### MEMORANDUM

SUBJ ECT: CISWI E.O. 12866 Meetings

FROM: Toni Jones, U.S. Environmental Protection Agency

TO: Commercial and Institutional Waste Incinerators (CISWI) Rule Docket

This memorandum lists various stakeholder meetings with the Office of Management and

Budget in response to the mandate of Executive Order 12866. Meeting materials and handouts

are attached.

**•** Jane Luxton, Pepper Hamilton LLP on behalf of Treated Wood Council

– 11/8/11 at 2:30 pm

**•** Tim Hunt, AF&PA

– 11/9/11 at 4:00 pm

**•** Bryan Brendle, Portland Cement Association

– 11/10/11 at 1:00 pm

**•** Peter Pagano, American Iron and Steel Institute

– 11/15/11 at 11:00 am

**•** Gregory M. Carnrick, Gephardt Government Affairs

– 11/16/11 at 4:30 pm

**•** Hal Shapiro, Akin Gump

– 11/18/11 at 3:00

**•** Douglas Green, Venable LLP on behalf o f NORA

– 11/22/11 at 2:00 pm

**•** Lisa Jaeger, Bracewell & Giuliani on behalf of CIBO

– 11/22/11 at 5:00 pm

**•** Tracey Norberg, Rubber Manufacturers Association

– 11/23/11 at 2:00 pm

**•** William Turley, Construction Materials Recycling Association

– 11/29/11 at 5:00 pmNovember 18, 2011

Via email: chiggins@omb.eop.gov

Ms. Cortney Higgins

Office of Information and Regulatory Affairs

The Office of Management and Budget

725 17 th Street, N.W.

Washington, DC 20503

Re: Non

‐ Hazardous Secondary Materials

– Executive Order 12866 Review of Forthcoming

EPA Proposed Rule: Standards of Performance for New Stationary Source and Emission

Guidelines for Existing Sources: Commercial and Industrial Solid Waste Incinerator

Units: Reconsideration and Proposed Amendments

Dear Ms. Higgins:

The Treated Wood Council (TWC) appreciated the opportunity to meet with you and other

representatives of the Office of Information and Regulatory Affairs (OIRA), Environmental Protection

Agency (EPA), and other interested federal government offices on November 8, 2011, during the

interagency review of EPA’s forthcoming proposed rule on Non

‐ Hazardous Secondary Materials (NHSM),

which we understand will now be part of a new proposed rule on Commercial and Industrial Solid Waste

Incinerator Units (CISWI). We have not, of course, seen the proposed rule, and accordingly base our

comments on the description of EPA’s intended rule that is contained in EPA Administrator Jackson’s

October 20, 2011 letter to Senators Wyden and Snowe.

TWC reiterates that EPA’s authority over nonhazardous secondary materials extends only to

those that are discarded, under a line of binding court decisions, e.g

., American Mining Congress v. EPA

,

824 F.2d 1177 (D.C. Cir. 1987). As discussed at our meeting, used treated wood has a long history of

legitimate use as a valuable fuel in combustion units. Examples include creosote railroad ties and utility

poles treated with pentachlorophenol, which are in demand as valuable fuels.

For many years, contracts and arrangements have been in place for “takeback” of railroad ties

treated with creosote, which are valuable as a fuel because of their lower moisture content

– compared

to virgin wood

– and higher BTU value, a result of the fact that creosote is made from coal tar oil, which

increases the burning temperature of wood products treated with it. An electricity

‐ generating plant in

central Pennsylvania was constructed specifically to burn creosote

‐ treated wood products, because of

this richer burning capacity. Cogen plants in the MidWest and other parts of the country preferentially

choose to burn railroad ties and penta treated utility poles because of these favorable properties, and 1111 19 th Street, NW

Suite 800

Washington, DC 20036

Phone: (202) 463-2045

Fax: (202) 463-2059paper mills throughout the country similarly seek treated wood biomass. These market realities have

existed for many years, and have been recognized in comments submitted in EPA’s prior NHSM

rulemaking by states that have noted the appropriateness of treated wood products for boiler

combustion. Further, EPA’s materials characterization paper on construction and demolition materials

acknowledges that treated wood is “in demand” for use as a fuel.

The Administrator’s letter references three categories of nonwaste secondary materials that

EPA is likely to set forth in the proposed rule: (1) traditional fuels such as virgin wood, (2) nonwaste

materials that have a track record of use as fuel, and (3) materials that are established as fuel on a case

by case basis, using the “legitimacy criteria” identified in EPA’s March 2011 final rule or “other

circumstances” that demonstrate that the materials are combusted as fuel. One example that the letter

cites of the second category as nonwaste materials, is resinated wood. Resinated wood includes

products that contain formaldehyde and organic solvents that were deliberately added to provide

properties useful for the product. Treated wood is analogous, in that it consists of wood with chemicals

added as preservatives to make a useful product. Just as resinated wood is regarded as a valuable

secondary material for combustion, the same is true of treated wood products. When nonhazardous

treated wood products are combusted as fuel, they too are not discarded.

Strong policy reasons support the view that these materials should not be viewed as wastes.

Biomass, including treated wood, that is burned for fuel results in lower greenhouse gas (GHG)

emissions than combustion of comparable quantities of fossil fuels. Barring treated wood from this

legitimate use will lead to the substitution of fossil fuels such as coal, oil, or natural gas and greater GHG

emissions. In addition, misclassification of these materials as wastes will result in their diversion to

landfills, a less desirable option in EPA’s established hierarchy than reuse as a combustion fuel.

For all these reasons, EPA should recognize that nonhazardous treated wood products are not

discarded when combusted for fuel. EPA should not pursue a rule that upsets the longstanding use of

treated wood as a valuable boiler fuel and produces undesirable environmental outcomes.

Sincerely,

Jeffrey T. Miller

President & Executive Director

cc: George Faison, EPA/OSWER ( faison.george@epa.gov )

Bob Wayland, EPA/OAR ( wayland.robertj@epa.gov )

Tom Gillis, EPA/OP ( gillis.thomas@epa.gov )

Toni Jones, EPA/OAR ( jones.toni@epa.gov )

David Cozzie, EPA/OAR ( cozzie.david@epa.gov )

Dom Mancini, OMB/OIRA ( dmancini@omb.eop.gov )

Glen Sheriff, CEQ ( glenn_d_sheriff@ceq.eop.gov )

Kevin Bromberg, SBA/Advocacy ( kevin.bromberg@sba.gov )

Bruce Rodan, OSTP ( brodan@ostp.eop.gov )

Kevin Neyland, OMB/OIRA ( kneyland@omb.eop.gov )

Sandra Levy, CEA ( slevy@cea.eop.gov )

David Rostker, SBA/Advocacy ( david.rostker@sba.gov )

## Executive Summary

Economic Impact of Pending Air Regulation s on the U.S. Pulp and Paper Industry

September 2011

Findings

The costs of implementing Boiler MACT regulations, when combined with the anticipated

costs of implementing other pending air regulations, would place at risk 36 mills and 20,541

pulp and paper mill jobs nationally – 18 percent of the primary pulp and paper industry

workforce. Those jobs losses would rise to 87,299 if jobs in the supplier and downstream

industries and jobs associated with the re-spending of wages are figured into the equation.

These 87,299 job losses would result in about $4 billion in reduced wages and some $1.3

billion in lost state, local and federal taxes (including FICA taxes).

Background

In March 2011, the Environmental Protection Agency (EPA) issued final rules establishing

Maximum Achievable Control Technology for industrial boilers, commonly referred to as the

Boiler and Incinerator MACT rules. Several other unrelated air regulations are also pending.

They include but are not limited to Cluster MACT reopening, Pulp and Paper Residual Risk,

and several National Ambient Air Quality Standard (NAAQS) revisions that directly or

indirectly drive more stringent rules.

Fisher International, authors of this report, conducted the economic and job impact analysis of

the cumulative impacts of the final Boiler MACT rules and other pending air regulations under

consideration by the EPA. Fisher Internati onal, a market leader specializing in market and

economic data on U.S. paper mills, utilized its proprietary database of mill assets and cost-ofproduction to make its evaluations of potential job loss and mill closures.

The compliance cost data used in the Economic Impact analysis are attributed to URS, a

leading provider of engineering, construction and technical services. While this report uses

the same methodology as was used in the 2010 Fisher International report on the proposed

rules, the capital and operating costs of compliance to regulations were updated by URS,

based on the latest available information.

The focus of the Fisher International study was to quantify the likely impact of potential new

air regulations on employment in U.S. pulp and paper mills.

Methodology

Fisher International determined that the typical U.S. paper mill could, at most, absorb an

average 12.5% increase in its cost of production before its free cash flow would be

exhausted. Using information provided by URS, Fisher then determined mills that reached or

exceeded the 12.5% threshold to be in jeopardy of closing. Finally, Fisher isolated the impact

of Boiler MACT by determining whether the mills most at risk would not close if Boiler MACT

were removed from the suite of pending air regulations.September 7, 2011 As most regulations require both capital and operating costs, a formula was devised to

translate capital costs into operating costs by using an interest rate of 11 percent and a term

of five years. This weighted average cost of capital was based on a 2010 survey of

investment bankers and industry analysts. Further details regarding the cost analysis can be

found in the report.

Job Losses and Mills At Risk Associated with Boiler MACT and Air Regulations 1

Mills At Risk Pulp and Pape r

Mill job losses Including j obs in other

industries sustained by

the mills

Boile r MACT 36 20,541 87,299

All Ai r Regulations 2 79 38,060 161,755

In brief, the Fisher findings suggest that the Boiler MACT regulations, considered along with

the costs of other pending air regulations, would place at risk 36 mills and 20,541 pulp and

paper mill jobs nationally (18% of the primary pulp and paper industry workforce). If jobs in

the supplier and downstream industries and jobs associated with the re-spending of wages

are figured into the equation, the job losses rise to 87,299. A multiplier effect of 4.25 was

chosen based on a study by the Economic Policy Institute. AF&PA estimates that these

87,299 job losses would result in about $4 billion in reduced wages and some $1.3 billion in

lost state, local and federal taxes (including FICA taxes).

According to URS, the total capital costs for the forest products industry from upcoming EPA air

regulations are about $17 billion. The Fisher findings indicate that the entire suite of air

regulations could place 79 pulp and paper mills in jeopardy of closing, resulting in the loss of

38,060 pulp and paper mill jobs, or 33% of the primary pulp and paper workforce. If jobs in

supplier industries and jobs associated with the re-spending of wages are also included, the

jobs loss figure rises to 161,755. AF&PA estimates that these 161,755 job losses would result

in $7.4 billion in reduced wages and some $2.5 billion in lost state, local and federal taxes

(including FICA taxes).

This new study, when compared to the 2010 study, shows that the final Boiler MACT rules

place about 3,500 more jobs at risk than the proposed rule. This is due partly to the fact that

many more boilers using biomass as a fuel w ill be treated as incinerators rather than boilers

and subject to much more costly control technology. Overall, slightly fewer jobs are placed at

risk from the cumulative burden in the 2011 study. Several marginal mills have closed since

the previous study was completed, taking them out of the calculation and the overall health of

the industry improved as the overall economy improved between the two studies.

1 Note that these estimates do not include jobs losses in the wood products manufactu ring sector of the forest

products industry from an estimated $2 billion in new MACT costs.

2 Roughly $2 billion in new capital costs for pulp and paper mills meeting various National Ambient Air Quality

Standards (NAAQS); changes to the New Source Revi ew (NSR) requirements; New Source Performance

Standards (NSPS) and the Clean Air Interstate Rule (CAIR) were not factored into the mill closure/job loss

calculations because they could not be allocated to specific mills.

# Boiler MACT

- NHSM Issues

November 9, 2011

# Overview

Major issue for forest product manufacturers

$7 Billion in capital to meet March rules

87,000 jobs at risk due to potential paper mill closures



# Severe impacts on wood product mills as well



# Non

- Hazardous Secondary Material (NHSM)

Roadblocks for biomass residuals and other common fuels



# Boiler MACT

– major issues

Achievable limits

– CO, dioxin, and new sources

Boiler testing for CO, PM subcategories, and time to comply

2

# NHSM: Perverse Outcomes

Preamble identifies many materials as likely to be fuels, HOWEVER

Rule language requires meeting “legitimacy criteria”

contaminant level must be comparable to “traditional fuel”

- coal, wood, etc.

Ignores historical use of these alternative fuels

Many biomass residuals will flunk test

- turning boilers into “Incinerators” (3X cost)

Resinated wood, wastewater and paper process residuals become solid wastes

No health concerns

– very small quantities and well controlled under MACT

Many/Most facilities will stop burning, landfill materials and buy fossil fuels

Millions of tons filling our landfills

$660 million/year just for forest products

– some mills won’t survive

Failure to fix puts MACT floor analysis in jeopardy ... again.



# 3

# NHSM Fixes

List residuals as non

- waste fuels, including:



# Biomass [such as, Resinated wood, Wastewater and

Paper recycling residuals, used Railway Ties]

TDF and used oil

Urban wood (clean C&D) as traditional fuel/clean biomass

Ensure contaminant legitimacy criteria do not prevent

materials becoming fuel

– make discretionary factor

Create workable petition process for classifying other



# NHSM as non

- waste fuels

Address contained gas to reflect comfort letter to AF&PA

4

# Boiler MACT: Unachievable

Unachievable biomass limits for Carbon Monoxide

Problem : Many biomass boilers cannot consistently meet CO limit

Solution : set feasible short term limits and alternative longer

- term (monthly)

limits that reflect data variability; mine existing data as much as possible ; use

Upper Permissible Limit at 99.9%



## Biomass Stokers: ~900 ppm (3

- hr) and ~500 ppm (monthly)

Biomass Fluidized bed: ~700 ppm (3

- hr) and ~350 ppm (monthly)

Unachievable limits for Dioxin



## Problem : Data are below levels that can accurately be measured (see diagram);

results are meaningless at extremely low levels ; limits more stringent than any

MACT (see chart)

Solution : Adopt reasonable work practices for all subcategories to sustain



## efficient combustion, as law provides



# 5

# 6 

# L Q 

# L

D 

# L C

Cannot differentiate

from background 

# L C



# L

D



# L Q Critical Level

Limit of Detection

Limit of Quantitation

Can differentiate

from background.

Low confidence in

detection. 

### Analyte is detectable.

Low confidence in

quantity. 

### The analyte is

quantifiable with a

known level of

precision and bias



# Analyte Concentration 

# Method Sensitivity Benchmarks

(All dioxin detections

are here

-- below the

level of confidence

that the number is

accurate)

# 7

# Boiler MACT: Unachievable

Unachievable New Source Limits

Problem : non

- gas boilers can’t reliably meet; discourages replacement of older

boilers/modernization including new biomass units

Solution: test methods can’t measure at these levels so adjust limits to reflect

quantitation limits



# 8 HAP/Surrogate Biomass Stokers Biomass Fluidized

PM (lb/MM Btu) ~0.01 ~0.008

CO (3

- hr in ppm) 550 300

CO (monthly in ppm) ~400 ~250



# Mercury (lb/T Btu) ~3.5 ~3.5

# Boiler Testing

Four CO CEMs tests getting underway on top

performing stoker and fluidized bed biomass boilers

Best to have year of data given operational and fuel



# changes

– wettest biomass January to May

If EPA finalizes in April, only have Nov

- Jan test data

will continue to test some units beyond January

every extra month important depending on “mining” of

existing data



# Notice of Data Availability

– consider late data

9

# Reasonable Particulate Limits

The depressed housing market has hit the wood



# product industry especially hard with 128,000 jobs

lost since 2008 (28% of the work force)

Banks will not lend money or companies cannot



# commit capital for controls

- mills will close

PM limits based on the unique fuels, products and

boiler designs could make the limits affordable and

protective

More compliance time, may see return to profitability

10

# Adequate Time to Comply

– Five Years

Three years insufficient given the investment of billions of



# dollars

– need 5 yrs; Incinerators get up to 5 yrs.

Most complex set of requirements manufacturers have ever

faced and in the worst economy since passage of the Act.



# Evaluation of control strategies for five pollutants plus other

obligations requires many engineering studies and planning.

Competition fierce for control vendors and qualified

consultants given other rules (e.g., Utility MACT, CSAPR)

More time increases the odds that mills will return to

profitability and be able to afford controls rather than close

Periodically report progress

– did in Paper Cluster MACT

Ask for comment in the preamble on extra two years 11

# Other Reconsideration Issues

Minimum of 90 day comment period to examine



# floor data and multiple rules together

PM CEMS not justified



# Retain work practices for start

- up and shutdown

Achievable liquid fuel limits (very low CO and PM

limits)

– distillate and residual subcategories

Defer energy audit for GACT sources by 2 years

New Source date should be reset with this proposal

12

# CUMULATIVE COST BURD EN

ANALYSIS OF AIR REGULATIONS

POTENTIALLY IMPACTIN G THE

FOREST PRODUCTS INDU STRY

Prepared for:

1111 19 th 

### St. NW, Suite 800

Washington, DC 20036

Prepared by:

URS Corporation

1600 Perime ter Park Drive

Morrisville, North Carolina 27560

(919) 461

- 1100

URS Project No. 318 2 6756

Updated August 201 1

# 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 Scenario s 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 L ist of Ac r on ym s an d Abb r e viation s

AF& P A Ame ric a n F or e st and P a p e r A ssocia ti on

B ACT B e st Ava il a bl e C ontrol Te c hnolo g y

B ART B e st Ava il a bl e R e trof it T e c hnolo g y

C A I R C lea n Air I nter stat e R ule

C I S W I C omm e rc ial or I nsti tut ional S oli d W a ste I nc iner a t or

CO 2 

### C a rbon Diox ide

C EMS C onti nuous Emi ssi on s M onit or ing S y stem

C P MS C onti nuous P a ra mete r Monitoring S y stem

EPA Environme ntal P rote c ti on Age nc y

GA C T Ge ne r a ll y Av a il a ble Con trol Te c hnolo g y

GHG Gr e e nhous e Ga s

H 2 

### S H y d ro g e n S ulfide

HAP Ha z a rdous A ir Pol lut a nt

HB C A He a lt h Base d Com pli a nc e Alter na ti ve

L AER L ow e st Ac hiev a ble E mi ssi on Rate

MACT Max im um Ac hieva ble Cont rol Te c hnolo g y

NAAQS Na ti ona l Ambi e nt Air Q ua li t y S tanda rds

NCAS I Na ti ona l C ounc il f or Air a nd S tre a m I mprove m e nt

NESHA P N a ti ona l Em iss ion S tand a rds f or H a z a rdous A ir P oll utants

NH S M Non

- Ha z a rdous Se c onda r y M a ter ials

NO

x 

### Nitrog e n Ox ides

NSP S Ne w Sourc e P e rf or m a nc e S tanda rds

NSR Ne w Sourc e R e view

P C W P P l y wood a nd Co mpos it e W ood P roduc ts

PM P a rticula te Ma tt e r

PM 10 

### P a rt icula te Ma tt e r w it h d iame ter less than 10 micr ons

PM 2

. 5 

### P a rticula te Ma tt e r w it h d iame ter less than 2.5 mic rons

P & P P ulp and Pape r

PSD P re ve nti on of S ig nific a nt De ter ior a ti on

R TR R isk and Te c hnolog y R e view

# TABLE OF CONTENTS

iii

SO 2 

### S ulfur

Diox ide

SSM S tar tup, S hutdown, or Malf unc ti on

VOC Vola ti le O r g a nic Com po und

# SECTION 

# ONE Int ro duc tio n/ S umm a ry

1

- 1 1. S e c t i o n 1 O N E I n t r o d u c t i o n / S u m m a r y



## 1 .1 INT RODU C T I O N

URS C or pora ti on (U R S ) pe rf

or med a de tailed a na l y s is of the c umul a ti ve c o st burde n of a ir

re g ulations that ma y pote nti a ll y im pa c t Ame ri c a n F or e st and P a p e r A sso c ia ti on (A F & P A)

membe r c ompanie s (e

. g

., wood pr oduc ts m a nuf a c t ur ing f a c il it ies a nd pulp a nd/or pa pe r

manuf a c turin g f a c il it ies)

. The purp ose o f th e a na l y s is wa s to de t e rmine a r oug h ord e r of

mag nit ude e sti mate of the c umul a ti ve c ost bu rd e n that would be im posed on the F or e st P roduc ts

I ndust r y if EPA im pleme nts var ious air re g ulato r y c ha n g e s that a re c urr e ntl y unde r

c onsi de ra ti on

. The a ir q ua li t y r e g ul a ti ons e va luat e d would im pa c t m e mber c ompan y boi ler s a nd

other proc e ss equipment. The c ost esti mate s we re c ompi led in a Mi c rosof t Ex c e l wor kbook ;

we re b a se d on publi shed infor mation or sim il a r pr ojec t costs ; ha ve be e n re view e d b y membe r

c ompan y r e p re se ntatives ; a nd ha ve b e e n mad e a va il a ble to the U S EP A a nd other s for r e view

. Note that the B oil e r MA C T a nd C I S W I c osts a r e ba se d on the Ma rc h 2011 rule s a nd infor mation

in EP A’ s Mar c h 2011 sur ve y a nd e mi ssi ons da taba se s , but also t a ke int o a c c ount t he

pr omul g a ted soli d w a ste de finiti on ru le, tha t dete r mi ne s whe ther se c onda r y mate ria ls bein g

burne d in boi ler s ar e f

ue l s or soli d wa ste a nd whe t he r boiler s a re r e g ulate d unde r B oil e r

MACT/ GA C T or

C I S W I

. This docume nt provide s bac k g round infor m a ti on on the r e g ulations

include d in t he a na l y sis a nd the me thodol og i es use d in t he a na l y sis

.



## 1 .2 CONC L USI O NS

The f oll owing p re se nts a summ a r y o f the c onc lusi ons fr om t he c ost esti mate a na l y sis

.

 B a se d on th e a na l y sis de s c ribe d in t his re port, a ir r e g ul a tor y a c ti ons c u rr e ntl y unde r

c onsi de ra ti on b y EPA c o uld re sult in a F or e st P ro duc ts I ndust r y tot a l e sti mate d ini ti a l

c a pit a l cost of $ 1 6

. 5 bil li on a nd a n e sti mate d a nnu a li z e d c ost of $ 4. 3 bil li on

.

 The r e g ulator y a c ti on wit h the most sig nific a nt e c onomi c im pa c t on fa c il it ies w it h

indus trial boil e rs w il l be the r e vised I ndust ria l B oi ler Max im um Ac hieva

ble Cont rol

Te c hnolo g y ( MACT) St a nda rd , c ombi ne d with t he r e vised C I S W I a nd soli d wa ste

de finiti on ru les

. W e ha ve e sti mate d c osts usi ng a pr im a r y sce n a rio tha t ass umes man y

se c onda r y m a ter ials burn e d b y for e st produ c ts fa c il it ies a re de ter mi ne d to b e sol id wa ste,

a nd a lso un de r a

sec ond a r y s c e na rio tha t assumes man y of th e se mate ria ls a re de te rmine d

to be f ue ls.

 The r e g ulator y a c ti on wit h the most sig nific a nt e c onomi c im pa c t on wood pr oduc ts

fa c il it ies is ex pe c ted to be the r e visi ons to t he wo od pr oduc ts M ACT st a nda rd.

 The r e g ulator y a c ti ons w it h the most sig nific a nt e c onomi c im pa c t on pul p a nd pa pe r mill s

a re c onsi d e re d to be dis c r e ti ona r y a c ti ons, a nd not manda ted a c ti ons, a nd include

re g ulation of h y dr o g e n s ulfide (H 2 

### S) a s a ha z a rdo us air poll utant ( HA P ), r e g ulation of

re c ove r y f

ur n a c e s unde r t he C lea n Air I nte rsta te R ule ( C A I R ) tha t cur re ntl y r e g ulate s

fossil f ue l

- fir e d uti li t y bo il e rs, a nd a ddin g r e g ul a te d c ompounds to t he pulp and pa pe r

MACT st a nda rds.

# SECTION 

# ONE Int ro duc tio n/ S umm a ry

1

- 2 

## 1 .3 REPORT O R G AN I Z AT I O N

The r e ma ind e r of

thi s re p or t i s di vided into t he f oll owing se c ti ons:

S e c ti on 2.0: Air Re g ul a ti ons Eva luate d

S e c ti on 3 .0: C ost M e thodol ogy a nd Result s

The table of c ontents c on tains a de tailed lis ti ng o f table s a nd a ppe ndi c e s.

# SECTION 

# TW O A ir Reg ulati ons Evalu ate d

2

- 1 2. S e c t i o n 2 T W O A i r R e g u l a

t i o n s E v a l u a

t e d



## 2 .1 REGULA T I O NS E VAL UA T E D

AF& P A me mber c ompa nies identifie d sev e r a l air qua li t y r e g ul a ti ons t ha t have the pote nti a l t o

sig nific a ntl y im pa c t t he m e c onomi c a ll y . Of the re g ulations identifie d, som e a re r e g ulations that

EPA i s re quire d to prom ulg a te o r r e vise a nd som e a re r e g ulations that EP A ma y d e c ide to

re view , r e vise, or

im ple ment. Note that be c a use the r e g ulator y sch e me f o r gr e e nhous e g a se s

(G HG ) is unc e rta in, t his a na l y sis did not f oc us on the c ost of

GH G re g ulati ons , whic h is a lso

e x pe c ted to be sig nifi c a n t for the indust r y

.

Table 2

- 1 pr e se nts the po tential a ir r e g ulator y a c t i ons c onsi de re d a nd the ma in re g ulate d

c ompounds im pa c ted. A F & P A c onsi de rs the f oll owing r e g ulator y a c ti ons di sc re ti ona r y on the

pa rt of EPA:

 R e visi ti ng the pulp a nd p a pe r MA C T stand a rds ou tsi de of the r e quir e d risk a nd

tec hnolog y re view (RTR) re quire m e nts ;

 I n c ludi ng indus trial boil e rs a nd re c ove r y fur na c e s in t he C lea n Air I nter stat e R ule ( C A I R )

re plac e ment, now te rm e d the C ross S tate Air Pol lut ion R ule ( C S APR ) ;

 R e g ulatin g H 2 

### S a s a H A P ;

 D e ve lopi n g Ne w Sour c e P e rf or manc e S tanda rds ( NSP S ) f or wood pr oduc t s

manuf a c turin g ; a nd

 R e visi on s to t he c urre nt Kr a ft Pul p Mi ll NSP S un de r 40 CF R 60, S ubpa rt B B

.

The other non

- disc re ti on a r y r e g ul a tor y a c ti ons i nc lude:

 B oil e r MA C T re

- pr omul g a ti on ( will r e sult in si g n ifica ntl y low e r lim it s than the 2004

re g ulation t ha t wa s va c a t e d) ;

 Ge ne r a ll y A c hieva

bl e C ontrol Te c hnolo g y ( GA C T ) f or boil e rs loc a ted a t a r e a

sourc e s of

HAP ;

 R e g ulation of boil e r s a s c omm e rc ial or indus trial s oli d wa ste inc iner a tors ( C I S W I ) if

c e rta in m a te ria ls ar e de e med w a ste a nd not fu e l ;

 R isk and Te c hnolog y R e view f or P ulp and Pape r MACT rule s (to de ter mi ne if a ddit ional

HA P e mi ssi ons c ontrols ar e ne e de d ) ;

 R e view ing /l owe rin g t he Na ti ona l Ambi e nt Air Q ua li t y S tanda rd (N AA QS ) f or Nitro g e n

Ox ides , ne w 1

- hour stan da rd (N O

x 

### ) ;

 R e view ing /l owe rin g the NA AQ S f or S ulfur Diox ide , ne w 1

- hou r sta nda rd (SO 2 

### ) ;

 The C onti nuous P a ra mete r Monitoring S y stem (C P MS ) r ule spe c if y in g qu a li t y a ssur a nc e

pr oc e dur e s for

C P MS r e quire d b y NSP S a nd MACT st a nda rds ;

 F ull im pleme ntation of the NA AQ S f o r particula t e matter

less than 2.5 mic rons in

diame ter ( P M 2

. 5 

### ) ;

 R e visi ons t o the Pl y woo d a nd Co mpos it e W ood P roduc ts (P C W P ) MA C T due to cour t

de c isi ons;

# SECTION 

# TW O A ir Reg ulati ons Evalu ate d

2

- 2  C ha ng e s to the PC W P a nd P ulp and Pape r MA C T r ules due to the S S M va c a tur (sour c e s

a re no lon g e r e x e mpt f

ro m compli a nc e durin g pe r iods o f SS M) ;

 R e view ing /l owe rin g the Oz one NA AQ S a nd incr e a se d numbe r of non

- a tt a inm e nt ar e a s ;

a nd

 F ur ther re g ulation of sou rc e s unde r th e R e g ional Ha z e r ule to mee t futur e pr ogre ss

tar ge ts

.

Esti mate d re g ulator y c ost s a re sum mar iz e d in App e ndix A a nd a re pr e se nte d b y r ule in

Appe ndix B of this docume nt.



## 2 .2 REGULA T O RY

TIME L I NE

The a ir r e g ulations we r e e va luate d in ord e r of e x pe c ted e ff e c ti ve da te a nd e ff

or ts we re made to

a void doubl e c ounti ng re g ulator y im pa c ts. F or e x a mpl e , if a boil e r installe d a c id g a s con trols

unde r B oil e r MA C T f

or c ontrol of h y dr o g e n c hloride a nd other inor ga nic HA P s , the f

a c il it y

would pr e sumabl y not ha ve to i nstall a ddit ional c ontrols on t he boil e r a s a r e sult of f uture

re g ulations im pa c ti ng S O 2 

### e mi ssi ons.

Table 2

- 2 pr e se nts t he r e g ulator y c ost i mpac t ana l y s is b y y e a r, ba se d on th e e x pe c ted tim ing

. F or r ules whe r e the ma

jo rit y of the sou rc e s a re im pa c ted upon the ini ti a l pr omul g a ti on of the r ul e

(e

. g ., B oil e r MA C T) , e sti mate d c a pit a l costs a re p ha se d thre e y e a rs pr ior to the c ompl ianc e d a te

a nd a nnua l costs r e main c onst a nt ea c h y e a r f oll owing the c ompl ianc e d a te ( the numbe r o f

a ff e c ted sour c e s is a ssum e d to re main r e l a ti ve l y c o nstant). F or r ul e s whe r e sourc e s a re im pa c t e d

ove r tim e ( e

. g

. , NSP S ), a nnua l oper a ti n g c osts inc re a se ov e r tim e a s the nu mber of a f fe c ted units

incr e a s e s. De tails o n ho w the c ost esti mate s we re de ve loped a re pr e se nted in S e c ti on 3.

# SECTION 

# TH RE E Co st Me thod olo gy

3

- 1 3. S e c t i o n 3 T H R E E C o s t M e t h o d o l o g y



## 3 .1 COST ES T IM A T E MET HOD O L O G Y

URS e sti mate d a ir r e g ula tor y c osts f o r thr e e c a t e gorie s of f

or e st produc ts i ndust r y sour c e s:

indus trial boil e rs, w ood pr oduc ts i ndust r y sour c e s (non

- boi ler s), a nd pulp a nd pa pe r industr y

sourc e s (non

- powe r boile rs) . The r e g ulations c ons ider e d in t his ana l y sis we re a ssi g ne d to one o r

more of the se c a te g o rie s, a s shown in Ta ble 2

- 1, a nd in g e n e ra l a re or d e r e d b y e x pe c ted e ff e c ti ve

da te.

The thre e k e y va ri a bles i n the a na l y sis we r e the c ost of c ontrols, t he number of a ff e c ted units

,

a nd the inter

- r e lations hip of the r e g ulations . F o r e a c h c a te g or y a nd re g ulati on, potential

c ompl ianc e or e mi ssi ons c ontrol sce na rios we r e de ter mi ne d ba se d on the c o mpounds e x pe c ted to

re quire c ontrol, and f

or e a c h of the s e sce n a rios, c o mpl ianc e c osts a nd numb e rs of unit s included

in t he sce na rio w e re e sti mate d. B oth a c a pit a l co st and a n a nnua l ope ra ti n g c ost w e re

de ter mi ne d, a nd the c a pit a l cost wa s ann u a li z e d usi ng a c a pit a l r e c ove r y fa c tor to de ve lop t he

tot a l estim a ted a nnua l co st for e a c h s c e n a rio. The r e g ulator y c osts a re driv e n b y s e lec ti on of the

c ompl ianc e method or c o ntrol t e c hnolog y to a c hie ve sig nific a nt emis sion re duc ti ons ra ther th a n

to m e e t an y spec ifi c li mi t unde r a pa rticula r re g ula ti on.

C a pit a l and ope ra ti n g c os ts esti mate s a re not i nten de d to re pr e se nt a w o rst c a se a n a l y sis . Rather

, the y r e pr e se nt m e dian c o sts f or the va rious sc e na ri os ba se d on publi shed re ports, indust r y

infor mation on spec ific p roje c t costs, EPA re po rts or c ontrol dev ic e f

a c t she e ts, or a c tual B ACT

or B ART a n a l y se s subm it ted to pe rmitt ing a g e n c ies. A pr im a r y r e sourc e wa s the doc ument

“ Eva luation of A ir Pol lut ion C ontrol C osts f or the Pul p a nd P a

pe r I ndust r y

, ” pre pa re d b y

Na ti ona l Eco nomi c R e se a rc h Asso c iate s (N ERA ) in Ma y 2003. Not e that c osts we re not s c a led

fr om t he da te of

th e r e fe r e nc e used to 20 1 1 doll a rs a s the int e nt wa s to d e ve lop an or de r o f

mag nit ude e sti mate f

or e a c h c ontrol sc e na rio.

Air e mi ssi ons c ontrols we re a ssi g ne d to t he rule w it h the e a rliest e ff e c ti ve d a te. F or e x a mpl e , if

a late r r ul e r e quir e s the s a me c ontrols (e

. g ., indus t ria l boi ler s ar e c ove re d b y C A I R a t a da te

following the impl e ment a ti on B oil e r MA C T) , the c ontrol cost is not doubl e c ounted. H owe v e r,

if a c ost f rom a n e a rlie r r ule doe s not oc c ur , o r if a r ulema king is d e la y e d, l a ter r ules c ould t he n

be c ome mor e e x pe nsive tha n c ur r e ntl y e sti mate d. S umm a rie s of the e sti mate d c osts f or e a c h

re g ulator y a c ti on a nd e a c h c a te g or y a re p re se nt e d in Appe ndix A.

URS r e c e iv e d the following e sti mate s f rom the N a ti ona l C ounc il f or Air a n d S tre a m

I mprov e ment ( NCAS I ) r e ga rdin g the numbe r s of e a c h t y pe o f f or e st produ c ts i ndust r y f

a c il it y :

700 s a wmil ls (approx im a tel y 221 of whic h a r e major

s ourc e s of HA P )

, 300 wood pr oduc ts m i lls (approx im a tel y 170 o f w hich a re major

sourc e s),

300 c onve rtin g plants (mostl y a re a sou rc e s )

, a nd

379 pulp and pa pe r mill s (mostl y m a jor sour c e s)

, i nc ludi ng 100 Kr a ft

, 8 se mi c he mi c a l,

18 mec ha nic a l pul p, 5 sul fite, a nd 1 soda

.

# SECTION 

# TH RE E Co st Me thod olo gy

3

- 2 

### 3.1.1 Boi l er Ca t eg o r

y

The de tailed c ost e sti mate s for the boiler c a te g o r y a re pr e se nted in App e nd ix B

. URS r e c e ived

the f oll owing infor m a ti on fr om NC AS I re ga rdin g the numbe r a nd t y pe s of boil e rs in the f or e st

pr oduc ts i ndust r y (note that 301 of the 918 pulp a nd pa pe r mill boil e rs a r e a t the 100 Kr a ft mi ll s) :

9 1 6 pul p a nd pap er m i l l bo i l e r s

8 3 coa l

67 coa l / w ood

1 08 w ood

658 oi l / g as ( abou t ha l f of t he se a

r e m aj or sour ce s of

H A P)

8 2 0 w ood pr odu ct s m i l l bo i l er s

600 w ood ( 100 m a j or sour ce s, 500 a

r e a s ou r ce s )

120 g as ( m ost ar e a s ou r ce s o f H A P)

100 oi l ( m ost ar e a s ou r ce s o f H A P)

200 boi l er s at conv er t i ng pl ant s ( pr ob abl y a l l a r e a s ou r ce s)



### The EPA c oll e c ted inf

o r mation during P ha se 1 of the B oil e r MA C T infor mation collec ti on

re que st ( I C R ) on 455 boi ler s at f a c il it ies in NA I C S 322xxx ( pulp and pa pe r a nd pa c k a g in g ) a nd

369 boil e rs in NA I C S c o de 321xxx ( wood pr oduc ts).

I n the boile r c a te g or y , a ll f or e st produc ts i ndust r y boil e rs ( not i nc ludi ng pul p mi ll r e c ove r y

boil e rs) will f

a ll unde r B oil e r MACT, B oil e r G A C T, or C I S W I

. URS identifie d the r e g ulate d

c ompounds li ke l y to re qu ire c ontrol, li ke l y c ontrol opti ons (some ti mes b y b oil e r f ue l t y pe )

,

t y pica l c ontrol costs, and e sti mate d number of un i ts af

fe c t e d for e a c h rule

. F or

the r e g ulator y

a c ti ons that ma y o c c u r a f ter these f irst t hr e e r ules, we then e sti mate d a ddit i ona l num be rs of

boil e rs tha t wil l also be a ff e c t e d, in an a tt e mpt to a void doubl e c ounti ng c on trol c osts . How e ve r,

note tha t an indivi dua l uni t m ig ht be r e pr e se nted m or e than one ti me in t he t a ble if it ha s to

inst a ll two diff

e re nt t y pe s of c ontrols for diff e r e nt re g ulate d c ompounds ( e

. g ., f a br ic f il te r f or P M

a nd c a rbon inj e c ti on fo r mer c ur y ). C osts of the b oil e r r ules w e re a ll oc a ted to t he wood pr oduc ts

a nd pulp and pa pe r se c to rs ba s e d on infor m a ti on a bout t he number s, t y p e s, and siz e s of boiler s in

e a c h c a te g or y

.

A de tailed spr e a dshee t w a s dev e loped to e sti mate c osts f or B oil e r MA C T, ba se d on EP A’ s major

sourc e boil e r inve nto r y d a taba se tabl e . Bec a us e t he r ule doe s not include e mi ss ion l im it s for

na tura l g a s boi ler s

, boil e r s less t ha n 10 MMB tu/ hr he a t i nput, or li mi ted use unit s, these unit s ar e

not i nc luded in the c ost a na l y sis

. B a se d on the inf or mation i n the E P A e mi ssi ons da taba se on

boil e r siz e , f

ue l, ex ist ing c ontrols, and e mi s sions , we e sti mate d c osts of c o ntrols t ha t would

li ke l y be n e c e ss a r y to co mpl y with t he B oil e r MA C T f or c oa l, bi omass, a n d li quid boil e rs. N ote

that EP A’ s Mar c h 2011 r ule a ssum e d that landf il l g a s boi le rs (f

or m e rl y in t he Ga s 2 c a te g or y )

c ould compl y with MAC T using wor k p ra c ti c e s

. As some f

or e st produ c ts boi ler s at ma jor

sourc e s di d not re c e ive a n I C R f rom EPA in 2008 , we a dde d inf or mation f

or those boil e rs to the

de tailed spr e a dshee t bas e d on a da taba s e maintain e d b y F isher I nter n a ti ona l and inf or mation

fr om NC AS I

.

I n for mation fr om va rious sourc e s w a s used to de te rmine a ba se c a pit a l cost for

a 250 MM B tu/ hr

boil e r f or e a c h P M , CO, a nd HCl c ontrol t e c hnolo g y opti on a nd then sc a led usi ng a n 0.6 pow e r

func ti on ba se d on the siz e of e a c h boil e r in the inv e n tor y

. F or e x a mpl e , the c a pit a l cost of a we t

sc rubbe r on a

100 MMB t u/hr boil e r is c a lcula ted a s the ba se c ost t im e s (10 0/250) 0

. 6 

### . A f ix e d

# SECTION 

# TH RE E Co st Me thod olo gy

3

- 3 c ost of $1 mi ll ion wa s assumed f or inst a ll a ti on of

a c a rbon a dsorption s y ste m for H g a nd/or

diox in contr ol, as these sy s tems do not va r y much in cost b y boil e r siz e . Base c ost assum pti ons

a re pr e se nted b e low . Op e ra ti n g c osts a r e ba se d o n EPA a nd ve ndor infor mation.

B as e Con t r o l Siz e, MM B t u 250

Fabr i c Fi l t er C api t a l C os t $7,000,000

We t S cr u bber C api t a l C os t $8,000,0 00

WS/ FF / ES P upg r ade C api t al C os t $4,000,000

C ar bon I nj ec t i on f

o r H g / di oxi n

C api t al C o st $1,000,000

C om bust i on I m

pr ov e m ent s or

C at a l y st f o r C O C api t a l C o st $ 3 ,000,000

I nt er es t R a t e 7 per ce n t

Equipm ent l i f

e, y r s 15

C api t al r ec ov er y f

ac t or 0.110

A ct i v at e d C ar

bon r at e, l b / m m ac f 4

A ct i v at e d C ar

bon co st

, $/ l b $1.00

We t sc r ubbe r ann ual ope r a t i ng

cos t

, $/ a cf

m $10

FF annua l ope r a t i ng co st $200,000



### F or the B oil e r MA C T c o ntrol c osts , we a ssum e d t ha t i f e mi ssi ons i nf o rma ti on (e it he r site

spec ific te st data o r E P A’ s base li ne e mi ssi on fa c to rs b y boil e r t y p e a nd e x ist ing c ontrol)

indi c a ted the boil e r w oul d not m e e t t he Mar c h 20 11 li mi ts , the unit would ne e d MACT, which

EPA sa y s is a fa

br ic filter (FF ) plus c a rbon inj e c ti on plus we t sc rubbe r plus c ombus ti on

imp rove ments (or

C O c a t a l y st). I n their

boil e r inv e ntor y t a ble, EPA put the boil e r pollut ion

c ontrols i nto ca te g or ies

. The c a te g o rie s a re e x plaine d in g r e a te r de tail i n E P A’ s base li ne

e mi ssi on fa c tor me mo, b ut basica ll y a re a s follow s : for P M c ontrol cod e

, 1

= F F , 2= E F B / ESP

, 3= ve nturi scr ubb e r, 4= w e t scr ubbe r, 5

= mul ti c lone , 6= none /m ist e li mi na tor/unknown

. I f a unit

did not a lre a d y ha v e a F F or E S P a nd the re w a s inf or mation t ha t i ndica ted the unit c a nnot m e e t

the lim it , we a ssum e d a

n e w FF

. I f th e unit a lre a d y ha d a F F or E S P a nd th e re w a s infor mation

that indi c a ted the unit c a nnot m e e t t he li mi t we a ssum e d a n up g ra d e to t he e x ist ing c ontrol

e quipm e nt . F or

HCl c on trol c ode , 1= w e t scr ubbe r or spr a y dr y e r, 2= d r y scr ubbe r, 3= sorb e nt

inj e c ti on, 4= ve nturi scr u bbe r , 5= non e /dr y P M onl y

. To e sti mate c ontrol co sts for HCl

, if the re

wa s infor mation t ha t i ndica ted the unit c a n not m e e t t he li mi t

, we a ssum e d e it he r a sc rubb e r

upg r a de or n e w sc rubbe r de pe ndin g on whe the r the unit c urre ntl y ha d a scr ubbe r . F o r H g c ontrol

c ode , 1= c a rbon inj e c ti on, 2= F F plus sorbe nt i njec t ion or spra y dr y e r, 3= F F onl y , 4= w e t scr ubb e r,

# SECTION 

# TH RE E Co st Me thod olo gy

3

- 4 5= ve nturi scr ubb e r, 6= no ne /m ult iclone /EF B /m ist e li mi na tor . F or H g a nd d iox in, if the re wa s

infor mation t ha t i ndica te d the unit c a nnot m e e t t he li mi t

, we a dd ed c a rbon inj e c ti on. F or C O, if

the re wa s info rma ti on that indi c a ted the unit c a nn ot m e e t t he li mi t , then we a ssum e d that c a pit a l

would be ne c e ssar y to eit he r pe r for m c ombus ti on/fue l fe e d im pr ove ments or other boil e r

im pr ove ment pr ojec ts t o re duc e C O o r inst a ll a C O c a tal y st.

C I S W I rule c osts we re d e ve loped in much the sa me ma nne r a s th e B oil e r MACT costs , usi ng

EPA’s C I S W I d a taba s e

. C ontrol costs for NO x we re a dd e d if ne c e ssa r y , a s sumi ng a ba s e c ost

for S NCR of $4 mi ll ion.

W e a ssum e d that c ompl ianc e with Bo il e r G ACT will onl y re quir e tune

- up s. Note that man y

fa c il it ies ma y c hoose fue l swi tching a s a c ompl ian c e opti on; howe ve r, a s th e c ost of f ue l

switching is hi g hl y d e pe nde nt on s it e spec ific f a c t or s (e

. g ., wh e ther

the boi ler

c a n bu rn the

a lt e rna te fue l, wh a t up g r a de s mus t be ma de to t he f ue l supp l y s y stem) a nd th e pric e o f f ue l i s

li ke l y to cha n ge ove r tim e due to fa c tors li ke supp l y a nd d e mand , we did n ot attempt t o qua nti f y

c osts f or f ue l swi tchin g

.

F or e a c h rul e , a

tot a l ann ua l cost i s pre se nted b a se d on the sum of e a c h li ne it e m under the r ule

a nd re pr e se nts t he f

irst y e a r of

im pleme ntation of the r ule ( fo r some r ules t he a nnua l ope ra ti n g

c ost wi ll incr e a se ov e r ti me a s more sour c e s be c o me subjec t t o the r ule, su c h a s NSP S ). The

B oil e r MA C T a nd C I S W I R ules a c c ount fo r the m a jorit y of th e e sti mate d c ost i n the boiler

c a te g or y a nd a r e e x pe c te d to re quire si g nific a nt a ddit ional c ontrol cost for the f or e st produ c ts

indus tr y . The tot a l estim a ted a nnua l c ost of the b oil e r r e g ulations e x a mi ne d is $1.3 bil li o n . The

major it y of this cost i mpac t wil l be on the pulp an d pa pe r c a te g or y , p rimar i l y im pa c ti n g Kr a ft

mi ll s (it i s esti mate d that Kr a ft mi ll s will be a r a rou nd 70 pe rc e nt o f the pulp a nd pa pe r c a te g o r y ’s

c ost, b a se d on the a ll oc a t ion of boil e rs a t Kra ft mi ll s ver sus ot he r mill s). W e a nti c ipate that the

Kr a ft pulp m il ls woul d be a r the majo rit y of th e B oil e r MA C T c ost assi g n e d to t he pulp and pa pe r

c a te g or y a nd that non

- Kr a ft mi ll s would be a r the major it y of the B oil e r G ACT c ost assi g n e d to

fa c il it ies in t he pulp and pa pe r c a te g or y

.



### 3.1.2 Boi l er Reg ulat or

y C os t Sc en ar i o s Eva l u ated f or MAC T and CI SW I

URS a ssum e d that the he a lt h ba se d c ompl ianc e a lt e rna ti ve ( HB C A ) is no long e r a n opti on fo r

B oil e r MA C T . How e ve r , the f oll owing table sho ws potential sa ving s that c ould be r e a li z e d if

the H B C A is a n opti on u nde r B oil e r MA C T. N ot e that the a na l y sis did not diff e re nti a t e b y f

ue l,

so i f ma nga ne se is t he on l y meta l t ha t c a n be e x c l ude d fr om a T S M l im it usi ng H B C A, the n c o a l

a nd oil

- fir e d boil e rs w oul d not bene fit fr om H B C A a s much a s a wood

- fir e d boil e r w ould, and

the sa ving s would b e less f or the indust r y a s a who le.

P ot e n tial Cost

S avin gs w ith H B CA u n d e r B oil e r M A CT

P ulp a nd P a per Wo o d P ro du ct s

Ca pita l C o s t Annu a l C o s t Ca pita l C o s t Annu a l C o s t

Ass u m in g 5 0 % o f m ills co u ld co m p l y w it h

P M/m e tals a n d HC l u s i n g HB C A in s tead o f

ad d

- o n co n tr o ls : $ 830 m illi o n $ 156 m illi o n $ 226 m illi o n $ 30 m illi o n

Ass u m in g 9 0 % o f m ills co u ld co m p l y w it h

P M/m e tals a n d HC l u s i n g HB C A in s tead o f

ad d

- o n co n tr o ls : $1. 5 b illi o n $ 282 m illi o n $ 407 m il lio n $ 54 m illi o n

# SECTION 

# TH RE E Co st Me thod olo gy

3

- 5 URS e x a mi ne d two re g ul a tor y s c e n a rio s for B oil e r MACT a nd C I S W I . The Non

- Ha z a rdous

S e c onda r y Mat e ria ls (N HSM ) de finiti on ru le de t e rmine s whe the r boiler s a re r e g ulate d und e r

B oil e r MA C T or

C I S W I

. I f a

boil e r o r othe r c om bust ion uni t bu rns a sec onda r y mate ri a l t ha t i s

soli d wa ste, it will be r e gulate d unde r the C I S W I r ule. The c ur re nt B oil e r MACT databa se

c ontains uni ts t ha t burn some t y pe s o f se c ond a r y mate ria ls, and onl y a f e w f or e st produc ts boi ler s

a re in t he C I S W I

d a taba s e

. Eve n t hou g h EPA i s c ontemplating g uidanc e that indi c a tes ma n y

mate ria ls t ra dit ionall y bu rne d a s fu e ls ca n st il l be c lassifie d a s fu e ls, t he c u rr e nt rule la n g u a g e

ma y r e sult in m a n y m a ter ials be ing c l a ssi fie d a s so li d wa ste ( e

. g

., w a stew a t e r tr e a tm e nt

re siduals

, re c y c li n g proc e ss re siduals, TD F , r e sin a ted w ood

, c r e osot e tre a t e d wood/r a il ti e s ).

URS e va luate d the impac ts of ha ving thes e mate ri a ls consider e d sol id wa st e s and ha vin g 104

boil e rs bur ning thes e mat e ria ls i nstall c ontrols t o c ompl y with t he C I S W I r u le i nstea d of the

B oil e r MA C T. U nd e r this s c e na rio, w e e sti mate t ha t one thi rd of the 500 f or e st produc ts a re a

sourc e boil e rs a nd 85 wo od pr oduc ts fa c il it ies bur ning sand e rdust in dr y e rs would a lso have to

inst a ll c ontrols t o c ompl y with the C I S W I rule (the a ve ra ge pe r boiler c ontr ol c ost of the

104 a ddit ional boil e rs of

$7.8 mi ll ion i s used f

or the se e sti mate s)

.

Scenar i o B o i l e r M A C T C ISWI Ru l e T ot al C o st

C ont r o l C os t W hen Ma ny

N H SM ar e Wa s t e s no t Fue l s $ 3.7 B i l l i on $3. 3 B i l l i on $ 7 B i l l i on

C ont r o l C os t W hen Mos t

N H SM ar e F uel s no t Wa st e $4.3 B i l l i on $470 M i l l i on $4.8 B i l l i on



### I f f a c il it ies w e re to st op burning N HSM a nd re pla c e the f u e ls wi th natur a l g a s, op e ra ti n g c osts

would incr e a s e inst e a d of c a pit a l costs. B a se d on t he number of mil ls kno wn to bur n NH S M a nd

e sti mate d a mount s burne d (ba se d on 2005 NCAS I sur ve y a nd suppl ier e sti mate s), the a nnu a l cost

for f or e st produc ts i ndust r y boil e rs to st op bur ning wa stew a te r tr e a tm e nt re s iduals, re c y c li n g

pr oc e ss r e siduals, TDF

, r e sinate d wood, a nd c re os ote tr e a ted w ood/ ra il ti e s would be ove r

$650 mi ll ion.

M a t er ia l # M ills # B o ilers 2 0 0 5 Am o un t

( T o ns ) % o f T o t a l

B o iler F uel

Used Co s t t o la nd f ill a nd

re pla ce w it h na t ura l g a s 1

W aste w a ter T r ea tm en t

R esid u als 57 68 1

, 3 4 0

, 0 0 0 1

. 8 $ 1 5 9

, 0 0 0

, 0 0 0

T DF 21 29 4 0 1

, 5 0 0 1

. 2 $68

, 5 8 2

, 0 0 0

R ec y cl in g P r o ce s s R e s id u als 2 11 14 1 7 2

, 2 0 0 0

. 3 $ 2 4

, 2 0 0

, 0 0 0

R ail ties 3 12 5 5 0

, 0 0 0 0

. 1 0 $ 5 7

, 6 0 0

, 0 0 0

R esi n ated W o o d 100+ 2

, 5 0 0

, 0 0 0 7 3

. 5 $ 3 5 2

, 0 0 0

, 0 0 0

T o t a l $ 6 6 1

, 3 8 2

, 0 0 0

1 = T DF a n d R ailr o ad ties co s ts o n l y in cl u d e f u el r ep lace m e n t, n o t la n d f il lin g

2 = T h is is li k el y to b e an u n d er esti m ate. T h er e ar e m o r e t h an 1 0 0 m il ls t h at r ec y cle, b u t n o t a ll h a v e o n

- s ite b o iler s

3 = T h is r ep r esen ts a n esti m at e b y a m aj o r s u p p lier o f r ail ties u s ed b y t h e FP I in 2 0 1 1

# SECTION 

# TH RE E Co st Me thod olo gy

3

- 6 

### 3.1.3 W ood Pr o duc t s C atego r y

The de taile d c ost e sti mate s for the w ood p roduc ts c a te g or y a re p re se nt e d in Appe ndix B

. Note

that we ha ve not i nc lud e d e mi ssi ons c ontrols for lum be r kilns , a lt houg h w e ha ve a ssum e d that

ther e will be som e c ost t o im pleme nt t he e x pe c ted w or k pra c ti c e r e quire m e nts. W e ha ve

a ssum e d that the le ve l of c ontrol for c u rr e ntl y c ont rolle d wood pr oduc ts M ACT sourc e s will not

c ha n g e ( e

. g ., EPA wil l not incr e a se th e r e quir e d c ontrol ef fic ien c y f rom 90 pe rc e nt t o

95 pe rc e nt ) . W e ha ve a lso assum e d that ba c kup c ontrols wil l not be re quire d a s a r e sult of the

S S M va c a tur

.

Of the r e g ul a tor y a c ti ons e va luate d, the re visi ons t o the PC W P MACT wil l pose the most

sig nific a nt c ost bu rde n o n the w ood pr oduc ts i ndu str y (non

- boil e r sour c e s)

, a s add it ional sourc e s

a re e x pe c ted to re quire c ontr ol under the r e vis e d r ule. The tot a l estim a ted a nnua l c ost of the

potential wood pr oduc ts a ir r e g ulator y a c ti ons e x a mi ne d (e x c ludi ng boil e r r e g ul a ti ons) is

$ 230 mi ll ion.



### 3.1.4 Pulp an d P ap e r Ca t eg or y

The de tailed c ost e sti mate s for the pulp a nd p a pe r c a te g or y a re p re se nt e d in Appe ndix B

. Note

a ga in t ha t we h a ve a tt e m pted to a void doubl e c ou nti ng in t he c ost ana l y sis

, but one f a c il it y mi g ht

ha ve c ontrol costs unde r diff e re nt re g ulations

. U R S r e c e ived the f oll owin g infor m a ti on fr om

NCAS I r e g a rdin g the nu mber

of e x ist ing r e c ove r y fu rna c e s and li me kilns a t pul p a nd pa pe r

mi ll s:

5 3 D i r ec t c ont ac t ev apor a t or ( D C E) r ec ov er y f

u r na ce s

1 08 N on

- di r ec t co nt a ct ev apor a t or ( N D C E) r ec ov er y f u r na c es

14 0 Lim e k i l ns



### The hig h e st pot e nti a l cos t i mpac ts for the pulp a n d pa pe r indus tr y (non

- po we r boiler sour c e s) a re

fr om re g ulator y a c ti ons t ha t ar e not r e quire d to be im pleme nted: r e g ulating H 2 

### S a s a H AP,

including r e c ove r y f

ur n a c e s in C A I R

, a nd makin g si g nific a nt r e visi ons t o the pulp a nd pa pe r

MACT rule s (e

. g ., a ddin g r e g ulat e d c ompounds ).

The r e g ulation of H 2 

### S a s a HA P is ex pe c ted to c a u se sig nific a nt re g ulator y burde n a s it would

li ke l y r e qui re H 2 

### S e mi ssi on re duc ti ons fr om w a ste wa ter tr e a tm e nt s y stems . This c ould re quire

c onve rsion of

s y stems wi th ae ra ted st a bil iz a ti on b a sins to ac ti va ted sludge s y stems at a c a pit a l

c ost of a pprox im a tel y $3 5 mi ll ion for e a c h of 6 7 mi ll s. B a se d on the items i n a S ier ra C lub

pe ti ti on to add r e g ul a ted c ompounds to t he pulp and pa pe r MA C T stand a r ds, we ha ve e sti mate d

c ontrol sce na rios a nd c on trol c osts that a mount to over $1 bil li on pe r y e a r f

or the pulp a nd pa pe r

indus tr y . The tot a l estim a ted a nnua l c ost of the p otential pulp and pa pe r a ir r e g ulator y a c ti ons

e x a mi ne d is $ 1.9 bil li on.



### 3.1.5 Col l at e r al Emi ss i o ns o r Ene r gy I nc r e as e s f o r Co nt r ols

Th e de tailed c ost e sti mate s in Appe ndix B a lso pr e se nt i nf or mation on whe ther

a c oll a te ra l

e mi ssi ons or e ne r g y incr e a se c a n be e x pe c ted w it h im pleme ntation of a c o ntrol t e c hnolog y

.

# SECTION 

# TH RE E Co st Me thod olo gy

3

- 7 W he re a c ontrol i s ex pe c t e d to s ig nific a ntl y inc re a se e lec tri c it y or fue l co ns umpt ion, or will

c onve rt CO to C O 2 

### ( e

. g

., a c a tal y st inst a ll e d on a b oil e r ), w e h a ve e sti mate d the CO 2 

### e mi ssi ons

incr e a s e in m e tric tons pe r y e a r. T h e notes c olum n in t he de tailed c ost esti mate s included in

Appe ndix B pr ovides the a ssum pti ons used to e s ti mate C O 2 

### . CO 2 

### e mi ss ion s fr om combust ion of

a ddit ional biom a ss ar e n ot esti mate d, a s these e m iss ions ar e c onsi de r e d c a rbon ne utra l.

I n c re a se d e l e c tricit y a nd fue l consumpt ion due to im pleme ntation of c e rta in c ontrol st ra te g ies

will a lso l e a d to hi g he r N O

x 

### e mi ssi ons, which wou ld not be f a vora bl e in an oz one non

- a tt a inm e nt

a re a

. An impac t of r e duc ing C O a nd TH C e mi ssi ons t hr oug h c ombus ti on c ontrols and f ue l

switching ma y be in c re a s e s in NO

x 

### e mi ssi ons, but the impac t would be de p e nde nt on t he

ope ra ti n g c on dit ions at e a c h boil e r be for e a nd a fte r the c ha n ge

.



## 3 .2 PO T EN T IA L RE G ULA T O RY COS T S N O T CA PT UR ED I N T H IS AN A L YSI S

The f or e st pro duc ts i ndust r y f

a c e s ot he r non

- C le a n Air A c t re g ul a tor y c osts unde r the C lea n

W a ter Ac t and the R e sou rc e C onser v a ti on a nd Re c ove r y A c t. The r e a r e a l so si g nific a nt costs

e x pe c ted to be incur

r e d b y a n y futur e G HG r e g ula tor y sch e me. F or e x a mpl e , e lec tri c it y ma y

be c ome ve r y e x pe nsive f

or f a c il it ies tha t bu y pow e r f

rom c o a l

- fir e d powe r plants a nd fa c il it ies

that ope ra te c oa l

- fir e d bo il e rs ma y b e f inan c iall y i mpac ted if

a c a rbon tax o r c a p a nd t ra de

pr ogra m i s ena c ted. R e n e wa ble e ne r g y le g isl a ti on is also ex pe c ted to si g nif ica ntl y inc re a s e the

c ost of biom a ss, t he f

or e s t produc ts i ndust r y ’s ra w mate ria l. This ana l y sis o nl y c a pture d c osts

t ha t wil l pot e nti a ll y

b e incur re d a s a r e sult of no n

- GH G a ir r e g ulator y a c ti ons c urre ntl y be in g

c onsi de re d b y EPA. W e we re a lso un a ble to pr e di c t t he im pa c t of the Ele c tric U ti li t y MACT on

fue l and ope ra ti n g c osts ( e .g ., in c re a se d e l e c tricit y c ost du e to i nc re a se d uti li t y c ontrol costs or

incr e a s e d na tura l ga s cos t due to incr e a s e in Uti li t y c onv e rsions of c o a l

- fir e d unit s to n a tura l gas

a nd de c r e a s e in i ndust ria l ava il a bil it y ).

Note that or ig in a ll y , w e ha d de ve loped c ost esti mate s for the impa c t of EPA r ol li ng ba c k NSR

re for m ( e

. g ., re v e rtin g to the “ a c tu a l t o potential ” P S D a ppli c a bil it y t e st i nstea d of the “ b a se li ne

a c tual to proje c t e d a c tu a l ” a ppli c a bil it y test ). Ho we ve r, re c e nt i nf or matio n indi c a tes tha t EP A

doe s not int e nd to g o for wa rd w it h thi s ac ti on. W e orig in a ll y e sti mate d a c a pit a l cost for

indus trial boil e rs of

$308 mi ll ion due to a

lar g e nu mber

of pr oje c ts t rigge ri ng P S D r e vie w tha t

would not have unde r the NSR r e for m rule, w it h a n e sti mate d a nnua l cost o f $38 .8 mi ll ion. The

e sti mate d c osts f

or pulp a nd pa pe r mill s we re a ppr ox im a tel y $115 mi ll ion i n c a pit a l and

$28 mi ll ion i n a nnua l costs, and f or wood pr odu c ts fa c il it ies w e r e $101 mi ll ion i n c a pit a l and

$16 mi ll ion i n a nnua l costs.

