483 $281,612,228 $407,181,082 $53,509,660

Note - the HBCA savings analysis does not differentiate between fuel. If a metals HBCA is not feasible for

a coal or oil fired boiler because manganese is the only pollutant that can be evaluated and excluded from

TSM, then the pool of boilers that would benefit from PM/metals HBCA would be smaller.

Note that the initial capital cost and the initial annual operating cost represent the cost for the initial number of 

units/facilities subject to the rule. For some rules, the number of units subject will increase over time (e.g., NSPS).

Pulp and Paper Wood Products

Potential savings with HBCA under Boiler MACT
Costs of Clean Air Rules for the Forest Products Industry

Updated 8/17/2011Organized by Rule:

Rule

Industrial Boilers 

- Initial Cost

Industrial Boilers 

- Initial Annual 

Operating Cost

Industrial Boilers - 

Total Annual Cost

Wood Products 

Sources - Initial 

Cost

Wood Products 

Sources - Initial 

Annual 

Operating Cost

Wood 

Products 

Sources - Total 

Annual Cost

Pulp and Paper 

Mills - Initial Cost

Pulp and Paper 

Mills - Initial 

Annual Operating 

Cost

Pulp and Paper 

Mills - Total 

Annual Cost

Ind

In

Boiler MACT $3,700,000,000 $290,000,000 $700,000,000 $3,Boiler GACT $10,000,000 $9,000,000 $9,000,000 $

CISWI $3,250,000,000 $805,000,000 $1,160,000,000 $3,

CAIR for industrial boilers/ recovery boilers $0 $0 $0 $470,000,000 $77,000,000 $130,000,000 $4Ozone NAAQS lowered $0 $0 $0 $32,000,000 $5,000,000 $8,500,000 $92,000,000 $1,500,000 $12,000,000 $1NOx NAAQS lowered $607,000,000 $141,900,000 $209,000,000 $2,500,000 $0 $300,000 $11,000,000 $0 $1,500,000 $6SO2 NAAQS lowered $100,000,000 $20,000,000 $31,000,000 $40,000,000 $7,500,000 $12,000,000 $1CPMS Rule $0 $69,000,000 $69,000,000 $0 $35,000,000 $35,000,000 $0 $12,000,000 $12,000,000 PM2.5 NAAQS fully implemented $180,000,000 $26,000,000 $45,000,000 $18,000,000 $0 $2,200,000 $120,000,000 $16,000,000 $30,000,000 $3Regional Haze $60,000,000 $7,500,000 $14,000,000 $32,000,000 $3,600,000 $7,100,000 $PCWP MACT revisions/RTR $780,000,000 $95,000,000 $180,000,000 $7SSM goes away under MACT $0 $0 $0 $100,000,000 $3,000,000 $14,000,000 $1Wood Products NSPS $28,000,000 $4,000,000 $7,000,000 $P&P MACT I revisions/RTR $780,000,000 $360,000,000 $450,000,000 $7P&P MACT II revisions/RTR $3,300,000,000 $300,000,000 $710,000,000 $3,NSPS Subpart BB update $83,000,000 $8,000,000 $18,000,000 $H2S listed as HAP $2,700,000,000 $180,000,000 $470,000,000 $2,Total Regulatory Cost $7,900,000,000 $1,370,000,000 $2,200,000,000 $860,000,000 $140,000,000 $230,000,000 $7,700,000,000 $1,000,000,000 $1,900,000,000 $16Cost by Sector With Boiler Rule Costs Allocated to Wood Products and Pulp and Paper by Rule

Rule

Wood Products 

Initial Cost

Wood Products 

Initial Annual 

Operating Cost

Wood Products 

Total Annual Cost

Pulp and Paper 

Initial Cost

Pulp and Paper 

Initial Annual 

Operating Cost

Pulp and 

Paper Total 

Annual Cost

Boiler MACT $900,000,000 $50,000,000 $140,000,000 $2,800,000,000 $240,000,000 $550,000,000Boiler GACT $10,000,000 $7,000,000 $7,000,000 $1,000,000 $1,000,000 $1,000,000CISWI $2,049,000,000 $615,000,000 $840,000,000 $1,200,000,000 $190,000,000 $320,000,000CAIR for industrial boilers/ recovery boilers $0 $0 $0 $470,000,000 $80,000,000 $130,000,000

Ozone NAAQS lowered $32,200,000 $5,000,000 $9,000,000 $95,000,000 $2,000,000 $12,000,000NOx NAAQS lowered $32,800,000 $7,000,000 $10,000,000 $590,000,000 $140,000,000 $200,000,000SO2 NAAQS lowered $5,000,000 $1,000,000 $2,000,000 $139,000,000 $26,000,000 $41,000,000CPMS Rule $0 $69,000,000 $69,000,000 $0 $46,000,000 $46,000,000

PM2.5 NAAQS fully implemented $26,400,000 $2,000,000 $4,500,000 $284,000,000 $40,000,000 $71,000,000Regional Haze $3,000,000 $400,000 $700,000 $89,000,000 $11,000,000 $21,000,000PCWP MACT revisions/RTR $780,000,000 $90,000,000 $180,000,000 $0 $0 $0

SSM goes away under MACT $0 $0 $0 $100,000,000 $3,000,000 $14,000,000Wood Products NSPS $28,000,000 $4,000,000 $7,000,000 $0 $0 $0

P&P MACT I revisions/RTR $0 $0 $0 $780,000,000 $360,000,000 $450,000,000P&P MACT II revisions/RTR $0 $0 $0 $3,340,000,000 $300,000,000 $710,000,000NSPS Subpart BB update $0 $0 $0 $83,000,000 $8,000,000 $18,000,000

H2S listed as HAP $0 $0 $0 $2,650,000,000 $180,000,000 $470,000,000Total Regulatory Cost $3,800,000,000 $860,000,000 $1,270,000,000 $12,600,000,000 $1,600,000,000 $3,000,000,000

Note that the initial capital cost and the initial annual operating cost represent the cost for the initial number of units/facilities subject to the rule. For some rules, the number of units subject will increase over time (e.g., NSPS). For costs over time, see the timeline ta
List of Possible Controls for 

Control Technology Unit Costs (

1. Scrubber (acid gases, H2S and SO2) $4 

2. ESPs or ESP upgrade (metals and PM) $3 

3. Carbon injection (mercury) $1

4. Oxidation catalysts (CO) $1‐

5. SNCR or SCR (NOx) $4 

6. Low NOx burner or combustion controls $0

7. Steam stripper/incinerator (VOCs/organic HAPs) $2

8. Fabric Filter (mercury/metals/PM) $7

9. Fuel switching (numerous pollutants) $1‐

10. Ducting sources to existing controls (HAPs) $2

11. Redesigned wastewater treatment (H2S) $3

12. Redesign Recovery Furnaces (organic HAPs) $20

TOTAL COST PER MILL* $25 M to $1

*depends on existing controls, type of mill/equipment and number of units affected
Summary of Benefits and Disbenefits of Various Control Strategies

Control Strategy Pollutants Reduced Collateral Increases/Impacts/Disbenefits

Scrubber on 

combustion unit SO2, acid gases, Hg

Installation of a scrubber on a combustion unit would likely require a bigger fan to pull 

the gases through the scrubber (increased electricity) and would increase water usage 

at the facility. Increased water usage is counter to the sustainability goals of many 

facilities. Many river systems have recently experienced record low flow due to 

extended drought periods, along with increasing competition from various 

upstream/downstream uses (municipalities, recreation, power generation, aquatic 

habitat). Depending on the water source, additional fresh water usage may not be 

feasible. If caustic is required, this is a high operating cost for facilities where a source 

of caustic is not available onsite. Scrubbers also produce wastewater and sludge that 

must be disposed of.

Reduce biomass 

burning to reduce CO CO

The forest products industry often produces steam and energy using renewable 

energy sources, such as biomass. Many facilities generate their own fuel from onsite 

operations such as log debarking, sawing, and sanding. Replacing biomass fuel with 

fossil fuel in an effort to reduce CO emissions would be contrary to our national goal to 

reduce our dependence on fossil fuels and increase generation of power through 

combustion of renewable fuels. Biomass is considered a "carbon neutral" fuel under 

many greenhouse gas reporting protocols because it is formed by removing carbon 

from the atmosphere. Therefore, replacing biomass fuels with fossil fuels would 

increase the concentration of CO2 in the atmosphere. Disposal of biomass generated 

during the production process at forest products facilities becomes problematic, 

consuming enormous amounts of space and eventually releasing methane during the 

natural decay process, a greenhouse gas 21 times more potent than CO2 released 

during combustion.

Install catalyst to 

reduce CO emissions CO

Catalyst oxidizes CO to CO2, so it increases greenhouse gas emissions instead of 

reducing emissions per the national goal.

Oxidizer on wood 

products or pulp and 

paper unit VOC/organic HAP

Installing an oxidizer increases auxiliary fuel usage (e.g, natural gas) and creates 

emissions of NOx, CO, and CO2 when the fuel is burned and the VOC compounds are 

oxidized. In areas where ground level ozone formation is NOx limited (e.g., Southeast 

US), this is contrary to the goal of reducing ground level ozone formation. This 

approach also is contrary to the goal of reducing fossil fuel usage.

Steam stripper

VOC/organic HAP, 

TRS

Installing a steam stripper to remove VOC/HAP/TRS from condensates prior to 

sending them to WWTP results in collateral emissions increases from burning these 

gases (NOx if ammonia is present and SO2 from burning TRS). The steam stripper 

operation also increases energy usage. If a mill is steam limited, a package boiler 

may have to be purchased to provide the steam.

Eliminate use of 

condensates in pulp 

mill/causticizing and 

use fresh water

VOC/organic HAP, 

TRS

Eliminating recycle of condensates within the mill will increase a mill's usage of fresh 

water, which may or may not be feasible, depending on the water supply. Many river 

systems have recently experienced record low flow due to extended drought periods, 

along with increasing competition from various upstream/downstream uses 

(municipalities, recreation, power generation, aquatic habitat). Energy use will also 

increase if the fresh water must be heated.

Increase the percent 

reduction required 

under PCWP MACT 

from 90% to 95% VOC/organic HAP

Increasing the percent reduction required under PCWP MACT would have the effect of 

eliminating the use of biofilters and RCOs. Facilities would have to convert RCOs to 

RTOs or replace biofilters with RTOs in order to achieve a higher percent reduction on 

a consistent basis. Increase in use of RTOs would increase natural gas usage and 

emissions of NOx, CO, and CO2. In areas where ground level ozone formation is NOx 

limited (e.g., Southeast US), this is contrary to the goal of reducing ground level ozone 

formation. This approach also is contrary to the goal of reducing fossil fuel usage.

Install biofilters to 

achieve HAP 

reductions at currently 

uncontrolled PCWP 

sources. VOC/organic HAP

Biofilters typically require a large footprint, especially when dealing with large air flows. 

The incoming air may need to be treated to adjust for moisture, temperature, or 

entrained particulate. Biofilters may not be feasible in cold climates. If there is a 

problem with the biological media, it takes time to get back to well-controlled 

conditions. If a faciltiy is shutdown for an extended period due to market conditions or 

other reasons, biofilter microbes will require replacement. Biofilters do not control all 

VOC compounds. Biofilters convert VOC and organic HAP into CO2.

SCR on boiler NOx

Installation of SCR on industrial boilers is generally not cost effective. SCR has very 

high initial and operating costs. Reheating of the flue gas may be required for SCR to 

work properly, which increases energy usage. A large volume of both catalyst and 

reagent (ammonia) are required. There are safety issues associated with storage and 

handling of ammonia, and ammonia slip can occur, which can impact plume visibility. 

The spent catalyst must be disposed of following replacement, creating a solid waste. 

If adequate particulate controls are not in place prior to the SCR, catalyst poisoning 

can also occur, and catalyst poisoning/fouling exacerbates the ammonia slip issue. 

The catalyst also oxidizes SO2 to SO3 (leading to sulfate formation, potentially 

impacting visibility) and CO to CO2.
Appendix B

Cost Estimates by Category and Regulatory Action
Costs of Clean Air Rules for the Forest Products Industry

Rule/Timing Pollutant Control

 Initial Investment 

per Unit 

Number of Units 

Upgraded/ 

Additional Units 

Affected

% Probability Total Cost (initial investment) 

 Annualized 

Capital Cost per 

Unit 

 Total Annualized 

Capital Cost 

 Typical Annual 

Operating Cost 

per Unit 

 Total Annualized 

Operating Cost 

 Total Annualized 

Cost 

 Cost Per 

Facility 

 Collateral 

Emissions/ 

Energy 

Increases 

 Estimated 

CO2 

increases, 

metric tons 

Boiler MACT HCl Scrubber (coal) 8,479,228 $ 65 551,149,820 $ 930,974 $ 60,513,288 $ 1,500,000 $ 97,500,000 $ 158,013,288 $ 4,861,947 $ water

Based on Bburning "trad

HCl Scrubber (wood) - $ 0 - $ - $ - $ 1,000,000 $ - $ - $ #DIV/0! water

Based on Bburning "trad

HCl Scrubber (gas2) - $ 0 - $ - $ - $ - $ - $ - $ - $ water Based on B

HCl Scrubber (oil) 6,896,710 $ 54 $ 372,422,340 $ 757,222 $ 40,889,971 $ 1,000,000 $ 54,000,000 $ 94,889,971 $ 3,514,443 water

Based on Bburning "trad

PM/metals

Upgrade existing controls or add FF (wood) $ 4,441,848 215 $ 954,997,320 $ 487,691 $ 104,853,572 $ 77,000 $ 16,555,000 $ 121,408,572 $ 1,129,382

Based on Bburning "trad

PM/metals

Upgrade existing controls or add FF (coal) $ 5,601,456 45 $ 252,065,520 $ 615,010 $ 27,675,439 $ 194,000 $ 8,730,000 $ 36,405,439 $ 1,618,020

Based on Bburning "trad

PM/metals

Upgrade existing controls or add FF (oil) $ 5,994,297 59 $ 353,663,523 $ 658,142 $ 38,830,354 $ 300,000 $ 17,700,000 $ 56,530,354 $ 1,916,283

Based on Bburning "trad

PM/metals Add FF (gas2) $ - 0 $ - $ - $ - $ - $ - $ - $ - Based on B

Mercury/ dioxin

Carbon injection (coal) $ 1,000,000 98 $ 98,000,000 $ 109,795 $ 10,759,873 $ 420,000 $ 41,160,000 $ 51,919,873 $ 1,059,589

Based on Bburning "tradparticulate cfollowing ca

Mercury/ dioxin

Carbon injection (wood) $ 1,000,000 253 $ 253,000,000 $ 109,795 $ 27,778,040 $ 211,000 $ 53,383,000 $ 81,161,040 $ 641,589

Based on Bburning "tradparticulate cfollowing ca

Mercury/ dioxin

Carbon injection (gas2) $ - 0 $ - $ - $ - $ - $ - $ - $ - Based on B

Mercury/ dioxin

Carbon injection (oil) $ 1,000,000 55 $ 55,000,000 $ 109,795 $ 6,038,704 $ 28,000 $ 1,540,000 $ 7,578,704 $ 275,589

Based on Bburning "tradparticulate cfollowing ca

CO

CO catalyst or combustion improvements (coal) $ 3,008,120 45 $ 135,365,400 $ 330,275 $ 14,862,393 $ - $ 14,862,393 - $ $ 660,551 CO2

Based on Bburning "trad

CO

CO catalyst or combustion improvements (wood) $ 2,341,248 214 $ 501,026,978 $ 257,056 $ 55,010,069 $ - $ 55,010,069 - $ $ 514,113 CO2

Based on Bburning "trad

CO

CO Catalyst - Gas2 (landfill gas) $ - 0 $ - $ - $ - $ - $ - $ - -$ CO2

CO

CO catalyst or combustion improvements (oil) $ 2,616,873 57 $ 149,161,761 $ 287,319 $ 16,377,160 $ - $ 16,377,160 - $ $ 574,637 CO2 4,782

Based on Bburning "tradassume avg AP-42 CO opercent con

All Energy audit $ 75,000 442 $ 33,150,000 $ 75,000 $ 33,150,000

$ 3,709,002,662 $ 436,738,863 $ 290,568,000 $ 694,156,863 note - cost 

Industrial Boilers at Forest Products Facilities

Expected timing: reproposal Oct 2011, final Apr 2012 
Costs of Clean Air Rules for the Forest Products Industry

Rule/Timing Pollutant Control

 Initial Investment 

per Unit 

Number of Units 

Upgraded/ 

Additional Units 

Affected

% Probability Total Cost (initial investment) 

 Annualized 

Capital Cost per 

Unit 

 Total Annualized 

Capital Cost 

 Typical Annual 

Operating Cost 

per Unit 

 Total Annualized 

Operating Cost 

 Total Annualized 

Cost 

 Cost Per 

Facility 

 Collateral 

Emissions/ 

Energy 

Increases 

 Estimated 

CO2 

increases, 

metric tons 

Industrial Boilers at Forest Products Facilities

Boiler GACT PM/metals Fabric Filter 500,000 $ 0 - $ - $ - $ - $ - $ - $ -$ 

No PM limits rule. Only 2 known.

Mercury

Carbon injection following FF 1,000,000 $ 0 - $ - $ - $ - $ - $ - $ -$ 

No Hg limits rule. Only 2 known.

CO/POM Tune-up 2,219 $ 1200 2,662,800 $ - $ 2,219 $ 2,662,800 $ 2,662,800 $ 4,438 $ Assumes all CO/POM Energy audit $ 5,000 1200 $ 6,000,000 $ - $ 5,000 $ 6,000,000 $ 6,000,000 $ 10,000

Assumes newill no longe

assumes req

CO/POM

Combustion controls (wood) 500,000 $ 0 $ - $ - $ - $ - $ - $ - -$ 

may increase 

NOx

No controls limits for exis

CO/POM LBMS $ 20,000 0 $ - $ - $ - $ - $ - $ - -$ 

No controls limits for exis

$ -

$ 8,662,800 $ - $ 8,662,800 $ 8,662,800 note - cost 

CISWI SO2/acid gas Scrubber $ 12,414,444 39 $ 484,163,333 $ 1,363,039 $ 53,158,531 $ 1,500,000 $ 58,500,000 $ 111,658,531 $ 2,863,039 water

PM/metals/ dioxin Fabric Filter $ 6,701,895 74 $ 495,940,248 $ 735,832 $ 54,451,573 $ 194,000 $ 14,356,000 $ 68,807,573 $ 929,832

Mercury Carbon injection 1,000,000 $ 112 $ 112,000,000 $ 109,795 $ 12,296,998 $ 420,000 $ 47,040,000 $ 59,336,998 $ 529,795

NOx SNCR $ 2,610,540 50 $ 130,527,013 $ 286,623 $ 14,331,164 $ 1,200,000 $ 60,000,000 $ 74,331,164 -$ 

NOx SCR $ 8,000,000 0 $ - $ - $ - $ - $ - $ - -$ ammoniaCO CO catalyst $ 3,445,537 23 $ 79,247,343 $ 378,301 $ 8,700,932 $ - $ - $ 8,700,932 $ 378,301 CO2 19,295

Area source boiler controls $ 7,800,000 165 $ 1,287,000,000 $ 856,398 $ 141,305,682 $ 2,500,000 $ 412,500,000 $ 553,805,682 $ 3,356,398 CO2

assumes 1/3 secondary m

Sanderdust dryers controls $ 7,800,000 85 $ 663,000,000 $ 856,398 $ 72,793,836 $ 2,500,000 $ 212,500,000 $ 285,293,836 $ 3,356,398 CO2

assumes 85 resinated wo

$ - $ - $ - $ -

$ 3,251,877,937 $ 357,038,718 $ 804,896,000 $ 1,161,934,718 note - cost p

NOx NAAQS NOx

Combustion controls $ 500,000 85 $ 42,500,000 $ 54,897 $ 4,666,272 $ - $ - $ 4,666,272 $ 54,897

Assumes liqclose to NAA 

New 1-hour standard NOx SNCR $ 4,000,000 115 $ 460,000,000 $ 439,178 $ 50,505,527 $ 1,200,000 $ 138,000,000 $ 188,505,527 $ 1,639,178

Assumes fathat are projan SCR.

Final Jan 2010, designations 2012, implementation 2013 NOx SCR $ 8,000,000 13 $ 104,000,000 $ 878,357 $ 11,418,641 $ 301,000 $ 3,913,000 $ 15,331,641 $ 1,179,357 ammonia

Assumes fathat are closSNCR

$ 606,500,000 $ 66,590,440 $ 141,913,000 $ 208,503,440 note - cost p

Ozone NAAQS NOx

Combustion controls $ 500,000 $ - $ - $ - $ - $ - $ - -$ 

NOx SNCR $ 4,000,000 $ - $ - $ - $ - $ - $ - -$ 

NOx SCR $ 8,000,000 $ - $ - $ - $ - $ - $ - -$ ammonia

More NA Areas NOx/VOC

More complex permitting/ permitting for more sources $ 40,000 80 $ 3,200,000 $ 4,392 $ 351,343 $ - $ 351,343 $ 4,392

The permitticomplex for become SerTitle V (50 tp

$ 3,200,000 $ 351,343 $ - $ 351,343 note - cost p

Addresse

Assumes bomaterials suresiduals, TDunder CISW

Expected timing: reproposal Oct 2011, final Apr 2012 Timing: Final Rule 

March 2011August 2011 for 

possible new lower standard, designations 2012, implementation 2014
Costs of Clean Air Rules for the Forest Products Industry

Rule/Timing Pollutant Control

 Initial Investment 

per Unit 

Number of Units 

Upgraded/ 

Additional Units 

Affected

% Probability Total Cost (initial investment) 

 Annualized 

Capital Cost per 

Unit 

 Total Annualized 

Capital Cost 

 Typical Annual 

Operating Cost 

per Unit 

 Total Annualized 

Operating Cost 

 Total Annualized 

Cost 

 Cost Per 

Facility 

 Collateral 

Emissions/ 

Energy 

Increases 

 Estimated 

CO2 

increases, 

metric tons 

Industrial Boilers at Forest Products Facilities

SO2 NAAQS SO2 Scrubber 8,000,000 $ 13 104,000,000 $ 878,357 $ 11,418,641 $ 1,500,000 $ 19,500,000 $ 30,918,641 $ 4,756,714 $ water

Remaining cto need scru

New 1-hour standard final 2010, designations 2012, implementation 2013 SO2

Low sulfur fuel/ fuel switch 0 - $ - $ - $ - $ - $ -$ 

Any boiler blikely have bBMACT/CIS

$ 11,418,641 104,000,000 $ 19,500,000 $ 30,918,641 $ 

CAIR/CSAPR for industrial boilers SO2 Wet Scrubber 8,000,000 $ 0 - $ - $ - $ - $ - $ - $ -$ water Covered abo

PM ESP $ 5,000,000 0 $ - $ - $ - $ - $ - $ - $ electricity 0 Covered abo

-

NOx

combustion controls $ 500,000 0 $ - $ - $ - $ - $ - $ - $ - Covered abo

NOx SNCR $ 4,000,000 0 $ - $ - $ - $ - $ - $ - $ - Covered aboNOx SCR $ 8,000,000 0 $ - $ - $ - $ - $ - $ - -$ ammonia Covered abo

$ - $ - $ - $ - note - cost 

Continuous Parametric Monitoring System Rule Shutdown to QA 600 $ - $ - $ - $ 100,000 $ 60,000,000 $ 60,000,000 $ 100,000

Shutdown 4 put cost for 100 kraft miwould be 60

in new MACT rules

Effort required to comply 600 $ - $ - $ - $ 15,000 $ 9,000,000 $ 9,000,000 $ 15,000

One facility's manpower r

$ - $ - $ 69,000,000 $ 69,000,000

PM2.5 NAAQS fully implemented PM2.5 ESP/FF upgrade 3,000,000 $ 5 $ 15,000,000 $ 329,384 $ 1,646,919 $ 65,000 $ 325,000 $ 1,971,919 $ 394,384 1,690

Assumes onachieve low MACT or CIto meet PM2calculated uincrease/yr/uCO2/MWh. 

PM2.5 WESP $ 10,000,000 10 $ 100,000,000 $ 1,097,946 $ 10,979,462 $ 1,800,000 $ 18,000,000 $ 28,979,462 $ 2,897,946 water

A few boilers 

or other con

NOx SNCR 4,000,000 $ 5 20,000,000 $ 439,178 $ 2,195,892 $ 1,200,000 $ 6,000,000 $ 8,195,892 $ 1,639,178 $ 

Assumes uncan't model NAAQS and to reduce ni

2011 NOx SCR 8,000,000 $ 5 40,000,000 $ 878,357 $ 4,391,785 $ 301,000 $ 1,505,000 $ 5,896,785 $ 1,179,357 $ ammonia

Assumes uncan't model NAAQS and to reduce ni

NOx

Combustion controls $ 500,000 5 $ 2,500,000 $ 54,897 $ 274,487 $ - $ - $ 274,487 $ 54,897

Assumes uncan't model NAAQS and to reduce ni

SO2 Scrubber $ 8,000,000 0 $ - $ 878,357 $ 1,500,000 - $ $ - $ - water

Any boiler blikely have babove.

SO2 Low sulfur fuel 0 $ - $ - $ - $ - $ -

Any boiler blikely have babove.

$ 177,500,000 $ 19,488,546 $ 25,830,000 $ 45,318,546 note - cost p

EPA working on CAIR replacement 3 - proposal and final 2012, implement 2015
Costs of Clean Air Rules for the Forest Products Industry

Rule/Timing Pollutant Control

 Initial Investment 

per Unit 

Number of Units 

Upgraded/ 

Additional Units 

Affected

% Probability Total Cost (initial investment) 

 Annualized 

Capital Cost per 

Unit 

 Total Annualized 

Capital Cost 

 Typical Annual 

Operating Cost 

per Unit 

 Total Annualized 

Operating Cost 

 Total Annualized 

Cost 

 Cost Per 

Facility 

 Collateral 

Emissions/ 

Energy 

Increases 

 Estimated 

CO2 

increases, 

metric tons 

Industrial Boilers at Forest Products Facilities

Regional Haze SO2 Scrubber 8,000,000 $ 0 - $ 878,357 $ - $ 1,500,000 $ - $ - $ water

Any boiler blikely have babove.

SO2 Low sulfur fuel 0 - $ - $ - $ - $ - $ 

Any boiler blikely have babove.

PM ESP 5,000,000 $ 0 - $ 548,973 $ - $ 77,000 $ - $ - $ electricity 0

Probably adabove

NOx SNCR 4,000,000 $ 5 20,000,000 $ 439,178 $ 2,195,892 $ 1,200,000 $ 6,000,000 $ 8,195,892 $ 1,639,178 $ 

Assumes smdidn't get cahave to instareductions

NOx SCR $ 8,000,000 5 $ 40,000,000 $ 878,357 $ 4,391,785 $ 301,000 $ 1,505,000 $ 5,896,785 $ 1,179,357 ammonia

Assumes smdidn't get cahave to instareductions

$ 60,000,000 $ 6,587,677 $ 7,505,000 $ 14,092,677 note - cost p

Total Regulatory Cost $ 7,920,743,399 $ 898,214,228 $ 1,367,874,800 $ 2,232,939,028 25,767

700 sawmills Capital Recovery Factor Calcuation for Annualized Costs:

300 converting Interest Equipment

300 wood products Rate Life, yrs CRF

400 pulp and paper 12 semi chem, 20 newsprint100 of which are kraft 7.00% 15 0.110

Cost per facility for MACT, GACT, CAIR assumes 2 boilers per facilityBART -additional control to meet milestones following 2018
Costs of Clean Air Rules for the Forest Products Industry

Rule/Timing Pollutant Control

 Initial Investment

per Unit 

Number of Units 

Upgraded/ 

Additional Units 

Affected

% Probability Total Cost (initial investment) 

 Annualized 

Capital Cost per 

Unit 

 Total 

Annualized 

Capital Cost 

 Typical Annual 

Operating Cost 

per Unit 

 Total 

Annualized 

Operating Cost 

 Total 

Annualized 

Cost 

 Cost Per 

Facility 

 Collateral 

Emissions/ 

Energy 

Increases 

 Estimated 

CO2 

increases, 

metric tons 

Ozone NAAQS NOx

LNB - direct fired units 500,000 $ 10 5,000,000 $ 54,897 $ 548,973 $ - $ - $ 548,973 $ 54,897 $ 

Assumes unitneed NOx redhave to install 

$ - - $ - $ - $ - $ 

VOC Oxidizer 5,000,000 $ 5 25,000,000 $ 548,973 $ 2,744,866 $ 1,000,000 $ 5,000,000 $ 7,744,866 $ 1,548,973 $ energy, NOx 9,225

Assumes a neto be installed at 5 plants in increase calcunatural gas*87CO2/MMBtu (

More NA Areas NOx/VOC

More complex permitting/ permitting for more sources $ 40,000 50 $ 2,000,000 $ 4,392 $ 219,589 $ - $ 219,589 - $ $ 4,392

The permitting complex for fabecome SerioV (50 tpy).

$ 32,000,000 $ 3,513,428 $ 5,000,000 $ 8,513,428

NOx NAAQS NOx

LNB - direct fired units $ 500,000 5 $ 2,500,000 $ 54,897 $ 274,487 $ - $ 274,487 - $ $ 54,897

Assumes unitcan't model coNAAQS and hon a direct fire

New 1-hour standard Final Jan 2010, designations 2012, impl. 2013 $ - $ - $ -

$ 2,500,000 $ 274,487 $ 274,487 - $ 

Continuous Parametric Monitoring System Rule Shutdown to QA 300 $ - $ - $ - $ 100,000 $ 30,000,000 $ 30,000,000 $ 100,000 Shutdown 4 ti

As part of MACT/ NSPS revs

Effort required to comply 300 $ - $ - $ - $ 15,000 $ 4,500,000 $ 4,500,000 $ 15,000

One facility's emanpower req

$ - $ - $ 34,500,000 $ 34,500,000

PM2.5 NAAQS fully implemented PM2.5 ESP upgrade $ 3,000,000 5 $ 15,000,000 $ 329,384 $ 1,646,919 $ 65,000 $ 325,000 $ 1,971,919 $ 394,384 electricity 338

Assumes unitcan't model coand have to ucomply. CO2 MWh additionavg 0.676 MT 

October 2011 NOx

LNB - direct fired units $ 500,000 5 $ 2,500,000 $ 54,897 $ 274,487 $ - $ 274,487 - $ $ 54,897

Assumes unitcan't model coand have to infired unit to im

$ 17,500,000 $ 1,921,406 $ 325,000 $ 2,246,406

PCWP MACT redo and remand VOHAP Catalytic Oxidizer 5,000,000 $ 85 $ 425,000,000 $ 548,973 $ 46,662,715 $ 1,000,000 $ 85,000,000 $ 1,548,973 131,662,715 $ energy, NOx 156,833

Assumes a neto be installed 1 for half of exfacilities. CO2 MMBtu/hr natCO2/MMBtu (

minimal residual risk costs VOHAP Biofilter $ 3,000,000 85 $ 255,000,000 $ 329,384 $ 27,997,629 $ 100,000 $ 8,500,000 $ 36,497,629 $ 429,384

Assumes a neinstalled to cohalf of existing facilities

ICR 2011, rule late 2013 VOHAP Enclosure $ 500,000 170 $ 85,000,000 $ 54,897 $ 9,332,543 $ 5,000 $ 850,000 $ 10,182,543 $ 59,897

Assumes encsources not cavg of 1 new 170 major sou

Sierra Club petition to redo MACTs VOHAP

Work practices - lumber kilns $ 55,000 225 $ 12,375,000 $ 6,039 $ 1,358,708 $ 1,300 $ 292,500 $ 1,651,208 $ 7,339

Assumes 225 have to implepractices on lupractice imple

meters for lum

VOHAP

Work practices - wood products mills 10,000 $ 170 1,700,000 $ 1,098 $ 186,651 $ 1,300 $ 221,000 $ 407,651 $ 2,398 $ 

Assumes 170 plants will havon units withoInitial cost incimplementatiosetting up rec

$ - - $ 

$ 85,538,247 779,075,000 $ 94,863,500 $ 180,401,747 $ 

Wood Products Plant Sources (Other Than Boilers)

Note - assumes no lumber kiln control, existing control requirement remains 90% instead of increasing and forcing conversion of RCO to RTOAugust 2011 for possible new lower standard, designations 2012, implementation 2014
Costs of Clean Air Rules for the Forest Products Industry

Rule/Timing Pollutant Control

 Initial Investment

per Unit 

Number of Units 

Upgraded/ 

Additional Units 

Affected

% Probability Total Cost (initial investment) 

 Annualized 

Capital Cost per 

Unit 

 Total 

Annualized 

Capital Cost 

 Typical Annual 

Operating Cost 

per Unit 

 Total 

Annualized 

Operating Cost 

 Total 

Annualized 

Cost 

 Cost Per 

Facility 

 Collateral 

Emissions/ 

Energy 

Increases 

 Estimated 

CO2 

increases, 

metric tons 

Wood Products Plant Sources (Other Than Boilers)

SSM exemption changes HAP

Shutdown process instead of vent - $ 0 - $ - $ - $ - $ - $ - $ 

Plan maintenaequipment if mnot change cuduring SSM e

Assumes RDCME will remain and operation will not be significantly impacted HAP

Duct to backup control $ 2,000,000 0 $ - $ 219,589 $ - $ - $ - $ -

Assumes it is backup controductwork onlyoption.

HAP

Install backup control $ 5,000,000 0 $ - $ 548,973 $ - $ - $ - $ - energy, NOx 0

Cost of installprocess does primary contro

$ -

$ - $ - $ - $ -

Wood Products NSPS PM WESP $ 5,000,000 5 $ 25,000,000 $ 548,973 $ 2,744,866 $ 800,000 $ 4,000,000 $ 6,744,866 $ 1,348,973 water 1,690

Assumes mills capacity and wPM controls dWESP to contcaptured by ocalculated usielectricity/yr/uCO2/MWh.

Reviewing need for NSPS for plywood/wood products, scope uncertain NOx

LNB - direct fired units $ 500,000 5 $ 2,500,000 $ 54,897 $ 274,487 $ - $ 274,487 - $ $ 54,897

Assumes mills capacity and wNOx controls 

Possible rule 2013 $ - $ - $ - $ - $ -

$ 27,500,000 $ 3,019,352 $ 4,000,000 $ 7,019,352

Total Regulatory Cost $ 858,575,000 $ 94,266,920 $ 138,688,500 $ 158,861 232,955,420

700 sawmills, approx 221 are major Capital Recovery Factor Calcuation for Annualized Costs:300 wood products, approx 170 are major Interest Equipment

Rate Life, yrs CRF

72 softwood plywood plants

7.00% 15 0.110
Costs of Clean Air Rules for the Forest Products Industry

Rule/Timing Pollutant Control

 Initial Investment

per Unit 

Number of Units 

Upgraded/ 

Additional Units 

Affected

% Probability Total Cost (initial investment) 

 Annualized 

Capital Cost per 

Unit 

 Total 

Annualized 

Capital Cost 

 Typical Annual 

Operating Cost 

per Unit 

 Total 

Annualized 

Operating Cost 

 Total 

Annualized 

Cost 

 Cost Per 

Facility 

 Collateral 

Emissions/ 

Energy 

Increases 

 Estimated 

CO2 

increases, 

metric tons 

Wood Products Plant Sources (Other Than Boilers)

Example Cost Analysis just for control of dry dryers under PCWP MACT (estimated 40 dry dryers at 31 plants):

Catalytic Oxidizer 5,000,000 $ 16 80,000,000 $ 548,973 $ 8,783,570 $ 350,000 $ 5,600,000 $ 14,383,570 $ 898,973 $ energy, NOx 29,522

Assumes a neto be installed of 31 facilities CO2 increase natural gas*87CO2/MMBtu (

Biofilter 3,000,000 $ 15 45,000,000 $ 329,384 $ 4,940,758 $ 35,000 $ 525,000 $ 5,465,758 $ 364,384 $ 

Assumes a neinstalled to cofacilities will c

Enclosure 500,000 $ 31 15,500,000 $ 54,897 $ 1,701,817 $ 5,000 $ 155,000 $ 1,856,817 $ 59,897 $ 

New enclosurwith dry dryer

$ 15,426,145 140,500,000 $ 6,280,000 $ 21,706,145 $ 
Costs of Clean Air Rules for the Forest Products Industry

Rule/Timing Pollutant Control

 Initial 

Investment per 

Unit 

Number of Units 

Upgraded/ 

Additional Units 

Affected

% Probability Total Cost (initial investment) 

 Annualized 

Capital Cost 

per Unit 

 Total Annualized 

Capital Cost 

Typical Annual 

Operating Cost 

per Unit 

 Total Annualized 

Operating Cost 

 Total Annualized 

Cost 

 Cost Per 

Facility 

 Collateral 

Emissions/ 

Energy 

Increases 

 Estimated 

CO2 

increases, 

metric tons 

P&P Cluster MACT I / III redo VOHAP Steam strippers 2,000,000 $ 25 50,000,000 $ 219,589 $ 5,489,731 $ 2,400,000 $ 60,000,000 $ 65,489,731 $ 2,619,589 $ energy 1,872,023

Assinstreducoa86.0EF)

Minimal residual risk costs - 2011 VOHAP

Paper machine controls 3,400,000 $ 200 680,000,000 $ 373,302 $ 74,660,345 $ 1,500,000 $ 300,000,000 $ 374,660,345 $ 3,746,603 $ energy 369,019

Asssort macchamacmay faciincrnatuCO2

Sierra Club petition to redo MACTs VOHAP

Pipe additional sources to combustion 2,000,000 $ 25 50,000,000 $ 219,589 $ 5,489,731 $ - $ - $ 5,489,731 $ 219,589 $ 

If Crequwasinci

$ 85,639,807 780,000,000 $ 360,000,000 $ 445,639,807 $ 

P&P MACT II redo HCl Scrubber 8,000,000 $ 120 960,000,000 $ 878,357 $ 105,402,840 $ 1,500,000 $ 180,000,000 $ 285,402,840 $ 3,805,371 $ water

Asson 7

Minimal residual risk costs - 2011 Organic HAP

BLOX control -RTO/scrubber 8,000,000 $ 27 50% 108,000,000 $ 878,357 $ 23,715,639 $ 500,000 $ 13,500,000 $ 37,215,639 $ 2,756,714 $ 

energy/ 

water 49,818

AssconinstCO2 MMkg C

Organic HAP

Recovery BoilerDCE to NDCE conversion 20,000,000 $ 26 50% 260,000,000 $ 2,195,892 $ 57,093,205 $ - $ - $ 57,093,205 $ 4,391,785 $ 

Assreconew Alteless 

Organic HAP

Organic HAP limits for lime kilns $ 2,000,000 40 $ 80,000,000 $ 219,589 $ 8,783,570 $ 1,200,000 $ 48,000,000 $ 56,783,570 $ 1,419,589

fresh water, 

heat loss 1,497,618

AssconareastripCO2 to mCO2MM

Organic HAP

Organic HAP limits for lime kilns $ 75,000 40 $ 3,000,000 $ 8,235 $ 329,384 $ - $ - $ 329,384 $ 8,235

Assconareaano

Organic HAP

Organic HAP limits for semi-chem mills 8,000,000 $ 5 $ 40,000,000 $ 878,357 $ 4,391,785 $ - $ 4,391,785 $ 878,357 energy 9,225

AssrecosmaincrnatuCO2

RTR proposal 2011; final 2012 Hg/dioxin

Carbon Injection plus fabric filter - lime kilns $ 8,000,000 108 $ 864,000,000 $ 878,357 $ 94,862,556 $ 222,000 $ 23,976,000 $ 118,838,556 $ 1,584,514

Assneediox

Hg/dioxin

Carbon Injection plus fabric filter - recovery boilers $ 8,000,000 121 $ 968,000,000 $ 878,357 $ 106,281,197 $ 222,000 $ 26,862,000 $ 133,143,197 $ 1,775,243

Assneediox

Sierra Club petition to redo MACTs PM/HAP

Smelt Tank Scrubber $ 500,000 81 $ 40,500,000 $ 54,897 $ 4,446,682 $ 75,000 $ 6,075,000 $ 10,521,682 $ 210,434 water

Ass

be nlowno lrecoHAP 

PM/HAP

PM limits for sulfite and semi-chem mills 3,000,000 $ 7 21,000,000 $ 329,384 $ 2,305,687 $ 65,000 $ 455,000 $ 2,760,687 $ 394,384 $ 

Asswill 

PM/HAP RB ESP upgrades 3,000,000 $ - $ 329,384 $ - $ 65,000 $ - $ - $ -$ energy 0

ProexisHg/

PM/HAP LK ESP upgrades 3,000,000 $ - $ 329,384 $ - $ 65,000 $ - $ - $ -$ energy 0

ProexisHg/

$ 407,612,544 3,344,500,000 $ 298,868,000 $ 706,480,544 $ 

Pulp and Paper Sources (Other Than Power Boilers)

Note - assumes that 

installing RTO is not a 

control option to 

reduce lime kiln 

organic HAP 

emissions due to cost
Costs of Clean Air Rules for the Forest Products Industry

Rule/Timing Pollutant Control

 Initial 

Investment per 

Unit 

Number of Units 

Upgraded/ 

Additional Units 

Affected

% Probability Total Cost (initial investment) 

 Annualized 

Capital Cost 

per Unit 

 Total Annualized 

Capital Cost 

Typical Annual 

Operating Cost 

per Unit 

 Total Annualized 

Operating Cost 

 Total Annualized 

Cost 

 Cost Per 

Facility 

 Collateral 

Emissions/ 

Energy 

Increases 

 Estimated 

CO2 

increases, 

metric tons 

Pulp and Paper Sources (Other Than Power Boilers)

NSPS Subpart BB NOx

LNB/Combustion Controls 500,000 $ 10 5,000,000 $ 54,897 $ 548,973 $ - $ - $ 548,973 $ 54,897 $ 

AssNSP

NOx SCR 8,000,000 $ 1 8,000,000 $ 878,357 $ 878,357 $ 301,000 $ 301,000 $ 1,179,357 $ 1,179,357 $ ammonia

AssNSPthat 

Part of integrated P&P rulemaking (2011?) SO2 Scrubber 8,000,000 $ 5 40,000,000 $ 878,357 $ 4,391,785 $ 1,500,000 $ 7,500,000 $ 11,891,785 $ 2,378,357 $ water

AssNSP

SO2 Low sulfur fuel 5 - $ - $ - $ - $ - $ -$ 

AssNSP

PM ESP upgrade 3,000,000 $ 10 30,000,000 $ 329,384 $ 3,293,839 $ 65,000 $ 650,000 $ 3,943,839 $ 394,384 $ 3,380

AssNSPincrelec0.67

$ 9,112,954 83,000,000 $ 8,451,000 $ 17,563,954 $ 

SSM exemption changes HAP

Shutdown process instead of venting during APCD malfunction or maintenance 100 - $ - $ - $ - $ - $ -$ 

Facopeinstvento smal

Changes in mill operation to account for loss of compliance exemption during SSM HAP

Duct to backup control $ 2,000,000 10 $ 20,000,000 $ 219,589 $ 2,195,892 $ - $ - $ 2,195,892 $ 219,589

Assan ecos

Assumes venting and APCD excursion allowances do not go away in Subparts S and MM. HAP

Install backup control (e.g., RTO/ scrubber for HVLC) 8,000,000 $ 10 $ 80,000,000 $ 878,357 $ 8,783,570 $ 300,000 $ 3,000,000 $ 11,783,570 $ energy, 1,178,357 NOx 18,451

Cosso pwheincrnatuCO2

$ - $ - $ - $ - $ -

$ 100,000,000 $ 10,979,462 $ 3,000,000 $ 13,979,462

Continuous Parametric Monitoring System Rule Shutdown to QA 100 $ - $ - $ 100,000 $ 10,000,000 $ 10,000,000 $ 100,000 Shu

As part of MACT/ 

NSPS revs

Effort required to comply 100 - $ - $ 15,000 $ 1,500,000 $ 1,500,000 $ 15,000 $ 

One man

$ - - $ 11,500,000 $ 11,500,000 $ 

Ozone NAAQS NOx Combustion controls 500,000 $ 50 25,000,000 $ 54,897 $ 2,744,866 $ - $ - $ 2,744,866 $ 54,897 $ 

Assconredu

NOx SCR 8,000,000 $ 5 40,000,000 $ 878,357 $ 4,391,785 $ 301,000 $ 1,505,000 $ 5,896,785 $ 1,179,357 $ ammonia

Assas a redufeas

VOC Oxidizer 5,000,000 $ 5 25,000,000 $ 548,973 $ 2,744,866 $ - $ 2,744,866 $ 548,973 $ energy, NOx 9,225

May areaNOxMMkg C

More NA areas NOx/VOC

More complex permitting/ permitting for more sources 40,000 $ 50 2,000,000 $ 4,392 $ 219,589 $ - $ - $ 219,589 $ 4,392 $ 

The combecTitle 

$ 10,101,105 92,000,000 $ 1,505,000 $ 11,606,105 $ 

CAIR Replacement SO2 Wet Scrubber 8,000,000 $ 50 400,000,000 $ 878,357 $ 43,917,850 $ 1,500,000 $ 75,000,000 $ 118,917,850 $ 2,378,357 $ water

AssCAI

PM ESP upgrade 3,000,000 $ 5 15,000,000 $ 329,384 $ 1,646,919 $ 65,000 $ 325,000 $ 1,971,919 $ 394,384 $ energy 1,690

AssCAICOelec0.67

NOx Combustion controls 500,000 $ 25 $ 12,500,000 $ 54,897 $ 1,372,433 $ - $ - $ 1,372,433 $ 54,897

AssCAI(uni

NOx SCR $ 8,000,000 5 $ 40,000,000 $ 878,357 $ 4,391,785 $ 301,000 $ 1,505,000 $ 5,896,785 $ ammonia 1,179,357

AssCAI(and 

$ 467,500,000 $ 51,328,987 $ 76,830,000 $ 128,158,987

EPA working on CAIR replacement 3 - proposal and final 2012, implement 2015August 2011 for possible new lower standard, designations 2012, implementation 2014
Costs of Clean Air Rules for the Forest Products Industry

Rule/Timing Pollutant Control

 Initial 

Investment per 

Unit 

Number of Units 

Upgraded/ 

Additional Units 

Affected

% Probability Total Cost (initial investment) 

 Annualized 

Capital Cost 

per Unit 

 Total Annualized 

Capital Cost 

Typical Annual 

Operating Cost 

per Unit 

 Total Annualized 

Operating Cost 

 Total Annualized 

Cost 

 Cost Per 

Facility 

 Collateral 

Emissions/ 

Energy 

Increases 

 Estimated 

CO2 

increases, 

metric tons 

Pulp and Paper Sources (Other Than Power Boilers)

NOx NAAQS NOx

LNB/Combustion Controls 500,000 $ 5 2,500,000 $ 54,897 $ 274,487 $ - $ - $ 274,487 $ 54,897 $ 

AsscanNAAcon

New 1-hour standard proposed June 2009; Final Jan 2010, designations 2012 NOx SCR 8,000,000 $ 1 8,000,000 $ 878,357 $ 878,357 $ 301,000 $ 301,000 $ 1,179,357 $ 1,179,357 $ ammonia

AsscanNAANOx 

$ 1,152,844 10,500,000 $ 301,000 $ 1,453,844 $ 

SO2 NAAQS SO2 Scrubber 8,000,000 $ 5 40,000,000 $ 878,357 $ 4,391,785 $ 1,500,000 $ 7,500,000 $ 11,891,785 $ 2,378,357 $ water

AsscanNAA

New 1-hour standard final 2010, designations 2012, implementation 2013 SO2 Low sulfur fuel 10 - $ - $ - $ - $ - $ -$ 

AsscanNAAfuel

$ 4,391,785 40,000,000 $ 7,500,000 $ 11,891,785 $ 

PM2.5 NAAQS fully implemented PM2.5 ESP upgrade 3,000,000 $ 5 15,000,000 $ 329,384 $ 1,646,919 $ 65,000 $ 325,000 $ 1,971,919 $ 394,384 $ energy 1,690

AsscanNAARB calcincrCO2

October 2011 NOx SCR 8,000,000 $ 1 8,000,000 $ 878,357 $ 878,357 $ 301,000 $ 301,000 $ 1,179,357 $ 1,179,357 $ ammonia

AsscanNAAto reis fe

NOx

LNB/Combustion Controls 500,000 $ 5 2,500,000 $ 54,897 $ 274,487 $ - $ - $ $ 274,487 $ 54,897

AsscanNAAto re

SO2 Scrubber $ 8,000,000 10 $ 80,000,000 $ 878,357 $ 8,783,570 $ 1,500,000 $ 15,000,000 $ 23,783,570 $ water 2,378,357

AsscanNAAto reredu

SO2 Low sulfur fuel $ 2,000,000 5 $ 10,000,000 $ 219,589 $ 1,097,946 $ - $ 1,097,946 $ 219,589

AsscanNAAfuel

$ 115,500,000 $ 12,681,279 $ 15,626,000 $ 28,307,279
Costs of Clean Air Rules for the Forest Products Industry

Rule/Timing Pollutant Control

 Initial 

Investment per 

Unit 

Number of Units 

Upgraded/ 

Additional Units 

Affected

% Probability Total Cost (initial investment) 

 Annualized 

Capital Cost 

per Unit 

 Total Annualized 

Capital Cost 

Typical Annual 

Operating Cost 

per Unit 

 Total Annualized 

Operating Cost 

 Total Annualized 

Cost 

 Cost Per 

Facility 

 Collateral 

Emissions/ 

Energy 

Increases 

 Estimated 

CO2 

increases, 

metric tons 

Pulp and Paper Sources (Other Than Power Boilers)

H2S listed as HAP H2S Scrubber 4,000,000 $ 50 200,000,000 $ 439,178 $ 21,958,925 $ 750,000 $ 37,500,000 $ 59,458,925 $ 1,189,178 $ water

Instemi

Sierra Club letter sent 3/09 H2S

Duct additional sources to control 2,000,000 $ 50 100,000,000 $ 219,589 $ 10,979,462 $ - $ - $ 10,979,462 $ 219,589 $ 

SO2 from 

combustion

Asssouconexis

H2S

Tall Oil System H2S limits - scrubber upgrade 200,000 $ 30 6,000,000 $ 21,959 $ 658,768 $ - $ - $ 658,768 $ 21,959 $ 

Asswill accWowou

H2S

Discontinue use of condensates as water at uncontrolled sources - $ 10 - $ - $ - $ - $ - $ - $ -$ 

incr fresh 

water use, 

heat loss

H2S elimreplthat Conor s

H2S WWTP upgrades 35,000,000 $ 67 2,345,000,000 $ 3,842,812 $ 257,468,395 $ 2,170,000 $ 145,390,000 $ 402,858,395 $ 6,012,812 $ 

trucking 

sludge to 

landfill

AssconMills and not 

H2S Steam stripper 2,000,000 $ 0 - $ 219,589 $ - $ 1,200,000 $ - $ - $ energy 0

InstprefconmakMA

$ 291,065,550 2,651,000,000 $ 182,890,000 $ 473,955,550 $ 

Regional Haze SO2 Scrubber 8,000,000 $ 2 16,000,000 $ 878,357 $ 1,756,714 $ 1,500,000 $ 3,000,000 $ 4,756,714 $ 2,378,357 $ water

Assscruscru

SO2 Low sulfur fuel 2 - $ - $ - $ - $ - $ -$ 

Assabo

PM ESP 5,000,000 $ - $ 548,973 $ - $ 77,000 $ - $ $ - electricity 0

adeach

NOx SCR $ 8,000,000 2 $ 16,000,000 $ 878,357 $ 1,756,714 $ 301,000 $ 602,000 $ 2,358,714 $ ammonia 1,179,357

AssneeSCR 

$ 32,000,000 $ 3,513,428 $ 3,602,000 $ 7,115,428

Total Regulatory Cost $ 7,716,000,000 $ 887,579,746 $ 970,073,000 $ 1,857,652,746 3,832,139

300 converting plants Capital Recovery Factor Calcuation for Annualized Costs:

400 pulp and paper facilities Interest Equipment

100 of which are kraft Rate Life, yrs CRF

56 DCE recovery boilers 7.00% 15 0.110

112 NDCE recovery boilers144 lime kilns

BART -additional control to meet milestones following 2018
Appendix C

Detailed Boiler MACT Cost Spreadsheets
FacilityID UnitID Unit CountMajor Source State ClassificatioCapacity (mCmapacity_Numeri Hours Per Year Installe Combustor Design Duty Cycle w NOx BurnAeCT Fuel Catego Baseline Fuel Cat Total Control Coal % Biomass % Liquid % Gas 2 %

F

ALAbitibiBowaterCP Power Boiler #1 1

MajorSource AL Boiler 300 300 8760 0 PC False Coal Coal

ElectrostaticPrecipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

ALAbitibiBowaterCP Power Boiler #2 1

MajorSource AL Boiler 300 300 8760 0 PC False Coal Coal

ElectrostaticPrecipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

ALAbitibiBowaterCP Power Boiler #3 1

MajorSource AL Boiler 300 300 8760 0 PC False Coal Coal

ElectrostaticPrecipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

ALAbitibiBowaterCP Power Boiler #4 1

MajorSource AL Boiler 300 300 8760 0 PC False Coal Coal

ElectrostaticPrecipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

ALBoiseWhitePaperJackson 102‐0001‐Z013 1

MajorSource AL Boiler 435 435 8400 1964 Stoker/SlopedGrate/Other Base‐loaded False Biomass Wet Biomass Venturi Scrubber 0 96.23577545 3.764224548 0 96

ALBrewton SB‐1 1

MajorSource AL Boiler 68 68 8700 1974 Stoker/SlopedGrate/Other Base‐loaded False Biomass Wet Biomass Cyclone or Multiclone 0 100 0 0 

ALChapmanForestProducts

EU 001 Wood FiredBoiler 1

MajorSource AL Boiler 86.25 86.25 8760 1974 Stoker/SlopedGrate/Other load following False Biomass Wet Biomass Venturi Scrubber 0 100 0 0 

ALChapmanForestProducts

EU 002 Wood FiredBoiler 1

MajorSource AL Boiler 47.38 47.38 8760 1993 Stoker/SlopedGrate/Other load following False Biomass Wet Biomass Venturi Scrubber 0 100 0 0 

ALChapmanForestProducts

EU 003 Wood FiredBoiler 1

MajorSource AL Boiler 47.38 47.38 8760 1967 Stoker/SlopedGrate/Other load following False Biomass Wet Biomass Venturi Scrubber 0 100 0 0 

ALGeorgiaPacificNaheola Z015 ‐ CB1 1

MajorSource AL Boiler 425 425 8760 1958 Stoker/SlopedGrate/Other load following False Biomass Wet Biomass

ElectrostaticPrecipitator 38.6035845 61.3964155 0 0 61

ALGeorgiaPacificNaheola Z016 ‐ CB2 1

MajorSource AL Boiler 318 318 8760 1962 Stoker/SlopedGrate/Other load following False Biomass Wet Biomass

ElectrostaticPrecipitator 56.1006735 43.89932654 0 0 56

ALGeorgiaPacificNaheola Z017 ‐ PB3 1

MajorSource AL Boiler 379 379 5000 1970 N/A load following False Liquid Heavy Liquid No HAP APCD Control 0 0 100 0 

ALGPBelkLumber

EU 001 Wood FiredBoiler 1

MajorSource AL Boiler 69 69 8760 1974 Stoker/SlopedGrate/Other load following False Biomass Wet Biomass

ElectrostaticPrecipitator 0 100 0 0 

ALGPBrewtonMill

BR‐PSG0‐S021 No.

2 Power Boiler 1

MajorSource AL Boiler 390 390 8640 1963 Stoker/SlopedGrate/Other Base‐loaded True Biomass Wet Biomass

ElectrostaticPrecipitator 0 79.53986768 0 0 79

ALGPBrewtonMill

BR‐PSG0‐S026 No.

3 Power Boiler 1

MajorSource AL Boiler 608 608 8640 1981 Stoker/SlopedGrate/Other Base‐loaded True Biomass Wet Biomass

ElectrostaticPrecipitator 0 100 0 0 

ALGPBrewtonMill

BR‐PSG0‐S018 No.

1 Power Boiler 1

MajorSource AL Boiler 289 289 2880 1956 N/A load following False Liquid Light Liquid No HAP APCD Control 0 0 34.32321744 0 

ALGPEngineeredWoodProductsThornsby

EU 001 Wood FiredBoiler 1

MajorSource AL Boiler 61.77 61.77 8760 1979 Stoker/SlopedGrate/Other load following False Biomass Wet Biomass Wet Scrubber 0 100 0 0 

ALGPPetermanPly

EU001 Woodwaste

Boilerw/Multiclone and 1

MajorSource AL Boiler 224 224 8305 1977 Stoker/SlopedGrate/Other load following False Biomass Wet Biomass

Electrostatic

Precipitator 0 0 00 

ALGPTalladegaPly

EU001 Wood

Waste Boiler w

Multiclone and ESP 1

MajorSource AL Boiler 185 185 8520 1975 Stoker/SlopedGrate/Other load following False Biomass Wet Biomass

Electrostatic

Precipitator 0 0 00 

ALGulfLumber Boiler #1 1

MajorSource AL Boiler 68 68 7500 1983 Stoker/SlopedGrate/Other False Biomass Wet Biomass Wet Scrubber

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

ALIPCourtland

No.2 Combination

Boiler / 11CU201 1

MajorSource AL Boiler 735 735 8511 1979 PC load following False Coal Coal

Dry

ScrubberElectrostaticPrecipitator 0 0 00 

ALIPCourtland

No. 1 Combination

Boiler / 11CU101 1

MajorSource AL Boiler 398 398 1437 1970 Stoker/SlopedGrate/Other Standby False Biomass Wet Biomass Venturi Scrubber 0 0 00 

ALIPCourtland

No. 3 Combination

Boier / 11CU301 1

MajorSource AL Boiler 710 710 8291 1993 FB Base‐loaded True Biomass Wet Biomass

Electrostatic

Precipitator 0 87.74449361 3.710686781 0 87

ALIPPineHill 109‐0001‐Z010 1

MajorSource AL Boiler 770 770 8400 1968 PC Base‐loaded False Coal Coal

ElectrostaticPrecipitator 0 0 00 

ALIPPineHill 109‐0001‐Z007 1

MajorSource AL Boiler 705 705 8400 1968 Stoker/SlopedGrate/Other load following False Biomass Wet Biomass

ElectrostaticPrecipitator 0 0 00 

ALIPPrattville Z008 1

MajorSource AL Boiler 630 630 8471 1980 Stoker/SlopedGrate/Other load following False Biomass Wet Biomass

ElectrostaticPrecipitator 33.2403294 66.75967059 0 0 66

ALIPPrattville Z006 1

MajorSource AL Boiler 707 707 8553 1967 Stoker/SlopedGrate/Other load following False Biomass Wet Biomass

ElectrostaticPrecipitator 0 80.61485909 0 0 80

ALIPRiverdale

No. 1 Bark Boiler /

BK01 1

MajorSource AL Boiler 245 245 8400 1979 Stoker/SlopedGrate/Other load following True Biomass Wet Biomass Venturi Scrubber 0 0 00 

ALK‐CMobile Bark Boiler #7 1

MajorSource AL Boiler 750 750 8760 0 Stoker/SlopedGrate/Other False Coal Coal Venturi Scrubber

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

ALK‐CMobile Power Boiler #6 1

MajorSource AL Boiler 500 500 8760 0 PC False Coal Coal

ElectrostaticPrecipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

ALManningtonWoodFloors BB01 1

MajorSource AL Boiler 28.2 28.2 8760 1991 Stoker/SlopedGrate/Other Base‐loaded False Biomass Wet Biomass

Electrostatic

Precipitator 0 100 0 0 

ALManningtonWoodFloors BB02 1

MajorSource AL Boiler 28.2 28.2 8760 2005 Stoker/SlopedGrate/Other Base‐loaded False Biomass Wet Biomass

Electrostatic

Precipitator 0 100 0 0 

ALMeadwestvacoCottonton46

No.1 WoodResidue Boiler 1

MajorSource AL Boiler 337 337 8520 1966 Stoker/SlopedGrate/Other load following False Biomass Wet Biomass Venturi Scrubber 0 0 00 

ALMeadwestvacoCottonton46

No.2 WoodResidue Boiler 1

MajorSource AL Boiler 550 550 8520 1981 Stoker/SlopedGrate/Other load following False Biomass Wet Biomass

ElectrostaticPrecipitator 0 0 00 

ALMeadwestvacoCottonton46

No.3 WoodResidue Boiler 1

MajorSource AL Boiler 915 915 8520 1990 Stoker/SlopedGrate/Other load following False Biomass Wet Biomass Venturi Scrubber 0 0 00 

ALP&WAlabamaRiver Power Boiler #1 1

MajorSource AL Boiler 440 440 8760 0 Stoker/SlopedGrate/Other False Biomass Wet Biomass Venturi Scrubber

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

ALP&WAlabamaRiver Power Boiler #2 1

MajorSource AL Boiler 190 190 8760 0 Stoker/SlopedGrate/Other False Biomass Wet Biomass

Electrostatic

Precipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

ALP&WAlabamaRiver Power Boiler #3 1

MajorSource AL Boiler 440 440 8760 0 Stoker/SlopedGrate/Other False Biomass Wet Biomass Venturi Scrubber

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

ALRock‐TennDemopolis Power Boiler #3 1

MajorSource AL Boiler 250 250 8760 0 Stoker/SlopedGrate/Other False Coal Coal Venturi Scrubber

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

ALRock‐TennDemopolis Power Boiler #1 1

MajorSource AL Boiler 225 225 8760 0 Stoker/SlopedGrate/Other False Biomass Wet Biomass Venturi Scrubber

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

ALScotchLumber

EU 001 (Wood‐Fired Boiler) 1

MajorSource AL Boiler 98.5 98.5 8400 1988 Stoker/SlopedGrate/Other load following False Biomass Wet Biomass Cyclone or Multiclone 0 100 0 0 

ALSeamanTimber 1 1

MajorSource AL Boiler 28.7 28.7 7500 1996 Stoker/SlopedGrate/Other Base‐loaded False Biomass Dry Biomass Cyclone or Multiclone

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 
FacilityID UnitID Unit CountMajor Source State ClassificatioCapacity (mCmapacity_Numeri Hours Per Year Installe Combustor Design Duty Cycle w NOx BurnAeCT Fuel Catego Baseline Fuel Cat Total Control Coal % Biomass % Liquid % Gas 2 %

F

ALSmurfit‐Stone Waste Boiler #1 1

MajorSource AL Boiler 225 225 8760 0 Stoker/SlopedGrate/Other False Biomass Wet Biomass

Wet Electrostatic

Precipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

ALSmurfit‐Stone Waste Boiler #2 1

MajorSource AL Boiler 375 375 8760 0 Stoker/SlopedGrate/Other False Biomass Wet Biomass

Electrostatic

Precipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

ALSmurfit‐Stone Power Boiler #1 1

MajorSource AL Boiler 170 170 8760 0 N/A False Liquid Heavy Liquid

Wet

ScrubberWetElectrostatic Precipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

ALSmurfit‐Stone Power Boiler #2 1

MajorSource AL Boiler 170 170 8760 0 N/A False Liquid Heavy Liquid

Wet

ScrubberWetElectrostatic Precipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

ALWestervelt Wellons ‐ Unit 001 1

MajorSource AL Boiler 98 98 8200 1997 Stoker/SlopedGrate/Other Base‐loaded True Biomass Wet Biomass

Electrostatic

Precipitator 0 100 0 0 

ALWestervelt Teaford ‐ Unit 003 1

MajorSource AL Boiler 99 99 8400 2006 Stoker/SlopedGrate/Other load following True Biomass Dry Biomass

Electrostatic

Precipitator 0 100 0 0 

ALWestFraserCitronelle Boiler‐1 1

MajorSource AL Boiler 90 90 7800 1973 Stoker/SlopedGrate/Other load following False Biomass Wet Biomass Wet Scrubber 0 100 0 0 

ALWestFraserMaplesville Boiler‐1 1

MajorSource AL Boiler 119 119 8708 1974 Stoker/SlopedGrate/Other load following False Biomass Wet Biomass Venturi Scrubber 0 100 0 0 

ALWeyerhaeuserMillport Boiler No. 1 1

MajorSource AL Boiler 115 115 8100 1973 Stoker/SlopedGrate/Other load following False Biomass Dry Biomass No HAP APCD Control 0 100 0 0 

ARAnthonyForestProducts SN‐12 1

MajorSource AR Boiler 29.56 29.56 8592 1997 Fuel Cell load following False Biomass Wet Biomass Cyclone or Multiclone 0 100 0 0 

ARAnthonyForestProducts SN‐13 1

MajorSource AR Boiler 29.56 29.56 8592 1997 Fuel Cell load following False Biomass Wet Biomass Cyclone or Multiclone 0 100 0 0 

ARAnthonyForestProducts SN‐16 1

MajorSource AR Boiler 29.75 29.75 8592 2002 Fuel Cell load following False Biomass Wet Biomass Cyclone or Multiclone 0 100 0 0 

ARDeltaNaturalKraft

Hog Fuel Boiler (SN‐

05) 1

MajorSource AR Boiler 160 160 8600 1976 Stoker/SlopedGrate/Other Base‐loaded False Biomass Dry Biomass Cyclone or Multiclone 0 100 0 0 

ARDelticTimberWaldo

Wood Fired Boiler

No. 1 (SN‐13) 1

MajorSource AR Boiler 60 60 8760 1995 Stoker/SlopedGrate/Other Base‐loaded False Biomass Wet Biomass

ElectrostaticPrecipitator 0 100 0 0 

ARDelticTimberWaldo

Wood Fired Boiler

No. 2 (SN‐14) 1

MajorSource AR Boiler 60 60 8760 1995 Stoker/SlopedGrate/Other Base‐loaded False Biomass Wet Biomass

ElectrostaticPrecipitator 0 100 0 0 

ARDelticTimberWaldo

Wood Fired Boiler

No. 3 (SN‐20) 1

MajorSource AR Boiler 60 60 8760 2005 Stoker/SlopedGrate/Other Base‐loaded False Biomass Wet Biomass

ElectrostaticPrecipitator 0 100 0 0 

ARDel‐Tin SN‐05 1

MajorSource AR Boiler 291 291 8760 1997 Stoker/SlopedGrate/Other load following False Biomass Dry Biomass

Electrostatic

Precipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

ARDomtarIndustries PB2 1

Major Source AR Boiler 820 820 8520 1975 Stoker/SlopedGrate/Other load following Coal Coal Wet Scrubber

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

ARDomtarIndustries PB1 1

Major Source AR Boiler 580 580 8049 1967 Stoker/SlopedGrate/Other load following Biomass Wet Biomass

Electrostatic Precipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

ARDomtarIndustries PB3 1

Major Source AR Boiler 790 790 8160 1990 Stoker/SlopedGrate/Other load following Biomass Wet Biomass

Electrostatic Precipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

AREvergreenPackaging BB 1

MajorSource AR Boiler 500 500 8570 1958 Stoker/SlopedGrate/Other Base‐loaded True Biomass Dry Biomass Venturi Scrubber 0 100 0 0 

AREvergreenPackaging PB1 1

MajorSource AR Boiler 600 600 6000 1958 N/A Base‐loaded True Liquid Heavy Liquid No HAP APCD Control 0 0 40.5398746 0 

ARGBPMorrilton SN‐02 1

MajorSource AR Boiler 162 162 2880 1968 Stoker/SlopedGrate/Other Base‐loaded False Biomass Wet Biomass Cyclone or Multiclone 0 100 0 0 

ARGBPMorrilton SN‐04 1

MajorSource AR Boiler 452 452 8400 1965 Stoker/SlopedGrate/Other Base‐loaded True Biomass Wet Biomass Venturi Scrubber 0 100 0 0 