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

MachinesTable 2-2. Forest Products Industry Regulatory Cost TimelineYear -->20102011201220132014201520162017201820192020Rule$370,000,000$925,000,000$2,405,000,000$290,000,000 $290,000,000 $290,000,000 $290,000,000 $290,000,000 $290,000,000$700,000,000 $700,000,000 $700,000,000 $700,000,000 $700,000,000 $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 $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 $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 $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 $1,160,000,000 $1,160,000,000 $1,160,000,000$62,000,000 $62,000,000$7,000,000 $7,000,000 $7,000,000 $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 $21,000,000 $21,000,000 $21,000,000$620,500,000$142,000,000 $142,000,000 $142,000,000 $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 $211,000,000 $211,000,000 $211,000,000$140,000,000$28,000,000 $28,000,000 $28,000,000 $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 $43,000,000 $43,000,000 $43,000,000CPMS Rule$60,000,000 $120,000,000 $120,000,000 $120,000,000 $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 $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 $80,000,000 $80,000,000 $80,000,000$5,160,347 $18,061,216 $46,443,126 $130,000,000 $130,000,000 $130,000,000 $130,000,000 $130,000,000$318,000,000$42,000,000 $42,000,000 $42,000,000 $42,000,000 $42,000,000 $42,000,000$34,914,691 $77,000,000 $77,000,000 $77,000,000 $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 $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 $14,000,000 $14,000,000 $14,000,000$780,000,000$360,000,000 $360,000,000 $360,000,000 $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 $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 $300,000,000 $300,000,000 $300,000,000$36,232,226 $710,000,000 $710,000,000 $710,000,000 $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 $83,000,000 $83,000,000 $83,000,000$8,000,000 $16,000,000 $24,000,000 $32,000,000 $40,000,000 $48,000,000 $56,000,000$9,112,954 $18,000,000 $36,000,000 $54,000,000 $72,000,000 $90,000,000 $108,000,000 $126,000,000$270,000,000$675,000,000$1,755,000,000$180,000,000 $180,000,000 $180,000,000 $180,000,000$470,000,000 $470,000,000 $470,000,000 $470,000,000 $470,000,000$78,000,000 $195,000,000$507,000,000$100,000,000 $100,000,000 $100,000,000 $100,000,000 $100,000,000$8,563,981 $29,973,933 $180,000,000 $180,000,000 $180,000,000 $180,000,000 $180,000,000$28,000,000 $28,000,000 $28,000,000 $28,000,000 $28,000,000 $28,000,000$4,000,000 $8,000,000 $12,000,000 $16,000,000 $20,000,000$3,074,249 $7,000,000 $14,000,000 $21,000,000 $28,000,000 $35,000,000$92,000,000$10,101,105Initial 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 $1,870,000,000 $110,000,000 $200,000,000Annual 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 $2,500,000,000 $2,500,000,000 $2,500,000,000Total 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$4,400,000,000$4,400,000,000$4,500,000,000= Expected Final Rule TimingCapital 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 IIrevisions/RTR(assume variable applicabilitytiming per proposed rule)CISWICAIR for industrial boilers/recovery boilersPM2.5 NAAQS fullyimplementedSSM goes away underMACTRegional HazeNSPS Subpart BB updateH2S listed as HAPOzone NAAQS loweredWood Products NSPSP&P MACT Irevisions/RTRSO2 NAAQS loweredNOx NAAQS loweredPCWP MACTrevisions/RTR

## Appendix A

Cost Estimate SummariesCombined 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 A nnual Capital A nnual

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 MACTCosts of Clean Air Rules for the Forest Products IndustryUpdated 8/17/2011Organized by Rule:RuleIndustrial Boilers- Initial CostIndustrial Boilers- Initial AnnualOperating CostIndustrial Boilers -Total Annual CostWood ProductsSources - InitialCostWood ProductsSources - InitialAnnualOperating CostWoodProductsSources - TotalAnnual CostPulp and PaperMills - Initial CostPulp and PaperMills - InitialAnnual OperatingCostPulp and PaperMills - TotalAnnual CostIndustry Wide -Initial CostIndustry Wide -Initial AnnualOperating CostIndustry Wide -Total AnnualCostBoiler MACT $3,700,000,000 $290,000,000 $700,000,000$3,700,000,000 $290,000,000 $700,000,000Boiler GACT$10,000,000 $9,000,000 $9,000,000$10,000,000 $9,000,000 $9,000,000CISWI$3,250,000,000 $805,000,000 $1,160,000,000$3,250,000,000 $805,000,000 $1,160,000,000CAIR for industrial boilers/recovery boilers$0 $0 $0 $470,000,000 $77,000,000 $130,000,000 $470,000,000 $80,000,000 $130,000,000Ozone NAAQS lowered$0 $0 $0 $32,000,000 $5,000,000 $8,500,000 $92,000,000 $1,500,000 $12,000,000 $124,000,000 $7,000,000 $21,000,000NOx NAAQS lowered$607,000,000 $141,900,000 $209,000,000 $2,500,000 $0 $300,000 $11,000,000 $0 $1,500,000 $620,500,000 $142,000,000 $211,000,000SO2 NAAQS lowered$100,000,000 $20,000,000 $31,000,000 $40,000,000 $7,500,000 $12,000,000 $140,000,000 $28,000,000 $43,000,000CPMS Rule $0 $69,000,000 $69,000,000 $0 $35,000,000 $35,000,000 $0 $12,000,000 $12,000,000 $0 $120,000,000 $120,000,000PM2.5 NAAQS fullyimplemented$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 $318,000,000 $42,000,000 $77,000,000Regional Haze$60,000,000 $7,500,000 $14,000,000 $32,000,000 $3,600,000 $7,100,000 $92,000,000 $11,000,000 $21,000,000PCWP MACT revisions/RTR$780,000,000 $95,000,000 $180,000,000 $780,000,000 $100,000,000 $180,000,000SSM goes away underMACT$0 $0 $0 $100,000,000 $3,000,000 $14,000,000 $100,000,000 $3,000,000 $14,000,000Wood Products NSPS$28,000,000 $4,000,000 $7,000,000 $28,000,000 $4,000,000 $7,000,000P&P MACT I revisions/RTR$780,000,000 $360,000,000 $450,000,000 $780,000,000 $360,000,000 $450,000,000P&P MACT II revisions/RTR$3,300,000,000 $300,000,000 $710,000,000 $3,300,000,000 $300,000,000 $710,000,000NSPS Subpart BB update$83,000,000 $8,000,000 $18,000,000 $83,000,000 $8,000,000 $18,000,000H2S listed as HAP$2,700,000,000 $180,000,000 $470,000,000 $2,700,000,000 $180,000,000 $470,000,000Total 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 $16,500,000,000 $2,500,000,000 $4,300,000,000Cost by Sector With Boiler Rule Costs Allocated to Wood Products and Pulp and Paper by RuleRuleWood ProductsInitial CostWood ProductsInitial AnnualOperating CostWood ProductsTotal Annual CostPulp and PaperInitial CostPulp and PaperInitial AnnualOperating CostPulp andPaper TotalAnnual CostBoiler 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 $130,000,000Ozone 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 $46,000,000PM2.5 NAAQS fullyimplemented$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$0SSM goes away underMACT$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$0P&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 $18,000,000H2S 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 $3,000,000,000Note that the initial capital cost and the initial annual operating cost represent the cost for the initial number of units/facilities subject to the rule. For some rules, the number of units subject will increase over time (e.g., NSPS). For costs over time, see the timeline table.ListofPossibleControlsforMillsControlTechnologyUnitCosts($M)1. Scrubber(acidgases,H2SandSO2)$4to82. ESPsorESPupgrade(metalsandPM)$3to$53. Carboninjection(mercury)$14. Oxidationcatalysts(CO)$1‐25. SNCRorSCR(NOx)$4to$86. LowNOxburnerorcombustioncontrols $0.5to$17. Steamstripper/incinerator(VOCs/organicHAPs) $28. FabricFilter(mercury/metals/PM)$79. Fuelswitching(numerouspollutants)$1‐210. Ductingsourcestoexistingcontrols(HAPs)$211. Redesignedwastewatertreatment(H2S)$3512. RedesignRecoveryFurnaces(organicHAPs) $20TOTALCOSTPERMILL* $25Mto$100+M*dependsonexistingcontrols,typeofmill/equipmentandnumberofunitsaffectedSummary of Benefits and Disbenefits of Various Control Strategies

Control Strateg y 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 Regula tory ActionCosts of Clean Air Rules for the Forest Products IndustryRule/TimingPollutantControlInitial Investmentper UnitNumber of UnitsUpgraded/Additional UnitsAffected% ProbabilityTotal Cost (initialinvestment)AnnualizedCapital Cost perUnitTotal AnnualizedCapital CostTypical AnnualOperating Costper UnitTotal AnnualizedOperating CostTotal AnnualizedCostCost PerFacilityCollateralEmissions/EnergyIncreasesEstimatedCO2increases,metric tonsNotesCost NotesBoiler MACTHCl 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$ waterBased on Boiler MACT database, boilersburning "traditional fuels."2003 NERA studyscrubber cost for capitalcost; combination of NERAstudy and URS BACTestimates for operatingcost.HCl Scrubber (wood) -$ 0 -$ -$ -$ 1,000,000$ -$ -$ #DIV/0! waterBased on Boiler MACT database, boilersburning "traditional fuels."2003 NERA studyscrubber cost for capitalcost; URS BACT estimatesfor operating cost.HCl Scrubber (gas2) -$ 0 -$ -$ -$ -$ -$ -$ -$ water Based on Boiler MACT database.2003 NERA studyscrubber cost for capitalcost; URS BACT estimatesfor operating cost.HClScrubber (oil) 6,896,710$54372,422,340$757,222$40,889,971$1,000,000$54,000,000$94,889,971$3,514,443$waterBased on Boiler MACT database, boilersburning "traditional fuels."2003 NERA studyscrubber cost for capitalcost; URS BACT estimatesfor operating cost.PM/metalsUpgrade existingcontrols or addFF (wood)4,441,848$215954,997,320$487,691$104,853,572$77,000$16,555,000$121,408,572$1,129,382$Based on Boiler MACT database, boilersburning "traditional fuels."Combination of URSengineering estimate andNERA study info for capitalcost, NERA study foroperating cost.PM/metalsUpgrade existingcontrols or addFF (coal)5,601,456$45252,065,520$615,010$27,675,439$194,000$8,730,000$36,405,439$1,618,020$Based on Boiler MACT database, boilersburning "traditional fuels."Combination of URSengineering estimate andNERA study info for capitalcost, NERA study foroperating cost.PM/metalsUpgrade existingcontrols or addFF (oil)5,994,297$59353,663,523$658,142$38,830,354$300,000$17,700,000$56,530,354$1,916,283$Based on Boiler MACT database, boilersburning "traditional fuels."Combination of URSengineering estimate andNERA study info for capitalcost, NERA study foroperating cost.PM/metals Add FF (gas2)-$0-$-$-$-$-$-$-$Based on Boiler MACT database.Combination of URSengineering estimate andNERA study info for capitalcost, NERA study foroperating cost.Mercury/dioxinCarbon injection(coal)1,000,000$9898,000,000$109,795$10,759,873$420,000$41,160,000$51,919,873$1,059,589$Based on Boiler MACT database, boilersburning "traditional fuels." Assumesparticulate control device already in placefollowing carbon injection site.URS engineering estimateconfirmed by vendorMercury/dioxinCarbon injection(wood)1,000,000$253253,000,000$109,795$27,778,040$211,000$53,383,000$81,161,040$641,589$Based on Boiler MACT database, boilersburning "traditional fuels." Assumesparticulate control device already in placefollowing carbon injection site.URS engineering estimateconfirmed by vendorMercury/dioxinCarbon injection(gas2)-$0-$-$-$-$-$-$-$Based on Boiler MACT database.URS engineering estimateconfirmed by vendorMercury/dioxinCarbon injection(oil)1,000,000$5555,000,000$109,795$6,038,704$28,000$1,540,000$7,578,704$275,589$Based on Boiler MACT database, boilersburning "traditional fuels." Assumesparticulate control device already in placefollowing carbon injection site.URS engineering estimateconfirmed by vendorCOCO catalyst orcombustionimprovements(coal)3,008,120$45135,365,400$330,275$14,862,393$-$-$ 14,862,393$660,551$CO2Based on Boiler MACT database, boilersburning "traditional fuels."vendor quoted 0.5 to$1MM just for catalyst, est.$1MM to installCOCO catalyst orcombustionimprovements(wood)2,341,248$214501,026,978$257,056$55,010,069$-$-$ 55,010,069$514,113$CO2Based on Boiler MACT database, boilersburning "traditional fuels."vendor quoted 0.5 to$1MM just for catalyst, est.$1MM to installCOCO Catalyst -Gas2 (landfillgas)-$0-$-$-$-$-$-$-$ CO2vendor quoted 0.5 to$1MM just for catalyst, est.$1MM to installCOCO catalyst orcombustionimprovements(oil)2,616,873$57149,161,761$287,319$16,377,160$-$-$ 16,377,160$574,637$CO2 4,782Based on Boiler MACT database, boilersburning "traditional fuels." CO2 emissionsassume avg 250 MMBtu/hr, 8700 hr/yr,AP-42 CO oil/gas avg 0.06 lb/MMBtu, 90percent conversion of CO to CO2.vendor quoted 0.5 to$1MM just for catalyst, est.$1MM to installAllEnergy audit75,000$44233,150,000$75,000$33,150,000$3,709,002,662$436,738,863$290,568,000$694,156,863$note - cost per facility assumes 2 boilers per facilityIndustrial Boilers at Forest Products FacilitiesExpected timing: reproposal Oct 2011,final Apr 2012Costs of Clean Air Rules for the Forest Products IndustryRule/TimingPollutantControlInitial Investmentper UnitNumber of UnitsUpgraded/Additional UnitsAffected% ProbabilityTotal Cost (initialinvestment)AnnualizedCapital Cost perUnitTotal AnnualizedCapital CostTypical AnnualOperating Costper UnitTotal AnnualizedOperating CostTotal AnnualizedCostCost PerFacilityCollateralEmissions/EnergyIncreasesEstimatedCO2increases,metric tonsNotesCost NotesIndustrial Boilers at Forest Products FacilitiesBoiler GACTPM/metals Fabric Filter 500,000$ 0 -$ -$ -$ -$ -$ -$ -$No PM limits for wood or oil in proposedrule. Only 2 coal boilers at area sourcesknown.EPA GACT costspreadsheets, median typecostMercuryCarbon injectionfollowing FF 1,000,000$ 0 -$ -$ -$ -$ -$ -$ -$No Hg limits for wood or oil in proposedrule. Only 2 coal boilers at area sourcesknown.URS engineering estimatefor capital cost; assumehalf of MACT operatingcostCO/POM Tune-up 2,219$ 1200 2,662,800$ -$ 2,219$ 2,662,800$ 2,662,800$ 4,438$ Assumes all units need tuneup. EPA cost estimateCO/POM Energy audit5,000$12006,000,000$-$5,000$6,000,000$6,000,000$10,000$Assumes needed by all units and utilitieswill no longer be able to offer for free;assumes required annually.URS engineering estimatefor simple auditCO/POMCombustioncontrols (wood) 500,000$0-$-$-$-$-$-$-$may increaseNOxNo controls because final rule had no COlimits for existing biomass boilersURS engineeringestimate/client costsCO/POM LBMS20,000$0-$-$-$-$-$-$-$No controls because final rule had no COlimits for existing biomass boilers EPA cost estimate-$8,662,800$-$8,662,800$8,662,800$note - cost per facility assumes 2 boilers per facilityCISWISO2/acid gas Scrubber12,414,444$39484,163,333$1,363,039$53,158,531$1,500,000$58,500,000$111,658,531$2,863,039$water2003 NERA studyscrubber cost for capitalcost; combination of NERAstudy and URS BACTestimates for operatingcost.PM/metals/dioxin Fabric Filter6,701,895$74495,940,248$735,832$54,451,573$194,000$14,356,000$68,807,573$929,832$Combination of URSengineering estimate andNERA study info.Mercury Carbon injection 1,000,000$112112,000,000$109,795$12,296,998$420,000$47,040,000$59,336,998$529,795$Vendor for capital cost andassumed coal boileroperating costNOx SNCR2,610,540$50130,527,013$286,623$14,331,164$1,200,000$60,000,000$74,331,164$-$URS engineering estimate;annual cost is primarilyreagent costNOx SCR8,000,000$0-$-$-$-$-$-$-$ ammoniaPublished cost estimatesrange from $4MM to$12MM; operating costfrom NERACOCO catalyst3,445,537$2379,247,343$378,301$8,700,932$-$-$8,700,932$378,301$CO2 19,295vendor quoted 0.5 to$1MM just for catalyst, est.$1MM to installArea sourceboiler controls7,800,000$1651,287,000,000$856,398$141,305,682$2,500,000$412,500,000$553,805,682$3,356,398$CO2assumes 1/3 of area source boilers burnsecondary materialsbased on average forestproducts boiler CISWIcontrol costSanderdustdryers controls7,800,000$85663,000,000$856,398$72,793,836$2,500,000$212,500,000$285,293,836$3,356,398$CO2assumes 85 facilities have dryers burningresinated woodbased on average forestproducts boiler CISWIcontrol cost-$-$-$-$3,251,877,937$357,038,718$804,896,000$1,161,934,718$note - cost per facility assumes 1 boiler per facilityNOx NAAQSNOxCombustioncontrols500,000$8542,500,000$54,897$4,666,272$-$-$4,666,272$54,897$Assumes liquid/gas-fired boilers in orclose to NAA will need burner retrofits.URS engineeringestimate/client costsNew 1-hour standardNOx SNCR4,000,000$115460,000,000$439,178$50,505,527$1,200,000$138,000,000$188,505,527$1,639,178$Assumes facilities with solid fuel boilersthat are projected to be in NAA will needan SCR.URS engineering estimatefor capital cost; NERA foroperating costFinal Jan 2010,designations 2012,implementation 2013NOx SCR8,000,000$13104,000,000$878,357$11,418,641$301,000$3,913,000$15,331,641$1,179,357$ammoniaAssumes facilities with solid fuel boilersthat are close to projected NAA will needSNCRPublished cost estimatesrange from $4MM to$12MM; operating costfrom NERA606,500,000$66,590,440$141,913,000$208,503,440$note - cost per facility assumes 1 boiler per facilityOzone NAAQSNOxCombustioncontrols500,000$-$-$-$-$-$-$-$URS engineeringestimate/client costsNOx SNCR4,000,000$-$-$-$-$-$-$-$URS engineering estimatefor capital cost; NERA foroperating costNOx SCR8,000,000$-$-$-$-$-$-$-$ ammoniaPublished cost estimatesrange from $4MM to$12MM; operating costfrom NERAMore NA AreasNOx/VOCMore complexpermitting/permitting formore sources40,000$803,200,000$4,392$351,343$-$351,343$4,392$The permitting process will become morecomplex for facilities in NAA. If NAAbecome Serious, more facilities will beTitle V (50 tpy).3,200,000$351,343$-$351,343$note - cost per facility assumes 1 boiler per facilityAddressed under BMACT and NOxNAAQSAssumes boilers burning secondarymaterials such as sludge, paper recyclingresiduals, TDF, crossties, are regulatedunder CISWI, not Boiler MACTExpected timing: reproposal Oct 2011,final Apr 2012Timing: Final RuleMarch 2011August2011 forpossible new lowerstandard,designations 2012,implementation 2014Costs of Clean Air Rules for the Forest Products IndustryRule/TimingPollutantControlInitial Investmentper UnitNumber of UnitsUpgraded/Additional UnitsAffected% ProbabilityTotal Cost (initialinvestment)AnnualizedCapital Cost perUnitTotal AnnualizedCapital CostTypical AnnualOperating Costper UnitTotal AnnualizedOperating CostTotal AnnualizedCostCost PerFacilityCollateralEmissions/EnergyIncreasesEstimatedCO2increases,metric tonsNotesCost NotesIndustrial Boilers at Forest Products FacilitiesSO2 NAAQSSO2 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$ waterRemaining coal fired boilers not projectedto need scrubbers under Boiler MACT.2003 NERA studyscrubber cost for capitalcost; combination of NERAstudy and URS BACTestimates for operatingcost.New 1-hour standardfinal 2010,designations 2012,implementation 2013SO2Low sulfur fuel/fuel switch 0 -$ -$ -$ -$ -$ -$Any boiler burning higher sulfur fuels willlikely have been captured inBMACT/CISWI.A switch in fuel type mayrequire capital to modifyboiler or controls, butdepending on fuel costs atthe time, could result insavings.104,000,000$ 11,418,641$ 19,500,000$ 30,918,641$CAIR/CSAPR forindustrial boilersSO2 Wet Scrubber 8,000,000$ 0 -$ -$ -$ -$ -$ -$ -$ waterCovered above2003 NERA studyscrubber cost for capitalcost; combination of NERAstudy and URS BACTestimates for operatingcost.PMESP5,000,000$0-$-$-$-$-$-$-$ electricity 0 Covered above2003 NERA study capitaland operating cost for newESPNOxcombustioncontrols500,000$0-$-$-$-$-$-$-$Covered aboveURS engineeringestimate/client costsNOx SNCR4,000,000$0-$-$-$-$-$-$-$Covered aboveURS engineering estimatefor capital cost; NERA foroperating costNOx SCR8,000,000$0-$-$-$-$-$-$-$ ammoniaCovered abovePublished cost estimatesrange from $4MM to$12MM; operating costfrom NERA-$-$-$-$note - cost per facility assumes 2 boilers per facilityContinuousParametricMonitoring SystemRuleShutdown to QA600-$-$-$100,000$60,000,000$60,000,000$100,000$Shutdown 4 times/yr at $25k per (haveput cost for 300 wood products mills and100 kraft mills on the other tab - thesewould be 600 more boiler MACT facilities)Industry comments onproposed rule; we have notincluded capital costs forredundant sensors.in new MACT rulesEffort required tocomply600-$-$-$15,000$9,000,000$9,000,000$15,000$One facility's estimate of additionalmanpower requiredIndustry comments onproposed rule-$-$69,000,000$69,000,000$PM2.5 NAAQS fullyimplementedPM2.5 ESP/FF upgrade 3,000,000$515,000,000$329,384$1,646,919$65,000$325,000$1,971,919$394,384$1,690Assumes only a few boilers did notachieve low enough PM emissions underMACT or CISWI and need further controlto meet PM2.5 NAAQS. CO2 increasecalculated using 500 MWh electricityincrease/yr/unit*DOE US avg 0.676 MTCO2/MWh.2003 NERA studyPM2.5 WESP10,000,000$10100,000,000$1,097,946$10,979,462$1,800,000$18,000,000$28,979,462$2,897,946$waterAfew boilers may need WESP for H2SO4or other condensible control. URS 2008 cost estimateNOx 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$Assumes units have projects where theycan't model compliance with PM2.5NAAQS and have to install NOx controlsto reduce nitrate formation.URS engineering estimatefor capital cost; NERA foroperating cost2011NOx SCR 8,000,000$ 5 40,000,000$ 878,357$ 4,391,785$ 301,000$ 1,505,000$ 5,896,785$ 1,179,357$ ammoniaAssumes units have projects where theycan't model compliance with PM2.5NAAQS and have to install NOx controlsto reduce nitrate formation.Published cost estimatesrange from $4MM to$12MM; operating costfrom NERANOxCombustioncontrols500,000$52,500,000$54,897$274,487$-$-$274,487$54,897$Assumes units have projects where theycan't model compliance with PM2.5NAAQS and have to install NOx controlsto reduce nitrate formation.URS engineeringestimate/client costsSO2 Scrubber8,000,000$0-$878,357$-$ 1,500,000$-$-$waterAny boiler burning higher sulfur fuels willlikely have been captured in the regsabove.2003 NERA studyscrubber cost for capitalcost; combination of NERAstudy and URS BACTestimates for operatingcost.SO2 Low sulfur fuel0-$-$-$-$-$Any boiler burning higher sulfur fuels willlikely have been captured in the regsabove.A switch in fuel type mayrequire capital to modifyboiler or controls, butdepending on fuel costs atthe time, could result insavings.177,500,000$19,488,546$25,830,000$45,318,546$note - cost per facility assumes 1 boiler per facilityEPA working on CAIRreplacement 3 -proposal and final2012, implement 2015Costs of Clean Air Rules for the Forest Products IndustryRule/TimingPollutantControlInitial Investmentper UnitNumber of UnitsUpgraded/Additional UnitsAffected% ProbabilityTotal Cost (initialinvestment)AnnualizedCapital Cost perUnitTotal AnnualizedCapital CostTypical AnnualOperating Costper UnitTotal AnnualizedOperating CostTotal AnnualizedCostCost PerFacilityCollateralEmissions/EnergyIncreasesEstimatedCO2increases,metric tonsNotesCost NotesIndustrial Boilers at Forest Products FacilitiesRegional HazeSO2 Scrubber 8,000,000$ 0 -$ 878,357$ -$ 1,500,000$ -$ -$ waterAny boiler burning higher sulfur fuels willlikely have been captured in the regsabove.2003 NERA studyscrubber cost for capitalcost; combination of NERAstudy and URS BACTestimates for operatingcost.SO2 Low sulfur fuel 0 -$ -$ -$ -$ -$Any boiler burning higher sulfur fuels willlikely have been captured in the regsabove.A switch in fuel type mayrequire capital to modifyboiler or controls, butdepending on fuel costs atthe time, could result insavings.PM ESP 5,000,000$ 0 -$ 548,973$ -$ 77,000$ -$ -$ electricity 0Probably adequate PM reductions in rulesabove2003 NERA study ESPcostNOx 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 small number of boilers thatdidn't get caught in regulation above nowhave to install controls for regional hazereductionsURS engineering estimatefor capital cost; NERA foroperating costNOx SCR8,000,000$540,000,000$878,357$4,391,785$301,000$1,505,000$5,896,785$1,179,357$ammoniaAssumes small number of boilers thatdidn't get caught in regulation above nowhave to install controls for regional hazereductionsPublished cost estimatesrange from $4MM to$12MM; operating costfrom NERA60,000,000$6,587,677$7,505,000$14,092,677$note - cost per facility assumes 1 boiler per facilityTotal Regulatory Cost7,920,743,399$898,214,228$1,367,874,800$2,232,939,028$25,767700sawmillsCapital Recovery Factor Calcuation for Annualized Costs:300convertingInterest Equipment300wood productsRateLife, yrsCRF400pulp and paper 12 semi chem, 20 newsprint100of which are kraft7.00% 15 0.110Cost per facility for MACT, GACT, CAIR assumes 2 boilers per facilityBART -additionalcontrol to meetmilestones following2018Costs of Clean Air Rules for the Forest Products IndustryRule/TimingPollutantControlInitial Investmentper UnitNumber of UnitsUpgraded/Additional UnitsAffected% ProbabilityTotal Cost (initialinvestment)AnnualizedCapital Cost perUnitTotalAnnualizedCapital CostTypical AnnualOperating Costper UnitTotalAnnualizedOperating CostTotalAnnualizedCostCost PerFacilityCollateralEmissions/EnergyIncreasesEstimatedCO2increases,metric tonsNotesCost NotesOzone NAAQSNOxLNB - direct firedunits 500,000$ 10 5,000,000$ 54,897$ 548,973$ -$ -$ 548,973$ 54,897$Assumes units have projects where theyneed NOx reductions in ozone NAA andhave to install controls on a direct fired unit.Based on info fromvarious industryprojects-$ -$ -$ -$ -$VOC Oxidizer 5,000,000$ 5 25,000,000$ 548,973$ 2,744,866$ 1,000,000$ 5,000,000$ 7,744,866$ 1,548,973$ energy, NOx 9,225Assumes a new catalytic oxidizer will haveto be installed to control additional sourcesat 5 plants in ozone NA areas. CO2increase calculated using 4 MMBtu/hrnatural gas*8700 hr/yr*53.02 kgCO2/MMBtu (EPA GHG rule EF).2008 facility cost fornew RCO; operatingcost assumes$10/scfm x 100kscfm(EPA fact sheet says$6-20/scfm)More NA AreasNOx/VOCMore complexpermitting/permitting for moresources40,000$502,000,000$4,392$219,589$-$-$ 219,589$4,392$The permitting process will become morecomplex for facilities in NAA. If NAAbecome Serious, more facilities will be TitleV (50 tpy).Conservativeestimate of whatpermitting and LAERmight cost (e.g.,equipment upgrades)32,000,000$3,513,428$5,000,000$8,513,428$NOx NAAQSNOxLNB - direct firedunits500,000$52,500,000$54,897$274,487$-$-$ 274,487$54,897$Assumes units have projects where theycan't model compliance with lower NOxNAAQS and have to install better burnerson a direct fired unit.Based on info fromvarious industryprojectsNew 1-hour standardFinal Jan 2010,designations 2012,impl. 2013-$-$-$2,500,000$274,487$-$ 274,487$ContinuousParametricMonitoring SystemRuleShutdown to QA300-$-$-$100,000$30,000,000$30,000,000$100,000$Shutdown 4 times/yr at $25k perIndustry commentson proposed ruleAs part of MACT/NSPS revsEffort required tocomply300-$-$-$15,000$4,500,000$4,500,000$15,000$One facility's estimate of additionalmanpower requiredIndustry commentson proposed rule-$-$34,500,000$34,500,000$PM2.5 NAAQS fullyimplementedPM2.5 ESP upgrade3,000,000$515,000,000$329,384$1,646,919$65,000$325,000$1,971,919$394,384$electricity 338Assumes units have projects where theycan't model compliance with PM2.5 NAAQSand have to upgrade an ESP or WESP tocomply. CO2 increase calculated using 100MWh additional electricity/yr/unit*DOE USavg 0.676 MT CO2/MWh.NERA studyOctober 2011NOxLNB - direct firedunits500,000$52,500,000$54,897$274,487$-$-$ 274,487$54,897$Assumes units have projects where theycan't model compliance with PM2.5 NAAQSand have to install NOx controls on a directfired unit to improve combustion.Based on info fromvarious industryprojects17,500,000$1,921,406$325,000$2,246,406$PCWP MACT redoand remandVOHAP Catalytic Oxidizer 5,000,000$85425,000,000$548,973$46,662,715$1,000,000$85,000,000$131,662,715$ 1,548,973$energy, NOx 156,833Assumes a new catalytic oxidizer will haveto be installed to control additional sources,1 for half of existing major wood productsfacilities. CO2 increase calculated using 4MMBtu/hr natural gas*8700 hr/yr*53.02 kgCO2/MMBtu (EPA GHG rule EF).2008 facility cost fornew RCO; operatingcost assumes$10/scfm x 100kscfm(EPA fact sheet says$6-20/scfm)minimal residual riskcostsVOHAP Biofilter3,000,000$85255,000,000$329,384$27,997,629$100,000$8,500,000$36,497,629$429,384$Assumes a new biofilter will have to beinstalled to control additional sources, 1 forhalf of existing major wood productsfacilities2008 facility cost fornew press biofilter;vendor estimate ofoperating cost$1/acfm and100,000 acfmassumedICR 2011, rule late2013VOHAP Enclosure500,000$17085,000,000$54,897$9,332,543$5,000$850,000$10,182,543$59,897$Assumes enclosures will be needed onsources not currently controlled - includesavg of 1 new enclosure per plant, assumes170 major sourcesenclosure cost fromMACT BID; EPA factsheet for O&M costSierra Club petition toredo MACTsVOHAPWork practices -lumber kilns55,000$22512,375,000$6,039$1,358,708$1,300$292,500$1,651,208$7,339$Assumes 225 major source lumber mills willhave to implement and document workpractices on lumber kilns (e.g., workpractice implementation plan, inline moisturemeters for lumber)Industry providedcost to install inlinemoisture meters;annual operatingcost assumes$25/hr*52 hrs/yrVOHAPWork practices -wood productsmills 10,000$ 170 1,700,000$ 1,098$ 186,651$ 1,300$ 221,000$ 407,651$ 2,398$Assumes 170 major source wood productsplants will have to implement work practiceson units without add-on VOC/HAP controls.Initial cost includes work practiceimplementation plan, training operators,setting up recordkeeping system.Engineering estimateof initial cost; annualoperating costassumes $25/hr*52hrs/yr-$ -$779,075,000$ 85,538,247$ 94,863,500$ 180,401,747$Wood Products Plant Sources (Other Than Boilers)Note - assumes no lumber kiln control, existing controlrequirement remains 90% instead of increasing and forcingconversion of RCO to RTOAugust 2011 forpossible new lowerstandard,designations 2012,implementation 2014Costs of Clean Air Rules for the Forest Products IndustryRule/TimingPollutantControlInitial Investmentper UnitNumber of UnitsUpgraded/Additional UnitsAffected% ProbabilityTotal Cost (initialinvestment)AnnualizedCapital Cost perUnitTotalAnnualizedCapital CostTypical AnnualOperating Costper UnitTotalAnnualizedOperating CostTotalAnnualizedCostCost PerFacilityCollateralEmissions/EnergyIncreasesEstimatedCO2increases,metric tonsNotesCost NotesWood Products Plant Sources (Other Than Boilers)SSM exemptionchangesHAPShutdown processinstead of vent -$ 0 -$ -$ -$ -$ -$ -$Plan maintenance outages. Shutdownequipment if malfunction. Plants will likelynot change current operating practicesduring SSM events.No costs assumedhereAssumes RDCME willremain and operationwill not be significantlyimpactedHAPDuct to backupcontrol2,000,000$0-$219,589$-$-$-$-$Assumes it is possible to duct sources to abackup control device (this is cost ofductwork only, not control). Not a likelyoption.Based on info fromvarious industryprojectsHAPInstall backupcontrol5,000,000$0-$548,973$-$-$-$-$energy, NOx 0Cost of installing a backup control device soprocess does not have to shut down whenprimary control is offline. Not a likely option.2008 facility cost fornew oxidizer-$-$-$-$-$Wood ProductsNSPSPMWESP5,000,000$525,000,000$548,973$2,744,866$800,000$4,000,000$6,744,866$1,348,973$water 1,690Assumes mills will do projects that increasecapacity and will have to install additionalPM controls due to NSPS (e.g., needWESP to control condensible PM notcaptured by oxidizer). CO2 increasecalculated using 500 MWh additionalelectricity/yr/unit*DOE US avg 0.676 MTCO2/MWh.2008 facility cost forWESP; operatingcost based on EPAfact sheet $8/scfm x100kscfmReviewing need forNSPS forplywood/woodproducts, scopeuncertainNOxLNB - direct firedunits500,000$52,500,000$54,897$274,487$-$-$ 274,487$54,897$Assumes mills will do projects that increasecapacity and will have to install additionalNOx controls due to NSPSBased on info fromvarious industryprojectsPossible rule 2013-$-$-$-$-$27,500,000$3,019,352$4,000,000$7,019,352$Total Regulatory Cost858,575,000$94,266,920$138,688,500$232,955,420$ 158,861700sawmills, approx 221 are majorCapital Recovery Factor Calcuation for Annualized Costs:300wood products, approx 170 are majorInterestEquipmentRateLife, yrsCRF72softwood plywood plants7.00% 15 0.110Costs of Clean Air Rules for the Forest Products IndustryRule/TimingPollutantControlInitial Investmentper UnitNumber of UnitsUpgraded/Additional UnitsAffected% ProbabilityTotal Cost (initialinvestment)AnnualizedCapital Cost perUnitTotalAnnualizedCapital CostTypical AnnualOperating Costper UnitTotalAnnualizedOperating CostTotalAnnualizedCostCost PerFacilityCollateralEmissions/EnergyIncreasesEstimatedCO2increases,metric tonsNotesCost NotesWood 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 29,522Assumes a new catalytic oxidizer will haveto be installed to control dry dryers and 16of 31 facilities will choose this control option.CO2 increase calculated using 4 MMBtu/hrnatural gas*8700 hr/yr*53.02 kgCO2/MMBtu (EPA GHG rule EF).2008 facility cost fornew RCO; operatingcost assumes$10/scfm x 35kscfm(EPA fact sheet says$6-20/scfm)Biofilter 3,000,000$ 15 45,000,000$ 329,384$ 4,940,758$ 35,000$ 525,000$ 5,465,758$ 364,384$Assumes a new biofilter will have to beinstalled to control dry dryers and 15 of 31facilities will choose this control option2008 facility cost fornew press biofilter;vendor estimate ofoperating cost$1/acfm and 35,000acfm assumedEnclosure 500,000$ 31 15,500,000$ 54,897$ 1,701,817$ 5,000$ 155,000$ 1,856,817$ 59,897$New enclosure will be needed at each plantwith dry dryers (est. 31 plants)enclosure cost fromMACT BID; EPA factsheet for O&M cost140,500,000$ 15,426,145$ 6,280,000$ 21,706,145$Costs of Clean Air Rules for the Forest Products IndustryRule/TimingPollutantControlInitialInvestment perUnitNumber of UnitsUpgraded/Additional UnitsAffected% ProbabilityTotal Cost (initialinvestment)AnnualizedCapital Costper UnitTotal AnnualizedCapital CostTypical AnnualOperating Costper UnitTotal AnnualizedOperating CostTotal AnnualizedCostCost PerFacilityCollateralEmissions/EnergyIncreasesEstimatedCO2increases,metric tonsNotesCost NotesP&P Cluster MACT I /III redoVOHAP Steam strippers 2,000,000$ 25 50,000,000$ 219,589$ 5,489,731$ 2,400,000$ 60,000,000$ 65,489,731$ 2,619,589$ energy 1,872,023Assumes additional facilities will have toinstall steam strippers for additional HAPreductions. CO2 increase assumescoal/oil mix fired to make steam: avg86.07 kg CO2/MMBtu (EPA GHG ruleEF)*100 MMBtu/hr*8700 hr/yr/unit.MACT BID for initialcapital cost; operatingcost assumes 100MMBtu/hr heat inputrequired to make steam,fuel cost $3/MMBtuMinimal residual riskcosts - 2011VOHAPPaper machinecontrols 3,400,000$ 200 680,000,000$ 373,302$ 74,660,345$ 1,500,000$ 300,000,000$ 374,660,345$ 3,746,603$ energy 369,019Assumes facilities will have to do somesort of emissions control on papermachines, could range from additiveschanges to add on controls. Avg 2machines at 100 kraft mills (but theremay be additional units at other types offacilities not captured here). CO2increase calculated using 4 MMBtu/hrnatural gas*8700 hr/yr*53.02 kgCO2/MMBtu (EPA GHG rule EF).BE&K Capital cost forincineration controls onwet end/industry RTOBACT cost estimate.Sierra Club petition toredo MACTsVOHAPPipe additionalsources tocombustion 2,000,000$ 25 50,000,000$ 219,589$ 5,489,731$ -$ -$ 5,489,731$ 219,589$If CCA goes away or if additional sourcesrequire control (e.g., semi-chemwashers). Assumes there is already anincineration device that can handle flow.Cost of ductwork for amill's HVLC controlproject.780,000,000$ 85,639,807$ 360,000,000$ 445,639,807$P&P MACT II redoHCl Scrubber 8,000,000$ 120 960,000,000$ 878,357$ 105,402,840$ 1,500,000$ 180,000,000$ 285,402,840$ 3,805,371$ waterAssumes HCl scrubbers will be neededon 75% of existing recovery furnaces2003 NERA study boilerscrubber costMinimal residual riskcosts - 2011Organic HAPBLOX 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 49,818Assumes facilities with DCE boilers willcontrol BLOX on half of the boilersinstead of converting DCE to NDCE.CO2 increase calculated using 4MMBtu/hr natural gas*8700 hr/yr*53.02kg CO2/MMBtu (EPA GHG rule EF).Industry projectinstallation cost;operating cost assumes$20/scfm x 25kscfm(EPA presents largerange in fact sheets)Organic HAPRecovery BoilerDCE to NDCEconversion 20,000,000$ 26 50% 260,000,000$ 2,195,892$ 57,093,205$ -$ -$ 57,093,205$ 4,391,785$Assumes facilities will convert DCErecovery boilers to NDCE boilers to meetnew limits for half of the DCE units.Alternate of controlling BLOX would beless expensive if allowed.Recent company cost(MACT BID estimated$18MM)Organic HAPOrganic HAP limitsfor lime kilns2,000,000$4080,000,000$219,589$8,783,570$1,200,000$48,000,000$56,783,570$1,419,589$fresh water,heat loss 1,497,618Assumes 80 mills discontinue use ofcondensates in mud washing/causticarea, half of bleached mills install newstripper to handle these condensates.CO2 increase assumes coal/oil mix firedto make steam for stripper: avg 86.07 kgCO2/MMBtu (EPA GHG rule EF)*50MMBtu/hr*8700 hr/yr/unit.Assumes stripper capitalcost is same as abovestripper, operating cost ishalf.Organic HAPOrganic HAP limitsfor lime kilns75,000$403,000,000$8,235$329,384$-$-$329,384$8,235$Assumes 80 mills discontinue use ofcondensates in mud washing/causticarea, half send condensates to WWTP oranother controlled part of the Mill.Piping cost for similarproject in 2009 at a mill.Organic HAPOrganic HAP limitsfor semi-chem mills 8,000,000$540,000,000$878,357$4,391,785$-$4,391,785$878,357$energy 9,225Assumes RTO necessary on chemrecovery units without current control;small number of semi-chem mills. CO2increase calculated using 4 MMBtu/hrnatural gas*8700 hr/yr*53.02 kgCO2/MMBtu (EPA GHG rule EF).RTR proposal 2011;final 2012Hg/dioxinCarbon Injectionplus fabric filter -lime kilns8,000,000$108864,000,000$878,357$94,862,556$222,000$23,976,000$118,838,556$1,584,514$Assumes fabric filter controls will beneeded to meet new standards for Hg ordioxin on 75% of existing 140 LKsURS engineering/ 2003NERA studyHg/dioxinCarbon Injectionplus fabric filter -recovery boilers8,000,000$121968,000,000$878,357$106,281,197$222,000$26,862,000$133,143,197$1,775,243$Assumes fabric filter controls will beneeded to meet new standards for Hg ordioxin on 75% of existing 161 RBsURS engineering/ 2003NERA studySierra Club petition toredo MACTsPM/HAPSmelt TankScrubber500,000$8140,500,000$54,897$4,446,682$75,000$6,075,000$10,521,682$210,434$waterAssumes smelt tank control upgrades willbe needed on half of smelt tanks to meetlower PM standards or because bubbleno longer allowed; could also duct torecovery furnace. Would control organicHAP also.Facility cost estimates forinstalled cost; variousBART and BACT costestimates for annualoperating cost.PM/HAPPM limits for sulfiteand semi-chem mills 3,000,000$ 7 21,000,000$ 329,384$ 2,305,687$ 65,000$ 455,000$ 2,760,687$ 394,384$Assumes 7 of the facilities burning liquorwill need control ugprades.Set cost equal to that ofESP upgrade.PM/HAP RB ESP upgrades 3,000,000$ -$ 329,384$ -$ 65,000$ -$ -$ -$ energy 0Probably would not need to upgradeexisting PM controls if FF/CI needed forHg/dioxin reductions following ESP 2003 NERA studyPM/HAP LK ESP upgrades 3,000,000$ -$ 329,384$ -$ 65,000$ -$ -$ -$ energy 0Probably would not need to upgradeexisting PM controls if FF/CI needed forHg/dioxin reductions following ESP 2003 NERA study3,344,500,000$ 407,612,544$ 298,868,000$ 706,480,544$Pulp and Paper Sources (Other Than Power Boilers)Note - assumes thatinstalling RTO is not acontrol option toreduce lime kilnorganic HAPemissions due to costCosts of Clean Air Rules for the Forest Products IndustryRule/TimingPollutantControlInitialInvestment perUnitNumber of UnitsUpgraded/Additional UnitsAffected% ProbabilityTotal Cost (initialinvestment)AnnualizedCapital Costper UnitTotal AnnualizedCapital CostTypical AnnualOperating Costper UnitTotal AnnualizedOperating CostTotal AnnualizedCostCost PerFacilityCollateralEmissions/EnergyIncreasesEstimatedCO2increases,metric tonsNotesCost NotesPulp and Paper Sources (Other Than Power Boilers)NSPS Subpart BBNOxLNB/CombustionControls 500,000$ 10 5,000,000$ 54,897$ 548,973$ -$ -$ 548,973$ 54,897$Assumes mills do projects that triggerNSPS and NOx controlBased on info fromvarious industry projectsNOx SCR 8,000,000$ 1 8,000,000$ 878,357$ 878,357$ 301,000$ 301,000$ 1,179,357$ 1,179,357$ ammoniaAssumes mills do projects that triggerNSPS and significant NOx control (andthat SCR is feasible)Published cost estimatesrange from $4MM to$12MMPart of integrated P&Prulemaking (2011?)SO2 Scrubber 8,000,000$ 5 40,000,000$ 878,357$ 4,391,785$ 1,500,000$ 7,500,000$ 11,891,785$ 2,378,357$ waterAssumes mills do projects that triggerNSPS and SO2 control 2003 NERA studySO2 Low sulfur fuel 5 -$ -$ -$ -$ -$ -$Assumes mills do projects that triggerNSPS and SO2 controlA switch in fuel type mayrequire capital to modifyboiler or controls, butdepending on fuel costsat the time, could resultin savings.PM ESP upgrade 3,000,000$ 10 30,000,000$ 329,384$ 3,293,839$ 65,000$ 650,000$ 3,943,839$ 394,384$ 3,380Assumes mills do projects that triggerNSPS and additional PM control. CO2increase calculated using 500 MWhelectricity increase/yr/unit*DOE US avg0.676 MT CO2/MWh. 2003 NERA study83,000,000$ 9,112,954$ 8,451,000$ 17,563,954$SSM exemptionchangesHAPShutdown processinstead of ventingduring APCDmalfunction ormaintenance 100 -$ -$ -$ -$ -$ -$Facilities would have to plan not tooperate during APCD maintenanceinstead of counting the time toward aventing allowance. Process would haveto shut down during any prolonged APCDmalfunction.A cost of lost productioncould be assigned here,but has not beenestimated for thisexercise.Changes in milloperation to accountfor loss of complianceexemption during SSM HAPDuct to backupcontrol2,000,000$1020,000,000$219,589$2,195,892$-$-$2,195,892$219,589$Assumes it is possible to duct sources toan existing backup control device (this iscost of ductwork only, not control)Cost of ductwork for amill's HVLC project.Assumes venting andAPCD excursionallowances do not goaway in Subparts Sand MM.HAPInstall backupcontrol (e.g., RTO/scrubber for HVLC) 8,000,000$1080,000,000$878,357$8,783,570$300,000$3,000,000$11,783,570$1,178,357$ energy,NOx 18,451Cost of installing a backup control deviceso process does not have to shut downwhen primary control is offline. CO2increase calculated using 4 MMBtu/hrnatural gas*8700 hr/yr*53.02 kgCO2/MMBtu (EPA GHG rule EF).2006 facility cost for newRTO/scrubber; operatingcost conservatively estusing $20/scfm x15kscfm-$-$-$-$-$100,000,000$10,979,462$3,000,000$13,979,462$ContinuousParametricMonitoring SystemRuleShutdown to QA100-$-$100,000$10,000,000$10,000,000$100,000$Shutdown 4 times/yr at $25k perIndustry comments onproposed ruleAs part of MACT/NSPS revsEffort required tocomply 100 -$ -$ 15,000$ 1,500,000$ 1,500,000$ 15,000$One facility's estimate of additionalmanpower requiredIndustry comments onproposed rule-$ -$ 11,500,000$ 11,500,000$Ozone NAAQSNOx Combustion controls 500,000$ 50 25,000,000$ 54,897$ 2,744,866$ -$ -$ 2,744,866$ 54,897$Assumes RF/LK need combustioncontrols as a result of need for NOxreductions in NAABased on info fromvarious industry projectsNOx SCR 8,000,000$ 5 40,000,000$ 878,357$ 4,391,785$ 301,000$ 1,505,000$ 5,896,785$ 1,179,357$ ammoniaAssumes units need combustion controlsas a result of need for more NOxreductions in NAA (and that SCR isfeasible)Published cost estimatesrange from $4MM to$12MMVOC Oxidizer 5,000,000$ 5 25,000,000$ 548,973$ 2,744,866$ -$ 2,744,866$ 548,973$ energy, NOx 9,225May need additional VOC control inareas where VOC controls ozone and notNOx. CO2 increase calculated using 4MMBtu/hr natural gas*8700 hr/yr*53.02kg CO2/MMBtu (EPA GHG rule EF).2008 facility cost for newoxidizerMore NA areasNOx/VOCMore complexpermitting/permitting for moresources 40,000$ 50 2,000,000$ 4,392$ 219,589$ -$ -$ 219,589$ 4,392$The permitting process will become morecomplex for facilities in NAA. If NAAbecome Serious, more facilities will beTitle V (50 tpy).Conservative estimate ofwhat permitting andLAER might cost (e.g.,equipment upgrades)92,000,000$ 10,101,105$ 1,505,000$ 11,606,105$CAIR ReplacementSO2 Wet Scrubber 8,000,000$ 50 400,000,000$ 878,357$ 43,917,850$ 1,500,000$ 75,000,000$ 118,917,850$ 2,378,357$ waterAssumes recovery boilers covered byCAIR and need SO2 controls 2003 NERA studyPM ESP upgrade 3,000,000$ 5 15,000,000$ 329,384$ 1,646,919$ 65,000$ 325,000$ 1,971,919$ 394,384$ energy 1,690Assumes recovery boilers covered byCAIR and need better PM controls.CO2 increase calculated using 500 MWhelectricity increase/yr/unit*DOE US avg0.676 MT CO2/MWh.2003 NERA studyNOx Combustion controls 500,000$2512,500,000$54,897$1,372,433$-$-$1,372,433$54,897$Assumes recovery boilers covered byCAIR and need minimum NOx controls(units not caught under ozone NA)Based on info fromvarious industry projectsNOx SCR8,000,000$540,000,000$878,357$4,391,785$301,000$1,505,000$5,896,785$1,179,357$ ammoniaAssumes recovery boilers covered byCAIR and need high level of NOx control(and that SCR is actually feasible)Published cost estimatesrange from $4MM to$12MM467,500,000$51,328,987$76,830,000$128,158,987$EPA working on CAIRreplacement 3 -proposal and final2012, implement 2015August 2011 forpossible new lowerstandard,designations 2012,implementation 2014Costs of Clean Air Rules for the Forest Products IndustryRule/TimingPollutantControlInitialInvestment perUnitNumber of UnitsUpgraded/Additional UnitsAffected% ProbabilityTotal Cost (initialinvestment)AnnualizedCapital Costper UnitTotal AnnualizedCapital CostTypical AnnualOperating Costper UnitTotal AnnualizedOperating CostTotal AnnualizedCostCost PerFacilityCollateralEmissions/EnergyIncreasesEstimatedCO2increases,metric tonsNotesCost NotesPulp and Paper Sources (Other Than Power Boilers)NOx NAAQSNOxLNB/CombustionControls 500,000$ 5 2,500,000$ 54,897$ 274,487$ -$ -$ 274,487$ 54,897$Assumes units have projects where theycan't model compliance with lower NOxNAAQS and have to install combustioncontrolsBased on info fromvarious industry projectsNew 1-hour standardproposed June 2009;Final Jan 2010,designations 2012NOx SCR 8,000,000$ 1 8,000,000$ 878,357$ 878,357$ 301,000$ 301,000$ 1,179,357$ 1,179,357$ ammoniaAssumes units have projects where theycan't model compliance with lower NOxNAAQS and have to install significantNOx control (and SCR is feasible)Published cost estimatesrange from $4MM to$12MM10,500,000$ 1,152,844$ 301,000$ 1,453,844$SO2 NAAQSSO2 Scrubber 8,000,000$ 5 40,000,000$ 878,357$ 4,391,785$ 1,500,000$ 7,500,000$ 11,891,785$ 2,378,357$ waterAssumes units have projects where theycan't model compliance with lower SO2NAAQS and have to install scrubber 2003 NERA studyNew 1-hour standardfinal 2010,designations 2012,implementation 2013SO2 Low sulfur fuel 10 -$ -$ -$ -$ -$ -$Assumes units have projects where theycan't model compliance with lower SO2NAAQS and have to switch to lower SfuelA switch in fuel type mayrequire capital to modifyboiler or controls, butdepending on fuel costsat the time, could resultin savings.40,000,000$ 4,391,785$ 7,500,000$ 11,891,785$PM2.5 NAAQS fullyimplementedPM2.5 ESP upgrade 3,000,000$ 5 15,000,000$ 329,384$ 1,646,919$ 65,000$ 325,000$ 1,971,919$ 394,384$ energy 1,690Assumes units have projects where theycan't model compliance with PM2.5NAAQS and have to upgrade an ESP onRB or LK to comply. CO2 increasecalculated using 500 MWh electricityincrease/yr/unit*DOE US avg 0.676 MTCO2/MWh. 2003 NERA studyOctober 2011NOx SCR 8,000,000$ 1 8,000,000$ 878,357$ 878,357$ 301,000$ 301,000$ 1,179,357$ 1,179,357$ ammoniaAssumes units have projects where theycan't model compliance with PM2.5NAAQS and have to install NOx controlsto reduce nitrate formation (and that SCRis feasible).Published cost estimatesrange from $4MM to$12MMNOxLNB/CombustionControls 500,000$ 5 2,500,000$ 54,897$ 274,487$ -$ -$274,487$54,897$Assumes units have projects where theycan't model compliance with PM2.5NAAQS and have to install NOx controlsto reduce nitrate formation.Based on info fromvarious industry projectsSO2 Scrubber8,000,000$1080,000,000$878,357$8,783,570$1,500,000$15,000,000$23,783,570$2,378,357$ waterAssumes units have projects where theycan't model compliance with PM2.5NAAQS and have to install SO2 controlsto reduce sulfate formation (would alsoreduce PM).2003 NERA studySO2 Low sulfur fuel2,000,000$510,000,000$219,589$1,097,946$-$1,097,946$219,589$Assumes units have projects where theycan't model compliance with PM2.5NAAQS and have to use lower sulfurfuels to reduce sulfate formation.A switch in fuel type mayrequire capital to modifyboiler or controls, butdepending on fuel costsat the time, could resultin savings.115,500,000$12,681,279$15,626,000$28,307,279$Costs of Clean Air Rules for the Forest Products IndustryRule/TimingPollutantControlInitialInvestment perUnitNumber of UnitsUpgraded/Additional UnitsAffected% ProbabilityTotal Cost (initialinvestment)AnnualizedCapital Costper UnitTotal AnnualizedCapital CostTypical AnnualOperating Costper UnitTotal AnnualizedOperating CostTotal AnnualizedCostCost PerFacilityCollateralEmissions/EnergyIncreasesEstimatedCO2increases,metric tonsNotesCost NotesPulp and Paper Sources (Other Than Power Boilers)H2S listed as HAPH2S Scrubber 4,000,000$ 50 200,000,000$ 439,178$ 21,958,925$ 750,000$ 37,500,000$ 59,458,925$ 1,189,178$ waterInstall/upgrade scrubbers to control H2SemissionsAssume cost is half ofboiler scrubberSierra Club letter sent3/09H2SDuct additionalsources to control 2,000,000$ 50 100,000,000$ 219,589$ 10,979,462$ -$ -$ 10,979,462$ 219,589$SO2 fromcombustionAssumes this will pick up additionalsources of H2S that are not currentlycontrolled and will require ducting toexisting control device/boilerCost of ductwork for amill's HVLC project.H2STall Oil System H2Slimits - scrubberupgrade 200,000$ 30 6,000,000$ 21,959$ 658,768$ -$ -$ 658,768$ 21,959$Assumes that tall oil systems at 30 millswill need H2S reduction that can beaccomplished by upgrading the scrubber.Worst case cost, not captured here,would be routing to NCG system.Cost of mill's tall oilscrubber systemupgrade.H2SDiscontinue use ofcondensates aswater atuncontrolled sources -$ 10 -$ -$ -$ -$ -$ -$ -$incr freshwater use,heat lossH2S reductions can be achieved byeliminating use of condensates andreplacing with fresh water at processesthat are not currently controlled.Condensates would either be re-routedor stripped.No additional cost,assume captured underLK organic HAP limitsaboveH2S WWTP upgrades 35,000,000$ 67 2,345,000,000$ 3,842,812$ 257,468,395$ 2,170,000$ 145,390,000$ 402,858,395$ 6,012,812$truckingsludge tolandfillAssume 67 kraft mills with ASB systemsconvert to activated sludge or UNOX.Mills could also be required to encloseand control WWTP, but those costs arenot presented here at this time.URS engineeringestimate for converting25MGD system from ASBto activated sludge; costexpected to be similar forUNOX. Operating cost isdisposing of 155,000 tonssludge at $14/ton (actualmill cost)H2S Steam stripper 2,000,000$ 0 -$ 219,589$ -$ 1,200,000$ -$ -$ energy 0Install or reconfigure stripper topreferentially strip TRS compounds fromcondensates (set affected units to zero tomake sure not double counting fromMACT I above)MACT BID for initialcapital cost; operatingcost assumes 50MMBtu/hr heat inputrequired to make steam,fuel cost $3/MMBtu2,651,000,000$ 291,065,550$ 182,890,000$ 473,955,550$Regional HazeSO2 Scrubber 8,000,000$ 2 16,000,000$ 878,357$ 1,756,714$ 1,500,000$ 3,000,000$ 4,756,714$ 2,378,357$ waterAssumes units that didn't have to put onscrubbers for rules above now need ascrubber2003 NERA studyscrubber cost for capitalcost; combination ofNERA study and URSBACT estimates foroperating cost.SO2 Low sulfur fuel 2 -$ -$ -$ -$ -$ -$Assumes units that didn't have to switchabove now need toA switch in fuel type mayrequire capital to modifyboiler or controls, butdepending on fuel costsat the time, could resultin savings.PM ESP 5,000,000$ -$ 548,973$ -$ 77,000$ -$-$electricity 0adequate PM reductions probablyachieved under previous rules2003 NERA study ESPcostNOx SCR8,000,000$216,000,000$878,357$1,756,714$301,000$602,000$2,358,714$1,179,357$ ammoniaAssumes units not caught up above nowneed significant NOx reductions (and thatSCR is feasible)Published cost estimatesrange from $4MM to$12MM; operating costfrom NERA32,000,000$3,513,428$3,602,000$7,115,428$Total Regulatory Cost7,716,000,000$887,579,746$970,073,000$1,857,652,746$3,832,139300converting plantsCapital Recovery Factor Calcuation for Annualized Costs:400pulp and paper facilitiesInterest Equipment100of which are kraftRateLife, yrsCRF56DCE recovery boilers7.00% 15 0.110112NDCE recovery boilers144lime kilnsBART -additionalcontrol to meetmilestones following2018