ARGeorgiaPacificCrossett93

SN‐WB1 WoodBoiler 1

MajorSource AR Boiler 245 245 8400 1981 Stoker/SlopedGrate/Other load following False Biomass Dry Biomass Wet Scrubber 0 100 0 0 

ARGeorgiaPacificCrossett93

SN‐WB2 WoodBoiler 1

MajorSource AR Boiler 245 245 8400 1981 Stoker/SlopedGrate/Other load following False Biomass Dry Biomass

Electrostatic

Precipitator 0 100 0 0 

ARGeorgiaPacificFordyce

SN ‐ 01 Wood Fuel

Boiler 1

MajorSource AR Boiler 185 185 8147 1974 Stoker/SlopedGrate/Other load following False Biomass Dry Biomass Wet Scrubber 0 100 0 0 

ARGPCrossett92 SN‐03 1

MajorSource AR Boiler 1001 1001 8400 1984 Stoker/SlopedGrate/Other Base‐loaded True Biomass Wet Biomass Wet Scrubber 0 100 0 0 

ARGPCrossett92 SN‐22 1

MajorSource AR Boiler 720 720 8500 1973 Stoker/SlopedGrate/Other load following True Biomass Wet Biomass Wet Scrubber 0 0 00 

ARGPFordyceOSB

SN ‐ 01A ThermalOil Heaters (#1) 1

MajorSource AR

ProcessHeater 40 40 8000 1999 Dutch Oven/Susp. Burner load following False Biomass Dry Biomass No HAP APCD Control

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

ARGPFordyceOSB

SN ‐ 01A ThermalOil Heaters (#2) 1

MajorSource AR

ProcessHeater 40 40 8000 1999 Dutch Oven/Susp. Burner load following False Biomass Dry Biomass No HAP APCD Control

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

ARGPGurdonPlyLumber

SN 02 No. 2 Wood

Residue FiredBoiler 1

MajorSource AR Boiler 135 135 8400 1979 Stoker/SlopedGrate/Other load following False Biomass Dry Biomass Venturi Scrubber 0 100 0 0 

ARGPGurdonPlyLumber

SN 01 No. 1 Wood

Residue FiredBoiler 1

MajorSource AR Boiler 135 135 8640 1979 Stoker/SlopedGrate/Other load following False Biomass Dry Biomass Venturi Scrubber 0 100 0 0 

ARLeolaLumberMill SN‐01A 1

MajorSource AR Boiler 94.15 94.15 8400 1994 Stoker/SlopedGrate/Other load following False Biomass Dry Biomass

Electrostatic

Precipitator 0 100 0 0 

ARLeolaLumberMill SN‐01B 1

MajorSource AR Boiler 94.15 94.15 8400 1994 Stoker/SlopedGrate/Other load following False Biomass Dry Biomass

Electrostatic

Precipitator 0 100 0 0 

ARLeolaLumberMill SN‐19 1

MajorSource AR Boiler 28.8 28.8 8400 1999 Stoker/SlopedGrate/Other load following False Biomass Wet Biomass Cyclone or Multiclone

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

ARPotlatchForestCypressBend Power Boiler #1 1

MajorSource AR Boiler 479 479 8700 1976 N/A load following True Liquid Heavy Liquid No HAP APCD Control 0 0 00 

ARPotlatchForestPrescott McBurney Boiler 1

MajorSource AR Boiler 175 175 8400 1996 Stoker/SlopedGrate/Other load following False Biomass Dry Biomass

Electrostatic

Precipitator 0 100 0 0 

ARPotlatchForestWarren Wellons Boiler 1

MajorSource AR Boiler 280 280 8400 1990 Stoker/SlopedGrate/Other Base‐loaded False Biomass Dry Biomass

ElectrostaticPrecipitator 0 100 0 0 

ARRiversideFurniturePlant5

SN‐01 Wood‐fired

Boiler 1

MajorSource AR Boiler 19.5 19.5 8760 1987 Stoker/SlopedGrate/Other Base‐loaded False Biomass Dry Biomass Cyclone or Multiclone 0 100 0 0 

ARTemple‐Inland PWBTHERM48 1

MajorSource AR

ProcessHeater 40 40 5600 1994 Dutch Oven/Susp. Burner load following False Biomass Dry Biomass No HAP APCD Control

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

ARTemple‐Inland PDTHERM48 1

MajorSource AR

ProcessHeater 40 40 6150 1994 Dutch Oven/Susp. Burner load following False Biomass Dry Biomass No HAP APCD Control

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 
FacilityID UnitID Unit CountMajor Source State ClassificatioCapacity (mCmapacity_Numeri Hours Per Year Installe Combustor Design Duty Cycle w NOx BurnAeCT Fuel Catego Baseline Fuel Cat Total Control Coal % Biomass % Liquid % Gas 2 %

F

ARTemple‐Inland HTFTHERM48 1

MajorSource AR

ProcessHeater 40 40 7100 1994 Dutch Oven/Susp. Burner load following False Biomass Dry Biomass No HAP APCD Control

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

ARWestFraserHuttig SN‐24 1

MajorSource AR Boiler 29.63 29.63 8290 2004 Stoker/SlopedGrate/Other Base‐loaded False Biomass Wet Biomass Cyclone or Multiclone 0 100 0 0 

ARWestFraserHuttig SN‐01 1

MajorSource AR Boiler 118 118 8650 1972 Stoker/SlopedGrate/Other Base‐loaded False Biomass Wet Biomass Cyclone or Multiclone 0 100 0 0 

ARWeyerhaeuser SN‐06 1

MajorSource AR Boiler 78.5 78.5 8520 1972 Stoker/SlopedGrate/Other load following False Biomass Dry Biomass No HAP APCD Control 0 100 0 0 

ARWeyerhaeuserDierksMill SN‐45 1

MajorSource AR Boiler 249 249 8400 1997 Fuel Cell load following False Biomass Dry Biomass

Electrostatic

Precipitator 0 100 0 0 

AZCatalystPaperSnowflake

Power Boiler #2

Coal 1

MajorSource AZ Boiler 1132 1132 8640 1975 PC load following False Coal Coal

Wet

ScrubberElectrostaticPrecipitator 100 0 0 0 

AZCatalystPaperSnowflake

Power Boiler #3

Natural Gas 1

MajorSource AZ Boiler 337 337 8400 2002 N/A Standby True Liquid Light Liquid No HAP APCD Control

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

CAHumboldtFlakeboard143 NS‐028 1

MajorSource CA Boiler 40 40 6000 1971 Stoker/SlopedGrate/Other Base‐loaded False Biomass Dry Biomass No HAP APCD Control 0 0 00 

CARoseburgWeed Boiler 1

MajorSource CA Boiler 169.74 169.74 8400 1996 Stoker/SlopedGrate/Other load following False Biomass Wet Biomass

ElectrostaticPrecipitator 0 100 0 0 

CASierraPine‐Rocklin SPRKBL01 1

MajorSource CA Boiler 71.7 71.7 8424 1976 Dutch Oven/Susp. Burner load following False Biomass Dry Biomass

Venturi

ScrubberElectrostaticPrecipitator 0 0 00 

FLCFRC252

Boiler #3

(McBurney) 1

MajorSource FL Boiler 85 85 8592 1980 Stoker/SlopedGrate/Other load following False Biomass Wet Biomass Wet Scrubber 0 100 0 0 

FLCFRC252

Boilers #4 & #5

(Hurst) 1

MajorSource FL Boiler 29.9 29.9 8592 1994 Stoker/SlopedGrate/Other Base‐loaded False Biomass Wet Biomass Cyclone or Multiclone

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

FLGPHawthorne

EU 001 Wood FiredBoiler 1

MajorSource FL Boiler 224 224 8556 1980 Stoker/SlopedGrate/Other load following False Biomass Wet Biomass

ElectrostaticPrecipitator 0 99.99980871 0 0 99

FLGPHosfordOSB

011‐THERMAL OIL

HEATER #1 1

MajorSource FL

ProcessHeater 40 40 8000 2003 Dutch Oven/Susp. Burner load following False Biomass Dry Biomass

ElectrostaticPrecipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

FLGPHosfordOSB

011‐THERMAL OIL

HEATER #2 1

MajorSource FL

ProcessHeater 40 40 8000 2003 Dutch Oven/Susp. Burner load following False Biomass Dry Biomass

ElectrostaticPrecipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

FLGPPalatka EU16 1

MajorSource FL Boiler 512.7 512.7 8400 1965 Stoker/SlopedGrate/Other load following False Biomass Wet Biomass

ElectrostaticPrecipitator 0 75.88820041 24.11179959 0 7

FLIPPensacola

Power Boiler 3 / EU

ID 33 1

MajorSource FL Boiler 347 347 8577 1961 PC load following True Coal Coal Venturi Scrubber 99.9692341 0 0 0 99

FLIPPensacola

Power Boiler 4 / EU

ID 37 1

MajorSource FL Boiler 666 666 8360 1981 Stoker/SlopedGrate/Other Base‐loaded True Biomass Wet Biomass Venturi Scrubber 11.4089608 80.97907581 0 0 80

FLNorthFloridaLumber 3‐3900‐150 1

MajorSource FL Boiler 23 23 8064 1981 Stoker/SlopedGrate/Other load following False Biomass Wet Biomass Cyclone or Multiclone

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

FLNorthFloridaLumber 4‐5700‐01 1

MajorSource FL Boiler 42.9 42.9 8400 1979 Stoker/SlopedGrate/Other False Biomass Wet Biomass No HAP APCD Control

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

FLRayonierPerformance PB06 1

MajorSource FL Boiler 525 525 8592 1983 FB load following False Biomass Wet Biomass

Wet

ScrubberElectrostaticPrecipitator 0 86.97087675 0 0 86

FLSmurfit‐Stone 7PB 1

MajorSource FL Boiler 1021 1021 8421 1981 PC Base‐loaded False Coal Coal

ElectrostaticPrecipitator 100 0 0 0 

FLSmurfit‐Stone Power Boiler #4 1

MajorSource FL Boiler 375 375 8760 0 PC False Coal Coal Venturi Scrubber

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

FLSmurfit‐Stone 5PB 1

MajorSource FL Boiler 805 805 8530 1968 Stoker/SlopedGrate/Other Base‐loaded False Biomass Dry Biomass

Electrostatic

Precipitator 0 55.86707367 44.13292633 0 55

FLSmurfit‐Stone Power Boiler #3 1

MajorSource FL Boiler 375 375 8760 0 Stoker/SlopedGrate/Other False Biomass Wet Biomass Venturi Scrubber

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

FLSmurfitStonePanamaCity

No. 4 Combination

Boiler 1

MajorSource FL Boiler 545 545 8760 0 Stoker/SlopedGrate/Other False Coal Coal Wet Scrubber

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

FLSmurfitStonePanamaCity

No. 3 Combination

Boiler 1

MajorSource FL Boiler 505 505 8760 0 Stoker/SlopedGrate/Other False Biomass Wet Biomass Wet Scrubber

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

GAAbitibiBowater Power Boiler #1 1

MajorSource GA Boiler 275 275 8760 0 Stoker/SlopedGrate/Other False Biomass Wet Biomass Venturi Scrubber

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

GACaraustar CB01 1

MajorSource GA Boiler 313 313 8592 1982 PC load following True Coal Coal Fabric Filter 100 0 0 0 

GAGPCedarSprings

U501 ‐ Power

Boiler No 2 1

MajorSource GA Boiler 784 784 8200 1967 PC load following True Coal Coal Venturi Scrubber 88.3636364 0 0 0 88

GAGPCedarSprings

U500 ‐ Power

Boiler No 1 1

MajorSource GA Boiler 784 784 8200 1963 Stoker/SlopedGrate/Other load following True Biomass Wet Biomass Venturi Scrubber 58.6560364 34.20652999 0 0 58

GAGPCelluloseBrunswick

U700 ‐‐ No. 4Power Boiler 1

MajorSource GA Boiler 800 800 8568 1961 Stoker/SlopedGrate/Other Standby False Biomass Wet Biomass

ElectrostaticPrecipitator 0 78.62667093 5.046531014 0 78

GAGPCelluloseBrunswick

U707 ‐‐ No. 7Power Boiler 1

MajorSource GA Boiler 208 208 2100 2003 N/A Base‐loaded True Liquid Light Liquid

Electrostatic

Precipitator 0 0 100 0 

GAGPCelluloseBrunswick

U706 ‐‐ No. 6Power Boiler 1

MajorSource GA Boiler 370 370 8568 1999 N/A Base‐loaded True Liquid Light Liquid

Electrostatic

Precipitator 0 0 100 0 

GAGPMadisonPly

800 Wood WasteBoiler 1

MajorSource GA Boiler 355 355 8500 1979 Stoker/SlopedGrate/Other load following False Biomass Wet Biomass

ElectrostaticPrecipitator 0 100 0 0 

GAGPMonticelloPlywood

EU700 ‐ Wood

Waste Boiler 1

MajorSource GA Boiler 235.3 235.3 8520 1985 Stoker/SlopedGrate/Other load following False Biomass Wet Biomass

ElectrostaticPrecipitator 0 100 0 0 

GAGPSRMRiincon EU BO01 1

MajorSource GA Boiler 422 422 8400 1986 FB load following False Coal Coal

Fabric FilterDry

Sorbent Injection 0 0 00 

GAGPSRMRiincon EU BO02 1

MajorSource GA Boiler 422 422 8400 1990 FB Base‐loaded False Coal Coal

Fabric FilterDry

Sorbent Injection 100 0 0 0 

GAGPSRMRiincon EU BO03 1

MajorSource GA Boiler 422 422 8400 1995 FB load following False Coal Coal

Fabric FilterDry

Sorbent Injection

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

GAGPWarmSprings

EU600 Wood FuelBoiler 1

MajorSource GA Boiler 180 180 8520 1974 Stoker/SlopedGrate/Other load following False Biomass Wet Biomass Cyclone or Multiclone 0 100 0 0 

GAGPWarrenton

400B Wood Waste

Boiler 1

MajorSource GA Boiler 85.7 85.7 7565 1973 Stoker/SlopedGrate/Other load following False Biomass Dry Biomass

ElectrostaticPrecipitator 0 100 0 0 

GAGPWoodClaxton 400 1

MajorSource GA Boiler 86 86 7000 1973 Stoker/SlopedGrate/Other load following False Biomass Dry Biomass

Electrostatic

Precipitator 0 100 0 0 
FacilityID UnitID Unit CountMajor Source State ClassificatioCapacity (mCmapacity_Numeri Hours Per Year Installe Combustor Design Duty Cycle w NOx BurnAeCT Fuel Catego Baseline Fuel Cat Total Control Coal % Biomass % Liquid % Gas 2 %

F

GAGraphicPackaging Bark Boiler #2 1

MajorSource GA Boiler 375 375 8760 0 PC False Coal Coal Venturi Scrubber

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

GAGraphicPackaging Power Boiler #1 1

MajorSource GA Boiler 188 188 8760 0 PC False Coal Coal Venturi Scrubber

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

GAGraphicPackaging Power Boiler #2 1

MajorSource GA Boiler 188 188 8760 0 PC False Coal Coal Venturi Scrubber

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

GAInternationalPaperAugustaMills PB2A 1

MajorSource GA Boiler 686 686 8600 1965 PC load following False Coal Coal

ElectrostaticPrecipitator 95.0161347 0 0 0 95

GAInternationalPaperAugustaMills PB1A 1

MajorSource GA Boiler 680 680 8600 1959 Stoker/SlopedGrate/Other Base‐loaded False Biomass Wet Biomass Venturi Scrubber 66.5223908 29.73588096 0 0 66

GAInternationalPaperAugustaMills PB3A 1

MajorSource GA Boiler 560 560 8600 1989 Stoker/SlopedGrate/Other Base‐loaded False Biomass Wet Biomass

Electrostatic

Precipitator 0 93.75578168 0 0 93

GAInterstateResources Power Boiler #2 1

MajorSource GA Boiler 250 250 8760 0 FB False Biomass Wet Biomass

Wet

ScrubberElectrostaticPrecipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

GAInterstateResources Power Boiler #3 1

MajorSource GA Boiler 188 188 8760 0 N/A False Liquid Heavy Liquid No HAP APCD Control

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

GAIPSavannah

No. 13 Power

Boiler ‐ PB13 1

MajorSource GA Boiler 1280 1280 8506 1982 Stoker/SlopedGrate/Other load following False Biomass Dry Biomass

Electrostatic

Precipitator 84.5172681 15.48273189 0 0 84

GALangboardWillacoochee EU24 1

MajorSource GA Boiler 185 185 8760 1998 FB Base‐loaded False Biomass Wet Biomass

Electrostatic

Precipitator 0 100 0 0 

GALouisianaPacificAthens TOH Wood Burner 1

MajorSource GA

ProcessHeater 40 40 8200 2004 Dutch Oven/Susp. Burner load following False Biomass Dry Biomass

ElectrostaticPrecipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

GAP&GAlbany B002 1

MajorSource GA Boiler 216 216 8277 1981 Stoker/SlopedGrate/Other load following False Biomass Wet Biomass

ElectrostaticPrecipitator 0 0 00 

GAP&GAlbany B001 1

MajorSource GA Boiler 187 187 7597 1972 N/A Standby False Liquid Light Liquid No HAP APCD Control

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

GAPCAValdosta 1006 1

MajorSource GA Boiler 243 243 8400 1953 Stoker/SlopedGrate/Other load following False Biomass Wet Biomass Venturi Scrubber 0 100 0 0 

GAPCAValdosta 1005 1

MajorSource GA Boiler 360 360 8448 1964 Stoker/SlopedGrate/Other load following False Biomass Wet Biomass Venturi Scrubber 0 100 0 0 

GARayonierBaxley PB01 1

MajorSource GA Boiler 58.74 58.74 8300 1974 Stoker/SlopedGrate/Other load following False Biomass Dry Biomass Venturi Scrubber 0 100 0 0 

GARayonierBaxley PB02 1

MajorSource GA Boiler 61.54 61.54 8400 1987 Stoker/SlopedGrate/Other Base‐loaded False Biomass Dry Biomass

Electrostatic

Precipitator 0 100 0 0 

GARayonierJesupMill PB01 1

MajorSource GA Boiler 176 176 8352 1954 Stoker/SlopedGrate/Other load following False Biomass Dry Biomass Wet Scrubber 0 97.2825637 2.717436299 0 97

GARayonierJesupMill PB02 1

MajorSource GA Boiler 313 313 8352 1955 Stoker/SlopedGrate/Other load following False Biomass Dry Biomass

Dry ScrubberCyclone

or Multiclone 0 65.59155381 34.40844619 0 65

GARayonierJesupMill PB03 1

MajorSource GA Boiler 612 612 8352 1973 Stoker/SlopedGrate/Other Base‐loaded False Biomass Dry Biomass Venturi Scrubber 0 79.88612095 19.05169589 0 79

GARoseburgForestVienna

600‐wood fired

boiler 1

MajorSource GA Boiler 53.3 53.3 8194 1969 Stoker/SlopedGrate/Other Base‐loaded False Biomass Dry Biomass Cyclone or Multiclone 0 100 0 0 

GASPNewsprint PB1 1

MajorSource GA Boiler 249 249 7752 1979 PC load following False Coal Coal

ElectrostaticPrecipitator 100 0 0 0 

GASPNewsprint PB2 1

MajorSource GA Boiler 550 550 8496 1989 FB load following False Coal Coal

ElectrostaticPrecipitator 30.0045638 0 50.03171372 0 30

GATempleInlandRome PB4 1

MajorSource GA Boiler 565 565 8757 1962 Stoker/SlopedGrate/Other load following True Biomass Wet Biomass

ElectrostaticPrecipitator 0 100 0 0 

GATempleInlandRome WF 1

MajorSource GA Boiler 856 856 8757 2004 FB Base‐loaded False Biomass Wet Biomass

Electrostatic

Precipitator 0 100 0 0 

GATempleInlandThomson BW‐B001 1

MajorSource GA Boiler 40 40 6165 1974 Dutch Oven/Susp. Burner load following False Biomass Dry Biomass

ElectrostaticPrecipitator 0 100 0 0 

GATempleInlandThomson Coen 1

MajorSource GA

ProcessHeater 30 30 6165 1997 Dutch Oven/Susp. Burner load following False Biomass Dry Biomass No HAP APCD Control

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

GAWestFraserFolkston FOB2 1

MajorSource GA Boiler 29.26 29.26 6680 1996 Stoker/SlopedGrate/Other Base‐loaded False Biomass Dry Biomass Cyclone or Multiclone 0 100 0 0 

GAWestFraserFolkston FOB1 1

MajorSource GA Boiler 28.5 28.5 6767 1969 Stoker/SlopedGrate/Other Base‐loaded False Biomass Dry Biomass Cyclone or Multiclone 0 100 0 0 

GAWeyerhaeuserCoOglethorpe

Power Boiler

(U400) 1

MajorSource GA Boiler 660 660 8400 1980 Stoker/SlopedGrate/Other load following False Biomass Dry Biomass Venturi Scrubber 0 100 0 0 

GAWYPortWentworth Power Boiler #4 1 Major SourGA Boiler 375 375 Stoker/SlopedGrate/Other #N/A Biomass Wet Biomass Electrostatic Precipitato

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

IA3MKnoxville

EPN 007‐031 Boiler

2 1

MajorSource IA Boiler 72 72 4340 1974 N/A Base‐loaded False Liquid Light Liquid No HAP APCD Control 0 0 100 0 

IA3MKnoxville

EPN 007‐030 Boiler

1 1

MajorSource IA Boiler 72 72 5524 1974 N/A Base‐loaded False Liquid Light Liquid No HAP APCD Control 0 0 100 0 

IAJELD‐WENDubuque Wood Fired Boiler 1

MajorSource IA Boiler 86 86 8760 1947 Stoker/SlopedGrate/Other load following False Biomass Dry Biomass Cyclone or Multiclone 0 100 0 0 

IDChilcoLakeSawmill HFB1 1

MajorSource ID Boiler 125 125 8500 1977 Stoker/SlopedGrate/Other Base‐loaded False Biomass Dry Biomass

Electrified Filter Bed

(EFB) 0 100 0 0 

IDMoyieSprings Lumber420 HFB1 1

MajorSource ID Boiler 125 125 8500 1972 Stoker/SlopedGrate/Other Base‐loaded False Biomass Dry Biomass

Electrified Filter Bed

(EFB) 0 100 0 0 

IDPotlatch PB‐1 CE 1

MajorSource ID Boiler 27.6 27.6 8544 1964 Fuel Cell load following False Biomass Dry Biomass

Electrostatic

Precipitator 0 100 0 0 

IDPotlatch PB‐2 Riley 1

MajorSource ID Boiler 92 92 8544 1966 Stoker/SlopedGrate/Other load following False Biomass Dry Biomass

Electrostatic

Precipitator 0 100 0 0 

IDPotlatch PB‐3 Hurst 1

MajorSource ID Boiler 39.675 39.675 8640 1987 Stoker/SlopedGrate/Other load following False Biomass Dry Biomass

Electrostatic

Precipitator 0 100 0 0 

IDRileyCreekLumber HFB1 1

MajorSource ID Boiler 70.23 70.23 8500 1976 Stoker/SlopedGrate/Other Base‐loaded False Biomass Dry Biomass

Electrostatic

Precipitator 0 100 0 0 

IDRileyCreekLumber HFB2 1

MajorSource ID Boiler 67.69 67.69 8500 1975 Stoker/SlopedGrate/Other Base‐loaded False Biomass Dry Biomass

Electrostatic

Precipitator 0 100 0 0 

INJasperSeating9

Wood‐Fired Boiler

B1 1

MajorSource IN Boiler 10.5 10.5 8760 1968 Stoker/SlopedGrate/Other False Biomass Dry Biomass No HAP APCD Control

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 
FacilityID UnitID Unit CountMajor Source State ClassificatioCapacity (mCmapacity_Numeri Hours Per Year Installe Combustor Design Duty Cycle w NOx BurnAeCT Fuel Catego Baseline Fuel Cat Total Control Coal % Biomass % Liquid % Gas 2 %

F

INKimballOfficeJasper B‐1A 1

MajorSource IN Boiler 20.5 20.5 3500 1995 Stoker/SlopedGrate/Other Base‐loaded False Biomass Dry Biomass Cyclone or Multiclone

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

INKimballOfficeSalem Boiler 1 1

MajorSource IN Boiler 39.5 39.5 4000 1986 Stoker/SlopedGrate/Other load following False Coal Coal Cyclone or Multiclone

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

INKimballOfficeSalem Boiler 2 1

MajorSource IN Boiler 39.5 39.5 4000 1986 Stoker/SlopedGrate/Other load following False Coal Coal Cyclone or Multiclone

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

INNOFJasper Boiler 3 1

MajorSource IN Boiler 20.978 20.978 3500 1981 Stoker/SlopedGrate/Other load following False Coal Coal Cyclone or Multiclone

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

INNOFJasper Boiler 1 1

MajorSource IN Boiler 10.487 10.487 3500 1977 Stoker/SlopedGrate/Other load following False Biomass Dry Biomass No HAP APCD Control

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

INNOFJasper Boiler 2 1

MajorSource IN Boiler 10.487 10.487 3500 1978 Stoker/SlopedGrate/Other load following False Biomass Dry Biomass No HAP APCD Control

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

KYDomtarHawesville

Biofuel Boiler B‐900 1

MajorSource KY Boiler 1050 1050 8400 1997 FB load following True Biomass Dry Biomass

Electrostatic

Precipitator 0 84.7460045 0 0 

KYHONCoOwensboro EP01 1

MajorSource KY Boiler

108.045884716157 108.0458847 5760 1980 Stoker/SlopedGrate/Other load following False Biomass Dry Biomass No HAP APCD Control

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

KYNewPage‐Wickliffe B09 1

MajorSource KY Boiler 631 631 8433 1979 Stoker/SlopedGrate/Other load following False Biomass Wet Biomass

ElectrostaticPrecipitator 0 87.17182666 0 0 87

KYWeyerhaeuserEKY MP 01‐01 1

MajorSource KY

ProcessHeater 75 75 5458 1994 Fuel Cell load following False Biomass Dry Biomass

Electrostatic

Precipitator 0 80.6352618 0 0 80

KYWeyerhaeuserEKY MP 01‐02 1

MajorSource KY

ProcessHeater 75 75 5458 1994 Fuel Cell load following False Biomass Dry Biomass

Electrostatic

Precipitator 0 74.18034906 0 0 74

KYWeyerhaeuserEKY MP 01‐03 1

MajorSource KY

ProcessHeater 75 75 5458 1994 Fuel Cell load following False Biomass Dry Biomass

Electrostatic

Precipitator 0 84.56775423 0 0 84

LABoiseCascadeFlorien B‐1 1

MajorSource LA Boiler 138 138 8592 1981 Stoker/SlopedGrate/Other load following False Biomass Dry Biomass Wet Scrubber 0 100 0 0 

LABoiseCascadeOakdale B‐1 1

MajorSource LA Boiler 138 138 8592 1977 Stoker/SlopedGrate/Other load following False Biomass Dry Biomass Cyclone or Multiclone 0 100 0 0 

LABoiseNewsprintDeRidder 69‐03 1

MajorSource LA Boiler 1591.3 1591.3 8400 1969 Stoker/SlopedGrate/Other Base‐loaded False Biomass Wet Biomass Venturi Scrubber 0 70.52097331 5.357175702 0 70

LABoiseNewsprintDeRidder 79‐01 1

MajorSource LA Boiler 454.29 454.29 8400 1979 Stoker/SlopedGrate/Other Base‐loaded False Biomass Wet Biomass Venturi Scrubber 0 78.79034704 0 0 78

LAGPLogansportPly EQT‐0009 1

MajorSource LA Boiler 222 222 8760 1977 Stoker/SlopedGrate/Other load following False Biomass Wet Biomass Wet Scrubber 0 100 0 0 

LAGPPortHudson

EQT0099

Combination BoilerNo. 1 1

MajorSource LA Boiler 459.2 459.2 5728 1969 Stoker/SlopedGrate/Other Base‐loaded True Biomass Wet Biomass Venturi Scrubber 0 94.26277582 0 0 94

LAGPPortHudson

EQT0109 ‐ No. 6CFB Boiler 1

MajorSource LA Boiler 1205 1205 8400 2006 FB load following True Biomass Wet Biomass

Dry Scrubber

LimestoneInjectionElectrostatic 83.0112489 13.93135275 3.057398327 0 83

LAGPSpringhillWood

01‐79 Woodwaste

Fired Boiler 1

MajorSource LA Boiler 208.8 208.8 8400 1979 Stoker/SlopedGrate/Other load following True Biomass Dry Biomass Wet Scrubber 0 100 0 0 

LAGraphic Packaging Bark Boiler 1

MajorSource LA Boiler 750 750 8760 Stoker/SlopedGrate/Other #N/A False Biomass Wet Biomass Venturi Scrubber

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

LAHoodIndustries

EQT001 (wood‐

fired boiler No. 1) 1

MajorSource LA Boiler 62.4 62.4 8400 1976 Stoker/SlopedGrate/Other load following False Biomass Wet Biomass Cyclone or Multiclone 0 100 0 0 

LAHoodIndustries

EQT002 (wood‐

fired boiler No. 2) 1

MajorSource LA Boiler 62.4 62.4 8400 1981 Stoker/SlopedGrate/Other load following False Biomass Wet Biomass Cyclone or Multiclone 0 100 0 0 

LAHuntNatalbany EQT0001 1

MajorSource LA Boiler 92.3 92.3 8592 1980 Stoker/SlopedGrate/Other load following False Biomass Wet Biomass Cyclone or Multiclone 0 100 0 0 

LAHuntPollock EQT0005 1

MajorSource LA Boiler 61.5 61.5 8592 1989 Stoker/SlopedGrate/Other load following False Biomass Wet Biomass Cyclone or Multiclone 0 100 0 0 

LAHuntPollock EQT0017 1

MajorSource LA Boiler 80 80 8592 1979 Stoker/SlopedGrate/Other load following False Biomass Wet Biomass Cyclone or Multiclone 0 0 00 

LAInternationalPaperRedRiverMill

EQT011 Hogged Fuel Boiler No. 2 1

Major Source LA Boiler 940 940 Stoker/SlopedGrate/Other #N/A Biomass Wet Biomass

Electrostatic Precipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

LAIPMansfield

1-78 - No. 1 Power Boiler / EQT005 1

Major Source LA Boiler 760 760 Stoker/SlopedGrate/Other #N/A Coal Coal

Electrostatic Precipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

LAIPMansfield

2-78 - No. 2 Power Boiler 1

Major Source LA Boiler 760 760 Stoker/SlopedGrate/Other #N/A Coal Coal

Electrostatic Precipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

LASmurfit‐Stone Power Boiler #2 1

MajorSource LA Boiler 750 750 8760 0 Stoker/SlopedGrate/Other False Biomass Wet Biomass Cyclone or Multiclone

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

LATempleInlandBogalusa No. 10C Boiler 1

MajorSource LA Boiler 494.4 494.4 8600 0 Stoker/SlopedGrate/Other False Biomass Wet Biomass Wet Scrubber

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

LATempleInlandBogalusa No. 12 Boiler 1

MajorSource LA Boiler 787.5 787.5 8600 0 Stoker/SlopedGrate/Other False Biomass Wet Biomass Wet Scrubber

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

LAWestFraserJoyce 74B 1

MajorSource LA Boiler 58.3 58.3 6800 1973 Stoker/SlopedGrate/Other load following False Biomass Wet Biomass Cyclone or Multiclone 0 100 0 0 

LAWestFraserJoyce 74A 1

MajorSource LA Boiler 58.3 58.3 7550 1973 Stoker/SlopedGrate/Other load following False Biomass Wet Biomass Cyclone or Multiclone 0 100 0 0 

LAWestFraserJoyce 75A 1

MajorSource LA Boiler 154.2 154.2 8000 1973 Stoker/SlopedGrate/Other load following False Biomass Wet Biomass Cyclone or Multiclone 0 100 0 0 

LAWeyerhaeuser1043 EQT ‐ 0010 1

MajorSource LA Boiler 100 100 8400 1974 Stoker/SlopedGrate/Other load following False Biomass Dry Biomass

Electrostatic

Precipitator 0 100 0 0 

LAWeyerhaeuserDodson ES‐017 WFB 1

MajorSource LA Boiler 233 233 8200 1996 Stoker/SlopedGrate/Other load following False Biomass Dry Biomass

Electrostatic

Precipitator 0 100 0 0 

MAHollingsworth&vose Boiler #1 1

MajorSource MA Boiler 49.5 49.5 8400 1988 N/A Base‐loaded False Liquid Heavy Liquid No HAP APCD Control

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

MAMWCustomPapers #1 Boiler 1

MajorSource MA Boiler 37.5 37.5 8760 0 N/A False Liquid Heavy Liquid No HAP APCD Control

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

MAMWCustomPapers #2 Boiler 1

MajorSource MA Boiler 48 48 8760 0 N/A False Liquid Heavy Liquid No HAP APCD Control

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

MANewarkAmerica Boiler #2 1

MajorSource MA Boiler 230 230 7500 2000 N/A load following True Liquid Light Liquid No HAP APCD Control 0 0 00 

MDNewPage‐Luke No. 24 1

MajorSource MD Boiler 590 590 8616 1959 Stoker/SlopedGrate/Other Base‐loaded False Coal Coal Fabric Filter 99.0811881 0 0.91881192 0 99
FacilityID UnitID Unit CountMajor Source State ClassificatioCapacity (mCmapacity_Numeri Hours Per Year Installe Combustor Design Duty Cycle w NOx BurnAeCT Fuel Catego Baseline Fuel Cat Total Control Coal % Biomass % Liquid % Gas 2 %

F

MDNewPage‐Luke No. 25 1

MajorSource MD Boiler 785 785 8640 1965 PC load following True Coal Coal Fabric Filter 100 0 0 0 

MEDomtarBaileyville #9 Power Boiler 1

MajorSource ME Boiler 625 625 8644 1971 Stoker/SlopedGrate/Other load following False Biomass Dry Biomass Venturi Scrubber 0 0 00 