## Appendix C

Detailed Boiler MACT Cost SpreadsheetsFacilityID UnitID UnitCountMajorSourceStateClassificatioCapacity(mmCapacity_NumeriHoursPerYearInstalle CombustorDesign DutyCyclewNOxBurneACTFuelCategoBaselineFuelCat TotalControlCoal % Biomass % Liquid % Gas 2 %MaxFuel% Max FuelBiomass/CoalCombo Boiler?WetBiomass? PM LimitPMEmissionsPMDifference PM %red HCL LimitHCLEmissionsHCLDifference HCl%red Hg LimitHgEmissionsHgDifferenceALAbitibiBowaterCP PowerBoiler#1 1MajorSource AL Boiler 300 300 8760 0 PC FalseCoalCoalElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AALAbitibiBowaterCP PowerBoiler#2 1MajorSource AL Boiler 300 300 8760 0 PC FalseCoalCoalElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AALAbitibiBowaterCP PowerBoiler#3 1MajorSource AL Boiler 300 300 8760 0 PC FalseCoalCoalElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AALAbitibiBowaterCP PowerBoiler#4 1MajorSource AL Boiler 300 300 8760 0 PC FalseCoalCoalElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AALBoiseWhitePaperJackson 102‐0001‐Z013 1MajorSource AL Boiler 435 435 8400 1964 Stoker/SlopedGrate/Other Base‐loaded False Biomass WetBiomass VenturiScrubber0 96.23577545 3.764224548 096.23578 Biomass no 10.039 0.112902 -0.0739 65.46% 0.035 0.000291 0.034709 4.6E-06 6.22E-07 3.98E-06ALBrewton SB‐1 1MajorSource AL Boiler 68 68 8700 1974 Stoker/SlopedGrate/Other Base‐loaded False Biomass WetBiomass CycloneorMulticlone0 100 0 0100 Biomass no 10.039 0.333333 -0.29433 88.30% 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AALChapmanForestProductsEU001WoodFiredBoiler 1MajorSource AL Boiler 86.25 86.25 8760 1974 Stoker/SlopedGrate/Other loadfollowing False Biomass WetBiomass VenturiScrubber0 100 0 0100 Biomass no 10.039 0.298518 -0.25952 86.94% 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AALChapmanForestProductsEU002WoodFiredBoiler 1MajorSource AL Boiler 47.38 47.38 8760 1993 Stoker/SlopedGrate/Other loadfollowing False Biomass WetBiomass VenturiScrubber0 100 0 0100 Biomass no 10.039 0.230285 -0.19129 83.06% 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AALChapmanForestProductsEU003WoodFiredBoiler 1MajorSource AL Boiler 47.38 47.38 8760 1967 Stoker/SlopedGrate/Other loadfollowing False Biomass WetBiomass VenturiScrubber0 100 0 0100 Biomass no 10.039 0.27293 -0.23393 85.71% 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AALGeorgiaPacificNaheola Z015‐CB1 1MajorSource AL Boiler 425 425 8760 1958 Stoker/SlopedGrate/Other loadfollowing False Biomass WetBiomassElectrostaticPrecipitator38.6035845 61.3964155 0 061.39642 Biomass combo 10.039 N/A N/A #VALUE! 0.035 0.008305 0.026695 4.6E-06 2.14E-06 2.46E-06ALGeorgiaPacificNaheola Z016‐CB2 1MajorSource AL Boiler 318 318 8760 1962 Stoker/SlopedGrate/Other loadfollowing False Biomass WetBiomassElectrostaticPrecipitator56.1006735 43.89932654 0 056.10067 Coal combo 10.039 N/A N/A #VALUE! 0.035 0.01883 0.01617 4.6E-06 1.43E-06 3.17E-06ALGeorgiaPacificNaheola Z017‐PB3 1MajorSource AL Boiler 379 379 5000 1970 N/A loadfollowing False Liquid HeavyLiquid NoHAPAPCDControl0 0 100 00 Biomass no 00.0075 N/A N/A #VALUE! 0.00033 N/A N/A #VALUE! 3.5E-06 N/A N/AALGPBelkLumberEU001WoodFiredBoiler 1MajorSource AL Boiler 69 69 8760 1974 Stoker/SlopedGrate/Other loadfollowing False Biomass WetBiomassElectrostaticPrecipitator0 100 0 0100 Biomass no 10.039 0.026667 0.012333 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AALGPBrewtonMillBR‐PSG0‐S021No.2PowerBoiler 1MajorSource AL Boiler 390 390 8640 1963 Stoker/SlopedGrate/Other Base‐loaded True Biomass WetBiomassElectrostaticPrecipitator0 79.53986768 0 079.53987 Biomass no 10.039 0.025833 0.013167 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AALGPBrewtonMillBR‐PSG0‐S026No.3PowerBoiler 1MajorSource AL Boiler 608 608 8640 1981 Stoker/SlopedGrate/Other Base‐loaded True Biomass WetBiomassElectrostaticPrecipitator0 100 0 0100 Biomass no 10.039 0.007556 0.031444 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AALGPBrewtonMillBR‐PSG0‐S018No.1PowerBoiler 1MajorSource AL Boiler 289 289 2880 1956 N/A loadfollowing False Liquid LightLiquid NoHAPAPCDControl0 0 34.32321744 00 Biomass no 00.0075 0.022333 -0.01483 66.42% 0.00033 N/A N/A #VALUE! 3.5E-06 N/A N/AALGPEngineeredWoodProductsThornsbyEU001WoodFiredBoiler 1MajorSource AL Boiler 61.77 61.77 8760 1979 Stoker/SlopedGrate/Other loadfollowing False Biomass WetBiomass WetScrubber0 100 0 0100 Biomass no 10.039 0.18312 -0.14412 78.70% 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AALGPPetermanPlyEU001WoodwasteBoilerw/Multicloneand1MajorSource AL Boiler 224 224 8305 1977 Stoker/SlopedGrate/Other loadfollowing False Biomass WetBiomassElectrostaticPrecipitator0 0 000 Biomass no 10.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AALGPTalladegaPlyEU001WoodWasteBoilerwMulticloneandESP 1MajorSource AL Boiler 185 185 8520 1975 Stoker/SlopedGrate/Other loadfollowing False Biomass WetBiomassElectrostaticPrecipitator0 0 000 Biomass no 10.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AALGulfLumber Boiler#1 1MajorSource AL Boiler 68 68 7500 1983 Stoker/SlopedGrate/Other False Biomass WetBiomass WetScrubberData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 10.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AALIPCourtlandNo.2CombinationBoiler/11CU201 1MajorSource AL Boiler 735 735 8511 1979 PC loadfollowing FalseCoalCoalDryScrubberElectrostaticPrecipitator0 0 000 Biomass no 00.039 N/A N/A #VALUE! 0.035 0.000282 0.034718 4.6E-06 5.38E-07 4.06E-06ALIPCourtlandNo.1CombinationBoiler/11CU101 1MajorSource AL Boiler 398 398 1437 1970 Stoker/SlopedGrate/Other Standby False Biomass WetBiomass VenturiScrubber0 0 000 Biomass no 10.039 N/A N/A #VALUE! 0.035 0.004179 0.030821 4.6E-06 6.08E-07 3.99E-06ALIPCourtlandNo.3CombinationBoier/11CU301 1MajorSource AL Boiler 710 710 8291 1993 FB Base‐loaded True Biomass WetBiomassElectrostaticPrecipitator0 87.74449361 3.710686781 087.74449 Biomass no 10.039 0.004917 0.034083 0.035 0.000208 0.034792 4.6E-06 4.14E-07 4.19E-06ALIPPineHill 109‐0001‐Z010 1MajorSource AL Boiler 770 770 8400 1968 PC Base‐loaded FalseCoalCoalElectrostaticPrecipitator0 0 000 Biomass no 00.039 0.035333 0.003667 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AALIPPineHill 109‐0001‐Z007 1MajorSource AL Boiler 705 705 8400 1968 Stoker/SlopedGrate/Other loadfollowing False Biomass WetBiomassElectrostaticPrecipitator0 0 000 Biomass no 10.039 0.114 -0.075 65.79% 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AALIPPrattville Z008 1MajorSource AL Boiler 630 630 8471 1980 Stoker/SlopedGrate/Other loadfollowing False Biomass WetBiomassElectrostaticPrecipitator33.2403294 66.75967059 0 066.75967 Biomass combo 10.039 0.045611 -0.00661 14.49% 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AALIPPrattville Z006 1MajorSource AL Boiler 707 707 8553 1967 Stoker/SlopedGrate/Other loadfollowing False Biomass WetBiomassElectrostaticPrecipitator0 80.61485909 0 080.61486 Biomass no 10.039 0.025611 0.013389 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AALIPRiverdaleNo.1BarkBoiler/BK01 1MajorSource AL Boiler 245 245 8400 1979 Stoker/SlopedGrate/Other loadfollowing True Biomass WetBiomass VenturiScrubber0 0 000 Biomass no 10.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AALK‐CMobile BarkBoiler#7 1MajorSource AL Boiler 750 750 8760 0 Stoker/SlopedGrate/Other FalseCoalCoal VenturiScrubberData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AALK‐CMobile PowerBoiler#6 1MajorSource AL Boiler 500 500 8760 0 PC FalseCoalCoalElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AALManningtonWoodFloors BB01 1MajorSource AL Boiler 28.2 28.2 8760 1991 Stoker/SlopedGrate/Other Base‐loaded False Biomass WetBiomassElectrostaticPrecipitator0 100 0 0100 Biomass no 10.039 0.009667 0.029333 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AALManningtonWoodFloors BB02 1MajorSource AL Boiler 28.2 28.2 8760 2005 Stoker/SlopedGrate/Other Base‐loaded False Biomass WetBiomassElectrostaticPrecipitator0 100 0 0100 Biomass no 10.039 0.009667 0.029333 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AALMeadwestvacoCottonton46No.1WoodResidueBoiler 1MajorSource AL Boiler 337 337 8520 1966 Stoker/SlopedGrate/Other loadfollowing False Biomass WetBiomass VenturiScrubber0 0 000 Biomass no 10.039 0.0441 -0.0051 11.56% 0.035 0.000964 0.034036 4.6E-06 1.21E-06 3.39E-06ALMeadwestvacoCottonton46No.2WoodResidueBoiler 1MajorSource AL Boiler 550 550 8520 1981 Stoker/SlopedGrate/Other loadfollowing False Biomass WetBiomassElectrostaticPrecipitator0 0 000 Biomass no 10.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AALMeadwestvacoCottonton46No.3WoodResidueBoiler 1MajorSource AL Boiler 915 915 8520 1990 Stoker/SlopedGrate/Other loadfollowing False Biomass WetBiomass VenturiScrubber0 0 000 Biomass no 10.039 0.033367 0.005633 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AALP&WAlabamaRiver PowerBoiler#1 1MajorSource AL Boiler 440 440 8760 0 Stoker/SlopedGrate/Other False Biomass WetBiomass VenturiScrubberData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 10.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AALP&WAlabamaRiver PowerBoiler#2 1MajorSource AL Boiler 190 190 8760 0 Stoker/SlopedGrate/Other False Biomass WetBiomassElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 10.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AALP&WAlabamaRiver PowerBoiler#3 1MajorSource AL Boiler 440 440 8760 0 Stoker/SlopedGrate/Other False Biomass WetBiomass VenturiScrubberData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 10.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AALRock‐TennDemopolis PowerBoiler#3 1MajorSource AL Boiler 250 250 8760 0 Stoker/SlopedGrate/Other FalseCoalCoal VenturiScrubberData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AALRock‐TennDemopolis PowerBoiler#1 1MajorSource AL Boiler 225 225 8760 0 Stoker/SlopedGrate/Other False Biomass WetBiomass VenturiScrubberData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 10.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AALScotchLumberEU001(Wood‐FiredBoiler) 1MajorSource AL Boiler 98.5 98.5 8400 1988 Stoker/SlopedGrate/Other loadfollowing False Biomass WetBiomass CycloneorMulticlone0 100 0 0100 Biomass no 10.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AALSeamanTimber 1 1MajorSource AL Boiler 28.7 28.7 7500 1996 Stoker/SlopedGrate/Other Base‐loaded False Biomass DryBiomass CycloneorMulticloneData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AFacilityID UnitID UnitCountMajorSourceStateClassificatioCapacity(mmCapacity_NumeriHoursPerYearInstalle CombustorDesign DutyCyclewNOxBurneACTFuelCategoBaselineFuelCat TotalControlCoal % Biomass % Liquid % Gas 2 %MaxFuel% Max FuelBiomass/CoalCombo Boiler?WetBiomass? PM LimitPMEmissionsPMDifference PM %red HCL LimitHCLEmissionsHCLDifference HCl%red Hg LimitHgEmissionsHgDifferenceALSmurfit‐Stone WasteBoiler#1 1MajorSource AL Boiler 225 225 8760 0 Stoker/SlopedGrate/Other False Biomass WetBiomassWetElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 10.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AALSmurfit‐Stone WasteBoiler#2 1MajorSource AL Boiler 375 375 8760 0 Stoker/SlopedGrate/Other False Biomass WetBiomassElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 10.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AALSmurfit‐Stone PowerBoiler#1 1MajorSource AL Boiler 170 170 8760 0 N/A False Liquid HeavyLiquidWetScrubberWetElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.0075 N/A N/A #VALUE! 0.00033 N/A N/A #VALUE! 3.5E-06 N/A N/AALSmurfit‐Stone PowerBoiler#2 1MajorSource AL Boiler 170 170 8760 0 N/A False Liquid HeavyLiquidWetScrubberWetElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.0075 N/A N/A #VALUE! 0.00033 N/A N/A #VALUE! 3.5E-06 N/A N/AALWestervelt Wellons‐Unit001 1MajorSource AL Boiler 98 98 8200 1997 Stoker/SlopedGrate/Other Base‐loaded True Biomass WetBiomassElectrostaticPrecipitator0 100 0 0100 Biomass no 10.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AALWestervelt Teaford‐Unit003 1MajorSource AL Boiler 99 99 8400 2006 Stoker/SlopedGrate/Other loadfollowing True Biomass DryBiomassElectrostaticPrecipitator0 100 0 0100 Biomass no 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AALWestFraserCitronelle Boiler‐1 1MajorSource AL Boiler 90 90 7800 1973 Stoker/SlopedGrate/Other loadfollowing False Biomass WetBiomass WetScrubber0 100 0 0100 Biomass no 10.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AALWestFraserMaplesville Boiler‐1 1MajorSource AL Boiler 119 119 8708 1974 Stoker/SlopedGrate/Other loadfollowing False Biomass WetBiomass VenturiScrubber0 100 0 0100 Biomass no 10.039 0.070446 -0.03145 44.64% 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AALWeyerhaeuserMillport BoilerNo.1 1MajorSource AL Boiler 115 115 8100 1973 Stoker/SlopedGrate/Other loadfollowing False Biomass DryBiomass NoHAPAPCDControl0 100 0 0100 Biomass no 00.039 0.314527 -0.27553 87.60% 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AARAnthonyForestProducts SN‐12 1MajorSource AR Boiler 29.56 29.56 8592 1997 FuelCell loadfollowing False Biomass WetBiomass CycloneorMulticlone0 100 0 0100 Biomass no 10.039 0.129252 -0.09025 69.83% 0.035 0.0002 0.0348 4.6E-06 8.24E-07 3.78E-06ARAnthonyForestProducts SN‐13 1MajorSource AR Boiler 29.56 29.56 8592 1997 FuelCell loadfollowing False Biomass WetBiomass CycloneorMulticlone0 100 0 0100 Biomass no 10.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AARAnthonyForestProducts SN‐16 1MajorSource AR Boiler 29.75 29.75 8592 2002 FuelCell loadfollowing False Biomass WetBiomass CycloneorMulticlone0 100 0 0100 Biomass no 10.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AARDeltaNaturalKraftHogFuelBoiler(SN‐05) 1MajorSource AR Boiler 160 160 8600 1976 Stoker/SlopedGrate/Other Base‐loaded False Biomass DryBiomass CycloneorMulticlone0 100 0 0100 Biomass no 00.039 0.332306 -0.29331 88.26% 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AARDelticTimberWaldoWoodFiredBoilerNo.1(SN‐13) 1MajorSource AR Boiler 60 60 8760 1995 Stoker/SlopedGrate/Other Base‐loaded False Biomass WetBiomassElectrostaticPrecipitator0 100 0 0100 Biomass no 10.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AARDelticTimberWaldoWoodFiredBoilerNo.2(SN‐14) 1MajorSource AR Boiler 60 60 8760 1995 Stoker/SlopedGrate/Other Base‐loaded False Biomass WetBiomassElectrostaticPrecipitator0 100 0 0100 Biomass no 10.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AARDelticTimberWaldoWoodFiredBoilerNo.3(SN‐20) 1MajorSource AR Boiler 60 60 8760 2005 Stoker/SlopedGrate/Other Base‐loaded False Biomass WetBiomassElectrostaticPrecipitator0 100 0 0100 Biomass no 10.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AARDel‐Tin SN‐05 1MajorSource AR Boiler 291 291 8760 1997 Stoker/SlopedGrate/Other loadfollowing False Biomass DryBiomassElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AARDomtarIndustries PB2 1MajorSource AR Boiler 82082085201975Stoker/SlopedGrate/OtherloadfollowingCoal Coal Wet ScrubberData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AARDomtarIndustries PB1 1MajorSource AR Boiler 58058080491967Stoker/SlopedGrate/OtherloadfollowingBiomass Wet BiomassElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 10.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AARDomtarIndustries PB3 1MajorSource AR Boiler 79079081601990Stoker/SlopedGrate/OtherloadfollowingBiomass Wet BiomassElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 10.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AAREvergreenPackaging BB 1MajorSource AR Boiler 500 500 8570 1958 Stoker/SlopedGrate/Other Base‐loaded True Biomass DryBiomass VenturiScrubber0 100 0 0100 Biomass no 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AAREvergreenPackaging PB1 1MajorSource AR Boiler 600 600 6000 1958 N/A Base‐loaded True Liquid HeavyLiquid NoHAPAPCDControl0 0 40.5398746 00 Biomass no 00.0075 N/A N/A #VALUE! 0.00033 N/A N/A #VALUE! 3.5E-06 N/A N/AARGBPMorrilton SN‐02 1MajorSource AR Boiler 162 162 2880 1968 Stoker/SlopedGrate/Other Base‐loaded False Biomass WetBiomass CycloneorMulticlone0 100 0 0100 Biomass no 10.039 0.259667 -0.22067 84.98% 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AARGBPMorrilton SN‐04 1MajorSource AR Boiler 452 452 8400 1965 Stoker/SlopedGrate/Other Base‐loaded True Biomass WetBiomass VenturiScrubber0 100 0 0100 Biomass no 10.039 0.041277 -0.00228 5.52% 0.035 0.001336 0.033664 4.6E-06 1.22E-06 3.38E-06ARGeorgiaPacificCrossett93SN‐WB1WoodBoiler 1MajorSource AR Boiler 245 245 8400 1981 Stoker/SlopedGrate/Other loadfollowing False Biomass DryBiomass WetScrubber0 100 0 0100 Biomass no 00.039 N/A N/A #VALUE! 0.035 8.33E-05 0.034917 4.6E-06 N/A N/AARGeorgiaPacificCrossett93SN‐WB2WoodBoiler 1MajorSource AR Boiler 245 245 8400 1981 Stoker/SlopedGrate/Other loadfollowing False Biomass DryBiomassElectrostaticPrecipitator0 100 0 0100 Biomass no 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AARGeorgiaPacificFordyceSN‐01WoodFuelBoiler 1MajorSource AR Boiler 185 185 8147 1974 Stoker/SlopedGrate/Other loadfollowing False Biomass DryBiomass WetScrubber0 100 0 0100 Biomass no 00.039 0.210333 -0.17133 81.46% 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AARGPCrossett92 SN‐03 1MajorSource AR Boiler 1001 1001 8400 1984 Stoker/SlopedGrate/Other Base‐loaded True Biomass WetBiomass WetScrubber0 100 0 0100 Biomass no 10.039 0.031633 0.007367 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AARGPCrossett92 SN‐22 1MajorSource AR Boiler 720 720 8500 1973 Stoker/SlopedGrate/Other loadfollowing True Biomass WetBiomass WetScrubber0 0 000 Biomass no 10.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AARGPFordyceOSBSN‐01AThermalOilHeaters(#1) 1MajorSource ARProcessHeater 40 40 8000 1999 DutchOven/Susp.Burner loadfollowing False Biomass DryBiomass NoHAPAPCDControlData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AARGPFordyceOSBSN‐01AThermalOilHeaters(#2) 1MajorSource ARProcessHeater 40 40 8000 1999 DutchOven/Susp.Burner loadfollowing False Biomass DryBiomass NoHAPAPCDControlData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AARGPGurdonPlyLumberSN02No.2WoodResidueFiredBoiler 1MajorSource AR Boiler 135 135 8400 1979 Stoker/SlopedGrate/Other loadfollowing False Biomass DryBiomass VenturiScrubber0 100 0 0100 Biomass no 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AARGPGurdonPlyLumberSN01No.1WoodResidueFiredBoiler 1MajorSource AR Boiler 135 135 8640 1979 Stoker/SlopedGrate/Other loadfollowing False Biomass DryBiomass VenturiScrubber0 100 0 0100 Biomass no 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AARLeolaLumberMill SN‐01A 1MajorSource AR Boiler 94.15 94.15 8400 1994 Stoker/SlopedGrate/Other loadfollowing False Biomass DryBiomassElectrostaticPrecipitator0 100 0 0100 Biomass no 00.039 0.003667 0.035333 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AARLeolaLumberMill SN‐01B 1MajorSource AR Boiler 94.15 94.15 8400 1994 Stoker/SlopedGrate/Other loadfollowing False Biomass DryBiomassElectrostaticPrecipitator0 100 0 0100 Biomass no 00.039 0.005567 0.033433 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AARLeolaLumberMill SN‐19 1MajorSource AR Boiler 28.8 28.8 8400 1999 Stoker/SlopedGrate/Other loadfollowing False Biomass WetBiomass CycloneorMulticloneData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 10.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AARPotlatchForestCypressBend PowerBoiler#1 1MajorSource AR Boiler 479 479 8700 1976 N/A loadfollowing True Liquid HeavyLiquid NoHAPAPCDControl0 0 000 Biomass no 00.0075 0.023261 -0.01576 67.76% 0.00033 N/A N/A #VALUE! 3.5E-06 N/A N/AARPotlatchForestPrescott McBurneyBoiler 1MajorSource AR Boiler 175 175 8400 1996 Stoker/SlopedGrate/Other loadfollowing False Biomass DryBiomassElectrostaticPrecipitator0 100 0 0100 Biomass no 00.039 0.023567 0.015433 0.035 0.004267 0.030733 4.6E-06 N/A N/AARPotlatchForestWarren WellonsBoiler 1MajorSource AR Boiler 280 280 8400 1990 Stoker/SlopedGrate/Other Base‐loaded False Biomass DryBiomassElectrostaticPrecipitator0 100 0 0100 Biomass no 00.039 0.0008 0.0382 0.035 0.001567 0.033433 4.6E-06 5.41E-07 4.06E-06ARRiversideFurniturePlant5SN‐01Wood‐firedBoiler 1MajorSource AR Boiler 19.5 19.5 8760 1987 Stoker/SlopedGrate/Other Base‐loaded False Biomass DryBiomass CycloneorMulticlone0 100 0 0100 Biomass no 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AARTemple‐Inland PWBTHERM48 1MajorSource ARProcessHeater 40 40 5600 1994 DutchOven/Susp.Burner loadfollowing False Biomass DryBiomass NoHAPAPCDControlData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AARTemple‐Inland PDTHERM48 1MajorSource ARProcessHeater 40 40 6150 1994 DutchOven/Susp.Burner loadfollowing False Biomass DryBiomass NoHAPAPCDControlData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AFacilityID UnitID UnitCountMajorSourceStateClassificatioCapacity(mmCapacity_NumeriHoursPerYearInstalle CombustorDesign DutyCyclewNOxBurneACTFuelCategoBaselineFuelCat TotalControlCoal % Biomass % Liquid % Gas 2 %MaxFuel% Max FuelBiomass/CoalCombo Boiler?WetBiomass? PM LimitPMEmissionsPMDifference PM %red HCL LimitHCLEmissionsHCLDifference HCl%red Hg LimitHgEmissionsHgDifferenceARTemple‐Inland HTFTHERM48 1MajorSource ARProcessHeater 40 40 7100 1994 DutchOven/Susp.Burner loadfollowing False Biomass DryBiomass NoHAPAPCDControlData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AARWestFraserHuttig SN‐24 1MajorSource AR Boiler 29.63 29.63 8290 2004 Stoker/SlopedGrate/Other Base‐loaded False Biomass WetBiomass CycloneorMulticlone0 100 0 0100 Biomass no 10.039 0.183333 -0.14433 78.73% 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AARWestFraserHuttig SN‐01 1MajorSource AR Boiler 118 118 8650 1972 Stoker/SlopedGrate/Other Base‐loaded False Biomass WetBiomass CycloneorMulticlone0 100 0 0100 Biomass no 10.039 0.243667 -0.20467 83.99% 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AARWeyerhaeuser SN‐06 1MajorSource AR Boiler 78.5 78.5 8520 1972 Stoker/SlopedGrate/Other loadfollowing False Biomass DryBiomass NoHAPAPCDControl0 100 0 0100 Biomass no 00.039 0.298 -0.259 86.91% 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AARWeyerhaeuserDierksMill SN‐45 1MajorSource AR Boiler 249 249 8400 1997 FuelCell loadfollowing False Biomass DryBiomassElectrostaticPrecipitator0 100 0 0100 Biomass no 00.039 0.00851 0.03049 0.035 0.001 0.034 4.6E-06 6.24E-07 3.98E-06AZCatalystPaperSnowflakePowerBoiler#2Coal 1MajorSource AZ Boiler 1132 1132 8640 1975 PC loadfollowing FalseCoalCoalWetScrubberElectrostaticPrecipitator100 0 0 0100 Coal no 00.039 0.0315 0.0075 0.035 0.000116 0.034884 4.6E-06 N/A N/AAZCatalystPaperSnowflakePowerBoiler#3NaturalGas 1MajorSource AZ Boiler 337 337 8400 2002 N/A Standby True Liquid LightLiquid NoHAPAPCDControlData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.0075 N/A N/A #VALUE! 0.00033 N/A N/A #VALUE! 3.5E-06 N/A N/ACAHumboldtFlakeboard143 NS‐028 1MajorSource CA Boiler 40 40 6000 1971 Stoker/SlopedGrate/Other Base‐loaded False Biomass DryBiomass NoHAPAPCDControl0 0 000 Biomass no 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/ACARoseburgWeed Boiler 1MajorSource CA Boiler 169.74 169.74 8400 1996 Stoker/SlopedGrate/Other loadfollowing False Biomass WetBiomassElectrostaticPrecipitator0 100 0 0100 Biomass no 10.039 0.016467 0.022533 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/ACASierraPine‐Rocklin SPRKBL01 1MajorSource CA Boiler 71.7 71.7 8424 1976 DutchOven/Susp.Burner loadfollowing False Biomass DryBiomassVenturiScrubberElectrostaticPrecipitator0 0 000 Biomass no 00.039 0.031074 0.007926 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AFLCFRC252Boiler#3(McBurney) 1MajorSource FL Boiler 85 85 8592 1980 Stoker/SlopedGrate/Other loadfollowing False Biomass WetBiomass WetScrubber0 100 0 0100 Biomass no 10.039 N/A N/A #VALUE! 0.035 0.00308 0.03192 4.6E-06 3.68E-07 4.23E-06FLCFRC252Boilers#4(Hurst) 1MajorSource FL Boiler 29.9 29.9 8592 1994 Stoker/SlopedGrate/Other Base‐loaded False Biomass WetBiomass CycloneorMulticloneData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 10.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AFLGPHawthorneEU001WoodFiredBoiler 1MajorSource FL Boiler 224 224 8556 1980 Stoker/SlopedGrate/Other loadfollowing False Biomass WetBiomassElectrostaticPrecipitator0 99.99980871 0 099.99981 Biomass no 10.039 0.004 0.035 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AFLGPHosfordOSB011‐THERMALOILHEATER#1 1MajorSource FLProcessHeater 40 40 8000 2003 DutchOven/Susp.Burner loadfollowing False Biomass DryBiomassElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AFLGPHosfordOSB011‐THERMALOILHEATER#2 1MajorSource FLProcessHeater 40 40 8000 2003 DutchOven/Susp.Burner loadfollowing False Biomass DryBiomassElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AFLGPPalatka EU16 1MajorSource FL Boiler 512.7 512.7 8400 1965 Stoker/SlopedGrate/Other loadfollowing False Biomass WetBiomassElectrostaticPrecipitator0 75.88820041 24.11179959 075.8882 Biomass no 10.039 0.13 -0.091 70.00% 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AFLIPPensacolaPowerBoiler3/EUID33 1MajorSource FL Boiler 347 347 8577 1961 PC loadfollowing TrueCoalCoal VenturiScrubber99.9692341 0 0 099.96923 Coal no 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 8.32E-06 -3.7E-06FLIPPensacolaPowerBoiler4/EUID37 1MajorSource FL Boiler 666 666 8360 1981 Stoker/SlopedGrate/Other Base‐loaded True Biomass WetBiomass VenturiScrubber11.4089608 80.97907581 0 080.97908 Biomass combo 10.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 9.81E-07 3.62E-06FLNorthFloridaLumber 3‐3900‐150 1MajorSource FL Boiler 23 23 8064 1981 Stoker/SlopedGrate/Other loadfollowing False Biomass WetBiomass CycloneorMulticloneData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 10.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AFLNorthFloridaLumber 4‐5700‐01 1MajorSource FL Boiler 42.9 42.9 8400 1979 Stoker/SlopedGrate/Other False Biomass WetBiomass NoHAPAPCDControlData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 10.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AFLRayonierPerformance PB06 1MajorSource FL Boiler 525 525 8592 1983 FB loadfollowing False Biomass WetBiomassWetScrubberElectrostaticPrecipitator0 86.97087675 0 086.97088 Biomass no 10.039 0.048373 -0.00937 19.38% 0.035 0.006428 0.028572 4.6E-06 2.84E-07 4.32E-06FLSmurfit‐Stone 7PB 1MajorSource FL Boiler 1021 1021 8421 1981 PC Base‐loaded FalseCoalCoalElectrostaticPrecipitator100 0 0 0100 Coal no 00.039 0.003237 0.035763 0.035 0.08275 -0.04775 57.70% 4.6E-06 2.99E-06 1.61E-06FLSmurfit‐Stone PowerBoiler#4 1MajorSource FL Boiler 375 375 8760 0 PC FalseCoalCoal VenturiScrubberData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AFLSmurfit‐Stone 5PB 1MajorSource FL Boiler 805 805 8530 1968 Stoker/SlopedGrate/Other Base‐loaded False Biomass DryBiomassElectrostaticPrecipitator0 55.86707367 44.13292633 055.86707 Biomass no 00.039 0.002667 0.036333 0.035 0.006247 0.028753 4.6E-06 2.05E-07 4.4E-06FLSmurfit‐Stone PowerBoiler#3 1MajorSource FL Boiler 375 375 8760 0 Stoker/SlopedGrate/Other False Biomass WetBiomass VenturiScrubberData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 10.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AFLSmurfitStonePanamaCityNo.4CombinationBoiler 1MajorSource FL Boiler 545 545 8760 0 Stoker/SlopedGrate/Other FalseCoalCoal WetScrubberData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AFLSmurfitStonePanamaCityNo.3CombinationBoiler 1MajorSource FL Boiler 505 505 8760 0 Stoker/SlopedGrate/Other False Biomass WetBiomass WetScrubberData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 10.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AGAAbitibiBowater PowerBoiler#1 1MajorSource GA Boiler 275 275 8760 0 Stoker/SlopedGrate/Other False Biomass WetBiomass VenturiScrubberData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 10.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AGACaraustar CB01 1MajorSource GA Boiler 313 313 8592 1982 PC loadfollowing TrueCoalCoal FabricFilter100 0 0 0100 Coal no 00.039 0.074667 -0.03567 47.77% 0.035 0.035267 -0.00027 0.76% 4.6E-06 1.54E-06 3.06E-06GAGPCedarSpringsU501‐PowerBoilerNo2 1MajorSource GA Boiler 784 784 8200 1967 PC loadfollowing TrueCoalCoal VenturiScrubber88.3636364 0 0 088.36364 Coal no 00.039 0.044333 -0.00533 12.03% 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AGAGPCedarSpringsU500‐PowerBoilerNo1 1MajorSource GA Boiler 784 784 8200 1963 Stoker/SlopedGrate/Other loadfollowing True Biomass WetBiomass VenturiScrubber58.6560364 34.20652999 0 058.65604 Coal combo 10.039 0.065667 -0.02667 40.61% 0.035 0.001553 0.033447 4.6E-06 1.42E-06 3.18E-06GAGPCelluloseBrunswickU700‐‐No.4PowerBoiler 1MajorSource GA Boiler 800 800 8568 1961 Stoker/SlopedGrate/Other Standby False Biomass WetBiomassElectrostaticPrecipitator0 78.62667093 5.046531014 078.62667 Biomass no 10.039 0.0054 0.0336 0.035 0.003107 0.031893 4.6E-06 6.05E-07 4E-06GAGPCelluloseBrunswickU707‐‐No.7PowerBoiler 1MajorSource GA Boiler 208 208 2100 2003 N/A Base‐loaded True Liquid LightLiquidElectrostaticPrecipitator0 0 100 00 Biomass no 00.0075 0.005233 0.002267 0.00033 N/A N/A #VALUE! 3.5E-06 N/A N/AGAGPCelluloseBrunswickU706‐‐No.6PowerBoiler 1MajorSource GA Boiler 370 370 8568 1999 N/A Base‐loaded True Liquid LightLiquidElectrostaticPrecipitator0 0 100 00 Biomass no 00.0075 0.008267 -0.00077 9.27% 0.00033 N/A N/A #VALUE! 3.5E-06 N/A N/AGAGPMadisonPly800WoodWasteBoiler 1MajorSource GA Boiler 355 355 8500 1979 Stoker/SlopedGrate/Other loadfollowing False Biomass WetBiomassElectrostaticPrecipitator0 100 0 0100 Biomass no 10.039 0.002667 0.036333 0.035 8.33E-05 0.034917 4.6E-06 5.79E-07 4.02E-06GAGPMonticelloPlywoodEU700‐WoodWasteBoiler 1MajorSource GA Boiler 235.3 235.3 8520 1985 Stoker/SlopedGrate/Other loadfollowing False Biomass WetBiomassElectrostaticPrecipitator0 100 0 0100 Biomass no 10.039 0.012 0.027 0.035 N/A N/A #VALUE! 4.6E-06 5.24E-07 4.08E-06GAGPSRMRiincon EUBO01 1MajorSource GA Boiler 422 422 8400 1986 FB loadfollowing FalseCoalCoalFabricFilterDrySorbentInjection0 0 000 Biomass no 00.039 0.04585 -0.00685 14.94% 0.035 0.003967 0.031033 4.6E-06 1.26E-06 3.34E-06GAGPSRMRiincon EUBO02 1MajorSource GA Boiler 422 422 8400 1990 FB Base‐loaded FalseCoalCoalFabricFilterDrySorbentInjection100 0 0 0100 Coal no 00.039 0.0109 0.0281 0.035 0.006533 0.028467 4.6E-06 5.67E-07 4.03E-06GAGPSRMRiincon EUBO03 1MajorSource GA Boiler 422 422 8400 1995 FB loadfollowing FalseCoalCoalFabricFilterDrySorbentInjectionData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AGAGPWarmSpringsEU600WoodFuelBoiler 1MajorSource GA Boiler 180 180 8520 1974 Stoker/SlopedGrate/Other loadfollowing False Biomass WetBiomass CycloneorMulticlone0 100 0 0100 Biomass no 10.039 0.061 -0.022 36.07% 0.035 0.001199 0.033801 4.6E-06 1.36E-06 3.24E-06GAGPWarrenton400BWoodWasteBoiler 1MajorSource GA Boiler 85.7 85.7 7565 1973 Stoker/SlopedGrate/Other loadfollowing False Biomass DryBiomassElectrostaticPrecipitator0 100 0 0100 Biomass no 00.039 0.035333 0.003667 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AGAGPWoodClaxton 400 1MajorSource GA Boiler 86 86 7000 1973 Stoker/SlopedGrate/Other loadfollowing False Biomass DryBiomassElectrostaticPrecipitator0 100 0 0100 Biomass no 00.039 0.036667 0.002333 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AFacilityID UnitID UnitCountMajorSourceStateClassificatioCapacity(mmCapacity_NumeriHoursPerYearInstalle CombustorDesign DutyCyclewNOxBurneACTFuelCategoBaselineFuelCat TotalControlCoal % Biomass % Liquid % Gas 2 %MaxFuel% Max FuelBiomass/CoalCombo Boiler?WetBiomass? PM LimitPMEmissionsPMDifference PM %red HCL LimitHCLEmissionsHCLDifference HCl%red Hg LimitHgEmissionsHgDifferenceGAGraphicPackaging BarkBoiler#2 1MajorSource GA Boiler 375 375 8760 0 PC FalseCoalCoal VenturiScrubberData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AGAGraphicPackaging PowerBoiler#1 1MajorSource GA Boiler 188 188 8760 0 PC FalseCoalCoal VenturiScrubberData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AGAGraphicPackaging PowerBoiler#2 1MajorSource GA Boiler 188 188 8760 0 PC FalseCoalCoal VenturiScrubberData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AGAInternationalPaperAugustaMills PB2A 1MajorSource GA Boiler 686 686 8600 1965 PC loadfollowing FalseCoalCoalElectrostaticPrecipitator95.0161347 0 0 095.01613 Coal no 00.039 0.0195 0.0195 0.035 0.171333 -0.13633 79.57% 4.6E-06 3.86E-06 7.37E-07GAInternationalPaperAugustaMills PB1A 1MajorSource GA Boiler 680 680 8600 1959 Stoker/SlopedGrate/Other Base‐loaded False Biomass WetBiomass VenturiScrubber66.5223908 29.73588096 0 066.52239 Coal combo 10.039 0.262333 -0.22333 85.13% 0.035 N/A N/A #VALUE! 4.6E-06 1.21E-06 3.39E-06GAInternationalPaperAugustaMills PB3A 1MajorSource GA Boiler 560 560 8600 1989 Stoker/SlopedGrate/Other Base‐loaded False Biomass WetBiomassElectrostaticPrecipitator0 93.75578168 0 093.75578 Biomass no 10.039 0.039 0 0.035 N/A N/A #VALUE! 4.6E-06 6E-07 4E-06GAInterstateResources PowerBoiler#2 1MajorSource GA Boiler 250 250 8760 0 FB False Biomass WetBiomassWetScrubberElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 10.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AGAInterstateResources PowerBoiler#3 1MajorSource GA Boiler 188 188 8760 0 N/A False Liquid HeavyLiquid NoHAPAPCDControlData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.0075 N/A N/A #VALUE! 0.00033 N/A N/A #VALUE! 3.5E-06 N/A N/AGAIPSavannahNo.13PowerBoiler‐PB13 1MajorSource GA Boiler 1280 1280 8506 1982 Stoker/SlopedGrate/Other loadfollowing False Biomass DryBiomassElectrostaticPrecipitator84.5172681 15.48273189 0 084.51727 Coal combo 00.039 0.016 0.023 0.035 0.0145 0.0205 4.6E-06 N/A N/AGALangboardWillacoochee EU24 1MajorSource GA Boiler 185 185 8760 1998 FB Base‐loaded False Biomass WetBiomassElectrostaticPrecipitator0 100 0 0100 Biomass no 10.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AGALouisianaPacificAthens TOHWoodBurner 1MajorSource GAProcessHeater 40 40 8200 2004 DutchOven/Susp.Burner loadfollowing False Biomass DryBiomassElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AGAP&GAlbany B002 1MajorSource GA Boiler 216 216 8277 1981 Stoker/SlopedGrate/Other loadfollowing False Biomass WetBiomassElectrostaticPrecipitator0 0 000 Biomass no 10.039 0.0107 0.0283 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AGAP&GAlbany B001 1MajorSource GA Boiler 187 187 7597 1972 N/A Standby False Liquid LightLiquid NoHAPAPCDControlData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.0075 N/A N/A #VALUE! 0.00033 N/A N/A #VALUE! 3.5E-06 N/A N/AGAPCAValdosta 1006 1MajorSource GA Boiler 243 243 8400 1953 Stoker/SlopedGrate/Other loadfollowing False Biomass WetBiomass VenturiScrubber0 100 0 0100 Biomass no 10.039 0.078417 -0.03942 50.27% 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AGAPCAValdosta 1005 1MajorSource GA Boiler 360 360 8448 1964 Stoker/SlopedGrate/Other loadfollowing False Biomass WetBiomass VenturiScrubber0 100 0 0100 Biomass no 10.039 0.083533 -0.04453 53.31% 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AGARayonierBaxley PB01 1MajorSource GA Boiler 58.74 58.74 8300 1974 Stoker/SlopedGrate/Other loadfollowing False Biomass DryBiomass VenturiScrubber0 100 0 0100 Biomass no 00.039 0.132444 -0.09344 70.55% 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AGARayonierBaxley PB02 1MajorSource GA Boiler 61.54 61.54 8400 1987 Stoker/SlopedGrate/Other Base‐loaded False Biomass DryBiomassElectrostaticPrecipitator0 100 0 0100 Biomass no 00.039 0.015267 0.023733 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AGARayonierJesupMill PB01 1MajorSource GA Boiler 176 176 8352 1954 Stoker/SlopedGrate/Other loadfollowing False Biomass DryBiomass WetScrubber0 97.2825637 2.717436299 097.28256 Biomass no 00.039 0.114333 -0.07533 65.89% 0.035 0.000367 0.034633 4.6E-06 1.19E-06 3.41E-06GARayonierJesupMill PB02 1MajorSource GA Boiler 313 313 8352 1955 Stoker/SlopedGrate/Other loadfollowing False Biomass DryBiomassDryScrubberCycloneorMulticlone0 65.59155381 34.40844619 065.59155 Biomass no 00.039 0.093333 -0.05433 58.21% 0.035 0.002333 0.032667 4.6E-06 N/A N/AGARayonierJesupMill PB03 1MajorSource GA Boiler 612 612 8352 1973 Stoker/SlopedGrate/Other Base‐loaded False Biomass DryBiomass VenturiScrubber0 79.88612095 19.05169589 079.88612 Biomass no 00.039 0.099 -0.06 60.61% 0.035 0.001 0.034 4.6E-06 N/A N/AGARoseburgForestVienna600‐woodfiredboiler 1MajorSource GA Boiler 53.3 53.3 8194 1969 Stoker/SlopedGrate/Other Base‐loaded False Biomass DryBiomass CycloneorMulticlone0 100 0 0100 Biomass no 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 1.9E-06 2.7E-06GASPNewsprint PB1 1MajorSource GA Boiler 249 249 7752 1979 PC loadfollowing FalseCoalCoalElectrostaticPrecipitator100 0 0 0100 Coal no 00.039 0.044333 -0.00533 12.03% 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AGASPNewsprint PB2 1MajorSource GA Boiler 550 550 8496 1989 FB loadfollowing FalseCoalCoalElectrostaticPrecipitator30.0045638 0 50.03171372 030.00456 Coal no 00.039 0.020333 0.018667 0.035 0.027294 0.007706 4.6E-06 2.94E-07 4.31E-06GATempleInlandRome PB4 1MajorSource GA Boiler 565 565 8757 1962 Stoker/SlopedGrate/Other loadfollowing True Biomass WetBiomassElectrostaticPrecipitator0 100 0 0100 Biomass no 10.039 0.003667 0.035333 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AGATempleInlandRome WF 1MajorSource GA Boiler 856 856 8757 2004 FB Base‐loaded False Biomass WetBiomassElectrostaticPrecipitator0 100 0 0100 Biomass no 10.039 0.023867 0.015133 0.035 0.001837 0.033163 4.6E-06 3.57E-07 4.24E-06GATempleInlandThomson BW‐B001 1MajorSource GA Boiler 40 40 6165 1974 DutchOven/Susp.Burner loadfollowing False Biomass DryBiomassElectrostaticPrecipitator0 100 0 0100 Biomass no 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AGATempleInlandThomson Coen 1MajorSource GAProcessHeater 30 30 6165 1997 DutchOven/Susp.Burner loadfollowing False Biomass DryBiomass NoHAPAPCDControlData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AGAWestFraserFolkston FOB2 1MajorSource GA Boiler 29.26 29.26 6680 1996 Stoker/SlopedGrate/Other Base‐loaded False Biomass DryBiomass CycloneorMulticlone0 100 0 0100 Biomass no 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AGAWestFraserFolkston FOB1 1MajorSource GA Boiler 28.5 28.5 6767 1969 Stoker/SlopedGrate/Other Base‐loaded False Biomass DryBiomass CycloneorMulticlone0 100 0 0100 Biomass no 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AGAWeyerhaeuserCoOglethorpePowerBoiler(U400) 1MajorSource GA Boiler 660 660 8400 1980 Stoker/SlopedGrate/Other loadfollowing False Biomass DryBiomass VenturiScrubber0 100 0 0100 Biomass no 00.039 0.044667 -0.00567 12.69% 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AGAWYPortWentworth Power Boiler #4 1 Major SourGA Boiler 375 375 Stoker/SlopedGrate/Other#N/ABiomass Wet Biomass Electrostatic PrecipitatoData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 10.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AIA3MKnoxvilleEPN007‐031Boiler2 1MajorSource IA Boiler 72 72 4340 1974 N/A Base‐loaded False Liquid LightLiquid NoHAPAPCDControl0 0 100 00 Biomass no 00.0075 N/A N/A #VALUE! 0.00033 N/A N/A #VALUE! 3.5E-06 N/A N/AIA3MKnoxvilleEPN007‐030Boiler1 1MajorSource IA Boiler 72 72 5524 1974 N/A Base‐loaded False Liquid LightLiquid NoHAPAPCDControl0 0 100 00 Biomass no 00.0075 N/A N/A #VALUE! 0.00033 N/A N/A #VALUE! 3.5E-06 N/A N/AIAJELD‐WENDubuque WoodFiredBoiler 1MajorSource IA Boiler 86 86 8760 1947 Stoker/SlopedGrate/Other loadfollowing False Biomass DryBiomass CycloneorMulticlone0 100 0 0100 Biomass no 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AIDChilcoLakeSawmill HFB1 1MajorSource ID Boiler 125 125 8500 1977 Stoker/SlopedGrate/Other Base‐loaded False Biomass DryBiomassElectrifiedFilterBed(EFB)0 100 0 0100 Biomass no 00.039 0.02087 0.01813 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AIDMoyieSpringsLumber420 HFB1 1MajorSource ID Boiler 125 125 8500 1972 Stoker/SlopedGrate/Other Base‐loaded False Biomass DryBiomassElectrifiedFilterBed(EFB)0 100 0 0100 Biomass no 00.039 0.028986 0.010014 0.035 0.000383 0.034617 4.6E-06 1.02E-06 3.58E-06IDPotlatch PB‐1CE 1MajorSource ID Boiler 27.6 27.6 8544 1964 FuelCell loadfollowing False Biomass DryBiomassElectrostaticPrecipitator0 100 0 0100 Biomass no 00.039 0.005867 0.033133 0.035 2.83E-05 0.034972 4.6E-06 8.8E-07 3.72E-06IDPotlatch PB‐2Riley 1MajorSource ID Boiler 92 92 8544 1966 Stoker/SlopedGrate/Other loadfollowing False Biomass DryBiomassElectrostaticPrecipitator0 100 0 0100 Biomass no 00.039 0.003433 0.035567 0.035 N/A N/A #VALUE! 4.6E-06 9.17E-07 3.68E-06IDPotlatch PB‐3Hurst 1MajorSource ID Boiler 39.675 39.675 8640 1987 Stoker/SlopedGrate/Other loadfollowing False Biomass DryBiomassElectrostaticPrecipitator0 100 0 0100 Biomass no 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 8.5E-07 3.75E-06IDRileyCreekLumber HFB1 1MajorSource ID Boiler 70.23 70.23 8500 1976 Stoker/SlopedGrate/Other Base‐loaded False Biomass DryBiomassElectrostaticPrecipitator0 100 0 0100 Biomass no 00.039 0.002112 0.036888 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AIDRileyCreekLumber HFB2 1MajorSource ID Boiler 67.69 67.69 8500 1975 Stoker/SlopedGrate/Other Base‐loaded False Biomass DryBiomassElectrostaticPrecipitator0 100 0 0100 Biomass no 00.039 0.045012 -0.00601 13.36% 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AINJasperSeating9Wood‐FiredBoilerB1 1MajorSource IN Boiler 10.5 10.5 8760 1968 Stoker/SlopedGrate/Other False Biomass DryBiomass NoHAPAPCDControlData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AFacilityID UnitID UnitCountMajorSourceStateClassificatioCapacity(mmCapacity_NumeriHoursPerYearInstalle CombustorDesign DutyCyclewNOxBurneACTFuelCategoBaselineFuelCat TotalControlCoal % Biomass % Liquid % Gas 2 %MaxFuel% Max FuelBiomass/CoalCombo Boiler?WetBiomass? PM LimitPMEmissionsPMDifference PM %red HCL LimitHCLEmissionsHCLDifference HCl%red Hg LimitHgEmissionsHgDifferenceINKimballOfficeJasper B‐1A 1MajorSource IN Boiler 20.5 20.5 3500 1995 Stoker/SlopedGrate/Other Base‐loaded False Biomass DryBiomass CycloneorMulticloneData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AINKimballOfficeSalem Boiler1 1MajorSource IN Boiler 39.5 39.5 4000 1986 Stoker/SlopedGrate/Other loadfollowing FalseCoalCoal CycloneorMulticloneData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AINKimballOfficeSalem Boiler2 1MajorSource IN Boiler 39.5 39.5 4000 1986 Stoker/SlopedGrate/Other loadfollowing FalseCoalCoal CycloneorMulticloneData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AINNOFJasper Boiler3 1MajorSource IN Boiler 20.978 20.978 3500 1981 Stoker/SlopedGrate/Other loadfollowing FalseCoalCoal CycloneorMulticloneData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AINNOFJasper Boiler1 1MajorSource IN Boiler 10.487 10.487 3500 1977 Stoker/SlopedGrate/Other loadfollowing False Biomass DryBiomass NoHAPAPCDControlData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AINNOFJasper Boiler2 1MajorSource IN Boiler 10.487 10.487 3500 1978 Stoker/SlopedGrate/Other loadfollowing False Biomass DryBiomass NoHAPAPCDControlData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AKYDomtarHawesvilleBiofuelBoilerB‐900 1MajorSource KY Boiler 1050 1050 8400 1997 FB loadfollowing True Biomass DryBiomassElectrostaticPrecipitator0 84.7460045 0 084.746 Biomass no 00.039 0.004467 0.034533 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AKYHONCoOwensboro EP01 1MajorSource KY Boiler108.045884716157 108.0458847 5760 1980 Stoker/SlopedGrate/Other loadfollowing False Biomass DryBiomass NoHAPAPCDControlData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AKYNewPage‐Wickliffe B09 1MajorSource KY Boiler 631 631 8433 1979 Stoker/SlopedGrate/Other loadfollowing False Biomass WetBiomassElectrostaticPrecipitator0 87.17182666 0 087.17183 Biomass no 10.039 0.009633 0.029367 0.035 0.001683 0.033317 4.6E-06 6E-07 0.000004KYWeyerhaeuserEKY MP01‐01 1MajorSource KYProcessHeater 75 75 5458 1994 FuelCell loadfollowing False Biomass DryBiomassElectrostaticPrecipitator0 80.6352618 0 080.63526 Biomass no 00.039 0.052 -0.013 25.00% 0.035 0.01383 0.02117 4.6E-06 N/A N/AKYWeyerhaeuserEKY MP01‐02 1MajorSource KYProcessHeater 75 75 5458 1994 FuelCell loadfollowing False Biomass DryBiomassElectrostaticPrecipitator0 74.18034906 0 074.18035 Biomass no 00.039 0.052 -0.013 25.00% 0.035 0.01383 0.02117 4.6E-06 N/A N/AKYWeyerhaeuserEKY MP01‐03 1MajorSource KYProcessHeater 75 75 5458 1994 FuelCell loadfollowing False Biomass DryBiomassElectrostaticPrecipitator0 84.56775423 0 084.56775 Biomass no 00.039 0.052 -0.013 25.00% 0.035 0.01383 0.02117 4.6E-06 N/A N/ALABoiseCascadeFlorien B‐1 1MajorSource LA Boiler 138 138 8592 1981 Stoker/SlopedGrate/Other loadfollowing False Biomass DryBiomass WetScrubber0 100 0 0100 Biomass no 00.039 0.230618 -0.19162 83.09% 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/ALABoiseCascadeOakdale B‐1 1MajorSource LA Boiler 138 138 8592 1977 Stoker/SlopedGrate/Other loadfollowing False Biomass DryBiomass CycloneorMulticlone0 100 0 0100 Biomass no 00.039 0.038681 0.000319 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/ALABoiseNewsprintDeRidder 69‐03 1MajorSource LA Boiler 1591.3 1591.3 8400 1969 Stoker/SlopedGrate/Other Base‐loaded False Biomass WetBiomass VenturiScrubber0 70.52097331 5.357175702 070.52097 Biomass no 10.039 0.113 -0.074 65.49% 0.035 1.76E-05 0.034982 4.6E-06 1.84E-07 4.42E-06LABoiseNewsprintDeRidder 79‐01 1MajorSource LA Boiler 454.29 454.29 8400 1979 Stoker/SlopedGrate/Other Base‐loaded False Biomass WetBiomass VenturiScrubber0 78.79034704 0 078.79035 Biomass no 10.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/ALAGPLogansportPly EQT‐0009 1MajorSource LA Boiler 222 222 8760 1977 Stoker/SlopedGrate/Other loadfollowing False Biomass WetBiomass WetScrubber0 100 0 0100 Biomass no 10.039 0.1658 -0.1268 76.48% 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/ALAGPPortHudsonEQT0099CombinationBoilerNo.1 1MajorSource LA Boiler 459.2 459.2 5728 1969 Stoker/SlopedGrate/Other Base‐loaded True Biomass WetBiomass VenturiScrubber0 94.26277582 0 094.26278 Biomass no 10.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/ALAGPPortHudsonEQT0109‐No.6CFBBoiler 1MajorSource LA Boiler 1205 1205 8400 2006 FB loadfollowing True Biomass WetBiomassDryScrubberLimestoneInjectionElectrostatic83.0112489 13.93135275 3.057398327 083.01125 Coal combo 10.039 0.010007 0.028993 0.035 0.0007 0.0343 4.6E-06 N/A N/ALAGPSpringhillWood01‐79WoodwasteFiredBoiler 1MajorSource LA Boiler 208.8 208.8 8400 1979 Stoker/SlopedGrate/Other loadfollowing True Biomass DryBiomass WetScrubber0 100 0 0100 Biomass no 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/ALAGraphicPackaging BarkBoiler 1MajorSource LA Boiler 750 750 8760 Stoker/SlopedGrate/Other #N/A False Biomass WetBiomass VenturiScrubberData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 10.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/ALAHoodIndustriesEQT001(wood‐firedboilerNo.1) 1MajorSource LA Boiler 62.4 62.4 8400 1976 Stoker/SlopedGrate/Other loadfollowing False Biomass WetBiomass CycloneorMulticlone0 100 0 0100 Biomass no 10.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/ALAHoodIndustriesEQT002(wood‐firedboilerNo.2) 1MajorSource LA Boiler 62.4 62.4 8400 1981 Stoker/SlopedGrate/Other loadfollowing False Biomass WetBiomass CycloneorMulticlone0 100 0 0100 Biomass no 10.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/ALAHuntNatalbany EQT0001 1MajorSource LA Boiler 92.3 92.3 8592 1980 Stoker/SlopedGrate/Other loadfollowing False Biomass WetBiomass CycloneorMulticlone0 100 0 0100 Biomass no 10.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/ALAHuntPollock EQT0005 1MajorSource LA Boiler 61.5 61.5 8592 1989 Stoker/SlopedGrate/Other loadfollowing False Biomass WetBiomass CycloneorMulticlone0 100 0 0100 Biomass no 10.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/ALAHuntPollock EQT0017 1MajorSource LA Boiler 80 80 8592 1979 Stoker/SlopedGrate/Other loadfollowing False Biomass WetBiomass CycloneorMulticlone0 0 000 Biomass no 10.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/ALAInternationalPaperRedRiverMillEQT011 HoggedFuel Boiler No. 2 1MajorSource LA Boiler 940940Stoker/SlopedGrate/Other#N/ABiomass Wet BiomassElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 10.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/ALAIPMansfield1-78 - No. 1 PowerBoiler / EQT005 1MajorSource LA Boiler 760760Stoker/SlopedGrate/Other#N/ACoal CoalElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/ALAIPMansfield2-78 - No. 2 PowerBoiler 1MajorSource LA Boiler 760760Stoker/SlopedGrate/Other#N/ACoal CoalElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 N/A N/A #VALUE! 0.035 0.002653 0.032347 4.6E-06 3.88E-08 4.56E-06LASmurfit‐Stone PowerBoiler#2 1MajorSource LA Boiler 750 750 8760 0 Stoker/SlopedGrate/Other False Biomass WetBiomass CycloneorMulticloneData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 10.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/ALATempleInlandBogalusa No.10CBoiler 1MajorSource LA Boiler 494.4 494.4 8600 0 Stoker/SlopedGrate/Other False Biomass WetBiomass WetScrubberData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 10.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/ALATempleInlandBogalusa No.12Boiler 1MajorSource LA Boiler 787.5 787.5 8600 0 Stoker/SlopedGrate/Other False Biomass WetBiomass WetScrubberData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 10.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/ALAWestFraserJoyce 74B 1MajorSource LA Boiler 58.3 58.3 6800 1973 Stoker/SlopedGrate/Other loadfollowing False Biomass WetBiomass CycloneorMulticlone0 100 0 0100 Biomass no 10.039 0.6 -0.561 93.50% 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/ALAWestFraserJoyce 74A 1MajorSource LA Boiler 58.3 58.3 7550 1973 Stoker/SlopedGrate/Other loadfollowing False Biomass WetBiomass CycloneorMulticlone0 100 0 0100 Biomass no 10.039 0.399 -0.36 90.23% 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/ALAWestFraserJoyce 75A 1MajorSource LA Boiler 154.2 154.2 8000 1973 Stoker/SlopedGrate/Other loadfollowing False Biomass WetBiomass CycloneorMulticlone0 100 0 0100 Biomass no 10.039 0.618333 -0.57933 93.69% 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/ALAWeyerhaeuser1043 EQT‐0010 1MajorSource LA Boiler 100 100 8400 1974 Stoker/SlopedGrate/Other loadfollowing False Biomass DryBiomassElectrostaticPrecipitator0 100 0 0100 Biomass no 00.039 0.030146 0.008854 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/ALAWeyerhaeuserDodson ES‐017WFB 1MajorSource LA Boiler 233 233 8200 1996 Stoker/SlopedGrate/Other loadfollowing False Biomass DryBiomassElectrostaticPrecipitator0 100 0 0100 Biomass no 00.039 0.019 0.02 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AMAHollingsworth&vose Boiler#1 1MajorSource MA Boiler 49.5 49.5 8400 1988 N/A Base‐loaded False Liquid HeavyLiquid NoHAPAPCDControlData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.0075 N/A N/A #VALUE! 0.00033 N/A N/A #VALUE! 3.5E-06 N/A N/AMAMWCustomPapers #1Boiler 1MajorSource MA Boiler 37.5 37.5 8760 0 N/A False Liquid HeavyLiquid NoHAPAPCDControlData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.0075 N/A N/A #VALUE! 0.00033 N/A N/A #VALUE! 3.5E-06 N/A N/AMAMWCustomPapers #2Boiler 1MajorSource MA Boiler 48 48 8760 0 N/A False Liquid HeavyLiquid NoHAPAPCDControlData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.0075 N/A N/A #VALUE! 0.00033 N/A N/A #VALUE! 3.5E-06 N/A N/AMANewarkAmerica Boiler#2 1MajorSource MA Boiler 230 230 7500 2000 N/A loadfollowing True Liquid LightLiquid NoHAPAPCDControl0 0 000 Biomass no 00.0075 0.0025 0.005 0.00033 N/A N/A #VALUE! 3.5E-06 N/A N/AMDNewPage‐Luke No.24 1MajorSource MD Boiler 590 590 8616 1959 Stoker/SlopedGrate/Other Base‐loaded FalseCoalCoal FabricFilter99.0811881 0 0.91881192 099.08119 Coal no 00.039 0.0174 0.0216 0.035 N/A N/A #VALUE! 4.6E-06 1.97E-05 -1.5E-05FacilityID UnitID UnitCountMajorSourceStateClassificatioCapacity(mmCapacity_NumeriHoursPerYearInstalle CombustorDesign DutyCyclewNOxBurneACTFuelCategoBaselineFuelCat TotalControlCoal % Biomass % Liquid % Gas 2 %MaxFuel% Max FuelBiomass/CoalCombo Boiler?WetBiomass? PM LimitPMEmissionsPMDifference PM %red HCL LimitHCLEmissionsHCLDifference HCl%red Hg LimitHgEmissionsHgDifferenceMDNewPage‐Luke No.25 1MajorSource MD Boiler 785 785 8640 1965 PC loadfollowing TrueCoalCoal FabricFilter100 0 0 0100 Coal no 00.039 0.012567 0.026433 0.035 0.032333 0.002667 4.6E-06 5.21E-06 -6.1E-07MEDomtarBaileyville #9PowerBoiler 1MajorSource ME Boiler 625 625 8644 1971 Stoker/SlopedGrate/Other loadfollowing False Biomass DryBiomass VenturiScrubber0 0 000 Biomass no 00.039 0.15 -0.111 74.00% 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AMEHuberEngineeredWoodLLC Boiler No.1 1MajorSource ME Boiler 8484Stoker/SlopedGrate/Other#N/ABiomass Dry BiomassElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AMEKatahdinPaperCo EB1 1MajorSource ME Boiler 370 370 4500 1953 N/A loadfollowing True Liquid HeavyLiquid NoHAPAPCDControlData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.0075 N/A N/A #VALUE! 0.00033 N/A N/A #VALUE! 3.5E-06 N/A N/AMEKatahdinPaperCo EB2 1MajorSource ME Boiler 370 370 4500 1953 N/A loadfollowing True Liquid HeavyLiquid NoHAPAPCDControlData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.0075 N/A N/A #VALUE! 0.00033 N/A N/A #VALUE! 3.5E-06 N/A N/AMEKatahdinPaperCo EB3 1MajorSource ME Boiler 498 498 8300 1980 Stoker/SlopedGrate/Other Base‐loaded True Biomass WetBiomassElectrostaticPrecipitator0 0 000 Biomass no 10.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AMELincolnPaper&Tissue #8PowerBoiler 1MajorSource ME Boiler 433 433 8600 1991 Stoker/SlopedGrate/Other loadfollowing False Biomass WetBiomassElectrostaticPrecipitator0 89.56851608 10.36406801 089.56852 Biomass no 10.039 N/A N/A #VALUE! 0.035 0.003203 0.031797 4.6E-06 9.09E-07 3.69E-06MELincolnPaper&Tissue#7TissueMachineDryer 1MajorSource MEProcessHeater 14.976 14.976 8400 1978 N/A False Liquid LightLiquid NoHAPAPCDControlData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.0075 N/A N/A #VALUE! 0.00033 N/A N/A #VALUE! 3.5E-06 N/A N/AMEMadisonPaper #7BoilerME6737 1MajorSource ME Boiler 117 117 5150 1991 N/A Base‐loaded True Liquid HeavyLiquid NoHAPAPCDControl0 0 100 00 Biomass no 00.0075 N/A N/A #VALUE! 0.00033 N/A N/A #VALUE! 3.5E-06 N/A N/AMEMadisonPaper #6BoilerME6454 1MajorSource ME Boiler 99 99 8250 1980 N/A loadfollowing True Liquid HeavyLiquid SprayDryer0 0 100 00 Biomass no 00.0075 N/A N/A #VALUE! 0.00033 N/A N/A #VALUE! 3.5E-06 N/A N/AMEMadisonPaper #4BoilerME5949 1MajorSource ME Boiler 119 119 8450 1968 N/A loadfollowing True Liquid HeavyLiquid SprayDryer0 0 100 00 Biomass no 00.0075 N/A N/A #VALUE! 0.00033 N/A N/A #VALUE! 3.5E-06 N/A N/AMENewPage‐Rumford Cogen#6 1MajorSource ME Boiler 630 630 8000 1990 FB Base‐loaded False Biomass DryBiomassDrySorbentInjectionElectrostaticPrecipitator12.2049719 57.43989926 3.195629338 057.4399 Biomass combo 00.039 0.001475 0.037525 0.035 0.011839 0.023161 4.6E-06 8.22E-07 3.78E-06MENewPage‐Rumford PB#3 1MajorSource ME Boiler 300 300 1900 1948 N/A Standby True Liquid HeavyLiquid VenturiScrubber0 0 73.19148936 00 Biomass no 00.0075 0.02 -0.0125 62.50% 0.00033 N/A N/A #VALUE! 3.5E-06 N/A N/AMENewPage‐Rumford Cogen#7 1MajorSource ME Boiler 630 630 8000 1990 FB Base‐loaded False Biomass DryBiomassDrySorbentInjectionElectrostaticPrecipitator12.1239147 57.49813574 3.199404525 057.49814 Biomass combo 00.039 0.001475 0.037525 0.035 0.013607 0.021393 4.6E-06 8.22E-07 3.78E-06MERedShieldRiley Boiler 1 Major SourME Boiler 188 188 Stoker/SlopedGrate/Other#N/ABiomass Wet Biomass Electrostatic PrecipitatoData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 10.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AMERedShield PowerBoiler#5 1MajorSource ME Boiler 250 250 8760 0 N/A False Liquid HeavyLiquid NoHAPAPCDControlData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.0075 N/A N/A #VALUE! 0.00033 N/A N/A #VALUE! 3.5E-06 N/A N/AMESappiWestbrook Power Boiler #20 1 Major SourME Boiler 188 188 N/A#N/ALiquid Heavy LiquidNo HAP APCDControlData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.0075 N/A N/A #VALUE! 0.00033 N/A N/A #VALUE! 3.5E-06 N/A N/AMESappiWestbrook Power Boiler #17 1 Major SourME Boiler 213 213 N/A#N/ALiquid Heavy LiquidNo HAP APCDControlData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.0075 N/A N/A #VALUE! 0.00033 N/A N/A #VALUE! 3.5E-06 N/A N/AMESappiWestbrook Power Boiler #18 1 Major SourME Boiler 213 213 N/A#N/ALiquid Heavy LiquidNo HAP APCDControlData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.0075 N/A N/A #VALUE! 0.00033 N/A N/A #VALUE! 3.5E-06 N/A N/AMESappiWestbrook Power Boiler #21 1 Major SourME Boiler 844 844 PC#N/ACoal Coal Electrostatic PrecipitatoData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AMESDWarren #21Boiler 1MajorSource ME Boiler 1074 1074 8440 1981 Stoker/SlopedGrate/Other loadfollowing True Biomass DryBiomassElectrostaticPrecipitator28.6138666 67.60790872 1.081996092 067.60791 Biomass combo 00.039 0.029667 0.009333 0.035 0.011333 0.023667 4.6E-06 1.11E-07 4.49E-06MESDWarren PowerBoiler#20 1MajorSource ME Boiler 188 188 8760 0 N/A False Liquid HeavyLiquid NoHAPAPCDControlData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.0075 N/A N/A #VALUE! 0.00033 N/A N/A #VALUE! 3.5E-06 N/A N/AMESDWarrenSomerset No1PowerBoiler 1MajorSource ME Boiler 848 848 8375 1975 Stoker/SlopedGrate/Other Base‐loaded False Biomass WetBiomassElectrostaticPrecipitator0 92.01078652 7.989213478 092.01079 Biomass no 10.039 0.0225 0.0165 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AMESDWarrenSomerset No2PowerBoiler 1MajorSource ME Boiler 1300 1300 8533 1989 Stoker/SlopedGrate/Other Base‐loaded False Biomass WetBiomassDryScrubberElectrostaticPrecipitator0 62.4595014 29.93520612 062.4595 Biomass no 10.039 0.01187 0.02713 0.035 0.000229 0.034771 4.6E-06 5.78E-07 4.02E-06MEVersoPaper Boiler#8 1MajorSource ME Boiler 814 814 8400 1984 Stoker/SlopedGrate/Other Base‐loaded True Biomass DryBiomassElectrostaticPrecipitator14.5458823 46.62256337 29.33682042 046.62256 Biomass combo 00.039 0.012 0.027 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AMEVersoPaper Boiler#5 1MajorSource ME Boiler 371 371 1300 1966 N/A Standby True Liquid HeavyLiquid NoHAPAPCDControlData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.0075 N/A N/A #VALUE! 0.00033 N/A N/A #VALUE! 3.5E-06 N/A N/AMEVersoPaperAndroscoggin WFI 1MajorSource ME Boiler 480 480 8400 1976 Stoker/SlopedGrate/Other Base‐loaded False Biomass WetBiomass VenturiScrubber0 87.19900338 12.80099662 087.199 Biomass no 10.039 0.092 -0.053 57.61% 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AMIDecorativePanels Boiler#1 1MajorSource MI Boiler 96 96 8000 1957 Stoker/SlopedGrate/Other loadfollowing TrueCoalCoalElectrostaticPrecipitator0 0 000 Biomass no 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AMIDecorativePanels Boiler#2 1MajorSource MI Boiler 96 96 8000 1957 Stoker/SlopedGrate/Other TrueCoalCoalElectrostaticPrecipitator0 0 000 Biomass no 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AMIDecorativePanels Boiler#3 1MajorSource MI Boiler 79 79 8000 1962 Stoker/SlopedGrate/Other loadfollowing True Biomass DryBiomass CycloneorMulticlone0 0 000 Biomass no 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AMIEBEddyPaper EUBOILER5 1MajorSource MI Boiler 196 196 8500 1969 PC loadfollowing FalseCoalCoalElectrostaticPrecipitator0 0 000 Biomass no 00.039 N/A N/A #VALUE! 0.035 0.115 -0.08 69.57% 4.6E-06 7.43E-06 -2.8E-06MILPCSagola TOH‐Wood 1MajorSource MIProcessHeater 60 60 8400 1987 Stoker/SlopedGrate/Other loadfollowing False Biomass WetBiomassDryElectrostaticGranularFilter0 100 0 0100 Biomass no 10.039 0.289894 -0.25089 86.55% 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AMIManistiquePaper EUBLR001 1MajorSource MI Boiler 1047.795 1047.795 8616 1964 Stoker/SlopedGrate/Other loadfollowing FalseCoalCoalElectrostaticPrecipitator100 0 0 0100 Coal no 00.039 0.025564 0.013436 0.035 0.11 -0.075 68.18% 4.6E-06 3.37E-06 1.23E-06MIManistiquePaper EUBLR002 1MajorSource MI Boiler 739.62 739.62 8616 1977 Stoker/SlopedGrate/Other loadfollowing FalseCoalCoalElectrostaticPrecipitator100 0 0 0100 Coal no 00.039 0.025564 0.013436 0.035 0.11 -0.075 68.18% 4.6E-06 3.37E-06 1.23E-06MIMenominee #5Boiler 1MajorSource MI Boiler 81.8 81.8 8400 1950 Stoker/SlopedGrate/Other Standby FalseCoalCoal FabricFilter100 0 0 0100 Coal no 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AMIMenominee #3Boiler 1MajorSource MI Boiler 101 101 8544 1962 Stoker/SlopedGrate/Other loadfollowing FalseCoalCoal FabricFilter100 0 0 0100 Coal no 00.039 N/A N/A #VALUE! 0.035 0.151 -0.116 76.82% 4.6E-06 6.6E-06 -2E-06MINeenahPaperMI Boiler1 1MajorSource MI Boiler 202 202 8520 1958 Stoker/SlopedGrate/Other Base‐loaded FalseCoalCoal FabricFilter100 0 0 0100 Coal no 00.039 0.009033 0.029967 0.035 0.145256 -0.11026 75.90% 4.6E-06 8.78E-07 3.72E-06MINewPageEscanaba PowerBoiler#11 1MajorSource MI Boiler 938 938 8760 1981 PC FalseCoalCoalElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AMINewPageEscanaba PowerBoiler#7 1MajorSource MI Boiler 154 154 8760 1947 N/A False Liquid HeavyLiquid NoHAPAPCDControlData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.0075 N/A N/A #VALUE! 0.00033 N/A N/A #VALUE! 3.5E-06 N/A N/AMINewPageEscanaba PowerBoiler#8 1MajorSource MI Boiler 563 563 8760 1968 N/A False Liquid HeavyLiquid NoHAPAPCDControlData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.0075 N/A N/A #VALUE! 0.00033 N/A N/A #VALUE! 3.5E-06 N/A N/AMINewPageEscanaba PowerBoiler#9 1MajorSource MI Boiler 563 563 8760 1972 Stoker/SlopedGrate/Other False Biomass WetBiomass WetScrubberData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 10.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AMIPackagingCorpofAmerica EUBOILER1 1MajorSource MI Boiler 240 240 8712 1950 PC loadfollowing FalseCoalCoal FabricFilterData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AFacilityID UnitID UnitCountMajorSourceStateClassificatioCapacity(mmCapacity_NumeriHoursPerYearInstalle CombustorDesign DutyCyclewNOxBurneACTFuelCategoBaselineFuelCat TotalControlCoal % Biomass % Liquid % Gas 2 %MaxFuel% Max FuelBiomass/CoalCombo Boiler?WetBiomass? PM LimitPMEmissionsPMDifference PM %red HCL LimitHCLEmissionsHCLDifference HCl%red Hg LimitHgEmissionsHgDifferenceMISmurfitStoneOntonagon No.1RileyBoiler 1MajorSource MI Boiler 375 375 8200 PC #N/A TrueCoalCoalFurnaceSorbentInjectionElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AMIVersoPaperQuinnesec WasteFuelBoiler 1MajorSource MI Boiler 624 624 8589 1981 Stoker/SlopedGrate/Other loadfollowing True Biomass WetBiomassElectrostaticPrecipitator0 0 000 Biomass no 10.039 0.0063 0.0327 0.035 0.002533 0.032467 4.6E-06 1.33E-08 4.59E-06MN3MHutchinson EU002‐Boiler4 1MajorSource MN Boiler 110 110 3500 1967 N/A Base‐loaded False Liquid HeavyLiquid NoHAPAPCDControlData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.0075 N/A N/A #VALUE! 0.00033 N/A N/A #VALUE! 3.5E-06 N/A N/AMN3MHutchinson EU001‐Boiler3 1MajorSource MN Boiler 110 110 5000 1967 N/A Base‐loaded False Liquid HeavyLiquid NoHAPAPCDControlData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.0075 N/A N/A #VALUE! 0.00033 N/A N/A #VALUE! 3.5E-06 N/A N/AMNAndersonCorpBayport Boiler11EU620 1MajorSource MN Boiler 52 52 7008 2006 Stoker/SlopedGrate/Other Base‐loaded True Biomass DryBiomassElectrostaticPrecipitator0 80.63403738 0 080.63404 Biomass no 00.039 0.003978 0.035022 0.035 0.0004 0.0346 4.6E-06 N/A N/AMNAndersonCorpBayport Boiler12EU621 1MajorSource MN Boiler 52 52 7008 2006 Stoker/SlopedGrate/Other Base‐loaded True Biomass DryBiomassElectrostaticPrecipitator0 80.63403738 0 080.63404 Biomass no 00.039 0.003978 0.035022 0.035 0.0004 0.0346 4.6E-06 N/A N/AMNBoisePaper1212 EU430Boiler#2 1MajorSource MN Boiler 395 395 8350 1956 Stoker/SlopedGrate/Other loadfollowing True Biomass WetBiomassElectrostaticPrecipitator0 92.33629867 7.663701327 092.3363 Biomass no 10.039 0.00188 0.03712 0.035 N/A N/A #VALUE! 4.6E-06 1.34E-06 3.26E-06MNGPDuluth EU31Boiler#1 1MajorSource MN Boiler 43 43 8400 1971 N/A loadfollowing False Liquid HeavyLiquid NoHAPAPCDControlData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.0075 N/A N/A #VALUE! 0.00033 N/A N/A #VALUE! 3.5E-06 N/A N/AMNGPDuluth EU32Boiler#2 1MajorSource MN Boiler 43 43 8400 1971 N/A loadfollowing False Liquid HeavyLiquid NoHAPAPCDControlData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.0075 N/A N/A #VALUE! 0.00033 N/A N/A #VALUE! 3.5E-06 N/A N/AMNGPDuluth EU34Boiler#4 1MajorSource MN Boiler 60 60 8400 1974 DutchOven/Susp.Burner Base‐loaded False Biomass DryBiomassElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AMNGPDuluth EU35Boiler#5 1MajorSource MN Boiler 17 17 8400 1975 Stoker/SlopedGrate/Other Base‐loaded False Biomass WetBiomassElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 10.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AMNGPDuluth EU33Boiler#3 1MajorSource MN Boiler 43 43 8400 1971 N/A loadfollowing False Liquid HeavyLiquidElectrostaticPrecipitator0 0 100 00 Biomass no 00.0075 0.011017 -0.00352 31.92% 0.00033 0.000742 -0.00041 55.53% 3.5E-06 1.05E-07 3.4E-06MNNorbordMinnesota KonusNo.1 1MajorSource MNProcessHeater 20 20 8200 1980 DutchOven/Susp.Burner Base‐loaded False Biomass WetBiomassCycloneorMulticlone/ElectrifiedFilterBed(EFB)0 100 0 0100 Biomass no 10.039 0.114 -0.075 65.79% 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AMNNorbordMinnesota KonusNo.2 1MajorSource MNProcessHeater 20 20 8200 1980 DutchOven/Susp.Burner Base‐loaded False Biomass WetBiomassCycloneorMulticlone/ElectrifiedFilterBed(EFB)0 100 0 0100 Biomass no 10.039 0.114 -0.075 65.79% 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AMNSappiCloquet EU002 1MajorSource MN Boiler 300 300 8363 1965 Stoker/SlopedGrate/Other Base‐loaded False Biomass WetBiomassElectrostaticPrecipitator0 0 000 Biomass no 10.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 4.48E-07 4.15E-06MNSappiCloquet EU004 1MajorSource MN Boiler 430 430 8532 1980 Stoker/SlopedGrate/Other Base‐loaded False Biomass WetBiomassElectrostaticPrecipitator0 0 000 Biomass no 10.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 7.2E-07 3.88E-06MNVersoPaper EU018Bros 1MajorSource MN Boiler 119 119 3700 1934 Stoker/SlopedGrate/Other Base‐loaded FalseCoalCoal VenturiScrubber100 0 0 0100 Coal no 00.039 0.05 -0.011 22.00% 0.035 N/A N/A #VALUE! 4.6E-06 2.81E-05 -2.3E-05MNVersoPaper EU006B&W 1MajorSource MN Boiler 368 368 8520 1981 Stoker/SlopedGrate/Other loadfollowing False Biomass WetBiomass VenturiScrubber70.5864405 20.18134521 2.334740365 070.58644 Coal combo 10.039 0.046333 -0.00733 15.83% 0.035 0.0033 0.0317 4.6E-06 3.88E-07 4.21E-06MNWausauPaper‐Brainerd EU002 1MajorSource MN Boiler 54 54 2100 1945 Stoker/SlopedGrate/Other loadfollowing FalseCoalCoalElectrostaticPrecipitator100 0 0 0100 Coal no 00.039 0.017778 0.021222 0.035 0.081441 -0.04644 57.02% 4.6E-06 1.72E-06 2.88E-06MNWausauPaper‐Brainerd EU003 1MajorSource MN Boiler 107 107 8400 1958 Stoker/SlopedGrate/Other loadfollowing FalseCoalCoalElectrostaticPrecipitator0 0 000 Biomass no 00.039 0.031667 0.007333 0.035 0.080514 -0.04551 56.53% 4.6E-06 1.72E-06 2.88E-06MNWausauPaper‐Brainerd EU004 1MajorSource MN Boiler 107 107 8400 1958 Stoker/SlopedGrate/Other loadfollowing FalseCoalCoalElectrostaticPrecipitator0 0 000 Biomass no 00.039 0.016167 0.022833 0.035 0.103362 -0.06836 66.14% 4.6E-06 3.67E-06 9.33E-07MNWeyerhaeuserIrontonEU001‐4CellFurnace 1MajorSource MNProcessHeater 225 225 8114 1990 Stoker/SlopedGrate/Other loadfollowing False Biomass DryBiomassElectrostaticPrecipitator0 100 0 0100 Biomass no 00.039 0.028662 0.010338 0.035 0.0033 0.0317 4.6E-06 N/A N/AMSBowaterSouth BarkBoiler 1MajorSource MS Boiler 234 234 8600 1989 Stoker/SlopedGrate/Other loadfollowing False Biomass WetBiomass VenturiScrubber0 92.99788788 3.76048334 092.99789 Biomass no 10.039 0.026 0.013 0.035 0.000333 0.034667 4.6E-06 4.72E-07 4.13E-06MSGeorgiaPacificMonticelloAA‐403(UT‐3)CombinationBoiler 1MajorSource MS Boiler 917 917 8400 1967 Stoker/SlopedGrate/Other Base‐loaded True Biomass WetBiomassElectrostaticPrecipitator0 94.19760252 0.046687697 094.1976 Biomass no 10.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AMSGPBaySpringsAA‐001(BoilerNo.1) 1MajorSource MS Boiler 73 73 7811 1972 Stoker/SlopedGrate/Other False Biomass DryBiomassElectrostaticPrecipitator0 100 0 0100 Biomass no 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AMSGPBaySpringsAA‐003(BoilerNo.2) 1MajorSource MS Boiler 59.42 59.42 7811 1990 Stoker/SlopedGrate/Other loadfollowing False Biomass DryBiomassElectrostaticPrecipitator0 100 0 0100 Biomass no 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AMSGPGlosterPly AA‐002 1MajorSource MS Boiler 48 48 7875 1966 Stoker/SlopedGrate/Other loadfollowing False Biomass DryBiomass CycloneorMulticlone0 100 0 0100 Biomass no 00.039 0.220667 -0.18167 82.33% 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AMSGPGlosterPly AA‐001 1MajorSource MS Boiler 48 48 7881 1966 Stoker/SlopedGrate/Other loadfollowing False Biomass DryBiomass CycloneorMulticlone0 100 0 0100 Biomass no 00.039 0.261333 -0.22233 85.08% 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AMSGPGlosterPly AA‐003 1MajorSource MS Boiler 98 98 7883 1967 Stoker/SlopedGrate/Other loadfollowing False Biomass DryBiomass CycloneorMulticlone0 100 0 0100 Biomass no 00.039 0.299 -0.26 86.96% 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AMSGPLouisvillePly AD‐003(Boiler#3) 1MajorSource MS Boiler 124 124 8343 1978 Stoker/SlopedGrate/Other loadfollowing False Biomass DryBiomassElectrostaticPrecipitator0 100 0 0100 Biomass no 00.039 0.127 -0.088 69.29% 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AMSGPNewAugustaAA‐015PowerBoiler 1MajorSource MS Boiler 642 642 8520 1983 Stoker/SlopedGrate/Other loadfollowing False Biomass DryBiomassElectrostaticPrecipitator0 100 0 0100 Biomass no 00.039 0.0018 0.0372 0.035 0.001 0.034 4.6E-06 1.1E-06 3.5E-06MSGPTaylorsvillePly AA‐700 1MajorSource MS Boiler 155 155 8652 1979 Stoker/SlopedGrate/Other Base‐loaded False Biomass DryBiomassElectrostaticPrecipitator0 100 0 0100 Biomass no 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AMSGPTaylorsvillePly AA‐500 1MajorSource MS Boiler 169 169 8724 1969 Stoker/SlopedGrate/Other False Biomass DryBiomass CycloneorMulticlone0 100 0 0100 Biomass no 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AMSGPTylertownMillAA‐001,WoodwasteBoiler 1MajorSource MS Boiler 30 30 8688 1978 Stoker/SlopedGrate/Other Base‐loaded False Biomass DryBiomass CycloneorMulticlone0 100 0 0100 Biomass no 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AMSHankinsLumber Boiler#1(AA‐001) 1MajorSource MS Boiler 65 65 8000 1981 Stoker/SlopedGrate/Other Base‐loaded False Biomass DryBiomass CycloneorMulticlone0 100 0 0100 Biomass no 00.039 N/A N/A #VALUE! 0.035 0.00026 0.03474 4.6E-06 N/A N/AMSHankinsLumber Boiler#2(AA‐002) 1MajorSource MS Boiler 23 23 8000 1973 Stoker/SlopedGrate/Other loadfollowing False Biomass DryBiomass CycloneorMulticlone0 100 0 0100 Biomass no 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AMSHoodBeaumontAA‐030(Wood‐FiredBoiler) 1MajorSource MS Boiler 140 140 8400 1994 Stoker/SlopedGrate/Other loadfollowing False Biomass WetBiomass VenturiScrubber0 100 0 0100 Biomass no 10.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AMSHoodWaynesboroAA‐001(Wood‐FiredBoiler) 1MajorSource MS Boiler 100 100 8400 1971 Stoker/SlopedGrate/Other loadfollowing False Biomass WetBiomass CycloneorMulticlone0 100 0 0100 Biomass no 10.039 N/A N/A #VALUE! 0.035 0.000211 0.034789 4.6E-06 N/A N/AMSHoodWigginsAA‐001(Wood‐FiredBoilerNo.1) 1MajorSource MS Boiler 65 65 8400 1971 Stoker/SlopedGrate/Other loadfollowing False Biomass WetBiomass CycloneorMulticlone0 100 0 0100 Biomass no 10.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AMSHoodWigginsAA‐002(Wood‐FiredBoilerNo.2) 1MajorSource MS Boiler 65 65 8400 1971 Stoker/SlopedGrate/Other loadfollowing False Biomass WetBiomass CycloneorMulticlone0 100 0 0100 Biomass no 10.039 N/A N/A #VALUE! 0.035 0.001067 0.033933 4.6E-06 N/A N/AMSHoodWigginsAA‐003(Wood‐FiredBoilerNo.3) 1MajorSource MS Boiler 90 90 8400 1975 Stoker/SlopedGrate/Other loadfollowing False Biomass WetBiomass CycloneorMulticlone0 100 0 0100 Biomass no 10.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 7.75E-07 3.82E-06MSIPVicksburgPowerBoiler‐AA‐006 1MajorSource MS Boiler 870 870 8400 1967 Stoker/SlopedGrate/Other loadfollowing True Biomass WetBiomass WetScrubber0 88.24659211 0 088.24659 Biomass no 10.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AFacilityID UnitID UnitCountMajorSourceStateClassificatioCapacity(mmCapacity_NumeriHoursPerYearInstalle CombustorDesign DutyCyclewNOxBurneACTFuelCategoBaselineFuelCat TotalControlCoal % Biomass % Liquid % Gas 2 %MaxFuel% Max FuelBiomass/CoalCombo Boiler?WetBiomass? PM LimitPMEmissionsPMDifference PM %red HCL LimitHCLEmissionsHCLDifference HCl%red Hg LimitHgEmissionsHgDifferenceMSNorbordMS WellonsNo.1 1MajorSource MSProcessHeater 100 100 8400 1995 FuelCell loadfollowing False Biomass WetBiomassElectrostaticPrecipitator0 100 0 0100 Biomass no 10.039 0.008944 0.030056 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AMSNorbordMS WellonsNo.2 1MajorSource MSProcessHeater 100 100 8400 1995 FuelCell loadfollowing False Biomass WetBiomassElectrostaticPrecipitator0 100 0 0100 Biomass no 10.039 0.008944 0.030056 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AMSNorbordMS WellonsNo.3 1MajorSource MSProcessHeater 100 100 8400 1995 FuelCell loadfollowing False Biomass WetBiomassElectrostaticPrecipitator0 100 0 0100 Biomass no 10.039 0.008944 0.030056 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AMSSandersonPlumbing AD‐001 1MajorSource MS Boiler 11.29 11.29 5808 1994 Stoker/SlopedGrate/Other Base‐loaded False Biomass DryBiomass CycloneorMulticlone0 0 000 Biomass no 00.039 N/A N/A #VALUE! 0.035 0.000633 0.034367 4.6E-06 2.01E-06 2.59E-06MSShuqualakLumber Boiler1(AA‐101) 1MajorSource MS Boiler 42 42 8000 1988 DutchOven/Susp.Burner Base‐loaded False Biomass DryBiomass CycloneorMulticlone0 100 0 0100 Biomass no 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AMSShuqualakLumber Boiler2(AA‐102) 1MajorSource MS Boiler 15 15 8000 1979 DutchOven/Susp.Burner Base‐loaded False Biomass DryBiomass CycloneorMulticlone0 100 0 0100 Biomass no 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AMSShuqualakLumber Boiler3(AA‐107) 1MajorSource MS Boiler 29 29 8000 1998 Stoker/SlopedGrate/Other Base‐loaded False Biomass DryBiomass CycloneorMulticlone0 100 0 0100 Biomass no 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AMSShuqualakLumber Boiler4(AA‐108) 1MajorSource MS Boiler 29 29 8000 2004 Stoker/SlopedGrate/Other Base‐loaded False Biomass DryBiomass CycloneorMulticlone0 100 0 0100 Biomass no 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AMSWeyerhaeuser1398 BoilerNo.1 1MajorSource MS Boiler 140 140 8200 1976 Stoker/SlopedGrate/Other loadfollowing False Biomass DryBiomass CycloneorMulticlone0 100 0 0100 Biomass no 00.039 0.50863 -0.46963 92.33% 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AMSWeyerhaeuser1398 BoilerNo.2 1MajorSource MS Boiler 28.9 28.9 8200 2002 Stoker/SlopedGrate/Other loadfollowing False Biomass DryBiomass CycloneorMulticlone0 100 0 0100 Biomass no 00.039 2.234024 -2.19502 98.25% 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AMSWeyerhaeuserBruceAA‐001No.1Boiler 1MajorSource MS Boiler 70 70 8496 1973 Stoker/SlopedGrate/Other loadfollowing False Biomass DryBiomass NoHAPAPCDControl0 100 0 0100 Biomass no 00.039 0.302 -0.263 87.09% 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AMSWeyerhaeuserBruceAA‐002No.2Boiler 1MajorSource MS Boiler 115 115 8496 1992 FuelCell loadfollowing False Biomass DryBiomassElectrostaticPrecipitator0 100 0 0100 Biomass no 00.039 0.005494 0.033506 0.035 0.000507 0.034493 4.6E-06 9.93E-07 3.61E-06MSWeyerhaeuserColumbus AA‐012 1MajorSource MS Boiler 1400 1400 8570 1979 Stoker/SlopedGrate/Other loadfollowing True Biomass DryBiomassElectrostaticPrecipitator14.8262321 76.92055489 2.313984958 0.12855576.92055 Biomass combo 00.039 0.022667 0.016333 0.035 N/A N/A #VALUE! 4.6E-06 4.59E-07 4.14E-06MTPlumCreek CoreCoen 1MajorSource MTProcessHeater 50 50 8400 1985 DutchOven/Susp.Burner Base‐loaded False Biomass DryBiomassElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AMTPlumCreek FaceCoen 1MajorSource MTProcessHeater 50 50 8500 0 DutchOven/Susp.Burner Base‐loaded False Biomass DryBiomassElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AMTPlumCreek Line2Coen 1MajorSource MTProcessHeater 85 85 8500 2000 DutchOven/Susp.Burner Base‐loaded True Biomass DryBiomass VenturiScrubberData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AMTPlumCreek WellonsPlywood 1MajorSource MTProcessHeater 30 30 8500 1965 FuelCell Base‐loaded False Biomass WetBiomassElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 10.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AMTPlumCreek HogFuelBoiler 1MajorSource MT Boiler 292 292 8700 1973 Stoker/SlopedGrate/Other loadfollowing False Biomass WetBiomassElectrostaticPrecipitator0 0 000 Biomass no 10.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AMTRoseburgMissoula Boiler 1MajorSource MT Boiler 55 55 8400 1969 Stoker/SlopedGrate/Other loadfollowing False Biomass DryBiomass CycloneorMulticlone0 1.217587622 0 01.217588 Biomass no 00.039 N/A N/A #VALUE! 0.035 0.003417 0.031583 4.6E-06 4.08E-07 4.19E-06MTSmurfitStone Multi‐FuelBoiler 1MajorSource MT Boiler 402.5 402.5 8520 Stoker/SlopedGrate/Other #N/A False Biomass DryBiomass VenturiScrubberData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/ANCBlueRidgePaper G11037 1MajorSource NC Boiler 364 364 7800 1930 PC loadfollowing TrueCoalCoalElectrostaticPrecipitator100 0 0 0100 Coal no 00.039 0.0785 -0.0395 50.32% 0.035 0.060333 -0.02533 41.99% 4.6E-06 4.24E-06 3.6E-07NCBlueRidgePaper G11038 1MajorSource NC Boiler 364 364 7890 1930 PC loadfollowing TrueCoalCoalElectrostaticPrecipitator100 0 0 0100 Coal no 00.039 0.074667 -0.03567 47.77% 0.035 0.060333 -0.02533 41.99% 4.6E-06 4.24E-06 3.6E-07NCBlueRidgePaper G11039 1MajorSource NC Boiler 399 399 8150 1946 PC loadfollowing TrueCoalCoalElectrostaticPrecipitator100 0 0 0100 Coal no 00.039 0.063833 -0.02483 38.90% 0.035 0.041 -0.006 14.63% 4.6E-06 3.13E-06 1.47E-06NCBlueRidgePaper G11040 1MajorSource NC Boiler 535 535 8350 1986 PC loadfollowing TrueCoalCoalElectrostaticPrecipitator100 0 0 0100 Coal no 00.039 0.035833 0.003167 0.035 0.006933 0.028067 4.6E-06 2.1E-06 2.5E-06NCBlueRidgePaper G11042 1MajorSource NC Boiler 380 380 7700 1952 Stoker/SlopedGrate/Other loadfollowing False Biomass WetBiomass VenturiScrubber67.8933946 32.10660538 0 067.89339 Coal combo 10.039 0.22 -0.181 82.27% 0.035 0.0028 0.0322 4.6E-06 3.42E-06 1.18E-06NCDomtar65‐25‐0310(No.2HogFuelBoiler) 1MajorSource NC Boiler 889 889 8279 1982 Stoker/SlopedGrate/Other loadfollowing False Biomass DryBiomassCycloneorMulticlone/ElectrifiedFilterBed(EFB)29.1516149 70.6691113 0.179273819 070.66911 Biomass combo 00.039 0.021833 0.017167 0.035 0.102367 -0.06737 65.81% 4.6E-06 1.95E-06 2.65E-06NCDomtar66‐25‐2050(No.1PackageBoiler) 1MajorSource NC Boiler 360 360 1342 1996 N/A Standby True Liquid LightLiquid Scrubber(unknown)0 0 100 00 Biomass no 00.0075 0.016147 -0.00865 53.55% 0.00033 0.007904 -0.00757 95.82% 3.5E-06 5.03E-06 -1.5E-06NCDomtar64‐25‐0290(No.1HogFuelBoiler) 1MajorSource NC Boiler 747.5 747.5 8337 1977 Stoker/SlopedGrate/Other loadfollowing False Biomass DryBiomassCycloneorMulticlone/ElectrifiedFilterBed(EFB)17.6021553 82.12547152 0.272373193 082.12547 Biomass combo 00.039 0.025983 0.013017 0.035 0.013417 0.021583 4.6E-06 2.47E-06 2.13E-06NCGPAhoskieCNSES‐B1‐WoodFiredBoiler 1MajorSource NC Boiler 91.8 91.8 7000 1973 Stoker/SlopedGrate/Other loadfollowing False Biomass DryBiomass CycloneorMulticlone0 100 0 0100 Biomass no 00.039 0.163333 -0.12433 76.12% 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/ANCGPDudley ES‐B1 1MajorSource NC Boiler 254 254 8500 1979 Stoker/SlopedGrate/Other loadfollowing False Biomass DryBiomass WetScrubber0 100 0 0100 Biomass no 00.039 0.133333 -0.09433 70.75% 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/ANCGPRoxboroES‐1WoodfiredBoiler 1MajorSource NC Boiler 70 70 8400 1985 Stoker/SlopedGrate/Other loadfollowing False Biomass DryBiomass CycloneorMulticlone0 100 0 0100 Biomass no 00.039 0.284333 -0.24533 86.28% 0.035 0.000217 0.034783 4.6E-06 2.67E-07 4.33E-06NCGPWhiteville ES‐B2 1MajorSource NC Boiler 241.5 241.5 8664 1984 Stoker/SlopedGrate/Other loadfollowing False Biomass DryBiomass WetScrubber0 100 0 0100 Biomass no 00.039 0.103333 -0.06433 62.26% 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/ANCInternationalPaperRiegelwood PB2 1MajorSource NC Boiler 425 425 8400 1957 Stoker/SlopedGrate/Other loadfollowing False Biomass WetBiomass VenturiScrubber12.7551416 60.6741094 26.57074895 060.67411 Biomass combo 10.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/ANCInternationalPaperRiegelwood PB1 1MajorSource NC Boiler 250 250 5000 1951 N/A Standby False Liquid HeavyLiquid WetScrubberData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.0075 N/A N/A #VALUE! 0.00033 N/A N/A #VALUE! 3.5E-06 N/A N/ANCInternationalPaperRiegelwood PB5 1MajorSource NC Boiler 600 600 8400 1978 Stoker/SlopedGrate/Other loadfollowing True Biomass WetBiomass VenturiScrubber11.5526316 74.77354722 13.67382119 074.77355 Biomass combo 10.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/ANCJacksonPaperSylva JP‐021 1MajorSource NC Boiler 145.1 145.1 8592 1982 Stoker/SlopedGrate/Other Base‐loaded False Biomass DryBiomass VenturiScrubber0 92.35407109 0 092.35407 Biomass no 00.039 0.199287 -0.16029 80.43% 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/ANCJeld‐Wen Boiler1 1MajorSource NC Boiler 43.6 43.6 8400 1988 Stoker/SlopedGrate/Other loadfollowing False Biomass DryBiomass CycloneorMulticlone0 100 0 0100 Biomass no 00.039 0.198333 -0.15933 80.34% 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/ANCKapStone PB1 1MajorSource NC Boiler 550 550 8600 1966 Stoker/SlopedGrate/Other loadfollowing False Biomass WetBiomass VenturiScrubber42.5487419 57.45125807 0 057.45126 Biomass combo 10.039 0.194333 -0.15533 79.93% 0.035 N/A N/A #VALUE! 4.6E-06 4.01E-06 5.87E-07NCKapStone PKG2 1MajorSource NC Boiler 185 185 2000 1974 N/A Standby False Liquid HeavyLiquid NoHAPAPCDControl0 0 100 00 Biomass no 00.0075 0.170333 -0.16283 95.60% 0.00033 N/A N/A #VALUE! 3.5E-06 N/A N/ANCLAPacificRoxboro TOH#1w 1MajorSource NCProcessHeater 40 40 3700 1995 DutchOven/Susp.Burner loadfollowing False Biomass WetBiomassElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 10.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/ANCLAPacificRoxboro TOH#2w 1MajorSource NCProcessHeater 40 40 3700 1995 DutchOven/Susp.Burner loadfollowing False Biomass DryBiomassElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/ANCLPRoaringRiver Boiler#2 1MajorSource NC Boiler 79 79 8400 1969 Stoker/SlopedGrate/Other Base‐loaded False Biomass WetBiomass VenturiScrubber0 100 0 0100 Biomass no 10.039 N/A N/A #VALUE! 0.035 0.000253 0.034747 4.6E-06 9.13E-07 3.69E-06FacilityID UnitID UnitCountMajorSourceStateClassificatioCapacity(mmCapacity_NumeriHoursPerYearInstalle CombustorDesign DutyCyclewNOxBurneACTFuelCategoBaselineFuelCat TotalControlCoal % Biomass % Liquid % Gas 2 %MaxFuel% Max FuelBiomass/CoalCombo Boiler?WetBiomass? PM LimitPMEmissionsPMDifference PM %red HCL LimitHCLEmissionsHCLDifference HCl%red Hg LimitHgEmissionsHgDifferenceNCLPRoaringRiver Boiler#1 1MajorSource NC Boiler 44 44 1000 1969 N/A Base‐loaded False Liquid HeavyLiquid NoHAPAPCDControlData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.0075 N/A N/A #VALUE! 0.00033 N/A N/A #VALUE! 3.5E-06 N/A N/ANCLPRoaringRiver Boiler#3 1MajorSource NC Boiler 183 183 8400 1979 Stoker/SlopedGrate/Other loadfollowing False Biomass WetBiomass VenturiScrubber0 0 000 Biomass no 10.039 N/A N/A #VALUE! 0.035 0.003633 0.031367 4.6E-06 0.000008 -3.4E-06NCSeaboardLumber ES‐3 1MajorSource NC Boiler 55.82 55.82 8400 2005 FB loadfollowing False Biomass WetBiomassElectrostaticPrecipitator0 100 0 0100 Biomass no 10.039 0.052406 -0.01341 25.58% 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/ANCSeaboardLumber ES‐NB 1MajorSource NC Boiler 33 33 8400 1979 FB loadfollowing False Biomass WetBiomass CycloneorMulticloneData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 10.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/ANCSeaboardLumber ES‐SB 1MajorSource NC Boiler 33 33 8400 1979 FB loadfollowing False Biomass WetBiomass CycloneorMulticloneData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 10.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/ANCUniboardUSASuspensionBurnerID1430 1MajorSource NCProcessHeater 60 60 8200 1996 DutchOven/Susp.Burner loadfollowing False Biomass DryBiomassElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/ANCWestFraser ES‐BW‐1 1MajorSource NC Boiler 104.336 104.336 8675 1974 Stoker/SlopedGrate/Other loadfollowing False Biomass DryBiomass VenturiScrubberData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/ANCWeyerhaeuserGrifton ES‐SEH‐2901 1MajorSource NCProcessHeater 57.16 57.16 8400 1989 FuelCell loadfollowing False Biomass DryBiomassElectrostaticPrecipitator0 0 000 Biomass no 00.039 0.020167 0.018833 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/ANCWeyerhaeuserGrifton ES‐SEH‐3901 1MajorSource NCProcessHeater 98 98 8400 1998 FuelCell loadfollowing False Biomass DryBiomassElectrostaticPrecipitator0 0 000 Biomass no 00.039 0.020167 0.018833 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/ANCWeyerhaeuserGrifton ES‐SHE‐1901 1MajorSource NCProcessHeater 57.16 57.16 8400 FuelCell #N/A False Biomass DryBiomassElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/ANCWeyerhaeuser‐Vanceboro ES150‐001 1MajorSource NC Boiler 579 579 6000 1969 N/A Base‐loaded False Liquid HeavyLiquid NoHAPAPCDControl0 0 100 00 Biomass no 00.0075 0.1411 -0.1336 94.68% 0.00033 N/A N/A #VALUE! 3.5E-06 N/A N/ANCWeyerhaeuser‐Vanceboro ES161‐001 1MajorSource NC Boiler 287 287 8760 1996 N/A loadfollowing True Liquid HeavyLiquid DryScrubber0 0 100 00 Biomass no 00.0075 0.037 -0.0295 79.73% 0.00033 N/A N/A #VALUE! 3.5E-06 N/A N/ANYFinchPaper#9WoodwasteBoiler(BLR‐1749) 1MajorSource NY Boiler 172.5 172.5 8520 1977 Stoker/SlopedGrate/Other Base‐loaded False Biomass WetBiomass VenturiScrubberData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 10.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/ANYIntlPaperTiconderoga PB1 1MajorSource NY Boiler 855 855 8520 1970 Stoker/SlopedGrate/Other loadfollowing True Biomass WetBiomassDryScrubberCycloneorMulticloneData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 10.039 0.081725 -0.04273 52.28% 0.035 0.001795 0.033205 4.6E-06 2.52E-07 4.35E-06OHAppletonIdeas Boiler2(B002) 1MajorSource OH Boiler 156 156 8400 1960 Stoker/SlopedGrate/Other loadfollowing FalseCoalCoalElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 0.016667 0.022333 0.035 0.094 -0.059 62.77% 4.6E-06 4.38E-06 2.15E-07OHAppletonIdeas Boiler4(B003) 1MajorSource OH Boiler 245 245 8539 1968 Stoker/SlopedGrate/Other loadfollowing FalseCoalCoalElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 0.043333 -0.00433 10.00% 0.035 0.115 -0.08 69.57% 4.6E-06 3.94E-07 4.21E-06OHGlatfelterChillicothe PowerBoiler#7 1MajorSource OH Boiler 375 375 8760 0 PC FalseCoalCoalElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AOHGlatfelterChillicothe PowerBoiler#8 1MajorSource OH Boiler 500 500 8760 0 PC FalseCoalCoalElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AOHGlatfelterChillicothe PowerBoiler#6 1MajorSource OH Boiler 288 288 8760 0 Stoker/SlopedGrate/Other False Biomass WetBiomassWetElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 10.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AOHRockTennCincinnati B001 1MajorSource OH Boiler 81 81 8136 1960 Stoker/SlopedGrate/Other Base‐loaded FalseCoalCoal FabricFilterData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 0.016333 0.022667 0.035 0.213667 -0.17867 83.62% 4.6E-06 N/A N/AOHSmartPapersHoldingsLLC B010 1MajorSource OH Boiler 420 420 8540 1928 PC loadfollowing TrueCoalCoalElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 0.001 0.038 0.035 N/A N/A #VALUE! 4.6E-06 6.16E-06 -1.6E-06OHSmurfitCoshocton B006 1MajorSource OH Boiler 644 644 8625 1982 Stoker/SlopedGrate/Other loadfollowing True Biomass WetBiomass VenturiScrubberData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 10.039 0.0675 -0.0285 42.22% 0.035 0.000155 0.034845 4.6E-06 8.91E-07 3.71E-06OKGPMuskogeeMill B‐2 1MajorSource OK Boiler 345 345 7320 1975 PC Base‐loaded FalseCoalCoalElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 N/A N/A #VALUE! 0.035 0.012333 0.022667 4.6E-06 2.67E-06 1.93E-06OKGPMuskogeeMill B‐4 1MajorSource OK Boiler 460 460 8496 1982 PC loadfollowing TrueCoalCoal FabricFilterData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 N/A N/A #VALUE! 0.035 0.032333 0.002667 4.6E-06 0.000002 2.6E-06OKGPMuskogeeMill B‐3 1MajorSource OK Boiler 460 460 8640 1979 PC loadfollowing FalseCoalCoal FabricFilterData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 0.004667 0.034333 0.035 0.030333 0.004667 4.6E-06 4.67E-07 4.13E-06OKIPValliantBark Boiler EUGD1 1MajorSource OK Boiler 900900Stoker/SlopedGrate/Other#N/ABiomass Wet Biomass Venturi ScrubberData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 10.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AOKIPValliantPowerBoilerEUG‐D2 1MajorSource OK Boiler 945 945 8642 1972 N/A loadfollowing False Liquid HeavyLiquid NoHAPAPCDControlData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.0075 N/A N/A #VALUE! 0.00033 N/A N/A #VALUE! 3.5E-06 N/A N/AOKPanPacificProducts EU100 1MajorSource OK Boiler 45 45 6500 1995 Stoker/SlopedGrate/Other Base‐loaded False Biomass DryBiomass WetScrubberData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 0.061074 -0.02207 36.14% 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AOKWeyerhaeuserWrightCity EUG19 1MajorSource OK Boiler 240 240 8400 1978 Stoker/SlopedGrate/Other loadfollowing False Biomass DryBiomassElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 0.026256 0.012744 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AORBBSMMedford B1 1MajorSource OR Boiler 57.5 57.5 8760 1955 Stoker/SlopedGrate/Other loadfollowing False Biomass WetBiomassElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 10.039 0.006333 0.032667 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AORBBSMMedford B2 1MajorSource OR Boiler 80.5 80.5 8760 1964 Stoker/SlopedGrate/Other loadfollowing False Biomass WetBiomassElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 10.039 0.006333 0.032667 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AORBBSMMedford B3 1MajorSource OR Boiler 115 115 8760 1991 Stoker/SlopedGrate/Other loadfollowing False Biomass WetBiomassElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 10.039 0.006333 0.032667 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AORBlueHeronPaper GBoiler 1MajorSource OR Boiler 112 112 8712 1949 Stoker/SlopedGrate/Other Base‐loaded False Biomass DryBiomass CycloneorMulticloneData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 0.018008 0.020992 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AORBoiseBuilding B2 1MajorSource OR Boiler 80 80 8600 1970 DutchOven/Susp.Burner Base‐loaded False Biomass DryBiomassElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 N/A N/A #VALUE! 0.035 0.000433 0.034567 4.6E-06 N/A N/AORCascadePacificPulp PB1EU 1MajorSource OR Boiler 230 230 8603 1968 N/A Base‐loaded False Liquid HeavyLiquid NoHAPAPCDControlData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.0075 0.040333 -0.03283 81.40% 0.00033 N/A N/A #VALUE! 3.5E-06 N/A N/AORFlakeboardEugene Boiler‐2 1MajorSource OR Boiler 51 51 7700 1987 DutchOven/Susp.Burner loadfollowing False Biomass DryBiomass FabricFilterData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 0.000757 0.038243 0.035 0.000233 0.034767 4.6E-06 1.36E-07 4.46E-06ORGeorgiaPacificWaunaMillEU33‐PowerBoiler 1MajorSource OR Boiler191.894613356164 191.8946134 8400 1965 N/A loadfollowing False Liquid HeavyLiquid NoHAPAPCDControlData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.0075 0.044102 -0.0366 82.99% 0.00033 N/A N/A #VALUE! 3.5E-06 N/A N/AORGeorgiaPacificWaunaMillEU35‐FluidizedBedBoiler 1MajorSource OR Boiler 179 179 8400 1996 FB Base‐loaded False Biomass DryBiomassFabricFilterDrySorbentInjectionData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 0.007104 0.031896 0.035 0.003239 0.031761 4.6E-06 7.62E-07 3.84E-06ORGPToledoEU13‐PowerBoiler#1 1MajorSource OR Boiler 187.5 187.5 8600 1957 N/A loadfollowing False Liquid HeavyLiquid NoHAPAPCDControlData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.0075 0.10925 -0.10175 93.14% 0.00033 N/A N/A #VALUE! 3.5E-06 N/A N/AORJeldWenKlamanthFalls BLRG 1MajorSource OR Boiler 74 74 8760 1988 Stoker/SlopedGrate/Other loadfollowing False Biomass WetBiomassElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 10.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AORRosboroSpringfield DV01.1 1MajorSource OR Boiler 50 50 8700 1946 DutchOven/Susp.Burner loadfollowing False Biomass DryBiomass CycloneorMulticloneData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 0.12 -0.081 67.50% 0.035 0.0056 0.0294 4.6E-06 1.65E-06 2.95E-06ORRosboroSpringfield DV01.2 1MajorSource OR Boiler 50 50 8700 1946 DutchOven/Susp.Burner loadfollowing False Biomass DryBiomass CycloneorMulticloneData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AFacilityID UnitID UnitCountMajorSourceStateClassificatioCapacity(mmCapacity_NumeriHoursPerYearInstalle CombustorDesign DutyCyclewNOxBurneACTFuelCategoBaselineFuelCat TotalControlCoal % Biomass % Liquid % Gas 2 %MaxFuel% Max FuelBiomass/CoalCombo Boiler?WetBiomass? PM LimitPMEmissionsPMDifference PM %red HCL LimitHCLEmissionsHCLDifference HCl%red Hg LimitHgEmissionsHgDifferenceORRosboroSpringfield DV01.3 1MajorSource OR Boiler 50 50 8700 1946 DutchOven/Susp.Burner loadfollowing False Biomass DryBiomass CycloneorMulticloneData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AORRoseburgCoquille Boiler1 1MajorSource OR Boiler 127.65 127.65 8400 1959 Stoker/SlopedGrate/Other loadfollowing False Biomass DryBiomass CycloneorMulticloneData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 N/A N/A #VALUE! 0.035 0.03445 0.00055 4.6E-06 1.25E-06 3.35E-06ORRoseburgForestDillard Boiler#1 1MajorSource OR Boiler 309 309 8500 1966 Stoker/SlopedGrate/Other loadfollowing False Biomass WetBiomass WetScrubberData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 10.039 N/A N/A #VALUE! 0.035 0.000939 0.034061 4.6E-06 2.28E-06 2.32E-06ORRoseburgForestDillard Boiler#2 1MajorSource OR Boiler 309 309 8500 1974 Stoker/SlopedGrate/Other loadfollowing False Biomass WetBiomass WetScrubberData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 10.039 N/A N/A #VALUE! 0.035 0.00224 0.03276 4.6E-06 1.64E-06 2.96E-06ORRoseburgForestDillard Boiler#6 1MajorSource OR Boiler 520 520 8500 1976 Stoker/SlopedGrate/Other loadfollowing False Biomass WetBiomass WetScrubberData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 10.039 N/A N/A #VALUE! 0.035 0.00079 0.03421 4.6E-06 5.04E-07 4.1E-06ORRoseburgRiddle2 Boiler#1 1MajorSource OR Boiler 126.5 126.5 8500 1967 Stoker/SlopedGrate/Other loadfollowing False Biomass DryBiomassElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 N/A N/A #VALUE! 0.035 0.0014 0.0336 4.6E-06 6.94E-07 3.91E-06ORRoseburgRiddle2 Boiler#2 1MajorSource OR Boiler 80.5 80.5 8500 1974 Stoker/SlopedGrate/Other loadfollowing False Biomass DryBiomass WetScrubberData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 N/A N/A #VALUE! 0.035 0.000567 0.034433 4.6E-06 7.45E-07 3.85E-06ORSierraPine SPMDBL01 1MajorSource OR Boiler 103.5 103.5 7077 1992 DutchOven/Susp.Burner loadfollowing True Biomass DryBiomassWetScrubberElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AORSierraPineSpringfield SPSPCU01 1MajorSource ORProcessHeater 20 20 8760 1970 Stoker/SlopedGrate/Other loadfollowing False Biomass DryBiomassElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AORSierraPineSpringfield SPSPCU03 1MajorSource ORProcessHeater 30 30 8760 1975 Stoker/SlopedGrate/Other loadfollowing False Biomass DryBiomassElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AORSierraPineSpringfield SPSPCU04 1MajorSource ORProcessHeater 30 30 8760 1975 Stoker/SlopedGrate/Other loadfollowing False Biomass DryBiomassElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AORSPNewsprint B10‐EU 1MajorSource OR Boiler 567 567 7880 1980 Stoker/SlopedGrate/Other Base‐loaded True Biomass DryBiomassElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 0.007667 0.031333 0.035 0.076933 -0.04193 54.51% 4.6E-06 2.77E-06 1.83E-06ORSPNewsprint B9‐EU 1MajorSource OR Boiler 274 274 8400 1975 Stoker/SlopedGrate/Other Standby False Biomass DryBiomass WetScrubberData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AORStimsonLumberForestGrove Boiler1 1MajorSource OR Boiler 76 76 8400 1973 Stoker/SlopedGrate/Other loadfollowing False Biomass DryBiomassElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AORStimsonLumberForestGrove Boiler2 1MajorSource OR Boiler 76 76 8400 1978 Stoker/SlopedGrate/Other loadfollowing False Biomass DryBiomassElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AORStimsonLumberForestGrove Boiler3 1MajorSource OR Boiler 76 76 8400 1978 Stoker/SlopedGrate/Other loadfollowing False Biomass DryBiomassElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/APAAppletonPapers #033 1MajorSource PA Boiler 205.03 205.03 8400 1995 N/A Standby True Liquid HeavyLiquid NoHAPAPCDControlData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.0075 N/A N/A #VALUE! 0.00033 N/A N/A #VALUE! 3.5E-06 N/A N/APAAppletonPapers #036 1MajorSource PA Boiler 180 180 8400 1977 Stoker/SlopedGrate/Other loadfollowing False Biomass WetBiomass VenturiScrubberData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 10.039 0.178398 -0.1394 78.14% 0.035 0.007184 0.027816 4.6E-06 1.03E-05 -5.7E-06PACraftMasterNo3BoilerSourceID033 1MajorSource PA Boiler 273.2 273.2 8600 1996 Stoker/SlopedGrate/Other loadfollowing True Biomass DryBiomassElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 0.019511 0.019489 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/APADomtarJohnsonburg #81CoalBoiler 1MajorSource PA Boiler 246 246 8640 1984 PC loadfollowing TrueCoalCoalWetScrubberElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 0.012667 0.026333 0.035 0.000833 0.034167 4.6E-06 3.77E-06 8.33E-07PADomtarJohnsonburg #82CoalBoiler 1MajorSource PA Boiler246.6666667 246.6666667 8640 1984 PC loadfollowing TrueCoalCoalWetScrubberElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 0.012667 0.026333 0.035 0.000833 0.034167 4.6E-06 4.13E-06 4.72E-07PAPHGlatfelter PB3 1MajorSource PA Boiler 140.1 140.1 1374 1948 PC Standby FalseCoalCoalElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 0.005259 0.033741 0.035 0.061998 -0.027 43.55% 4.6E-06 3.15E-06 1.45E-06PAPHGlatfelter PB4 1MajorSource PA Boiler 363.7 363.7 8550 1956 PC loadfollowing TrueCoalCoalElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 0.005225 0.033775 0.035 0.061997 -0.027 43.55% 4.6E-06 3.14E-06 1.46E-06PAPHGlatfelter PB1 1MajorSource PA Boiler 262.3 262.3 8574 1965 PC Base‐loaded TrueCoalCoalElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 0.005214 0.033786 0.035 0.062003 -0.027 43.55% 4.6E-06 3.15E-06 1.45E-06PAPHGlatfelter PB5 1MajorSource PA Boiler 545 545 8412 1989 FB Base‐loaded False Biomass WetBiomassDrySorbentInjectionElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 10.039 0.005212 0.033788 0.035 0.021022 0.013978 4.6E-06 1.43E-06 3.17E-06PAProctorGambleMehoopanyPA Boiler#1(031) 1MajorSource PA Boiler 242 242 8400 1966 N/A loadfollowing True Liquid HeavyLiquid NoHAPAPCDControlData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.0075 N/A N/A #VALUE! 0.00033 N/A N/A #VALUE! 3.5E-06 N/A N/APATeamTen033ABabcockandWilcoxNo.7Boiler 1MajorSource PA Boiler 236 236 8400 1957 Stoker/SlopedGrate/Other Base‐loaded FalseCoalCoal FabricFilterData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/APATemple‐Inland Westec 1MajorSource PAProcessHeater 50 50 7100 1994 DutchOven/Susp.Burner loadfollowing False Biomass DryBiomass NoHAPAPCDControlData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/APATemple‐Inland GEKA 1MajorSource PAProcessHeater 66 66 7250 1994 DutchOven/Susp.Burner loadfollowing False Biomass DryBiomass NoHAPAPCDControlData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/ASCBowaterCoatedPaperCombinationBoilerNo.1 1MajorSource SC Boiler 405 405 8600 1959 Stoker/SlopedGrate/Other loadfollowing False Biomass WetBiomassElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 10.039 0.042 -0.003 7.14% 0.035 0.0165 0.0185 4.6E-06 7.66E-07 3.83E-06SCBowaterCoatedPaper PowerBoiler 1MajorSource SC Boiler 375 375 1000 1959 N/A Standby False Liquid HeavyLiquid NoHAPAPCDControlData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.0075 0.183333 -0.17583 95.91% 0.00033 N/A N/A #VALUE! 3.5E-06 N/A N/ASCBowaterCoatedPaperCombinationBoilerNo.2 1MajorSource SC Boiler 720 720 8600 1968 Stoker/SlopedGrate/Other loadfollowing False Biomass WetBiomassElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 10.039 0.10415 -0.06515 62.55% 0.035 0.00185 0.03315 4.6E-06 2.43E-07 4.36E-06SCChesterWoodProducts Boiler 1MajorSource SC Boiler 142 142 8640 1981 Stoker/SlopedGrate/Other False Biomass WetBiomass WetScrubberData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 10.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/ASCCogenSouth B001‐MainBoiler 1MajorSource SC Boiler 1337 1337 8592 1999 Stoker/SlopedGrate/Other loadfollowing True Biomass WetBiomassSprayDryer/FabricFilterData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 10.039 0.014846 0.024154 0.035 0.000523 0.034477 4.6E-06 9.17E-07 3.68E-06SCCollumsLumber 01 1MajorSource SC Boiler 33.5 33.5 8200 1988 Stoker/SlopedGrate/Other Base‐loaded False Biomass WetBiomass CycloneorMulticloneData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 10.039 0.233333 -0.19433 83.29% 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/ASCGPProsperityPlyB,WoodFiredBoiler 1MajorSource SC Boiler 200 200 8520 1989 Stoker/SlopedGrate/Other loadfollowing False Biomass WetBiomass WetScrubberData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 10.039 0.089333 -0.05033 56.34% 0.035 N/A N/A #VALUE! 4.6E-06 8.51E-07 3.75E-06SCGPRussellville Wood‐firedboiler 1MajorSource SC Boiler 248.67 248.67 8400 1986 Stoker/SlopedGrate/Other loadfollowing False Biomass DryBiomass CycloneorMulticloneData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 0.057 -0.018 31.58% 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/ASCInternationalPaperEastover No.2PowerBoiler 1MajorSource SC Boiler 500 500 8500 1989 Stoker/SlopedGrate/Other Base‐loaded False Biomass WetBiomassElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 10.039 0.0104 0.0286 0.035 0.002517 0.032483 4.6E-06 6.28E-08 4.54E-06SCInternationalPaperEastover No.1PowerBoiler 1MajorSource SC Boiler 545 545 8600 1982 Stoker/SlopedGrate/Other loadfollowing True Biomass WetBiomassElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 10.039 0.022442 0.016558 0.035 0.145667 -0.11067 75.97% 4.6E-06 N/A N/ASCIPGeorgetown PB01 1MajorSource SC Boiler 592 592 8616 1982 Stoker/SlopedGrate/Other loadfollowing True Biomass WetBiomassElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 10.039 N/A N/A #VALUE! 0.035 0.006053 0.028947 4.6E-06 N/A N/ASCIPGeorgetown PB02 1MajorSource SC Boiler 592 592 8616 1982 Stoker/SlopedGrate/Other loadfollowing True Biomass WetBiomassElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 10.039 N/A N/A #VALUE! 0.035 0.006053 0.028947 4.6E-06 N/A N/ASCMarlboroPaper HoggedFuelBoiler 1MajorSource SC Boiler 470 470 8400 1989 Stoker/SlopedGrate/Other loadfollowing False Biomass WetBiomassElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 10.039 0.005333 0.033667 0.035 6.64E-05 0.034934 4.6E-06 9.62E-07 3.64E-06FacilityID UnitID UnitCountMajorSourceStateClassificatioCapacity(mmCapacity_NumeriHoursPerYearInstalle CombustorDesign DutyCyclewNOxBurneACTFuelCategoBaselineFuelCat TotalControlCoal % Biomass % Liquid % Gas 2 %MaxFuel% Max FuelBiomass/CoalCombo Boiler?WetBiomass? PM LimitPMEmissionsPMDifference PM %red HCL LimitHCLEmissionsHCLDifference HCl%red Hg LimitHgEmissionsHgDifferenceSCNewSouthCamden WWB1 1MajorSource SC Boiler 92 92 8400 1982 Stoker/SlopedGrate/Other loadfollowing False Biomass WetBiomassElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 10.039 0.248667 -0.20967 84.32% 0.035 0.000867 0.034133 4.6E-06 4.39E-07 4.16E-06SCNewSouthCoConway WWB1 1MajorSource SC Boiler 92 92 8400 1983 Stoker/SlopedGrate/Other loadfollowing False Biomass WetBiomassElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 10.039 0.326667 -0.28767 88.06% 0.035 0.001198 0.033802 4.6E-06 4.76E-07 4.12E-06SCNewSouthLumberCoDarlington BLR1 1MajorSource SC Boiler 28.93 28.93 8400 1994 Stoker/SlopedGrate/Other loadfollowing False Biomass WetBiomass CycloneorMulticloneData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 10.039 0.216333 -0.17733 81.97% 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/ASCNewSouthLumberCoDarlington BLR3 1MajorSource SC Boiler 28.7 28.7 8400 1997 Stoker/SlopedGrate/Other loadfollowing False Biomass WetBiomass CycloneorMulticloneData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 10.039 0.254 -0.215 84.65% 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/ASCRoseburgForestRussellville Boiler 1MajorSource SC Boiler 30.8 30.8 8480 1971 DutchOven/Susp.Burner Base‐loaded False Biomass DryBiomass FabricFilterData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 1.15E-06 3.45E-06SCSimpsonLumberGeorgetown 02 1MajorSource SC Boiler 63.7 63.7 8592 1975 Stoker/SlopedGrate/Other Base‐loaded False Biomass DryBiomassElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/ASCSimpsonLumberGeorgetown B03 1MajorSource SC Boiler 28.7 28.7 8592 1998 Stoker/SlopedGrate/Other Base‐loaded False Biomass DryBiomass CycloneorMulticloneData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/ASCSmurfitStone Unit15:Boiler#3 1MajorSource SC Boiler 343 343 8380 1963 Stoker/SlopedGrate/Other loadfollowing False Biomass DryBiomassElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 0.009167 0.029833 0.035 0.001267 0.033733 4.6E-06 6.67E-07 3.93E-06SCSmurfitStone Unit16:Boiler#4 1MajorSource SC Boiler 955 955 8380 1987 Stoker/SlopedGrate/Other Base‐loaded True Biomass DryBiomassElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 0.018533 0.020467 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/ASCSonocoHartsville BoilerNumber9 1MajorSource SC Boiler 180 180 8111 1997 FB Base‐loaded FalseCoalCoalFabricFilterDrySorbentInjectionData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 0.015022 0.023978 0.035 0.055333 -0.02033 36.75% 4.6E-06 7.63E-07 3.84E-06SCSonocoHartsville BoilerNumber3 1MajorSource SC Boiler 178 178 8345 1950 PC Base‐loaded FalseCoalCoalElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 0.41 -0.371 90.49% 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/ASCSonocoHartsville BoilerNumber4 1MajorSource SC Boiler 380 380 8400 1957 Stoker/SlopedGrate/Other loadfollowing FalseCoalCoal FabricFilterData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 0.005667 0.033333 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/ASCWestFraserNewberry B2 1MajorSource SC Boiler 28.7 28.7 8169 1996 Stoker/SlopedGrate/Other loadfollowing False Biomass WetBiomass CycloneorMulticloneData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 10.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/ASCWestFraserNewberry B3 1MajorSource SC Boiler 28.7 28.7 8196 1996 Stoker/SlopedGrate/Other loadfollowing False Biomass WetBiomass CycloneorMulticloneData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 10.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/ASCWestFraserNewberry B1 1MajorSource SC Boiler 28.7 28.7 8386 1996 Stoker/SlopedGrate/Other loadfollowing False Biomass WetBiomass CycloneorMulticloneData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 10.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/ATNArborCraft B‐1 1MajorSource TN Boiler 17.14 17.14 8000 1990 Stoker/SlopedGrate/Other Base‐loaded False Biomass DryBiomass CycloneorMulticloneData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/ATNArborCraft B‐2 1MajorSource TN Boiler 17.14 17.14 8000 1990 Stoker/SlopedGrate/Other Base‐loaded False Biomass DryBiomass CycloneorMulticloneData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/ATNBowaterNewsprint PowerBoilerNo.1 1MajorSource TN Boiler 214 214 8600 1956 PC loadfollowing FalseCoalCoalElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 0.026 0.013 0.035 0.008667 0.026333 4.6E-06 6.93E-06 -2.3E-06TNBowaterNewsprint PowerBoilerNo.2 1MajorSource TN Boiler 460 460 8600 1957 PC loadfollowing TrueCoalCoalElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/ATNBowaterNewsprint PowerBoilerNo.3 1MajorSource TN Boiler 460 460 8600 1957 PC loadfollowing TrueCoalCoalElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 0.013 0.026 0.035 0.008 0.027 4.6E-06 2.77E-06 1.83E-06TNBowaterNewsprintBubblingFluidizedBedBoiler 1MajorSource TN Boiler 877 877 8600 1997 FB Base‐loaded False Biomass WetBiomassElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 10.039 0.034 0.005 0.035 0.009233 0.025767 4.6E-06 3.57E-07 4.24E-06TNDomtar2384 HFB1‐1 1MajorSource TN Boiler 544 544 8760 1998 FB Base‐loaded True Biomass DryBiomassElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 0.096 -0.057 59.38% 0.035 0.0031 0.0319 4.6E-06 8.1E-07 3.79E-06TNPackagingCorpCounceCombination Boiler#2 1 TN Boiler 860860Stoker/SlopedGrate/Other#N/ABiomass Wet BiomassElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 10.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/ATNPackagingCorpCounceCombinationBoiler#1 1MajorSource TN Boiler 400 400 5689 1961 N/A Standby False Liquid HeavyLiquid NoHAPAPCDControlData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.0075 N/A N/A #VALUE! 0.00033 0.011864 -0.01153 97.22% 3.5E-06 N/A N/ATXAnthonyForestProd‐ATL EP10.1Superior 1MajorSource TX Boiler 24 24 8592 1996 Stoker/SlopedGrate/Other Base‐loaded False Biomass WetBiomass CycloneorMulticloneData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 10.039 0.114067 -0.07507 65.81% 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/ATXAnthonyForestProd‐ATL EP11.1Hurst 1MajorSource TX Boiler 28.7 28.7 8592 1997 Stoker/SlopedGrate/Other Base‐loaded False Biomass WetBiomass CycloneorMulticloneData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 10.039 0.142 -0.103 72.54% 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/ATXDibollTemple‐Inland COEN 1MajorSource TXProcessHeater 28 28 7500 1989 DutchOven/Susp.Burner loadfollowing False Biomass DryBiomass CycloneorMulticloneData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/ATXDibollTemple‐Inland PB‐44 1MajorSource TX Boiler 40 40 7500 1970 DutchOven/Susp.Burner loadfollowing False Biomass DryBiomassElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 N/A N/A #VALUE! 0.035 2.65E-05 0.034973 4.6E-06 1.26E-06 3.34E-06TXGPClevelandPlyLumber GRP‐SBOIL 1MajorSource TX Boiler 289.8 289.8 8568 1979 Stoker/SlopedGrate/Other loadfollowing False Biomass WetBiomass VenturiScrubberData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 10.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/ATXInternationalPaperQueenCity PB02 1MajorSource TX Boiler 108410848400 Stoker/SlopedGrate/Other#N/ABiomass Wet Biomass venturi ScrubberData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 10.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/ATXLPCarthageTOHPrimaryWoodBurner 1MajorSource TXProcessHeater 32 32 8600 1996 Stoker/SlopedGrate/Other loadfollowing False Biomass DryBiomassElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/ATXLPJasperOSBSuspensionBurner#3 1MajorSource TXProcessHeater 125.9642 125.9642 5613 1993 Stoker/SlopedGrate/Other loadfollowing False Biomass DryBiomassElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/ATXLPJasperOSBThermalOilHeater‐Wood 1MajorSource TXProcessHeater 34 34 7200 1993 DutchOven/Susp.Burner loadfollowing False Biomass DryBiomassElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/ATXMeadWestvacoEvadale 21‐2081 1MajorSource TX Boiler 318 318 8400 1994 Stoker/SlopedGrate/Other Standby True Biomass WetBiomass NoHAPAPCDControlData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 10.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/ATXNorbordTexasJefferson NorthTeaford 1MajorSource TXProcessHeater 175 175 7000 2005 Stoker/SlopedGrate/Other Base‐loaded True Biomass WetBiomassElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 10.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/ATXNorbordTexasJefferson SouthTeaford 1MajorSource TXProcessHeater 175 175 7000 2005 Stoker/SlopedGrate/Other Base‐loaded True Biomass WetBiomassElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 10.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/ATXNorbordTexasNacogdoches CoreMcConnell 1MajorSource TXProcessHeater 40 40 8000 1986 DutchOven/Susp.Burner Base‐loaded False Biomass DryBiomassElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/ATXNorbordTexasNacogdoches KonusNo.1 1MajorSource TXProcessHeater 16 16 8000 1986 FuelCell Base‐loaded False Biomass WetBiomassElectrifiedFilterBed(EFB)Data NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 10.039 0.037333 0.001667 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/ATXNorbordTexasNacogdoches KonusNo.2 1MajorSource TXProcessHeater 16 16 8000 1986 FuelCell Base‐loaded False Biomass WetBiomassElectrifiedFilterBed(EFB)Data NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 10.039 0.037333 0.001667 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/ATXNorbordTexasNacogdoches SurfaceMcConnell 1MajorSource TXProcessHeater 40 40 8000 1986 DutchOven/Susp.Burner Base‐loaded False Biomass DryBiomassElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/ATXNorbordTexasNacogdoches Teaford 1MajorSource TXProcessHeater 60 60 8000 2006 Stoker/SlopedGrate/Other Base‐loaded True Biomass WetBiomassElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 10.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/ATXPinelandTemple‐Inland EPN22 1MajorSource TX Boiler 175 175 8000 1973 Stoker/SlopedGrate/Other loadfollowing False Biomass WetBiomassElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 10.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AFacilityID UnitID UnitCountMajorSourceStateClassificatioCapacity(mmCapacity_NumeriHoursPerYearInstalle CombustorDesign DutyCyclewNOxBurneACTFuelCategoBaselineFuelCat TotalControlCoal % Biomass % Liquid % Gas 2 %MaxFuel% Max FuelBiomass/CoalCombo Boiler?WetBiomass? PM LimitPMEmissionsPMDifference PM %red HCL LimitHCLEmissionsHCLDifference HCl%red Hg LimitHgEmissionsHgDifferenceTXPinelandTemple‐Inland EPN91 1MajorSource TXProcessHeater 22 22 8000 1985 DutchOven/Susp.Burner loadfollowing False Biomass DryBiomass NoHAPAPCDControlData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/ATXPinelandTemple‐Inland EPN92 1MajorSource TXProcessHeater 22 22 8000 2005 DutchOven/Susp.Burner loadfollowing False Biomass DryBiomass NoHAPAPCDControlData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/ATXTempleInlandFiberboard FB‐25 1MajorSource TX Boiler 230 230 8640 1979 Stoker/SlopedGrate/Other loadfollowing False Biomass DryBiomass WetScrubberData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 1.03E-06 3.57E-06TXTemple‐InlandOrange BarkBoiler 1MajorSource TX Boiler 394 394 8760 0 Stoker/SlopedGrate/Other False Biomass WetBiomass VenturiScrubberData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 10.