MEHuberEngineeredWoodLLC Boiler No.1 1

Major Source ME Boiler 84 84 Stoker/SlopedGrate/Other #N/A Biomass Dry Biomass

Electrostatic Precipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

MEKatahdinPaperCo EB1 1

MajorSource ME Boiler 370 370 4500 1953 N/A load following True Liquid Heavy Liquid No HAP APCD Control

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

MEKatahdinPaperCo EB2 1

MajorSource ME Boiler 370 370 4500 1953 N/A load following True Liquid Heavy Liquid No HAP APCD Control

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

MEKatahdinPaperCo EB3 1

MajorSource ME Boiler 498 498 8300 1980 Stoker/SlopedGrate/Other Base‐loaded True Biomass Wet Biomass

Electrostatic

Precipitator 0 0 00 

MELincolnPaper&Tissue #8 Power Boiler 1

MajorSource ME Boiler 433 433 8600 1991 Stoker/SlopedGrate/Other load following False Biomass Wet Biomass

Electrostatic

Precipitator 0 89.56851608 10.36406801 0 89

MELincolnPaper&Tissue

#7 Tissue Machine

Dryer 1

MajorSource ME

ProcessHeater 14.976 14.976 8400 1978 N/A False Liquid Light Liquid No HAP APCD Control

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

MEMadisonPaper #7 Boiler ME6737 1

MajorSource ME Boiler 117 117 5150 1991 N/A Base‐loaded True Liquid Heavy Liquid No HAP APCD Control 0 0 100 0 

MEMadisonPaper #6 Boiler ME6454 1

MajorSource ME Boiler 99 99 8250 1980 N/A load following True Liquid Heavy Liquid Spray Dryer 0 0 100 0 

MEMadisonPaper #4 Boiler ME5949 1

MajorSource ME Boiler 119 119 8450 1968 N/A load following True Liquid Heavy Liquid Spray Dryer 0 0 100 0 

MENewPage‐Rumford Cogen#6 1

MajorSource ME Boiler 630 630 8000 1990 FB Base‐loaded False Biomass Dry Biomass

Dry Sorbent

InjectionElectrostaticPrecipitator 12.2049719 57.43989926 3.195629338 0 5

MENewPage‐Rumford PB#3 1

MajorSource ME Boiler 300 300 1900 1948 N/A Standby True Liquid Heavy Liquid Venturi Scrubber 0 0 73.19148936 0 

MENewPage‐Rumford Cogen#7 1

MajorSource ME Boiler 630 630 8000 1990 FB Base‐loaded False Biomass Dry Biomass

Dry Sorbent

InjectionElectrostaticPrecipitator 12.1239147 57.49813574 3.199404525 0 57

MERedShield Riley Boiler 1 Major SourME Boiler 188 188 Stoker/SlopedGrate/Other #N/A Biomass Wet Biomass Electrostatic Precipitato

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

MERedShield Power Boiler #5 1

MajorSource ME Boiler 250 250 8760 0 N/A False Liquid Heavy Liquid No HAP APCD Control

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

MESappiWestbrook Power Boiler #20 1 Major SourME Boiler 188 188 N/A #N/A Liquid Heavy Liquid

No HAP APCD Control

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

MESappiWestbrook Power Boiler #17 1 Major SourME Boiler 213 213 N/A #N/A Liquid Heavy Liquid

No HAP APCD Control

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

MESappiWestbrook Power Boiler #18 1 Major SourME Boiler 213 213 N/A #N/A Liquid Heavy Liquid

No HAP APCD Control

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

MESappiWestbrook Power Boiler #21 1 Major SourME Boiler 844 844 PC #N/A Coal Coal Electrostatic Precipitato

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

MESDWarren #21 Boiler 1

MajorSource ME Boiler 1074 1074 8440 1981 Stoker/SlopedGrate/Other load following True Biomass Dry Biomass

Electrostatic

Precipitator 28.6138666 67.60790872 1.081996092 0 67

MESDWarren Power Boiler #20 1

MajorSource ME Boiler 188 188 8760 0 N/A False Liquid Heavy Liquid No HAP APCD Control

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

MESDWarrenSomerset No1 Power Boiler 1

MajorSource ME Boiler 848 848 8375 1975 Stoker/SlopedGrate/Other Base‐loaded False Biomass Wet Biomass

ElectrostaticPrecipitator 0 92.01078652 7.989213478 0 92

MESDWarrenSomerset No2 Power Boiler 1

MajorSource ME Boiler 1300 1300 8533 1989 Stoker/SlopedGrate/Other Base‐loaded False Biomass Wet Biomass

DryScrubberElectrostatic Precipitator 0 62.4595014 29.93520612 0 6

MEVersoPaper Boiler #8 1

MajorSource ME Boiler 814 814 8400 1984 Stoker/SlopedGrate/Other Base‐loaded True Biomass Dry Biomass

Electrostatic

Precipitator 14.5458823 46.62256337 29.33682042 0 46

MEVersoPaper Boiler #5 1

MajorSource ME Boiler 371 371 1300 1966 N/A Standby True Liquid Heavy Liquid No HAP APCD Control

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

MEVersoPaperAndroscoggin WFI 1

MajorSource ME Boiler 480 480 8400 1976 Stoker/SlopedGrate/Other Base‐loaded False Biomass Wet Biomass Venturi Scrubber 0 87.19900338 12.80099662 0 

MIDecorativePanels Boiler #1 1

MajorSource MI Boiler 96 96 8000 1957 Stoker/SlopedGrate/Other load following True Coal Coal

ElectrostaticPrecipitator 0 0 00 

MIDecorativePanels Boiler #2 1

MajorSource MI Boiler 96 96 8000 1957 Stoker/SlopedGrate/Other True Coal Coal

ElectrostaticPrecipitator 0 0 00 

MIDecorativePanels Boiler #3 1

MajorSource MI Boiler 79 79 8000 1962 Stoker/SlopedGrate/Other load following True Biomass Dry Biomass Cyclone or Multiclone 0 0 00 

MIEBEddyPaper EUBOILER5 1

MajorSource MI Boiler 196 196 8500 1969 PC load following False Coal Coal

ElectrostaticPrecipitator 0 0 00 

MILPCSagola TOH‐Wood 1

MajorSource MI

ProcessHeater 60 60 8400 1987 Stoker/SlopedGrate/Other load following False Biomass Wet Biomass

Dry ElectrostaticGranular Filter 0 100 0 0 

MIManistiquePaper EUBLR001 1

MajorSource MI Boiler 1047.795 1047.795 8616 1964 Stoker/SlopedGrate/Other load following False Coal Coal

ElectrostaticPrecipitator 100 0 0 0 

MIManistiquePaper EUBLR002 1

MajorSource MI Boiler 739.62 739.62 8616 1977 Stoker/SlopedGrate/Other load following False Coal Coal

ElectrostaticPrecipitator 100 0 0 0 

MIMenominee #5 Boiler 1

MajorSource MI Boiler 81.8 81.8 8400 1950 Stoker/SlopedGrate/Other Standby False Coal Coal Fabric Filter 100 0 0 0 

MIMenominee #3 Boiler 1

MajorSource MI Boiler 101 101 8544 1962 Stoker/SlopedGrate/Other load following False Coal Coal Fabric Filter 100 0 0 0 

MINeenahPaperMI Boiler 1 1

MajorSource MI Boiler 202 202 8520 1958 Stoker/SlopedGrate/Other Base‐loaded False Coal Coal Fabric Filter 100 0 0 0 

MINewPageEscanaba Power Boiler #11 1

MajorSource MI Boiler 938 938 8760 1981 PC False Coal Coal

ElectrostaticPrecipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

MINewPageEscanaba Power Boiler #7 1

MajorSource MI Boiler 154 154 8760 1947 N/A False Liquid Heavy Liquid No HAP APCD Control

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

MINewPageEscanaba Power Boiler #8 1

MajorSource MI Boiler 563 563 8760 1968 N/A False Liquid Heavy Liquid No HAP APCD Control

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

MINewPageEscanaba Power Boiler #9 1

MajorSource MI Boiler 563 563 8760 1972 Stoker/SlopedGrate/Other False Biomass Wet Biomass Wet Scrubber

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

MIPackagingCorpofAmerica EUBOILER1 1

MajorSource MI Boiler 240 240 8712 1950 PC load following False Coal Coal Fabric Filter

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 
FacilityID UnitID Unit CountMajor Source State ClassificatioCapacity (mCmapacity_Numeri Hours Per Year Installe Combustor Design Duty Cycle w NOx BurnAeCT Fuel Catego Baseline Fuel Cat Total Control Coal % Biomass % Liquid % Gas 2 %

F

MISmurfitStoneOntonagon No. 1 Riley Boiler 1

MajorSource MI Boiler 375 375 8200 PC #N/A True Coal Coal

Furnace Sorbent

InjectionElectrostaticPrecipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

MIVersoPaperQuinnesec Waste Fuel Boiler 1

MajorSource MI Boiler 624 624 8589 1981 Stoker/SlopedGrate/Other load following True Biomass Wet Biomass

ElectrostaticPrecipitator 0 0 00 

MN3MHutchinson EU002 ‐ Boiler 4 1

MajorSource MN Boiler 110 110 3500 1967 N/A Base‐loaded False Liquid Heavy Liquid No HAP APCD Control

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

MN3MHutchinson EU001 ‐ Boiler 3 1

MajorSource MN Boiler 110 110 5000 1967 N/A Base‐loaded False Liquid Heavy Liquid No HAP APCD Control

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

MNAndersonCorpBayport Boiler 11 EU620 1

MajorSource MN Boiler 52 52 7008 2006 Stoker/SlopedGrate/Other Base‐loaded True Biomass Dry Biomass

ElectrostaticPrecipitator 0 80.63403738 0 0 80

MNAndersonCorpBayport Boiler 12 EU621 1

MajorSource MN Boiler 52 52 7008 2006 Stoker/SlopedGrate/Other Base‐loaded True Biomass Dry Biomass

ElectrostaticPrecipitator 0 80.63403738 0 0 80

MNBoisePaper1212 EU 430 Boiler #2 1

MajorSource MN Boiler 395 395 8350 1956 Stoker/SlopedGrate/Other load following True Biomass Wet Biomass

Electrostatic

Precipitator 0 92.33629867 7.663701327 0 9

MNGPDuluth EU31 Boiler #1 1

MajorSource MN Boiler 43 43 8400 1971 N/A load following False Liquid Heavy Liquid No HAP APCD Control

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

MNGPDuluth EU32 Boiler #2 1

MajorSource MN Boiler 43 43 8400 1971 N/A load following False Liquid Heavy Liquid No HAP APCD Control

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

MNGPDuluth EU34 Boiler #4 1

MajorSource MN Boiler 60 60 8400 1974 Dutch Oven/Susp. Burner Base‐loaded False Biomass Dry Biomass

ElectrostaticPrecipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

MNGPDuluth EU35 Boiler#5 1

MajorSource MN Boiler 17 17 8400 1975 Stoker/SlopedGrate/Other Base‐loaded False Biomass Wet Biomass

ElectrostaticPrecipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

MNGPDuluth EU33 Boiler #3 1

MajorSource MN Boiler 43 43 8400 1971 N/A load following False Liquid Heavy Liquid

ElectrostaticPrecipitator 0 0 100 0 

MNNorbordMinnesota Konus No. 1 1

MajorSource MN

ProcessHeater 20 20 8200 1980 Dutch Oven/Susp. Burner Base‐loaded False Biomass Wet Biomass

Cyclone or

Multiclone/ElectrifiedFilter Bed (EFB) 0 100 0 0 

MNNorbordMinnesota Konus No. 2 1

MajorSource MN

ProcessHeater 20 20 8200 1980 Dutch Oven/Susp. Burner Base‐loaded False Biomass Wet Biomass

Cyclone or

Multiclone/ElectrifiedFilter Bed (EFB) 0 100 0 0 

MNSappiCloquet EU002 1

MajorSource MN Boiler 300 300 8363 1965 Stoker/SlopedGrate/Other Base‐loaded False Biomass Wet Biomass

Electrostatic

Precipitator 0 0 00 

MNSappiCloquet EU004 1

MajorSource MN Boiler 430 430 8532 1980 Stoker/SlopedGrate/Other Base‐loaded False Biomass Wet Biomass

Electrostatic

Precipitator 0 0 00 

MNVersoPaper EU018 Bros 1

MajorSource MN Boiler 119 119 3700 1934 Stoker/SlopedGrate/Other Base‐loaded False Coal Coal Venturi Scrubber 100 0 0 0 

MNVersoPaper EU006 B&W 1

MajorSource MN Boiler 368 368 8520 1981 Stoker/SlopedGrate/Other load following False Biomass Wet Biomass Venturi Scrubber 70.5864405 20.18134521 2.334740365 0 70

MNWausauPaper‐Brainerd EU 002 1

MajorSource MN Boiler 54 54 2100 1945 Stoker/SlopedGrate/Other load following False Coal Coal

ElectrostaticPrecipitator 100 0 0 0 

MNWausauPaper‐Brainerd EU 003 1

MajorSource MN Boiler 107 107 8400 1958 Stoker/SlopedGrate/Other load following False Coal Coal

ElectrostaticPrecipitator 0 0 00 

MNWausauPaper‐Brainerd EU 004 1

MajorSource MN Boiler 107 107 8400 1958 Stoker/SlopedGrate/Other load following False Coal Coal

ElectrostaticPrecipitator 0 0 00 

MNWeyerhaeuserIronton

EU 001 ‐ 4 CellFurnace 1

MajorSource MN

ProcessHeater 225 225 8114 1990 Stoker/SlopedGrate/Other load following False Biomass Dry Biomass

ElectrostaticPrecipitator 0 100 0 0 

MSBowaterSouth Bark Boiler 1

MajorSource MS Boiler 234 234 8600 1989 Stoker/SlopedGrate/Other load following False Biomass Wet Biomass Venturi Scrubber 0 92.99788788 3.76048334 0 92

MSGeorgiaPacificMonticello

AA‐403 (UT‐3)

Combination Boiler 1

MajorSource MS Boiler 917 917 8400 1967 Stoker/SlopedGrate/Other Base‐loaded True Biomass Wet Biomass

ElectrostaticPrecipitator 0 94.19760252 0.046687697 0 9

MSGPBaySprings

AA‐001 (Boiler No.

1) 1

MajorSource MS Boiler 73 73 7811 1972 Stoker/SlopedGrate/Other False Biomass Dry Biomass

ElectrostaticPrecipitator 0 100 0 0 

MSGPBaySprings

AA‐003 (Boiler No.

2) 1

MajorSource MS Boiler 59.42 59.42 7811 1990 Stoker/SlopedGrate/Other load following False Biomass Dry Biomass

Electrostatic

Precipitator 0 100 0 0 

MSGPGlosterPly AA‐002 1

MajorSource MS Boiler 48 48 7875 1966 Stoker/SlopedGrate/Other load following False Biomass Dry Biomass Cyclone or Multiclone 0 100 0 0 

MSGPGlosterPly AA‐001 1

MajorSource MS Boiler 48 48 7881 1966 Stoker/SlopedGrate/Other load following False Biomass Dry Biomass Cyclone or Multiclone 0 100 0 0 

MSGPGlosterPly AA‐003 1

MajorSource MS Boiler 98 98 7883 1967 Stoker/SlopedGrate/Other load following False Biomass Dry Biomass Cyclone or Multiclone 0 100 0 0 

MSGPLouisvillePly AD‐003 (Boiler #3) 1

MajorSource MS Boiler 124 124 8343 1978 Stoker/SlopedGrate/Other load following False Biomass Dry Biomass

ElectrostaticPrecipitator 0 100 0 0 

MSGPNewAugusta

AA‐015 Power

Boiler 1

MajorSource MS Boiler 642 642 8520 1983 Stoker/SlopedGrate/Other load following False Biomass Dry Biomass

Electrostatic

Precipitator 0 100 0 0 

MSGPTaylorsvillePly AA‐700 1

MajorSource MS Boiler 155 155 8652 1979 Stoker/SlopedGrate/Other Base‐loaded False Biomass Dry Biomass

ElectrostaticPrecipitator 0 100 0 0 

MSGPTaylorsvillePly AA‐500 1

MajorSource MS Boiler 169 169 8724 1969 Stoker/SlopedGrate/Other False Biomass Dry Biomass Cyclone or Multiclone 0 100 0 0 

MSGPTylertownMill

AA‐001,

Woodwaste Boiler 1

MajorSource MS Boiler 30 30 8688 1978 Stoker/SlopedGrate/Other Base‐loaded False Biomass Dry Biomass Cyclone or Multiclone 0 100 0 0 

MSHankinsLumber Boiler #1 (AA‐001) 1

MajorSource MS Boiler 65 65 8000 1981 Stoker/SlopedGrate/Other Base‐loaded False Biomass Dry Biomass Cyclone or Multiclone 0 100 0 0 

MSHankinsLumber Boiler #2 (AA‐002) 1

MajorSource MS Boiler 23 23 8000 1973 Stoker/SlopedGrate/Other load following False Biomass Dry Biomass Cyclone or Multiclone 0 100 0 0 

MSHoodBeaumont

AA‐030 (Wood‐

Fired Boiler) 1

MajorSource MS Boiler 140 140 8400 1994 Stoker/SlopedGrate/Other load following False Biomass Wet Biomass Venturi Scrubber 0 100 0 0 

MSHoodWaynesboro

AA‐001 (Wood‐

Fired Boiler) 1

MajorSource MS Boiler 100 100 8400 1971 Stoker/SlopedGrate/Other load following False Biomass Wet Biomass Cyclone or Multiclone 0 100 0 0 

MSHoodWiggins

AA‐001 (Wood‐

Fired Boiler No. 1) 1

MajorSource MS Boiler 65 65 8400 1971 Stoker/SlopedGrate/Other load following False Biomass Wet Biomass Cyclone or Multiclone 0 100 0 0 

MSHoodWiggins

AA‐002 (Wood‐

Fired Boiler No. 2) 1

MajorSource MS Boiler 65 65 8400 1971 Stoker/SlopedGrate/Other load following False Biomass Wet Biomass Cyclone or Multiclone 0 100 0 0 

MSHoodWiggins

AA‐003 (Wood‐

Fired Boiler No. 3) 1

MajorSource MS Boiler 90 90 8400 1975 Stoker/SlopedGrate/Other load following False Biomass Wet Biomass Cyclone or Multiclone 0 100 0 0 

MSIPVicksburg

Power Boiler‐AA‐

006 1

MajorSource MS Boiler 870 870 8400 1967 Stoker/SlopedGrate/Other load following True Biomass Wet Biomass Wet Scrubber 0 88.24659211 0 0 88
FacilityID UnitID Unit CountMajor Source State ClassificatioCapacity (mCmapacity_Numeri Hours Per Year Installe Combustor Design Duty Cycle w NOx BurnAeCT Fuel Catego Baseline Fuel Cat Total Control Coal % Biomass % Liquid % Gas 2 %

F

MSNorbordMS Wellons No. 1 1

MajorSource MS

ProcessHeater 100 100 8400 1995 Fuel Cell load following False Biomass Wet Biomass

ElectrostaticPrecipitator 0 100 0 0 

MSNorbordMS Wellons No. 2 1

MajorSource MS

ProcessHeater 100 100 8400 1995 Fuel Cell load following False Biomass Wet Biomass

ElectrostaticPrecipitator 0 100 0 0 

MSNorbordMS Wellons No. 3 1

MajorSource MS

ProcessHeater 100 100 8400 1995 Fuel Cell load following False Biomass Wet Biomass

ElectrostaticPrecipitator 0 100 0 0 

MSSandersonPlumbing AD‐001 1

MajorSource MS Boiler 11.29 11.29 5808 1994 Stoker/SlopedGrate/Other Base‐loaded False Biomass Dry Biomass Cyclone or Multiclone 0 0 00 

MSShuqualakLumber Boiler 1 (AA‐101) 1

MajorSource MS Boiler 42 42 8000 1988 Dutch Oven/Susp. Burner Base‐loaded False Biomass Dry Biomass Cyclone or Multiclone 0 100 0 0 

MSShuqualakLumber Boiler 2 (AA‐102) 1

MajorSource MS Boiler 15 15 8000 1979 Dutch Oven/Susp. Burner Base‐loaded False Biomass Dry Biomass Cyclone or Multiclone 0 100 0 0 

MSShuqualakLumber Boiler 3 (AA‐107) 1

MajorSource MS Boiler 29 29 8000 1998 Stoker/SlopedGrate/Other Base‐loaded False Biomass Dry Biomass Cyclone or Multiclone 0 100 0 0 

MSShuqualakLumber Boiler 4 (AA‐108) 1

MajorSource MS Boiler 29 29 8000 2004 Stoker/SlopedGrate/Other Base‐loaded False Biomass Dry Biomass Cyclone or Multiclone 0 100 0 0 

MSWeyerhaeuser1398 Boiler No. 1 1

MajorSource MS Boiler 140 140 8200 1976 Stoker/SlopedGrate/Other load following False Biomass Dry Biomass Cyclone or Multiclone 0 100 0 0 

MSWeyerhaeuser1398 Boiler No. 2 1

MajorSource MS Boiler 28.9 28.9 8200 2002 Stoker/SlopedGrate/Other load following False Biomass Dry Biomass Cyclone or Multiclone 0 100 0 0 

MSWeyerhaeuserBruce

AA‐001 No. 1Boiler 1

MajorSource MS Boiler 70 70 8496 1973 Stoker/SlopedGrate/Other load following False Biomass Dry Biomass No HAP APCD Control 0 100 0 0 

MSWeyerhaeuserBruce

AA‐002 No. 2Boiler 1

MajorSource MS Boiler 115 115 8496 1992 Fuel Cell load following False Biomass Dry Biomass

ElectrostaticPrecipitator 0 100 0 0 

MSWeyerhaeuserColumbus AA‐012 1

MajorSource MS Boiler 1400 1400 8570 1979 Stoker/SlopedGrate/Other load following True Biomass Dry Biomass

Electrostatic

Precipitator 14.8262321 76.92055489 2.313984958 0.128555 76

MTPlumCreek Core Coen 1

MajorSource MT

ProcessHeater 50 50 8400 1985 Dutch Oven/Susp. Burner Base‐loaded False Biomass Dry Biomass

ElectrostaticPrecipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

MTPlumCreek Face Coen 1

MajorSource MT

ProcessHeater 50 50 8500 0 Dutch Oven/Susp. Burner Base‐loaded False Biomass Dry Biomass

ElectrostaticPrecipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

MTPlumCreek Line 2 Coen 1

MajorSource MT

ProcessHeater 85 85 8500 2000 Dutch Oven/Susp. Burner Base‐loaded True Biomass Dry Biomass Venturi Scrubber

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

MTPlumCreek Wellons Plywood 1

MajorSource MT

ProcessHeater 30 30 8500 1965 Fuel Cell Base‐loaded False Biomass Wet Biomass

Electrostatic

Precipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

MTPlumCreek Hog Fuel Boiler 1

MajorSource MT Boiler 292 292 8700 1973 Stoker/SlopedGrate/Other load following False Biomass Wet Biomass

ElectrostaticPrecipitator 0 0 00 

MTRoseburgMissoula Boiler 1

MajorSource MT Boiler 55 55 8400 1969 Stoker/SlopedGrate/Other load following False Biomass Dry Biomass Cyclone or Multiclone 0 1.217587622 0 0 1.

MTSmurfitStone Multi‐Fuel Boiler 1

MajorSource MT Boiler 402.5 402.5 8520 Stoker/SlopedGrate/Other #N/A False Biomass Dry Biomass Venturi Scrubber

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

NCBlueRidgePaper G11037 1

MajorSource NC Boiler 364 364 7800 1930 PC load following True Coal Coal

ElectrostaticPrecipitator 100 0 0 0 

NCBlueRidgePaper G11038 1

MajorSource NC Boiler 364 364 7890 1930 PC load following True Coal Coal

ElectrostaticPrecipitator 100 0 0 0 

NCBlueRidgePaper G11039 1

MajorSource NC Boiler 399 399 8150 1946 PC load following True Coal Coal

ElectrostaticPrecipitator 100 0 0 0 

NCBlueRidgePaper G11040 1

MajorSource NC Boiler 535 535 8350 1986 PC load following True Coal Coal

ElectrostaticPrecipitator 100 0 0 0 

NCBlueRidgePaper G11042 1

MajorSource NC Boiler 380 380 7700 1952 Stoker/SlopedGrate/Other load following False Biomass Wet Biomass Venturi Scrubber 67.8933946 32.10660538 0 0 67

NCDomtar

65‐25‐0310 (No. 2

Hog Fuel Boiler) 1

MajorSource NC Boiler 889 889 8279 1982 Stoker/SlopedGrate/Other load following False Biomass Dry Biomass

Cyclone or

Multiclone/ElectrifiedFilter Bed (EFB) 29.1516149 70.6691113 0.179273819 0 70

NCDomtar

66‐25‐2050 (No. 1

Package Boiler) 1

MajorSource NC Boiler 360 360 1342 1996 N/A Standby True Liquid Light Liquid Scrubber (unknown) 0 0 100 0 

NCDomtar

64‐25‐0290 (No. 1

Hog Fuel Boiler) 1

MajorSource NC Boiler 747.5 747.5 8337 1977 Stoker/SlopedGrate/Other load following False Biomass Dry Biomass

Cyclone or

Multiclone/ElectrifiedFilter Bed (EFB) 17.6021553 82.12547152 0.272373193 0 82

NCGPAhoskieCNS

ES‐B1 ‐ Wood Fired

Boiler 1

MajorSource NC Boiler 91.8 91.8 7000 1973 Stoker/SlopedGrate/Other load following False Biomass Dry Biomass Cyclone or Multiclone 0 100 0 0 

NCGPDudley ES‐B1 1

MajorSource NC Boiler 254 254 8500 1979 Stoker/SlopedGrate/Other load following False Biomass Dry Biomass Wet Scrubber 0 100 0 0 

NCGPRoxboro

ES‐1 Wood fired

Boiler 1

MajorSource NC Boiler 70 70 8400 1985 Stoker/SlopedGrate/Other load following False Biomass Dry Biomass Cyclone or Multiclone 0 100 0 0 

NCGPWhiteville ES‐B2 1

MajorSource NC Boiler 241.5 241.5 8664 1984 Stoker/SlopedGrate/Other load following False Biomass Dry Biomass Wet Scrubber 0 100 0 0 

NCInternationalPaperRiegelwood PB2 1

MajorSource NC Boiler 425 425 8400 1957 Stoker/SlopedGrate/Other load following False Biomass Wet Biomass Venturi Scrubber 12.7551416 60.6741094 26.57074895 0 60

NCInternationalPaperRiegelwood PB1 1

MajorSource NC Boiler 250 250 5000 1951 N/A Standby False Liquid Heavy Liquid Wet Scrubber

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

NCInternationalPaperRiegelwood PB5 1

MajorSource NC Boiler 600 600 8400 1978 Stoker/SlopedGrate/Other load following True Biomass Wet Biomass Venturi Scrubber 11.5526316 74.77354722 13.67382119 0 74

NCJacksonPaperSylva JP‐021 1

MajorSource NC Boiler 145.1 145.1 8592 1982 Stoker/SlopedGrate/Other Base‐loaded False Biomass Dry Biomass Venturi Scrubber 0 92.35407109 0 0 92

NCJeld‐Wen Boiler 1 1

MajorSource NC Boiler 43.6 43.6 8400 1988 Stoker/SlopedGrate/Other load following False Biomass Dry Biomass Cyclone or Multiclone 0 100 0 0 

NCKapStone PB1 1

MajorSource NC Boiler 550 550 8600 1966 Stoker/SlopedGrate/Other load following False Biomass Wet Biomass Venturi Scrubber 42.5487419 57.45125807 0 0 57

NCKapStone PKG2 1

MajorSource NC Boiler 185 185 2000 1974 N/A Standby False Liquid Heavy Liquid No HAP APCD Control 0 0 100 0 

NCLAPacificRoxboro TOH#1w 1

MajorSource NC

ProcessHeater 40 40 3700 1995 Dutch Oven/Susp. Burner load following False Biomass Wet Biomass

Electrostatic

Precipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

NCLAPacificRoxboro TOH#2w 1

MajorSource NC

ProcessHeater 40 40 3700 1995 Dutch Oven/Susp. Burner load following False Biomass Dry Biomass

Electrostatic

Precipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

NCLPRoaringRiver Boiler #2 1

MajorSource NC Boiler 79 79 8400 1969 Stoker/SlopedGrate/Other Base‐loaded False Biomass Wet Biomass Venturi Scrubber 0 100 0 0 
FacilityID UnitID Unit CountMajor Source State ClassificatioCapacity (mCmapacity_Numeri Hours Per Year Installe Combustor Design Duty Cycle w NOx BurnAeCT Fuel Catego Baseline Fuel Cat Total Control Coal % Biomass % Liquid % Gas 2 %

F

NCLPRoaringRiver Boiler #1 1

MajorSource NC Boiler 44 44 1000 1969 N/A Base‐loaded False Liquid Heavy Liquid No HAP APCD Control

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

NCLPRoaringRiver Boiler #3 1

MajorSource NC Boiler 183 183 8400 1979 Stoker/SlopedGrate/Other load following False Biomass Wet Biomass Venturi Scrubber 0 0 00 

NCSeaboardLumber ES‐3 1

MajorSource NC Boiler 55.82 55.82 8400 2005 FB load following False Biomass Wet Biomass

Electrostatic

Precipitator 0 100 0 0 

NCSeaboardLumber ES‐NB 1

MajorSource NC Boiler 33 33 8400 1979 FB load following False Biomass Wet Biomass Cyclone or Multiclone

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

NCSeaboardLumber ES‐SB 1

MajorSource NC Boiler 33 33 8400 1979 FB load following False Biomass Wet Biomass Cyclone or Multiclone

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

NCUniboardUSA

Suspension Burner

ID 1430 1

MajorSource NC

ProcessHeater 60 60 8200 1996 Dutch Oven/Susp. Burner load following False Biomass Dry Biomass

ElectrostaticPrecipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

NCWestFraser ES‐BW‐1 1

MajorSource NC Boiler 104.336 104.336 8675 1974 Stoker/SlopedGrate/Other load following False Biomass Dry Biomass Venturi Scrubber

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

NCWeyerhaeuserGrifton ES‐SEH‐2901 1

MajorSource NC

ProcessHeater 57.16 57.16 8400 1989 Fuel Cell load following False Biomass Dry Biomass

Electrostatic

Precipitator 0 0 00 

NCWeyerhaeuserGrifton ES‐SEH‐3901 1

MajorSource NC

ProcessHeater 98 98 8400 1998 Fuel Cell load following False Biomass Dry Biomass

Electrostatic

Precipitator 0 0 00 

NCWeyerhaeuserGrifton ES‐SHE‐1901 1

MajorSource NC

ProcessHeater 57.16 57.16 8400 Fuel Cell #N/A False Biomass Dry Biomass

ElectrostaticPrecipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

NCWeyerhaeuser‐Vanceboro ES 150‐001 1

MajorSource NC Boiler 579 579 6000 1969 N/A Base‐loaded False Liquid Heavy Liquid No HAP APCD Control 0 0 100 0 

NCWeyerhaeuser‐Vanceboro ES 161‐001 1

MajorSource NC Boiler 287 287 8760 1996 N/A load following True Liquid Heavy Liquid Dry Scrubber 0 0 100 0 

NYFinchPaper

#9 Woodwaste

Boiler (BLR‐1749) 1

MajorSource NY Boiler 172.5 172.5 8520 1977 Stoker/SlopedGrate/Other Base‐loaded False Biomass Wet Biomass Venturi Scrubber

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

NYIntlPaperTiconderoga PB1 1

MajorSource NY Boiler 855 855 8520 1970 Stoker/SlopedGrate/Other load following True Biomass Wet Biomass

Dry ScrubberCycloneor Multiclone

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

OHAppletonIdeas Boiler 2 (B002) 1

MajorSource OH Boiler 156 156 8400 1960 Stoker/SlopedGrate/Other load following False Coal Coal

ElectrostaticPrecipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

OHAppletonIdeas Boiler 4 (B003) 1

MajorSource OH Boiler 245 245 8539 1968 Stoker/SlopedGrate/Other load following False Coal Coal

ElectrostaticPrecipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

OHGlatfelterChillicothe Power Boiler #7 1

MajorSource OH Boiler 375 375 8760 0 PC False Coal Coal

ElectrostaticPrecipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

OHGlatfelterChillicothe Power Boiler #8 1

MajorSource OH Boiler 500 500 8760 0 PC False Coal Coal

ElectrostaticPrecipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

OHGlatfelterChillicothe Power Boiler #6 1

MajorSource OH Boiler 288 288 8760 0 Stoker/SlopedGrate/Other False Biomass Wet Biomass

Wet Electrostatic

Precipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

OHRockTennCincinnati B001 1

MajorSource OH Boiler 81 81 8136 1960 Stoker/SlopedGrate/Other Base‐loaded False Coal Coal Fabric Filter

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

OHSmartPapersHoldingsLLC B010 1

MajorSource OH Boiler 420 420 8540 1928 PC load following True Coal Coal

ElectrostaticPrecipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

OHSmurfitCoshocton B006 1

MajorSource OH Boiler 644 644 8625 1982 Stoker/SlopedGrate/Other load following True Biomass Wet Biomass Venturi Scrubber

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

OKGPMuskogeeMill B‐2 1

MajorSource OK Boiler 345 345 7320 1975 PC Base‐loaded False Coal Coal

ElectrostaticPrecipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

OKGPMuskogeeMill B‐4 1

MajorSource OK Boiler 460 460 8496 1982 PC load following True Coal Coal Fabric Filter

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

OKGPMuskogeeMill B‐3 1

MajorSource OK Boiler 460 460 8640 1979 PC load following False Coal Coal Fabric Filter

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

OKIPValliant

Bark Boiler EUGD1 1 Major Source OK Boiler 900 900 Stoker/SlopedGrate/Other #N/A Biomass Wet Biomass Venturi Scrubber Data Not Provided Data Not Provided Data Not Provided Data Not Provided 

OKIPValliant

Power Boiler EUG‐

D2 1

MajorSource OK Boiler 945 945 8642 1972 N/A load following False Liquid Heavy Liquid No HAP APCD Control

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

OKPanPacificProducts EU 100 1

MajorSource OK Boiler 45 45 6500 1995 Stoker/SlopedGrate/Other Base‐loaded False Biomass Dry Biomass Wet Scrubber

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

OKWeyerhaeuserWrightCity EUG 19 1

MajorSource OK Boiler 240 240 8400 1978 Stoker/SlopedGrate/Other load following False Biomass Dry Biomass

Electrostatic

Precipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

ORBBSMMedford B1 1

MajorSource OR Boiler 57.5 57.5 8760 1955 Stoker/SlopedGrate/Other load following False Biomass Wet Biomass

ElectrostaticPrecipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

ORBBSMMedford B2 1

MajorSource OR Boiler 80.5 80.5 8760 1964 Stoker/SlopedGrate/Other load following False Biomass Wet Biomass

ElectrostaticPrecipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

ORBBSMMedford B3 1

MajorSource OR Boiler 115 115 8760 1991 Stoker/SlopedGrate/Other load following False Biomass Wet Biomass

ElectrostaticPrecipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

ORBlueHeronPaper G Boiler 1

MajorSource OR Boiler 112 112 8712 1949 Stoker/SlopedGrate/Other Base‐loaded False Biomass Dry Biomass Cyclone or Multiclone

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

ORBoiseBuilding B2 1

MajorSource OR Boiler 80 80 8600 1970 Dutch Oven/Susp. Burner Base‐loaded False Biomass Dry Biomass

ElectrostaticPrecipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

ORCascadePacificPulp PB1EU 1

MajorSource OR Boiler 230 230 8603 1968 N/A Base‐loaded False Liquid Heavy Liquid No HAP APCD Control

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

ORFlakeboardEugene Boiler‐2 1

MajorSource OR Boiler 51 51 7700 1987 Dutch Oven/Susp. Burner load following False Biomass Dry Biomass Fabric Filter

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

ORGeorgiaPacificWaunaMill

EU33 ‐ Power

Boiler 1

MajorSource OR Boiler

191.894613356164 191.8946134 8400 1965 N/A load following False Liquid Heavy Liquid No HAP APCD Control

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

ORGeorgiaPacificWaunaMill

EU35 ‐ Fluidized

Bed Boiler 1

MajorSource OR Boiler 179 179 8400 1996 FB Base‐loaded False Biomass Dry Biomass

Fabric FilterDry

Sorbent Injection

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

ORGPToledo

EU13 ‐ Power

Boiler #1 1

MajorSource OR Boiler 187.5 187.5 8600 1957 N/A load following False Liquid Heavy Liquid No HAP APCD Control

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

ORJeldWenKlamanthFalls BLRG 1

MajorSource OR Boiler 74 74 8760 1988 Stoker/SlopedGrate/Other load following False Biomass Wet Biomass

ElectrostaticPrecipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

ORRosboroSpringfield DV 01.1 1

MajorSource OR Boiler 50 50 8700 1946 Dutch Oven/Susp. Burner load following False Biomass Dry Biomass Cyclone or Multiclone

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

ORRosboroSpringfield DV 01.2 1

MajorSource OR Boiler 50 50 8700 1946 Dutch Oven/Susp. Burner load following False Biomass Dry Biomass Cyclone or Multiclone

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 
FacilityID UnitID Unit CountMajor Source State ClassificatioCapacity (mCmapacity_Numeri Hours Per Year Installe Combustor Design Duty Cycle w NOx BurnAeCT Fuel Catego Baseline Fuel Cat Total Control Coal % Biomass % Liquid % Gas 2 %

F

ORRosboroSpringfield DV 01.3 1

MajorSource OR Boiler 50 50 8700 1946 Dutch Oven/Susp. Burner load following False Biomass Dry Biomass Cyclone or Multiclone

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

ORRoseburgCoquille Boiler 1 1

MajorSource OR Boiler 127.65 127.65 8400 1959 Stoker/SlopedGrate/Other load following False Biomass Dry Biomass Cyclone or Multiclone

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

ORRoseburgForestDillard Boiler #1 1

MajorSource OR Boiler 309 309 8500 1966 Stoker/SlopedGrate/Other load following False Biomass Wet Biomass Wet Scrubber

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

ORRoseburgForestDillard Boiler #2 1

MajorSource OR Boiler 309 309 8500 1974 Stoker/SlopedGrate/Other load following False Biomass Wet Biomass Wet Scrubber

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

ORRoseburgForestDillard Boiler #6 1

MajorSource OR Boiler 520 520 8500 1976 Stoker/SlopedGrate/Other load following False Biomass Wet Biomass Wet Scrubber

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

ORRoseburgRiddle2 Boiler #1 1

MajorSource OR Boiler 126.5 126.5 8500 1967 Stoker/SlopedGrate/Other load following False Biomass Dry Biomass

ElectrostaticPrecipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

ORRoseburgRiddle2 Boiler #2 1

MajorSource OR Boiler 80.5 80.5 8500 1974 Stoker/SlopedGrate/Other load following False Biomass Dry Biomass Wet Scrubber

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

ORSierraPine SPMDBL01 1

MajorSource OR Boiler 103.5 103.5 7077 1992 Dutch Oven/Susp. Burner load following True Biomass Dry Biomass

Wet

ScrubberElectrostaticPrecipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

ORSierraPineSpringfield SPSPCU01 1

MajorSource OR

ProcessHeater 20 20 8760 1970 Stoker/SlopedGrate/Other load following False Biomass Dry Biomass

ElectrostaticPrecipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

ORSierraPineSpringfield SPSPCU03 1

MajorSource OR

ProcessHeater 30 30 8760 1975 Stoker/SlopedGrate/Other load following False Biomass Dry Biomass

ElectrostaticPrecipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

ORSierraPineSpringfield SPSPCU04 1

MajorSource OR

ProcessHeater 30 30 8760 1975 Stoker/SlopedGrate/Other load following False Biomass Dry Biomass

ElectrostaticPrecipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

ORSPNewsprint B10‐EU 1

MajorSource OR Boiler 567 567 7880 1980 Stoker/SlopedGrate/Other Base‐loaded True Biomass Dry Biomass

ElectrostaticPrecipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

ORSPNewsprint B9‐EU 1

MajorSource OR Boiler 274 274 8400 1975 Stoker/SlopedGrate/Other Standby False Biomass Dry Biomass Wet Scrubber

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

ORStimsonLumberForestGrove Boiler 1 1

MajorSource OR Boiler 76 76 8400 1973 Stoker/SlopedGrate/Other load following False Biomass Dry Biomass

ElectrostaticPrecipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

ORStimsonLumberForestGrove Boiler 2 1

MajorSource OR Boiler 76 76 8400 1978 Stoker/SlopedGrate/Other load following False Biomass Dry Biomass

ElectrostaticPrecipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

ORStimsonLumberForestGrove Boiler 3 1

MajorSource OR Boiler 76 76 8400 1978 Stoker/SlopedGrate/Other load following False Biomass Dry Biomass

ElectrostaticPrecipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

PAAppletonPapers #033 1

MajorSource PA Boiler 205.03 205.03 8400 1995 N/A Standby True Liquid Heavy Liquid No HAP APCD Control

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

PAAppletonPapers #036 1

MajorSource PA Boiler 180 180 8400 1977 Stoker/SlopedGrate/Other load following False Biomass Wet Biomass Venturi Scrubber

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

PACraftMaster

No3 Boiler Source

ID 033 1

MajorSource PA Boiler 273.2 273.2 8600 1996 Stoker/SlopedGrate/Other load following True Biomass Dry Biomass

ElectrostaticPrecipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

PADomtarJohnsonburg #81 Coal Boiler 1

MajorSource PA Boiler 246 246 8640 1984 PC load following True Coal Coal

Wet

ScrubberElectrostaticPrecipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

PADomtarJohnsonburg #82 Coal Boiler 1

MajorSource PA Boiler

246.6666667 246.6666667 8640 1984 PC load following True Coal Coal

Wet

ScrubberElectrostaticPrecipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

PAPHGlatfelter PB3 1

MajorSource PA Boiler 140.1 140.1 1374 1948 PC Standby False Coal Coal

ElectrostaticPrecipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

PAPHGlatfelter PB4 1

MajorSource PA Boiler 363.7 363.7 8550 1956 PC load following True Coal Coal

ElectrostaticPrecipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

PAPHGlatfelter PB1 1

MajorSource PA Boiler 262.3 262.3 8574 1965 PC Base‐loaded True Coal Coal

ElectrostaticPrecipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

PAPHGlatfelter PB5 1

MajorSource PA Boiler 545 545 8412 1989 FB Base‐loaded False Biomass Wet Biomass

Dry Sorbent

InjectionElectrostaticPrecipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

PAProctorGambleMehoopanyPA Boiler #1 (031) 1

MajorSource PA Boiler 242 242 8400 1966 N/A load following True Liquid Heavy Liquid No HAP APCD Control

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

PATeamTen

033A Babcock and

Wilcox No. 7 Boiler 1

MajorSource PA Boiler 236 236 8400 1957 Stoker/SlopedGrate/Other Base‐loaded False Coal Coal Fabric Filter

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

PATemple‐Inland Westec 1

MajorSource PA

ProcessHeater 50 50 7100 1994 Dutch Oven/Susp. Burner load following False Biomass Dry Biomass No HAP APCD Control

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

PATemple‐Inland GEKA 1

MajorSource PA

ProcessHeater 66 66 7250 1994 Dutch Oven/Susp. Burner load following False Biomass Dry Biomass No HAP APCD Control

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

SCBowaterCoatedPaper

Combination BoilerNo. 1 1

MajorSource SC Boiler 405 405 8600 1959 Stoker/SlopedGrate/Other load following False Biomass Wet Biomass

ElectrostaticPrecipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

SCBowaterCoatedPaper Power Boiler 1

MajorSource SC Boiler 375 375 1000 1959 N/A Standby False Liquid Heavy Liquid No HAP APCD Control

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

SCBowaterCoatedPaper

Combination BoilerNo. 2 1

MajorSource SC Boiler 720 720 8600 1968 Stoker/SlopedGrate/Other load following False Biomass Wet Biomass

ElectrostaticPrecipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

SCChesterWoodProducts Boiler 1

MajorSource SC Boiler 142 142 8640 1981 Stoker/SlopedGrate/Other False Biomass Wet Biomass Wet Scrubber

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

SCCogenSouth B001 ‐ Main Boiler 1

MajorSource SC Boiler 1337 1337 8592 1999 Stoker/SlopedGrate/Other load following True Biomass Wet Biomass

Spray Dryer/Fabric

Filter

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

SCCollumsLumber 01 1

MajorSource SC Boiler 33.5 33.5 8200 1988 Stoker/SlopedGrate/Other Base‐loaded False Biomass Wet Biomass Cyclone or Multiclone

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

SCGPProsperityPly

B, Wood FiredBoiler 1

MajorSource SC Boiler 200 200 8520 1989 Stoker/SlopedGrate/Other load following False Biomass Wet Biomass Wet Scrubber

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

SCGPRussellville Wood‐fired boiler 1

MajorSource SC Boiler 248.67 248.67 8400 1986 Stoker/SlopedGrate/Other load following False Biomass Dry Biomass Cyclone or Multiclone

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

SCInternationalPaperEastover No. 2 Power Boiler 1

MajorSource SC Boiler 500 500 8500 1989 Stoker/SlopedGrate/Other Base‐loaded False Biomass Wet Biomass

ElectrostaticPrecipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

SCInternationalPaperEastover No. 1 Power Boiler 1

MajorSource SC Boiler 545 545 8600 1982 Stoker/SlopedGrate/Other load following True Biomass Wet Biomass

Electrostatic

Precipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

SCIPGeorgetown PB01 1

MajorSource SC Boiler 592 592 8616 1982 Stoker/SlopedGrate/Other load following True Biomass Wet Biomass

ElectrostaticPrecipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

SCIPGeorgetown PB02 1

MajorSource SC Boiler 592 592 8616 1982 Stoker/SlopedGrate/Other load following True Biomass Wet Biomass

ElectrostaticPrecipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

SCMarlboroPaper Hogged Fuel Boiler 1

MajorSource SC Boiler 470 470 8400 1989 Stoker/SlopedGrate/Other load following False Biomass Wet Biomass

Electrostatic

Precipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 
FacilityID UnitID Unit CountMajor Source State ClassificatioCapacity (mCmapacity_Numeri Hours Per Year Installe Combustor Design Duty Cycle w NOx BurnAeCT Fuel Catego Baseline Fuel Cat Total Control Coal % Biomass % Liquid % Gas 2 %

F

SCNewSouthCamden WWB1 1

MajorSource SC Boiler 92 92 8400 1982 Stoker/SlopedGrate/Other load following False Biomass Wet Biomass

ElectrostaticPrecipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

SCNewSouthCoConway WWB1 1

MajorSource SC Boiler 92 92 8400 1983 Stoker/SlopedGrate/Other load following False Biomass Wet Biomass

ElectrostaticPrecipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

SCNewSouthLumberCoDarlington BLR1 1

MajorSource SC Boiler 28.93 28.93 8400 1994 Stoker/SlopedGrate/Other load following False Biomass Wet Biomass Cyclone or Multiclone

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

SCNewSouthLumberCoDarlington BLR3 1

MajorSource SC Boiler 28.7 28.7 8400 1997 Stoker/SlopedGrate/Other load following False Biomass Wet Biomass Cyclone or Multiclone

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

SCRoseburgForestRussellville Boiler 1

MajorSource SC Boiler 30.8 30.8 8480 1971 Dutch Oven/Susp. Burner Base‐loaded False Biomass Dry Biomass Fabric Filter

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

SCSimpsonLumberGeorgetown 02 1

MajorSource SC Boiler 63.7 63.7 8592 1975 Stoker/SlopedGrate/Other Base‐loaded False Biomass Dry Biomass

Electrostatic

Precipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

SCSimpsonLumberGeorgetown B03 1

MajorSource SC Boiler 28.7 28.7 8592 1998 Stoker/SlopedGrate/Other Base‐loaded False Biomass Dry Biomass Cyclone or Multiclone

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

SCSmurfitStone Unit 15: Boiler #3 1

MajorSource SC Boiler 343 343 8380 1963 Stoker/SlopedGrate/Other load following False Biomass Dry Biomass

Electrostatic

Precipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

SCSmurfitStone Unit 16: Boiler #4 1

MajorSource SC Boiler 955 955 8380 1987 Stoker/SlopedGrate/Other Base‐loaded True Biomass Dry Biomass

ElectrostaticPrecipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

SCSonocoHartsville Boiler Number 9 1

MajorSource SC Boiler 180 180 8111 1997 FB Base‐loaded False Coal Coal

Fabric FilterDry

Sorbent Injection

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

SCSonocoHartsville Boiler Number 3 1

MajorSource SC Boiler 178 178 8345 1950 PC Base‐loaded False Coal Coal

ElectrostaticPrecipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

SCSonocoHartsville Boiler Number 4 1

MajorSource SC Boiler 380 380 8400 1957 Stoker/SlopedGrate/Other load following False Coal Coal Fabric Filter

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

SCWestFraserNewberry B2 1

MajorSource SC Boiler 28.7 28.7 8169 1996 Stoker/SlopedGrate/Other load following False Biomass Wet Biomass Cyclone or Multiclone

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

SCWestFraserNewberry B3 1

MajorSource SC Boiler 28.7 28.7 8196 1996 Stoker/SlopedGrate/Other load following False Biomass Wet Biomass Cyclone or Multiclone

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

SCWestFraserNewberry B1 1

MajorSource SC Boiler 28.7 28.7 8386 1996 Stoker/SlopedGrate/Other load following False Biomass Wet Biomass Cyclone or Multiclone

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

TNArborCraft B‐1 1

MajorSource TN Boiler 17.14 17.14 8000 1990 Stoker/SlopedGrate/Other Base‐loaded False Biomass Dry Biomass Cyclone or Multiclone

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

TNArborCraft B‐2 1

MajorSource TN Boiler 17.14 17.14 8000 1990 Stoker/SlopedGrate/Other Base‐loaded False Biomass Dry Biomass Cyclone or Multiclone

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

TNBowaterNewsprint Power Boiler No. 1 1

MajorSource TN Boiler 214 214 8600 1956 PC load following False Coal Coal

ElectrostaticPrecipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

TNBowaterNewsprint Power Boiler No. 2 1

MajorSource TN Boiler 460 460 8600 1957 PC load following True Coal Coal

ElectrostaticPrecipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

TNBowaterNewsprint Power Boiler No. 3 1

MajorSource TN Boiler 460 460 8600 1957 PC load following True Coal Coal

ElectrostaticPrecipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

TNBowaterNewsprint

Bubbling FluidizedBed Boiler 1

MajorSource TN Boiler 877 877 8600 1997 FB Base‐loaded False Biomass Wet Biomass

Electrostatic

Precipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

TNDomtar2384 HFB1‐1 1

MajorSource TN Boiler 544 544 8760 1998 FB Base‐loaded True Biomass Dry Biomass

Electrostatic

Precipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

TNPackagingCorpCounce

Combination Boiler #2 1 TN Boiler 860 860 Stoker/SlopedGrate/Other #N/A Biomass Wet Biomass

Electrostatic Precipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

TNPackagingCorpCounce

Combination Boiler#1 1

MajorSource TN Boiler 400 400 5689 1961 N/A Standby False Liquid Heavy Liquid No HAP APCD Control

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

TXAnthonyForestProd‐ATL EP 10.1 Superior 1

MajorSource TX Boiler 24 24 8592 1996 Stoker/SlopedGrate/Other Base‐loaded False Biomass Wet Biomass Cyclone or Multiclone

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

TXAnthonyForestProd‐ATL EP 11.1 Hurst 1

MajorSource TX Boiler 28.7 28.7 8592 1997 Stoker/SlopedGrate/Other Base‐loaded False Biomass Wet Biomass Cyclone or Multiclone

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

TXDibollTemple‐Inland COEN 1

MajorSource TX

ProcessHeater 28 28 7500 1989 Dutch Oven/Susp. Burner load following False Biomass Dry Biomass Cyclone or Multiclone

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

TXDibollTemple‐Inland PB‐44 1

MajorSource TX Boiler 40 40 7500 1970 Dutch Oven/Susp. Burner load following False Biomass Dry Biomass

Electrostatic

Precipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

TXGPClevelandPlyLumber GRP‐SBOIL 1

MajorSource TX Boiler 289.8 289.8 8568 1979 Stoker/SlopedGrate/Other load following False Biomass Wet Biomass Venturi Scrubber

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

TXInternationalPaperQueenCity PB02 1

Major Source TX Boiler 1084 1084 8400 Stoker/SlopedGrate/Other #N/A Biomass Wet Biomass venturi Scrubber

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

TXLPCarthage

TOH Primary WoodBurner 1

MajorSource TX

ProcessHeater 32 32 8600 1996 Stoker/SlopedGrate/Other load following False Biomass Dry Biomass

ElectrostaticPrecipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

TXLPJasperOSB

Suspension Burner

#3 1

MajorSource TX

ProcessHeater 125.9642 125.9642 5613 1993 Stoker/SlopedGrate/Other load following False Biomass Dry Biomass

Electrostatic

Precipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

TXLPJasperOSB

Thermal Oil Heater

‐ Wood 1

MajorSource TX

ProcessHeater 34 34 7200 1993 Dutch Oven/Susp. Burner load following False Biomass Dry Biomass

Electrostatic

Precipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

TXMeadWestvacoEvadale 21‐2081 1

MajorSource TX Boiler 318 318 8400 1994 Stoker/SlopedGrate/Other Standby True Biomass Wet Biomass No HAP APCD Control

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

TXNorbordTexasJefferson North Teaford 1

MajorSource TX

ProcessHeater 175 175 7000 2005 Stoker/SlopedGrate/Other Base‐loaded True Biomass Wet Biomass

ElectrostaticPrecipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

TXNorbordTexasJefferson South Teaford 1

MajorSource TX

ProcessHeater 175 175 7000 2005 Stoker/SlopedGrate/Other Base‐loaded True Biomass Wet Biomass

ElectrostaticPrecipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

TXNorbordTexasNacogdoches Core McConnell 1

MajorSource TX

ProcessHeater 40 40 8000 1986 Dutch Oven/Susp. Burner Base‐loaded False Biomass Dry Biomass

ElectrostaticPrecipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

TXNorbordTexasNacogdoches Konus No. 1 1

MajorSource TX

ProcessHeater 16 16 8000 1986 Fuel Cell Base‐loaded False Biomass Wet Biomass

Electrified Filter Bed

(EFB)

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

TXNorbordTexasNacogdoches Konus No. 2 1

MajorSource TX

ProcessHeater 16 16 8000 1986 Fuel Cell Base‐loaded False Biomass Wet Biomass

Electrified Filter Bed

(EFB)

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

TXNorbordTexasNacogdoches Surface McConnell 1

MajorSource TX

ProcessHeater 40 40 8000 1986 Dutch Oven/Susp. Burner Base‐loaded False Biomass Dry Biomass

ElectrostaticPrecipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

TXNorbordTexasNacogdoches Teaford 1

MajorSource TX

ProcessHeater 60 60 8000 2006 Stoker/SlopedGrate/Other Base‐loaded True Biomass Wet Biomass

ElectrostaticPrecipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

TXPinelandTemple‐Inland EPN22 1

MajorSource TX Boiler 175 175 8000 1973 Stoker/SlopedGrate/Other load following False Biomass Wet Biomass

Electrostatic

Precipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 
FacilityID UnitID Unit CountMajor Source State ClassificatioCapacity (mCmapacity_Numeri Hours Per Year Installe Combustor Design Duty Cycle w NOx BurnAeCT Fuel Catego Baseline Fuel Cat Total Control Coal % Biomass % Liquid % Gas 2 %

F

TXPinelandTemple‐Inland EPN91 1

MajorSource TX

ProcessHeater 22 22 8000 1985 Dutch Oven/Susp. Burner load following False Biomass Dry Biomass No HAP APCD Control

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

TXPinelandTemple‐Inland EPN92 1

MajorSource TX

ProcessHeater 22 22 8000 2005 Dutch Oven/Susp. Burner load following False Biomass Dry Biomass No HAP APCD Control

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

TXTempleInlandFiberboard FB‐25 1

MajorSource TX Boiler 230 230 8640 1979 Stoker/SlopedGrate/Other load following False Biomass Dry Biomass Wet Scrubber

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

TXTemple‐InlandOrange Bark Boiler 1

MajorSource TX Boiler 394 394 8760 0 Stoker/SlopedGrate/Other False Biomass Wet Biomass Venturi Scrubber

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

TXwestfraser Boiler‐1 1

MajorSource TX Boiler 90.7 90.7 8472 1980 Stoker/SlopedGrate/Other load following False Biomass Wet Biomass Wet Scrubber

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

VAATCPanels

Babcock & Wilcox

Boiler 1

MajorSource VA Boiler 46 46 8280 1971 Dutch Oven/Susp. Burner load following False Biomass Dry Biomass Cyclone or Multiclone

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

VAATCPanels Coen Burner 1

MajorSource VA

ProcessHeater 40 40 8280 1989 Stoker/SlopedGrate/Other load following False Biomass Dry Biomass Cyclone or Multiclone

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

VABassettFiberboard BL2 1

MajorSource VA Boiler 35 35 6000 1977 Stoker/SlopedGrate/Other load following False Biomass Dry Biomass Cyclone or Multiclone

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

VABassettFiberboard BL1 1

MajorSource VA Boiler 25.1 25.1 8400 1969 N/A load following False Liquid Light Liquid No HAP APCD Control

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

VABearIslandPaperCoAshland

Unit Ref #2

(Combo Boiler) 1

MajorSource VA Boiler 243 243 8760 1979 Stoker/SlopedGrate/Other load following False Biomass Dry Biomass

Electrostatic

Precipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

VAGeorgiaPacificBrooknealGladys 5600 1

MajorSource VA

ProcessHeater 240 240 8000 1995 Fuel Cell load following False Biomass Wet Biomass

Electrostatic

Precipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

VAGeorgiaPacificEmporia WWB 1

MajorSource VA Boiler 179.4 179.4 8500 1977 Stoker/SlopedGrate/Other load following False Biomass Dry Biomass Wet Scrubber

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

VAGPBigIsland2703

PWR04 ‐ No. 4Power Boiler 1

MajorSource VA Boiler 284 284 8529 1943 PC Base‐loaded True Coal Coal

ElectrostaticPrecipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

VAGPBigIsland2703

PWR05 ‐ No. 5Power Boiler 1

MajorSource VA Boiler 334 334 8567 1947 Stoker/SlopedGrate/Other load following False Biomass Wet Biomass

ElectrostaticPrecipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

VAGPJarrattFiberboard

EP‐15 No. 3 Keeler

Boiler 1

MajorSource VA Boiler 86.6 86.6 8400 1978 Stoker/SlopedGrate/Other load following False Coal Coal Cyclone or Multiclone

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

VAGreif BLR01 1

MajorSource VA Boiler 225 225 5141 1975 N/A load following True Liquid Heavy Liquid No HAP APCD Control

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

VAGreif BLR05 1

MajorSource VA Boiler 244 244 8640 2000 Stoker/SlopedGrate/Other Base‐loaded True Biomass Wet Biomass

Electrostatic

Precipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

VAGreif BLR02 1

MajorSource VA Boiler 225 225 8640 1975 N/A load following False Liquid Heavy Liquid No HAP APCD Control

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

VAMeadWestVaco‐CovingtonVA PWR007 1

MajorSource VA Boiler 440 440 8200 1950 Stoker/SlopedGrate/Other load following False Coal Coal

Dry

ScrubberElectrostaticPrecipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

VAMeadWestVaco‐CovingtonVA PWR008 1

MajorSource VA Boiler 580 580 8300 1955 Stoker/SlopedGrate/Other load following False Coal Coal

Dry

ScrubberElectrostaticPrecipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

VAMeadWestVaco‐CovingtonVA PWR009 1

MajorSource VA Boiler 807 807 8500 1964 Stoker/SlopedGrate/Other Base‐loaded True Coal Coal

Dry

ScrubberElectrostaticPrecipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

VAMeadWestVaco‐CovingtonVA PWR006 1

MajorSource VA Boiler 550 550 8600 1940 PC Base‐loaded True Coal Coal

Dry

ScrubberElectrostaticPrecipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

VASmurfitStoneHopewell Combination Boiler 1

MajorSource VA Boiler 846 846 8575 1979 PC load following False Coal Coal

ElectrostaticPrecipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

VASmurfitStoneWestpt PB08 1

MajorSource VA Boiler 553 553 8047 1964 PC load following True Coal Coal

ElectrostaticPrecipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

VASmurfitStoneWestpt PB10 1

MajorSource VA Boiler 659 659 8285 1981 Stoker/SlopedGrate/Other Base‐loaded False Biomass Wet Biomass

Electrostatic

Precipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

WABoiseKettleFallsPlywood B1 1

MajorSource WA Boiler 45 45 8400 1975 Stoker/SlopedGrate/Other Base‐loaded False Biomass Dry Biomass

Cyclone or

Multiclone/ElectrifiedFilter Bed (EFB)

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

WABoisePaperWallula Hog Fuel Boiler 1

MajorSource WA Boiler 270.25 270.25 8500 1978 Stoker/SlopedGrate/Other load following False Biomass Dry Biomass

Venturi

ScrubberElectrostaticPrecipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

WAGPCamas No. 3 Power Boiler 1

MajorSource WA Boiler 276 276 8000 1948 Stoker/SlopedGrate/Other load following True Biomass Dry Biomass

Electrostatic

Precipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

WAGPCamas No. 5 Power Boiler 1

MajorSource WA Boiler 318 318 8340 1970 N/A load following True Liquid Heavy Liquid Venturi Scrubber

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

WAGraysHarborPaper No. 6 Boiler (EU2) 1

MajorSource WA Boiler 210 210 4750 1952 Dutch Oven/Susp. Burner False Biomass Wet Biomass Venturi Scrubber

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

WAGraysHarborPaper No. 8 Boiler (EU1) 1

MajorSource WA Boiler 400 400 7646 1976 Stoker/SlopedGrate/Other load following False Biomass Wet Biomass Wet Scrubber

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

WAJeldWenWhiteSwan Boiler 1 1

MajorSource WA Boiler 47.3 47.3 8400 1984 Stoker/SlopedGrate/Other load following False Biomass Dry Biomass

ElectrostaticPrecipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

WAJeldWenWhiteSwan Boiler 2 1

MajorSource WA Boiler 37.8 37.8 3000 1997 N/A load following False Liquid Light Liquid No HAP APCD Control

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

WAKimberlyClarkEverett

No. 14

CogenerationBoiler 1

MajorSource WA Boiler 435 435 8180 1995 Stoker/SlopedGrate/Other Base‐loaded True Biomass Dry Biomass Fabric Filter

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

WANipponPaper #9 Package Boiler 1

MajorSource WA Boiler 115 115 1600 1964 N/A Standby False Liquid Heavy Liquid No HAP APCD Control

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

WANipponPaper #8 Hog Fuel Boiler 1

MajorSource WA Boiler 161 161 8550 1953 Stoker/SlopedGrate/Other Base‐loaded False Biomass Dry Biomass Venturi Scrubber

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

WANipponPaper #10 Package Boiler 1

MajorSource WA Boiler 115 115 3000 1982 N/A Standby False Liquid Heavy Liquid No HAP APCD Control

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

WAPonderayAbibo FBB boiler 1

MajorSource WA Boiler 64 64 8600 0 FB False Biomass Dry Biomass

Fabric FilterDry

Sorbent Injection

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

WAPort Townsend Power Boiler 1 Major SourWA Boiler 188 188 N/A #N/A Liquid Heavy Liquid No HAP APCD Control

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

WASierraPacific Co‐Gen 1

MajorSource WA Boiler 287.5 287.5 8400 2006 Stoker/SlopedGrate/Other Base‐loaded True Biomass Dry Biomass No HAP APCD Control

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

WASimpsonLumberCompany EU1 1

MajorSource WA Boiler 185 185 8500 1986 Stoker/SlopedGrate/Other load following False Biomass Dry Biomass

Electrostatic

Precipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

WASimpsonTacoma2784 #7 PB 1

MajorSource WA Boiler 345 345 8700 1991 Stoker/SlopedGrate/Other load following True Biomass Dry Biomass

Electrostatic

Precipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 
FacilityID UnitID Unit CountMajor Source State ClassificatioCapacity (mCmapacity_Numeri Hours Per Year Installe Combustor Design Duty Cycle w NOx BurnAeCT Fuel Catego Baseline Fuel Cat Total Control Coal % Biomass % Liquid % Gas 2 %

F

WAWeyerhaeuser_Raymond

Hog Fuel Boiler

EU1 1

MajorSource WA Boiler 115 115 8550 1996 Fuel Cell load following False Biomass Dry Biomass

Electrostatic

Precipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

WAWeyerhaeuserLongview

No. 11 Hog Fuel

Boiler 1

MajorSource WA Boiler 632.5 632.5 8400 1975 Stoker/SlopedGrate/Other load following False Biomass Dry Biomass

Duct Sorbent

InjectionElectrostaticPrecipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

WIAlgoma B02 1

MajorSource WI Boiler 21 21 3949 1986 Stoker/SlopedGrate/Other load following False Biomass Dry Biomass No HAP APCD Control

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

WIAlgoma B03 1

MajorSource WI Boiler 34 34 4751 1987 Stoker/SlopedGrate/Other load following False Biomass Dry Biomass No HAP APCD Control

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

WIAppleton

B22 Coal Fired

Boiler 1

MajorSource WI Boiler 44 44 8232 1947 Stoker/SlopedGrate/Other Base‐loaded False Coal Coal Cyclone or Multiclone

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

WIAppletonCoated B23 1

MajorSource WI Boiler 341 341 8520 1985 Stoker/SlopedGrate/Other Base‐loaded True Coal Coal

ElectrostaticPrecipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

WIDomtar2814 B11, S11 1

MajorSource WI Boiler 120 120 7728 1972 Stoker/SlopedGrate/Other Base‐loaded False Biomass Wet Biomass

ElectrostaticPrecipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

WIDomtar2814 B10, S10 1

MajorSource WI Boiler 200 200 8400 1976 N/A Base‐loaded False Liquid Light Liquid No HAP APCD Control

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

WIDomtarNekoosa B22 ‐ Boiler No. 7 1

MajorSource WI Boiler 148.4 148.4 1468 1942 Stoker/SlopedGrate/Other Standby False Coal Coal

ElectrostaticPrecipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

WIDomtarNekoosa B20 ‐ Boiler No. 1 1

MajorSource WI Boiler 153.4 153.4 8640 1947 PC load following False Coal Coal

ElectrostaticPrecipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

WIDomtarNekoosa B21 ‐ Boiler No. 2 1

MajorSource WI Boiler 153.4 153.4 8640 1952 PC load following False Coal Coal

ElectrostaticPrecipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

WIDomtarNekoosa B24 ‐ Boiler No. 10 1

MajorSource WI Boiler 303.2 303.2 8640 1966 Stoker/SlopedGrate/Other Base‐loaded False Coal Coal

ElectrostaticPrecipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

WIFlambeauRiverPaper B24 1

MajorSource WI Boiler 249 249 8400 1982 Stoker/SlopedGrate/Other Base‐loaded False Biomass Wet Biomass Venturi Scrubber

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

WIGPGreenBay2818

B25 ‐ Stoker Boiler

#5 1

MajorSource WI Boiler 200 200 4080 1950 Stoker/SlopedGrate/Other Standby False Coal Coal Fabric Filter

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

WIGPGreenBay2818

B29 ‐ Fluidized BedBoiler #9 1

MajorSource WI Boiler 486 486 7896 1992 FB Base‐loaded False Coal Coal

Fabric FilterDry

Sorbent Injection

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

WIGPGreenBay2818

B26 ‐ Stoker Boiler

#6 1

MajorSource WI Boiler 350 350 8304 1962 Stoker/SlopedGrate/Other load following False Coal Coal Fabric Filter