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/ATXwestfraser Boiler‐1 1MajorSource TX Boiler 90.7 90.7 8472 1980 Stoker/SlopedGrate/Other loadfollowing False Biomass WetBiomass WetScrubberData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 10.039 0.045165 -0.00616 13.65% 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AVAATCPanelsBabcock&WilcoxBoiler 1MajorSource VA Boiler 46 46 8280 1971 DutchOven/Susp.Burner loadfollowing False Biomass DryBiomass CycloneorMulticloneData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 2.03E-06 2.57E-06VAATCPanels CoenBurner 1MajorSource VAProcessHeater 40 40 8280 1989 Stoker/SlopedGrate/Other loadfollowing False Biomass DryBiomass CycloneorMulticloneData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AVABassettFiberboard BL2 1MajorSource VA Boiler 35 35 6000 1977 Stoker/SlopedGrate/Other loadfollowing False Biomass DryBiomass CycloneorMulticloneData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AVABassettFiberboard BL1 1MajorSource VA Boiler 25.1 25.1 8400 1969 N/A loadfollowing False Liquid LightLiquid NoHAPAPCDControlData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.0075 N/A N/A #VALUE! 0.00033 N/A N/A #VALUE! 3.5E-06 N/A N/AVABearIslandPaperCoAshlandUnitRef#2(ComboBoiler) 1MajorSource VA Boiler 243 243 8760 1979 Stoker/SlopedGrate/Other loadfollowing False Biomass DryBiomassElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 N/A N/A #VALUE! 0.035 0.0897 -0.0547 60.98% 4.6E-06 2.7E-06 1.9E-06VAGeorgiaPacificBrooknealGladys 5600 1MajorSource VAProcessHeater 240 240 8000 1995 FuelCell loadfollowing False Biomass WetBiomassElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 10.039 2.443333 -2.40433 98.40% 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AVAGeorgiaPacificEmporia WWB 1MajorSource VA Boiler 179.4 179.4 8500 1977 Stoker/SlopedGrate/Other loadfollowing False Biomass DryBiomass WetScrubberData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 0.204667 -0.16567 80.94% 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AVAGPBigIsland2703PWR04‐No.4PowerBoiler 1MajorSource VA Boiler 284 284 8529 1943 PC Base‐loaded TrueCoalCoalElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 0.013129 0.025871 0.035 0.013053 0.021947 4.6E-06 2.5E-06 2.1E-06VAGPBigIsland2703PWR05‐No.5PowerBoiler 1MajorSource VA Boiler 334 334 8567 1947 Stoker/SlopedGrate/Other loadfollowing False Biomass WetBiomassElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 10.039 0.021033 0.017967 0.035 0.00948 0.02552 4.6E-06 4.87E-07 4.11E-06VAGPJarrattFiberboardEP‐15No.3KeelerBoiler 1MajorSource VA Boiler 86.6 86.6 8400 1978 Stoker/SlopedGrate/Other loadfollowing FalseCoalCoal CycloneorMulticloneData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 N/A N/A #VALUE! 0.035 0.013667 0.021333 4.6E-06 7.4E-06 -2.8E-06VAGreif BLR01 1MajorSource VA Boiler 225 225 5141 1975 N/A loadfollowing True Liquid HeavyLiquid NoHAPAPCDControlData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.0075 N/A N/A #VALUE! 0.00033 N/A N/A #VALUE! 3.5E-06 N/A N/AVAGreif BLR05 1MajorSource VA Boiler 244 244 8640 2000 Stoker/SlopedGrate/Other Base‐loaded True Biomass WetBiomassElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 10.039 0.004563 0.034437 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AVAGreif BLR02 1MajorSource VA Boiler 225 225 8640 1975 N/A loadfollowing False Liquid HeavyLiquid NoHAPAPCDControlData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.0075 N/A N/A #VALUE! 0.00033 N/A N/A #VALUE! 3.5E-06 N/A N/AVAMeadWestVaco‐CovingtonVA PWR007 1MajorSource VA Boiler 440 440 8200 1950 Stoker/SlopedGrate/Other loadfollowing FalseCoalCoalDryScrubberElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 0.0378 0.0012 0.035 N/A N/A #VALUE! 4.6E-06 1.29E-06 3.31E-06VAMeadWestVaco‐CovingtonVA PWR008 1MajorSource VA Boiler 580 580 8300 1955 Stoker/SlopedGrate/Other loadfollowing FalseCoalCoalDryScrubberElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 0.0378 0.0012 0.035 N/A N/A #VALUE! 4.6E-06 1.29E-06 3.31E-06VAMeadWestVaco‐CovingtonVA PWR009 1MajorSource VA Boiler 807 807 8500 1964 Stoker/SlopedGrate/Other Base‐loaded TrueCoalCoalDryScrubberElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 0.0378 0.0012 0.035 N/A N/A #VALUE! 4.6E-06 1.29E-06 3.31E-06VAMeadWestVaco‐CovingtonVA PWR006 1MajorSource VA Boiler 550 550 8600 1940 PC Base‐loaded TrueCoalCoalDryScrubberElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 0.0378 0.0012 0.035 N/A N/A #VALUE! 4.6E-06 1.29E-06 3.31E-06VASmurfitStoneHopewell CombinationBoiler 1MajorSource VA Boiler 846 846 8575 1979 PC loadfollowing FalseCoalCoalElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 0.021297 0.017703 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AVASmurfitStoneWestpt PB08 1MajorSource VA Boiler 553 553 8047 1964 PC loadfollowing TrueCoalCoalElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 0.013753 0.025247 0.035 0.007381 0.027619 4.6E-06 9.48E-07 3.65E-06VASmurfitStoneWestpt PB10 1MajorSource VA Boiler 659 659 8285 1981 Stoker/SlopedGrate/Other Base‐loaded False Biomass WetBiomassElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 10.039 0.024411 0.014589 0.035 0.002882 0.032118 4.6E-06 5.5E-06 -9E-07WABoiseKettleFallsPlywood B1 1MajorSource WA Boiler 45 45 8400 1975 Stoker/SlopedGrate/Other Base‐loaded False Biomass DryBiomassCycloneorMulticlone/ElectrifiedFilterBed(EFB)Data NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 0.01804 0.02096 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AWABoisePaperWallula HogFuelBoiler 1MajorSource WA Boiler 270.25 270.25 8500 1978 Stoker/SlopedGrate/Other loadfollowing False Biomass DryBiomassVenturiScrubberElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 N/A N/A #VALUE! 0.035 8.93E-05 0.034911 4.6E-06 N/A N/AWAGPCamas No.3PowerBoiler 1MajorSource WA Boiler 276 276 8000 1948 Stoker/SlopedGrate/Other loadfollowing True Biomass DryBiomassElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 N/A N/A #VALUE! 0.035 0.000335 0.034665 4.6E-06 9.96E-07 3.6E-06WAGPCamas No.5PowerBoiler 1MajorSource WA Boiler 318 318 8340 1970 N/A loadfollowing True Liquid HeavyLiquid VenturiScrubberData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.0075 N/A N/A #VALUE! 0.00033 N/A N/A #VALUE! 3.5E-06 N/A N/AWAGraysHarborPaper No.6Boiler(EU2) 1MajorSource WA Boiler 210 210 4750 1952 DutchOven/Susp.Burner False Biomass WetBiomass VenturiScrubberData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 10.039 0.204333 -0.16533 80.91% 0.035 0.044967 -0.00997 22.16% 4.6E-06 2.74E-06 1.86E-06WAGraysHarborPaper No.8Boiler(EU1) 1MajorSource WA Boiler 400 400 7646 1976 Stoker/SlopedGrate/Other loadfollowing False Biomass WetBiomass WetScrubberData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 10.039 0.11 -0.071 64.55% 0.035 0.003667 0.031333 4.6E-06 2.42E-06 2.18E-06WAJeldWenWhiteSwan Boiler1 1MajorSource WA Boiler 47.3 47.3 8400 1984 Stoker/SlopedGrate/Other loadfollowing False Biomass DryBiomassElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AWAJeldWenWhiteSwan Boiler2 1MajorSource WA Boiler 37.8 37.8 3000 1997 N/A loadfollowing False Liquid LightLiquid NoHAPAPCDControlData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.0075 N/A N/A #VALUE! 0.00033 N/A N/A #VALUE! 3.5E-06 N/A N/AWAKimberlyClarkEverettNo.14CogenerationBoiler 1MajorSource WA Boiler 435 435 8180 1995 Stoker/SlopedGrate/Other Base‐loaded True Biomass DryBiomass FabricFilterData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 0.006558 0.032442 0.035 0.094873 -0.05987 63.11% 4.6E-06 1.83E-06 2.77E-06WANipponPaper #9PackageBoiler 1MajorSource WA Boiler 115 115 1600 1964 N/A Standby False Liquid HeavyLiquid NoHAPAPCDControlData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.0075 0.041136 -0.03364 81.77% 0.00033 N/A N/A #VALUE! 3.5E-06 N/A N/AWANipponPaper #8HogFuelBoiler 1MajorSource WA Boiler 161 161 8550 1953 Stoker/SlopedGrate/Other Base‐loaded False Biomass DryBiomass VenturiScrubberData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 0.093943 -0.05494 58.49% 0.035 0.006333 0.028667 4.6E-06 2.03E-06 2.57E-06WANipponPaper #10PackageBoiler 1MajorSource WA Boiler 115 115 3000 1982 N/A Standby False Liquid HeavyLiquid NoHAPAPCDControlData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.0075 0.030633 -0.02313 75.52% 0.00033 N/A N/A #VALUE! 3.5E-06 N/A N/AWAPonderayAbibo FBBboiler 1MajorSource WA Boiler 64 64 8600 0 FB False Biomass DryBiomassFabricFilterDrySorbentInjectionData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AWAPort Townsend Power Boiler 1 Major SourWA Boiler 188 188 N/A#N/ALiquid Heavy Liquid No HAP APCD ControlData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.0075 N/A N/A #VALUE! 0.00033 N/A N/A #VALUE! 3.5E-06 N/A N/AWASierraPacific Co‐Gen 1MajorSource WA Boiler 287.5 287.5 8400 2006 Stoker/SlopedGrate/Other Base‐loaded True Biomass DryBiomass NoHAPAPCDControlData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AWASimpsonLumberCompany EU1 1MajorSource WA Boiler 185 185 8500 1986 Stoker/SlopedGrate/Other loadfollowing False Biomass DryBiomassElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 2.5E-06 2.1E-06WASimpsonTacoma2784 #7PB 1MajorSource WA Boiler 345 345 8700 1991 Stoker/SlopedGrate/Other loadfollowing True Biomass DryBiomassElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 0.004627 0.034373 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AFacilityID UnitID UnitCountMajorSourceStateClassificatioCapacity(mmCapacity_NumeriHoursPerYearInstalle CombustorDesign DutyCyclewNOxBurneACTFuelCategoBaselineFuelCat TotalControlCoal % Biomass % Liquid % Gas 2 %MaxFuel% Max FuelBiomass/CoalCombo Boiler?WetBiomass? PM LimitPMEmissionsPMDifference PM %red HCL LimitHCLEmissionsHCLDifference HCl%red Hg LimitHgEmissionsHgDifferenceWAWeyerhaeuser_RaymondHogFuelBoilerEU1 1MajorSource WA Boiler 115 115 8550 1996 FuelCell loadfollowing False Biomass DryBiomassElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 0.001317 0.037683 0.035 0.000267 0.034733 4.6E-06 1.86E-06 2.74E-06WAWeyerhaeuserLongviewNo.11HogFuelBoiler 1MajorSource WA Boiler 632.5 632.5 8400 1975 Stoker/SlopedGrate/Other loadfollowing False Biomass DryBiomassDuctSorbentInjectionElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 0.002667 0.036333 0.035 0.021667 0.013333 4.6E-06 N/A N/AWIAlgoma B02 1MajorSource WI Boiler 21 21 3949 1986 Stoker/SlopedGrate/Other loadfollowing False Biomass DryBiomass NoHAPAPCDControlData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AWIAlgoma B03 1MajorSource WI Boiler 34 34 4751 1987 Stoker/SlopedGrate/Other loadfollowing False Biomass DryBiomass NoHAPAPCDControlData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AWIAppletonB22CoalFiredBoiler 1MajorSource WI Boiler 44 44 8232 1947 Stoker/SlopedGrate/Other Base‐loaded FalseCoalCoal CycloneorMulticloneData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 1.3E-06 3.3E-06WIAppletonCoated B23 1MajorSource WI Boiler 341 341 8520 1985 Stoker/SlopedGrate/Other Base‐loaded TrueCoalCoalElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AWIDomtar2814 B11,S11 1MajorSource WI Boiler 120 120 7728 1972 Stoker/SlopedGrate/Other Base‐loaded False Biomass WetBiomassElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 10.039 0.0031 0.0359 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AWIDomtar2814 B10,S10 1MajorSource WI Boiler 200 200 8400 1976 N/A Base‐loaded False Liquid LightLiquid NoHAPAPCDControlData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.0075 N/A N/A #VALUE! 0.00033 N/A N/A #VALUE! 3.5E-06 N/A N/AWIDomtarNekoosa B22‐BoilerNo.7 1MajorSource WI Boiler 148.4 148.4 1468 1942 Stoker/SlopedGrate/Other Standby FalseCoalCoalElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 0.0209 0.0181 0.035 0.10514 -0.07014 66.71% 4.6E-06 3.93E-06 6.7E-07WIDomtarNekoosa B20‐BoilerNo.1 1MajorSource WI Boiler 153.4 153.4 8640 1947 PC loadfollowing FalseCoalCoalElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 0.0209 0.0181 0.035 0.10514 -0.07014 66.71% 4.6E-06 3.93E-06 6.7E-07WIDomtarNekoosa B21‐BoilerNo.2 1MajorSource WI Boiler 153.4 153.4 8640 1952 PC loadfollowing FalseCoalCoalElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 0.0209 0.0181 0.035 0.10514 -0.07014 66.71% 4.6E-06 3.93E-06 6.7E-07WIDomtarNekoosa B24‐BoilerNo.10 1MajorSource WI Boiler 303.2 303.2 8640 1966 Stoker/SlopedGrate/Other Base‐loaded FalseCoalCoalElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 0.0209 0.0181 0.035 0.10514 -0.07014 66.71% 4.6E-06 3.93E-06 6.7E-07WIFlambeauRiverPaper B24 1MajorSource WI Boiler 249 249 8400 1982 Stoker/SlopedGrate/Other Base‐loaded False Biomass WetBiomass VenturiScrubberData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 10.039 0.061083 -0.02208 36.15% 0.035 0.004577 0.030423 4.6E-06 3.03E-06 1.57E-06WIGPGreenBay2818B25‐StokerBoiler#5 1MajorSource WI Boiler 200 200 4080 1950 Stoker/SlopedGrate/Other Standby FalseCoalCoal FabricFilterData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 11.29802 -11.259 99.65% 0.035 N/A N/A #VALUE! 4.6E-06 1.39E-06 3.21E-06WIGPGreenBay2818B29‐FluidizedBedBoiler#9 1MajorSource WI Boiler 486 486 7896 1992 FB Base‐loaded FalseCoalCoalFabricFilterDrySorbentInjectionData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 0.990467 -0.95147 96.06% 0.035 0.002828 0.032172 4.6E-06 4.3E-07 4.17E-06WIGPGreenBay2818B26‐StokerBoiler#6 1MajorSource WI Boiler 350 350 8304 1962 Stoker/SlopedGrate/Other loadfollowing FalseCoalCoal FabricFilterData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 3.059554 -3.02055 98.73% 0.035 0.039678 -0.00468 11.79% 4.6E-06 3.56E-06 1.04E-06WIGPGreenBay2818B28‐StokerBoiler#8 1MajorSource WI Boiler 235 235 8304 1975 Stoker/SlopedGrate/Other loadfollowing FalseCoalCoal FabricFilterData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 3.975124 -3.93612 99.02% 0.035 0.039678 -0.00468 11.79% 4.6E-06 3.56E-06 1.04E-06WIGPGreenBay2818B27‐CycloneBoiler#7 1MajorSource WI Boiler 615 615 8328 1969 Stoker/SlopedGrate/Other loadfollowing FalseCoalCoal FabricFilterData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 1.408985 -1.36998 97.23% 0.035 0.039678 -0.00468 11.79% 4.6E-06 3.56E-06 1.04E-06WIGPGreenBay2818B10WastepaperSludge‐FiredBoiler10 1MajorSource WI Boiler 95 95 8376 1998 FB Base‐loaded True Biomass WetBiomass FabricFilterData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 10.039 0.002017 0.036983 0.035 0.072067 -0.03707 51.43% 4.6E-06 1.07E-05 -6.1E-06WIGreenBayPackagingMillDivisionBoilerB26‐CoalFiredBoiler 1MajorSource WI Boiler 229 229 8760 1977 Stoker/SlopedGrate/Other loadfollowing FalseCoalCoal FabricFilterData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 0.00064 0.03836 0.035 0.172 -0.137 79.65% 4.6E-06 1.03E-06 3.57E-06WILPHayward K1Line1Konus 1MajorSource WIProcessHeater 19.4 19.4 6575 1979 Stoker/SlopedGrate/Other loadfollowing False Biomass WetBiomassElectrifiedFilterBed(EFB)Data NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 10.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AWILPHayward K2Line1Konus 1MajorSource WIProcessHeater 19.4 19.4 6575 1979 Stoker/SlopedGrate/Other loadfollowing False Biomass WetBiomassElectrifiedFilterBed(EFB)Data NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 10.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AWILPHayward K3Line2Konus 1MajorSource WIProcessHeater 23.8 23.8 6575 1981 Stoker/SlopedGrate/Other loadfollowing False Biomass WetBiomassElectrifiedFilterBed(EFB)Data NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 10.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AWILPHayward K4Line2Konus 1MajorSource WIProcessHeater 23.8 23.8 6575 1981 Stoker/SlopedGrate/Other loadfollowing False Biomass WetBiomassElectrifiedFilterBed(EFB)Data NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 10.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AWINeenahPaperAppleton UnionBoiler(B22) 1MajorSource WI Boiler 60 60 5900 1957 N/A loadfollowing False Liquid HeavyLiquid NoHAPAPCDControlData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.0075 N/A N/A #VALUE! 0.00033 N/A N/A #VALUE! 3.5E-06 N/A N/AWINewPageBiron B24 1MajorSource WI Boiler 445.16 445.16 8324 1986 Stoker/SlopedGrate/Other loadfollowing FalseCoalCoalElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 0.003733 0.035267 0.035 0.000587 0.034413 4.6E-06 2.69E-06 1.91E-06WINewPageBiron B23 1MajorSource WI Boiler 340 340 8349 1958 PC Base‐loaded FalseCoalCoalElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 0.033667 0.005333 0.035 0.076167 -0.04117 54.05% 4.6E-06 7.69E-06 -3.1E-06WINewPageKimberly B21 1MajorSource WI Boiler 137.5 137.5 8760 1951 Stoker/SlopedGrate/Other Base‐loaded FalseCoalCoalElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 0.089933 -0.05093 56.63% 0.035 0.154333 -0.11933 77.32% 4.6E-06 1.73E-06 2.87E-06WINewPageKimberly B22 1MajorSource WI Boiler 165 165 8760 1957 Stoker/SlopedGrate/Other Base‐loaded FalseCoalCoalElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 0.089933 -0.05093 56.63% 0.035 0.154333 -0.11933 77.32% 4.6E-06 1.73E-06 2.87E-06WINewPage‐Whiting B24 1MajorSource WI Boiler 211.4 211.4 8626 1976 Stoker/SlopedGrate/Other loadfollowing False Biomass WetBiomassElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 10.039 0.054767 -0.01577 28.79% 0.035 0.002733 0.032267 4.6E-06 8.69E-06 -4.1E-06WINewPage‐WisconsinRapidsPowerBoiler1‐B21 1MajorSource WI Boiler 412.3 412.3 8623 1966 Stoker/SlopedGrate/Other loadfollowing False Biomass WetBiomassElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 10.039 0.018033 0.020967 0.035 0.0008 0.0342 4.6E-06 2.28E-06 2.32E-06WINewPage‐WisconsinRapidsPowerBoiler2‐B20 1MajorSource WI Boiler 412.3 412.3 8623 1966 Stoker/SlopedGrate/Other loadfollowing False Biomass WetBiomassElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 10.039 0.009833 0.029167 0.035 0.0009 0.0341 4.6E-06 1.85E-06 2.75E-06WIPCATomahawk B24 1MajorSource WI Boiler 250.6 250.6 8312 1977 Stoker/SlopedGrate/Other Base‐loaded False Biomass DryBiomassElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 0.044833 -0.00583 13.01% 0.035 0.167533 -0.13253 79.11% 4.6E-06 N/A N/AWIPCATomahawk B27 1MajorSource WI Boiler 122 122 8381 1955 Stoker/SlopedGrate/Other Base‐loaded False Biomass DryBiomassElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 0.044833 -0.00583 13.01% 0.035 0.167533 -0.13253 79.11% 4.6E-06 N/A N/AWIPCATomahawk B28 1MajorSource WI Boiler 190.9 190.9 8397 1956 Stoker/SlopedGrate/Other Base‐loaded False Biomass DryBiomassElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 0.044833 -0.00583 13.01% 0.035 0.167533 -0.13253 79.11% 4.6E-06 N/A N/AWIThilmanyLLC B07 1MajorSource WI Boiler 204 204 7989 1948 Stoker/SlopedGrate/Other loadfollowing False Biomass WetBiomass WetScrubberData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 10.039 0.211333 -0.17233 81.55% 0.035 0.012647 0.022353 4.6E-06 5.16E-06 -5.6E-07WIThilmanyLLC B11 1MajorSource WI Boiler 379 379 8400 1967 Stoker/SlopedGrate/Other loadfollowing FalseCoalCoalElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 0.1799 -0.1409 78.32% 0.035 0.2072 -0.1722 83.11% 4.6E-06 1.85E-06 2.76E-06WIThilmanyLLC B09 1MajorSource WI Boiler 192.4 192.4 8657 1957 Stoker/SlopedGrate/Other FalseCoalCoalElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 0.1799 -0.1409 78.32% 0.035 0.2072 -0.1722 83.11% 4.6E-06 1.85E-06 2.76E-06WIThilmanyPapersNicoletMill B23 1MajorSource WI Boiler 105 105 8616 1960 Stoker/SlopedGrate/Other loadfollowing FalseCoalCoalElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 0.002939 0.036061 0.035 0.088 -0.053 60.23% 4.6E-06 2.86E-06 1.74E-06WIThilmanyPapersNicoletMill B24 1MajorSource WI Boiler 105 105 8616 1963 Stoker/SlopedGrate/Other loadfollowing FalseCoalCoalElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 0.002939 0.036061 0.035 0.088 -0.053 60.23% 4.6E-06 2.86E-06 1.74E-06WIWausau#5PowerBoiler(B24) 1MajorSource WI Boiler 143 143 8520 1966 Stoker/SlopedGrate/Other loadfollowing FalseCoalCoalElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 0.002307 0.036693 0.035 0.061333 -0.02633 42.93% 4.6E-06 3.52E-06 1.08E-06WIWausau#6PowerBoiler(B20) 1MajorSource WI Boiler 211.7 211.7 8600 1975 Stoker/SlopedGrate/Other loadfollowing FalseCoalCoalElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 0.008287 0.030713 0.035 0.055967 -0.02097 37.46% 4.6E-06 3.2E-06 1.4E-06FacilityID UnitID UnitCountMajorSourceStateClassificatioCapacity(mmCapacity_NumeriHoursPerYearInstalle CombustorDesign DutyCyclewNOxBurneACTFuelCategoBaselineFuelCat TotalControlCoal % Biomass % Liquid % Gas 2 %MaxFuel% Max FuelBiomass/CoalCombo Boiler?WetBiomass? PM LimitPMEmissionsPMDifference PM %red HCL LimitHCLEmissionsHCLDifference HCl%red Hg LimitHgEmissionsHgDifferenceWIWausauRhine B20 1MajorSource WI Boiler 91 91 3000 1934 Stoker/SlopedGrate/Other Base‐loaded FalseCoalCoal FabricFilterData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 0.021 0.018 0.035 N/A N/A #VALUE! 4.6E-06 2.42E-06 2.18E-06WIWausauRhine B21 1MajorSource WI Boiler 91 91 3000 1929 Stoker/SlopedGrate/Other Base‐loaded FalseCoalCoal FabricFilterData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 0.021 0.018 0.035 N/A N/A #VALUE! 4.6E-06 2.42E-06 2.18E-06WIWausauRhine B22 1MajorSource WI Boiler 91 91 3000 1929 Stoker/SlopedGrate/Other Base‐loaded FalseCoalCoal FabricFilterData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 0.021 0.018 0.035 N/A N/A #VALUE! 4.6E-06 2.42E-06 2.18E-06WIWausauRhine B23 1MajorSource WI Boiler 91 91 3000 1941 Stoker/SlopedGrate/Other Base‐loaded FalseCoalCoal FabricFilterData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 0.021 0.018 0.035 N/A N/A #VALUE! 4.6E-06 2.42E-06 2.18E-06WIWausauRhine B26 1MajorSource WI Boiler 300 300 8600 1958 Stoker/SlopedGrate/Other Base‐loaded FalseCoalCoalElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 0.008933 0.030067 0.035 0.010343 0.024657 4.6E-06 1.01E-06 3.59E-06WVGPMtHopeOSB5600‐WellonsEnergySystem 1MajorSource WVProcessHeater 240 240 8000 1995 FuelCell loadfollowing False Biomass DryBiomassElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 0.044333 -0.00533 12.03% 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AWVJELD‐WENCraigsville WoodFiredBoiler 1MajorSource WV Boiler 62.5 62.5 8760 1998 Stoker/SlopedGrate/Other loadfollowing False Biomass DryBiomassElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 N/A N/A #VALUE! 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/AWVWeyerhaeuserBuckhannon 001‐01 1MajorSource WVProcessHeater 116 116 8376 1995 Stoker/SlopedGrate/Other loadfollowing False Biomass DryBiomassElectrostaticPrecipitatorData NotProvidedData NotProvidedData NotProvidedData NotProvided0 Data NotPno 00.039 0.003841 0.035159 0.035 N/A N/A #VALUE! 4.6E-06 N/A N/ARepresents Biomass, Coal, Liquid, Gas2NewInInventoryAdded to Old, not in New (probably didn't get ICR) CISWI units kept in CISWI, not hereShaded units indicate changes to EPA inventoryDeleted limited use units 554 Subtotal for filtered units (F9 to update)1593 Total Unit Countall boilers: green 332 216 311all boilers: red 294 237 90FacilityIDALAbitibiBowaterCPALAbitibiBowaterCPALAbitibiBowaterCPALAbitibiBowaterCPALBoiseWhitePaperJacksonALBrewtonALChapmanForestProductsALChapmanForestProductsALChapmanForestProductsALGeorgiaPacificNaheolaALGeorgiaPacificNaheolaALGeorgiaPacificNaheolaALGPBelkLumberALGPBrewtonMillALGPBrewtonMillALGPBrewtonMillALGPEngineeredWoodProductsThornsbyALGPPetermanPlyALGPTalladegaPlyALGulfLumberALIPCourtlandALIPCourtlandALIPCourtlandALIPPineHillALIPPineHillALIPPrattvilleALIPPrattvilleALIPRiverdaleALK‐CMobileALK‐CMobileALManningtonWoodFloorsALManningtonWoodFloorsALMeadwestvacoCottonton46ALMeadwestvacoCottonton46ALMeadwestvacoCottonton46ALP&WAlabamaRiverALP&WAlabamaRiverALP&WAlabamaRiverALRock‐TennDemopolisALRock‐TennDemopolisALScotchLumberALSeamanTimberHg %redDioxinLimitDioxinEmissionsDioxinDifferenceDioxin%red CO LimitCOEmissionsCODifference CO %redHClControlGroupHgControlGroupPMControlGroupMetalsControlGroupNAICSPM NeedUpgrade?HCl NeedUpgrade?Hg NeedUpgrade?DioxinNeedUpgrade?CO NeedUpgrade? PM Upgrade Cost HCl Upgrade Cost Hg/Dioxin Upgrade Cost CO Upgrade Cost Total Capital CostTotal AnnualizedCapital CostAnnual OperatingCosts for New FFfor PMAnnual OperatingCosts for new WSfor HClAnnual OperatingCost for CarbonInjection for Hg/dioxin#VALUE! 0.004 N/A N/A #VALUE! 160 N/A N/A #VALUE!5 6 2 2 3222 2 2 $4,462,402 $8,924,805 $1,000,000 $0 $14,387,207 $1,579,638 $223,120 $1,368,970 $287,812#VALUE! 0.004 N/A N/A #VALUE! 160 N/A N/A #VALUE!5 6 2 2 3222 2 2 $4,462,402 $8,924,805 $1,000,000 $0 $14,387,207 $1,579,638 $223,120 $1,368,970 $287,812#VALUE! 0.004 N/A N/A #VALUE! 160 N/A N/A #VALUE!5 6 2 2 3222 2 2 $4,462,402 $8,924,805 $1,000,000 $0 $14,387,207 $1,579,638 $223,120 $1,368,970 $287,812#VALUE! 0.004 N/A N/A #VALUE! 160 N/A N/A #VALUE!5 6 2 2 3222 2 2 $4,462,402 $8,924,805 $1,000,000 $0 $14,387,207 $1,579,638 $223,120 $1,368,970 $287,8120.005 0.009345 -0.00434 46.50% 490 400.4394 89.560634 5 3 3 3221 1 $9,759,500 $0 $1,000,000 $0 $10,759,500 $1,181,335 $278,843 $0 $407,962#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 5 5 3211 2 2 $3,205,084 $0 $1,000,000 $1,373,607 $5,578,691 $612,510 $91,574 $0 $63,773#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!4 5 3 3 3211 2 2 $3,696,490 $0 $1,000,000 $1,584,210 $6,280,700 $689,587 $105,614 $0 $80,889#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!4 5 3 3 3211 2 2 $2,580,424 $0 $1,000,000 $1,105,896 $4,686,320 $514,533 $73,726 $0 $44,435#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!4 5 3 3 3211 2 2 $2,580,424 $0 $1,000,000 $1,105,896 $4,686,320 $514,533 $73,726 $0 $44,4350.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 2 2 3222 2 2 $5,499,578 $0 $1,000,000 $4,124,683 $10,624,261 $1,166,487 $274,979 $0 $398,5830.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 2 2 3222 2 2 $4,621,173 $0 $1,000,000 $3,465,880 $9,087,053 $997,710 $231,059 $0 $298,234#VALUE! 4 N/A N/A #VALUE! 10 N/A N/A #VALUE!5 6 6 6 3222 2 2 2 $8,984,989 $10,268,559 $1,000,000 $3,850,710 $24,104,258 $2,646,518 $256,714 $1,201,537 $252,611#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 2 2 3212 2 $0 $0 $1,000,000 $1,385,692 $2,385,692 $261,936 $0 $0 $64,711#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 2 2 3222 2 $0 $0 $1,000,000 $3,917,383 $4,917,383 $539,902 $0 $0 $365,759#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 2 2 3222 2 $0 $0 $1,000,000 $5,113,278 $6,113,278 $671,205 $0 $0 $570,209#VALUE! 4 N/A N/A #VALUE! 10 N/A N/A #VALUE!5 6 6 6 3221 2 2 2 $7,636,120 $8,726,994 $1,000,000 $3,272,623 $20,635,737 $2,265,693 $218,175 $888,904 $186,883#VALUE! 0.005 N/A N/A #VALUE! 490 996.9221 -506.922 50.85%1 4 4 4 3211 2 1 $3,025,524 $0 $1,000,000 $1,296,653 $5,322,177 $584,346 $86,444 $0 $57,931#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 2 2 3212 2 2 $3,744,939 $0 $1,000,000 $2,808,705 $7,553,644 $829,350 $187,247 $0 $210,077#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 2 2 3212 2 2 $3,338,866 $0 $1,000,000 $2,504,150 $6,843,016 $751,326 $166,943 $0 $173,501#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!1 4 4 4 3212 2 2 $3,205,084 $0 $1,000,000 $1,373,607 $5,578,691 $612,510 $91,574 $0 $63,7730.004 N/A N/A #VALUE! 160 170.3968 -10.3968 6.10%2 6 2 2 3222 2 1 $7,639,561 $0 $1,000,000 $5,729,671 $14,369,231 $1,577,664 $381,978 $0 $614,8480.005 N/A N/A #VALUE! 490 160.3697 329.63034 5 3 3 3222 2 $9,252,602 $0 $1,000,000 $0 $10,252,602 $1,125,681 $264,360 $0 $373,2620.02 0.003299 0.016701 430 39.81268 390.18735 6 2 2 322$0 $0 $0 $0 $0 $0 $0 $0 $0#VALUE! 0.004 N/A N/A #VALUE! 160 N/A N/A #VALUE!5 6 2 2 3222 2 $0 $15,711,600 $1,000,000 $0 $16,711,600 $1,834,844 $0 $3,063,767 $644,126#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 2 2 3221 2 2 $7,450,912 $0 $1,000,000 $5,588,184 $14,039,097 $1,541,417 $372,546 $0 $661,179#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 2 2 3221 2 2 $6,964,666 $0 $1,000,000 $5,223,500 $13,188,166 $1,447,990 $348,233 $0 $590,841#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 2 2 3222 2 $0 $0 $1,000,000 $5,597,691 $6,597,691 $724,391 $0 $0 $663,055#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!4 5 3 3 3222 2 2 $6,915,661 $0 $1,000,000 $2,963,855 $10,879,515 $1,194,512 $197,590 $0 $229,772#VALUE! 0.003 N/A N/A #VALUE! 270 N/A N/A #VALUE!4 5 3 3 3222 2 2 2 $13,532,274 $0 $1,000,000 $5,799,546 $20,331,820 $2,232,325 $386,636 $0 $627,396#VALUE! 0.004 N/A N/A #VALUE! 160 N/A N/A #VALUE!5 6 2 2 3222 2 2 $6,062,866 $12,125,733 $1,000,000 $0 $19,188,599 $2,106,805 $303,143 $1,989,459 $418,264#VALUE! 0.005 N/A N/A #VALUE! 490 1309.168 -819.168 62.57%5 6 2 2 3212 1 $0 $0 $1,000,000 $810,040 $1,810,040 $198,733 $0 $0 $26,447#VALUE! 0.005 N/A N/A #VALUE! 490 1309.168 -819.168 62.57%5 6 2 2 3212 1 $0 $0 $1,000,000 $810,040 $1,810,040 $198,733 $0 $0 $26,4470.005 N/A N/A #VALUE! 490 2734.408 -2244.41 82.08%4 5 3 3 3221 2 1 $8,373,595 $0 $1,000,000 $3,588,684 $12,962,279 $1,423,189 $239,246 $0 $316,053#VALUE! 0.005 N/A N/A #VALUE! 490 259.641 230.3595 6 2 2 3222 2 $6,419,683 $0 $1,000,000 $0 $7,419,683 $814,641 $320,984 $0 $515,814#VALUE! 0.005 N/A N/A #VALUE! 490 121.8274 368.17264 5 3 3 3222 $0 $0 $1,000,000 $0 $1,000,000 $109,795 $0 $0 $858,126#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!4 5 3 3 3222 2 2 $9,826,653 $0 $1,000,000 $4,211,423 $15,038,076 $1,651,100 $280,762 $0 $412,651#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 2 2 3222 2 2 $3,392,721 $0 $1,000,000 $2,544,541 $6,937,262 $761,674 $169,636 $0 $178,190#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!4 5 3 3 3222 2 2 $9,826,653 $0 $1,000,000 $4,211,423 $15,038,076 $1,651,100 $280,762 $0 $412,651#VALUE! 0.003 N/A N/A #VALUE! 270 N/A N/A #VALUE!4 5 3 3 3222 2 2 2 $7,000,000 $0 $1,000,000 $3,000,000 $11,000,000 $1,207,741 $200,000 $0 $239,844#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!4 5 3 3 3222 2 2 $6,571,183 $0 $1,000,000 $2,816,221 $10,387,404 $1,140,481 $187,748 $0 $211,015#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 5 5 3212 2 2 $4,003,094 $0 $1,000,000 $1,715,612 $6,718,706 $737,678 $114,374 $0 $92,378#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 5 5 3212 2 2 $1,910,131 $0 $1,000,000 $818,628 $3,728,759 $409,398 $54,575 $0 $26,267FacilityIDALSmurfit‐StoneALSmurfit‐StoneALSmurfit‐StoneALSmurfit‐StoneALWesterveltALWesterveltALWestFraserCitronelleALWestFraserMaplesvilleALWeyerhaeuserMillportARAnthonyForestProductsARAnthonyForestProductsARAnthonyForestProductsARDeltaNaturalKraftARDelticTimberWaldoARDelticTimberWaldoARDelticTimberWaldoARDel‐TinARDomtarIndustriesARDomtarIndustriesARDomtarIndustriesAREvergreenPackagingAREvergreenPackagingARGBPMorriltonARGBPMorriltonARGeorgiaPacificCrossett93ARGeorgiaPacificCrossett93ARGeorgiaPacificFordyceARGPCrossett92ARGPCrossett92ARGPFordyceOSBARGPFordyceOSBARGPGurdonPlyLumberARGPGurdonPlyLumberARLeolaLumberMillARLeolaLumberMillARLeolaLumberMillARPotlatchForestCypressBendARPotlatchForestPrescottARPotlatchForestWarrenARRiversideFurniturePlant5ARTemple‐InlandARTemple‐InlandHg %redDioxinLimitDioxinEmissionsDioxinDifferenceDioxin%red CO LimitCOEmissionsCODifference CO %redHClControlGroupHgControlGroupPMControlGroupMetalsControlGroupNAICSPM NeedUpgrade?HCl NeedUpgrade?Hg NeedUpgrade?DioxinNeedUpgrade?CO NeedUpgrade? PM Upgrade Cost HCl Upgrade Cost Hg/Dioxin Upgrade Cost CO Upgrade Cost Total Capital CostTotal AnnualizedCapital CostAnnual OperatingCosts for New FFfor PMAnnual OperatingCosts for new WSfor HClAnnual OperatingCost for CarbonInjection for Hg/dioxin#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 2 2 3222 2 2 $3,754,962 $0 $1,000,000 $2,816,221 $7,571,183 $831,275 $187,748 $0 $211,015#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 2 2 3222 2 2 $5,101,698 $0 $1,000,000 $3,826,274 $9,927,972 $1,090,038 $255,085 $0 $351,691#VALUE! 4 N/A N/A #VALUE! 10 N/A N/A #VALUE!1 4 2 2 3222 2 $3,173,696 $0 $0 $2,380,272 $5,553,968 $609,796 $158,685 $0 $0#VALUE! 4 N/A N/A #VALUE! 10 N/A N/A #VALUE!1 4 2 2 3222 2 $3,173,696 $0 $0 $2,380,272 $5,553,968 $609,796 $158,685 $0 $0#VALUE! 0.005 N/A N/A #VALUE! 490 432.518 57.482045 6 2 2 3212 2 $2,280,508 $0 $1,000,000 $0 $3,280,508 $360,182 $114,025 $0 $91,909#VALUE! 0.005 N/A N/A #VALUE! 490 159.4541 330.54595 6 2 2 3212 2 $2,294,442 $0 $1,000,000 $0 $3,294,442 $361,712 $114,722 $0 $90,608#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!1 4 4 4 3212 2 2 $3,792,098 $0 $1,000,000 $1,625,185 $6,417,283 $704,583 $108,346 $0 $84,406#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!4 5 3 3 3211 2 2 $4,483,965 $0 $1,000,000 $1,921,699 $7,405,664 $813,102 $128,113 $0 $111,603#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 5 5 3211 2 2 $4,392,914 $0 $1,000,000 $1,882,678 $7,275,592 $798,821 $125,512 $0 $105,2524 0.007409 3.992591 690 654.2629 35.737145 6 5 5 3211 $1,944,271 $0 $0 $0 $1,944,271 $213,470 $55,551 $0 $0#VALUE! 4 N/A N/A #VALUE! 690 N/A N/A #VALUE!5 6 5 5 3212 $1,944,271 $0 $0 $0 $1,944,271 $213,470 $55,551 $0 $0#VALUE! 4 N/A N/A #VALUE! 690 541.3322 148.66785 6 5 5 3212 $1,951,759 $0 $0 $0 $1,951,759 $214,293 $55,765 $0 $0#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 5 5 3221 2 2 $5,355,574 $0 $1,000,000 $2,295,246 $8,650,820 $949,814 $153,016 $0 $146,437#VALUE! 0.005 N/A N/A #VALUE! 490 199.1758 290.82425 6 2 2 3212 2 $1,698,974 $0 $1,000,000 $0 $2,698,974 $296,333 $84,949 $0 $56,271#VALUE! 0.005 N/A N/A #VALUE! 490 266.9093 223.09075 6 2 2 3212 2 $1,698,974 $0 $1,000,000 $0 $2,698,974 $296,333 $84,949 $0 $56,271#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 2 2 3212 2 2 $1,698,974 $0 $1,000,000 $1,274,231 $3,973,205 $436,236 $84,949 $0 $56,271#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 2 2 3212 2 2 $4,381,590 $0 $1,000,000 $3,286,193 $8,667,783 $951,676 $219,080 $0 $266,332#VALUE! 0.003 N/A N/A #VALUE! 270 N/A N/A #VALUE! 1 4 4 322 3222 22SEE CISWI#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 2 3222 22SEE CISWI#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 2 3222 22SEE CISWI#VALUE! 0.005 N/A N/A #VALUE! 490 502.7179 -12.7179 2.53%4 5 3 3 3222 2 1 $10,610,016 $0 $1,000,000 $4,547,150 $16,157,166 $1,773,970 $303,143 $0 $457,616#VALUE! 4 N/A N/A #VALUE! 10 20.95782 -10.9578 52.29%5 6 6 6 3222 2 2 1 $11,836,540 $13,527,475 $1,000,000 $5,072,803 $31,436,818 $3,451,594 $338,187 $1,902,170 $399,912#VALUE! 0.005 N/A N/A #VALUE! 490 1068.183 -578.183 54.13%5 6 5 5 3221 2 1 $5,395,641 $0 $1,000,000 $2,312,418 $8,708,059 $956,098 $154,161 $0 $151,9310.005 0.011704 -0.0067 57.28% 490 459.7391 30.260884 5 3 3 3221 1 $9,986,587 $0 $1,000,000 $0 $10,986,587 $1,206,268 $285,331 $0 $423,905#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!1 4 4 4 3212 2 2 $6,915,661 $0 $1,000,000 $2,963,855 $10,879,515 $1,194,512 $197,590 $0 $224,232#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 2 2 3212 2 2 $3,951,806 $0 $1,000,000 $2,963,855 $7,915,661 $869,097 $197,590 $0 $224,232#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!1 4 4 4 3211 2 2 $5,843,016 $0 $1,000,000 $2,504,150 $9,347,166 $1,026,269 $166,943 $0 $169,318#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!1 4 4 4 3222 2 $0 $0 $1,000,000 $6,896,325 $7,896,325 $866,974 $0 $0 $938,781#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!1 4 4 4 3222 2 2 $13,204,852 $0 $1,000,000 $5,659,222 $19,864,074 $2,180,969 $377,281 $0 $675,247#VALUE! 0.2 N/A N/A #VALUE! 470 N/A N/A #VALUE!5 6 5 5 3212 2 2 $2,331,149 $0 $1,000,000 $999,064 $4,330,213 $475,434 $66,604 $0 $36,609#VALUE! 0.2 N/A N/A #VALUE! 470 N/A N/A #VALUE!5 6 5 5 3212 2 2 $2,331,149 $0 $1,000,000 $999,064 $4,330,213 $475,434 $66,604 $0 $36,609#VALUE! 0.005 N/A N/A #VALUE! 490 339.1004 150.89964 5 3 3 3212 2 $4,836,535 $0 $1,000,000 $0 $5,836,535 $640,820 $138,187 $0 $123,556#VALUE! 0.005 N/A N/A #VALUE! 490 321.0572 168.94284 5 3 3 3212 2 $4,836,535 $0 $1,000,000 $0 $5,836,535 $640,820 $138,187 $0 $123,556#VALUE! 0.005 N/A N/A #VALUE! 490 237.9658 252.03425 6 2 2 3212 $0 $0 $1,000,000 $0 $1,000,000 $109,795 $0 $0 $86,169#VALUE! 0.005 N/A N/A #VALUE! 490 391.8251 98.174955 6 2 2 3212 $0 $0 $1,000,000 $0 $1,000,000 $109,795 $0 $0 $86,169#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 5 5 3212 2 2 $1,914,122 $0 $1,000,000 $820,338 $3,734,459 $410,024 $54,689 $0 $27,010#VALUE! 4 N/A N/A #VALUE! 10 57.5983 -47.5983 82.64%5 6 6 6 3221 2 2 1 $10,340,352 $11,817,546 $1,000,000 $4,431,580 $27,589,478 $3,029,176 $295,439 $1,518,565 $319,263#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 2 2 3212 2 $0 $0 $1,000,000 $2,422,033 $3,422,033 $375,721 $0 $0 $160,1660.005 0.010353 -0.00535 51.70% 490 285.9735 204.02655 6 2 2 3211 $0 $0 $1,000,000 $0 $1,000,000 $109,795 $0 $0 $256,265#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 5 5 3212 2 2 $1,514,798 $0 $1,000,000 $649,199 $3,163,998 $347,390 $43,280 $0 $17,847#VALUE! 0.2 N/A N/A #VALUE! 470 N/A N/A #VALUE!5 6 5 5 3212 2 2 $2,331,149 $0 $1,000,000 $999,064 $4,330,213 $475,434 $66,604 $0 $36,609#VALUE! 0.2 N/A N/A #VALUE! 470 N/A N/A #VALUE!5 6 5 5 3212 2 2 $2,331,149 $0 $1,000,000 $999,064 $4,330,213 $475,434 $66,604 $0 $36,609FacilityIDARTemple‐InlandARWestFraserHuttigARWestFraserHuttigARWeyerhaeuserARWeyerhaeuserDierksMillAZCatalystPaperSnowflakeAZCatalystPaperSnowflakeCAHumboldtFlakeboard143CARoseburgWeedCASierraPine‐RocklinFLCFRC252FLCFRC252FLGPHawthorneFLGPHosfordOSBFLGPHosfordOSBFLGPPalatkaFLIPPensacolaFLIPPensacolaFLNorthFloridaLumberFLNorthFloridaLumberFLRayonierPerformanceFLSmurfit‐StoneFLSmurfit‐StoneFLSmurfit‐StoneFLSmurfit‐StoneFLSmurfitStonePanamaCityFLSmurfitStonePanamaCityGAAbitibiBowaterGACaraustarGAGPCedarSpringsGAGPCedarSpringsGAGPCelluloseBrunswickGAGPCelluloseBrunswickGAGPCelluloseBrunswickGAGPMadisonPlyGAGPMonticelloPlywoodGAGPSRMRiinconGAGPSRMRiinconGAGPSRMRiinconGAGPWarmSpringsGAGPWarrentonGAGPWoodClaxtonHg %redDioxinLimitDioxinEmissionsDioxinDifferenceDioxin%red CO LimitCOEmissionsCODifference CO %redHClControlGroupHgControlGroupPMControlGroupMetalsControlGroupNAICSPM NeedUpgrade?HCl NeedUpgrade?Hg NeedUpgrade?DioxinNeedUpgrade?CO NeedUpgrade? PM Upgrade Cost HCl Upgrade Cost Hg/Dioxin Upgrade Cost CO Upgrade Cost Total Capital CostTotal AnnualizedCapital CostAnnual OperatingCosts for New FFfor PMAnnual OperatingCosts for new WSfor HClAnnual OperatingCost for CarbonInjection for Hg/dioxin#VALUE! 0.2 N/A N/A #VALUE! 470 N/A N/A #VALUE!5 6 5 5 3212 2 2 $2,331,149 $0 $1,000,000 $999,064 $4,330,213 $475,434 $66,604 $0 $36,609#VALUE! 0.005 N/A N/A #VALUE! 490 64.80667 425.19335 6 5 5 3211 2 $1,947,032 $0 $1,000,000 $0 $2,947,032 $323,568 $55,629 $0 $27,788#VALUE! 0.005 N/A N/A #VALUE! 490 475.1572 14.842845 6 5 5 3211 2 $4,461,319 $0 $1,000,000 $0 $5,461,319 $599,623 $127,466 $0 $110,665#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 5 5 3211 2 2 $3,493,460 $0 $1,000,000 $1,497,197 $5,990,658 $657,742 $99,813 $0 $71,8464 0.021378 3.978622 690 152.1682 537.83185 6 2 2 321$0 $0 $0 $0 $0 $0 $0 $0 $0#VALUE! 0.004 N/A N/A #VALUE! 160 2.226869 157.77311 4 2 2 3222 $0 $0 $1,000,000 $0 $1,000,000 $109,795 $0 $0 $1,141,869#VALUE! 4 N/A N/A #VALUE! 10 N/A N/A #VALUE!5 6 6 6 3222 2 2 2 $8,373,595 $9,569,823 $1,000,000 $3,588,684 $22,532,103 $2,473,904 $239,246 $1,036,542 $217,923#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 5 5 3212 2 2 $2,331,149 $0 $1,000,000 $999,064 $4,330,213 $475,434 $66,604 $0 $36,609#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 2 2 3212 2 $0 $0 $1,000,000 $2,378,087 $3,378,087 $370,896 $0 $0 $159,189#VALUE! 0.2 N/A N/A #VALUE! 470 N/A N/A #VALUE!4 5 2 2 3212 2 $0 $0 $1,000,000 $1,417,976 $2,417,976 $265,481 $0 $0 $65,6220.005 N/A N/A #VALUE! 490 363.9491 126.05091 4 4 4 3212 2 $3,664,252 $0 $1,000,000 $0 $4,664,252 $512,110 $104,693 $0 $79,717#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 5 5 3212 2 2 $1,957,658 $0 $1,000,000 $838,996 $3,796,654 $416,852 $55,933 $0 $28,042#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 2 2 3212 2 $0 $0 $1,000,000 $2,808,705 $3,808,705 $418,175 $0 $0 $210,077#VALUE! 0.2 N/A N/A #VALUE! 470 N/A N/A #VALUE!5 6 2 2 3212 2 2 $1,332,085 $0 $1,000,000 $999,064 $3,331,149 $365,742 $66,604 $0 $36,609#VALUE! 0.2 N/A N/A #VALUE! 470 N/A N/A #VALUE!5 6 2 2 3212 2 2 $1,332,085 $0 $1,000,000 $999,064 $3,331,149 $365,742 $66,604 $0 $36,609#VALUE! 0.005 N/A N/A #VALUE! 490 301.1009 188.89915 6 2 2 3221 2 $6,154,800 $0 $1,000,000 $0 $7,154,800 $785,559 $307,740 $0 $480,83244.71% 0.004 N/A N/A #VALUE! 160 N/A N/A #VALUE!4 5 3 3 3222 1 2 $8,521,808 $0 $1,000,000 $0 $9,521,808 $1,045,443 $243,480 $0 $332,9030.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!4 5 3 3 3222 2 2 $12,601,393 $0 $1,000,000 $5,400,597 $19,001,991 $2,086,316 $360,040 $0 $624,603#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 5 5 3212 2 2 $1,672,518 $0 $1,000,000 $716,793 $3,389,311 $372,128 $47,786 $0 $21,570#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 5 5 3212 2 2 $2,431,131 $0 $1,000,000 $1,041,913 $4,473,045 $491,116 $69,461 $0 $40,2330.02 N/A N/A #VALUE! 430 72.01906 357.98091 4 2 2 3221 $6,242,975 $0 $0 $0 $6,242,975 $685,445 $312,149 $0 $00.004 N/A N/A #VALUE! 160 15.2574 144.74265 6 2 2 3221 2 $0 $18,609,788 $1,000,000 $0 $19,609,788 $2,153,049 $0 $4,062,475 $854,095#VALUE! 0.004 N/A N/A #VALUE! 160 N/A N/A #VALUE!4 5 3 3 3222 2 2 $8,927,972 $0 $1,000,000 $0 $9,927,972 $1,090,038 $255,085 $0 $359,7650.005 N/A N/A #VALUE! 490 387.5904 102.40965 6 2 2 3222 $0 $0 $1,000,000 $0 $1,000,000 $109,795 $0 $0 $736,761#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!4 5 3 3 3222 2 2 $8,927,972 $0 $1,000,000 $3,826,274 $13,754,245 $1,510,142 $255,085 $0 $351,691#VALUE! 0.003 N/A N/A #VALUE! 270 N/A N/A #VALUE!1 4 4 4 3222 2 2 $11,173,055 $0 $1,000,000 $4,788,452 $16,961,507 $1,862,282 $319,230 $0 $455,908#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!1 4 4 4 3222 2 2 $10,673,549 $0 $1,000,000 $4,574,378 $16,247,928 $1,783,935 $304,959 $0 $473,611#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!4 5 3 3 3222 2 2 $7,411,970 $0 $1,000,000 $3,176,559 $11,588,529 $1,272,358 $211,771 $0 $257,9070.004 N/A N/A #VALUE! 160 N/A N/A #VALUE!5 3 1 1 3221 1 2 $4,577,439 $9,154,878 $1,000,000 $0 $14,732,318 $1,617,529 $0 $1,428,292 $300,284#VALUE! 0.004 N/A N/A #VALUE! 160 N/A N/A #VALUE!4 5 3 3 3221 2 2 $13,897,084 $0 $1,000,000 $0 $14,897,084 $1,635,620 $397,060 $0 $655,8380.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!4 5 3 3 3221 2 2 $13,897,084 $0 $1,000,000 $5,955,893 $20,852,977 $2,289,545 $397,060 $0 $735,2690.005 N/A N/A #VALUE! 490 217.2575 272.74255 6 2 2 3222 $0 $0 $1,000,000 $0 $1,000,000 $109,795 $0 $0 $750,274#VALUE! 4 N/A N/A #VALUE! 10 N/A N/A #VALUE!5 6 2 2 3222 2 2 $0 $7,164,139 $1,000,000 $2,686,552 $10,850,691 $1,191,348 $0 $639,765 $134,504#VALUE! 4 N/A N/A #VALUE! 10 1.453583 8.5464175 6 2 2 3221 2 2 $5,060,775 $10,121,550 $1,000,000 $0 $16,182,325 $1,776,732 $253,039 $1,138,044 $239,2620.005 0.002012 0.002988 490 2475.007 -1985.01 80.20%5 6 2 2 3211 $0 $0 $0 $3,702,493 $3,702,493 $406,514 $0 $0 $00.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 2 2 3212 2 $0 $0 $1,000,000 $2,892,880 $3,892,880 $427,417 $0 $0 $220,6740.002 N/A N/A #VALUE! 82 N/A N/A #VALUE!3 2 1 1 3221 2 $5,476,252 $0 $1,000,000 $0 $6,476,252 $711,058 $0 $0 $353,0150.002 N/A N/A #VALUE! 82 N/A N/A #VALUE!3 2 1 1 3222 $0 $0 $1,000,000 $0 $1,000,000 $109,795 $0 $0 $353,015#VALUE! 0.002 N/A N/A #VALUE! 82 N/A N/A #VALUE!3 2 1 1 3222 $0 $0 $1,000,000 $0 $1,000,000 $109,795 $0 $0 $353,0150.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 5 5 3211 2 2 $5,747,746 $0 $1,000,000 $2,463,320 $9,211,065 $1,011,325 $164,221 $0 $168,812#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 2 2 3212 2 $0 $0 $1,000,000 $1,578,141 $2,578,141 $283,066 $0 $0 $78,435#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 2 2 3212 2 $0 $0 $1,000,000 $1,581,453 $2,581,453 $283,430 $0 $0 $78,710FacilityIDGAGraphicPackagingGAGraphicPackagingGAGraphicPackagingGAInternationalPaperAugustaMillsGAInternationalPaperAugustaMillsGAInternationalPaperAugustaMillsGAInterstateResourcesGAInterstateResourcesGAIPSavannahGALangboardWillacoocheeGALouisianaPacificAthensGAP&GAlbanyGAP&GAlbanyGAPCAValdostaGAPCAValdostaGARayonierBaxleyGARayonierBaxleyGARayonierJesupMillGARayonierJesupMillGARayonierJesupMillGARoseburgForestViennaGASPNewsprintGASPNewsprintGATempleInlandRomeGATempleInlandRomeGATempleInlandThomsonGATempleInlandThomsonGAWestFraserFolkstonGAWestFraserFolkstonGAWeyerhaeuserCoOglethorpeGAWYPortWentworthIA3MKnoxvilleIA3MKnoxvilleIAJELD‐WENDubuqueIDChilcoLakeSawmillIDMoyieSpringsLumber420IDPotlatchIDPotlatchIDPotlatchIDRileyCreekLumberIDRileyCreekLumberINJasperSeating9Hg %redDioxinLimitDioxinEmissionsDioxinDifferenceDioxin%red CO LimitCOEmissionsCODifference CO %redHClControlGroupHgControlGroupPMControlGroupMetalsControlGroupNAICSPM NeedUpgrade?HCl NeedUpgrade?Hg NeedUpgrade?DioxinNeedUpgrade?CO NeedUpgrade? PM Upgrade Cost HCl Upgrade Cost Hg/Dioxin Upgrade Cost CO Upgrade Cost Total Capital CostTotal AnnualizedCapital CostAnnual OperatingCosts for New FFfor PMAnnual OperatingCosts for new WSfor HClAnnual OperatingCost for CarbonInjection for Hg/dioxin#VALUE! 0.004 N/A N/A #VALUE! 160 N/A N/A #VALUE!4 5 3 3 3222 2 2 $8,927,972 $0 $1,000,000 $0 $9,927,972 $1,090,038 $255,085 $0 $359,765#VALUE! 0.004 N/A N/A #VALUE! 160 N/A N/A #VALUE!4 5 3 3 3222 2 2 $5,899,684 $0 $1,000,000 $0 $6,899,684 $757,548 $168,562 $0 $180,362#VALUE! 0.004 N/A N/A #VALUE! 160 N/A N/A #VALUE!4 5 3 3 3222 2 2 $5,899,684 $0 $1,000,000 $0 $6,899,684 $757,548 $168,562 $0 $180,3620.004 N/A N/A #VALUE! 160 N/A N/A #VALUE!5 6 2 2 3221 2 $0 $14,659,544 $1,000,000 $0 $15,659,544 $1,719,334 $0 $2,729,538 $573,8580.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!4 5 3 3 3221 2 2 $12,759,668 $0 $1,000,000 $5,468,429 $19,228,097 $2,111,142 $364,562 $0 $637,7330.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 2 2 3222 2 $0 $0 $1,000,000 $4,867,098 $5,867,098 $644,176 $0 $0 $525,192#VALUE! 0.02 N/A N/A #VALUE! 430 N/A N/A #VALUE!1 4 2 2 3222 $4,000,000 $0 $0 $0 $4,000,000 $439,178 $200,000 $0 $0#VALUE! 4 N/A N/A #VALUE! 10 N/A N/A #VALUE!5 6 6 6 3222 2 2 2 $5,899,684 $6,742,496 $1,000,000 $2,528,436 $16,170,616 $1,775,447 $168,562 $596,013 $125,306#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 2 2 3222 2 $0 $0 $1,000,000 $7,992,511 $8,992,511 $987,329 $0 $0 $1,171,496#VALUE! 0.02 N/A N/A #VALUE! 430 N/A N/A #VALUE!5 6 2 2 3212 $3,338,866 $0 $0 $0 $3,338,866 $366,590 $166,943 $0 $0#VALUE! 0.2 N/A N/A #VALUE! 470 N/A N/A #VALUE!5 6 2 2 3212 2 2 $1,332,085 $0 $1,000,000 $999,064 $3,331,149 $365,742 $66,604 $0 $36,609#VALUE! 0.005 N/A N/A #VALUE! 490 384.4832 105.51685 6 2 2 3222 $0 $0 $1,000,000 $0 $1,000,000 $109,795 $0 $0 $202,574#VALUE! 4 N/A N/A #VALUE! 10 N/A N/A #VALUE!5 6 6 6 3222 2 2 2 $5,880,835 $6,720,954 $1,000,000 $2,520,358 $16,122,147 $1,770,125 $168,024 $575,173 $120,924#VALUE! 0.005 N/A N/A #VALUE! 490 3420.103 -2930.1 85.67%4 5 3 3 3221 2 1 $6,881,733 $0 $1,000,000 $2,949,314 $10,831,047 $1,189,191 $196,621 $0 $227,896#VALUE! 0.005 N/A N/A #VALUE! 490 3420.103 -2930.1 85.67%4 5 3 3 3221 2 1 $8,711,953 $0 $1,000,000 $3,733,694 $13,445,647 $1,476,260 $248,913 $0 $337,624#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!4 5 3 3 3211 2 2 $2,935,583 $0 $1,000,000 $1,258,107 $5,193,690 $570,239 $83,874 $0 $53,761#VALUE! 0.005 N/A N/A #VALUE! 490 350.2887 139.71135 6 2 2 3212 $0 $0 $1,000,000 $0 $1,000,000 $109,795 $0 $0 $56,3230.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!1 4 4 4 3221 2 2 $5,670,765 $0 $1,000,000 $2,430,328 $9,101,093 $999,251 $162,022 $0 $161,081#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!2 6 5 5 3221 2 2 $8,010,519 $0 $1,000,000 $3,433,079 $12,443,598 $1,366,240 $228,872 $0 $286,467#VALUE! 0.005 N/A N/A #VALUE! 490 347.8726 142.12744 5 3 3 3221 2 $11,978,016 $0 $1,000,000 $0 $12,978,016 $1,424,916 $342,229 $0 $560,1220.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 5 5 3212 2 2 $2,769,302 $0 $1,000,000 $1,186,844 $4,956,146 $544,158 $79,123 $0 $48,782#VALUE! 0.004 N/A N/A #VALUE! 160 N/A N/A #VALUE!5 6 2 2 3221 2 2 $3,990,392 $7,980,785 $1,000,000 $0 $12,971,177 $1,424,166 $199,520 $1,136,245 $238,8840.002 N/A N/A #VALUE! 82 117.6226 -35.6226 30.29%5 6 2 2 3222 1 $0 $0 $1,000,000 $4,814,762 $5,814,762 $638,430 $0 $0 $460,090#VALUE! 0.005 N/A N/A #VALUE! 490 130.3333 359.66675 6 2 2 3222 $0 $0 $1,000,000 $0 $1,000,000 $109,795 $0 $0 $529,8810.02 0.009674 0.010326 430 129.2 300.85 6 2 2 322$0 $0 $0 $0 $0 $0 $0 $0 $0#VALUE! 0.2 N/A N/A #VALUE! 470 563.5428 -93.5428 16.60%5 6 2 2 3212 2 1 $1,332,085 $0 $1,000,000 $999,064 $3,331,149 $365,742 $66,604 $0 $36,609#VALUE! 0.2 N/A N/A #VALUE! 470 N/A N/A #VALUE!5 6 5 5 3212 2 2 $1,961,583 $0 $1,000,000 $840,679 $3,802,262 $417,468 $56,045 $0 $27,457#VALUE! 0.005 N/A N/A #VALUE! 490 13303.34 -12813.3 96.32%5 6 5 5 3212 2 1 $1,932,407 $0 $1,000,000 $828,174 $3,760,582 $412,892 $55,212 $0 $26,780#VALUE! 0.005 N/A N/A #VALUE! 490 9463.896 -8973.9 94.82%5 6 5 5 3212 2 1 $1,902,133 $0 $1,000,000 $815,200 $3,717,333 $408,143 $54,347 $0 $26,084#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!4 5 3 3 3221 2 2 $12,533,155 $0 $1,000,000 $5,371,352 $18,904,507 $2,075,613 $358,090 $0 $604,053#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5623222 2 2 $5,101,698 $0 $1,000,000 $3,826,274 $9,927,972 $1,090,038 $255,085 $0 $355,443#VALUE! 4 N/A N/A #VALUE! 10 N/A N/A #VALUE!5 6 6 6 3222 2 2 2 $3,316,909 $3,790,753 $1,000,000 $1,421,532 $9,529,194 $1,046,254 $94,769 $221,457 $46,559#VALUE! 4 N/A N/A #VALUE! 10 N/A N/A #VALUE!5 6 6 6 3222 2 2 2 $3,316,909 $3,790,753 $1,000,000 $1,421,532 $9,529,194 $1,046,254 $94,769 $221,457 $46,559#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 5 5 3212 2 2 $3,690,057 $0 $1,000,000 $1,581,453 $6,271,510 $688,578 $105,430 $0 $78,710#VALUE! 0.005 N/A N/A #VALUE! 490 51.0253 438.97475 6 2 2 3212 $0 $0 $1,000,000 $0 $1,000,000 $109,795 $0 $0 $114,4040.005 N/A N/A #VALUE! 490 1883.684 -1393.68 73.99%5 6 2 2 3212 1 $0 $0 $1,000,000 $1,979,262 $2,979,262 $327,107 $0 $0 $114,4044 0.5656 3.4344 690 272.1349 417.86515 6 2 2 321$0 $0 $0 $0 $0 $0 $0 $0 $00.005 N/A N/A #VALUE! 490 454.9756 35.024415 6 2 2 3212 $0 $0 $1,000,000 $0 $1,000,000 $109,795 $0 $0 $84,2010.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 2 2 3212 2 2 $1,325,581 $0 $1,000,000 $994,185 $3,319,766 $364,492 $66,279 $0 $36,312#VALUE! 0.005 N/A N/A #VALUE! 490 161.3135 328.68655 6 2 2 3212 $0 $0 $1,000,000 $0 $1,000,000 $109,795 $0 $0 $64,277#VALUE! 0.005 N/A N/A #VALUE! 490 1308.888 -818.888 62.56%5 6 2 2 3211 2 1 $1,826,462 $0 $1,000,000 $1,369,847 $4,196,309 $460,732 $91,323 $0 $61,952#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 6 5 3212 2 2 $1,044,835 $0 $1,000,000 $447,786 $2,492,621 $273,676 $29,852 $0 $9,610FacilityIDINKimballOfficeJasperINKimballOfficeSalemINKimballOfficeSalemINNOFJasperINNOFJasperINNOFJasperKYDomtarHawesvilleKYHONCoOwensboroKYNewPage‐WickliffeKYWeyerhaeuserEKYKYWeyerhaeuserEKYKYWeyerhaeuserEKYLABoiseCascadeFlorienLABoiseCascadeOakdaleLABoiseNewsprintDeRidderLABoiseNewsprintDeRidderLAGPLogansportPlyLAGPPortHudsonLAGPPortHudsonLAGPSpringhillWoodLAGraphicPackagingLAHoodIndustriesLAHoodIndustriesLAHuntNatalbanyLAHuntPollockLAHuntPollockLAInternationalPaperRedRiverMillLAIPMansfieldLAIPMansfieldLASmurfit‐StoneLATempleInlandBogalusaLATempleInlandBogalusaLAWestFraserJoyceLAWestFraserJoyceLAWestFraserJoyceLAWeyerhaeuser1043LAWeyerhaeuserDodsonMAHollingsworth&voseMAMWCustomPapersMAMWCustomPapersMANewarkAmericaMDNewPage‐LukeHg %redDioxinLimitDioxinEmissionsDioxinDifferenceDioxin%red CO LimitCOEmissionsCODifference CO %redHClControlGroupHgControlGroupPMControlGroupMetalsControlGroupNAICSPM NeedUpgrade?HCl NeedUpgrade?Hg NeedUpgrade?DioxinNeedUpgrade?CO NeedUpgrade? PM Upgrade Cost HCl Upgrade Cost Hg/Dioxin Upgrade Cost CO Upgrade Cost Total Capital CostTotal AnnualizedCapital CostAnnual OperatingCosts for New FFfor PMAnnual OperatingCosts for new WSfor HClAnnual OperatingCost for CarbonInjection for Hg/dioxin#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 5 5 3212 2 2 $1,560,941 $0 $1,000,000 $668,975 $3,229,915 $354,627 $44,598 $0 $18,762#VALUE! 0.003 N/A N/A #VALUE! 270 N/A N/A #VALUE!5 6 5 5 3212 2 2 2 $2,313,621 $2,644,139 $1,000,000 $991,552 $6,949,312 $762,997 $66,103 $180,248 $37,895#VALUE! 0.003 N/A N/A #VALUE! 270 N/A N/A #VALUE!5 6 5 5 3212 2 2 2 $2,313,621 $2,644,139 $1,000,000 $991,552 $6,949,312 $762,997 $66,103 $180,248 $37,895#VALUE! 0.003 N/A N/A #VALUE! 270 N/A N/A #VALUE!5 6 5 5 3212 2 2 2 $1,582,678 $1,808,775 $1,000,000 $678,290 $5,069,743 $556,630 $45,219 $95,728 $20,126#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 6 5 3212 2 2 $1,044,058 $0 $1,000,000 $447,454 $2,491,512 $273,555 $29,830 $0 $9,598#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 6 5 3212 2 2 $1,044,058 $0 $1,000,000 $447,454 $2,491,512 $273,555 $29,830 $0 $9,598#VALUE! 0.02 N/A N/A #VALUE! 430 111.6637 318.33635 6 2 2 322$0 $0 $0 $0 $0 $0 $0 $0 $0#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 6 5 3212 2 2 $4,231,545 $0 $1,000,000 $1,813,519 $7,045,064 $773,510 $120,901 $0 $98,8870.005 N/A N/A #VALUE! 490 265.0952 224.90485 6 2 2 3222 $0 $0 $1,000,000 $0 $1,000,000 $109,795 $0 $0 $591,779#VALUE! 4 N/A N/A #VALUE! 690 109.5222 580.47785 6 2 2 3211 $1,942,373 $0 $0 $0 $1,942,373 $213,262 $97,119 $0 $0#VALUE! 4 N/A N/A #VALUE! 690 N/A N/A #VALUE!5 6 2 2 3211 $1,942,373 $0 $0 $0 $1,942,373 $213,262 $97,119 $0 $0#VALUE! 4 N/A N/A #VALUE! 690 109.5222 580.47785 6 2 2 3211 $1,942,373 $0 $0 $0 $1,942,373 $213,262 $97,119 $0 $0#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!1 4 4 4 3211 2 2 $4,900,738 $0 $1,000,000 $2,100,316 $8,001,054 $878,473 $140,021 $0 $126,302#VALUE! 0.005 N/A N/A #VALUE! 490 1448.817 -958.817 66.18%5 6 5 5 3212 1 $0 $0 $1,000,000 $2,100,316 $3,100,316 $340,398 $0 $0 $126,3020.005 N/A N/A #VALUE! 490 602.5834 -112.583 18.68%4 5 3 3 3221 2 1 $21,251,289 $0 $1,000,000 $9,107,695 $31,358,984 $3,443,048 $607,180 $0 $1,492,390#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!4 5 3 3 3222 2 2 $10,016,914 $0 $1,000,000 $4,292,963 $15,309,877 $1,680,942 $286,198 $0 $426,053#VALUE! 0.005 N/A N/A #VALUE! 490 342.8737 147.12631 4 4 4 3211 2 $6,518,472 $0 $1,000,000 $0 $7,518,472 $825,488 $186,242 $0 $208,201#VALUE! 0.005 N/A N/A #VALUE! 490 1260.465 -770.465 61.13%4 5 3 3 3222 2 1 $10,081,732 $0 $1,000,000 $4,320,742 $15,402,475 $1,691,109 $288,049 $0 $430,658#VALUE! 0.02 N/A N/A #VALUE! 430 N/A N/A #VALUE!2 6 2 2 322$0 $0 $0 $0 $0 $0 $0 $0 $0#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!1 4 4 4 3212 2 2 $6,283,076 $0 $1,000,000 $2,692,747 $9,975,823 $1,095,292 $179,516 $0 $191,100#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!4 5 3 3 3222 2 2 $13,532,274 $0 $1,000,000 $5,799,546 $20,331,820 $2,232,325 $386,636 $0 $703,382#VALUE! 0.005 N/A N/A #VALUE! 490 1768.444 -1278.44 72.29%5 6 5 5 3212 2 1 $3,044,001 $0 $1,000,000 $1,304,572 $5,348,573 $587,245 $86,971 $0 $58,521#VALUE! 0.005 N/A N/A #VALUE! 490 2329.841 -1839.84 78.97%5 6 5 5 3212 2 1 $3,044,001 $0 $1,000,000 $1,304,572 $5,348,573 $587,245 $86,971 $0 $58,521#VALUE! 0.005 N/A N/A #VALUE! 490 1569.911 -1079.91 68.79%5 6 5 5 3212 2 1 $3,849,950 $0 $1,000,000 $1,649,978 $6,499,928 $713,657 $109,999 $0 $86,563#VALUE! 0.005 N/A N/A #VALUE! 490 584.8403 -94.8403 16.22%5 6 5 5 3212 2 1 $3,017,582 $0 $1,000,000 $1,293,249 $5,310,832 $583,101 $86,217 $0 $57,677#VALUE! 0.005 N/A N/A #VALUE! 490 3566.918 -3076.92 86.26%5 6 5 5 3212 2 1 $3,533,361 $0 $1,000,000 $1,514,298 $6,047,659 $664,000 $100,953 $0 $75,027#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 2 3222 22SEE CISWI#VALUE! 0.003 N/A N/A #VALUE! 270 N/A N/A #VALUE! 5 6 2 32222 22SEE CISWI0.003 N/A N/A #VALUE! 270 N/A N/A #VALUE! 5 6 2 3222 22SEE CISWI#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 5 5 3222 2 2 $13,532,274 $0 $1,000,000 $5,799,546 $20,331,820 $2,232,325 $386,636 $0 $703,382#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!1 4 4 4 3222 2 2 $10,538,556 $0 $1,000,000 $4,516,524 $16,055,080 $1,762,761 $301,102 $0 $463,670#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!1 4 4 4 3222 2 2 $13,934,275 $0 $1,000,000 $5,971,832 $20,906,107 $2,295,378 $398,122 $0 $738,551#VALUE! 0.005 N/A N/A #VALUE! 490 2331.176 -1841.18 78.98%5 6 5 5 3211 2 1 $2,922,370 $0 $1,000,000 $1,252,444 $5,174,814 $568,167 $83,496 $0 $54,676#VALUE! 0.005 N/A N/A #VALUE! 490 1606.367 -1116.37 69.50%5 6 5 5 3211 2 1 $2,922,370 $0 $1,000,000 $1,252,444 $5,174,814 $568,167 $83,496 $0 $54,676#VALUE! 0.005 N/A N/A #VALUE! 490 1741.834 -1251.83 71.87%5 6 5 5 3211 2 1 $5,238,231 $0 $1,000,000 $2,244,956 $8,483,187 $931,408 $149,664 $0 $144,615#VALUE! 0.005 N/A N/A #VALUE! 490 375.5549 114.44515 6 2 2 3212 $0 $0 $1,000,000 $0 $1,000,000 $109,795 $0 $0 $91,523#VALUE! 0.005 N/A N/A #VALUE! 490 433.2898 56.710165 6 2 2 3212 $0 $0 $1,000,000 $0 $1,000,000 $109,795 $0 $0 $213,249#VALUE! 4 N/A N/A #VALUE! 10 N/A N/A #VALUE!5 6 6 6 3222 2 2 2 $2,649,093 $3,027,535 $1,000,000 $1,135,325 $7,811,953 $857,710 $75,688 $156,929 $32,993#VALUE! 4 N/A N/A #VALUE! 10 N/A N/A #VALUE!5 6 6 6 3222 2 2 2 $2,242,605 $2,562,977 $1,000,000 $961,116 $6,766,699 $742,947 $64,074 $118,886 $24,995#VALUE! 4 N/A N/A #VALUE! 10 N/A N/A #VALUE!5 6 6 6 3222 2 2 2 $2,600,631 $2,972,150 $1,000,000 $1,114,556 $7,687,338 $844,028 $74,304 $152,174 $31,993#VALUE! 4 N/A N/A #VALUE! 10 1.316966 8.6830345 6 6 6 3222 2 $0 $7,609,615 $1,000,000 $0 $8,609,615 $945,289 $0 $707,433 $148,73176.69% 0.003 N/A N/A #VALUE! 