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

WIGPGreenBay2818

B28 ‐ Stoker Boiler

#8 1

MajorSource WI Boiler 235 235 8304 1975 Stoker/SlopedGrate/Other load following False Coal Coal Fabric Filter

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

WIGPGreenBay2818

B27 ‐ Cyclone

Boiler #7 1

MajorSource WI Boiler 615 615 8328 1969 Stoker/SlopedGrate/Other load following False Coal Coal Fabric Filter

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

WIGPGreenBay2818

B10 Wastepaper

Sludge‐Fired Boiler

10 1

MajorSource WI Boiler 95 95 8376 1998 FB Base‐loaded True Biomass Wet Biomass Fabric Filter

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

WIGreenBayPackagingMillDivision

Boiler B26‐ Coal

Fired Boiler 1

MajorSource WI Boiler 229 229 8760 1977 Stoker/SlopedGrate/Other load following False Coal Coal Fabric Filter

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

WILPHayward K1 Line 1 Konus 1

MajorSource WI

ProcessHeater 19.4 19.4 6575 1979 Stoker/SlopedGrate/Other load following False Biomass Wet Biomass

Electrified Filter Bed

(EFB)

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

WILPHayward K2 Line 1 Konus 1

MajorSource WI

ProcessHeater 19.4 19.4 6575 1979 Stoker/SlopedGrate/Other load following False Biomass Wet Biomass

Electrified Filter Bed

(EFB)

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

WILPHayward K3 Line 2 Konus 1

MajorSource WI

ProcessHeater 23.8 23.8 6575 1981 Stoker/SlopedGrate/Other load following False Biomass Wet Biomass

Electrified Filter Bed

(EFB)

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

WILPHayward K4 Line 2 Konus 1

MajorSource WI

ProcessHeater 23.8 23.8 6575 1981 Stoker/SlopedGrate/Other load following False Biomass Wet Biomass

Electrified Filter Bed

(EFB)

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

WINeenahPaperAppleton Union Boiler (B22) 1

MajorSource WI Boiler 60 60 5900 1957 N/A load following False Liquid Heavy Liquid No HAP APCD Control

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

WINewPageBiron B24 1

MajorSource WI Boiler 445.16 445.16 8324 1986 Stoker/SlopedGrate/Other load following False Coal Coal

ElectrostaticPrecipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

WINewPageBiron B23 1

MajorSource WI Boiler 340 340 8349 1958 PC Base‐loaded False Coal Coal

ElectrostaticPrecipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

WINewPageKimberly B21 1

MajorSource WI Boiler 137.5 137.5 8760 1951 Stoker/SlopedGrate/Other Base‐loaded False Coal Coal

ElectrostaticPrecipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

WINewPageKimberly B22 1

MajorSource WI Boiler 165 165 8760 1957 Stoker/SlopedGrate/Other Base‐loaded False Coal Coal

ElectrostaticPrecipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

WINewPage‐Whiting B24 1

MajorSource WI Boiler 211.4 211.4 8626 1976 Stoker/SlopedGrate/Other load following False Biomass Wet Biomass

ElectrostaticPrecipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

WINewPage‐WisconsinRapids

Power Boiler 1 ‐ 

B21 1

MajorSource WI Boiler 412.3 412.3 8623 1966 Stoker/SlopedGrate/Other load following False Biomass Wet Biomass

Electrostatic

Precipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

WINewPage‐WisconsinRapids

Power Boiler 2 ‐ 

B20 1

MajorSource WI Boiler 412.3 412.3 8623 1966 Stoker/SlopedGrate/Other load following False Biomass Wet Biomass

Electrostatic

Precipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

WIPCATomahawk B24 1

MajorSource WI Boiler 250.6 250.6 8312 1977 Stoker/SlopedGrate/Other Base‐loaded False Biomass Dry Biomass

Electrostatic

Precipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

WIPCATomahawk B27 1

MajorSource WI Boiler 122 122 8381 1955 Stoker/SlopedGrate/Other Base‐loaded False Biomass Dry Biomass

Electrostatic

Precipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

WIPCATomahawk B28 1

MajorSource WI Boiler 190.9 190.9 8397 1956 Stoker/SlopedGrate/Other Base‐loaded False Biomass Dry Biomass

Electrostatic

Precipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

WIThilmanyLLC B07 1

MajorSource WI Boiler 204 204 7989 1948 Stoker/SlopedGrate/Other load following False Biomass Wet Biomass Wet Scrubber

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

WIThilmanyLLC B11 1

MajorSource WI Boiler 379 379 8400 1967 Stoker/SlopedGrate/Other load following False Coal Coal

ElectrostaticPrecipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

WIThilmanyLLC B09 1

MajorSource WI Boiler 192.4 192.4 8657 1957 Stoker/SlopedGrate/Other False Coal Coal

ElectrostaticPrecipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

WIThilmanyPapersNicoletMill B23 1

MajorSource WI Boiler 105 105 8616 1960 Stoker/SlopedGrate/Other load following False Coal Coal

ElectrostaticPrecipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

WIThilmanyPapersNicoletMill B24 1

MajorSource WI Boiler 105 105 8616 1963 Stoker/SlopedGrate/Other load following False Coal Coal

ElectrostaticPrecipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

WIWausau

# 5 Power Boiler

(B24) 1

MajorSource WI Boiler 143 143 8520 1966 Stoker/SlopedGrate/Other load following False Coal Coal

ElectrostaticPrecipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

WIWausau

# 6 Power Boiler

(B20) 1

MajorSource WI Boiler 211.7 211.7 8600 1975 Stoker/SlopedGrate/Other load following False Coal Coal

ElectrostaticPrecipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 
FacilityID UnitID Unit CountMajor Source State ClassificatioCapacity (mCmapacity_Numeri Hours Per Year Installe Combustor Design Duty Cycle w NOx BurnAeCT Fuel Catego Baseline Fuel Cat Total Control Coal % Biomass % Liquid % Gas 2 %

F

WIWausauRhine B20 1

MajorSource WI Boiler 91 91 3000 1934 Stoker/SlopedGrate/Other Base‐loaded False Coal Coal Fabric Filter

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

WIWausauRhine B21 1

MajorSource WI Boiler 91 91 3000 1929 Stoker/SlopedGrate/Other Base‐loaded False Coal Coal Fabric Filter

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

WIWausauRhine B22 1

MajorSource WI Boiler 91 91 3000 1929 Stoker/SlopedGrate/Other Base‐loaded False Coal Coal Fabric Filter

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

WIWausauRhine B23 1

MajorSource WI Boiler 91 91 3000 1941 Stoker/SlopedGrate/Other Base‐loaded False Coal Coal Fabric Filter

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

WIWausauRhine B26 1

MajorSource WI Boiler 300 300 8600 1958 Stoker/SlopedGrate/Other Base‐loaded False Coal Coal

ElectrostaticPrecipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

WVGPMtHopeOSB

5600 ‐ Wellons

Energy System 1

MajorSource WV

ProcessHeater 240 240 8000 1995 Fuel Cell load following False Biomass Dry Biomass

Electrostatic

Precipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

WVJELD‐WENCraigsville Wood Fired Boiler 1

MajorSource WV Boiler 62.5 62.5 8760 1998 Stoker/SlopedGrate/Other load following False Biomass Dry Biomass

Electrostatic

Precipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

WVWeyerhaeuserBuckhannon 001‐01 1

MajorSource WV

ProcessHeater 116 116 8376 1995 Stoker/SlopedGrate/Other load following False Biomass Dry Biomass

ElectrostaticPrecipitator

Data Not Provided

Data Not Provided

Data Not Provided

Data Not Provided 

Represents Biomass, Coal, Liquid, Gas2 New In Inventory Added to Old, not in New (probably didn't get ICR) CISWI units kept in CISWI, not here

Shaded units indicate changes to EPA inventoryDeleted limited use units 554 Subtotal for filtered units (F9 to update)

1593 Total Unit Count 
FacilityID

ALAbitibiBowaterCPALAbitibiBowaterCPALAbitibiBowaterCPALAbitibiBowaterCPALBoiseWhitePaperJacksonALBrewtonALChapmanForestProductsALChapmanForestProductsALChapmanForestProductsALGeorgiaPacificNaheolaALGeorgiaPacificNaheolaALGeorgiaPacificNaheolaALGPBelkLumberALGPBrewtonMillALGPBrewtonMillALGPBrewtonMillALGPEngineeredWoodProductsThornsbyALGPPetermanPlyALGPTalladegaPlyALGulfLumberALIPCourtlandALIPCourtlandALIPCourtlandALIPPineHillALIPPineHillALIPPrattvilleALIPPrattvilleALIPRiverdaleALK‐CMobileALK‐CMobileALManningtonWoodFloorsALManningtonWoodFloorsALMeadwestvacoCottonton46ALMeadwestvacoCottonton46ALMeadwestvacoCottonton46ALP&WAlabamaRiverALP&WAlabamaRiverALP&WAlabamaRiverALRock‐TennDemopolisALRock‐TennDemopolisALScotchLumberALSeamanTimber

Hg %red

Dioxin 

Limit

Dioxin 

Emissions

Dioxin 

Difference

Dioxin 

%red CO Limit

CO 

Emissions

CO 

Difference CO %red

HCl 

Control 

Group

Hg 

Control 

Group

PM 

Control 

Group

Metals 

Control 

Group NAICS

PM Need 

Upgrade?

HCl Need 

Upgrade?

Hg Need 

Upgrade?

Dioxin 

Need 

Upgrade?

CO Need 

Upgrade? PM Upgrade Cost HCl Upgrade Cost Hg/Dioxin Upgrade Cost CO Upgra

#VALUE! 0.004 N/A N/A #VALUE! 160 N/A N/A #VALUE! 5 6 2 2 322 2 2 2 $4,462,402 $8,924,805 $1,000,000 

#VALUE! 0.004 N/A N/A #VALUE! 160 N/A N/A #VALUE! 5 6 2 2 322 2 2 2 $4,462,402 $8,924,805 $1,000,000 #VALUE! 0.004 N/A N/A #VALUE! 160 N/A N/A #VALUE! 5 6 2 2 322 2 2 2 $4,462,402 $8,924,805 $1,000,000 #VALUE! 0.004 N/A N/A #VALUE! 160 N/A N/A #VALUE! 5 6 2 2 322 2 2 2 $4,462,402 $8,924,805 $1,000,000 

0.005 0.009345 -0.00434 46.50% 490 400.4394 89.56063 4 5 3 3 322 1 1 $9,759,500 $0 $1,000,000 

#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 5 5 321 1 2 2 $3,205,084 $0 $1,000,000 $#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 4 5 3 3 321 1 2 2 $3,696,490 $0 $1,000,000 $#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 4 5 3 3 321 1 2 2 $2,580,424 $0 $1,000,000 $#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 4 5 3 3 321 1 2 2 $2,580,424 $0 $1,000,000 $

0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 2 2 322 2 2 2 $5,499,578 $0 $1,000,000 $0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 2 2 322 2 2 2 $4,621,173 $0 $1,000,000 $

#VALUE! 4 N/A N/A #VALUE! 10 N/A N/A #VALUE! 5 6 6 6 322 2 2 2 2 $8,984,989 $10,268,559 $1,000,000 $#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 2 2 321 2 2 $0 $0 $1,000,000 $

#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 2 2 322 2 2 $0 $0 $1,000,000 $#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 2 2 322 2 2 $0 $0 $1,000,000 $#VALUE! 4 N/A N/A #VALUE! 10 N/A N/A #VALUE! 5 6 6 6 322 1 2 2 2 $7,636,120 $8,726,994 $1,000,000 $

#VALUE! 0.005 N/A N/A #VALUE! 490 996.9221 -506.922 50.85% 1 4 4 4 321 1 2 1 $3,025,524 $0 $1,000,000 $#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 2 2 321 2 2 2 $3,744,939 $0 $1,000,000 $#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 2 2 321 2 2 2 $3,338,866 $0 $1,000,000 $#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 1 4 4 4 321 2 2 2 $3,205,084 $0 $1,000,000 $

0.004 N/A N/A #VALUE! 160 170.3968 -10.3968 6.10% 2 6 2 2 322 2 2 1 $7,639,561 $0 $1,000,000 $0.005 N/A N/A #VALUE! 490 160.3697 329.6303 4 5 3 3 322 2 2 $9,252,602 $0 $1,000,000 

0.02 0.003299 0.016701 430 39.81268 390.1873 5 6 2 2 322 $0 $0 $0 

#VALUE! 0.004 N/A N/A #VALUE! 160 N/A N/A #VALUE! 5 6 2 2 322 2 2 $0 $15,711,600 $1,000,000 

#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 2 2 322 1 2 2 $7,450,912 $0 $1,000,000 $

#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 2 2 322 1 2 2 $6,964,666 $0 $1,000,000 $#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 2 2 322 2 2 $0 $0 $1,000,000 $

#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 4 5 3 3 322 2 2 2 $6,915,661 $0 $1,000,000 $

#VALUE! 0.003 N/A N/A #VALUE! 270 N/A N/A #VALUE! 4 5 3 3 322 2 2 2 2 $13,532,274 $0 $1,000,000 $#VALUE! 0.004 N/A N/A #VALUE! 160 N/A N/A #VALUE! 5 6 2 2 322 2 2 2 $6,062,866 $12,125,733 $1,000,000 #VALUE! 0.005 N/A N/A #VALUE! 490 1309.168 -819.168 62.57% 5 6 2 2 321 2 1 $0 $0 $1,000,000 

#VALUE! 0.005 N/A N/A #VALUE! 490 1309.168 -819.168 62.57% 5 6 2 2 321 2 1 $0 $0 $1,000,000 

0.005 N/A N/A #VALUE! 490 2734.408 -2244.41 82.08% 4 5 3 3 322 1 2 1 $8,373,595 $0 $1,000,000 $

#VALUE! 0.005 N/A N/A #VALUE! 490 259.641 230.359 5 6 2 2 322 2 2 $6,419,683 $0 $1,000,000 #VALUE! 0.005 N/A N/A #VALUE! 490 121.8274 368.1726 4 5 3 3 322 2 $0 $0 $1,000,000 

#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 4 5 3 3 322 2 2 2 $9,826,653 $0 $1,000,000 $

#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 2 2 322 2 2 2 $3,392,721 $0 $1,000,000 $#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 4 5 3 3 322 2 2 2 $9,826,653 $0 $1,000,000 $#VALUE! 0.003 N/A N/A #VALUE! 270 N/A N/A #VALUE! 4 5 3 3 322 2 2 2 2 $7,000,000 $0 $1,000,000 $#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 4 5 3 3 322 2 2 2 $6,571,183 $0 $1,000,000 $#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 5 5 321 2 2 2 $4,003,094 $0 $1,000,000 $#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 5 5 321 2 2 2 $1,910,131 $0 $1,000,000 
FacilityID

ALSmurfit‐Stone

ALSmurfit‐StoneALSmurfit‐Stone

ALSmurfit‐Stone

ALWesterveltALWesterveltALWestFraserCitronelleALWestFraserMaplesvilleALWeyerhaeuserMillportARAnthonyForestProductsARAnthonyForestProductsARAnthonyForestProductsARDeltaNaturalKraftARDelticTimberWaldoARDelticTimberWaldoARDelticTimberWaldoARDel‐Tin

ARDomtarIndustriesARDomtarIndustriesARDomtarIndustriesAREvergreenPackagingAREvergreenPackagingARGBPMorriltonARGBPMorriltonARGeorgiaPacificCrossett93ARGeorgiaPacificCrossett93ARGeorgiaPacificFordyceARGPCrossett92ARGPCrossett92ARGPFordyceOSBARGPFordyceOSBARGPGurdonPlyLumberARGPGurdonPlyLumberARLeolaLumberMillARLeolaLumberMillARLeolaLumberMillARPotlatchForestCypressBendARPotlatchForestPrescottARPotlatchForestWarrenARRiversideFurniturePlant5ARTemple‐Inland

ARTemple‐Inland

Hg %red

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Dioxin 

Emissions

Dioxin 

Difference

Dioxin 

%red CO Limit

CO 

Emissions

CO 

Difference CO %red

HCl 

Control 

Group

Hg 

Control 

Group

PM 

Control 

Group

Metals 

Control 

Group NAICS

PM Need 

Upgrade?

HCl Need 

Upgrade?

Hg Need 

Upgrade?

Dioxin 

Need 

Upgrade?

CO Need 

Upgrade? PM Upgrade Cost HCl Upgrade Cost Hg/Dioxin Upgrade Cost CO Upgra

#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 2 2 322 2 2 2 $3,754,962 $0 $1,000,000 $

#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 2 2 322 2 2 2 $5,101,698 $0 $1,000,000 $#VALUE! 4 N/A N/A #VALUE! 10 N/A N/A #VALUE! 1 4 2 2 322 2 2 $3,173,696 $0 $0 $#VALUE! 4 N/A N/A #VALUE! 10 N/A N/A #VALUE! 1 4 2 2 322 2 2 $3,173,696 $0 $0 $#VALUE! 0.005 N/A N/A #VALUE! 490 432.518 57.48204 5 6 2 2 321 2 2 $2,280,508 $0 $1,000,000 #VALUE! 0.005 N/A N/A #VALUE! 490 159.4541 330.5459 5 6 2 2 321 2 2 $2,294,442 $0 $1,000,000 #VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 1 4 4 4 321 2 2 2 $3,792,098 $0 $1,000,000 $#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 4 5 3 3 321 1 2 2 $4,483,965 $0 $1,000,000 $#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 5 5 321 1 2 2 $4,392,914 $0 $1,000,000 $

4 0.007409 3.992591 690 654.2629 35.73714 5 6 5 5 321 1 $1,944,271 $0 $0 

#VALUE! 4 N/A N/A #VALUE! 690 N/A N/A #VALUE! 5 6 5 5 321 2 $1,944,271 $0 $0 #VALUE! 4 N/A N/A #VALUE! 690 541.3322 148.6678 5 6 5 5 321 2 $1,951,759 $0 $0 #VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 5 5 322 1 2 2 $5,355,574 $0 $1,000,000 $#VALUE! 0.005 N/A N/A #VALUE! 490 199.1758 290.8242 5 6 2 2 321 2 2 $1,698,974 $0 $1,000,000 #VALUE! 0.005 N/A N/A #VALUE! 490 266.9093 223.0907 5 6 2 2 321 2 2 $1,698,974 $0 $1,000,000 #VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 2 2 321 2 2 2 $1,698,974 $0 $1,000,000 $#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 2 2 321 2 2 2 $4,381,590 $0 $1,000,000 $#VALUE! 0.003 N/A N/A #VALUE! 270 N/A N/A #VALUE! 1 4 4 322 322 2 22 

#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 2 322 2 22 

#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 2 322 2 22 

#VALUE! 0.005 N/A N/A #VALUE! 490 502.7179 -12.7179 2.53% 4 5 3 3 322 2 2 1 $10,610,016 $0 $1,000,000 $

#VALUE! 4 N/A N/A #VALUE! 10 20.95782 -10.9578 52.29% 5 6 6 6 322 2 2 2 1 $11,836,540 $13,527,475 $1,000,000 $#VALUE! 0.005 N/A N/A #VALUE! 490 1068.183 -578.183 54.13% 5 6 5 5 322 1 2 1 $5,395,641 $0 $1,000,000 $

0.005 0.011704 -0.0067 57.28% 490 459.7391 30.26088 4 5 3 3 322 1 1 $9,986,587 $0 $1,000,000 

#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 1 4 4 4 321 2 2 2 $6,915,661 $0 $1,000,000 $#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 2 2 321 2 2 2 $3,951,806 $0 $1,000,000 $#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 1 4 4 4 321 1 2 2 $5,843,016 $0 $1,000,000 $#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 1 4 4 4 322 2 2 $0 $0 $1,000,000 $

#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 1 4 4 4 322 2 2 2 $13,204,852 $0 $1,000,000 $

#VALUE! 0.2 N/A N/A #VALUE! 470 N/A N/A #VALUE! 5 6 5 5 321 2 2 2 $2,331,149 $0 $1,000,000 #VALUE! 0.2 N/A N/A #VALUE! 470 N/A N/A #VALUE! 5 6 5 5 321 2 2 2 $2,331,149 $0 $1,000,000 #VALUE! 0.005 N/A N/A #VALUE! 490 339.1004 150.8996 4 5 3 3 321 2 2 $4,836,535 $0 $1,000,000 #VALUE! 0.005 N/A N/A #VALUE! 490 321.0572 168.9428 4 5 3 3 321 2 2 $4,836,535 $0 $1,000,000 #VALUE! 0.005 N/A N/A #VALUE! 490 237.9658 252.0342 5 6 2 2 321 2 $0 $0 $1,000,000 

#VALUE! 0.005 N/A N/A #VALUE! 490 391.8251 98.17495 5 6 2 2 321 2 $0 $0 $1,000,000 #VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 5 5 321 2 2 2 $1,914,122 $0 $1,000,000 

#VALUE! 4 N/A N/A #VALUE! 10 57.5983 -47.5983 82.64% 5 6 6 6 322 1 2 2 1 $10,340,352 $11,817,546 $1,000,000 $#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 2 2 321 2 2 $0 $0 $1,000,000 $

0.005 0.010353 -0.00535 51.70% 490 285.9735 204.0265 5 6 2 2 321 1 $0 $0 $1,000,000 

#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 5 5 321 2 2 2 $1,514,798 $0 $1,000,000 

#VALUE! 0.2 N/A N/A #VALUE! 470 N/A N/A #VALUE! 5 6 5 5 321 2 2 2 $2,331,149 $0 $1,000,000 #VALUE! 0.2 N/A N/A #VALUE! 470 N/A N/A #VALUE! 5 6 5 5 321 2 2 2 $2,331,149 $0 $1,000,000 
FacilityID

ARTemple‐Inland

ARWestFraserHuttigARWestFraserHuttigARWeyerhaeuserARWeyerhaeuserDierksMillAZCatalystPaperSnowflakeAZCatalystPaperSnowflakeCAHumboldtFlakeboard143CARoseburgWeedCASierraPine‐Rocklin

FLCFRC252FLCFRC252FLGPHawthorneFLGPHosfordOSBFLGPHosfordOSBFLGPPalatkaFLIPPensacolaFLIPPensacolaFLNorthFloridaLumberFLNorthFloridaLumberFLRayonierPerformanceFLSmurfit‐StoneFLSmurfit‐StoneFLSmurfit‐StoneFLSmurfit‐StoneFLSmurfitStonePanamaCityFLSmurfitStonePanamaCityGAAbitibiBowaterGACaraustarGAGPCedarSpringsGAGPCedarSpringsGAGPCelluloseBrunswickGAGPCelluloseBrunswickGAGPCelluloseBrunswickGAGPMadisonPlyGAGPMonticelloPlywoodGAGPSRMRiinconGAGPSRMRiinconGAGPSRMRiinconGAGPWarmSpringsGAGPWarrentonGAGPWoodClaxton

Hg %red

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Dioxin 

Emissions

Dioxin 

Difference

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%red CO Limit

CO 

Emissions

CO 

Difference CO %red

HCl 

Control 

Group

Hg 

Control 

Group

PM 

Control 

Group

Metals 

Control 

Group NAICS

PM Need 

Upgrade?

HCl Need 

Upgrade?

Hg Need 

Upgrade?

Dioxin 

Need 

Upgrade?

CO Need 

Upgrade? PM Upgrade Cost HCl Upgrade Cost Hg/Dioxin Upgrade Cost CO Upgra

#VALUE! 0.2 N/A N/A #VALUE! 470 N/A N/A #VALUE! 5 6 5 5 321 2 2 2 $2,331,149 $0 $1,000,000 

#VALUE! 0.005 N/A N/A #VALUE! 490 64.80667 425.1933 5 6 5 5 321 1 2 $1,947,032 $0 $1,000,000 #VALUE! 0.005 N/A N/A #VALUE! 490 475.1572 14.84284 5 6 5 5 321 1 2 $4,461,319 $0 $1,000,000 #VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 5 5 321 1 2 2 $3,493,460 $0 $1,000,000 $

4 0.021378 3.978622 690 152.1682 537.8318 5 6 2 2 321 $0 $0 $0 

#VALUE! 0.004 N/A N/A #VALUE! 160 2.226869 157.7731 1 4 2 2 322 2 $0 $0 $1,000,000 

#VALUE! 4 N/A N/A #VALUE! 10 N/A N/A #VALUE! 5 6 6 6 322 2 2 2 2 $8,373,595 $9,569,823 $1,000,000 $

#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 5 5 321 2 2 2 $2,331,149 $0 $1,000,000 #VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 2 2 321 2 2 $0 $0 $1,000,000 $

#VALUE! 0.2 N/A N/A #VALUE! 470 N/A N/A #VALUE! 4 5 2 2 321 2 2 $0 $0 $1,000,000 $

0.005 N/A N/A #VALUE! 490 363.9491 126.0509 1 4 4 4 321 2 2 $3,664,252 $0 $1,000,000 

#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 5 5 321 2 2 2 $1,957,658 $0 $1,000,000 #VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 2 2 321 2 2 $0 $0 $1,000,000 $

#VALUE! 0.2 N/A N/A #VALUE! 470 N/A N/A #VALUE! 5 6 2 2 321 2 2 2 $1,332,085 $0 $1,000,000 

#VALUE! 0.2 N/A N/A #VALUE! 470 N/A N/A #VALUE! 5 6 2 2 321 2 2 2 $1,332,085 $0 $1,000,000 #VALUE! 0.005 N/A N/A #VALUE! 490 301.1009 188.8991 5 6 2 2 322 1 2 $6,154,800 $0 $1,000,000 

44.71% 0.004 N/A N/A #VALUE! 160 N/A N/A #VALUE! 4 5 3 3 322 2 1 2 $8,521,808 $0 $1,000,000 

0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 4 5 3 3 322 2 2 2 $12,601,393 $0 $1,000,000 $

#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 5 5 321 2 2 2 $1,672,518 $0 $1,000,000 #VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 5 5 321 2 2 2 $2,431,131 $0 $1,000,000 $

0.02 N/A N/A #VALUE! 430 72.01906 357.9809 1 4 2 2 322 1 $6,242,975 $0 $0 

0.004 N/A N/A #VALUE! 160 15.2574 144.7426 5 6 2 2 322 1 2 $0 $18,609,788 $1,000,000 

#VALUE! 0.004 N/A N/A #VALUE! 160 N/A N/A #VALUE! 4 5 3 3 322 2 2 2 $8,927,972 $0 $1,000,000 

0.005 N/A N/A #VALUE! 490 387.5904 102.4096 5 6 2 2 322 2 $0 $0 $1,000,000 

#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 4 5 3 3 322 2 2 2 $8,927,972 $0 $1,000,000 $

#VALUE! 0.003 N/A N/A #VALUE! 270 N/A N/A #VALUE! 1 4 4 4 322 2 2 2 $11,173,055 $0 $1,000,000 $#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 1 4 4 4 322 2 2 2 $10,673,549 $0 $1,000,000 $#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 4 5 3 3 322 2 2 2 $7,411,970 $0 $1,000,000 $

0.004 N/A N/A #VALUE! 160 N/A N/A #VALUE! 5 3 1 1 322 1 1 2 $4,577,439 $9,154,878 $1,000,000 

#VALUE! 0.004 N/A N/A #VALUE! 160 N/A N/A #VALUE! 4 5 3 3 322 1 2 2 $13,897,084 $0 $1,000,000 

0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 4 5 3 3 322 1 2 2 $13,897,084 $0 $1,000,000 $0.005 N/A N/A #VALUE! 490 217.2575 272.7425 5 6 2 2 322 2 $0 $0 $1,000,000 

#VALUE! 4 N/A N/A #VALUE! 10 N/A N/A #VALUE! 5 6 2 2 322 2 2 2 $0 $7,164,139 $1,000,000 $

#VALUE! 4 N/A N/A #VALUE! 10 1.453583 8.546417 5 6 2 2 322 1 2 2 $5,060,775 $10,121,550 $1,000,000 

0.005 0.002012 0.002988 490 2475.007 -1985.01 80.20% 5 6 2 2 321 1 $0 $0 $0 $

0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 2 2 321 2 2 $0 $0 $1,000,000 $

0.002 N/A N/A #VALUE! 82 N/A N/A #VALUE! 3 2 1 1 322 1 2 $5,476,252 $0 $1,000,000 

0.002 N/A N/A #VALUE! 82 N/A N/A #VALUE! 3 2 1 1 322 2 $0 $0 $1,000,000 

#VALUE! 0.002 N/A N/A #VALUE! 82 N/A N/A #VALUE! 3 2 1 1 322 2 $0 $0 $1,000,000 

0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 5 5 321 1 2 2 $5,747,746 $0 $1,000,000 $

#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 2 2 321 2 2 $0 $0 $1,000,000 $

#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 2 2 321 2 2 $0 $0 $1,000,000 $
FacilityID

GAGraphicPackagingGAGraphicPackagingGAGraphicPackagingGAInternationalPaperAugustaMillsGAInternationalPaperAugustaMillsGAInternationalPaperAugustaMillsGAInterstateResourcesGAInterstateResourcesGAIPSavannahGALangboardWillacoocheeGALouisianaPacificAthensGAP&GAlbanyGAP&GAlbanyGAPCAValdostaGAPCAValdostaGARayonierBaxleyGARayonierBaxleyGARayonierJesupMillGARayonierJesupMillGARayonierJesupMillGARoseburgForestViennaGASPNewsprintGASPNewsprintGATempleInlandRomeGATempleInlandRomeGATempleInlandThomsonGATempleInlandThomsonGAWestFraserFolkstonGAWestFraserFolkstonGAWeyerhaeuserCoOglethorpeGAWYPortWentworthIA3MKnoxvilleIA3MKnoxvilleIAJELD‐WENDubuqueIDChilcoLakeSawmillIDMoyieSprings Lumber420IDPotlatchIDPotlatchIDPotlatchIDRileyCreekLumberIDRileyCreekLumberINJasperSeating9

Hg %red

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Dioxin 

Emissions

Dioxin 

Difference

Dioxin 

%red CO Limit

CO 

Emissions

CO 

Difference CO %red

HCl 

Control 

Group

Hg 

Control 

Group

PM 

Control 

Group

Metals 

Control 

Group NAICS

PM Need 

Upgrade?

HCl Need 

Upgrade?

Hg Need 

Upgrade?

Dioxin 

Need 

Upgrade?

CO Need 

Upgrade? PM Upgrade Cost HCl Upgrade Cost Hg/Dioxin Upgrade Cost CO Upgra

#VALUE! 0.004 N/A N/A #VALUE! 160 N/A N/A #VALUE! 4 5 3 3 322 2 2 2 $8,927,972 $0 $1,000,000 

#VALUE! 0.004 N/A N/A #VALUE! 160 N/A N/A #VALUE! 4 5 3 3 322 2 2 2 $5,899,684 $0 $1,000,000 #VALUE! 0.004 N/A N/A #VALUE! 160 N/A N/A #VALUE! 4 5 3 3 322 2 2 2 $5,899,684 $0 $1,000,000 

0.004 N/A N/A #VALUE! 160 N/A N/A #VALUE! 5 6 2 2 322 1 2 $0 $14,659,544 $1,000,000 

0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 4 5 3 3 322 1 2 2 $12,759,668 $0 $1,000,000 $

0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 2 2 322 2 2 $0 $0 $1,000,000 $

#VALUE! 0.02 N/A N/A #VALUE! 430 N/A N/A #VALUE! 1 4 2 2 322 2 $4,000,000 $0 $0 

#VALUE! 4 N/A N/A #VALUE! 10 N/A N/A #VALUE! 5 6 6 6 322 2 2 2 2 $5,899,684 $6,742,496 $1,000,000 $#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 2 2 322 2 2 $0 $0 $1,000,000 $

#VALUE! 0.02 N/A N/A #VALUE! 430 N/A N/A #VALUE! 5 6 2 2 321 2 $3,338,866 $0 $0 

#VALUE! 0.2 N/A N/A #VALUE! 470 N/A N/A #VALUE! 5 6 2 2 321 2 2 2 $1,332,085 $0 $1,000,000 #VALUE! 0.005 N/A N/A #VALUE! 490 384.4832 105.5168 5 6 2 2 322 2 $0 $0 $1,000,000 

#VALUE! 4 N/A N/A #VALUE! 10 N/A N/A #VALUE! 5 6 6 6 322 2 2 2 2 $5,880,835 $6,720,954 $1,000,000 $

#VALUE! 0.005 N/A N/A #VALUE! 490 3420.103 -2930.1 85.67% 4 5 3 3 322 1 2 1 $6,881,733 $0 $1,000,000 $#VALUE! 0.005 N/A N/A #VALUE! 490 3420.103 -2930.1 85.67% 4 5 3 3 322 1 2 1 $8,711,953 $0 $1,000,000 $#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 4 5 3 3 321 1 2 2 $2,935,583 $0 $1,000,000 $#VALUE! 0.005 N/A N/A #VALUE! 490 350.2887 139.7113 5 6 2 2 321 2 $0 $0 $1,000,000 

0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 1 4 4 4 322 1 2 2 $5,670,765 $0 $1,000,000 $

#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 2 6 5 5 322 1 2 2 $8,010,519 $0 $1,000,000 $#VALUE! 0.005 N/A N/A #VALUE! 490 347.8726 142.1274 4 5 3 3 322 1 2 $11,978,016 $0 $1,000,000 

0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 5 5 321 2 2 2 $2,769,302 $0 $1,000,000 $

#VALUE! 0.004 N/A N/A #VALUE! 160 N/A N/A #VALUE! 5 6 2 2 322 1 2 2 $3,990,392 $7,980,785 $1,000,000 

0.002 N/A N/A #VALUE! 82 117.6226 -35.6226 30.29% 5 6 2 2 322 2 1 $0 $0 $1,000,000 $

#VALUE! 0.005 N/A N/A #VALUE! 490 130.3333 359.6667 5 6 2 2 322 2 $0 $0 $1,000,000 

0.02 0.009674 0.010326 430 129.2 300.8 5 6 2 2 322 $0 $0 $0 

#VALUE! 0.2 N/A N/A #VALUE! 470 563.5428 -93.5428 16.60% 5 6 2 2 321 2 2 1 $1,332,085 $0 $1,000,000 

#VALUE! 0.2 N/A N/A #VALUE! 470 N/A N/A #VALUE! 5 6 5 5 321 2 2 2 $1,961,583 $0 $1,000,000 #VALUE! 0.005 N/A N/A #VALUE! 490 13303.34 -12813.3 96.32% 5 6 5 5 321 2 2 1 $1,932,407 $0 $1,000,000 #VALUE! 0.005 N/A N/A #VALUE! 490 9463.896 -8973.9 94.82% 5 6 5 5 321 2 2 1 $1,902,133 $0 $1,000,000 #VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 4 5 3 3 322 1 2 2 $12,533,155 $0 $1,000,000 $#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 562 322 2 2 2 $5,101,698 $0 $1,000,000 $#VALUE! 4 N/A N/A #VALUE! 10 N/A N/A #VALUE! 5 6 6 6 322 2 2 2 2 $3,316,909 $3,790,753 $1,000,000 $#VALUE! 4 N/A N/A #VALUE! 10 N/A N/A #VALUE! 5 6 6 6 322 2 2 2 2 $3,316,909 $3,790,753 $1,000,000 $#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 5 5 321 2 2 2 $3,690,057 $0 $1,000,000 $#VALUE! 0.005 N/A N/A #VALUE! 490 51.0253 438.9747 5 6 2 2 321 2 $0 $0 $1,000,000 

0.005 N/A N/A #VALUE! 490 1883.684 -1393.68 73.99% 5 6 2 2 321 2 1 $0 $0 $1,000,000 $

4 0.5656 3.4344 690 272.1349 417.8651 5 6 2 2 321 $0 $0 $0 

0.005 N/A N/A #VALUE! 490 454.9756 35.02441 5 6 2 2 321 2 $0 $0 $1,000,000 

0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 2 2 321 2 2 2 $1,325,581 $0 $1,000,000 

#VALUE! 0.005 N/A N/A #VALUE! 490 161.3135 328.6865 5 6 2 2 321 2 $0 $0 $1,000,000 

#VALUE! 0.005 N/A N/A #VALUE! 490 1308.888 -818.888 62.56% 5 6 2 2 321 1 2 1 $1,826,462 $0 $1,000,000 $

#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 6 5 321 2 2 2 $1,044,835 $0 $1,000,000 
FacilityID

INKimballOfficeJasperINKimballOfficeSalemINKimballOfficeSalemINNOFJasperINNOFJasperINNOFJasperKYDomtarHawesvilleKYHONCoOwensboroKYNewPage‐Wickliffe

KYWeyerhaeuserEKYKYWeyerhaeuserEKYKYWeyerhaeuserEKYLABoiseCascadeFlorienLABoiseCascadeOakdaleLABoiseNewsprintDeRidderLABoiseNewsprintDeRidderLAGPLogansportPlyLAGPPortHudsonLAGPPortHudsonLAGPSpringhillWoodLAGraphic Packaging

LAHoodIndustriesLAHoodIndustriesLAHuntNatalbanyLAHuntPollockLAHuntPollock

LAInternationalPaperRedRiverMillLAIPMansfieldLAIPMansfieldLASmurfit‐Stone

LATempleInlandBogalusaLATempleInlandBogalusaLAWestFraserJoyceLAWestFraserJoyceLAWestFraserJoyceLAWeyerhaeuser1043LAWeyerhaeuserDodsonMAHollingsworth&voseMAMWCustomPapersMAMWCustomPapersMANewarkAmericaMDNewPage‐Luke

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Upgrade? PM Upgrade Cost HCl Upgrade Cost Hg/Dioxin Upgrade Cost CO Upgra

#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 5 5 321 2 2 2 $1,560,941 $0 $1,000,000 

#VALUE! 0.003 N/A N/A #VALUE! 270 N/A N/A #VALUE! 5 6 5 5 321 2 2 2 2 $2,313,621 $2,644,139 $1,000,000 #VALUE! 0.003 N/A N/A #VALUE! 270 N/A N/A #VALUE! 5 6 5 5 321 2 2 2 2 $2,313,621 $2,644,139 $1,000,000 #VALUE! 0.003 N/A N/A #VALUE! 270 N/A N/A #VALUE! 5 6 5 5 321 2 2 2 2 $1,582,678 $1,808,775 $1,000,000 #VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 6 5 321 2 2 2 $1,044,058 $0 $1,000,000 #VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 6 5 321 2 2 2 $1,044,058 $0 $1,000,000 #VALUE! 0.02 N/A N/A #VALUE! 430 111.6637 318.3363 5 6 2 2 322 $0 $0 $0 

#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 6 5 321 2 2 2 $4,231,545 $0 $1,000,000 $

0.005 N/A N/A #VALUE! 490 265.0952 224.9048 5 6 2 2 322 2 $0 $0 $1,000,000 

#VALUE! 4 N/A N/A #VALUE! 690 109.5222 580.4778 5 6 2 2 321 1 $1,942,373 $0 $0 

#VALUE! 4 N/A N/A #VALUE! 690 N/A N/A #VALUE! 5 6 2 2 321 1 $1,942,373 $0 $0 #VALUE! 4 N/A N/A #VALUE! 690 109.5222 580.4778 5 6 2 2 321 1 $1,942,373 $0 $0 #VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 1 4 4 4 321 1 2 2 $4,900,738 $0 $1,000,000 $#VALUE! 0.005 N/A N/A #VALUE! 490 1448.817 -958.817 66.18% 5 6 5 5 321 2 1 $0 $0 $1,000,000 $

0.005 N/A N/A #VALUE! 490 602.5834 -112.583 18.68% 4 5 3 3 322 1 2 1 $21,251,289 $0 $1,000,000 $

#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 4 5 3 3 322 2 2 2 $10,016,914 $0 $1,000,000 $#VALUE! 0.005 N/A N/A #VALUE! 490 342.8737 147.1263 1 4 4 4 321 1 2 $6,518,472 $0 $1,000,000 #VALUE! 0.005 N/A N/A #VALUE! 490 1260.465 -770.465 61.13% 4 5 3 3 322 2 2 1 $10,081,732 $0 $1,000,000 $#VALUE! 0.02 N/A N/A #VALUE! 430 N/A N/A #VALUE! 2 6 2 2 322 $0 $0 $0 

#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 1 4 4 4 321 2 2 2 $6,283,076 $0 $1,000,000 $

#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 4 5 3 3 322 2 2 2 $13,532,274 $0 $1,000,000 $#VALUE! 0.005 N/A N/A #VALUE! 490 1768.444 -1278.44 72.29% 5 6 5 5 321 2 2 1 $3,044,001 $0 $1,000,000 $#VALUE! 0.005 N/A N/A #VALUE! 490 2329.841 -1839.84 78.97% 5 6 5 5 321 2 2 1 $3,044,001 $0 $1,000,000 $#VALUE! 0.005 N/A N/A #VALUE! 490 1569.911 -1079.91 68.79% 5 6 5 5 321 2 2 1 $3,849,950 $0 $1,000,000 $#VALUE! 0.005 N/A N/A #VALUE! 490 584.8403 -94.8403 16.22% 5 6 5 5 321 2 2 1 $3,017,582 $0 $1,000,000 $#VALUE! 0.005 N/A N/A #VALUE! 490 3566.918 -3076.92 86.26% 5 6 5 5 321 2 2 1 $3,533,361 $0 $1,000,000 $#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 2 322 2 22 

#VALUE! 0.003 N/A N/A #VALUE! 270 N/A N/A #VALUE! 5 6 2 322 22 22 

0.003 N/A N/A #VALUE! 270 N/A N/A #VALUE! 5 6 2 322 2 22 

#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 5 5 322 2 2 2 $13,532,274 $0 $1,000,000 $

#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 1 4 4 4 322 2 2 2 $10,538,556 $0 $1,000,000 $#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 1 4 4 4 322 2 2 2 $13,934,275 $0 $1,000,000 $#VALUE! 0.005 N/A N/A #VALUE! 490 2331.176 -1841.18 78.98% 5 6 5 5 321 1 2 1 $2,922,370 $0 $1,000,000 $#VALUE! 0.005 N/A N/A #VALUE! 490 1606.367 -1116.37 69.50% 5 6 5 5 321 1 2 1 $2,922,370 $0 $1,000,000 $#VALUE! 0.005 N/A N/A #VALUE! 490 1741.834 -1251.83 71.87% 5 6 5 5 321 1 2 1 $5,238,231 $0 $1,000,000 $#VALUE! 0.005 N/A N/A #VALUE! 490 375.5549 114.4451 5 6 2 2 321 2 $0 $0 $1,000,000 

#VALUE! 0.005 N/A N/A #VALUE! 490 433.2898 56.71016 5 6 2 2 321 2 $0 $0 $1,000,000 #VALUE! 4 N/A N/A #VALUE! 10 N/A N/A #VALUE! 5 6 6 6 322 2 2 2 2 $2,649,093 $3,027,535 $1,000,000 $

#VALUE! 4 N/A N/A #VALUE! 10 N/A N/A #VALUE! 5 6 6 6 322 2 2 2 2 $2,242,605 $2,562,977 $1,000,000 #VALUE! 4 N/A N/A #VALUE! 10 N/A N/A #VALUE! 5 6 6 6 322 2 2 2 2 $2,600,631 $2,972,150 $1,000,000 $#VALUE! 4 N/A N/A #VALUE! 10 1.316966 8.683034 5 6 6 6 322 2 2 $0 $7,609,615 $1,000,000 

76.69% 0.003 N/A N/A #VALUE! 270 290.9382 -20.9382 7.20% 5 3 1 1 322 2 1 2 1 $0 $13,391,746 $1,000,000 $
FacilityID

MDNewPage‐Luke

MEDomtarBaileyville

MEHuberEngineeredWoodLLCMEKatahdinPaperCoMEKatahdinPaperCoMEKatahdinPaperCoMELincolnPaper&TissueMELincolnPaper&TissueMEMadisonPaperMEMadisonPaperMEMadisonPaperMENewPage‐RumfordMENewPage‐RumfordMENewPage‐RumfordMERedShieldMERedShieldMESappiWestbrookMESappiWestbrookMESappiWestbrookMESappiWestbrookMESDWarrenMESDWarrenMESDWarrenSomersetMESDWarrenSomersetMEVersoPaperMEVersoPaperMEVersoPaperAndroscogginMIDecorativePanelsMIDecorativePanelsMIDecorativePanelsMIEBEddyPaperMILPCSagolaMIManistiquePaperMIManistiquePaperMIMenomineeMIMenomineeMINeenahPaperMIMINewPageEscanabaMINewPageEscanabaMINewPageEscanabaMINewPageEscanabaMIPackagingCorpofAmerica

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PM Need 

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Need 

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CO Need 

Upgrade? PM Upgrade Cost HCl Upgrade Cost Hg/Dioxin Upgrade Cost CO Upgra

11.71% 0.004 N/A N/A #VALUE! 160 131.0361 28.96385 5 3 1 1 322 1 2 $0 $0 $1,000,000 

#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 4 5 3 3 322 1 2 2 $12,130,035 $0 $1,000,000 $

#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 2 321 2 2 2 $2,079,043 $0 $1,000,000 $#VALUE! 4 N/A N/A #VALUE! 10 N/A N/A #VALUE! 5 6 6 6 322 2 2 2 2 $8,856,356 $10,121,550 $1,000,000 $#VALUE! 4 N/A N/A #VALUE! 10 N/A N/A #VALUE! 5 6 6 6 322 2 2 2 2 $8,856,356 $10,121,550 $1,000,000 $#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 2 2 322 2 2 2 $6,048,304 $0 $1,000,000 $

0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 2 2 322 2 2 2 $5,561,459 $0 $1,000,000 $

#VALUE! 4 N/A N/A #VALUE! 10 N/A N/A #VALUE! 5 6 6 6 322 2 2 2 2 $1,292,920 $1,477,622 $1,000,000 #VALUE! 4 N/A N/A #VALUE! 10 N/A N/A #VALUE! 5 6 6 6 322 2 2 2 2 $4,438,595 $5,072,680 $1,000,000 $#VALUE! 4 N/A N/A #VALUE! 10 N/A N/A #VALUE! 5 6 6 6 322 2 2 2 2 $4,015,274 $4,588,884 $1,000,000 $#VALUE! 4 N/A N/A #VALUE! 10 N/A N/A #VALUE! 5 6 6 6 322 2 2 2 2 $4,483,965 $5,124,531 $1,000,000 $

0.02 N/A N/A #VALUE! 430 14.60129 415.3987 3 6 2 2 322 $0 $0 $0 

#VALUE! 4 N/A N/A #VALUE! 10 N/A N/A #VALUE! 4 5 3 3 322 1 2 $7,809,204 $0 $0 $

0.02 N/A N/A #VALUE! 430 14.60129 415.3987 3 6 2 2 322 $0 $0 $0 

#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 562 322 2 2 2 $3,371,248 $0 $1,000,000 $#VALUE! 4 N/A N/A #VALUE! 10 N/A N/A #VALUE! 5 6 6 6 322 2 2 2 2 $7,000,000 $8,000,000 $1,000,000 $

#VALUE! 4 N/A N/A #VALUE! 10 N/A N/A #VALUE! 566 322 2 2 2 2 $5,899,684 $6,742,496 $1,000,000 $#VALUE! 4 N/A N/A #VALUE! 10 N/A N/A #VALUE! 566 322 2 2 2 2 $6,358,604 $7,266,976 $1,000,000 $#VALUE! 4 N/A N/A #VALUE! 10 N/A N/A #VALUE! 566 322 2 2 2 2 $6,358,604 $7,266,976 $1,000,000 $#VALUE! 0.004 N/A N/A #VALUE! 160 N/A N/A #VALUE! 562 322 2 2 2 $8,300,446 $16,600,893 $1,000,000 

0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 2 2 322 2 2 $0 $0 $1,000,000 $

#VALUE! 4 N/A N/A #VALUE! 10 N/A N/A #VALUE! 5 6 6 6 322 2 2 2 2 $5,899,684 $6,742,496 $1,000,000 $

#VALUE! 0.005 N/A N/A #VALUE! 490 275.416 214.584 5 6 2 2 322 2 $0 $0 $1,000,000 

0.005 N/A N/A #VALUE! 490 204.7091 285.2909 2 6 2 2 322 2 $0 $0 $1,000,000 

#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 2 2 322 2 2 $0 $0 $1,000,000 $#VALUE! 4 N/A N/A #VALUE! 10 N/A N/A #VALUE! 5 6 6 6 322 2 2 2 2 $8,870,710 $10,137,954 $1,000,000 $

#VALUE! 0.005 N/A N/A #VALUE! 490 1396.063 -906.063 64.90% 4 5 3 3 322 1 2 1 $10,353,299 $0 $1,000,000 $#VALUE! 0.003 N/A N/A #VALUE! 270 N/A N/A #VALUE! 5 6 2 2 321 2 2 2 2 $2,252,468 $4,504,937 $1,000,000 $#VALUE! 0.003 N/A N/A #VALUE! 270 N/A N/A #VALUE! 5 6 2 2 321 2 2 2 2 $2,252,468 $4,504,937 $1,000,000 $#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 5 5 321 2 2 2 $3,506,794 $0 $1,000,000 $

38.09% 0.004 N/A N/A #VALUE! 160 N/A N/A #VALUE! 5 6 2 2 322 2112 $3,456,604 $6,913,208 $1,000,000 

#VALUE! 0.005 N/A N/A #VALUE! 490 67.95856 422.0414 5 6 5 5 321 1 2 $2,973,205 $0 $1,000,000 

0.003 N/A N/A #VALUE! 270 N/A N/A #VALUE! 5 6 2 2 322 1 2 2 $0 $18,901,304 $1,000,000 $

0.003 N/A N/A #VALUE! 270 N/A N/A #VALUE! 5 6 2 2 322 1 2 2 $0 $15,336,673 $1,000,000 $

#VALUE! 0.003 N/A N/A #VALUE! 270 N/A N/A #VALUE! 5 3 1 1 322 2 2 2 2 $0 $4,092,399 $1,000,000 $

30.34% 0.003 N/A N/A #VALUE! 270 N/A N/A #VALUE! 5 3 1 1 322 1 1 2 2 $0 $4,644,284 $1,000,000 $

0.003 N/A N/A #VALUE! 270 N/A N/A #VALUE! 5 3 1 1 322 1 2 2 $0 $7,039,419 $1,000,000 $

#VALUE! 0.004 N/A N/A #VALUE! 160 N/A N/A #VALUE! 5 6 2 2 322 2 2 2 $8,843,368 $17,686,736 $1,000,000 

#VALUE! 4 N/A N/A #VALUE! 10 N/A N/A #VALUE! 5 6 6 6 322 2 2 2 2 $5,234,154 $5,981,890 $1,000,000 $#VALUE! 4 N/A N/A #VALUE! 10 N/A N/A #VALUE! 5 6 6 6 322 2 2 2 2 $11,393,026 $13,020,601 $1,000,000 $#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 1 4 4 4 322 2 2 2 $11,393,026 $0 $1,000,000 $#VALUE! 0.004 N/A N/A #VALUE! 160 N/A N/A #VALUE! 5 3 1 1 322 2 2 2 $0 $7,806,435 $1,000,000 
FacilityID

MISmurfitStoneOntonagonMIVersoPaperQuinnesecMN3MHutchinsonMN3MHutchinsonMNAndersonCorpBayportMNAndersonCorpBayportMNBoisePaper1212MNGPDuluthMNGPDuluthMNGPDuluthMNGPDuluthMNGPDuluthMNNorbordMinnesotaMNNorbordMinnesotaMNSappiCloquetMNSappiCloquetMNVersoPaperMNVersoPaperMNWausauPaper‐BrainerdMNWausauPaper‐BrainerdMNWausauPaper‐BrainerdMNWeyerhaeuserIrontonMSBowaterSouthMSGeorgiaPacificMonticelloMSGPBaySpringsMSGPBaySpringsMSGPGlosterPlyMSGPGlosterPlyMSGPGlosterPlyMSGPLouisvillePlyMSGPNewAugustaMSGPTaylorsvillePlyMSGPTaylorsvillePlyMSGPTylertownMillMSHankinsLumberMSHankinsLumberMSHoodBeaumontMSHoodWaynesboroMSHoodWigginsMSHoodWigginsMSHoodWigginsMSIPVicksburg

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Difference

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%red CO Limit

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PM 

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PM Need 

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HCl Need 

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Hg Need 

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Dioxin 

Need 

Upgrade?

CO Need 

Upgrade? PM Upgrade Cost HCl Upgrade Cost Hg/Dioxin Upgrade Cost CO Upgra

#VALUE! 0.004 N/A N/A #VALUE! 160 N/A N/A #VALUE! 3 6 2 2 322 2 2 $5,101,698 $0 $1,000,000 

0.005 N/A N/A #VALUE! 490 109.1374 380.8626 5 6 2 2 322 2 $0 $0 $1,000,000 

#VALUE! 4 N/A N/A #VALUE! 10 N/A N/A #VALUE! 5 6 6 6 322 2 2 2 2 $4,277,299 $4,888,342 $1,000,000 $

#VALUE! 4 N/A N/A #VALUE! 10 N/A N/A #VALUE! 5 6 6 6 322 2 2 2 2 $4,277,299 $4,888,342 $1,000,000 $#VALUE! 0.005 N/A N/A #VALUE! 490 31.40845 458.5915 5 6 2 2 321 2 $0 $0 $1,000,000 

#VALUE! 0.005 N/A N/A #VALUE! 490 31.40845 458.5915 5 6 2 2 321 2 $0 $0 $1,000,000 

0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 2 2 322 2 2 $0 $0 $1,000,000 $

#VALUE! 4 N/A N/A #VALUE! 10 N/A N/A #VALUE! 5 6 6 6 321 2 2 2 2 $2,434,530 $2,782,320 $1,000,000 $

#VALUE! 4 N/A N/A #VALUE! 10 N/A N/A #VALUE! 5 6 6 6 321 2 2 2 2 $2,434,530 $2,782,320 $1,000,000 $#VALUE! 0.2 N/A N/A #VALUE! 470 N/A N/A #VALUE! 5 6 2 2 321 2 2 2 $1,698,974 $0 $1,000,000 $#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 2 2 321 2 2 2 $797,196 $0 $1,000,000 

4 0.010391 3.989609 10 77.82179 -67.8218 87.15% 5 6 2 2 321 1 1 1 $1,391,160 $2,782,320 $0 $

#VALUE! 0.2 N/A N/A #VALUE! 470 959.7274 -489.727 51.03% 5 6 2 2 321 1 2 1 $878,848 $0 $1,000,000 #VALUE! 0.2 N/A N/A #VALUE! 470 959.7274 -489.727 51.03% 5 6 2 2 321 1 2 1 $878,848 $0 $1,000,000 

0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 2 2 322 2 2 2 $4,462,402 $0 $1,000,000 $0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 2 2 322 2 2 2 $5,538,307 $0 $1,000,000 $

83.61% 0.003 N/A N/A #VALUE! 270 N/A N/A #VALUE! 4 5 3 3 322 1 1 2 2 $4,483,965 $0 $1,000,000 $

0.005 N/A N/A #VALUE! 490 59.71165 430.2883 4 5 3 3 322 1 2 $8,827,602 $0 $1,000,000 0.003 N/A N/A #VALUE! 270 N/A N/A #VALUE! 5 6 2 2 322 1 2 2 $0 $3,189,791 $1,000,000 $

0.003 N/A N/A #VALUE! 270 N/A N/A #VALUE! 5 6 2 2 322 1 2 2 $0 $4,807,909 $1,000,000 $0.003 N/A N/A #VALUE! 270 N/A N/A #VALUE! 5 6 2 2 322 1 2 2 $0 $4,807,909 $1,000,000 $

#VALUE! 0.005 N/A N/A #VALUE! 490 132.3223 357.6777 5 6 2 2 321 2 $0 $0 $1,000,000 

0.005 N/A N/A #VALUE! 490 412.9498 77.05025 4 5 3 3 322 2 $0 $0 $1,000,000 

#VALUE! 0.005 N/A N/A #VALUE! 490 326.7245 163.2755 5 6 2 2 322 2 2 $8,724,039 $0 $1,000,000 

#VALUE! 0.005 N/A N/A #VALUE! 490 546.3959 -56.3959 10.32% 5 6 2 2 321 2 2 1 $1,911,128 $0 $1,000,000 $#VALUE! 0.005 N/A N/A #VALUE! 490 585.9405 -95.9405 16.37% 5 6 2 2 321 2 2 1 $1,689,101 $0 $1,000,000 $#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 5 5 321 1 2 2 $2,600,631 $0 $1,000,000 $#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 5 5 321 1 2 2 $2,600,631 $0 $1,000,000 $#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 5 5 321 1 2 2 $3,990,889 $0 $1,000,000 $#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 2 2 321 1 2 2 $2,626,328 $0 $1,000,000 $

0.005 N/A N/A #VALUE! 490 101.9839 388.0161 5 6 2 2 322 2 $0 $0 $1,000,000 

#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 2 2 321 2 2 2 $3,002,583 $0 $1,000,000 $

#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 5 5 321 2 2 2 $5,534,343 $0 $1,000,000 $#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 5 5 321 2 2 2 $1,961,583 $0 $1,000,000 #VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 5 5 321 2 2 2 $3,119,479 $0 $1,000,000 $#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 5 5 321 2 2 2 $1,672,518 $0 $1,000,000 #VALUE! 0.005 N/A N/A #VALUE! 490 383.3162 106.6838 4 5 3 3 321 2 2 $4,943,230 $0 $1,000,000 #VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 5 5 321 2 2 2 $4,039,560 $0 $1,000,000 $#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 5 5 321 2 2 2 $3,119,479 $0 $1,000,000 $#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 5 5 321 2 2 2 $3,119,479 $0 $1,000,000 $

0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 5 5 321 2 2 2 $3,792,098 $0 $1,000,000 $

#VALUE! 0.005 N/A N/A #VALUE! 490 259.2119 230.7881 1 4 4 4 322 2 2 $14,792,637 $0 $1,000,000 
FacilityID

MSNorbordMSMSNorbordMSMSNorbordMSMSSandersonPlumbingMSShuqualakLumberMSShuqualakLumberMSShuqualakLumberMSShuqualakLumberMSWeyerhaeuser1398MSWeyerhaeuser1398MSWeyerhaeuserBruceMSWeyerhaeuserBruceMSWeyerhaeuserColumbusMTPlumCreekMTPlumCreekMTPlumCreekMTPlumCreekMTPlumCreekMTRoseburgMissoulaMTSmurfitStoneNCBlueRidgePaperNCBlueRidgePaperNCBlueRidgePaperNCBlueRidgePaperNCBlueRidgePaperNCDomtarNCDomtarNCDomtarNCGPAhoskieCNSNCGPDudleyNCGPRoxboroNCGPWhitevilleNCInternationalPaperRiegelwoodNCInternationalPaperRiegelwoodNCInternationalPaperRiegelwoodNCJacksonPaperSylvaNCJeld‐WenNCKapStoneNCKapStoneNCLAPacificRoxboroNCLAPacificRoxboroNCLPRoaringRiver

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#VALUE! 4 N/A N/A #VALUE! 690 N/A N/A #VALUE! 5 6 2 2 321 $0 $0 $0 

#VALUE! 4 N/A N/A #VALUE! 690 N/A N/A #VALUE! 5 6 2 2 321 $0 $0 $0 #VALUE! 4 N/A N/A #VALUE! 690 N/A N/A #VALUE! 5 6 2 2 321 $0 $0 $0 

0.005 N/A N/A #VALUE! 490 476.2361 13.76386 5 6 5 5 321 2 2 $1,091,316 $0 $1,000,000 

#VALUE! 0.2 N/A N/A #VALUE! 470 N/A N/A #VALUE! 5 6 5 5 321 2 2 2 $2,400,400 $0 $1,000,000 $#VALUE! 0.2 N/A N/A #VALUE! 470 N/A N/A #VALUE! 5 6 5 5 321 2 2 2 $1,294,162 $0 $1,000,000 #VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 5 5 321 2 2 2 $1,922,086 $0 $1,000,000 #VALUE! 0.005 N/A N/A #VALUE! 490 122.248 367.752 5 6 5 5 321 2 2 $1,922,086 $0 $1,000,000 #VALUE! 0.005 N/A N/A #VALUE! 490 2891.434 -2401.43 83.05% 5 6 5 5 321 1 2 1 $4,943,230 $0 $1,000,000 $#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 5 5 321 1 2 2 $1,918,107 $0 $1,000,000 #VALUE! 0.005 N/A N/A #VALUE! 490 2124.637 -1634.64 76.94% 5 6 6 5 321 1 2 1 $3,261,316 $0 $1,000,000 $

4 0.003171 3.996829 690 354.881 335.119 5 6 2 2 321 $0 $0 $0 

0.005 N/A N/A #VALUE! 490 96.24913 393.7509 5 6 2 2 322 2 $0 $0 $1,000,000 

#VALUE! 0.2 N/A N/A #VALUE! 470 N/A N/A #VALUE! 5 6 2 2 321 2 2 2 $1,522,923 $0 $1,000,000 $

#VALUE! 0.2 N/A N/A #VALUE! 470 N/A N/A #VALUE! 5 6 2 2 321 2 2 2 $1,522,923 $0 $1,000,000 $#VALUE! 0.2 N/A N/A #VALUE! 470 N/A N/A #VALUE! 4 5 3 3 321 2 2 2 $3,664,252 $0 $1,000,000 $#VALUE! 4 N/A N/A #VALUE! 690 N/A N/A #VALUE! 5 6 2 2 321 2 $1,120,905 $0 $0 #VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 2 2 321 2 2 2 $4,390,618 $0 $1,000,000 $

0.005 N/A N/A #VALUE! 490 53.53662 436.4634 5 6 5 5 321 2 2 $2,821,965 $0 $1,000,000 

#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 4 5 3 3 322 2 2 2 $9,315,230 $0 $1,000,000 $

0.004 N/A N/A #VALUE! 160 75.24458 84.75542 5 6 2 2 322 1 1 2 $5,011,374 $10,022,748 $1,000,000 0.004 N/A N/A #VALUE! 160 15.82828 144.1717 5 6 2 2 322 1 1 2 $5,011,374 $10,022,748 $1,000,000 0.004 N/A N/A #VALUE! 160 15.3462 144.6538 5 6 2 2 322 1 1 2 $5,295,168 $10,590,336 $1,000,000 0.004 N/A N/A #VALUE! 160 13.49823 146.5018 5 6 2 2 322 2 $0 $0 $1,000,000 

0.005 N/A N/A #VALUE! 490 666.8057 -176.806 26.52% 4 5 3 3 322 1 2 1 $8,999,206 $0 $1,000,000 $

0.005 N/A N/A #VALUE! 490 55.91815 434.0818 5 6 2 2 322 1 2 $0 $17,126,438 $1,000,000 

30.35% 4 N/A N/A #VALUE! 10 49.05812 -39.0581 79.62% 2 6 6 6 322 1 1 1 1 $8,711,953 $0 $1,000,000 $

0.005 N/A N/A #VALUE! 490 1634.34 -1144.34 70.02% 5 6 2 2 322 2 1 $0 $0 $1,000,000 $

#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 5 5 321 1 2 2 $3,837,423 $0 $1,000,000 $

#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 1 4 4 4 321 1 2 2 $7,066,987 $0 $1,000,000 $

0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 5 5 321 1 2 2 $3,261,316 $0 $1,000,000 $

#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 1 4 4 4 321 1 2 2 $6,856,213 $0 $1,000,000 $#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 4 5 3 3 322 2 2 2 $9,624,261 $0 $1,000,000 $#VALUE! 4 N/A N/A #VALUE! 10 N/A N/A #VALUE! 1 4 4 4 322 2 2 $7,000,000 $0 $0 $#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 4 5 3 3 322 2 2 2 $11,836,540 $0 $1,000,000 $#VALUE! 0.005 N/A N/A #VALUE! 490 879.8478 -389.848 44.31% 4 5 3 3 322 1 2 1 $5,050,501 $0 $1,000,000 $#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 5 5 321 1 2 2 $2,454,855 $0 $1,000,000 $

0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 4 5 3 3 322 1 2 2 $11,234,446 $0 $1,000,000 $

#VALUE! 4 N/A N/A #VALUE! 10 N/A N/A #VALUE! 5 6 6 6 322 1 2 2 2 $5,843,016 $6,677,733 $1,000,000 $#VALUE! 0.2 N/A N/A #VALUE! 470 N/A N/A #VALUE! 5 6 2 2 321 2 2 2 $1,332,085 $0 $1,000,000 #VALUE! 0.2 N/A N/A #VALUE! 470 N/A N/A #VALUE! 5 6 2 2 321 2 2 2 $1,332,085 $0 $1,000,000 

0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 4 5 3 3 321 2 2 2 $3,506,794 $0 $1,000,000 $
FacilityID

NCLPRoaringRiverNCLPRoaringRiverNCSeaboardLumberNCSeaboardLumberNCSeaboardLumberNCUniboardUSANCWestFraserNCWeyerhaeuserGriftonNCWeyerhaeuserGriftonNCWeyerhaeuserGriftonNCWeyerhaeuser‐Vanceboro

NCWeyerhaeuser‐Vanceboro

NYFinchPaperNYIntlPaperTiconderogaOHAppletonIdeasOHAppletonIdeasOHGlatfelterChillicotheOHGlatfelterChillicotheOHGlatfelterChillicotheOHRockTennCincinnatiOHSmartPapersHoldingsLLCOHSmurfitCoshoctonOKGPMuskogeeMillOKGPMuskogeeMillOKGPMuskogeeMill

OKIPValliantOKIPValliantOKPanPacificProductsOKWeyerhaeuserWrightCityORBBSMMedfordORBBSMMedfordORBBSMMedfordORBlueHeronPaperORBoiseBuildingORCascadePacificPulpORFlakeboardEugeneORGeorgiaPacificWaunaMillORGeorgiaPacificWaunaMillORGPToledoORJeldWenKlamanthFallsORRosboroSpringfieldORRosboroSpringfield

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#VALUE! 4 N/A N/A #VALUE! 10 N/A N/A #VALUE! 5 6 6 6 321 2 2 2 2 $2,468,344 $2,820,964 $1,000,000 $

42.50% 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 4 5 3 3 321 2 1 2 2 $5,805,033 $0 $1,000,000 $

#VALUE! 0.02 N/A N/A #VALUE! 430 N/A N/A #VALUE! 5 6 2 2 321 1 $1,626,934 $0 $0 #VALUE! 0.02 N/A N/A #VALUE! 430 N/A N/A #VALUE! 5 6 5 5 321 2 $2,077,028 $0 $0 #VALUE! 0.02 N/A N/A #VALUE! 430 N/A N/A #VALUE! 5 6 5 5 321 2 $2,077,028 $0 $0 #VALUE! 0.2 N/A N/A #VALUE! 470 N/A N/A #VALUE! 5 6 2 2 321 2 2 2 $1,698,974 $0 $1,000,000 $#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 4 5 3 3 321 2 2 2 $4,143,760 $0 $1,000,000 $#VALUE! 4 N/A N/A #VALUE! 690 460.0472 229.9528 5 6 2 2 321 $0 $0 $0 

#VALUE! 4 N/A N/A #VALUE! 690 460.0472 229.9528 5 6 2 2 321 $0 $0 $0 #VALUE! 4 N/A N/A #VALUE! 690 N/A N/A #VALUE! 5 6 2 2 321 2 $1,650,256 $0 $0 

#VALUE! 4 N/A N/A #VALUE! 10 N/A N/A #VALUE! 5 6 6 6 322 1 2 2 2 $11,586,204 $13,241,376 $1,000,000 $#VALUE! 4 N/A N/A #VALUE! 10 N/A N/A #VALUE! 2 6 6 6 322 1 2 2 $7,604,369 $0 $1,000,000 $#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 4 5 3 3 322 2 2 2 $5,602,831 $0 $1,000,000 $