270 290.9382 -20.9382 7.20%5 3 1 1 3222 1 2 1 $0 $13,391,746 $1,000,000 $5,021,905 $19,413,650 $2,131,514 $0 $2,347,562 $493,551FacilityIDMDNewPage‐LukeMEDomtarBaileyvilleMEHuberEngineeredWoodLLCMEKatahdinPaperCoMEKatahdinPaperCoMEKatahdinPaperCoMELincolnPaper&TissueMELincolnPaper&TissueMEMadisonPaperMEMadisonPaperMEMadisonPaperMENewPage‐RumfordMENewPage‐RumfordMENewPage‐RumfordMERedShieldMERedShieldMESappiWestbrookMESappiWestbrookMESappiWestbrookMESappiWestbrookMESDWarrenMESDWarrenMESDWarrenSomersetMESDWarrenSomersetMEVersoPaperMEVersoPaperMEVersoPaperAndroscogginMIDecorativePanelsMIDecorativePanelsMIDecorativePanelsMIEBEddyPaperMILPCSagolaMIManistiquePaperMIManistiquePaperMIMenomineeMIMenomineeMINeenahPaperMIMINewPageEscanabaMINewPageEscanabaMINewPageEscanabaMINewPageEscanabaMIPackagingCorpofAmericaHg %redDioxinLimitDioxinEmissionsDioxinDifferenceDioxin%red CO LimitCOEmissionsCODifference CO %redHClControlGroupHgControlGroupPMControlGroupMetalsControlGroupNAICSPM NeedUpgrade?HCl NeedUpgrade?Hg NeedUpgrade?DioxinNeedUpgrade?CO NeedUpgrade? PM Upgrade Cost HCl Upgrade Cost Hg/Dioxin Upgrade Cost CO Upgrade Cost Total Capital CostTotal AnnualizedCapital CostAnnual OperatingCosts for New FFfor PMAnnual OperatingCosts for new WSfor HClAnnual OperatingCost for CarbonInjection for Hg/dioxin11.71% 0.004 N/A N/A #VALUE! 160 131.0361 28.963855 3 1 1 3221 2 $0 $0 $1,000,000 $0 $1,000,000 $109,795 $0 $0 $656,674#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!4 5 3 3 3221 2 2 $12,130,035 $0 $1,000,000 $5,198,586 $18,328,621 $2,012,384 $346,572 $0 $572,020#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 2 3212 2 2 $2,079,043 $0 $1,000,000 $1,559,283 $4,638,326 $509,263 $103,952 $0 $97,043#VALUE! 4 N/A N/A #VALUE! 10 N/A N/A #VALUE!5 6 6 6 3222 2 2 2 $8,856,356 $10,121,550 $1,000,000 $3,795,581 $23,773,487 $2,610,201 $253,039 $1,173,005 $246,612#VALUE! 4 N/A N/A #VALUE! 10 N/A N/A #VALUE!5 6 6 6 3222 2 2 2 $8,856,356 $10,121,550 $1,000,000 $3,795,581 $23,773,487 $2,610,201 $253,039 $1,173,005 $246,612#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 2 2 3222 2 2 $6,048,304 $0 $1,000,000 $4,536,228 $11,584,532 $1,271,919 $302,415 $0 $467,0460.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 2 2 3222 2 2 $5,561,459 $0 $1,000,000 $4,171,094 $10,732,553 $1,178,377 $278,073 $0 $406,086#VALUE! 4 N/A N/A #VALUE! 10 N/A N/A #VALUE!5 6 6 6 3222 2 2 2 $1,292,920 $1,477,622 $1,000,000 $554,108 $4,324,651 $474,823 $36,941 $46,063 $9,684#VALUE! 4 N/A N/A #VALUE! 10 N/A N/A #VALUE!5 6 6 6 3222 2 2 2 $4,438,595 $5,072,680 $1,000,000 $1,902,255 $12,413,531 $1,362,939 $126,817 $370,923 $77,983#VALUE! 4 N/A N/A #VALUE! 10 N/A N/A #VALUE!5 6 6 6 3222 2 2 2 $4,015,274 $4,588,884 $1,000,000 $1,720,832 $11,324,989 $1,243,423 $114,722 $313,858 $65,986#VALUE! 4 N/A N/A #VALUE! 10 N/A N/A #VALUE!5 6 6 6 3222 2 2 2 $4,483,965 $5,124,531 $1,000,000 $1,921,699 $12,530,196 $1,375,748 $128,113 $377,264 $79,3160.02 N/A N/A #VALUE! 430 14.60129 415.39873 6 2 2 322$0 $0 $0 $0 $0 $0 $0 $0 $0#VALUE! 4 N/A N/A #VALUE! 10 N/A N/A #VALUE!4 5 3 3 3221 2 $7,809,204 $0 $0 $3,346,802 $11,156,006 $1,224,870 $223,120 $0 $00.02 N/A N/A #VALUE! 430 14.60129 415.39873 6 2 2 322$0 $0 $0 $0 $0 $0 $0 $0 $0#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5623222 2 2 $3,371,248 $0 $1,000,000 $2,528,436 $6,899,684 $757,548 $168,562 $0 $169,318#VALUE! 4 N/A N/A #VALUE! 10 N/A N/A #VALUE!5 6 6 6 3222 2 2 2 $7,000,000 $8,000,000 $1,000,000 $3,000,000 $19,000,000 $2,086,098 $200,000 $792,571 $166,630#VALUE! 4 N/A N/A #VALUE! 10 N/A N/A #VALUE!5663222 2 2 2 $5,899,684 $6,742,496 $1,000,000 $2,528,436 $16,170,616 $1,775,447 $168,562 $578,864 $121,700#VALUE! 4 N/A N/A #VALUE! 10 N/A N/A #VALUE!5663222 2 2 2 $6,358,604 $7,266,976 $1,000,000 $2,725,116 $17,350,697 $1,905,013 $181,674 $675,270 $141,969#VALUE! 4 N/A N/A #VALUE! 10 N/A N/A #VALUE!5663222 2 2 2 $6,358,604 $7,266,976 $1,000,000 $2,725,116 $17,350,697 $1,905,013 $181,674 $675,270 $141,969#VALUE! 0.004 N/A N/A #VALUE! 160 N/A N/A #VALUE!5623222 2 2 $8,300,446 $16,600,893 $1,000,000 $0 $25,901,339 $2,843,828 $415,022 $4,059,055 $853,3760.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 2 2 3222 2 $0 $0 $1,000,000 $7,193,824 $8,193,824 $899,638 $0 $0 $982,959#VALUE! 4 N/A N/A #VALUE! 10 N/A N/A #VALUE!5 6 6 6 3222 2 2 2 $5,899,684 $6,742,496 $1,000,000 $2,528,436 $16,170,616 $1,775,447 $168,562 $596,013 $125,306#VALUE! 0.005 N/A N/A #VALUE! 490 275.416 214.5845 6 2 2 3222 $0 $0 $1,000,000 $0 $1,000,000 $109,795 $0 $0 $795,2910.005 N/A N/A #VALUE! 490 204.7091 285.29092 6 2 2 3222 $0 $0 $1,000,000 $0 $1,000,000 $109,795 $0 $0 $1,219,196#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 2 2 3222 2 $0 $0 $1,000,000 $6,091,607 $7,091,607 $778,620 $0 $0 $744,998#VALUE! 4 N/A N/A #VALUE! 10 N/A N/A #VALUE!5 6 6 6 3222 2 2 2 $8,870,710 $10,137,954 $1,000,000 $3,801,733 $23,810,397 $2,614,254 $253,449 $1,176,175 $247,279#VALUE! 0.005 N/A N/A #VALUE! 490 1396.063 -906.063 64.90%4 5 3 3 3221 2 1 $10,353,299 $0 $1,000,000 $4,437,128 $15,790,428 $1,733,704 $295,809 $0 $450,165#VALUE! 0.003 N/A N/A #VALUE! 270 N/A N/A #VALUE!5 6 2 2 3212 2 2 2 $2,252,468 $4,504,937 $1,000,000 $1,689,351 $9,446,757 $1,037,203 $112,623 $438,071 $92,100#VALUE! 0.003 N/A N/A #VALUE! 270 N/A N/A #VALUE!5 6 2 2 3212 2 2 2 $2,252,468 $4,504,937 $1,000,000 $1,689,351 $9,446,757 $1,037,203 $112,623 $438,071 $92,100#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 5 5 3212 2 2 $3,506,794 $0 $1,000,000 $1,502,912 $6,009,706 $659,833 $100,194 $0 $72,30338.09% 0.004 N/A N/A #VALUE! 160 N/A N/A #VALUE!5 6 2 2 3222112$3,456,604 $6,913,208 $1,000,000 $0 $11,369,812 $1,248,344 $172,830 $894,394 $188,037#VALUE! 0.005 N/A N/A #VALUE! 490 67.95856 422.04145 6 5 5 3211 2 $2,973,205 $0 $1,000,000 $0 $3,973,205 $436,236 $84,949 $0 $56,2710.003 N/A N/A #VALUE! 270 N/A N/A #VALUE!5 6 2 2 3221 2 2 $0 $18,901,304 $1,000,000 $7,087,989 $26,989,293 $2,963,279 $0 $4,169,090 $876,5100.003 N/A N/A #VALUE! 270 N/A N/A #VALUE!5 6 2 2 3221 2 2 $0 $15,336,673 $1,000,000 $5,751,253 $22,087,926 $2,425,136 $0 $2,942,887 $618,713#VALUE! 0.003 N/A N/A #VALUE! 270 N/A N/A #VALUE!5 3 1 1 3222 2 2 2 $0 $4,092,399 $1,000,000 $1,534,650 $6,627,049 $727,614 $0 $373,273 $78,47730.34% 0.003 N/A N/A #VALUE! 270 N/A N/A #VALUE!5 3 1 1 3221 1 2 2 $0 $4,644,284 $1,000,000 $1,741,607 $7,385,891 $810,931 $0 $460,887 $96,8970.003 N/A N/A #VALUE! 270 N/A N/A #VALUE!5 3 1 1 3221 2 2 $0 $7,039,419 $1,000,000 $2,639,782 $10,679,201 $1,172,519 $0 $921,773 $193,794#VALUE! 0.004 N/A N/A #VALUE! 160 N/A N/A #VALUE!5 6 2 2 3222 2 2 $8,843,368 $17,686,736 $1,000,000 $0 $27,530,103 $3,022,657 $442,168 $3,732,225 $784,663#VALUE! 4 N/A N/A #VALUE! 10 N/A N/A #VALUE!5 6 6 6 3222 2 2 2 $5,234,154 $5,981,890 $1,000,000 $2,243,209 $14,459,252 $1,587,548 $149,547 $488,224 $102,644#VALUE! 4 N/A N/A #VALUE! 10 N/A N/A #VALUE!5 6 6 6 3222 2 2 2 $11,393,026 $13,020,601 $1,000,000 $4,882,725 $30,296,351 $3,326,377 $325,515 $1,784,869 $375,251#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!1 4 4 4 3222 2 2 $11,393,026 $0 $1,000,000 $4,882,725 $17,275,751 $1,896,785 $325,515 $0 $528,006#VALUE! 0.004 N/A N/A #VALUE! 160 N/A N/A #VALUE!5 3 1 1 3222 2 2 $0 $7,806,435 $1,000,000 $0 $8,806,435 $966,899 $0 $1,095,176 $230,250FacilityIDMISmurfitStoneOntonagonMIVersoPaperQuinnesecMN3MHutchinsonMN3MHutchinsonMNAndersonCorpBayportMNAndersonCorpBayportMNBoisePaper1212MNGPDuluthMNGPDuluthMNGPDuluthMNGPDuluthMNGPDuluthMNNorbordMinnesotaMNNorbordMinnesotaMNSappiCloquetMNSappiCloquetMNVersoPaperMNVersoPaperMNWausauPaper‐BrainerdMNWausauPaper‐BrainerdMNWausauPaper‐BrainerdMNWeyerhaeuserIrontonMSBowaterSouthMSGeorgiaPacificMonticelloMSGPBaySpringsMSGPBaySpringsMSGPGlosterPlyMSGPGlosterPlyMSGPGlosterPlyMSGPLouisvillePlyMSGPNewAugustaMSGPTaylorsvillePlyMSGPTaylorsvillePlyMSGPTylertownMillMSHankinsLumberMSHankinsLumberMSHoodBeaumontMSHoodWaynesboroMSHoodWigginsMSHoodWigginsMSHoodWigginsMSIPVicksburgHg %redDioxinLimitDioxinEmissionsDioxinDifferenceDioxin%red CO LimitCOEmissionsCODifference CO %redHClControlGroupHgControlGroupPMControlGroupMetalsControlGroupNAICSPM NeedUpgrade?HCl NeedUpgrade?Hg NeedUpgrade?DioxinNeedUpgrade?CO NeedUpgrade? PM Upgrade Cost HCl Upgrade Cost Hg/Dioxin Upgrade Cost CO Upgrade Cost Total Capital CostTotal AnnualizedCapital CostAnnual OperatingCosts for New FFfor PMAnnual OperatingCosts for new WSfor HClAnnual OperatingCost for CarbonInjection for Hg/dioxin#VALUE! 0.004 N/A N/A #VALUE! 160 N/A N/A #VALUE!3 6 2 2 3222 2 $5,101,698 $0 $1,000,000 $0 $6,101,698 $669,934 $255,085 $0 $359,7650.005 N/A N/A #VALUE! 490 109.1374 380.86265 6 2 2 3222 $0 $0 $1,000,000 $0 $1,000,000 $109,795 $0 $0 $585,214#VALUE! 4 N/A N/A #VALUE! 10 N/A N/A #VALUE!5 6 6 6 3222 2 2 2 $4,277,299 $4,888,342 $1,000,000 $1,833,128 $11,998,770 $1,317,400 $122,209 $348,731 $73,317#VALUE! 4 N/A N/A #VALUE! 10 N/A N/A #VALUE!5 6 6 6 3222 2 2 2 $4,277,299 $4,888,342 $1,000,000 $1,833,128 $11,998,770 $1,317,400 $122,209 $348,731 $73,317#VALUE! 0.005 N/A N/A #VALUE! 490 31.40845 458.59155 6 2 2 3212 $0 $0 $1,000,000 $0 $1,000,000 $109,795 $0 $0 $47,592#VALUE! 0.005 N/A N/A #VALUE! 490 31.40845 458.59155 6 2 2 3212 $0 $0 $1,000,000 $0 $1,000,000 $109,795 $0 $0 $47,5920.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 2 2 3222 2 $0 $0 $1,000,000 $3,947,440 $4,947,440 $543,202 $0 $0 $370,448#VALUE! 4 N/A N/A #VALUE! 10 N/A N/A #VALUE!5 6 6 6 3212 2 2 2 $2,434,530 $2,782,320 $1,000,000 $1,043,370 $7,260,220 $797,133 $69,558 $136,322 $28,660#VALUE! 4 N/A N/A #VALUE! 10 N/A N/A #VALUE!5 6 6 6 3212 2 2 2 $2,434,530 $2,782,320 $1,000,000 $1,043,370 $7,260,220 $797,133 $69,558 $136,322 $28,660#VALUE! 0.2 N/A N/A #VALUE! 470 N/A N/A #VALUE!5 6 2 2 3212 2 2 $1,698,974 $0 $1,000,000 $1,274,231 $3,973,205 $436,236 $84,949 $0 $54,914#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 2 2 3212 2 2 $797,196 $0 $1,000,000 $597,897 $2,395,094 $262,968 $39,860 $0 $15,9434 0.010391 3.989609 10 77.82179 -67.8218 87.15%5 6 2 2 3211 1 1 $1,391,160 $2,782,320 $0 $1,043,370 $5,216,850 $572,782 $69,558 $136,322 $0#VALUE! 0.2 N/A N/A #VALUE! 470 959.7274 -489.727 51.03%5 6 2 2 3211 2 1 $878,848 $0 $1,000,000 $659,136 $2,537,985 $278,657 $43,942 $0 $18,757#VALUE! 0.2 N/A N/A #VALUE! 470 959.7274 -489.727 51.03%5 6 2 2 3211 2 1 $878,848 $0 $1,000,000 $659,136 $2,537,985 $278,657 $43,942 $0 $18,7570.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 2 2 3222 2 2 $4,462,402 $0 $1,000,000 $3,346,802 $8,809,204 $967,203 $223,120 $0 $281,3530.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 2 2 3222 2 2 $5,538,307 $0 $1,000,000 $4,153,731 $10,692,038 $1,173,928 $276,915 $0 $403,27383.61% 0.003 N/A N/A #VALUE! 270 N/A N/A #VALUE!4 5 3 3 3221 1 2 2 $4,483,965 $0 $1,000,000 $1,921,699 $7,405,664 $813,102 $128,113 $0 $114,1660.005 N/A N/A #VALUE! 490 59.71165 430.28834 5 3 3 3221 2 $8,827,602 $0 $1,000,000 $0 $9,827,602 $1,079,018 $252,217 $0 $345,1260.003 N/A N/A #VALUE! 270 N/A N/A #VALUE!5 6 2 2 3221 2 2 $0 $3,189,791 $1,000,000 $1,196,172 $5,385,963 $591,350 $0 $246,415 $51,8060.003 N/A N/A #VALUE! 270 N/A N/A #VALUE!5 6 2 2 3221 2 2 $0 $4,807,909 $1,000,000 $1,802,966 $7,610,875 $835,633 $0 $488,266 $102,6530.003 N/A N/A #VALUE! 270 N/A N/A #VALUE!5 6 2 2 3221 2 2 $0 $4,807,909 $1,000,000 $1,802,966 $7,610,875 $835,633 $0 $488,266 $102,653#VALUE! 0.005 N/A N/A #VALUE! 490 132.3223 357.67775 6 2 2 3212 $0 $0 $1,000,000 $0 $1,000,000 $109,795 $0 $0 $205,9270.005 N/A N/A #VALUE! 490 412.9498 77.050254 5 3 3 3222 $0 $0 $1,000,000 $0 $1,000,000 $109,795 $0 $0 $219,455#VALUE! 0.005 N/A N/A #VALUE! 490 326.7245 163.27555 6 2 2 3222 2 $8,724,039 $0 $1,000,000 $0 $9,724,039 $1,067,647 $436,202 $0 $860,002#VALUE! 0.005 N/A N/A #VALUE! 490 546.3959 -56.3959 10.32%5 6 2 2 3212 2 1 $1,911,128 $0 $1,000,000 $1,433,346 $4,344,473 $477,000 $95,556 $0 $66,812#VALUE! 0.005 N/A N/A #VALUE! 490 585.9405 -95.9405 16.37%5 6 2 2 3212 2 1 $1,689,101 $0 $1,000,000 $1,266,826 $3,955,926 $434,339 $84,455 $0 $54,383#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 5 5 3211 2 2 $2,600,631 $0 $1,000,000 $1,114,556 $4,715,188 $517,702 $74,304 $0 $43,931#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 5 5 3211 2 2 $2,600,631 $0 $1,000,000 $1,114,556 $4,715,188 $517,702 $74,304 $0 $43,931#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 5 5 3211 2 2 $3,990,889 $0 $1,000,000 $1,710,381 $6,701,270 $735,763 $114,025 $0 $89,693#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 2 2 3211 2 2 $2,626,328 $0 $1,000,000 $1,969,746 $5,596,074 $614,419 $131,316 $0 $113,4890.005 N/A N/A #VALUE! 490 101.9839 388.01615 6 2 2 3222 $0 $0 $1,000,000 $0 $1,000,000 $109,795 $0 $0 $587,579#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 2 2 3212 2 2 $3,002,583 $0 $1,000,000 $2,251,937 $6,254,520 $686,713 $150,129 $0 $141,861#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 5 5 3212 2 2 $5,534,343 $0 $1,000,000 $2,371,861 $8,906,204 $977,853 $158,124 $0 $154,674#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 5 5 3212 2 2 $1,961,583 $0 $1,000,000 $840,679 $3,802,262 $417,468 $56,045 $0 $27,457#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 5 5 3212 2 2 $3,119,479 $0 $1,000,000 $1,336,920 $5,456,398 $599,083 $89,128 $0 $59,490#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 5 5 3212 2 2 $1,672,518 $0 $1,000,000 $716,793 $3,389,311 $372,128 $47,786 $0 $21,050#VALUE! 0.005 N/A N/A #VALUE! 490 383.3162 106.68384 5 3 3 3212 2 $4,943,230 $0 $1,000,000 $0 $5,943,230 $652,535 $141,235 $0 $131,298#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 5 5 3212 2 2 $4,039,560 $0 $1,000,000 $1,731,240 $6,770,800 $743,397 $115,416 $0 $93,784#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 5 5 3212 2 2 $3,119,479 $0 $1,000,000 $1,336,920 $5,456,398 $599,083 $89,128 $0 $60,960#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 5 5 3212 2 2 $3,119,479 $0 $1,000,000 $1,336,920 $5,456,398 $599,083 $89,128 $0 $60,9600.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 5 5 3212 2 2 $3,792,098 $0 $1,000,000 $1,625,185 $6,417,283 $704,583 $108,346 $0 $84,406#VALUE! 0.005 N/A N/A #VALUE! 490 259.2119 230.78811 4 4 4 3222 2 $14,792,637 $0 $1,000,000 $0 $15,792,637 $1,733,947 $422,647 $0 $815,923FacilityIDMSNorbordMSMSNorbordMSMSNorbordMSMSSandersonPlumbingMSShuqualakLumberMSShuqualakLumberMSShuqualakLumberMSShuqualakLumberMSWeyerhaeuser1398MSWeyerhaeuser1398MSWeyerhaeuserBruceMSWeyerhaeuserBruceMSWeyerhaeuserColumbusMTPlumCreekMTPlumCreekMTPlumCreekMTPlumCreekMTPlumCreekMTRoseburgMissoulaMTSmurfitStoneNCBlueRidgePaperNCBlueRidgePaperNCBlueRidgePaperNCBlueRidgePaperNCBlueRidgePaperNCDomtarNCDomtarNCDomtarNCGPAhoskieCNSNCGPDudleyNCGPRoxboroNCGPWhitevilleNCInternationalPaperRiegelwoodNCInternationalPaperRiegelwoodNCInternationalPaperRiegelwoodNCJacksonPaperSylvaNCJeld‐WenNCKapStoneNCKapStoneNCLAPacificRoxboroNCLAPacificRoxboroNCLPRoaringRiverHg %redDioxinLimitDioxinEmissionsDioxinDifferenceDioxin%red CO LimitCOEmissionsCODifference CO %redHClControlGroupHgControlGroupPMControlGroupMetalsControlGroupNAICSPM NeedUpgrade?HCl NeedUpgrade?Hg NeedUpgrade?DioxinNeedUpgrade?CO NeedUpgrade? PM Upgrade Cost HCl Upgrade Cost Hg/Dioxin Upgrade Cost CO Upgrade Cost Total Capital CostTotal AnnualizedCapital CostAnnual OperatingCosts for New FFfor PMAnnual OperatingCosts for new WSfor HClAnnual OperatingCost for CarbonInjection for Hg/dioxin#VALUE! 4 N/A N/A #VALUE! 690 N/A N/A #VALUE!5 6 2 2 321$0 $0 $0 $0 $0 $0 $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 $0 $0 $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 $0 $0 $0 $0 $00.005 N/A N/A #VALUE! 490 476.2361 13.763865 6 5 5 3212 2 $1,091,316 $0 $1,000,000 $0 $2,091,316 $229,615 $31,180 $0 $10,333#VALUE! 0.2 N/A N/A #VALUE! 470 N/A N/A #VALUE!5 6 5 5 3212 2 2 $2,400,400 $0 $1,000,000 $1,028,743 $4,429,143 $486,296 $68,583 $0 $38,440#VALUE! 0.2 N/A N/A #VALUE! 470 N/A N/A #VALUE!5 6 5 5 3212 2 2 $1,294,162 $0 $1,000,000 $554,641 $2,848,803 $312,783 $36,976 $0 $13,728#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 5 5 3212 2 2 $1,922,086 $0 $1,000,000 $823,751 $3,745,837 $411,273 $54,917 $0 $26,542#VALUE! 0.005 N/A N/A #VALUE! 490 122.248 367.7525 6 5 5 3212 2 $1,922,086 $0 $1,000,000 $0 $2,922,086 $320,829 $54,917 $0 $26,542#VALUE! 0.005 N/A N/A #VALUE! 490 2891.434 -2401.43 83.05%5 6 5 5 3211 2 1 $4,943,230 $0 $1,000,000 $2,118,527 $8,061,758 $885,138 $141,235 $0 $128,132#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 5 5 3211 2 2 $1,918,107 $0 $1,000,000 $822,046 $3,740,152 $410,649 $54,803 $0 $26,450#VALUE! 0.005 N/A N/A #VALUE! 490 2124.637 -1634.64 76.94%5 6 6 5 3211 2 1 $3,261,316 $0 $1,000,000 $1,397,707 $5,659,023 $621,330 $93,180 $0 $64,0664 0.003171 3.996829 690 354.881 335.1195 6 2 2 321$0 $0 $0 $0 $0 $0 $0 $0 $00.005 N/A N/A #VALUE! 490 96.24913 393.75095 6 2 2 3222 $0 $0 $1,000,000 $0 $1,000,000 $109,795 $0 $0 $1,281,324#VALUE! 0.2 N/A N/A #VALUE! 470 N/A N/A #VALUE!5 6 2 2 3212 2 2 $1,522,923 $0 $1,000,000 $1,142,192 $3,665,116 $402,410 $76,146 $0 $45,762#VALUE! 0.2 N/A N/A #VALUE! 470 N/A N/A #VALUE!5 6 2 2 3212 2 2 $1,522,923 $0 $1,000,000 $1,142,192 $3,665,116 $402,410 $76,146 $0 $45,762#VALUE! 0.2 N/A N/A #VALUE! 470 N/A N/A #VALUE!4 5 3 3 3212 2 2 $3,664,252 $0 $1,000,000 $1,570,394 $6,234,646 $684,531 $104,693 $0 $77,795#VALUE! 4 N/A N/A #VALUE! 690 N/A N/A #VALUE!5 6 2 2 3212 $1,120,905 $0 $0 $0 $1,120,905 $123,069 $56,045 $0 $0#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 2 2 3212 2 2 $4,390,618 $0 $1,000,000 $3,292,964 $8,683,582 $953,411 $219,531 $0 $273,8500.005 N/A N/A #VALUE! 490 53.53662 436.46345 6 5 5 3212 2 $2,821,965 $0 $1,000,000 $0 $3,821,965 $419,631 $80,628 $0 $50,338#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!4 5 3 3 3222 2 2 $9,315,230 $0 $1,000,000 $3,992,241 $14,307,471 $1,570,883 $266,149 $0 $368,3810.004 N/A N/A #VALUE! 160 75.24458 84.755425 6 2 2 3221 1 2 $5,011,374 $10,022,748 $1,000,000 $0 $16,034,122 $1,760,460 $250,569 $1,661,017 $349,2120.004 N/A N/A #VALUE! 160 15.82828 144.17175 6 2 2 3221 1 2 $5,011,374 $10,022,748 $1,000,000 $0 $16,034,122 $1,760,460 $250,569 $1,661,017 $349,2120.004 N/A N/A #VALUE! 160 15.3462 144.65385 6 2 2 3221 1 2 $5,295,168 $10,590,336 $1,000,000 $0 $16,885,503 $1,853,937 $264,758 $1,820,731 $382,7900.004 N/A N/A #VALUE! 160 13.49823 146.50185 6 2 2 3222 $0 $0 $1,000,000 $0 $1,000,000 $109,795 $0 $0 $447,5420.005 N/A N/A #VALUE! 490 666.8057 -176.806 26.52%4 5 3 3 3221 2 1 $8,999,206 $0 $1,000,000 $3,856,803 $13,856,009 $1,521,315 $257,120 $0 $356,3800.005 N/A N/A #VALUE! 490 55.91815 434.08185 6 2 2 3221 2 $0 $17,126,438 $1,000,000 $0 $18,126,438 $1,990,185 $0 $3,870,057 $813,64130.35% 4 N/A N/A #VALUE! 10 49.05812 -39.0581 79.62%2 6 6 6 3221 1 1 1 $8,711,953 $0 $1,000,000 $3,733,694 $13,445,647 $1,476,260 $248,913 $0 $232,7960.005 N/A N/A #VALUE! 490 1634.34 -1144.34 70.02%5 6 2 2 3222 1 $0 $0 $1,000,000 $5,787,939 $6,787,939 $745,279 $0 $0 $684,136#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 5 5 3211 2 2 $3,837,423 $0 $1,000,000 $1,644,610 $6,482,032 $711,692 $109,641 $0 $84,018#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!1 4 4 4 3211 2 2 $7,066,987 $0 $1,000,000 $3,028,709 $11,095,695 $1,218,248 $201,914 $0 $232,4690.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 5 5 3211 2 2 $3,261,316 $0 $1,000,000 $1,397,707 $5,659,023 $621,330 $93,180 $0 $64,066#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!1 4 4 4 3211 2 2 $6,856,213 $0 $1,000,000 $2,938,377 $10,794,590 $1,185,188 $195,892 $0 $221,028#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!4 5 3 3 3222 2 2 $9,624,261 $0 $1,000,000 $4,124,683 $14,748,944 $1,619,355 $274,979 $0 $398,583#VALUE! 4 N/A N/A #VALUE! 10 N/A N/A #VALUE!1 4 4 4 3222 2 $7,000,000 $0 $0 $3,000,000 $10,000,000 $1,097,946 $200,000 $0 $0#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!4 5 3 3 3222 2 2 $11,836,540 $0 $1,000,000 $5,072,803 $17,909,343 $1,966,350 $338,187 $0 $562,706#VALUE! 0.005 N/A N/A #VALUE! 490 879.8478 -389.848 44.31%4 5 3 3 3221 2 1 $5,050,501 $0 $1,000,000 $2,164,501 $8,215,002 $901,963 $144,300 $0 $132,800#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 5 5 3211 2 2 $2,454,855 $0 $1,000,000 $1,052,081 $4,506,936 $494,837 $70,139 $0 $39,9040.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!4 5 3 3 3221 2 2 $11,234,446 $0 $1,000,000 $4,814,762 $17,049,208 $1,871,911 $320,984 $0 $515,814#VALUE! 4 N/A N/A #VALUE! 10 N/A N/A #VALUE!5 6 6 6 3221 2 2 2 $5,843,016 $6,677,733 $1,000,000 $2,504,150 $16,024,898 $1,759,448 $166,943 $586,502 $123,306#VALUE! 0.2 N/A N/A #VALUE! 470 N/A N/A #VALUE!5 6 2 2 3212 2 2 $1,332,085 $0 $1,000,000 $999,064 $3,331,149 $365,742 $66,604 $0 $37,514#VALUE! 0.2 N/A N/A #VALUE! 470 N/A N/A #VALUE!5 6 2 2 3212 2 2 $1,332,085 $0 $1,000,000 $999,064 $3,331,149 $365,742 $66,604 $0 $36,6090.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!4 5 3 3 3212 2 2 $3,506,794 $0 $1,000,000 $1,502,912 $6,009,706 $659,833 $100,194 $0 $74,090FacilityIDNCLPRoaringRiverNCLPRoaringRiverNCSeaboardLumberNCSeaboardLumberNCSeaboardLumberNCUniboardUSANCWestFraserNCWeyerhaeuserGriftonNCWeyerhaeuserGriftonNCWeyerhaeuserGriftonNCWeyerhaeuser‐VanceboroNCWeyerhaeuser‐VanceboroNYFinchPaperNYIntlPaperTiconderogaOHAppletonIdeasOHAppletonIdeasOHGlatfelterChillicotheOHGlatfelterChillicotheOHGlatfelterChillicotheOHRockTennCincinnatiOHSmartPapersHoldingsLLCOHSmurfitCoshoctonOKGPMuskogeeMillOKGPMuskogeeMillOKGPMuskogeeMillOKIPValliantOKIPValliantOKPanPacificProductsOKWeyerhaeuserWrightCityORBBSMMedfordORBBSMMedfordORBBSMMedfordORBlueHeronPaperORBoiseBuildingORCascadePacificPulpORFlakeboardEugeneORGeorgiaPacificWaunaMillORGeorgiaPacificWaunaMillORGPToledoORJeldWenKlamanthFallsORRosboroSpringfieldORRosboroSpringfieldHg %redDioxinLimitDioxinEmissionsDioxinDifferenceDioxin%red CO LimitCOEmissionsCODifference CO %redHClControlGroupHgControlGroupPMControlGroupMetalsControlGroupNAICSPM NeedUpgrade?HCl NeedUpgrade?Hg NeedUpgrade?DioxinNeedUpgrade?CO NeedUpgrade? PM Upgrade Cost HCl Upgrade Cost Hg/Dioxin Upgrade Cost CO Upgrade Cost Total Capital CostTotal AnnualizedCapital CostAnnual OperatingCosts for New FFfor PMAnnual OperatingCosts for new WSfor HClAnnual OperatingCost for CarbonInjection for Hg/dioxin#VALUE! 4 N/A N/A #VALUE! 10 N/A N/A #VALUE!5 6 6 6 3212 2 2 2 $2,468,344 $2,820,964 $1,000,000 $1,057,862 $7,347,170 $806,680 $70,524 $139,492 $29,32742.50% 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!4 5 3 3 3212 1 2 2 $5,805,033 $0 $1,000,000 $2,487,871 $9,292,904 $1,020,311 $165,858 $0 $171,625#VALUE! 0.02 N/A N/A #VALUE! 430 N/A N/A #VALUE!5 6 2 2 3211 $1,626,934 $0 $0 $0 $1,626,934 $178,629 $81,347 $0 $0#VALUE! 0.02 N/A N/A #VALUE! 430 N/A N/A #VALUE!5 6 5 5 3212 $2,077,028 $0 $0 $0 $2,077,028 $228,047 $59,344 $0 $0#VALUE! 0.02 N/A N/A #VALUE! 430 N/A N/A #VALUE!5 6 5 5 3212 $2,077,028 $0 $0 $0 $2,077,028 $228,047 $59,344 $0 $0#VALUE! 0.2 N/A N/A #VALUE! 470 N/A N/A #VALUE!5 6 2 2 3212 2 2 $1,698,974 $0 $1,000,000 $1,274,231 $3,973,205 $436,236 $84,949 $0 $54,914#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!4 5 3 3 3212 2 2 $4,143,760 $0 $1,000,000 $1,775,897 $6,919,656 $759,741 $118,393 $0 $95,492#VALUE! 4 N/A N/A #VALUE! 690 460.0472 229.95285 6 2 2 321$0 $0 $0 $0 $0 $0 $0 $0 $0#VALUE! 4 N/A N/A #VALUE! 690 460.0472 229.95285 6 2 2 321$0 $0 $0 $0 $0 $0 $0 $0 $0#VALUE! 4 N/A N/A #VALUE! 690 N/A N/A #VALUE!5 6 2 2 3212 $1,650,256 $0 $0 $0 $1,650,256 $181,189 $82,513 $0 $0#VALUE! 4 N/A N/A #VALUE! 10 N/A N/A #VALUE!5 6 6 6 3221 2 2 2 $11,586,204 $13,241,376 $1,000,000 $4,965,516 $30,793,096 $3,380,916 $331,034 $1,835,594 $385,915#VALUE! 4 N/A N/A #VALUE! 10 N/A N/A #VALUE!2 6 6 6 3221 2 2 $7,604,369 $0 $1,000,000 $3,259,015 $11,863,384 $1,302,536 $217,268 $0 $191,291#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!4 5 3 3 3222 2 2 $5,602,831 $0 $1,000,000 $2,401,213 $9,004,044 $988,596 $160,081 $0 $161,7780.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!2 6 5 5 3221 2 2 $14,639,077 $0 $1,000,000 $6,273,890 $21,912,968 $2,405,926 $418,259 $0 $801,8560.003 N/A N/A #VALUE! 270 45.63686 224.36315 6 2 2 3221 2 $0 $6,028,382 $1,000,000 $0 $7,028,382 $771,679 $0 $711,865 $149,6620.003 N/A N/A #VALUE! 270 19.7315 250.26855 6 2 2 3221 1 2 $3,951,806 $7,903,612 $1,000,000 $0 $12,855,419 $1,411,456 $197,590 $1,117,992 $235,047#VALUE! 0.004 N/A N/A #VALUE! 160 N/A N/A #VALUE!5 6 2 2 3222 2 2 $5,101,698 $10,203,396 $1,000,000 $0 $16,305,094 $1,790,212 $255,085 $1,711,213 $359,765#VALUE! 0.004 N/A N/A #VALUE! 160 N/A N/A #VALUE!5 6 2 2 3222 2 2 $6,062,866 $12,125,733 $1,000,000 $0 $19,188,599 $2,106,805 $303,143 $1,989,459 $418,264#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 2 2 3222 2 2 $4,354,432 $0 $1,000,000 $3,265,824 $8,620,255 $946,458 $217,722 $0 $270,099#VALUE! 0.003 N/A N/A #VALUE! 270 N/A N/A #VALUE!5 3 1 1 3221 2 2 2 $0 $4,068,338 $1,000,000 $1,525,627 $6,593,964 $723,982 $0 $369,622 $77,70925.28% 0.004 N/A N/A #VALUE! 160 N/A N/A #VALUE!5 6 2 2 3222 1 2 $0 $10,921,331 $1,000,000 $0 $11,921,331 $1,308,898 $0 $1,671,145 $351,3420.005 N/A N/A #VALUE! 490 272.6726 217.32744 5 3 3 3221 2 $12,349,960 $0 $1,000,000 $0 $13,349,960 $1,465,754 $352,856 $0 $603,9710.004 N/A N/A #VALUE! 160 26.51437 133.48565 6 2 2 3222 2 $4,852,745 $0 $1,000,000 $0 $5,852,745 $642,600 $242,637 $0 $330,9840.004 N/A N/A #VALUE! 160 13.96812 146.03195 3 1 1 3222 $0 $0 $1,000,000 $0 $1,000,000 $109,795 $0 $0 $464,0100.004 N/A N/A #VALUE! 160 3.200772 156.79925 3 1 1 3222 $0 $0 $1,000,000 $0 $1,000,000 $109,795 $0 $0 $464,010#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 4 5 3 3222 22SEE CISWI#VALUE! 4 N/A N/A #VALUE! 10 N/A N/A #VALUE!5 6 6 6 3222 2 2 2 $15,545,086 $17,765,812 $1,000,000 $6,662,180 $40,973,077 $4,498,624 $444,145 $2,995,917 $629,862#VALUE! 0.005 N/A N/A #VALUE! 490 557.0262 -67.0262 12.03%1 4 4 4 3211 2 1 $2,501,852 $0 $1,000,000 $1,072,222 $4,574,074 $502,209 $71,481 $0 $41,185#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 2 2 3212 2 $0 $0 $1,000,000 $2,927,413 $3,927,413 $431,209 $0 $0 $219,656#VALUE! 0.005 N/A N/A #VALUE! 490 3852.927 -3362.93 87.28%5 6 2 2 3212 1 $0 $0 $1,000,000 $1,242,104 $2,242,104 $246,171 $0 $0 $53,926#VALUE! 0.005 N/A N/A #VALUE! 490 3852.927 -3362.93 87.28%5 6 2 2 3212 1 $0 $0 $1,000,000 $1,519,969 $2,519,969 $276,679 $0 $0 $75,496#VALUE! 0.005 N/A N/A #VALUE! 490 3852.927 -3362.93 87.28%5 6 2 2 3212 1 $0 $0 $1,000,000 $1,882,678 $2,882,678 $316,503 $0 $0 $107,852#VALUE! 0.005 N/A N/A #VALUE! 490 147.0563 342.94375 6 5 5 3222 $0 $0 $1,000,000 $0 $1,000,000 $109,795 $0 $0 $102,506#VALUE! 0.2 N/A N/A #VALUE! 470 N/A N/A #VALUE!5 6 2 2 3212 2 2 $2,019,064 $0 $1,000,000 $1,514,298 $4,533,361 $497,739 $100,953 $0 $73,219#VALUE! 4 N/A N/A #VALUE! 10 4.871715 5.1282855 6 6 6 3211 2 2 $6,658,413 $7,609,615 $1,000,000 $0 $15,268,028 $1,676,347 $190,240 $729,165 $153,3000.2 N/A N/A #VALUE! 470 448.4687 21.531345 3 1 1 3212 $0 $0 $1,000,000 $0 $1,000,000 $109,795 $0 $0 $46,677#VALUE! 4 N/A N/A #VALUE! 10 0.209332 9.7906685 6 6 6 3221 2 2 $5,972,714 $6,825,959 $1,000,000 $0 $13,798,672 $1,515,020 $170,649 $608,360 $127,9020.02 0.00228 0.01772 430 23.89197 406.1083 2 1 1 322$0 $0 $0 $0 $0 $0 $0 $0 $0#VALUE! 4 N/A N/A #VALUE! 10 27.20041 -17.2004 63.24%5 6 6 6 3221 2 2 1 $5,890,265 $6,731,731 $1,000,000 $2,524,399 $16,146,394 $1,772,787 $168,293 $594,428 $124,973#VALUE! 0.005 N/A N/A #VALUE! 490 297.4003 192.59975 6 2 2 3212 2 $1,926,793 $0 $1,000,000 $0 $2,926,793 $321,346 $96,340 $0 $69,4000.2 0.032539 0.167461 470 409.9549 60.045055 6 5 5 3211 $2,665,116 $0 $0 $0 $2,665,116 $292,615 $76,146 $0 $0#VALUE! 0.2 N/A N/A #VALUE! 470 N/A N/A #VALUE!5 6 5 5 3212 2 2 $2,665,116 $0 $1,000,000 $1,142,192 $4,807,308 $527,817 $76,146 $0 $45,762FacilityIDORRosboroSpringfieldORRoseburgCoquilleORRoseburgForestDillardORRoseburgForestDillardORRoseburgForestDillardORRoseburgRiddle2ORRoseburgRiddle2ORSierraPineORSierraPineSpringfieldORSierraPineSpringfieldORSierraPineSpringfieldORSPNewsprintORSPNewsprintORStimsonLumberForestGroveORStimsonLumberForestGroveORStimsonLumberForestGrovePAAppletonPapersPAAppletonPapersPACraftMasterPADomtarJohnsonburgPADomtarJohnsonburgPAPHGlatfelterPAPHGlatfelterPAPHGlatfelterPAPHGlatfelterPAProctorGambleMehoopanyPAPATeamTenPATemple‐InlandPATemple‐InlandSCBowaterCoatedPaperSCBowaterCoatedPaperSCBowaterCoatedPaperSCChesterWoodProductsSCCogenSouthSCCollumsLumberSCGPProsperityPlySCGPRussellvilleSCInternationalPaperEastoverSCInternationalPaperEastoverSCIPGeorgetownSCIPGeorgetownSCMarlboroPaperHg %redDioxinLimitDioxinEmissionsDioxinDifferenceDioxin%red CO LimitCOEmissionsCODifference CO %redHClControlGroupHgControlGroupPMControlGroupMetalsControlGroupNAICSPM NeedUpgrade?HCl NeedUpgrade?Hg NeedUpgrade?DioxinNeedUpgrade?CO NeedUpgrade? PM Upgrade Cost HCl Upgrade Cost Hg/Dioxin Upgrade Cost CO Upgrade Cost Total Capital CostTotal AnnualizedCapital CostAnnual OperatingCosts for New FFfor PMAnnual OperatingCosts for new WSfor HClAnnual OperatingCost for CarbonInjection for Hg/dioxin#VALUE! 0.2 N/A N/A #VALUE! 470 N/A N/A #VALUE!5 6 5 5 3212 2 2 $2,665,116 $0 $1,000,000 $1,142,192 $4,807,308 $527,817 $76,146 $0 $45,7620.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 5 5 3212 2 2 $4,676,776 $0 $1,000,000 $2,004,332 $7,681,108 $843,344 $133,622 $0 $116,8290.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!1 4 4 4 3212 2 2 $7,948,938 $0 $1,000,000 $3,406,688 $12,355,626 $1,356,581 $227,113 $0 $289,7940.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!1 4 4 4 3212 2 2 $7,948,938 $0 $1,000,000 $3,406,688 $12,355,626 $1,356,581 $227,113 $0 $289,7940.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!1 4 4 4 3212 2 2 $10,862,656 $0 $1,000,000 $4,655,424 $16,518,081 $1,813,596 $310,362 $0 $487,6780.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 2 2 3212 2 2 $2,657,971 $0 $1,000,000 $1,993,479 $5,651,450 $620,499 $132,899 $0 $115,7770.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!1 4 4 4 3212 2 2 $3,546,595 $0 $1,000,000 $1,519,969 $6,066,564 $666,076 $101,331 $0 $73,676#VALUE! 0.2 N/A N/A #VALUE! 470 N/A N/A #VALUE!1 4 2 2 3212 2 2 $2,356,461 $0 $1,000,000 $1,767,346 $5,123,806 $562,566 $117,823 $0 $94,726#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 2 2 3212 2 2 $878,848 $0 $1,000,000 $659,136 $2,537,985 $278,657 $43,942 $0 $18,305#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 2 2 3212 2 2 $1,120,905 $0 $1,000,000 $840,679 $2,961,583 $325,166 $56,045 $0 $27,457#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 2 2 3212 2 2 $1,120,905 $0 $1,000,000 $840,679 $2,961,583 $325,166 $56,045 $0 $27,4570.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 2 2 3221 2 2 $0 $13,076,027 $1,000,000 $4,903,510 $18,979,537 $2,083,851 $0 $2,468,304 $518,936#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!1 4 4 4 3222 2 2 $7,395,787 $0 $1,000,000 $3,169,623 $11,565,409 $1,269,820 $211,308 $0 $250,773#VALUE! 0.005 N/A N/A #VALUE! 490 378.7998 111.20025 6 2 2 3212 2 $1,957,871 $0 $1,000,000 $0 $2,957,871 $324,758 $97,894 $0 $69,558#VALUE! 0.005 N/A N/A #VALUE! 490 378.7998 111.20025 6 2 2 3212 2 $1,957,871 $0 $1,000,000 $0 $2,957,871 $324,758 $97,894 $0 $69,558#VALUE! 0.005 N/A N/A #VALUE! 490 378.7998 111.20025 6 2 2 3212 2 $1,957,871 $0 $1,000,000 $0 $2,957,871 $324,758 $97,894 $0 $69,558#VALUE! 4 N/A N/A #VALUE! 10 33.09038 -23.0904 69.78%5 6 6 6 3222 2 2 1 $6,214,762 $7,102,585 $1,000,000 $2,663,469 $16,980,816 $1,864,402 $177,565 $650,003 $136,65755.41% 0.005 N/A N/A #VALUE! 490 1070.274 -580.274 54.22%4 5 3 3 3221 1 2 1 $5,747,746 $0 $1,000,000 $2,463,320 $9,211,065 $1,011,325 $164,221 $0 $168,812#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 2 2 3212 2 $0 $0 $1,000,000 $3,164,067 $4,164,067 $457,192 $0 $0 $250,0410.004 N/A N/A #VALUE! 160 68.2946 91.70541 4 2 2 3222 $0 $0 $1,000,000 $0 $1,000,000 $109,795 $0 $0 $284,1970.004 N/A N/A #VALUE! 160 68.2946 91.70541 4 2 2 3222 $0 $0 $1,000,000 $0 $1,000,000 $109,795 $0 $0 $284,9670.004 N/A N/A #VALUE! 160 N/A N/A #VALUE!5 6 2 2 3221 2 $0 $5,651,827 $1,000,000 $0 $6,651,827 $730,335 $0 $639,309 $134,4080.004 N/A N/A #VALUE! 160 N/A N/A #VALUE!5 6 2 2 3221 2 $0 $10,017,791 $1,000,000 $0 $11,017,791 $1,209,694 $0 $1,659,648 $348,9240.004 N/A N/A #VALUE! 160 N/A N/A #VALUE!5 6 2 2 3221 2 $0 $8,233,888 $1,000,000 $0 $9,233,888 $1,013,831 $0 $1,196,936 $251,6440.02 N/A N/A #VALUE! 430 23.18695 406.8133 6 2 2 322$0 $0 $0 $0 $0 $0 $0 $0 $0#VALUE! 4 N/A N/A #VALUE! 10 N/A N/A #VALUE!5 6 6 6 3222 2 2 2 $6,864,727 $7,845,402 $1,000,000 $2,942,026 $18,652,154 $2,047,906 $196,135 $767,208 $161,298#VALUE! 0.003 N/A N/A #VALUE! 270 N/A N/A #VALUE!5 3 1 1 3222 2 2 2 $0 $7,728,108 $1,000,000 $2,898,041 $11,626,149 $1,276,489 $0 $1,076,923 $226,412#VALUE! 0.2 N/A N/A #VALUE! 470 N/A N/A #VALUE!5 6 6 5 3212 2 2 $2,665,116 $0 $1,000,000 $1,142,192 $4,807,308 $527,817 $76,146 $0 $45,762#VALUE! 0.2 N/A N/A #VALUE! 470 N/A N/A #VALUE!5 6 6 5 3212 2 2 $3,148,186 $0 $1,000,000 $1,349,223 $5,497,409 $603,586 $89,948 $0 $60,4050.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 2 2 3221 2 2 $5,342,801 $0 $1,000,000 $4,007,101 $10,349,902 $1,136,364 $267,140 $0 $379,826#VALUE! 4 N/A N/A #VALUE! 10 N/A N/A #VALUE!5 6 6 6 3221 2 2 2 $8,927,972 $10,203,396 $1,000,000 $3,826,274 $23,957,641 $2,630,420 $255,085 $1,188,856 $249,9450.005 0.004861 0.000139 490 2818.176 -2328.18 82.61%5 6 2 2 3221 1 $7,545,630 $0 $0 $5,659,222 $13,204,852 $1,449,822 $377,281 $0 $0#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!1 4 4 4 3212 2 2 $4,985,481 $0 $1,000,000 $2,136,635 $8,122,115 $891,765 $142,442 $0 $133,1740.005 N/A N/A #VALUE! 490 16.09804 473.9021 2 1 1 3222 $0 $0 $1,000,000 $0 $1,000,000 $109,795 $0 $0 $1,253,896#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 5 5 3211 2 2 $2,095,853 $0 $1,000,000 $898,223 $3,994,076 $438,528 $59,882 $0 $31,4180.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!1 4 4 4 3211 2 2 $6,122,828 $0 $1,000,000 $2,624,069 $9,746,897 $1,070,157 $174,938 $0 $187,569#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 5 5 3211 2 2 $6,977,632 $0 $1,000,000 $2,990,414 $10,968,046 $1,204,232 $199,361 $0 $227,5910.005 N/A N/A #VALUE! 490 520.3779 -30.3779 5.84%5 6 2 2 3222 1 $0 $0 $1,000,000 $4,547,150 $5,547,150 $609,047 $0 $0 $468,922#VALUE! 0.005 N/A N/A #VALUE! 490 25.71091 464.28915 6 2 2 3221 2 $0 $12,769,206 $1,000,000 $0 $13,769,206 $1,511,785 $0 $2,431,148 $511,124#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 2 2 3222 2 2 $6,709,482 $0 $1,000,000 $5,032,112 $12,741,594 $1,398,959 $335,474 $0 $555,203#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 2 2 3222 2 2 $6,709,482 $0 $1,000,000 $5,032,112 $12,741,594 $1,398,959 $335,474 $0 $555,2030.005 0.002758 0.002242 490 313.5231 176.47695 6 2 2 322$0 $0 $0 $0 $0 $0 $0 $0 $0FacilityIDSCNewSouthCamdenSCNewSouthCoConwaySCNewSouthLumberCoDarlingtonSCNewSouthLumberCoDarlingtonSCRoseburgForestRussellvilleSCSimpsonLumberGeorgetownSCSimpsonLumberGeorgetownSCSmurfitStoneSCSmurfitStoneSCSonocoHartsvilleSCSonocoHartsvilleSCSonocoHartsvilleSCWestFraserNewberrySCWestFraserNewberrySCWestFraserNewberryTNArborCraftTNArborCraftTNBowaterNewsprintTNBowaterNewsprintTNBowaterNewsprintTNBowaterNewsprintTNDomtar2384TNPackagingCorpCounceTNPackagingCorpCounceTXAnthonyForestProd‐ATLTXAnthonyForestProd‐ATLTXDibollTemple‐InlandTXDibollTemple‐InlandTXGPClevelandPlyLumberTXInternationalPaperQueenCityTXLPCarthageTXLPJasperOSBTXLPJasperOSBTXMeadWestvacoEvadaleTXNorbordTexasJeffersonTXNorbordTexasJeffersonTXNorbordTexasNacogdochesTXNorbordTexasNacogdochesTXNorbordTexasNacogdochesTXNorbordTexasNacogdochesTXNorbordTexasNacogdochesTXPinelandTemple‐InlandHg %redDioxinLimitDioxinEmissionsDioxinDifferenceDioxin%red CO LimitCOEmissionsCODifference CO %redHClControlGroupHgControlGroupPMControlGroupMetalsControlGroupNAICSPM NeedUpgrade?HCl NeedUpgrade?Hg NeedUpgrade?DioxinNeedUpgrade?CO NeedUpgrade? PM Upgrade Cost HCl Upgrade Cost Hg/Dioxin Upgrade Cost CO Upgrade Cost Total Capital CostTotal AnnualizedCapital CostAnnual OperatingCosts for New FFfor PMAnnual OperatingCosts for new WSfor HClAnnual OperatingCost for CarbonInjection for Hg/dioxin0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 2 2 3211 2 2 $2,195,678 $0 $1,000,000 $1,646,759 $4,842,437 $531,674 $109,784 $0 $86,2820.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 2 2 3211 2 2 $2,195,678 $0 $1,000,000 $1,646,759 $4,842,437 $531,674 $109,784 $0 $86,282#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 5 5 3211 2 2 $1,919,301 $0 $1,000,000 $822,558 $3,741,859 $410,836 $54,837 $0 $27,132#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 5 5 3211 2 2 $1,910,131 $0 $1,000,000 $818,628 $3,728,759 $409,398 $54,575 $0 $26,9160.2 N/A N/A #VALUE! 470 N/A N/A #VALUE!5 3 1 1 3212 2 $0 $0 $1,000,000 $854,059 $1,854,059 $203,566 $0 $0 $28,189#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 2 2 3212 2 2 $1,761,082 $0 $1,000,000 $1,320,812 $4,081,894 $448,170 $88,054 $0 $58,300#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 5 5 3212 2 2 $1,910,131 $0 $1,000,000 $818,628 $3,728,759 $409,398 $54,575 $0 $26,2670.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 2 2 3222 2 $0 $0 $1,000,000 $3,626,884 $4,626,884 $508,007 $0 $0 $313,924#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 2 2 3222 2 $0 $0 $1,000,000 $6,704,390 $7,704,390 $845,901 $0 $0 $874,0460.002 0.001388 0.000612 82 168.4007 -86.4007 51.31%3 2 1 1 3221 1 $0 $0 $0 $2,463,320 $2,463,320 $270,459 $0 $0 $0#VALUE! 0.004 N/A N/A #VALUE! 160 N/A N/A #VALUE!5 6 2 2 3221 2 2 $3,262,481 $6,524,962 $1,000,000 $0 $10,787,443 $1,184,403 $163,124 $812,256 $170,769#VALUE! 0.003 N/A N/A #VALUE! 270 N/A N/A #VALUE!5 3 1 1 3222 2 2 2 $0 $10,284,807 $1,000,000 $3,856,803 $15,141,609 $1,662,467 $0 $1,734,029 $364,562#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 5 5 3212 2 2 $1,910,131 $0 $1,000,000 $818,628 $3,728,759 $409,398 $54,575 $0 $26,916#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 5 5 3212 2 2 $1,910,131 $0 $1,000,000 $818,628 $3,728,759 $409,398 $54,575 $0 $26,916#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 5 5 3212 2 2 $1,910,131 $0 $1,000,000 $818,628 $3,728,759 $409,398 $54,575 $0 $26,916#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 5 5 3212 2 2 $1,401,976 $0 $1,000,000 $600,847 $3,002,823 $329,694 $40,056 $0 $15,687#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 5 5 3212 2 2 $1,401,976 $0 $1,000,000 $600,847 $3,002,823 $329,694 $40,056 $0 $15,68733.65% 0.004 N/A N/A #VALUE! 160 N/A N/A #VALUE!5 6 2 2 3221 2 $0 $0 $1,000,000 $0 $1,000,000 $109,795 $0 $0 $205,306#VALUE! 0.004 N/A N/A #VALUE! 160 N/A N/A #VALUE!5 6 2 2 3222 2 2 $5,767,010 $11,534,019 $1,000,000 $0 $18,301,029 $2,009,355 $288,350 $1,830,302 $384,8030.004 N/A N/A #VALUE! 160 N/A N/A #VALUE!5 6 2 2 3222 $0 $0 $1,000,000 $0 $1,000,000 $109,795 $0 $0 $384,8030.02 0.005345 0.014656 430 115.3842 314.61585 6 2 2 322$0 $0 $0 $0 $0 $0 $0 $0 $00.02 0.01886 0.00114 430 81.74706 348.25295 6 2 2 3221 $6,377,571 $0 $0 $0 $6,377,571 $700,223 $318,879 $0 $0#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 5 6 2 3222 22SEE CISWI#VALUE! 4 N/A N/A #VALUE! 10 N/A N/A #VALUE!5 6 6 6 3222 1 2 2 $9,280,471 $10,606,253 $1,000,000 $3,977,345 $24,864,069 $2,729,941 $265,156 $1,268,113 $266,608#VALUE! 0.005 N/A N/A #VALUE! 490 300.3018 189.69825 6 5 5 3211 2 $1,715,777 $0 $1,000,000 $0 $2,715,777 $298,178 $49,022 $0 $22,508#VALUE! 0.005 N/A N/A #VALUE! 490 233.151 256.8495 6 5 5 3211 2 $1,910,131 $0 $1,000,000 $0 $2,910,131 $319,517 $54,575 $0 $26,916#VALUE! 0.2 N/A N/A #VALUE! 470 N/A N/A #VALUE!5 6 5 5 3212 2 2 $1,882,040 $0 $1,000,000 $806,589 $3,688,629 $404,992 $53,773 $0 $25,6260.2 N/A N/A #VALUE! 470 69.30937 400.69065 6 2 2 3212 2 $1,332,085 $0 $1,000,000 $0 $2,332,085 $256,050 $66,604 $0 $36,609#VALUE! 0.005 N/A N/A #VALUE! 490 386.6385 103.36154 5 3 3 3212 2 $7,648,796 $0 $1,000,000 $0 $8,648,796 $949,591 $218,537 $0 $271,787#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE! 4 5 3 3222 22SEE CISWI#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 2 2 3212 2 2 $1,165,161 $0 $1,000,000 $873,871 $3,039,032 $333,669 $58,258 $0 $29,287#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 2 2 3212 2 2 $2,651,211 $0 $1,000,000 $1,988,408 $5,639,619 $619,200 $132,561 $0 $115,286#VALUE! 0.2 N/A N/A #VALUE! 470 N/A N/A #VALUE!5 6 2 2 3212 2 2 $1,208,324 $0 $1,000,000 $906,243 $3,114,567 $341,963 $60,416 $0 $31,118#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 6 5 3222 2 2 $8,087,053 $0 $1,000,000 $3,465,880 $12,552,933 $1,378,245 $231,059 $0 $298,234#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 2 2 3212 2 2 $3,229,378 $0 $1,000,000 $2,422,033 $6,651,411 $730,289 $161,469 $0 $164,123#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 2 2 3212 2 2 $3,229,378 $0 $1,000,000 $2,422,033 $6,651,411 $730,289 $161,469 $0 $164,123#VALUE! 0.2 N/A N/A #VALUE! 470 N/A N/A #VALUE!5 6 2 2 3212 2 2 $1,332,085 $0 $1,000,000 $999,064 $3,331,149 $365,742 $66,604 $0 $36,609#VALUE! 4 N/A N/A #VALUE! 690 1222.067 -532.067 43.54%5 6 2 2 3211 $0 $0 $0 $576,540 $576,540 $63,301 $0 $0 $0#VALUE! 4 N/A N/A #VALUE! 690 1222.067 -532.067 43.54%5 6 2 2 3211 $0 $0 $0 $576,540 $576,540 $63,301 $0 $0 $0#VALUE! 0.2 N/A N/A #VALUE! 470 N/A N/A #VALUE!5 6 2 2 3212 2 2 $1,332,085 $0 $1,000,000 $999,064 $3,331,149 $365,742 $66,604 $0 $36,609#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 2 2 3212 2 2 $1,698,974 $0 $1,000,000 $1,274,231 $3,973,205 $436,236 $84,949 $0 $56,271#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 2 2 3212 2 2 $3,229,378 $0 $1,000,000 $2,422,033 $6,651,411 $730,289 $161,469 $0 $164,123FacilityIDTXPinelandTemple‐InlandTXPinelandTemple‐InlandTXTempleInlandFiberboardTXTemple‐InlandOrangeTXwestfraserVAATCPanelsVAATCPanelsVABassettFiberboardVABassettFiberboardVABearIslandPaperCoAshlandVAGeorgiaPacificBrooknealGladysVAGeorgiaPacificEmporiaVAGPBigIsland2703VAGPBigIsland2703VAGPJarrattFiberboardVAGreifVAGreifVAGreifVAMeadWestVaco‐CovingtonVAVAMeadWestVaco‐CovingtonVAVAMeadWestVaco‐CovingtonVAVAMeadWestVaco‐CovingtonVAVASmurfitStoneHopewellVASmurfitStoneWestptVASmurfitStoneWestptWABoiseKettleFallsPlywoodWABoisePaperWallulaWAGPCamasWAGPCamasWAGraysHarborPaperWAGraysHarborPaperWAJeldWenWhiteSwanWAJeldWenWhiteSwanWAKimberlyClarkEverettWANipponPaperWANipponPaperWANipponPaperWAPonderayAbiboWAPort TownsendWASierraPacificWASimpsonLumberCompanyWASimpsonTacoma2784Hg %redDioxinLimitDioxinEmissionsDioxinDifferenceDioxin%red CO LimitCOEmissionsCODifference CO %redHClControlGroupHgControlGroupPMControlGroupMetalsControlGroupNAICSPM NeedUpgrade?HCl NeedUpgrade?Hg NeedUpgrade?DioxinNeedUpgrade?CO NeedUpgrade? PM Upgrade Cost HCl Upgrade Cost Hg/Dioxin Upgrade Cost CO Upgrade Cost Total Capital CostTotal AnnualizedCapital CostAnnual OperatingCosts for New FFfor PMAnnual OperatingCosts for new WSfor HClAnnual OperatingCost for CarbonInjection for Hg/dioxin#VALUE! 0.2 N/A N/A #VALUE! 470 N/A N/A #VALUE!5 6 6 5 3212 2 2 $1,628,500 $0 $1,000,000 $697,928 $3,326,428 $365,224 $46,529 $0 $20,135#VALUE! 0.2 N/A N/A #VALUE! 470 N/A N/A #VALUE!5 6 6 5 3212 2 2 $1,628,500 $0 $1,000,000 $697,928 $3,326,428 $365,224 $46,529 $0 $20,1350.005 N/A N/A #VALUE! 490 1089.894 -599.894 55.04%1 4 4 4 3212 2 1 $6,658,413 $0 $1,000,000 $2,853,606 $10,512,019 $1,154,163 $190,240 $0 $210,503#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!4 5 3 3 3222 2 2 $9,196,695 $0 $1,000,000 $3,941,441 $14,138,135 $1,552,291 $262,763 $0 $369,510#VALUE! 0.005 N/A N/A #VALUE! 490 569.9905 -79.9905 14.03%1 4 4 4 3211 2 1 $3,809,767 $0 $1,000,000 $1,632,757 $6,442,524 $707,355 $108,850 $0 $85,0620.2 N/A N/A #VALUE! 470 N/A N/A #VALUE!5 6 5 5 3212 2 2 $2,535,063 $0 $1,000,000 $1,086,456 $4,621,518 $507,418 $72,430 $0 $42,101#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 5 5 3212 2 2 $2,331,149 $0 $1,000,000 $999,064 $4,330,213 $475,434 $66,604 $0 $36,609#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 5 5 3212 2 2 $2,151,666 $0 $1,000,000 $922,143 $4,073,809 $447,282 $61,476 $0 $32,033#VALUE! 4 N/A N/A #VALUE! 10 N/A N/A #VALUE!5 6 6 6 3212 2 2 2 $1,762,537 $2,014,328 $1,000,000 $755,373 $5,532,238 $607,410 $50,358 $77,202 $16,2310.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 2 2 3222 1 2 2 $3,932,419 $7,864,837 $1,000,000 $2,949,314 $15,746,570 $1,728,889 $196,621 $1,057,845 $222,401#VALUE! 4 N/A N/A #VALUE! 690 172.6735 517.32655 6 2 2 3211 $3,903,217 $0 $0 $0 $3,903,217 $428,552 $195,161 $0 $0#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!1 4 4 4 3211 2 2 $5,736,242 $0 $1,000,000 $2,458,390 $9,194,632 $1,009,521 $163,893 $0 $164,1930.004 N/A N/A #VALUE! 160 33.58487 126.41515 6 2 2 3222 $0 $0 $1,000,000 $0 $1,000,000 $109,795 $0 $0 $272,4620.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 2 2 3222 2 $0 $0 $1,000,000 $3,569,481 $4,569,481 $501,705 $0 $0 $313,24037.87% 0.003 N/A N/A #VALUE! 270 N/A N/A #VALUE!5 6 5 5 3212 1 2 2 $3,705,483 $0 $1,000,000 $1,588,064 $6,293,546 $690,998 $105,871 $0 $83,082#VALUE! 4 N/A N/A #VALUE! 10 N/A N/A #VALUE!5 6 6 6 3222 2 2 2 $6,571,183 $7,509,923 $1,000,000 $2,816,221 $17,897,327 $1,965,030 $187,748 $713,314 $149,967#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 2 2 3222 2 $0 $0 $1,000,000 $2,956,590 $3,956,590 $434,412 $0 $0 $228,834#VALUE! 4 N/A N/A #VALUE! 10 N/A N/A #VALUE!5 6 6 6 3222 2 2 2 $6,571,183 $7,509,923 $1,000,000 $2,816,221 $17,897,327 $1,965,030 $187,748 $713,314 $149,9670.003 N/A N/A #VALUE! 270 N/A N/A #VALUE!2 6 2 2 3222 2 $0 $0 $1,000,000 $4,211,423 $5,211,423 $572,186 $0 $0 $368,0720.003 N/A N/A #VALUE! 270 N/A N/A #VALUE!2 6 2 2 3222 2 $0 $0 $1,000,000 $4,970,660 $5,970,660 $655,546 $0 $0 $485,1860.003 N/A N/A #VALUE! 270 N/A N/A #VALUE!2 6 2 2 3222 2 $0 $0 $1,000,000 $6,060,122 $7,060,122 $775,163 $0 $0 $675,0780.004 N/A N/A #VALUE! 160 N/A N/A #VALUE!2 6 2 2 3222 $0 $0 $1,000,000 $0 $1,000,000 $109,795 $0 $0 $460,090#VALUE! 0.004 N/A N/A #VALUE! 160 N/A N/A #VALUE!5 6 2 2 3222 2 $0 $16,624,485 $1,000,000 $0 $17,624,485 $1,935,074 $0 $3,366,164 $707,7020.004 0.003281 0.000719 160 16.49103 143.5095 6 2 2 322$0 $0 $0 $0 $0 $0 $0 $0 $016.33% 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 2 2 3221 2 2 $0 $0 $1,000,000 $5,366,467 $6,366,467 $699,004 $0 $0 $618,039#VALUE! 0.005 N/A N/A #VALUE! 490 5482.714 -4992.71 91.06%5 6 2 2 3212 1 $0 $0 $1,000,000 $1,072,222 $2,072,222 $227,519 $0 $0 $41,185#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!4 5 2 2 3222 2 2 $4,191,364 $0 $1,000,000 $3,143,523 $8,334,887 $915,126 $209,568 $0 $247,3410.005 N/A N/A #VALUE! 490 295.5398 194.46025 6 2 2 3222 2 $4,244,646 $0 $1,000,000 $0 $5,244,646 $575,834 $212,232 $0 $252,604#VALUE! 4 N/A N/A #VALUE! 10 36.53786 -26.5379 72.63%4 5 3 3 3222 1 $8,087,053 $0 $0 $3,465,880 $11,552,933 $1,268,450 $231,059 $0 $00.2 0.371994 -0.17199 46.24% 470 993.0823 -523.082 52.67%4 5 3 3 3221 1 1 1 $6,304,717 $0 $1,000,000 $2,702,022 $10,006,739 $1,098,686 $180,135 $0 $196,9470.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!1 4 4 4 3221 2 2 $9,280,471 $0 $1,000,000 $3,977,345 $14,257,816 $1,565,432 $265,156 $0 $375,137#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 2 2 3212 2 2 $1,473,034 $0 $1,000,000 $1,104,775 $3,577,809 $392,824 $73,652 $0 $43,290#VALUE! 4 N/A N/A #VALUE! 10 N/A N/A #VALUE!5 6 6 6 3212 2 2 2 $2,253,352 $2,575,260 $1,000,000 $965,722 $6,794,335 $745,981 $64,381 $116,265 $24,4440.005 N/A N/A #VALUE! 490 33.92247 456.07755 3 1 1 3221 2 $0 $11,153,715 $1,000,000 $0 $12,153,715 $1,334,413 $0 $1,893,673 $398,126#VALUE! 4 N/A N/A #VALUE! 10 N/A N/A #VALUE!5 6 6 6 3221 2 2 2 $4,392,914 $5,020,474 $1,000,000 $1,882,678 $12,296,066 $1,350,042 $125,512 $364,583 $76,6500.005 0.00614 -0.00114 18.57% 490 498.4054 -8.40543 1.69%4 5 3 3 3221 1 1 $5,375,632 $0 $1,000,000 $2,303,842 $8,679,475 $952,960 $153,589 $0 $147,352#VALUE! 4 N/A N/A #VALUE! 10 N/A N/A #VALUE!5 6 6 6 3221 2 2 2 $4,392,914 $5,020,474 $1,000,000 $1,882,678 $12,296,066 $1,350,042 $125,512 $364,583 $76,650#VALUE! 0.02 N/A N/A #VALUE! 430 N/A N/A #VALUE!3 2 1 1 322$0 $0 $0 $0 $0 $0 $0 $0 $0#VALUE! 4 N/A N/A #VALUE! 10 N/A N/A #VALUE!5663222 2 2 2 $5,899,684 $6,742,496 $1,000,000 $2,528,436 $16,170,616 $1,775,447 $168,562 $578,864 $121,700#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 6 5 3212 2 2 $7,612,315 $0 $1,000,000 $3,262,421 $11,874,736 $1,303,782 $217,495 $0 $263,1290.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 2 2 3212 2 2 $3,338,866 $0 $1,000,000 $2,504,150 $6,843,016 $751,326 $166,943 $0 $169,318#VALUE! 0.005 N/A N/A #VALUE! 490 131.8708 358.12925 6 2 2 3222 $0 $0 $1,000,000 $0 $1,000,000 $109,795 $0 $0 $315,755FacilityIDWAWeyerhaeuser_RaymondWAWeyerhaeuserLongviewWIAlgomaWIAlgomaWIAppletonWIAppletonCoatedWIDomtar2814WIDomtar2814WIDomtarNekoosaWIDomtarNekoosaWIDomtarNekoosaWIDomtarNekoosaWIFlambeauRiverPaperWIGPGreenBay2818WIGPGreenBay2818WIGPGreenBay2818WIGPGreenBay2818WIGPGreenBay2818WIGPGreenBay2818WIGreenBayPackagingMillDivisionWILPHaywardWILPHaywardWILPHaywardWILPHaywardWINeenahPaperAppletonWINewPageBironWINewPageBironWINewPageKimberlyWINewPageKimberlyWINewPage‐WhitingWINewPage‐WisconsinRapidsWINewPage‐WisconsinRapidsWIPCATomahawkWIPCATomahawkWIPCATomahawkWIThilmanyLLCWIThilmanyLLCWIThilmanyLLCWIThilmanyPapersNicoletMillWIThilmanyPapersNicoletMillWIWausauWIWausauHg %redDioxinLimitDioxinEmissionsDioxinDifferenceDioxin%red CO LimitCOEmissionsCODifference CO %redHClControlGroupHgControlGroupPMControlGroupMetalsControlGroupNAICSPM NeedUpgrade?HCl NeedUpgrade?Hg NeedUpgrade?DioxinNeedUpgrade?CO NeedUpgrade? PM Upgrade Cost HCl Upgrade Cost Hg/Dioxin Upgrade Cost CO Upgrade Cost Total Capital CostTotal AnnualizedCapital CostAnnual OperatingCosts for New FFfor PMAnnual OperatingCosts for new WSfor HClAnnual OperatingCost for CarbonInjection for Hg/dioxin4 0.001873 3.998127 690 121.2614 568.73865 6 2 2 321$0 $0 $0 $0 $0 $0 $0 $0 $0#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!3 6 2 2 3222 2 $0 $0 $1,000,000 $5,235,927 $6,235,927 $684,671 $0 $0 $578,884#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 6 5 3212 2 2 $1,583,673 $0 $1,000,000 $678,717 $3,262,391 $358,193 $45,248 $0 $19,220#VALUE! 0.005 N/A N/A #VALUE! 490 206.6548 283.34525 6 6 5 3212 2 $2,114,567 $0 $1,000,000 $0 $3,114,567 $341,963 $60,416 $0 $31,1180.003 N/A N/A #VALUE! 270 N/A N/A #VALUE!5 6 5 5 3222 2 2 2 $2,468,344 $2,820,964 $1,000,000 $1,057,862 $7,347,170 $806,680 $70,524 $200,782 $42,212#VALUE! 0.003 N/A N/A #VALUE! 270 N/A N/A #VALUE!5 6 2 2 3222 2 2 2 $4,818,908 $9,637,816 $1,000,000 $3,614,181 $19,070,904 $2,093,883 $240,945 $1,556,063 $327,147#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 2 2 3222 2 $0 $0 $1,000,000 $1,931,372 $2,931,372 $321,849 $0 $0 $112,541#VALUE! 4 N/A N/A #VALUE! 10 N/A N/A #VALUE!5 6 6 6 3222 2 2 2 $6,122,828 $6,997,517 $1,000,000 $2,624,069 $16,744,414 $1,838,447 $174,938 $615,159 $129,3310.003 N/A N/A #VALUE! 270 N/A N/A #VALUE!5 6 2 2 3221 2 2 $0 $5,850,410 $1,000,000 $2,193,904 $9,044,314 $993,017 $0 $677,184 $142,3710.004 N/A N/A #VALUE! 160 N/A N/A #VALUE!5 6 2 2 3221 2 $0 $5,967,895 $1,000,000 $0 $6,967,895 $765,037 $0 $700,000 $147,1680.004 N/A N/A #VALUE! 160 N/A N/A #VALUE!5 6 2 2 3221 2 $0 $5,967,895 $1,000,000 $0 $6,967,895 $765,037 $0 $700,000 $147,1680.003 N/A N/A #VALUE! 270 N/A N/A #VALUE!5 6 2 2 3221 2 2 $0 $8,981,802 $1,000,000 $3,368,176 $13,349,978 $1,465,756 $0 $1,383,573 $290,8820.005 N/A N/A #VALUE! 490 104.1038 385.89624 5 3 3 3221 2 $6,983,187 $0 $1,000,000 $0 $7,983,187 $876,511 $199,520 $0 $233,5230.003 N/A N/A #VALUE! 270 N/A N/A #VALUE!5 3 1 1 3221 2 2 2 $3,498,759 $6,997,517 $1,000,000 $2,624,069 $14,120,345 $1,550,338 $0 $912,647 $191,8750.002 N/A N/A #VALUE! 82 98.36852 -16.3685 16.64%3 2 1 1 3221 2 1 $5,960,432 $0 $1,000,000 $4,470,324 $11,430,756 $1,255,036 $0 $0 $406,5520.003 N/A N/A #VALUE! 270 N/A N/A #VALUE!5 3 1 1 3221 1 2 2 $4,894,821 $9,789,642 $1,000,000 $3,671,116 $19,355,579 $2,125,138 $0 $1,597,132 $335,7810.003 N/A N/A #VALUE! 270 N/A N/A #VALUE!5 3 1 1 3221 1 2 2 $3,854,222 $7,708,444 $1,000,000 $2,890,666 $15,453,332 $1,696,693 $0 $1,072,360 $225,4530.003 N/A N/A #VALUE! 270 N/A N/A #VALUE!5 3 1 1 3221 1 2 2 $6,864,692 $13,729,384 $1,000,000 $5,148,519 $26,742,595 $2,936,193 $0 $2,447,034 $514,46557.03% 0.02 0.033158 -0.01316 39.68% 430 1.501291 428.49875 3 1 1 3221 1 1 $0 $4,476,722 $1,000,000 $0 $5,476,722 $601,315 $0 $423,778 $89,0950.003 N/A N/A #VALUE! 270 N/A N/A #VALUE!5 3 1 1 3221 2 2 $0 $7,589,747 $1,000,000 $2,846,155 $11,435,901 $1,255,601 $0 $1,044,981 $219,697#VALUE! 0.005 N/A N/A #VALUE! 490 1204.099 -714.099 59.31%5 6 2 2 3212 2 1 $862,933 $0 $1,000,000 $647,200 $2,510,133 $275,599 $43,147 $0 $18,194#VALUE! 0.005 N/A N/A #VALUE! 490 743.4 -253.4 34.09%5 6 2 2 3212 2 1 $862,933 $0 $1,000,000 $647,200 $2,510,133 $275,599 $43,147 $0 $18,194#VALUE! 0.005 N/A N/A #VALUE! 490 2350.471 -1860.47 79.15%5 6 2 2 3212 2 1 $975,533 $0 $1,000,000 $731,650 $2,707,184 $297,234 $48,777 $0 $22,321#VALUE! 0.005 N/A N/A #VALUE! 490 1645.33 -1155.33 70.22%5 6 2 2 3212 2 1 $975,533 $0 $1,000,000 $731,650 $2,707,184 $297,234 $48,777 $0 $22,321#VALUE! 4 N/A N/A #VALUE! 10 N/A N/A #VALUE!5 6 6 6 3222 2 2 2 $2,973,205 $3,397,948 $1,000,000 $1,274,231 $8,645,383 $949,217 $84,949 $190,217 $39,9910.003 0.001521 0.001479 270 N/A N/A #VALUE!5 6 2 2 3222 $0 $0 $0 $4,240,987 $4,240,987 $465,638 $0 $0 $040.18% 0.004 N/A N/A #VALUE! 160 N/A N/A #VALUE!5 6 2 2 3221 1 2 $0 $9,620,848 $1,000,000 $0 $10,620,848 $1,166,112 $0 $1,551,500 $326,1870.003 N/A N/A #VALUE! 270 N/A N/A #VALUE!5 6 2 2 3221 1 2 2 $2,794,329 $5,588,659 $1,000,000 $2,095,747 $11,478,735 $1,260,303 $139,716 $627,445 $131,9140.003 N/A N/A #VALUE! 270 N/A N/A #VALUE!5 6 2 2 3221 1 2 2 $3,117,356 $6,234,711 $1,000,000 $2,338,017 $12,690,084 $1,393,303 $155,868 $752,934 $158,29747.05% 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 2 2 3221 1 2 2 $3,617,087 $0 $1,000,000 $2,712,815 $7,329,903 $804,784 $180,854 $0 $198,2600.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 2 2 3222 2 $0 $0 $1,000,000 $4,050,282 $5,050,282 $554,494 $0 $0 $386,6730.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 2 2 3222 2 $0 $0 $1,000,000 $4,050,282 $5,050,282 $554,494 $0 $0 $386,673#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 2 2 3221 1 2 2 $4,005,757 $8,011,514 $1,000,000 $3,004,318 $16,021,590 $1,759,084 $200,288 $1,090,930 $229,357#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 2 2 3221 1 2 2 $2,600,830 $5,201,659 $1,000,000 $1,950,622 $10,753,111 $1,180,634 $130,041 $531,099 $111,658#VALUE! 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!5 6 2 2 3221 1 2 2 $3,402,354 $6,804,709 $1,000,000 $2,551,766 $13,758,829 $1,510,645 $170,118 $831,039 $174,71810.88% 0.005 N/A N/A #VALUE! 490 N/A N/A #VALUE!1 4 4 4 3221 1 2 2 $6,196,010 $0 $1,000,000 $2,655,433 $9,851,443 $1,081,636 $177,029 $0 $191,3200.003 0.008731 -0.00573 65.64% 270 64.45627 205.54375 6 2 2 3221 1 1 $5,134,280 $10,268,559 $1,000,000 $0 $16,402,839 $1,800,944 $256,714 $1,729,466 $363,6030.003 0.008731 -0.00573 65.64% 270 64.45627 205.54375 6 2 2 3221 1 1 $3,418,370 $6,836,739 $1,000,000 $0 $11,255,109 $1,235,750 $170,918 $877,966 $184,5840.003 N/A N/A #VALUE! 270 212.115 57.885015 6 2 2 3221 2 $0 $4,753,785 $1,000,000 $0 $5,753,785 $631,735 $0 $479,140 $100,7340.003 N/A N/A #VALUE! 270 212.115 57.885015 6 2 2 3221 2 $0 $4,753,785 $1,000,000 $0 $5,753,785 $631,735 $0 $479,140 $100,7340.003 N/A N/A #VALUE! 270 N/A N/A #VALUE!5 6 2 2 3221 2 2 $0 $5,721,733 $1,000,000 $2,145,650 $8,867,383 $973,591 $0 $652,543 $137,1910.003 N/A N/A #VALUE! 270 N/A N/A #VALUE!5 6 2 2 3221 2 2 $0 $7,240,332 $1,000,000 $2,715,125 $10,955,457 $1,202,850 $0 $966,037 $203,100FacilityIDWIWausauRhineWIWausauRhineWIWausauRhineWIWausauRhineWIWausauRhineWVGPMtHopeOSBWVJELD‐WENCraigsvilleWVWeyerhaeuserBuckhannonRepresents Biomass, Coal, LiquShaded units indicate changestDeleted limited use unitsHg %redDioxinLimitDioxinEmissionsDioxinDifferenceDioxin%red CO LimitCOEmissionsCODifference CO %redHClControlGroupHgControlGroupPMControlGroupMetalsControlGroupNAICSPM NeedUpgrade?HCl NeedUpgrade?Hg NeedUpgrade?DioxinNeedUpgrade?CO NeedUpgrade? PM Upgrade Cost HCl Upgrade Cost Hg/Dioxin Upgrade Cost CO Upgrade Cost Total Capital CostTotal AnnualizedCapital CostAnnual OperatingCosts for New FFfor PMAnnual OperatingCosts for new WSfor HClAnnual OperatingCost for CarbonInjection for Hg/dioxin0.003 N/A N/A #VALUE! 270 N/A N/A #VALUE!5 3 1 1 3222 2 2 $0 $4,362,654 $1,000,000 $1,635,995 $6,998,650 $768,414 $0 $415,254 $87,3030.003 N/A N/A #VALUE! 270 N/A N/A #VALUE!5 3 1 1 3222 2 2 $0 $4,362,654 $1,000,000 $1,635,995 $6,998,650 $768,414 $0 $415,254 $87,3030.003 N/A N/A #VALUE! 270 N/A N/A #VALUE!5 3 1 1 3222 2 2 $0 $4,362,654 $1,000,000 $1,635,995 $6,998,650 $768,414 $0 $415,254 $87,3030.003 N/A N/A #VALUE! 270 N/A N/A #VALUE!5 3 1 1 3222 2 2 $0 $4,362,654 $1,000,000 $1,635,995 $6,998,650 $768,414 $0 $415,254 $87,3030.003 N/A N/A #VALUE! 270 N/A N/A #VALUE!5 6 2 2 3222 2 $0 $0 $1,000,000 $3,346,802 $4,346,802 $477,255 $0 $0 $287,812#VALUE! 4 N/A N/A #VALUE! 690 126.9091 563.09095 6 2 2 3211 $3,903,217 $0 $0 $0 $3,903,217 $428,552 $195,161 $0 $0#VALUE! 0.005 N/A N/A #VALUE! 490 181.5465 308.45355 6 2 2 3212 2 $1,741,101 $0 $1,000,000 $0 $2,741,101 $300,958 $87,055 $0 $57,202#VALUE! 0.005 N/A N/A #VALUE! 490 22.81118 467.18885 6 2 2 3212 $0 $0 $1,000,000 $0 $1,000,000 $109,795 $0 $0 $106,167Filtered Boilers:TOTAL $1,873,342,142 $1,036,172,140 $494,000,000 $944,291,976$4,347,806,258$477,365,756 $61,962,722 $142,633,729 $115,730,669COUNT 545 545 545 545545545 545 545 545AVERAGE $3,437,325 $1,901,233 $906,422 $1,732,646$7,977,626$875,900 $113,693 $261,713 $212,350*Press F9 to recalculate34.4%All Boilers:TOTAL $5,119,891,642 $5,149,190,442 $1,424,000,000 $2,491,022,961$14,184,105,045$1,557,338,490 $165,307,040 $603,803,895 $259,601,89440 255COUNT 1584 1584 1584 158415841584 1584 1584 158423 115AVERAGE $3,232,255 $3,250,752 $898,990 $1,572,616$8,954,612$983,168 $104,361 $381,189 $163,890November 10, 2011



### peA Preferred Definition of ((Processing"

IIProcessing means any operation that transforms discarded nonhazardous

secondary material into a non-waste fuel or non-waste ingredient product.

Processing includes, but is not limited to, removal of extraneous debris, sizing for

safe and efficient handling, shredding, sorting, segregating, cleaning, culling,

racking, or other systematic procedures for making a material ready for use as a

fuel. For example, for tires being used as fuel in a portland cement kiln, neither

shredding nor metal removal shall be necessary.1I

### SUGGESTED REGULATORY LANGUAGE

TO CODIFY ADMINISTRATOR JACKSON'S

MAY 17, 2011 RULING REGARDING

PORTLAND CEMENT KILN INGREDIENTS

(76 FR 28318, 28322)



### Both § 60.2265 (for subpart CCCC) and § 60.2875 (for subpart DDDD)

contain the following definition for "waste-burning kiln"

-

Waste-burning kiln means a kiln that is heated, in whole

or in part, by combusting solid waste (as that term is

defined by the Administrator pursuant to Subtitle D of

RCRA).

Only portland cement kilns that are "waste-burning kilns" as defined in these

sections are subject to CISWI. We accordingly urge EPA to amend both

§§ 60.2265 and 60.2875 by adding the following (new language in bold italics):

Waste-burning kiln means a kiln that is heated, in whole

or in part, by combusting solid waste (as that term is

defined by the Administrator pursuant to Subtitle D of

RCRA). 

### Materials used as ingredients in portland

cement kilns shall not be deemed combusted.

There is currently no definition of "ingredient" in the CISWI

regulations. We urge EPA to amend both §§ 60.2265 and 60.2875 by

adding the following new definition (please note this definition is

taken 

### verbatim from the NHSM definitions

- see § 241.2 at 76 FR

15550):



### "Ingredient" means a non-hazardous secondary

material that is a component in a compound, process, or

product.

### PortlClnd 

### Cemem flS50ciation

August 18,2011

Honorable Mathy Stanislaus

Assistant Administrator Solid Waste and Emergency Response

Environmental Protection Agency

Ariel Rios Building

1200 Pennsylvania Avenue, N.W.

Washington, DC 20460

Re: Portland Cement Association ("PCA") Petition to Amend NonHazardous Secondary Materials ("NHSM") Rule, Filed June 16, 2011

Dear Mr. Stanislaus:

Thank you for taking the time to meet with me and others from PCA regarding our abovereferenced NHSM rulemaking petition on August 4. Based on questions and points you and other

EP A personnel raised during the meeting, we would like to follow up with further elaboration, as set

forth below.

Need for Coordination on Commercial and Industrial Solid Waste Incinerator (CISwn

Rulemaking and Response to PCA's NHSM Administrative Petition

In our NHSM rule administrative petition, we stated (on page 2):

Since the CISWI and NHSM rules are so closely linked

- in fact, the entire

foundation for CISWI applicability over a facility rests entirely on the NHSM

rule

- we believe EPA should consider amendments to key provisions of the

NHSM rule as EPA reconsiders the CISWI rule.

We appreciated having representatives of EPA's Office of Air and Radiation (OAR) and an

Office of General Counsel (OGC) CAA attorney participate with you and your Resource

Conservation and Recovery Act (RCRA) staff in our August 4 meeting. We suggested at that

meeting that since EPA has announced plans to issue a new proposed CISWI rule by the end of

October, 2011, EPA's response to our NHSM petition could be folded into that CISWI rulemaking.

To follow up on that suggestion, we are sending a letter today (copy attached) to Ms. Gina

McCarthy, OAR's Assistant Administrator. We are also sending Ms. McCarthy a copy of this letter

to you.

As you will see in our letter to Ms. McCarthy, PCA filed a petition for reconsideration of the

CISWI rule on May 20,2011. The first issue we raised in our CISWI petition is identical to the first

issue raised in our NHSM petition: ingredients utilized by portland cement kilns are not

"combusted," and therefore such ingredients cannot be deemed a "solid waste" under the NHSM rule

and cannot be subject to the CISWI rule under CAA § 129.

500 New Jersey Avenue, NW

yth Floor

Washington, D.C. 20001

(202) 408-9494As we discussed in our August 4 meeting (and explained in both our NHSM and CISWI

petitions), Administrator Jackson has already resolved that issue in a recent final Federal Register

ruling. 76 FR 28322, May 17, 2011. We also pointed out that even though Administrator Jackson's

ruling definitively resolves this issue, it is important that EPA now clarify the CISWI and NHSM

rules on this point.

Ms. Jackson's Federal Register ruling will not be codified in the c.P.R., but the CISWI and

NHSM rules will. While nothing in the NHSM or CISWI rules contradicts these points, the rules do

not expressly state them. For the benefit of the regulated community, state and regional personnel,

and all interested parties, we believe it is incumbent upon EPA to clarify both rules on these points.

To this end, we provided suggested regulatory language in an Addendum to our NHSM

administrative petition. In today's letter to Ms. McCarthy, we suggest that similar or alternative

language should be added to the CISWI rule.

In today's letter to Ms. McCarthy, we also elaborate upon the suggestion we raised in our

August 4 meeting with you that the upcoming CISWI preamble could reference and notice PCA's

NHSM petition. PCA's NHSM administrative petition was filed pursuant to RCRA

§ 7004(a). This subsection ofRCRA requires that EPA take action in the Federal Register with

respect to any such petition within a reasonable time.

In light of the extremely close relationship between the CISWI and NHSM rules, we believe

it would be most appropriate for EPA to comply with its RCRA § 7004(a) obligations in this manner.

EPA would then be procedurally postured to take final action on the NHSM petition at the same time

it finalizes its CISWI rules. This coordination would be consistent with EPA's earlier approach of

issuing the NHSM and CISWI rules in tandem.

Follow Up on Points Raised in August 4 Meeting

- Processing

We repeated points made in our NHSM petition showing how EPA's approach to

"processing" was, in our view, unnecessarily stringent and would discourage beneficial recyclelreuse

of non-hazardous materials with no benefit to human health and the environment. We also pointed

out that even if one were to concede (which we do not) that some D.C. Circuit case law under RCRA

Subtitle C required the Subtitle D NHSM lUle's approach to "discard," there is no case law (or

statutory language) requiring the NHSM lUle's approach to "processing."

U sing tires as an example, EPA personnel asked what level of processing for whole tires

from landfills and piles would we consider sufficient? EPA personnel wondered whether anything

would be necessary in our view.

The justification for the requirement for processing as expressed in EPA's preambles is to

assure that a discarded material can be processed to a sufficient degree so that it can serve as a bona

fide fuel material. We believe that if only a minimal amount of processing is necessary to make a

certain type of "discarded" material a bona fide fuel (such as a whole tire), then as a matter oflogic,

only a minimal amount of processing should be necessary.

2In the draft regulatory language accompanying our NHSM petition, we made clear that

(contraIY to EPA's current approach) shredding and metal removal would not be necessaIY for whole

tires. We included several other types of actions, however, such as: removal of extraneous debris,

sizing for safe and efficient handling, sorting, segregating, cleaning, culling, racking, and "other

systematic procedures for making a material ready for use as a fuel." Thus something would be

required under our approach.

If some might consider this minimal, that is because only minimal processing is necessary to

render a whole tire usable as a bona fide fuel in a cement kiln. And there clearly can be no health

and environmental justification for EPA's current approach, since the NHSM rule excludes whole

tires that have been subject to neither shredding nor metal removal if the tires come to a kiln through

an "established program."

As noted above, the tire derived fuel example was used for illustrative purposes. The cement

sector utilizes a long list of alternatives to conventional fuels, most of which are acquired from off

site and much of which generally require little processing to be effectively utilized (sizing for

insertion into the kiln being the most common). Unnecessarily stringent processing requirements

should not impede the use of alternative fuels.

- "Traditional" Fuels

We pointed out during the meeting (and explained further in our NHSM petition) that

portland cement kilns have been utilizing tires on a routine basis since the 1980s, and that EPA

should classify tires as "traditional" fuels. EPA personnel asked for our views on how lines could be

drawn in determining how long a fuel must have been used to be considered "traditional."

As in the case of "processing," there is no relevant statutory language or D.C. Circuit case

law that restrains EPA's discretion on this issue. We note further that the first part of EPA's two-part

regulatory definition of "traditional" uses the word "historical" but does not define that term. 40

C.F.R. § 241.2, 76 FR at 15550. The second part of the definition discusses alternative fuels from

virgin materials that can "now" be used as fuels, and does not require any "historical" use. We

believe in this statutory/regulatOlY setting, EPA has ample leeway to classify tires as 'traditional"

fuels where such classification with promote recyclelreuse of secondary materials and have no

impact on human health and the environment.

- The 2007 D.C. Circuit NRDC Opinion

Some EPA personnel noted that if EP A amended the NHSM rule as we are requesting, most

if not all material combusted as fuel by portland cement kilns would be excluded from the definition

of solid waste (and therefore CISWI coverage), and this could appear contrary to the result in NRDC

v. EPA, 489 F.3d 1250 (D.C. Cir. 2007). They expressed concern that the D.C. Circuit would view

this as somehow inconsistent with their 2007 opinion.

We explained in our NHSM petition (as well as our rulemaking comments) that EPA's

discretion to exclude materials from the definition of solid waste through the RCRA NHSM

rulemaking was in no way constrained by NRDC v. EPA, 489 F.3d 1250 (D.C. Cir. 2007). Section

129(g)(1) of the CAA provides (with specified exceptions) that any facility that combusts any "solid

waste" will be subject to CAA § 129. Section 129(g)(6) then provides that "solid waste" shall have

the meaning established by the Administrator pursuant to RCRA.

3In the 2000 CISWI rulemaking (65 Fed. Reg. 75338) leading up to the NRDC case, EPA had

not attempted to exclude any non-hazardous material combusted for energy recovery from the

definition of "solid waste" pursuant to RCRA. EPA had engaged in no RCRA rulemaking related to

CISWI at all.

Rather, EPA's CISWI rule simply provided that facilities combusting solid waste for energy

recovery would not be subject to CISWI. Id. at 1256. It is easy to see how the D.C. Circuit could

come to the conclusion that the rule "conflicts with the plain language of section 129." Id. at 1257.

The rule said that material which could arguably be considered a "solid waste" would nevertheless be

exempt from CAA § 129.

EP A has now

- quite properly

- engaged in rulemaking under RCRA. There is absolutely

nothing in the NRDC opinion that constrains EPA's discretion in defining solid waste under RCRA.

In the RCRA rulemaking EPA can

- as it has done

- provide that certain materials managed in

certain ways will not be deemed solid wastes for purposes of triggering CAA § 129. In fact, a vast

amount of material that EPA attempted to exclude through its prior CISWI rulemaking is now

excluded through the current NHSM rule. And that material is most clearly combusted for energy

recovery.

Certainly, the fact that a court has rejected a result an agency has reached through improper

legal avenues does not mean the agency is precluded from later reaching the same result through

proper legal avenues. We find that proposition rather unremarkable, and cannot imagine why the

D.C. Circuit would have any problem with such a proposition. We note that just two months ago, the

Supreme Court found it entirely appropriate to give effect to an FCC order that had previously been

rej ected on judicial review when the FCC "found another way to support that same conclusion."

Talk America, Inc. v. Michigan Bell Telephone, 131 S.Ct. 2254, 2264 (June 9,2011). EPA's RCRA

rulemaking will stand or fall in the D.C. Circuit based on the rulemaking record and EPA's

articulation of its rationale, and we are confident that EPA can articulate solid rationale for excluding

bona fide fuels in a manner that serves the purposes ofRCRA Subtitle D.

- "Concept Paper" for Legitimacy Criteria Comparable Contaminants

PCA appreciates the opportunity provided by EPA to review the concept paper you

distributed at the meeting, which is posted on EPA's Web site and dated July 11, 20 II.

http://www.epa.gov/epawaste/nonhaz/define/pdfs/nhsm-concept.pdf. While we do believe that the

grouping of contaminants by type is a step in the right direction, we struggle with the application of

the guidance in practice at cement plants. As we have indicated on numerous occasions, cement

plants are capable of using a long list of alternatives to conventional fuels. These fuels, like

conventional fuels, are combusted to provide the necessary process heat to produce clinker, the

intermediate cement product. The process temperatures are such that organic compounds present in

fuels are fully combusted (greater than 99.99% destruction), whether they are contained in

conventional or traditional fuels. Accordingly, PCA struggles with the approach outlined in the

concept paper which would require a contaminant comparison between alternative and "traditional"

fuels prior to combustion. For example, some alternative fuels may have a higher concentration of

one or two organic compounds when compared to a traditional fuel, though this difference becomes

irrelevant once the fuel is combusted in the kiln.

4PCA believes that the focus should be on whether the utilization of an alternative fuel

impacts a facility's ability to comply with the underlying air emission standards. This very burden of

proof is already a part of the portland cement national emission standard for hazardous air pollutants

(NESHAP), where the operator must determine whether (or not) to re-test a kiln to confirm

compliance with an air emission standard when switching fuels.

This makes sense, as the issue in question is whether the use of a non-hazardous alternative

fuel will impact air quality. PCA believes that the approach currently employed under the NESHAP

could also be employed here, especially in light of the fact that the focus in on non-hazardous

materials in the first instance. In implementing such an approach, PCA believes it would be highly

appropriate for cement plants to consider groups of pollutants, rather than individual pollutants, as

has been suggested in the concept paper for contaminants in fuels pre-combustion.

Moreover, EPA has already come to this very conclusion regarding scrap tires managed

through an established program. EPA has determined that these tires can be deemed to pass the

legitimacy criteria. PCA suspects that the Agency may have come to this conclusion having had the

opportunity to review the comparative air emission analysis prepared by PCA addressing tire

combustion in kilns which demonstrated that the emissions when burning tires versus when burning

only conventional fuels are virtually indistinguishable.

Lastly, we note that if EPA does plan to issue some type of comparable contaminant

guidance, this should be offered up as an official change to the NHSM rule and be accomplished

through normal notice and comment rulemaking. PCA continues to believe, however, that the

legitimacy criteria in the NHSM rule for non-hazardous fuels are unnecessary and regulatory overkill

for the materials in question.

Please do not hesitate to contact me with any questions regarding PCA perspectives on this

matter. I may be reached at (202) 408-9494 or aohare@cement.org.

Cc: Gina McCarthy, OAR

Barry Breen, OSWER

Suzanne Rudzinski, ORCR

Jim Berlow, ORCR

John Michaud, OGC

Steve Silverman, OGC

5 Sincerely,

Andrew T. O'Hare

Vice President, Regulatory AffairsTUESDAY, NOVEMBER 08 , 2011 1 TECHNICAL MEMORANDUM



## Boiler MACT Economic Impact Evaluation

PREPARED FOR: 

### Amy Banister, Waste Management, Inc.

PREPARED BY: 

### Evan Griffiths , Dan Pitzler and Tom Kraemer, CH2M HILL

DATE: 

### November 9 , 2011



## Introduction

This Technical Memorandum summarizes the economic evaluation of the cumulative, nationwide financial impact s of

switching from landfill gas (LFG) to natural gas at facilities currently using LFG as boiler fuel, if this were to occur in

response to the requirements of the currently promulgated Boiler Maximum Achievable Control Technology (MACT)

rule. The faciliti es used for this evaluation were th ose included in a database spreadsheet provided by USEPA’s

Landfill Methane Outreach Program (LMOP) by email to Waste Management on September 26 of this year.

This analysis is limited to the projected financial costs for existing projects utilizing landfill gas in boilers that would be

affected by the Boiler MACT rule if it became effective. Additional economic impacts including projected loss of jobs

have been projected by LMOP. Still more economic impacts would result from the inability to develop new projects

that would use landfill gas in boilers. LMOP estimates there are over 500 landfills capable of development into

landfill gas

- to

- energy projects. However, the number that would use LFG in boilers and the investm ents and returns

for these prospective projects are too uncertain to estimate the financial impacts.



## Results

Table 1 lists the estimated financial impacts of switching from LFG to natural gas for all LFG

- fired boilers in the United

States listed in USEPA’s LMOP database. Costs in Table 1 are rounded to the nearest million dollars

TABLE 1. Summary Costs for Converting LFG Boiler and Boiler Steam Turbine Projects to natural gas

Type of Project NPV of Natural Gas

Supply

Minus LFG

O&M Costs NPV of Lost Royalty

Payments Capital Cost (2011 dollars) Abandoned Value

(Depreciated Value of

Capital Cost)

Boilers $ 797 ,000,000 $62,000,000 $156,000,000 $78,000,000

Boiler Steam Turbines $ 190,000,000 $15,000,000 $94,000,000 $ 9 ,000,000

Combined TOTAL (Boiler

and Steam Turbine) $ 987 ,000,000 $77,000,000 $250,000,000 $ 87 ,000,000

Th e order

- of

- magnitude estimate of the total direct financial impact of fuel

- switching from LFG to natural gas for the

list of sites provided by LMOP is thus estimated to be $1.064 b illion , the sum of the NPV of natural gas costs in excess

of LFG O&M costs, and the NPV of lost royalty payments to landfill owners

.

The costs for utilizing natural gas to replace th e LFG were calculated for each project. These costs were computed as

the net present value of the cost differences between natural gas supply and estimated LFG operations and

maintenance (O&M) costs over the remaining life of the project. Lost royalty pay ments to landfill owner and/or

developer were estimated based on the amount of BTUs for which royalty payments would no longer be paid over

the remaining life of the system.

In addition to direct revenue impacts , project owners will lose the value of LFG p rocessing and transport equipment

that must be abandoned when switching from LFG to natural gas. To estimate this impact, t he capital costs

associated with constructing compressor systems and pipelines for utilizing LFG in the boiler projects were estimat edBOILER MACT ECONOMIC IMPACT EVALUATION

TUESDAY, NOVEMBER 08 , 2011 2 for each project in the LMOP database, as described below under Methodolo gy. The costs were depreciated based

on the age of the project to estimate the depreciated value of the installed system that would be abandoned. These

sunk costs must be written off as stranded assets before they are fully depreciated. The total estimated capital

assets lost for all existing project is $87 million.

In addition, Waste Management has estimated they could lose $4 to 5 million annually in revenue from third party

developers and directly from large industries. This loss of revenue is likely only a portion of the total revenue that

could be lost when all other factors such as end user costs are also factored.



## Methodology

A list of projects that use LFG as boiler fuel was generated by LMOP

. LMOP is a voluntary program of the U.S.

Environmental Protection Agency that is intended to help reduce methane emissions from landfills by encouraging

the recovery and beneficial use of LFG as an energy resource. LMOP maintains a database of projects that use LFG as

boiler fuel. This database was downloaded to an Excel file and used as the basis for this financial evaluation

. T he

database contain s, among other data, the landfill name, location, start

- up date, quantity of LFG used, and the length

of pipeline used to pipe the LFG from the landfill to the boiler location (i.e. p roject site)

. This data was sufficient to

for m the basis for an order

- of

- magnitude estimate of the total capital costs, depreciated capital costs (that would be

abandoned upon switching to natural gas), annual O&M costs for the LFG

- to

- boiler fuel projects and lost royalty

payments

. Additional tabs were added to the LMOP database Excel file to aid in conducting the evaluation.

A “Base Project” capital cost estimate was prepared and used as the basis to extrapolate the capital costs for

compressing, chillin g

, and transporting LFG to the receiving boiler for each of the projects in the LMOP database. The

Base Project construction cost is based on previous CH2M HILL projects for LFG compressor system s at landfill s and

the pipeline s between the landfill s and th e gas use site. O&M costs for the base project were similarly estimated

based on previous projects. The O&M costs for the LMOP sites were calculated based on the LFG flow which was

used to compute compressor power requirements. Labor and materials O&M co st s were assumed based on previous

project experience

.

Once the costs for each system were extrapolated from the base project, additional project costs (engineering,

administrative, etc) were added based on a percent age (Table 2) of the subtotal capital costs to estimate the grand

total based on 2011 dollars

.

The grand total cost calculated for 2011 was then used to estimate the current year cost for construction of the

compressor, chiller, and pipeline reflective of the startup date presented for each p roject in the database. This was

done by multiplying the grand total base project cost by the ratio between the historic (i.e. date of startup) and

current ENR (Engineering New Record) City CCI values. This value was then depreciated to 2011 using the stra ightline

method and an assumed project life of 20 years to estimate the a bandoned v alue of the LFG system and pi peline that

would occur upon switching to natural gas

.

The loss in royalty payments was calculated based on the amount of BTUs that would no lo nger be utilized by the end

user over the remaining life of the LFG system and pipeline , multiplied by a factor that approximates typical royalty

payments to landfill owners for landfill gas

- to

- energy projects

. The total cost reported in Table 1 is the ne t present

value of payments projected over the remaining life of the project if fuel

- switching had not occurred.

The cost for utilizing natural gas instead of landfill gas was calculated by subtracting the displaced cost of operating

and maintaining the landfill gas processing and transport system from the cost for purchasing natural gas. The total

natural gas cost t hat would be paid in lieu of the landfill gas was then calculated based on Net Present Value (NPV)

using the remaining life of the system ass uming a 20 year project life and a real interest rate of 7 % , which is assumed

to approximate the private sector cost of capital

. Although many of the landfills are publicly owned, almost all of the

boiler operations using the gas are privately owned and wo uld bear the cost of switching to natural gas.



## Assumptions

The following assumptions were made in conducting this economic evaluation.BOILER MACT ECONOMIC IMPACT EVALUATION

3

TUESDAY, NOVEMBER 08 , 2011 1) The capital cost for the base project compressor and chiller system w as estimated at $6 75 ,000 for a 750 cfm

compressor system. The costs for systems that had flows less than or greater than this range were

extrapolated from the base project using an extrapolation exponent of 0.75. The ratio of a given project

capacity to the base project capacity is raised to the exponent and the result multiplied by the base project

cost to estimate the given project cost. 1

2) The capital costs for the base project pipeline were estimated at $2/in diameter

- ft of pipeline for flows less

than 2 000 cfm and $6/in diameter

- ft of pi peline for flows greater than 2 000 cfm. Therefore, the installation

, including labor and materials

, of a 4 inch pipeline at 1000 cfm would be $8/ pipeline ft or approximately

$42,000 per mile plus other additional costs as described below

.

3) If pipel ine info rmation was not listed for a project on the LMOP database, the median pipeline length (3.30

miles) obtained from the boiler project tab was used. Just over half of the boiler site projects did not include

pipeline length information. It is noted no pipeline information was provided on the Boiler

- Steam Turbine

Tab.

4) Project capital costs in addition to construction were added to the capital costs based on a percentage of the

subtotal (compresso r and pipeline) costs ( Table 2 ).

TABLE 2.

Additional Costs added to Capital Cost for Compressor System and Pipeline (Subtotal)

Item Percent Addition to Cost

Road Crossing (s) 10%

Engineering 10%

Permitting 3%

Administration and Legal 5%

Construction Management 8%

Mobilization/Demobilization 12%

5) The cost of natural gas was assumed to be the latest available average U.S. retail natural gas price for

industrial users of $5.40 per MMBTU, as published by the U.S. Energy Information Agency.

( http://38.96.246.204/totalenergy/data/annual/showtext.cfm?t=ptb0608 )

6) The price per kilowatt

- hour for Operation and Maintenance (O&M) of the LFG system was assumed to be the

latest available average U.S. retail electricity price for industrial users of $0.0679 /kw

- hr , as published by the

U.S. Energy Information Agency

. ( http://38.96.246.204/totalenergy/data/annual/showtext.cfm?t=ptb0810 )

7) The pipeline costs for transporting natural gas from a high pressure supply pipe line to the project site were

considered minor (i.e. a trivial distance between the project site and supply pipeline) ; therefore, they were

not estimated or considered in this evaluation.

8) Regional costs for capital investments including labor were not considered as part of the evaluation. It was

assumed that the costs for varied capital and labor costs across the United States, which is covered by the

LMOP program, would average out. Royalt y payments were estimated at $0.75/MM BTU.

9) The life cycle of the LFG project was assumed to be 20 years.

1 Whitesides, Process Equipment Cost Estimating by Ratio and Proportion

( http://www.pdhonline.org/courses/g127/g127content.pdf)BOILER MACT ECONOMIC IMPACT EVALUATION

TUESDAY, NOVEMBER 08 , 2011 4 10) The 20 City Construction Cost Index (CCI), which is calculated annually by The Engineering News Record

(ENR), was used to calculate the capital costs of the landfill gas compressor and chiller based on the startup

date from the estimated 2011 dollars (Grand Total) derived from the base project. The CCI values used in this

estimation were an average of the 20 cities listed in the CCI.

11) The energy content of natural gas was assumed to be approximately 1000 B TU/ft 3

.

12) The methane content of LFG was assumed to be 50%; therefore, the energy cont ent was assumed to be 500

BTU/ft 3

.

13) T he Net Present Value (NPV) was estimated based on an inflation rate of 3% and a nom inal discount rate of

10 %. Therefore, the ‘real discount rate’ is 7 %.

14) For projects older than twenty years, it is assumed there is no economic impact to fuel

- switching. Projects at

the end of their useful project lives are assumed to be replaced or abandoned in the near future

.

# Copyrighted page(s) removed. Copyrighted

material is not available in Regulations.gov since

it may not be reproduced without consent of the

copyright holder.

Removed pages can be viewed at the USEPA

Docket Center, Public Reading Room.

Address: 1301 Constitution Ave, NW

Room 3334

Washington, DC 20004

Telephone: 202-566-1744

Email: docket-customerservice@epa.gov

### Definition of resinated wood and resinated trim :

Resinated wood means wood products (containing resin binders and adhesives)

derived from produced by primary and secondary wood products manufacturing

.

Resinated wood includes residues from the manufacture and use of resinated wood,

including materials and comprised of such items as board trim, sander dust, and panel

trim , and off

- specification resinated wood products.

Suggested changes to March 2011 NHSM definitions.

 Clarifies the spectrum of resinated materials currently used as fuels throughout

the wood product manufacturing process

 Includes definition of resinated wood trim to include broad class of materials

produced at wood product mills.

# E cono mi c Im pact of P e nd i ng A i r R e gu l a t i ons on

t he U .S

. P u l p and P aper I ndus t r y

- U pda t e d

P r e p a r e d b y Fi s h e r In t e rn a t ion a l, I n c

.

September 201 1

### 2

In t rodu c t ion

T h is re po r t is a n up d a t e d v e r si o n o f a re po r t o f si m il a r n a m e r e l e a s e d in Au g u st 20 1 0. It

describes the potential impact of a series of rules issued by the Environmental Protection

Agency (EPA) i n March 2011 establishing Maximum Achievable Control Technology for

industrial boilers, commonly referred to as the Boiler and Incinerator MACT rule s 1



### . Several other unrelated air regulations also are pending. They include but are not limited

to the Cluster MACT reopening, Pulp and Paper Residual Risk, and several National

Ambient Air Quality Standard (NAAQS) revisions that directly or indirectly dr ive more

stringent standards

.



### T h is u pd a te u s e s t h e s a m e a ss u m p ti on s a s t h e o r i g i na l r e p o r t w ith t h e f o ll o w i ng

e x c ep ti on s:

 

### Pu lp a n d p a pe r m ill assets and c o sts

- o f

- p r odu c ti o n w e r e t a k e n f ro m

Fis he r S o lv

e TM 

### ’s Q 1_ 2 01 1 r e l ea s e ;

 

### Capital and operating costs of compliance to regulations were updated by the

consulting firm URS based on the latest available information.

T h e A m e r ic a n F o r e st & P a pe r A ss o ci a ti on ( A F &PA ) en g a g e d URS to up d a te e st i m a t e s o f

t h e lik e ly c o sts o f c o m p l y i n g w ith t he se pe n d i n g r e g u l a ti o n c h a n g e s an d Fis he r

I n t e rn a ti o n a l I n c. to a ss e ss t h e i m pa ct o f t he s e c o m p li a n ce c o sts o n t h e e c o n o m ic v i ab ility

o f U. S

. pu l p a n d pa p e r m i lls.

T h e URS f i n d i n g s a r e p r e s en t e d i n d e t a il in a r epo r t entitled, “ C u m u l a ti v e C o st Bu rd e n

A na l y sis o f A ir R e g u l a ti o n s P o t e n ti a lly I m pa ct i n g t h e F o r e st P ro du cts I n d u st r y ,” da t e d

August 20 1 1

. A r e g u l a ti on

- s pe ci f ic s u m m a r y o f t h e URS c o st e sti m a t e s a p p e a r s in

Ap p e n d ix A o f t h is r epo r t and i n d ic a t es w h ich r u l e s w e r e i n cl ud e d in t h is a ss e s s m e n t a nd

w h ich w e r e no t.

In s um m a r y

, t h is up d a t e s ho w s potentially s e v e r e i m pa cts o n t h e pu lp an d p a per i ndu st r y

f ro m EP A r e g u l a ti on s a ff e cti n g i n d u s t r y bo il e r s ( e

. g

. Bo il e r M A CT a n d C I S W I) an d o t h e r

u p c o m i n g Cl ea n A ir r u l e s f o r w h ich t h e c o sts c ou ld b e e sti m a t e d

, a s f o ll o w s:

 

### The Bo il e r MACT r u l e s

, a f t e r accounting for the impact on jobs of proposed

g ene r a l pu lp a n d p a p e r m a n u f a ct u r i n g Clean Air r e g u l a ti on s , put at serious risk an

incremental :

o 20

, 541 j ob s in p u lp a n d p a p e r m ills a l o n e

o 8 7

, 299 j ob s c o n si de r i n g bo th j o b l o s s e s in pu lp an d p a pe r m ills a n d j o b s

l o st a l on g t h e ir s upp ly c ha in a n d in t h e s u rr ound i n g c om m u n i ty

. 2

1 On March 21, EPA published the Boiler MACT rule and three related rules

-- the Commercial and Industrial

Solid Waste Incinerator (CISWI) rule (setting emissions limits for non

- hazardous solid waste incinerators);

the definition of Non

- Hazardous Secondary Materials (a Resource Conservation Recovery Act rule

determining which materials are wastes and thus covered under the CISWI rule when burned); and Boiler

GACT (Generally Achievable Control Technology for boilers at smaller sites). These four rules often are collectively referred to as the “Boiler MACT rules.”

2 Note t h at t he s e e s t i m ates do n ot i n c l u de j ob l o ss es i n the wood p r o d u c ts m anu f a c tu r i ng s e c tor of the

f o r e s t p r odu c ts i n du s t r y f r o m an e s t i m ated $2 b i l l i on i n ne w M A CT c o s t s.

### 3

 

### The Bo il e r MACT r u l e s and o t he r up c o m i n g Cl e a n A ir reg u l a ti on s put at serious

risk a total of :

o 3 8

, 06 0 j o b s in pu lp an d p a pe r m a nu f a c t u r i n g a l o n e

o 16 1

, 755 j ob s c on si de r i n g b o th t h e l o s s e s in pu lp a n d pa p er m ills an d t h e

j ob s l o st a l on g t h e s u p p ly c ha in an d i n t h e s u rr o u nd i ng c o m m u n it y

. 3



### M e t hodolo g y

Fis he r I n t e r na ti o na l w a s a sk e d to qu an t i f y t h e lik e ly i m pa ct o f ne w a ir po ll u ti o n c on t r o l

r e g u l a ti o n s o n e m p l o y m en t i n U. S

. p u lp a n d p a pe r m ills b y e sti m a ti n g h o w m any m ills

w ou ld b e in j eo par d y o f cl o si n g i f t he y h a d to c o m p ly with t h e r e l e v an t ne w a ir r e g u l a ti on s.

T o m a ke t h e e s ti m a t e

, w e u s e d t w o m a j o r re s ou r c e s : Fis he r So lv e TM, a p r op r i e t a r y

i ndu st r y da t aba s e de sc r i b i n g t h e a ss e ts a n d c o sts

- o f

- p ro du cti o n o f ea c h m ill, an d

de sc r i p ti o n s p r o v i de d b y URS o f h o w d iff e r en t t y pe s o f m ills w ou ld n ee d to r e s p o nd to

e a ch po t en ti a l ne w r e g u l a ti o n an d t h e c o s t s o f t ha t c o m p li an c e

.

W e p r o j e ct e d t h e c o sts o f c o m p li a n ce f o r e a c h m ill a n d c a lc u l a t e d t h e m a s a pe r c e n t a g e

o f c o sts o f p r o d u cti o n

. W he n c o m p li a n ce w o u ld i n c r ea se a m ill’s c o s t

- o f

- p r odu c ti o n by

m o r e t h a n a s u st a i nab l e a m o u n t, w e list e d t h a t m ill an d its a ss o c i a t e d e m p l o y m en t as

be i n g “ a t

- r isk.” N o t e t h a t t h e c o sts p r o j e c t e d in t h is r epo r t f o r e a ch m ill’s c o m p li a n ce d o

no t i n cl ud e t h e c o sts a ss o ci a t e d w ith a n u m be r o f reg u l a ti on s f o r w h ich URS w a s unab le

to qu an t i f y a m ill

- s pe c i f ic c o m p li an c e i m pa c t

. 4 

### Moreover, t he r e is a n o t h er s e t o f

r e g u l a ti on s t h a t t r i g g e r a c o st t o a m ill o n ly w he n t h e m ill m a k e s a p h y sic a l c han g e in t h e

f u t u r e

, s u ch a s r ebu il d i n g a bo i l e r

. A s w e d o no t k no w w h ich m ills m ay m a ke c h a n g e s in

t h e f u t u r e

, t he s e i m pa cts a l so a r e no t i n cl u d e d in t h is a n a l y sis. For this reason, t he

ana l y sis m a y unde r st a t e t h e i m pa c t o f r e g u l a t i on s o n m ill c o sts and jobs

.

W e a ss u m e d t h a t t h e “ s u st a i n ab le a m ou n t” o f i n c r e m en t a l c o st a g iv e n m ill can ab s o r b is

e q ua l to t h e a m o u n t o f c a s h t ha t t h e a v e r a g e m ill p ro du c e s f o r its o w ner a f t e r v a r i ab le

c o s ts an d c ap i t a l e x pe n d it u r e s. In o t he r w o r d s, w he n a m ill g e ts t o a c a sh b r ea k

- e v e n

l e v e l, it be c o m e s a s e r i ou s r isk f o r cl o s u r e

. It w ou ld b e f a ir t o a rg ue t ha t this is a

conservative assumption because m a n y o w ne r s w ou l d p re f e r to s hu t t e r a m i ll w e l l b e f o r e it

r ea c h e d a c a s h c o st b r ea k e v e n l e v e l t o r ed e p l o y m a n a g e m en t t i m e a n d m a i n t e nan c e

c ap it a l t o o t he r

, m o r e p ro f it a b le f a ciliti e s. T h e a v e r a g e s u s t a i nab le a m o u n t o f c o s t

i n c r ea se f o r t he i ndu st r y ba s e d o n t h is ana l y sis is 12

. 5 % o f c o st o f p r odu c ti on

. ( Se e be l o w

f o r a m o r e de t a il e d e x p l a n a ti o n o f ho w t h is f i g u r e w a s d er i v ed .)

3 Note the s e e s t i m ates do n ot i n c l u d e j ob l o ss es i n t h e wood p r o d u c ts m anu f a c tu r i ng s e c tor of the f o r e s t

p r odu c ts i ndu s t r y

.

4 Roughly $2 billion in new capital costs for pulp and paper mills meeting various National Ambient Air Quality

Standards (NAAQS)

, changes to the New Source Review (NSR) requirements

, New Source Performance

Standards (NSPS)

, and the Clean Air Interstate Rule (CAIR) were not factored into the mill closure/job loss

calculations because they could not be allocated to specific mills.

### 4

F o r m o st r e g u l a ti on s

, c o m p li a n ce r e q u i r e s bo t h c ap i t a l a n d o pe ra ti n g c o sts. W e t r an sl a t e d

c a p it a l c o sts i n to ope ra ti n g c o sts b y u si n g a n i n t e r e st r a te o f 1 1 %, r ep r e s e n ti n g t h e

i ndu st r y’s w e i g h t e d a v e r a g e c o st o f c ap i t a l ( W A CC )

, a n d a t e r m o f f i v e y ea r s. W e b a s e d

t h e W A CC o n a s u r v e y o f i n v e st m e n t b an k e r s a n d i n d u st r y ana l y sts. T h e f i v e

- y ea r t e r m

w a s a rr i v e d a t b y no ti n g t h a t :

 

### t h e i n du st r y ’s c ap it a l s t r u ct u r e is a pp r o x i m a t e ly 50 % de b t a n d 50 % eq u it y

,

 

### t h e a v e r a g e i ndu st r y t er m o f d e b t is a bo u t t e n y ea r s, and

 

### f und i n g w ith e q u ity is e q u i v a l en t to a t e r m o f “ z e r o ” y ea r s ( be c au s e s ha r e s a r e

d il u t e d i m m ed i a t e l y w he n a c o m p an y r a is e s c a sh b y s e lli n g e q u it y )

.

T h e re f o re

, t h e a v e r a g e pa y ba ck t e r m w e u s e d to c a lc u l a t e t h e c o s t o f f u nd i ng c o m p li a n ce

is f i v e y ea r s (( 1 0 y ea r s + 0 y ea r s) d i v i de d b y 2 = 5 y ea r s )

.

T h e t a b le be l o w s u mm a r i z e s ho w w e a rr i v e d a t t h e f i n an ci a l “a t

- r isk” r a te o f s p end i n g on

c o m p li a n ce t h a t w ou ld pu t a m ill in j eo p a r d y o f c l o si n g

. I d ea ll y

, w e w ou ld ha v e c o m p a r e d

t h e c o st i m p a ct o f c o m p li an c e t o m i ll m a rg i n s. H o w e v e r

, s i n ce w e d id n ot ha v e da t a o n

e a ch m ill’s p ro f it m a rg i n

, w e a s s u m e d a n i n du st r y a v e r a g e m a rg i n

, a d d ed a n i n du st r y

a v e r a g e f a ct o r f o r c a s h s p en t o n c ap it a l an d a p p li e d t h e m t o c o st

- o f

- p r odu ct i o n da t a t h a t

w e d o ha v e

. T h is a ll o w e d u s t o c r e a te a n i n du s t r y a v e r a g e “ a t

- r isk” r a te t h a t w e c ou l d

c om pa r e t o t h e c o s ts o f c o m p li an c e

. 5



### W e e sti m a t e d t h e i n d u st r y a v e r a g e “ a t

- r isk” r a te u si n g da t a d r a w n f r o m t h e f i n a n ci al

st a t e m e n ts o f a gr o u p o f p ub lic U. S

. pu lp a n d pa p e r c o m p a n i e s. W e f o u n d t h e i ndu st r y ’s

a v e r a g e gr o ss m a rg in o v e r a 10

- y ea r pe r i o d

, w h ich is r e v enu e l e ss t h e c o s t o f g oods s o ld

(m a i n ly m a t e r i a ls an d l abo r ) a s a p e r c e n t a g e o f r e v e n ue

. W e t h e n d edu c t ed a v e r a g e

c ap it a l e x pe n d it u r e s p e r do ll a r o f s a l e s a n d a n a v e r a g e c o s t

- o f

- s a l e s ( s u ch a s b r o k e r

c om m issi on s a n d e a r ly pa y m en t d is c oun ts ).

I t e m Pe r c e nt

10

- y ea r a v e r a g e i ndu s t r y gr o ss m a rg in 19

. 7%

Le ss 1 0

- y ea r a v e r a g e c ap it a l e x pend it u r e s p e r $ o f s a l es 7

. 6%

Le ss f a ct o r f o r c o st o f s a l es 2

. 0%

E q ua ls a t

- r isk r a te a s p e r c en t o f s a l es 10

. 1%

A t

- r isk r a te a s pe r c e n t o f c o s t

- o f

- p r o d u cti o n 12

. 5%

5 While the method olo gy is the same, t h is de sc r i p ti o n is d i f f e re n t f ro m t h e on e s u p p li e d in t h e o r i g i na l r epo r t

in a n a t t e m p t to cl a r i f y t h e m e t ho d o l o g y u s ed

.

### 5

These c a lc u l a ti o n s r e s u lt e d i n a n a v e r a g e “ a t

- r isk” r a te ( t h e m a x i m u m a m o un t o f c a sh

c o st i n c r ea s e t h e t y p i c a l m ill c ou l d a b s o r b ) o f 10

. 1 % o f s a l e s

. Gi v e n t h e i ndu s t r y ’s

a v e r a g e m a rg i n s, t h is i s e q u i v a l en t to 12

. 5 % o f c a s h c o st

- o f

- p r o d u c t i on

. H e n c e

, i f a ir

r e g u l a ti on

- r e l a t e d i n c re m e n t a l o pe r a t i n g c o sts an d a n nua li z e d c o s ts a ss o ci a t e d w ith

c ap it a l e x pend it u r e s to c o m p ly w ith t h e r e g u l a ti on s a m o un t to m o r e t ha n 12

. 5 % o f a m ill’s

c a sh c o s ts, t h e m ill is cl a ssi f i e d a s a t r isk o f cl o si n g

.



### The i n c re a se in c o sts o f c o m p li a n ce w ith n e w a ir r e g u l a ti on s w i ll a ff e ct m ills in d i ff e r ent

w a y s. In s o m e c a s e s, m ills w i l l s u ff e r i n c r ea s e s in c o s ts gr ea t e r t h a n t h e ir d o m e stic

c o m p e tit o r s, t h u s l o si n g c o m p e titi v ene ss in t h e ir h o m e m a r k e ts a n d be c o m i n g r isks f or

cl o s u r e

. I n o t he r c a s e s

, e v e n i f a ll m ills in a p r odu ct c a t e g o r y e x pe r i e n ce si m il a r c o st

i n c r ea s e s, m a n y U. S

. m ills be c o m e “ a t

- r isk” f o r cl o s u r e b e c a u se i n t e r na ti o nal c o m p e tit o r s

g a in a c o s t ad v an t a g e and prevent prices from rising

.

A s o f t h is d a t e

, t h e r e s t ill is s o m e un c e r t a i n ty a r ou n d h o w c e r t a in r u l e s w ill b e w r itt en.

T h e re f o re

, t h is r epo r t c on t a i n s t h e r e s u lts o f t w o sc ena r i o s, e a ch re p r e s en t i n g one

po ssi b le ou t c o m e

. T h e r e s u lts f o r S c e nar io 1 a r e p r e s en t e d in t h is re po r t. The results for

Scenario 2 are summarized at the end. T h e t w o sc ena r i o s a r e:

 

### S c ena r io 1

– many types of b i o m a ss t ha t is bu r n e d are t re a t e d a s solid w a ste

, an d

t h e re f o r e, a r e s ub j e ct to the So lid W a s t e I n c i n e r a t o r r u l e s instead of the Industrial

Boiler MACT rule

.

 

### S c ena r io 2

- many types of b i o m a ss t ha t is bu r n e d are t re a t e d a s f ue l

, a n d

t he re f o r e

, a r e s ub j e c t to the I n d u st r i a l Bo il e r MACT r u l e and not the Solid Waste

Incinerator rule

.

Scenario 1 R es ul t s

Ana l y sis o f m ill

- s pe c i f i c i n c r ea s e s i n a nn u a liz e d a ir r e g u l a ti o n c o m p l i an ce c o sts s u gg e st

t ha t the Bo il e r M A C T r e g u l a ti on s, i f t h e y a r e i n c re m e n t a l t o t h e p e n d i n g m a nu f a c t u r i n g

r e l a t e d a ir r e g u l a ti on s, c ou ld r e s u lt in t h e c l o s u r e o f 3 6 m ills e m p l o y i n g 20,541 pe o p le or

18 % o f t h e p r i m a r y pu lp a n d p ape r s e ct o r ’s w o r kf o r c e

. ( T h e p r i m a r y pu lp an d p a per s e ct o r

e n c o m pa s s e s o n ly pu lp a n d p ape r m ill j ob s; the r isk to l o gg i n g j ob s a n d c o n v e r ti ng

ope r a t i on s a r e n o t i n c l ud e d in t he se f i g u r e s.)

T h e c a lc u l a ti on s s u gg e st t h a t 7 9 p u lp a n d pa p e r m ills w ou ld b e a t si g n i f i c an t r isk o f

cl o si n g if the larger suite of ne w air r e g u l a ti on s for which we have data w e r e

i m p l em en t e d

. T he se m ills em p l o y 3 8

, 06 0 p e o p l e

, o r 33 % o f t h e p r i m a r y pu lp an d p a pe r

s e c t o r ’s w o r k f o r c e

. T h e f o ll o wi n g t ab le s h o w s po t e n ti a l m ill s hu t do w n s an d j o b l o s s e s:

### 6 M ills a t S igni f i ca nt R i s k of Clo s ure

In c r e m e n ta l f rom A d ding

Boil e r M A CT P &P Mf g R e gs On l y To t a l of Boil e r M A CT

a nd P &P Mf g R e gul a t ions

J obs A t Ri sk # of M ills J obs A t

Ri s k # of M ills J obs A t

Ri s k # of M ills

20,541 3 6 17

, 5 19 43 3 8,060 7 9

B ase 113

, 858 349

Pe r c e nt c h a nge 33% 2 3 %

Ripple E ff ect

Pu lp a n d p a pe r m ill j o b s s up p o r t j ob s in o t he r i ndu st r i e s t ha t s u p p ly t h e p u lp a n d p a per

i ndu st r y in l o c a l c omm un iti e s an d t h ro u g hou t t h e U n i t e d S t a t e s. A s c ho l a r ly paper

p r epa re d b y t h e E c o n o m ic Po licy I n stit u te

- - “ U pda t e d E m p l o y m en t M u lti p li e r s f o r t h e US

E c o n o m y

, 2 003 ”

- - w a s p r o v i de d to Fis he r b y A F &PA

. T ab le 9 o f t h e pa p e r i nd ic a t es t ha t

f o r e v e r y 10 0 j ob s in t h e p a pe r i n du st r y

, t he r e a r e a n a d d iti o n a l 32 5 j ob s s u s t a i n ed in

o t h e r i n d u st r i e s d u e to t h e p u r c ha s e o f s u p p li e s a n d t h e r e

- s p end i n g o f w o r k er i n c o m e s.

H e n c e

, t h e p u lp a n d p a p e r i ndu s t r y ’ s m u lti p li e r is 4

. 2 5

.