0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 2 6 5 5 322 1 2 2 $14,639,077 $0 $1,000,000 $0.003 N/A N/A #VALUE! 270 45.63686 224.3631 5 6 2 2 322 1 2 $0 $6,028,382 $1,000,000 

0.003 N/A N/A #VALUE! 270 19.7315 250.2685 5 6 2 2 322 1 1 2 $3,951,806 $7,903,612 $1,000,000 

#VALUE! 0.004 N/A N/A #VALUE! 160 N/A N/A #VALUE! 5 6 2 2 322 2 2 2 $5,101,698 $10,203,396 $1,000,000 #VALUE! 0.004 N/A N/A #VALUE! 160 N/A N/A #VALUE! 5 6 2 2 322 2 2 2 $6,062,866 $12,125,733 $1,000,000 #VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 2 2 322 2 2 2 $4,354,432 $0 $1,000,000 $#VALUE! 0.003 N/A N/A #VALUE! 270 N/A N/A #VALUE! 5 3 1 1 322 1 2 2 2 $0 $4,068,338 $1,000,000 $

25.28% 0.004 N/A N/A #VALUE! 160 N/A N/A #VALUE! 5 6 2 2 322 2 1 2 $0 $10,921,331 $1,000,000 

0.005 N/A N/A #VALUE! 490 272.6726 217.3274 4 5 3 3 322 1 2 $12,349,960 $0 $1,000,000 

0.004 N/A N/A #VALUE! 160 26.51437 133.4856 5 6 2 2 322 2 2 $4,852,745 $0 $1,000,000 0.004 N/A N/A #VALUE! 160 13.96812 146.0319 5 3 1 1 322 2 $0 $0 $1,000,000 

0.004 N/A N/A #VALUE! 160 3.200772 156.7992 5 3 1 1 322 2 $0 $0 $1,000,000 

#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 4 5 3 322 2 22 

#VALUE! 4 N/A N/A #VALUE! 10 N/A N/A #VALUE! 5 6 6 6 322 2 2 2 2 $15,545,086 $17,765,812 $1,000,000 $

#VALUE! 0.005 N/A N/A #VALUE! 490 557.0262 -67.0262 12.03% 1 4 4 4 321 1 2 1 $2,501,852 $0 $1,000,000 $#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 2 2 321 2 2 $0 $0 $1,000,000 $

#VALUE! 0.005 N/A N/A #VALUE! 490 3852.927 -3362.93 87.28% 5 6 2 2 321 2 1 $0 $0 $1,000,000 $#VALUE! 0.005 N/A N/A #VALUE! 490 3852.927 -3362.93 87.28% 5 6 2 2 321 2 1 $0 $0 $1,000,000 $#VALUE! 0.005 N/A N/A #VALUE! 490 3852.927 -3362.93 87.28% 5 6 2 2 321 2 1 $0 $0 $1,000,000 $#VALUE! 0.005 N/A N/A #VALUE! 490 147.0563 342.9437 5 6 5 5 322 2 $0 $0 $1,000,000 #VALUE! 0.2 N/A N/A #VALUE! 470 N/A N/A #VALUE! 5 6 2 2 321 2 2 2 $2,019,064 $0 $1,000,000 $

#VALUE! 4 N/A N/A #VALUE! 10 4.871715 5.128285 5 6 6 6 321 1 2 2 $6,658,413 $7,609,615 $1,000,000 

0.2 N/A N/A #VALUE! 470 448.4687 21.53134 5 3 1 1 321 2 $0 $0 $1,000,000 

#VALUE! 4 N/A N/A #VALUE! 10 0.209332 9.790668 5 6 6 6 322 1 2 2 $5,972,714 $6,825,959 $1,000,000 

0.02 0.00228 0.01772 430 23.89197 406.108 3 2 1 1 322 $0 $0 $0 

#VALUE! 4 N/A N/A #VALUE! 10 27.20041 -17.2004 63.24% 5 6 6 6 322 1 2 2 1 $5,890,265 $6,731,731 $1,000,000 $

#VALUE! 0.005 N/A N/A #VALUE! 490 297.4003 192.5997 5 6 2 2 321 2 2 $1,926,793 $0 $1,000,000 

0.2 0.032539 0.167461 470 409.9549 60.04505 5 6 5 5 321 1 $2,665,116 $0 $0 

#VALUE! 0.2 N/A N/A #VALUE! 470 N/A N/A #VALUE! 5 6 5 5 321 2 2 2 $2,665,116 $0 $1,000,000 $
FacilityID

ORRosboroSpringfieldORRoseburgCoquilleORRoseburgForestDillardORRoseburgForestDillardORRoseburgForestDillardORRoseburgRiddle2ORRoseburgRiddle2ORSierraPineORSierraPineSpringfieldORSierraPineSpringfieldORSierraPineSpringfieldORSPNewsprintORSPNewsprintORStimsonLumberForestGroveORStimsonLumberForestGroveORStimsonLumberForestGrovePAAppletonPapersPAAppletonPapersPACraftMasterPADomtarJohnsonburgPADomtarJohnsonburgPAPHGlatfelterPAPHGlatfelterPAPHGlatfelterPAPHGlatfelterPAProctorGambleMehoopanyPAPATeamTenPATemple‐Inland

PATemple‐Inland

SCBowaterCoatedPaperSCBowaterCoatedPaperSCBowaterCoatedPaperSCChesterWoodProductsSCCogenSouthSCCollumsLumberSCGPProsperityPlySCGPRussellvilleSCInternationalPaperEastoverSCInternationalPaperEastoverSCIPGeorgetownSCIPGeorgetownSCMarlboroPaper

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#VALUE! 0.2 N/A N/A #VALUE! 470 N/A N/A #VALUE! 5 6 5 5 321 2 2 2 $2,665,116 $0 $1,000,000 $

0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 5 5 321 2 2 2 $4,676,776 $0 $1,000,000 $0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 1 4 4 4 321 2 2 2 $7,948,938 $0 $1,000,000 $0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 1 4 4 4 321 2 2 2 $7,948,938 $0 $1,000,000 $0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 1 4 4 4 321 2 2 2 $10,862,656 $0 $1,000,000 $0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 2 2 321 2 2 2 $2,657,971 $0 $1,000,000 $0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 1 4 4 4 321 2 2 2 $3,546,595 $0 $1,000,000 $

#VALUE! 0.2 N/A N/A #VALUE! 470 N/A N/A #VALUE! 1 4 2 2 321 2 2 2 $2,356,461 $0 $1,000,000 $#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 2 2 321 2 2 2 $878,848 $0 $1,000,000 #VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 2 2 321 2 2 2 $1,120,905 $0 $1,000,000 #VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 2 2 321 2 2 2 $1,120,905 $0 $1,000,000 

0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 2 2 322 1 2 2 $0 $13,076,027 $1,000,000 $

#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 1 4 4 4 322 2 2 2 $7,395,787 $0 $1,000,000 $

#VALUE! 0.005 N/A N/A #VALUE! 490 378.7998 111.2002 5 6 2 2 321 2 2 $1,957,871 $0 $1,000,000 #VALUE! 0.005 N/A N/A #VALUE! 490 378.7998 111.2002 5 6 2 2 321 2 2 $1,957,871 $0 $1,000,000 #VALUE! 0.005 N/A N/A #VALUE! 490 378.7998 111.2002 5 6 2 2 321 2 2 $1,957,871 $0 $1,000,000 #VALUE! 4 N/A N/A #VALUE! 10 33.09038 -23.0904 69.78% 5 6 6 6 322 2 2 2 1 $6,214,762 $7,102,585 $1,000,000 $

55.41% 0.005 N/A N/A #VALUE! 490 1070.274 -580.274 54.22% 4 5 3 3 322 1 1 2 1 $5,747,746 $0 $1,000,000 $

#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 2 2 321 2 2 $0 $0 $1,000,000 $

0.004 N/A N/A #VALUE! 160 68.2946 91.7054 1 4 2 2 322 2 $0 $0 $1,000,000 0.004 N/A N/A #VALUE! 160 68.2946 91.7054 1 4 2 2 322 2 $0 $0 $1,000,000 0.004 N/A N/A #VALUE! 160 N/A N/A #VALUE! 5 6 2 2 322 1 2 $0 $5,651,827 $1,000,000 

0.004 N/A N/A #VALUE! 160 N/A N/A #VALUE! 5 6 2 2 322 1 2 $0 $10,017,791 $1,000,000 0.004 N/A N/A #VALUE! 160 N/A N/A #VALUE! 5 6 2 2 322 1 2 $0 $8,233,888 $1,000,000 

0.02 N/A N/A #VALUE! 430 23.18695 406.813 3 6 2 2 322 $0 $0 $0 

#VALUE! 4 N/A N/A #VALUE! 10 N/A N/A #VALUE! 5 6 6 6 322 2 2 2 2 $6,864,727 $7,845,402 $1,000,000 $

#VALUE! 0.003 N/A N/A #VALUE! 270 N/A N/A #VALUE! 5 3 1 1 322 2 2 2 2 $0 $7,728,108 $1,000,000 $

#VALUE! 0.2 N/A N/A #VALUE! 470 N/A N/A #VALUE! 5 6 6 5 321 2 2 2 $2,665,116 $0 $1,000,000 $

#VALUE! 0.2 N/A N/A #VALUE! 470 N/A N/A #VALUE! 5 6 6 5 321 2 2 2 $3,148,186 $0 $1,000,000 $

0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 2 2 322 1 2 2 $5,342,801 $0 $1,000,000 $

#VALUE! 4 N/A N/A #VALUE! 10 N/A N/A #VALUE! 5 6 6 6 322 1 2 2 2 $8,927,972 $10,203,396 $1,000,000 $

0.005 0.004861 0.000139 490 2818.176 -2328.18 82.61% 5 6 2 2 322 1 1 $7,545,630 $0 $0 $

#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 1 4 4 4 321 2 2 2 $4,985,481 $0 $1,000,000 $

0.005 N/A N/A #VALUE! 490 16.09804 473.902 1 2 1 1 322 2 $0 $0 $1,000,000 

#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 5 5 321 1 2 2 $2,095,853 $0 $1,000,000 

0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 1 4 4 4 321 1 2 2 $6,122,828 $0 $1,000,000 $

#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 5 5 321 1 2 2 $6,977,632 $0 $1,000,000 $

0.005 N/A N/A #VALUE! 490 520.3779 -30.3779 5.84% 5 6 2 2 322 2 1 $0 $0 $1,000,000 $

#VALUE! 0.005 N/A N/A #VALUE! 490 25.71091 464.2891 5 6 2 2 322 1 2 $0 $12,769,206 $1,000,000 

#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 2 2 322 2 2 2 $6,709,482 $0 $1,000,000 $

#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 2 2 322 2 2 2 $6,709,482 $0 $1,000,000 $

0.005 0.002758 0.002242 490 313.5231 176.4769 5 6 2 2 322 $0 $0 $0 
FacilityID

SCNewSouthCamdenSCNewSouthCoConwaySCNewSouthLumberCoDarlingtonSCNewSouthLumberCoDarlingtonSCRoseburgForestRussellvilleSCSimpsonLumberGeorgetownSCSimpsonLumberGeorgetownSCSmurfitStoneSCSmurfitStoneSCSonocoHartsvilleSCSonocoHartsvilleSCSonocoHartsvilleSCWestFraserNewberrySCWestFraserNewberrySCWestFraserNewberryTNArborCraftTNArborCraftTNBowaterNewsprintTNBowaterNewsprintTNBowaterNewsprintTNBowaterNewsprintTNDomtar2384TNPackagingCorpCounceTNPackagingCorpCounceTXAnthonyForestProd‐ATLTXAnthonyForestProd‐ATLTXDibollTemple‐Inland

TXDibollTemple‐Inland

TXGPClevelandPlyLumber

TXInternationalPaperQueenCityTXLPCarthageTXLPJasperOSBTXLPJasperOSBTXMeadWestvacoEvadaleTXNorbordTexasJeffersonTXNorbordTexasJeffersonTXNorbordTexasNacogdochesTXNorbordTexasNacogdochesTXNorbordTexasNacogdochesTXNorbordTexasNacogdochesTXNorbordTexasNacogdochesTXPinelandTemple‐Inland

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PM 

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PM Need 

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Upgrade?

CO Need 

Upgrade? PM Upgrade Cost HCl Upgrade Cost Hg/Dioxin Upgrade Cost CO Upgra

0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 2 2 321 1 2 2 $2,195,678 $0 $1,000,000 $

0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 2 2 321 1 2 2 $2,195,678 $0 $1,000,000 $

#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 5 5 321 1 2 2 $1,919,301 $0 $1,000,000 #VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 5 5 321 1 2 2 $1,910,131 $0 $1,000,000 

0.2 N/A N/A #VALUE! 470 N/A N/A #VALUE! 5 3 1 1 321 2 2 $0 $0 $1,000,000 

#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 2 2 321 2 2 2 $1,761,082 $0 $1,000,000 $

#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 5 5 321 2 2 2 $1,910,131 $0 $1,000,000 

0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 2 2 322 2 2 $0 $0 $1,000,000 $

#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 2 2 322 2 2 $0 $0 $1,000,000 $

0.002 0.001388 0.000612 82 168.4007 -86.4007 51.31% 3 2 1 1 322 1 1 $0 $0 $0 $

#VALUE! 0.004 N/A N/A #VALUE! 160 N/A N/A #VALUE! 5 6 2 2 322 1 2 2 $3,262,481 $6,524,962 $1,000,000 

#VALUE! 0.003 N/A N/A #VALUE! 270 N/A N/A #VALUE! 5 3 1 1 322 2 2 2 2 $0 $10,284,807 $1,000,000 $

#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 5 5 321 2 2 2 $1,910,131 $0 $1,000,000 

#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 5 5 321 2 2 2 $1,910,131 $0 $1,000,000 #VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 5 5 321 2 2 2 $1,910,131 $0 $1,000,000 #VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 5 5 321 2 2 2 $1,401,976 $0 $1,000,000 #VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 5 5 321 2 2 2 $1,401,976 $0 $1,000,000 

33.65% 0.004 N/A N/A #VALUE! 160 N/A N/A #VALUE! 5 6 2 2 322 1 2 $0 $0 $1,000,000 

#VALUE! 0.004 N/A N/A #VALUE! 160 N/A N/A #VALUE! 5 6 2 2 322 2 2 2 $5,767,010 $11,534,019 $1,000,000 

0.004 N/A N/A #VALUE! 160 N/A N/A #VALUE! 5 6 2 2 322 2 $0 $0 $1,000,000 

0.02 0.005345 0.014656 430 115.3842 314.6158 5 6 2 2 322 $0 $0 $0 

0.02 0.01886 0.00114 430 81.74706 348.2529 5 6 2 2 322 1 $6,377,571 $0 $0 

#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 2 322 2 22 

#VALUE! 4 N/A N/A #VALUE! 10 N/A N/A #VALUE! 5 6 6 6 322 2 1 2 2 $9,280,471 $10,606,253 $1,000,000 $

#VALUE! 0.005 N/A N/A #VALUE! 490 300.3018 189.6982 5 6 5 5 321 1 2 $1,715,777 $0 $1,000,000 #VALUE! 0.005 N/A N/A #VALUE! 490 233.151 256.849 5 6 5 5 321 1 2 $1,910,131 $0 $1,000,000 #VALUE! 0.2 N/A N/A #VALUE! 470 N/A N/A #VALUE! 5 6 5 5 321 2 2 2 $1,882,040 $0 $1,000,000 

0.2 N/A N/A #VALUE! 470 69.30937 400.6906 5 6 2 2 321 2 2 $1,332,085 $0 $1,000,000 

#VALUE! 0.005 N/A N/A #VALUE! 490 386.6385 103.3615 4 5 3 3 321 2 2 $7,648,796 $0 $1,000,000 #VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 4 5 3 322 2 22 

#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 2 2 321 2 2 2 $1,165,161 $0 $1,000,000 

#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 2 2 321 2 2 2 $2,651,211 $0 $1,000,000 $#VALUE! 0.2 N/A N/A #VALUE! 470 N/A N/A #VALUE! 5 6 2 2 321 2 2 2 $1,208,324 $0 $1,000,000 #VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 6 5 322 2 2 2 $8,087,053 $0 $1,000,000 $#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 2 2 321 2 2 2 $3,229,378 $0 $1,000,000 $#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 2 2 321 2 2 2 $3,229,378 $0 $1,000,000 $#VALUE! 0.2 N/A N/A #VALUE! 470 N/A N/A #VALUE! 5 6 2 2 321 2 2 2 $1,332,085 $0 $1,000,000 #VALUE! 4 N/A N/A #VALUE! 690 1222.067 -532.067 43.54% 5 6 2 2 321 1 $0 $0 $0 

#VALUE! 4 N/A N/A #VALUE! 690 1222.067 -532.067 43.54% 5 6 2 2 321 1 $0 $0 $0 #VALUE! 0.2 N/A N/A #VALUE! 470 N/A N/A #VALUE! 5 6 2 2 321 2 2 2 $1,332,085 $0 $1,000,000 

#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 2 2 321 2 2 2 $1,698,974 $0 $1,000,000 $#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 2 2 321 2 2 2 $3,229,378 $0 $1,000,000 $
FacilityID

TXPinelandTemple‐Inland

TXPinelandTemple‐Inland

TXTempleInlandFiberboardTXTemple‐InlandOrange

TXwestfraserVAATCPanelsVAATCPanelsVABassettFiberboardVABassettFiberboardVABearIslandPaperCoAshlandVAGeorgiaPacificBrooknealGladysVAGeorgiaPacificEmporiaVAGPBigIsland2703VAGPBigIsland2703VAGPJarrattFiberboardVAGreifVAGreifVAGreifVAMeadWestVaco‐CovingtonVAVAMeadWestVaco‐CovingtonVAVAMeadWestVaco‐CovingtonVAVAMeadWestVaco‐CovingtonVAVASmurfitStoneHopewellVASmurfitStoneWestptVASmurfitStoneWestptWABoiseKettleFallsPlywoodWABoisePaperWallulaWAGPCamasWAGPCamasWAGraysHarborPaperWAGraysHarborPaperWAJeldWenWhiteSwanWAJeldWenWhiteSwanWAKimberlyClarkEverettWANipponPaperWANipponPaperWANipponPaperWAPonderayAbibo

WAPort TownsendWASierraPacificWASimpsonLumberCompanyWASimpsonTacoma2784

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HCl Need 

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Hg Need 

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Dioxin 

Need 

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CO Need 

Upgrade? PM Upgrade Cost HCl Upgrade Cost Hg/Dioxin Upgrade Cost CO Upgra

#VALUE! 0.2 N/A N/A #VALUE! 470 N/A N/A #VALUE! 5 6 6 5 321 2 2 2 $1,628,500 $0 $1,000,000 

#VALUE! 0.2 N/A N/A #VALUE! 470 N/A N/A #VALUE! 5 6 6 5 321 2 2 2 $1,628,500 $0 $1,000,000 

0.005 N/A N/A #VALUE! 490 1089.894 -599.894 55.04% 1 4 4 4 321 2 2 1 $6,658,413 $0 $1,000,000 $

#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 4 5 3 3 322 2 2 2 $9,196,695 $0 $1,000,000 $#VALUE! 0.005 N/A N/A #VALUE! 490 569.9905 -79.9905 14.03% 1 4 4 4 321 1 2 1 $3,809,767 $0 $1,000,000 $

0.2 N/A N/A #VALUE! 470 N/A N/A #VALUE! 5 6 5 5 321 2 2 2 $2,535,063 $0 $1,000,000 $

#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 5 5 321 2 2 2 $2,331,149 $0 $1,000,000 #VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 5 5 321 2 2 2 $2,151,666 $0 $1,000,000 #VALUE! 4 N/A N/A #VALUE! 10 N/A N/A #VALUE! 5 6 6 6 321 2 2 2 2 $1,762,537 $2,014,328 $1,000,000 

0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 2 2 322 2 1 2 2 $3,932,419 $7,864,837 $1,000,000 $

#VALUE! 4 N/A N/A #VALUE! 690 172.6735 517.3265 5 6 2 2 321 1 $3,903,217 $0 $0 #VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 1 4 4 4 321 1 2 2 $5,736,242 $0 $1,000,000 $

0.004 N/A N/A #VALUE! 160 33.58487 126.4151 5 6 2 2 322 2 $0 $0 $1,000,000 

0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 2 2 322 2 2 $0 $0 $1,000,000 $

37.87% 0.003 N/A N/A #VALUE! 270 N/A N/A #VALUE! 5 6 5 5 321 2 1 2 2 $3,705,483 $0 $1,000,000 $

#VALUE! 4 N/A N/A #VALUE! 10 N/A N/A #VALUE! 5 6 6 6 322 2 2 2 2 $6,571,183 $7,509,923 $1,000,000 $#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 2 2 322 2 2 $0 $0 $1,000,000 $

#VALUE! 4 N/A N/A #VALUE! 10 N/A N/A #VALUE! 5 6 6 6 322 2 2 2 2 $6,571,183 $7,509,923 $1,000,000 $

0.003 N/A N/A #VALUE! 270 N/A N/A #VALUE! 2 6 2 2 322 2 2 $0 $0 $1,000,000 $

0.003 N/A N/A #VALUE! 270 N/A N/A #VALUE! 2 6 2 2 322 2 2 $0 $0 $1,000,000 $0.003 N/A N/A #VALUE! 270 N/A N/A #VALUE! 2 6 2 2 322 2 2 $0 $0 $1,000,000 $0.004 N/A N/A #VALUE! 160 N/A N/A #VALUE! 2 6 2 2 322 2 $0 $0 $1,000,000 

#VALUE! 0.004 N/A N/A #VALUE! 160 N/A N/A #VALUE! 5 6 2 2 322 2 2 $0 $16,624,485 $1,000,000 

0.004 0.003281 0.000719 160 16.49103 143.509 5 6 2 2 322 $0 $0 $0 

16.33% 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 2 2 322 1 2 2 $0 $0 $1,000,000 $

#VALUE! 0.005 N/A N/A #VALUE! 490 5482.714 -4992.71 91.06% 5 6 2 2 321 2 1 $0 $0 $1,000,000 $

#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 4 5 2 2 322 2 2 2 $4,191,364 $0 $1,000,000 $

0.005 N/A N/A #VALUE! 490 295.5398 194.4602 5 6 2 2 322 2 2 $4,244,646 $0 $1,000,000 

#VALUE! 4 N/A N/A #VALUE! 10 36.53786 -26.5379 72.63% 4 5 3 3 322 2 1 $8,087,053 $0 $0 $

0.2 0.371994 -0.17199 46.24% 470 993.0823 -523.082 52.67% 4 5 3 3 322 1 1 1 1 $6,304,717 $0 $1,000,000 $

0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 1 4 4 4 322 1 2 2 $9,280,471 $0 $1,000,000 $

#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 2 2 321 2 2 2 $1,473,034 $0 $1,000,000 $#VALUE! 4 N/A N/A #VALUE! 10 N/A N/A #VALUE! 5 6 6 6 321 2 2 2 2 $2,253,352 $2,575,260 $1,000,000 

0.005 N/A N/A #VALUE! 490 33.92247 456.0775 5 3 1 1 322 1 2 $0 $11,153,715 $1,000,000 

#VALUE! 4 N/A N/A #VALUE! 10 N/A N/A #VALUE! 5 6 6 6 322 1 2 2 2 $4,392,914 $5,020,474 $1,000,000 $

0.005 0.00614 -0.00114 18.57% 490 498.4054 -8.40543 1.69% 4 5 3 3 322 1 1 1 $5,375,632 $0 $1,000,000 $

#VALUE! 4 N/A N/A #VALUE! 10 N/A N/A #VALUE! 5 6 6 6 322 1 2 2 2 $4,392,914 $5,020,474 $1,000,000 $#VALUE! 0.02 N/A N/A #VALUE! 430 N/A N/A #VALUE! 3 2 1 1 322 $0 $0 $0 

#VALUE! 4 N/A N/A #VALUE! 10 N/A N/A #VALUE! 566 322 2 2 2 2 $5,899,684 $6,742,496 $1,000,000 $#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 6 5 321 2 2 2 $7,612,315 $0 $1,000,000 $

0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 2 2 321 2 2 2 $3,338,866 $0 $1,000,000 $

#VALUE! 0.005 N/A N/A #VALUE! 490 131.8708 358.1292 5 6 2 2 322 2 $0 $0 $1,000,000 
FacilityID

WAWeyerhaeuser_RaymondWAWeyerhaeuserLongviewWIAlgomaWIAlgomaWIAppletonWIAppletonCoatedWIDomtar2814WIDomtar2814WIDomtarNekoosaWIDomtarNekoosaWIDomtarNekoosaWIDomtarNekoosaWIFlambeauRiverPaperWIGPGreenBay2818WIGPGreenBay2818WIGPGreenBay2818WIGPGreenBay2818WIGPGreenBay2818WIGPGreenBay2818WIGreenBayPackagingMillDivisionWILPHaywardWILPHaywardWILPHaywardWILPHaywardWINeenahPaperAppletonWINewPageBironWINewPageBironWINewPageKimberlyWINewPageKimberlyWINewPage‐WhitingWINewPage‐WisconsinRapidsWINewPage‐WisconsinRapidsWIPCATomahawkWIPCATomahawkWIPCATomahawkWIThilmanyLLCWIThilmanyLLCWIThilmanyLLCWIThilmanyPapersNicoletMillWIThilmanyPapersNicoletMillWIWausauWIWausau

Hg %red

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CO 

Difference CO %red

HCl 

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Group

Hg 

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PM 

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Group NAICS

PM Need 

Upgrade?

HCl Need 

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Hg Need 

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Need 

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Upgrade? PM Upgrade Cost HCl Upgrade Cost Hg/Dioxin Upgrade Cost CO Upgra

4 0.001873 3.998127 690 121.2614 568.7386 5 6 2 2 321 $0 $0 $0 

#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 3 6 2 2 322 2 2 $0 $0 $1,000,000 $

#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 6 5 321 2 2 2 $1,583,673 $0 $1,000,000 

#VALUE! 0.005 N/A N/A #VALUE! 490 206.6548 283.3452 5 6 6 5 321 2 2 $2,114,567 $0 $1,000,000 

0.003 N/A N/A #VALUE! 270 N/A N/A #VALUE! 5 6 5 5 322 2 2 2 2 $2,468,344 $2,820,964 $1,000,000 $

#VALUE! 0.003 N/A N/A #VALUE! 270 N/A N/A #VALUE! 5 6 2 2 322 2 2 2 2 $4,818,908 $9,637,816 $1,000,000 $#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 2 2 322 2 2 $0 $0 $1,000,000 $

#VALUE! 4 N/A N/A #VALUE! 10 N/A N/A #VALUE! 5 6 6 6 322 2 2 2 2 $6,122,828 $6,997,517 $1,000,000 $

0.003 N/A N/A #VALUE! 270 N/A N/A #VALUE! 5 6 2 2 322 1 2 2 $0 $5,850,410 $1,000,000 $

0.004 N/A N/A #VALUE! 160 N/A N/A #VALUE! 5 6 2 2 322 1 2 $0 $5,967,895 $1,000,000 0.004 N/A N/A #VALUE! 160 N/A N/A #VALUE! 5 6 2 2 322 1 2 $0 $5,967,895 $1,000,000 0.003 N/A N/A #VALUE! 270 N/A N/A #VALUE! 5 6 2 2 322 1 2 2 $0 $8,981,802 $1,000,000 $0.005 N/A N/A #VALUE! 490 104.1038 385.8962 4 5 3 3 322 1 2 $6,983,187 $0 $1,000,000 

0.003 N/A N/A #VALUE! 270 N/A N/A #VALUE! 5 3 1 1 322 1 2 2 2 $3,498,759 $6,997,517 $1,000,000 $0.002 N/A N/A #VALUE! 82 98.36852 -16.3685 16.64% 3 2 1 1 322 1 2 1 $5,960,432 $0 $1,000,000 $0.003 N/A N/A #VALUE! 270 N/A N/A #VALUE! 5 3 1 1 322 1 1 2 2 $4,894,821 $9,789,642 $1,000,000 $0.003 N/A N/A #VALUE! 270 N/A N/A #VALUE! 5 3 1 1 322 1 1 2 2 $3,854,222 $7,708,444 $1,000,000 $0.003 N/A N/A #VALUE! 270 N/A N/A #VALUE! 5 3 1 1 322 1 1 2 2 $6,864,692 $13,729,384 $1,000,000 $

57.03% 0.02 0.033158 -0.01316 39.68% 430 1.501291 428.4987 5 3 1 1 322 1 1 1 $0 $4,476,722 $1,000,000 

0.003 N/A N/A #VALUE! 270 N/A N/A #VALUE! 5 3 1 1 322 1 2 2 $0 $7,589,747 $1,000,000 $

#VALUE! 0.005 N/A N/A #VALUE! 490 1204.099 -714.099 59.31% 5 6 2 2 321 2 2 1 $862,933 $0 $1,000,000 

#VALUE! 0.005 N/A N/A #VALUE! 490 743.4 -253.4 34.09% 5 6 2 2 321 2 2 1 $862,933 $0 $1,000,000 #VALUE! 0.005 N/A N/A #VALUE! 490 2350.471 -1860.47 79.15% 5 6 2 2 321 2 2 1 $975,533 $0 $1,000,000 #VALUE! 0.005 N/A N/A #VALUE! 490 1645.33 -1155.33 70.22% 5 6 2 2 321 2 2 1 $975,533 $0 $1,000,000 #VALUE! 4 N/A N/A #VALUE! 10 N/A N/A #VALUE! 5 6 6 6 322 2 2 2 2 $2,973,205 $3,397,948 $1,000,000 $

0.003 0.001521 0.001479 270 N/A N/A #VALUE! 5 6 2 2 322 2 $0 $0 $0 $

40.18% 0.004 N/A N/A #VALUE! 160 N/A N/A #VALUE! 5 6 2 2 322 1 1 2 $0 $9,620,848 $1,000,000 

0.003 N/A N/A #VALUE! 270 N/A N/A #VALUE! 5 6 2 2 322 1 1 2 2 $2,794,329 $5,588,659 $1,000,000 $

0.003 N/A N/A #VALUE! 270 N/A N/A #VALUE! 5 6 2 2 322 1 1 2 2 $3,117,356 $6,234,711 $1,000,000 $

47.05% 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 2 2 322 1 1 2 2 $3,617,087 $0 $1,000,000 $

0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 2 2 322 2 2 $0 $0 $1,000,000 $

0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 2 2 322 2 2 $0 $0 $1,000,000 $

#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 2 2 322 1 1 2 2 $4,005,757 $8,011,514 $1,000,000 $

#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 2 2 322 1 1 2 2 $2,600,830 $5,201,659 $1,000,000 $#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 2 2 322 1 1 2 2 $3,402,354 $6,804,709 $1,000,000 $

10.88% 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 1 4 4 4 322 1 1 2 2 $6,196,010 $0 $1,000,000 $

0.003 0.008731 -0.00573 65.64% 270 64.45627 205.5437 5 6 2 2 322 1 1 1 $5,134,280 $10,268,559 $1,000,000 0.003 0.008731 -0.00573 65.64% 270 64.45627 205.5437 5 6 2 2 322 1 1 1 $3,418,370 $6,836,739 $1,000,000 0.003 N/A N/A #VALUE! 270 212.115 57.88501 5 6 2 2 322 1 2 $0 $4,753,785 $1,000,000 

0.003 N/A N/A #VALUE! 270 212.115 57.88501 5 6 2 2 322 1 2 $0 $4,753,785 $1,000,000 0.003 N/A N/A #VALUE! 270 N/A N/A #VALUE! 5 6 2 2 322 1 2 2 $0 $5,721,733 $1,000,000 $0.003 N/A N/A #VALUE! 270 N/A N/A #VALUE! 5 6 2 2 322 1 2 2 $0 $7,240,332 $1,000,000 $
FacilityID

WIWausauRhineWIWausauRhineWIWausauRhineWIWausauRhineWIWausauRhineWVGPMtHopeOSBWVJELD‐WENCraigsvilleWVWeyerhaeuserBuckhannonRepresents Biomass, Coal, LiquShaded units indicate changes tDeleted limited use units

Hg %red

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PM 

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Metals 

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Group NAICS

PM Need 

Upgrade?

HCl Need 

Upgrade?

Hg Need 

Upgrade?

Dioxin 

Need 

Upgrade?

CO Need 

Upgrade? PM Upgrade Cost HCl Upgrade Cost Hg/Dioxin Upgrade Cost CO Upgra

0.003 N/A N/A #VALUE! 270 N/A N/A #VALUE! 5 3 1 1 322 2 2 2 $0 $4,362,654 $1,000,000 $

0.003 N/A N/A #VALUE! 270 N/A N/A #VALUE! 5 3 1 1 322 2 2 2 $0 $4,362,654 $1,000,000 $0.003 N/A N/A #VALUE! 270 N/A N/A #VALUE! 5 3 1 1 322 2 2 2 $0 $4,362,654 $1,000,000 $0.003 N/A N/A #VALUE! 270 N/A N/A #VALUE! 5 3 1 1 322 2 2 2 $0 $4,362,654 $1,000,000 $0.003 N/A N/A #VALUE! 270 N/A N/A #VALUE! 5 6 2 2 322 2 2 $0 $0 $1,000,000 $

#VALUE! 4 N/A N/A #VALUE! 690 126.9091 563.0909 5 6 2 2 321 1 $3,903,217 $0 $0 

#VALUE! 0.005 N/A N/A #VALUE! 490 181.5465 308.4535 5 6 2 2 321 2 2 $1,741,101 $0 $1,000,000 #VALUE! 0.005 N/A N/A #VALUE! 490 22.81118 467.1888 5 6 2 2 321 2 $0 $0 $1,000,000 

Filtered Boilers: TOTAL $1,873,342,142 $1,036,172,140 $494,000,000 $94COUNT 545 545 545 AVERAGE $3,437,325 $1,901,233 $906,422 $

*Press F9 to recalculate 

All Boilers:TOTAL $5,119,891,642 $5,149,190,442 $1,424,000,000 $2,49

40 255 COUNT 1584 1584 1584 

23 115 AVERAGE $3,232,255 $3,250,752 $898,990 $