App l y i n g t h e 4

. 2 5 m u lt i p li e r in t h e p r e v i ou s t a b le s u gg e sts t h a t 8 7

, 299 j ob s c a n be l o st b y

i m po s i n g Bo il e r M A CT r e g u l a ti o n s o n t o p o f t h e p ro po s e d n e w pu lp an d p a per

m a nu f a c t u r i n g

- r e l a t e d a ir r e g u l a ti on s ( 20,541 X 4

. 2 5 = 8 7

, 299 ) . A t o t a l o f 161,755 j ob s

–

i n si d e an d ou tsi d e t h e pu lp a n d p ape r i ndu s t r y

- - c o u ld b e l o st a s a r e s u lt o f t h e e n ti r e

s u i t e o f p r o p o s e d a ir r e g u l a ti on s (3 8

, 06 0 X 4

. 2 5 = 1 61,755 ).

M ill & Communi t y J o bs a t Ri s k a t 4

. 2 5 M ul t ipli e r

In c r e m e n ta l f rom A d ding

Boil e r P &P Mf g On l y T o t a l of Boil e r M A CT a nd P & P

Mf g R e gul a t ions

Sce n a r io 87,299 74

, 4 56 161,755

Fis he r I n t e r na ti o na l a lso c a lc u l a t e d pu lp a n d pa p e r j ob s l o s s e s a s s o ci a t e d w ith t h e

p r opo s e d r e g u l a t i on s b y r eg i on

. R e g i ona l f i gur e s d o no t i n cl u d e t h e m u lti p li e r e ff e ct s

.

### 7 J ob lo s s e s f or R e gi o ns ( No M ul t ipli e r)

In c r e m e n t a l A t Ri sk

J obs f rom A dding

Boil e r R e gul a t ions A t Ri s k J obs f or P &P

Mf g. R e gul a t ions

On l y A t Ri s k J obs f or Boil e r

a nd P &P Mf g

R e gul a t ions

US

-

Nor t h east 2

, 1 7 7 2

, 8 7 7 5

, 0 5 4

US

-

M i d w e s t 5

, 5 0 5 3

, 8 7 8 9

, 3 8 3

US

- S ou t h eas t 11

, 92 4 7

, 5 2 9 19,453

US

- W est 935 3

, 2 3 5 4

, 1 7 0

T o t a l US 20,541 17

, 5 19 38,060

Scenario 2 Results

Under Scenario 2, many types of b i o m a ss t ha t are bu r n e d are t re a t e d a s f ue l, a n d

t he re f o r e

, m o st p l a n ts a r e s ub j e c t to the I n d u st r i a l Bo il e r MACT r u l e and not the Solid

Waste Incinerator rule.

The calculations for this scenario suggest that the Bo il e r M A C T r e g u l a ti on s, i f t h e y a r e

i n c re m e n t a l t o t h e p e n d i n g m a nu f a c t u r i n g

- r e l a t e d a ir r e g u l a ti on s, c ou ld r e s u lt in t h e

c l o s u r e o f 3 5 m ills e m p l o y i n g 19,921 pe o p le, or 17.5 % o f t h e p r i m a r y pu lp a n d p ape r

s e ct o r ’s w o r kf o r c e

. If jobs in supplier industries and local communities are factored in, the

number of jobs in jeopardy rise s to 84,664. The impact of the pending manufacturing

related air regulations on employment and mill closings is the same as under Scenario 1.

Comparison of Findings: This Report vs. August 2010 Report

In August 2010, Fisher prepared a study on EPA’s propos ed Boiler MACT regulations and

other pending air regulation s

. The August 2010 study found that 43,666 pulp and paper

mill jobs would be placed at risk due to a broad suite of pending air regulations.

Of the 43,666 at

- risk paper industry jobs identified i n the 2010 study, 26,778 were

associated with the “other” pending air regulations and 16,888 with Boiler MACT

- related

compliance spending that is incremental to spending on the other air rules.

This new study examin ing the final Boiler MACT rules found that 38,060 paper industry

jobs would be placed at risk due to the entire suite of air regulations. Among those

### 8

38,060 jobs, 20,541 job losses could result from the final Boiler MACT/CISWI

- related

costs that are incremen tal to spending needed to comply with the other air regulations,

and 17,519 jobs are placed at risk by the costs of non

- Boiler MACT air regulations.

The decline in the number of jobs placed in jeopardy by non

- Boiler MACT air regulations

between the origi nal and updated study reflects several factors:

 Between the first and second studies, the number of mills operating in the U.S.

declined by 7, and the employee base declined by 5,302 jobs. Of the 5,302 fewer

jobs, 2,600 were lost due to mill closures after the completion of the first report, and

the remainder reflected headcount reductions at mills that remained operational.

 A verage cost

- of

- production increased between the two study periods. Because we

measured compliance costs as a percentage of cash cost s, higher cash costs

appeared to raise the threshold for compliance costs that would put mills at risk. In

actuality

, higher costs might put more U.S. mills at risk rather than fewer because

foreign mills gain a cost advantage vis

- a

- vis U.S.mills.

The in crease in the number of jobs put at risk by Boiler MACT rules reflects the underlying

fact that the regulations as a whole still threaten a significant number of mills and jobs:

 While fewer mills were placed in jeopardy of closing by the “other” air rules, the total

number of jobs at risk declined by a smaller number. The Boiler MACT/Incinerator

MACT rules , therefore, account for a larger incremental impact.

 In the 2010 study, capital s pending was estimated by URS at $5 billion for the

proposed Boiler MACT/CISWI rules and $13.7 billion for the larger suite of pending

air rules, including the Boiler MACT/CISWI rules. However, not all of the costs

could be allocated to specific mills, so capital spending

- related compliance costs

used by Fisher came to $4.6 billion for Boiler MACT and $10.3 billion for the entire

suite of air regulations.

 Capital spending for the 2011 study was estimated by URS at $4 billion for the final

Boiler MACT/CISWI and $12.6 billion for all of the pending air rules, including Boiler

MACT/CISWI. However, not all of the costs could be allocated to specific mills, so

capital spending

- related compliance costs used by Fisher came to about $3.8 billion

for Boiler MACT/CI SWI and $10.1 billion for the entire suite of air regulations.

 The Boiler Rules changed betw een proposal and promulgation. In particular, more

fuels were classified as solid wastes and therefore, many plants are subject to the

CISWI rule instead of the Boiler MACT rule. In addition, costs were added for NOx

emissions reduction requirements to mills in close proximity to projec ted non

attainment areas

.

### 9

In sum, this study, like the preceding study, shows that the EPA’s Boiler MACT r ules would

have a major impact on the economic viability of many pulp and paper mills and place at risk

tens of thousands of pulp and paper mill jo bs as well as jobs in surrounding communities and

supplier industries.

### 10 

## A pp e nd ix A

UR S Est i mates o f P u l p a n d Pa p e r M i ll s Co sts o f Co m p l y i n g W i th

P r opo sed A i r R e gu l at i on s:

How Co s t

s W e re D e t e rmin e d:

URS C o r po r a ti o n ( UR S ) w o r k e d w ith t h e A m e r ic a n F o r e st a n d P a p e r A ss o ci a ti o n

( A F &PA ) a n d its m e m b e r s to d e v e l o p a r ou g h o r de r o f m a g n it u d e e st i m a t e o f t h e c o sts

o f c o m p l y i n g with v a r i o u s a ir r e g u l a ti on s t h a t c ou ld i m pa c t t h e f o r e st p r odu c ts i n d u st r y

. T h e c o st e st i m a t e s w e r e c o m p il e d in a M ic ro s o f t E x c e l w o r k boo k; w e r e ba s e d on

pub lis h e d i n f o rm a ti o n o r si m il a r p r o j e ct c o sts; ha v e b e e n r e v i e w e d b y m e m b e r c o m p a ny

r ep r e s e n t a ti v e s; a n d h a v e bee n m a d e a v a il ab le to t h e US E P A an d o t h e r s f o r r e v i e w

. T h e B o il e r M A CT an d CI S W I e sti m a t e d c o s ts a r e in l a rg e p a r t b a s e d o n i n f o r m a ti o n in

EPA ’s M a r ch 20 1 1 s u r

v e y an d e m issi on s d a t aba s e s.

C ap it a l a n d ope ra ti n g c o sts e st i m a t e s a r e n o t i n t e nd e d t o r ep r e s en t a w o r st c a se

ana l y sis. R a t he r

, t h e y r ep r e s e n t m ed i a n c o st s f o r t h e v a r i ou s sc e nar i o s ba s e d o n

pub lis h e d re po r ts, i n d u st r y i n f o rm a ti o n o n s p e ci f ic p r o j e ct c o s ts, E P A r epo r ts o r c on t r ol

de v ice f a ct s he e ts, o r a ct ua l Best Achievable Control Technology (BACT) o r Best

Achievable Retrofit Technology (BART) ana l y s e s s u b m it t e d t o pe r m itt i n g a g en ci e s. A

p r i m a r y r e s ou r ce w a s t h e do c u m en t entitled, “ E v a l u a ti o n o f A ir P o ll u ti o n C on t r o l C o sts

f o r t he Pu lp a n d Pa p e r I n du st r y ,” p r epa r e d b y N a ti on a l E c o no m ic R e s ea r ch A ss o ci a t e s

( N E R A ) in M a y 2003

. A ll c o sts w e r e d isc u ss e d w ith a c o r e t ea m o f A F & P A m e m b e r s

a n d r e v i e w e d b y URS en g i nee r s f a m ili a r w ith bo i l e r an d o t he r p u lp a n d pa p e r m ill

o p e r a ti o ns an d c on t r o ls p r i o r to f i n a li z i n g t h e st u d y

.

Boil e r M A CT Co s t s :

T h e B o il e r M A CT w ill r e q u i r e e m issi o n s c o n t r o ls f o r p a r tic u l a te m a t t e r

, h y d r o g en

c h l o r i de

, m e r c u r y

, c a rb o n m o n o x i de

, a n d d i o x i n / f u r a n

. T h e c o n t r o l t e c h n o l o g i e s t h a t

EP A h a s i d en t i f i e d a s ne c e s s a r y to c o m p ly with t h e Bo il e r M A C T a r e a f ab r ic f ilt e r f o r

c on t r o l o f p a r tic u l a te m a tt e r

, c a r b o n i n j e cti o n f o r c on t r o l o f m e r c u r y a n d d i o x i n / f u r an

, a

sc r ubbe r f o r c o n t r o l o f h y d r o g e n c h l o r i de

, a n d c o m bu sti o n i m p r o v e m en ts o r a n o x i da ti on

c a t a l y st f o r c o n t r o l o f c a r bo n m ono x i de

. In s om e c a s e s, t h e e m issi o n li m its w i ll b e v e r y

d if f ic u lt to a c h i e v e o v e r a ll ope r a t i n g c ond iti on s

, but t h e c o s t ana l y sis a ss u m e s t ha t f o r

e a ch bo il e r

, f a c iliti e s c a n a pp ly e m iss i on s c o n t r o ls t o a c h i e v e t h e Bo il e r M A C T li m its w ith

a c o m f o r t a b l e m a rg in o f c o m p li a n c e

. I n s o m e c a s e s, e x isti n g e q u i p m e nt c o n f i g u r a ti on s

m a y p r o v e i m po ssi b le to up gr ade

, an d bo il e r s an d p ro c e ss h e a t e r s m ay ne e d to b e

r ep l a c ed

, w h ich is a c o st t ha t is n o t re f l e ct e d in t h e a n a l y sis. N o te a lso t hat m an y

f a ciliti e s m a y c h oo se f ue l s w itc h i n g a s a c o m p li an c e o p ti o n ; h o w e v e r

, a s t h e c o st o f f u e l

s w itc h i n g is h i gh ly depe n de n t o n site s pe c i f ic f a c t o r s ( e

. g

., w he t h e r t h e b o il e r c an bu r n

t h e a lt e r n a te f ue l, w ha t up gr ade s m u s t b e m ad e to t h e f u e l s u p p ly s y st e m ) a n d t he p r ice

o f f ue l w ill c han g e o v e r ti m e d u e to f a ct o r s like s u p p ly an d de m a n d

, URS d id n ot a tt e m p t

to q uan t i f y c o s ts f o r f ue l s w itc h i n g

.

### 11

T h e E P A c o ll e c t e d i n f or m a ti o n d u r i n g Pha se 1 o f t h e Bo il e r M A C T i n f o rm a ti o n c o ll e cti o n

r e q ue st ( ICR) o n t hou s and s o f bo il e r s a n d p ro c e ss h e a t e r s a t h u n d re d s o f f a ciliti e s. A

de t a il e d s p re ad s h ee t w a s de v e l ope d t o e st i m a t e c o sts f o r B o il e r M A CT f o r i nd i v i dual

bo il e r s a n d p r o c e ss he a t e r s, b a s e d o n E P A ’s m a j o r s ou r ce bo il e r i n v en t o r y da t aba s e

t ab le an d t h e e m issi o n s da t a i n cl u d e d i n E PA ’s bo il e r M A CT da t a ba s e

. URS e x t r a ct ed

i n f o rm a ti o n f r o m E P A ’s m a j o r s ou r ce bo il e r i n v en t o r y da t aba s e i n cl u d i n g bo il e r ID, si z e,

f ue l c a t e g o r y

, e m issi o n s, a n d c u rr e n t a ir p o ll u t i o n c o n t r o l e q u i p m e n t. Ba s e d o n t h e

i n f o rm a ti o n i n E P A ’s d a t a b a se an d t h e b a s e l i n e e m issi o n f a c t o r s d e v e l ope d b y EP A b y

bo il e r t y p e a n d c on t r o l de v ic e

, URS de t e r m i n e d w he t he r ea c h u n it w ou ld r e q u i r e

add iti o na l a ir po ll u ti o n c on t r o ls t o m e e t t h e B o il e r M A CT li m it s

. N o t e t h a t w e d id not

pe r f o r m an y q ua lity a ss u r an ce o n t h e i n f o r m a ti o n in EPA ’s da t aba s e

, bu t w he r e w e had

k no w l ed g e t ha t a b o il e r ha d be e n m is

- c a t e gor i z e d ( e

. g

., a b i o m a ss bo il e r w a s list e d as a

li q u id bo il e r ) w e d id m a ke t h o se c han g e s i n ou r s p r ead s h e e t.

A s p r e a d s h e e t w a s d e v e l ope d t h a t re p r e s e n t s on ly t h e un its t o b e r e g u l a t e d b y t h e r u l e

( e x cl ude s na t u r a l g a s bo il e r s, p r o c e ss h ea t e r s, bo il e r s a n d p r o c e ss hea t e r s l e ss t ha n 10

MM B t u / h r h ea t i npu t

, a n d li m i t e d u se un its )

. Ba s e d o n t h e i n f o r m a ti o n in t h e EP A

e m issi on s d a t a b a s e

, we e st i m a t e d c o sts o f c o n t r o ls t h a t w ou ld lik e ly b e n e c e ss a r y to

c o m p ly w ith t h e B o il e r M A CT f o r c oa l, b i o m a s s, li q u i d

, an d G a s 2 b o i l e r s 1 0 MM B t u / h r

an d gr ea t e r ( no t e t ha t f o r t h e f i na l r u l e

, E P A m o v e d a ll g a s

- f i r e d bo i l e r s to t h e G a s 1

s ub c a t e g o r y un l e ss t h e y w e r e bu r n i n g an y a m o u n t o f c o k e o v e n ga s o r b l a st f u rn a ce

g a s )

. A s s o m e f o r e st p r odu cts bo il e r s a t m a j o r s ou r c e s d id n o t r e c e i v e a n ICR f r om EP A

in 2 0 08

, w e a dd e d i n f o r m a ti o n f o r t h o se bo il e r s to t h e d e t a il e d s p r ead s he e t b a s ed o n

i n f o rm a ti o n f r o m A F &PA /National Council for Air and Steam Improvement (NCASI).

T he r e a r e lik e ly o t he r un its t ha t ar e no t i n cl u d e d in t h e s t ud y

, a s o t h e r t r a d e gr oup s h a v e

s u b m it t e d c om m e n ts i nd i c a ti n g t ha t E P A h as lik e ly unde r e sti m a t e d t h e u n i v e r se o f

a ff e c t e d un its ( e

. g

., American Chemistry Council ( A CC) a n d American Petroleum

Institute ( A P I)/ National Petrochemical and Refiners Association (N P R A )

.

I n f o r m a ti o n f ro m v a r i ou s s ou r c e s w a s u s e d t o d e t e r m i n e a ba s e c a p it a l c o st f o r a 25 0

MM B t u / h r bo il e r f o r ea ch P M

, CO, a n d H Cl c on t r o l t e c h n o l o g y op ti o n an d t h en sc a l e d

u si n g a n 0 .6 p o w e r f un cti o n b a s e d o n t h e si z e o f ea c h bo il e r i n t h e i n v en t o r y . F o r

e x a m p l e

, t h e c a p i t a l c o st o f a w e t sc r ub b e r o n a 1 0 0 MM B t u / h r bo il e r is c a lc u l a t ed a s t h e

b a se c o st t i m e s ( 100 / 2 50 ) 0

. 6



### . A f i x e d c o st o f $ 1 m illi o n w a s a ss u m e d f or i n st a ll a ti o n o f a

c a r bo n ad s o rp ti o n s y st e m f o r Hg and / o r d i o x in c on t r o l, a s t he s e s y st e m s d o n o t v a r y

m u ch in c o st b y bo il e r si z e

. Ba se c o st a s s u m p ti o n s a r e p r e s en t e d be l o w

.

Base Control Size, MMBtu 250

Fabric Filter $7,000,000

Scrubber $8,000,000

Scrubber/FF/ESP upgrade $4

, 0 00

, 000

Carbon Injection for Hg/dioxin $1

, 0 00

, 000

Combustion Improvements or Catalyst for CO $3

, 0 00

, 000

### 12

C on t r o ls w e r e e v a l ua t e d s e p a r a t e l y

, f i r st f o r p a r tic u l a te m a tt e r

, t h e n f o r h y d r o g en

c h l o r i de

, t h e n f o r m e r c u r y an d d i o x i n / f u ra n

, a n d l a st f o r c a r bo n m o n o x i de

. To e s ti m a te

Bo il e r M A CT c on t r o ls an d c o sts f o r ea c h u n i t

, if t h e r e w a s n o e m iss i on s i n f o r m a ti on

a v a il ab le f o r a pa r tic u l a r bo il e r

, w e u se t h e b a s e li n e e m issi o n f a c t o r s de v e l op e d b y EP A

f o r t he ir ana l y sis. In t h e ir bo il e r i n v en t o r y t ab l e

, E P A p u t t h e bo il e r p o ll u ti o n c on t r o ls i n to

c a t e g o r i e s. T h e c a t e g o r i e s a r e e x p l a i ne d in gr ea t e r de t a il in E P A ’s ba s e li n e e m issi on

f a ct o r m e m o

, b u t b a sic a lly a r e a s f o ll o w s: f o r P M c on t r o l c od e

, 1

= F F

, 2

= E F B / E SP

, 3

= v en t u r i sc r ubbe r

, 4

= w e t sc r ubbe r

, 5

= m u lti c l one

, 6

= no n e / m ist e l i m i na t o r / u n k n o w n

. I f a

un it d id no t a l r e a d y ha v e a FF o r E S P a n d t he r e w a s i n f o r m a ti o n t ha t i n d ic a t e d t he un it

c a nn o t m e e t t h e l i m it, w e a ss u m e d a n e w FF. If t h e un it a l r ea d y ha d a FF o r ES P an d

t he r e w a s i n f o rm a t i o n t h a t i n d ic a t e d t h e u n it c a n no t m ee t t h e li m it w e a ss u m e d a n

up gr ad e t o t h e e x isti n g c on t r o l e q u i p m en t. F o r HCl c on t r o l c o d e

, 1 =w e t sc r ubbe r or

s p r a y d r y e r

, 2

= d r y sc r ub b e r

, 3

= s o r b e n t i n j e c t i on

, 4

= v en t u r i sc r u b be r

, 5

= n o ne / d r y P M

on l y

. T o e st i m a t e c o n t r o l c o sts f o r HCl, i f t he r e w a s i n f o r m a ti o n t h a t i nd ic a t e d t h e u n it

c an n o t m e e t t h e li m it, w e a ss u m e d e i t he r a s c r ubbe r up gr ad e o r n e w sc r ubber

de p end i n g o n w he t h e r t h e un it c u rr en tly ha d a sc r ubbe r

. F o r Hg c on t r o l c ode

, 1

= c a r b o n

i n j e cti on

, 2

= FF p l u s s or ben t i n j e cti o n o r s p r a y d r y e r

, 3

= FF on l y

, 4

= w e t sc r u b be r

, 5

= v en t u r i sc r ubbe r

, 6

= no n e / m u lticl o n e / E F B / m ist e l i m i na t o r

. F o r H g an d d i o x i n

, i f t he r e

w a s i n f o r m a ti o n t h a t i n d ic a t e d t h e u n it c a nn o t m e e t t h e l i m it, w e ad d e d c a rb o n i n j e cti o n

. F o r CO, i f t h e r e w a s i n f o r m a ti o n t h a t i nd ic a t e d t h e u n it c a nno t m ee t t h e li m i t

, t h e n w e

a ss u m e d t h a t c a p it a l w ou ld b e n e c e s s a r y to e it he r pe r f o r m c o m bu st i on / f ue l f eed

i m p r o v e m e n ts o r o t h e r bo il e r i m p r o v e m e n t p r o j e cts t o r e d u ce CO o r i n st a ll a CO

c a t a l y st.

A lt hou g h EPA ’s e sti ma t e s i nd i c a te t h a t t h e t o t a l c ap i t a l c o st o f t h e f i n a l r u le w ill be $ 5

b illi on

, URS ha s e s t i m a t e d t ha t t h e t o t a l c a p it a l c o st o f t h e r u le w i l l b e o v e r $ 1 4 b illi o n f o r

a ll i n d u st r y ( $2.85 to 3 .2 b i l li o n f o r p u lp an d p a pe r m ills, depending on whether more

materials are waste or fuel )

. It is e v i de n t m a j o r c ap it al i n v e st m en ts in a dd

- o n c on t r o l

t e c h n o l o g y w ill b e r e q u i r e d f o r c o n ti n u e d o pe r a t i o n o f s o lid a n d li q u id f u e l e d bo il e r s a n d

p r o c e ss he a t e r s.

URS c ap it a l c o st e s ti m a t e s d i f f e r f ro m EPA ’s c o st e st i m a t e s a s f o ll o w s:

 

### EP A h a s u s e d t h e o u t d a t e d C on t r o l C o st M a n ua l a n d URS ba s e d c o st e sti m a t es

o n m o r e r e c en t i n f o r m a ti on

, i n cl ud i n g a c t ua l v endo r c o st e sti m a t e s, a ct u a l p r o j e ct

c o sts, B A CT a n d BA R T ana l y s e s, i n d u st r y c on t r o l c o st s t ud i e s, e tc.

 

### URS used a CO catalyst cost 4 times higher than EPA’s. The URS cost is based

on a recent quote from BASF and EPA’s is based on the 1998 Control Cost

Manual section on catalytic oxidizers for VOC control.

 

### EP A h a s e s ti m a t e d t ha t a t une

- u p o r bu rn e r r ep l a c e m e n t w ill b e a deq ua te f or

m an y un its to a c h i e v e t h e CO li m it s

. URS d o e s n o t a gr e e w ith t h is a ss u m p ti o n

be c a u se s om e o f t h e CO li m its a r e f a i r ly l o w an d m u s t b e m e t o v e r a ll ope ra ti ng

c ond iti o n s e x c ep t s t a r t u p a n d s hu t do w n

, so w e ha v e e s ti m a t e d h i gh e r c o sts t o

i m p l e m e n t c o m b u sti o n c on t r o ls, bu rn e r r ep l a c e m e n ts, f ue l f e e d s y st em

i m p r o v e m e n ts, o r CO c a t a l y st.

### 13  

### URS CO c on t r o l c ap it a l c o sts a r e h i g he r t h a n EPA ’s, m o stly be c au se EP A

a ss u m e d t h a t t u ne

- u p s an d r ep l a c e m en t bu rn e r s w i l l b e a d e q ua te f o r t h e v a st

m a j o r ity o f b o il e r s to c o m p l y

, a n d URS d oe s no t a gr e e w ith t ha t a s s u m p ti on.

 

### EP A h a s e s ti m a t e d t ha t a cti v a t e d c a r b o n i n j e c ti o n w ill b e r e q u i r e d o n on ly 120

e x isti n g un its be c a u se i n st a ll a ti o n o f a f ab r ic f i lt e r is e x pe ct e d to a c h i e v e t he

m e r c u r y e m issi o n li m i t s, e x c ep t in c a s e s w h er e a u n it a l r e a d y ha s a f ab r ic

f ilt er an d doe s n o t m e e t t h e li m its. URS d oe s no t agr e e t ha t f ab r ic f ilt e r s w i ll

be s u f f ici en t to re du c e mer c u r y e m issi on s to t h e u lt r a

- l o w l e v e ls in t h is r u l e

. T h e r e is a f l a w in t h e l o g ic t ha t f ab r ic f il t e r s a r e e x pe c t e d t o a c h i e v e m e r c u r y

e m issi o n li m i t s w he n t he r e a r e m a n y bo il e r s in t h e da t a b a s e t h a t a r e e q u i ppe d

w ith f ab r ic f il t e r s an d ha v e m ea s u re d m e r c u r y e m issi on s h i g he r t han t h e

app lic a b le li m it. E PA ’s e st i m a t e d i n du st r y

- wi d e c ap it a l c o st f o r a cti v a t ed

c a r bo n i n j e cti o n p r e s e n t e d in t h e E RG c o st a n d e m issi on s i m p a cts m e m o is

e x t r e m e ly l o w

, a t on ly $6 .2 m illi o n (o n ly $52

, 00 0 pe r u n it a v e r a g e )

. T h is c o st

be t t e r r ep r e s e n ts 1 2 u n its t h a n 12 0 affected un its.

 

### EP A h a s e s ti m a t e d c o sts to i n s t a ll p a ck e d b e d sc r ub b e r s f o r HCl c o n t r o l.

I ndu s t r i a l bo il e r s d o no t u se pa c k e d be d sc r u bbe r s f o r a cid g a s c on t r o l, a s t h e

li m it a ti on s o f t he s e d e v ic e s m a k e t h e m i m p ra ctic a l f o r u s e o n a pp li c a ti on s w ith

h i g h f l o w r a t e s, h i g h P M l oad i n g

, a n d h i g h i n l e t p o ll u t a n t c o n c e n t r a t i on

. EPA ’s

o w n f a c t s h ee t o n t he s e de v ic e s, l o c a t e d at

h tt p : //ww w

. epa

. g o v

/tt n / c a tc/ d i r 1 /

f pa ck

. p d f, lis t s t he s e li m it a ti on s o f t h e se

d e v ic es an d i nd ic a t e s t h a t t he y a r e o n ly u s e d in a p p lic a ti on s u p to 75

, 0 0 0

s cf m

, w h ich li m its t he ir u se t o s m a ll un its on ly ( EP A r e s po nd e d to t h is

c o m m e n t b y app l y i ng m u lti p le pa c k e d be d s c r ubbe r s t o u n its w ith h i g he r f l o w

r a t e s )

. F a ciliti e s w ill i n st e a d i n st a ll w e t sc ru bbe r s, d r y sc r ubbe r s, o r s e m i

- d r y

sc r ubbe r s to c on t r o l a cid g a s e m issi on s f ro m i n d u st r i a l bo il e r s. EP A h a s

e sti m a t e d HCl c on t ro l c o sts f or e q u i p m e n t t ha t i n d u st r y is no t lik e ly to i n st a ll.

 

### EP A h a s a s s u m e d t h a t f a ciliti e s w ill no t i n c u r c o sts to c o m p ly w ith t he

d i o x i n /f u r a n s t a n da r d s be c a u se t he y w i l l t e st f o r d i o x i n /f u r a n a n d b e be l ow

de t e c ti o n l e v e ls. T h is l o g ic doe s n o t m a k e s e n s e

, e s pe ci a lly w he n t he r e a r e

bo il e r s in t h e E P A e m i ssi on s d a t a b a se w ith d i o x i n / f u ra n e m issi on s t ha t a r e

n on

- de t e c t b u t a c t ua lly m e a s u r e d e m issi on s h i gh e r t h a n t h e a pp lic a b le l i m it

a n d t he r e a r e bo il e r s w he r e E PA ’ s ba s e li n e e m issi o n f a ct o r f o r d i o x i n /f u r a n is

abo v e t h e app lic ab l e li m it. W e h a v e e sti m a t e d c a r b o n i n j e cti o n a s t h e c on t r o l

m ea s u r e f or d i o x i n /f u r a n e m issi o n s, a ss u m i n g t h a t it w ill b e e ff e cti v e a t t he s e

l o w l e v e ls.

### 14

T h e f o ll o w i n g c ap it a l c o sts f o r c on t r o l add it i o n s/ up gr a d e s w e r e e st i m a t e d b y URS f o r

pu lp an d p a pe r c o a l, b i o m a s s

, a n d li q u i d un its ha v i n g n u m e r ic a l e m issi o n li m its

un d e r Bo il e r M A C T ( a s s u m i n g many materials burned are solid waste and not fuel ).

This is Scenario I :

T h e f o ll o w i n g c ap it a l c o sts f o r c on t r o l add it i o n s/ up gr a d e s w e r e e st i m a t e d b y URS f o r

pu lp an d p a pe r c o a l, b i o m a s s

, a n d li q u i d un its ha v i n g n u m e r ic a l e m issi o n li m its

un d e r Bo il e r M A C T ( a s s u m i n g many materials burned are fuels and not solid waste ).

This is Scenario II :

T h e se e sti m a t e d c o sts d i f f e r f ro m t h e c o sts o f t h e p r o p o s e d r u le a s f o ll o w s:

 

### T h e f i n a l e m issi o n li m i t s an d t h e c o m b i n a ti o n o f b i o m a ss a n d c o a l b o il e r s i n to

a s o lid f u e l s ub c a t e g o r y f o r t h e f ue l

- b a s e d H A P (PM, HCl, and Hg) r e s u lt e d i n

a re du ct i o n in c on t r ol c o st f o r m a n y un its.

 

### F o r t h e p r o p o s e d r u l e

, si n ce m an y o f t h e l i m i t s w e r e so l o w a s to b e

una c h i e v ab l e

, w e e st i m a t e d t ha t c o n t r o ls w ou ld b e r e q u i r e d o n b o il e r s w he r e

no e m issi on s i n f o r m a t i o n w a s a v a il ab l e

. F o r t h e f i na l r u le c o sts, i f n o b o il e r

s pe ci f ic e m issi on s i n f o r m a t i o n w a s a v a il ab le w e u s e d EPA ’s b a s e li n e

e m issi o n f a ct o r s by bo il e r t y p e a n d c on t r o l t y p e to d e t e r m i n e i f c o n t r o ls w ou ld

b e r e q u i r ed.

 

### C o sts f o r c om p li an ce w ith t h e CO li m its w e r e ad j u s t e d ba s e d o n i n f o r m a t i on

r e c e i v e d f ro m c o m p a n i e s t h a t h a d do n e p r e li m i na r y en g i nee r i n g a n d c o st

e sti m a t e s. W e u s e d a ba se c o st o f $ 3 m illi o n an d s c a l e d u si n g t h e 0 .6 f a c t o r

by bo il e r si z e f o r t h e f i na l r u l e

, v e r s u s a f i x e d c o s t o f $ 2 m illi o n f o r t h e

p r opo s e d r u l e

. PM

Upgrade Cost HCI

Upgrade Cost Hg/Dioxin

Upgrade Cost CO

Upgrade Cost Total

Capital Cost

$1.1 Billion $918 Million $232 Million $578 Million $2.85 Billion

PM

Upgrade Cost HCI

Upgrade Cost Hg/Dioxin

Upgrade Cost CO

Upgrade Cost Total

Capital Cost

$1.3 Billion $1 Billion $270 Million $660 Million $3.2 Billion

### 15  

### Costs for mercury and dioxin are captured in the same column because it is

assumed that carbon injection will be needed to meet both, based on the use

of carbon injection to meet dioxin standards for higher emitting source

categories such as municipal waste incinerators. However, the costs to

achieve the dioxin limits for industrial boil ers are uncertain and are likely

underestimated because most of the dioxin limits are 100

- 1000 times lower

than any previous MACT and it is unclear what emission reduction strategies

could be implemented to meet the standards. The dioxin limits are essenti ally

unachievable for most boilers.

CI SW I Ru l e :

C o sts f o r t h e C I S W I R u le w e r e de v e l op e d in a si m il a r m a n ne r a s c o sts f o r t h e B o il er

M A CT r u l e

. E P A ’s C I S W I ICR da t aba s e w a s u s e d to de t e r m i n e w h ich u n its w ou ld

be s ub j e ct to t h e C I S W I r u le a n d w ha t c o n t r o ls w ou ld b e n ee d ed . Units were also

identified that were in EPA’s Boiler MACT database, but burn NHSM such as

wastewater treatment residuals, recycling process residuals, TDF, resinated wood,

creosote treated wood/rail ties. C o s ts w e r e a ssi g ne d f or P M / m e t a ls, NO x

, a cid g a s,

an d m e r c u r y

/ d i o x i n c o n t r o ls. T h e e s ti m a t e d c ap it a l c o st o f c on t r o ls f o r boilers at

large pu lp a n d p ape r m ills, a ss u m i n g the current NHSM rule, which classifies many

existing biomass fuels as solid wastes, is app r o x i m a t e ly $ 9 5 0 m illi o n. Smaller mills

that would otherwise be regulated under the Boiler GACT rule but are burning

secondary materials could also face costs under CISWI, but those costs were not

modeled in this study. If changes are affected to the NHSM rule that allow more

mate rials to be classified as fuels, the cost for CISWI controls for large pulp and

paper mill boilers could be reduced to $470 million.

Scenario Solid Waste

Determination Capital Cost for Boilers at

Large Pulp and Paper

Mills

One Many materials wastes $950 M

Two Few materials wastes $470 M

O t h e r Pe nding Air R e

gul a t ions W h e re Co st

s Could Be A ss ig n e d t o M ill s 6

 

### Cl u st e r M A CT I/III R e

- do a nd R e s i dual Risk

o 

### $7 8 0 m illi o n

– > 9 5 % o f c o sts d u e to M A C T o r g an ic H A P (M e t h a no l)

c on t r o ls o n p a p e r m a c h i ne s; $3 6 0 m illi o n in O & M is e s p e ci a lly h i g h du e

to ene rg y i n t en si v e na t u r e o f c on t r o ls w h ich a l s o p r o d u ce o v e r 2 m illi o n

m e t r ic t on s o f CO 2

6 F i s her w as un a b l e to a l l o c ate about $2 b i l l i o n of the s e c o s ts to s pe c i f i c m ill s

, s o the t ot a l c a p i t a l c o s t

u s ed w as $6.3 b i l l i o n.

### 16 o 

### N e w Cl u st e r M A CT c o u ld s e t li m its o n a dd iti o na l p i e c e s o f e q u i p m e n t

( like pa p e r m a c h i ne s) f o r o r g an ic H AP s; E P A h a s d isc r e ti o n no t to

un d e r t a ke d e n o v o r e v i e w o f M A C T s

o 

### R e si dua l r isk r e v i e w li k e ly to s ho w f e w r isks r e m a i n

o 

### EP A sc h e d u l e d to c o m p l e te i n June 2 0 1 2 w ith c o n t r o ls b y mid

- 2015

 

### Cl u st e r M A CT II R e

- d

o an d R e si d u a l Risk

o $3.3 billion: >95% of cost due to MACT; $300 million in O&M plus 1.5

million metric tons of new CO2 emissions

o New MACT II could lead to addition of mercury, and HCl controls and

more stringent PM controls on recovery furnaces, lime kilns, and smelt

tanks. Again, EPA has discretion whether to revisit MACTs;

o Residua l risks from these sources also small

o EPA is likely to complete in 2013 with controls by 2016

 

### Hydrogen Sulfide HAP Listing

o $2.7 billion in capital, plus $180 million in operating costs

o Assumes H2S listed as HAP and MACT establishes limits for pulping

operations and wastewater treatment ponds

o EPA has discretion to deny petition or conclude not an issue for pulp

mills based on careful risk assessment

o Possible final rule in 2015 (maybe sooner), with 2018 implementation

 

### NOx Controls due to Tighter NAAQS

o Assumed NOx controls (either low

- NOx burners, SNCR, or SCR)

needed on boilers at facilities in or near projected non

- attainment

areas.

o $600 million in capital, plus $140 million in operating costs.

o Final 1

- hour NOx standard was published in 2010, ozone sta ndard

expected to be lowered in 2011 (reductions will be driven by NOx in

many areas), implementation in 2013.

o Facilities have had problems meeting new 1

- hour NOx standard when

modeling for projects

O t h e r Pe nding Air R e

gul a t ions W h e re Co st

s Could NOT Be A s s ign e d t o M ill s

 

### Boiler Area Source/GACT

o Rule sets HAP emission requirements for smaller biomass and liquid

boilers at so called “area sources” such as box plants; rule does not

apply to gas

- fired boilers.

o Impact of rule is minimal since EPA adopted work practices (tune

- ups)

rather than numeric limits for CO for existing biomass and liquid

boilers.

o Final rule March 2011, compliance within 3 years

### 17  

### CAIR 3/Cross

- State Rule for Industrial Boilers and Recovery Furnaces

o $870 million in capital; tot al O&M would be $220 million

o Assumes next phase of rule requires medium and large boilers burning

majority coal or oil to significantly reduce SO2 and NOx

o Possible promulgation in 2012 with compliance over the next five

years

 

### Start

- up, Shutdown & Malfunct ions (SSM) Provisions Removed from MACT

o $100 million, plus $3 million in O&M

o If EPA compelled to eliminate SSM exemptions and venting

allowances then installation of redundant controls or suffer periods of

shutdown with no production would drive costs even higher. EPA has

discretion to develop reasonable work practices to replace current

SSM exemptions

o EPA linking schedule with pulp and paper MACT rules, so complete by

2012

 

### Ozone NAAQS revisit

o $400 million in capital and $30 million in O&M

o Tighter standard will drive more VOC and NOx controls than other

rules require for smaller contributors in or near more numerous non

attainment areas

o EPA plans to reset NAAQS in 2011; impacts would occur 4 to 5 years

after finalization

 

### PM fine NAAQS Implementation

o $284 m illion in capital and $40 million in O&M

o Assume tighter annual standard will drive further SO2 and NOx

controls. As in all the above NAAQS, EPA has the discretion to

determine “ample margin of safety” necessary to protect public health.

o Final in 2012 with controls needed for attainment 5 or so years out

 

### Revised NAAQS for SO2

o $40 million in capital and $7.5 million in operating costs

o Final in June 2010 with controls on select sources in five years (2015)

o Significant uncertainty in ability to meet increments modeling for

projects

 

### Kraft Pulp NSPS Revisions

o $83 million in capital through 2020 and $56 million six years after

effective date given more mills trigger retrofit requirements

o EPA can defer action on NSPS or set equivalent to MACT to avoid

new costs

o EP A linking schedule with pulp and paper MACT rules so complete by

April 20121 

### EPA’s Prior Determinations That Landfill Gas is Not a Solid Waste

**•** Since 1986, EPA has determined under RCRA that l andfill gas would be regulated as an

“air pollutant”, rather than as “solid waste” In that regard, the regulation of MSW

landfill emissions was considered during deliberations under a RCRA subtitle D

rulemaking. In 1986 and 1987 the Administrator decided to regulate these emissions

under the authority of the Clean Air Act. See

, e.g. March 6, 19 86 Memorandum from

Marcia Williams to H. Lanier Hickman, Jr. (attached), cited in Definition of Solid Waste

Compendium, Volume U, (Un)

- Contained Gases (December 2010) (attached) (see

particular ly page 9, which refer s to the Hickman memorandum and which characterize s

landfill gas as “uncontained” and therefore not “solid waste” ). After further

consideration, the EPA announced in the Federal Register on August 30, 1988 (53 F ed.

R eg. 33

, 314) (atta ched) their decision to regulate MSW landfill emissions under section

111 of the CAA. This ultimately occurred through the promulgation of the landfill

NSPS, 40 CFR Part 60, Subpart s W WW and Cc in 1996

.

**•** In the proposed Landfill NSPS standards published on May 30, 1991 (56 F ed. R eg.

24

, 468) (attached) , EPA again reiterated its decision to treat landfill gas as a Clean Air

Act pollutan t (rather than as solid waste).

**•** The issue was re

- raised during public comment for the proposed NSPS. In response,

EPA sp ecifically stated in response: “the RCRA subtitle D establishes a framework for

controlling the management of nonhazardous solid waste. Because the intent of this rule

is to regulate emissions of landfill gas, and not solid waste, this regulation has bee n

developed under the CAA instead of under RCRA. Some requirements in the RCRA

subtitle D regulation are referenced within the NSPS and EG and are necessary to achieve

compliance with these regulations.” See Air Emissions From Municipal Solid Waste

Landfills

– Background Information for Final Standards and Guidelines, EPA

- 453/R

- 94

- 021 (December 1995), at page s 1

- 4, 2

- 31 to 2

- 34 (attached). Thus, t he concept of

utilizing RCRA authority and regulating landfill gas as solid waste was specifical ly

rejected by EPA at that time. “Although one commenter suggested that LFG emissions

should be regulated under RCRA authority, the EPA continues to consider Section 111

NSPS and EG to be the appropriate statutory approa ch for regulating these emissions

because the adverse health and welfare effects of concern result from air emissions.

Therefore, the final notice added MSW landfills as a source catego ry for regulation under

Section 111(b)(1)(A) of the CAA to th e priority list in 40 CFR 60.16. ” See id.

**•** On January 16, 2003, EPA issued National Emission Standards for Hazardous Air

Pollutants: Municipal Solid Waste Landfills (68 F ed. R eg. 2

, 227), which ensured that

landfill gas collection and treatment and/or control systems (including combustion units

and landfill gas used on or offsite in beneficial use projects) achieved MACT level

controls.

**•** EPA again noted on March 22, 2004, in revisions to its Criteria for Municipal Solid

Waste Landfills, Final Rule for Research , Develo pment and Demonstration Permits for

Municipal Solid Waste Landfills :2 

### “With the exception of explosive gas control requirements, landfill gas controls are not

regulated pursuant to Subtitle D of RCRA: rather landfill gas emissions are regulated

under the Clean Air Act (CAA). The air criteria in 40 CFR 258.24 refer to CAA

requirements by requiring compliance with the applicable State Implementation Plan

provisions under section 110 of the CAA. Specific requirements pertaining to landfill gas

emissions from MSWLF units are addressed in 40 CFR Part 60,Subparts Cc and WWW.

Recently, EPA promulgated National Emission Standards for Hazardous Air Pollutants:

Municipal Solid Waste Landfills (68 FR 2227, Jan. 16, 2003). This rule includes

requirements for initiating landfill gas collection and control in bioreactor landfills. See

40 CFR Part 63, Subpart AAAA.... [C] onsistent with section 1006(b) of RCRA, EPA

sees no need for additional requirements under RCRA to address air emissions in today’s

rule. ”

See Final Rul e, Research, Development and Demonstration Permits for Municipal Solid

Waste Landfills, 69 F ed. R eg. 13

, 242 (2004) (attached)

.

**•** Thus, b y 2004, all landfills regulated under WWW were regulated under the Section 112

Landfill MACT standards promulgated at 40 CFR Part 63, Subpart AAAA. In all

instances, the notion was that landfill gas would be combusted either in open flares,

enclosed combustors (enclosed flares, turbines, engines or boilers), or the gas would be

treated (com pressed, filtered to 10 microns or less, and cooled or chilled) and routed for

use as fuel as either onsite or offsite

. When combusted in turbines, engines or boilers, the

landfill gas is either controlled to NSPS

- specified treatment limits, or it is ”tre ated” as per

the NSPS for end use.

**•** Having exercised its asserted authority under RCRA Section 4004 to regulate air

emissions from landfills as a “designated air pollutant” under the Clean Air Act rather

than as solid waste under RCRA, the combustion of this designated air pollutant in a

flare

, turbine

, boiler or engine should not be deemed to be the combustion of a solid

waste. Stated di fferently, something cannot be a designated air pollutant and a solid

waste at the same time.

**•** For purposes of Secti on 129, the term “solid waste’ has the meaning established by the

Administrator pursuant to the Solid Waste Disposal Act. The meaning established for

many years by the Administrator pursuant to the Solid Waste Disposal Act (RCRA) was

that landfill gas wou ld not be treated as solid waste, and its combustion would not be

treated as solid waste combustion, but rather, as an uncontained gaseous emission

regulated as a designated air pol lutant by the Clean Air Act. There is nothing in the Non

Hazardous Seconda ry Materials Rule (NHSM) that establishes that landfill gas is a solid

waste, and the regulatory impact analysis for the CISWI rule gave no consideration of

landfill gas as a source type for establishment of MACT. Indeed, the NHSM establishes

that solid w aste follows the meaning of solid waste for purposes of Subtitle D, 40 CFR

258.2. That definition excludes uncontained gas from the definition of solid waste, and

has via rulemaking always excluded landfill gas.3 

### Longstanding EPA Precedent that Uncontain ed Gas is not a Solid Waste

**•** The statutory definition of “solid waste” includes “contained gaseous material.” 42 USC

§ 6903(27).

**•** EPA interpretation of the term “contained gaseous material” demonstrates that RCRA

only applies to “contained” gases, to t he exclusion of “uncontained” gases.

**•** EPA’s interpretation of “contained” has been limited to gas present inside “containers.”

o In a 1989 preamble to a final rule dealing with the listing of certain hazardous

substances under RCRA, EPA stated that EPA “b elieves our authority to identify

or list a waste as hazardous under RCRA is limited to containerized or condensed

gases (i.e., section 1004(27) of RCRA excludes all other gases from the definition

of solid wastes and thus cannot be considered hazardous wa stes). See Hazardous

Waste Management System: Identification and Listing of Hazardous Waste, 54

F ed. R eg. 50968, 50973 (Dec. 11, 1989).

o The CISWI Rule promulgated in 2000 defined contained gaseous material as

limited to “gases that are in a container when that container is combusted.” (EPA

provided no explanation for deletion of this definition, which was not mandated

or even discussed in the D.C. Circuit’s NRDC decision.)

o Similarly, 40 CFR Part 60, Subpart EEEE, governing Other Solid Waste

Incineration U nits, includes the same definition of “contained gaseous material.”

**•** EPA has a longstanding policy providing that fume incinerators are subject to regulation

only under the CAA, and not also RCRA.

o For example, in the preamble to a 1982 dealing with regulation of incinerators

that burn hazardous waste, EPA stated that “fume incinerators are subject only to

regulation under the Clean Air Act . . . . Fume incinerators which are used to

destroy gaseou s emissions from various industrial processes, for example, are not

subject to regulation under RCRA. In general, the RCRA standards do not apply

to fume incinerators since the input is not identifiable as a solid waste.” See The

Hazardous Waste Management System, Interim Final Amendments to Interim

Final and Final Rules, 47 F ed. R eg. 27

, 520, 27

, 530 ( June 24, 19 82)

. See also

, RCRA Superfund Hotline Monthly Summary, 9488.1986(03) available at RCRA

Online.

o EPA has reaffir med this position on subsequent occasions. For example, in the

1989 preamble discussed above, EPA stated that “fume incinerators are installed

as air pollution control devices pursuant to regulations under the Clean Air Act;

they are used to destroy gaseo us emissions from various industrial processes.

EPA concluded that, in general, RCRA standards do not apply to fume

incinerators because the input (an uncontainerized gas) is not a solid waste.” 544 

### F ed. R eg. 50

, 973 n.5. See also , Memorandum from Matthew Straus, Chief,

Waste Characterization Branch, to Clifford Ng, Engineer, EPA Region II, dated

June 17, 1987, available at RCRA Online (“Methanol

- laden air from the drying

and granulation step of the process does not meet the definition of solid waste

under RCRA because it is in vapor form and not confined in a container.”)

**•** On a few occasions, some in EPA attempted to take a broader view of contained gas (e.g.

piping was enough) but that view was rejected by the courts or the administrative

tribunal. See

, e.g. In re BP Chemicals America, Inc. , RCRA Appeal No. 89

- 4, 1991 EPA

App. LEXIS 27; 3 E.A.D. 667 ( EPA Admin., Aug. 20, 1991) (The Administrator

specifically rejected Region V's argument that gaseous emissions were "contained" by the

process units they pas sed through, associated piping or the facility itself, holding that the

Agency's definition of the term "contained" has consistently been confined "in the

narrower sense of being in an individual container such that the gas is amenable to

shipment”). See also In re: Chemical Waste Management of Indiana, Inc. , RCRA Appeal

No. 95

- 4, 1995 EPA App. LEXIS 31 (E PA Environmental Appeals Board , Aug. 23, 1995)

(emissions from microencapsulation of hazardous debris) (The EAB concludes the air

emissions are excludable from Subtitle C regulation "because the air emissions that the

Region seeks to regulate are not containerized.”)

**•** In the landfill gas context, that view was similarly rejected by stakeholder groups

assigned to review combustion issues. See

, e.g

. , Recomme ndation from the Incinerator

Workgroup on Section 112 Subcategories April 28, 1998 (“Section 129 Requirements.

Section 129 applies to "solid waste combustion.” Because solid waste is defined to

exclude gases (except gases which are in containers), Section 129 does not apply to

landfill gas flares .” ) (available at http://www.epa.gov/ttn/atw/iccr/incin/rec

- 112.pdf )

.

 The final Boiler MACT rule expressly recognizes that landfill gas constitutes a “gaseous

fuel .” (76 F ed. R eg. 15

, 684)

 See also:

o Burning of Hazardous Waste in Boilers and Industrial Furnaces, Final Rule, 56

Fed

. Reg. 7134, 7200 (Feb. 21, 1991) ( activat ed carbon units used as air emission

control devises are not subject to RCRA because “the gas originally treated is not

a solid waste (it is an uncontained gas).” See also RCRA Online Determinations

12783 (November 20, 1986) ( Volatile organics released to the air are not

hazardous waste because they are not solid wastes. (They do not fit the definition

established in §1004(27) of RCRA as "contained gaseous materials.") ”

o Hazardous Waste TSDF

- Technical Guidance RCRA Air Emission Standards for

Process Vents and Equipment Leaks, EPA

- 450/3

- 89

- 021 (July 1990) at page s 2

- 3:

"Air standards have been promulgated for the control of air emissions from

permitted hazardous waste incinerators. 40 CFR Part 264, Subpart O. These

standards require that incinerato rs burning hazardous waste be operated to achieve

a destruction and removal efficiency (DRE) of at le a st 99.99 percent for those5 

### primary organic hazardous constituents listed in the facility permit However, the

process vent stream (i.e. gases and vapors) from a hazardous waste management

unit would not be classified as a hazardous wastes. Noncontainerized gases

emitted from hazardous wastes are not themselves hazardous wastes because the

RCRA statute implicitly excludes them. Therefore combustion of proc ess vent

streams in an incinerator is not subject to the 99.99 DRE requirement."

o Hazardous Waste Treatment, Storage, and Disposal Facilities (TSDF):

Background Information for Promulgated Organic Air Organic Air Emission

Standards for Tanks, Surface Imp oundments, and Containers , EPA/453/R

94/076b (November 1994) ( since organic vapors emitted from hazardous waste

are not solid or hazardous waste, control devices installed to comply with Subpart

CC organic vapor control requirements are not hazardous waste management

units and do not require RCRA permits).

## Defining Landfill Gas as Solid Waste

Implications for Renewable Energy & Innovative Materials Management

The Agency’s statements in the NHSM rulemaking record (the Response to Comments document), and the

deletion from the CISWI rule of the definition of “contained gaseous material” clarified as “gases that are in

a container when the container is combusted” h ave created significant uncertainty about the regulatory

status of landfill gas combusted in pollution control devices and as a fuel.



## Regulatin g LFG as a solid waste will have a dramatic and detrimental impact on the use of

LFG as a renewable fuel, d isrup ti ng a significant portion of the US renewable energy portfolio.

According to DOE’s Energy Information Administration, the entire domestic solar industry produced a little

over 800

- thousand megawatt hours of power in 2009. That same year WM produced over five times that

amount of electricity from landfill gas

.

WM has 131 landfill gas

- to energy (LFGTE) projects and has been producing LFGTE since the mid

- 1980’s

. Municipalities, state and federal agencies, and private entities have invested in LFG to ene rgy projects with

strong encouragement from:

**•** Congress (Renewable Energy Production Tax Credit) available since the early 1990’s;

**•** EPA’s Landfill Methane outreach Program (LMOP) ;

**•** 29 state Renewable Portfolio Standards that recognize LFG as a renewable energy source ; and

**•** EPA’s Renewable Fuel Standard ( RFS2 ) regulation (for transportation & heating fuel) that specifies

LFG as an advanced biofuel and biogenic MSW remaining after reasonably practicable separation of

recyclables a s renewable biomass;

**•** OSWER cites L FG to energy as part of its “Green Remediation” goals.

Private companies and local governments have made significant capital investments to make these

renewable energy projects possible. About a half a billion dollars have been invested in projects acros s the

country to deliver landfill gas to third parties for use as fuel.



## Failure to recognize LFG as a legitimate fuel will undermine significant sustainability

investments by cities and small communities, private companies large and small, and

members of the federal family.

Examples of how LFG fuels many companies’ and Federal Agencies’ sustainability goals:

**•** LFG provides 95% of NASA Goddard Spaceflight Center’s heating energy ;

**•** DoD is turning to LFG to electricity to power its bases (e.g., Ft Benning) ;

**•** DAR PA awarded WM’s partner, Terrebon, a $20M contract to make jet fuel from LFG and organic

waste ;

**•** LFG powers Dell’s Corporate HQ campus, BMW’s Greenville Mfg facility, DuPont, Dow, GM, Ford

plants to name a few ;

**•** LFG powers U. of New Hampshire’s facility heating ;

**•** LFG powers small businesses in rural communities: paint shops, greenhouses, glassblowing, schools

**•** LFG converted to LNG powers over 300 WM garbage trucks in CA

## Regulation of landfill gas under Section 129 would be detrimental to the economy and t he

environment.

Regulation of the combustion of landfill gas for energy recovery under section 129 would likely end th ese

beneficial projects

. We would simply return to flaring the landfill gas. Customers purchasing landfill gas as

a fuel would stop doi ng so. The benefits of criteria pollutant reductions and greenhouse gas emission

reductions associated with using landfill gas as a fuel would be lost.

Regulation of landfill gas under Section 129 of the CAA would also dramatically affect the cost of cap ture

and control of landfill gas. Landfill gas flares, engines and turbines (all of which are approved pollution

control devices under the MSW Landfill NSPS and NESHAP) would need to be replaced with thermal

oxidizers to meet the section 129 standards. E PA estimated the annual costs of compliance per site to be

a bout $186,000 , or for WM more than $50 million per year . Our rough estimates of the capital costs for

WM to install thermal oxidizers to replace flares would exceed the total estimated costs of t he CISWI rule

for its intended sources (about $ 412 million)

. The costs would be ruinous to the local governments that

own and operate many landfills.



## EPA is already successfully regulating Landfill gas emissions.

EPA has established extensive regulatory programs based on the determination that landfill gas is not a

solid waste.

WM has already invested about $330 million in over 200 active LFG collection systems and spends about

$30 million each year on O&M.

F ederal regulation of MSW landfills under sections 111 and 112 of the CAA, and promotion of LFG capture

and beneficial use has been highly successful as demonstrated in EPA’s U.S. GHG Inventory, which shows

LFG emissions have declined by over 20% from 1990 through 2009.



## The Derived

- From Rule has never been pertinent to the status of Non

- Hazardous Solid

Waste.

The Derived

- From rule states that all wastes that are produced as the result of treatment, storage, or

disposal of a listed hazardous waste are regul ated as that listed hazardous waste §261.3(c) (2)(i) . The same

is true of characteristic wastes, unless the resulting waste does not exhi bit a hazardous characteristic

§261.3(d)(1)

. There is no such derived

- from concept in Subtitle D of RCRA. (see §257.2 Solid Waste

Facility Definitions and 258.2 Definitions under MSW Landfill Criteria) In fact, the Derived

- From Rule only

applies to wastes derived from hazardous wastes. (See

http://homer.ornl.gov/sesa/environment/guidance/rcra/derived.pdf )



## Extension of this Derived

- From concept to Non Hazardous Solid Waste will render

renewable energy and materials recovery from MSW inoperable in the U.S.

## 1 Recommendations for OMB

Landfill Gas (LFG) Issues in Non

- Hazardous Secondary Materials (“NHSM”)

Commercial and Institutional Solid Waste Incineration (“CISWI”) and Boiler

MACT Rules

**1) EPA should clarify in regulation that**  **landfill gas (LFG)**  **is not a solid waste subject**

**to the NHSM Rule**

. Agency statements in the Responses to Comments Document for the

NHSM Rule (February 2011) at (3b

- 13

- 1; 3b

- 13

- 2; and 3b

- 13

- 4) indicated that EPA had changed

long

- standing interpretation of what constitutes “contained gaseous material” a component of

the definition of “solid waste,” as well as the regulatory status of LFG

.

EPA has since provided helpful “comfort letters” to WM and the AF&PA clarifying that EPA has

not changed its prior interpretations and affirmed generally that gaseous material is not solid

waste unless held in a container when combusted, consistent with the regulatory definition and

interpretations of “contained gaseous material” EPA has used over many years and in various

contexts. Instead, LFG has long been subject to overlapping federal, state and local regulatory

programs that have required the control of LFG as an air pollutant, not a solid waste, and have

encouraged the use of L FG as fuel where economically and practically feasible to do so. EPA’s

letter to WM clarified that it did not intend to change prior interpretations of the regulatory

status of LFG

. (Attachment A

– August 5, 2011 Letter from EPA to Waste Management)

The EPA comfort letters were offered as a band aid fix at a point when the Agency did not want

to reopen the NHSM Rule. Now that it has reopened the rule, EPA needs to provide regulatory

certainty and eliminate confusion resulting from the Response to Comm ents document for the

NHSM R ule . Specifically, consistent with the statutory definition of “solid waste,” EPA should

clarify in the NHSM Rule that the rule may apply only to contained gaseous material, and not to

uncontained gaseous streams such as LFG.

**2) EPA also**  **should restore the deleted regulatory definition of “contained gaseous** 

**material” in the CISWI Rule** 

**.** Consistent with the existing CISWI Rule and the discussion

above, maintaining the definition within CISWI for “contained gaseous material” wil l clarify that

LFG is not solid waste under typical LFG control and combustion scenarios, including when

conveyed to a pollution control device for air emission control; when conveyed to a combustion

device for e lectricity generation ; or when conveyed to t hird parties for use as a fuel. Failure to

clarify that CISWI does not apply to LFG combustion will adversely affect beneficial use and

control of LFG

. ( Attachment B

– Defining LFG as Solid Waste

- Implications for Renewable Energy

& Innovative Materials Ma nagement )

## 2 **•** Regulating LFG as solid waste would have a dramatic and detrimental impact on use of

LFG as a renewable fuel.

**•** Regulation of LFG under CISWI would

, for WM alone

, exceed the total estimated costs

of the CISWI R ule for its intended sources

– about $412 million in capital, $50

million/year in O&M.

**•** Failure to recognize LFG as a legitimate fuel will undermine private, local government

and federal sustainability initiatives.

**3 )**  **EPA should insert regulatory language in the NHSM Rule**  **that lists LFG**  **as a**

**“traditional fuel.”** T he Agency needs to correct the rulemaking record at the NHSM R ule

Response to Comments 3b

- 13

- 2 where the Agency suggests that LFG must meet the legitimacy

criteria of the NHSM rule to be deemed a legitimate fuel , even though the Agenc y later clarified

that LFG is not a solid waste in its comfort letter to WM. Like natural gas, refinery gas, blast

furnace gas, recovered gaseous butane and coke oven gas, all of which are listed within the

NHS M Rule definit ion of “traditional fuels,” LFG should be acknowledged as a traditional fuel.

Failure to clarify in the NHSM Rule that LFG is a traditional fuel is contrary to statutory and

regulatory definitions and program policies that recognize LFG as a renewable fuel. For

example:

**•** EPA’s La ndfill Methane Outreach Program (LMOP) promotes use of LFG as a renewable

fuel for boilers, turbines and engines;

**•** The Federal Renewable Energy Production Tax Credit rewards electricity production

from LFG ;

**•** EISA 2007 and EPA’s Renewable Fuel Standard (RFS2) which specify that LFG is an

advanced biofuel;

**•** The Boiler MACT Rule defines LFG as a gaseous fuel; and

**•** All 29 state Renewable Portfolio Standards define LFG as a renewable fuel for green

electricity production.

EPA has now through its comfort letters cla rified that it maintains its long

- standing definition of

“contained gaseous material” and maintains prior Agency determinations that LFG is not a solid

waste. The Agency should amend its rulemaking record and clarify in rule language that LFG is

a traditi onal fuel, not a solid waste, and therefore NOT subject to the NHSM Rule. ( Attachment

C

– EPA’s Prior Determinations That LFG is Not a Solid Waste )

**4 ) EPA**  **should amend**  **the Boiler MACT Rule to**  **categorize LFG**  **as a “Gas 1” fuel** 

**. Alternatively, EPA should correct the fuel specification used to qualify**  **gaseous fuels**

**as “other Gas 1 fuels.”** The combustion of LFG in boilers is a positive alternative to control

of LFG in flares. Failure to categorize LFG as a “Gas 1” fuel will subje ct LFG boilers to stringent

emission limit s , thereby creat ing strong disincent ives to the use of LFG in boilers and hamper ing

many private, local government and federal government facilities’ sustainability efforts and

significantly disrupt ing domestic ren ewable energy production

. The U.S LFG to energy sector is

a significant portion of the domestic renewable energy sector, producing more than 7 times the

energy output of the entire domestic solar energy sector

.

## 3 Under the Boiler MACT, units designed to bu rn Gas 1 fuel ( including natural gas and refinery

gas) are not subject to emission limits, while units designed to burn “ Gas 2 ” fuels are subject to

strict emission limits for PM, HCL, Mercury, CO and dioxins/furans. By EPA’s own analysis the

control cost s for Gas 2 boilers are estimated to be higher than the combined compliance capital

costs for boilers and process heaters in all other categories. All of WM’s LFG customers have

indicated that they would switch to natural gas or other fossil fuels if LFG

- fired boilers are

subject to “Gas 2” emission limits.

The environmental consequences of fuel switching from landfill to natural gas are very

detrimental:

As of September 20, 2011, EPA’s LMOP has data on 60 US boiler projects and 17 projects tha t

utilize LFG in a boiler

- steam turbine. EPA estimates that the 60 boi ler projects utilize

approximately 1900 Million British Thermal Units (MMB tu ) per hour of LFG

, and that the 17

boiler

- steam turbine projects utilize approximately 2400 MMBtu per hour of LFG. If the project

owners switch from LFG to natural gas , LFG will still be generated by the landfills and therefore

must be combusted in flares , increasing emissions of greenhouse gases and criteria pollutants.

EPA calculated the net increase in overall fossil fuel based CO2 emissions from boiler and boiler

– turbine projects would be 2,025,698 tons. The nation would also realize an additional 12,841

tons of CO, 291 tons of PM and 684 tons of NOx

. SO2 and Hg emi ssions would also increase

slightly by 10.2 and 0.00 5 2 tons, respectively. (Attachment D

– EPA LMOP Environmental

Analysis provided to WM)

The financial costs associated with switching from LFG to natural gas to comply with the

Boiler MACT as promulgated, are also quite significant. For boiler and boiler

- turbine projects

now using LFG, the order

- of

- magnitude estimate of the total direct costs of fuel switching to

natural gas is estimated to be $ 1.064 billion

.

In addition, project owners will lose the va lue of the LFG processing and transport equipment

that must be abandoned when fuel switching from LFG. The total estimated capital assets lost

for existing projects is $87 million. (Attachment E

– CH2M Hill Boiler MACT Economic Impact

Evaluation)

If EPA does not categorize LFG as a “Gas 1” fuel, it should revise and correct the fuel

specification used to allow other gases to qualify as “Gas 1.” The fuel specification relies on

two constituents as parameters; mercury and hydrogen sulfide (H 2 

### S). H 2 

### S is an inappropriate

parameter for this MACT standard , and is set at a technically infeasible level. Therefore, in

revising the specification, EPA should rely solely on the mercury parameter and remove the

H 2 

### S parameter. Based upon a review of the EPA doc ket for the Boiler MACT, CH2M HILL

concluded the following with respect to the fuel speceification:

## 4 EPA has not established a valid rationale for using H 2 

### S, as a relevant parameter. MACT

regulates hazardous air pollutant (HAP) emissions. H 2 

### S is not a HAP, nor has EPA established

(or even suggested in its rationale of the fuel specification) any correlation of H 2 

### S in fuel with

any HAP or HAP surrogate emissions.

EPA has not established a valid rationale for the specific H 2 

### S concentration of 4 parts per

million by volume (ppmv) in the fuel specification . The specified concentration is based on

natural gas sweetening for corrosion protection. However, boiler units generally do not

require this level of protection. Fuel gases, including refinery gases, that have much higher

H 2 

### S levels, commonly are used in boilers without treatment to the fuel specification

standard. (Attachment F

– CH2M Hill Review of Technical Basis for H2S in Boiler MACT Fuel

Specification)

5) EPA should clarify the Non

- Waste Determinati on Process. The NHSM Rul e framework for

distinguishing alternative fuels from solid waste is to require that the secondary material be

sufficiently processed in producing the fuel, and that the fuel meet s enumerated “legitimacy

criteria.” In this evaluat ion, EPA requires a comparison of contaminants in the fuel product to

traditional and alternative fuel materials. There is a great deal of uncertainty surrounding how

these non

- waste determinations will be conducted, and the type of analysis and informati on

required to satisfy the Agency.

1. Fuel combustors and/or fuel producers should receive one

- time, national non

- waste

determinations;

2. EPA’s headquarters Office of Resource Conservation and Recovery should make

coherent, consistent determinations to ensure national consistency;

3. The legitimacy criteria should be discretionary rather than mandatory. The criteria were

developed originally to provide indicia of legitimate recycling of hazardous waste. The

criteria are not appropriate mandatory requirements in this context;

4. EPA’s legitimacy analysis should focus on the heating value of the fuel, whether material

management and processing is conducted in a safe and protective manner, and whether

the material’s use as a fuel will extract value from the material an d reduce landfill

disposal.

Failure to adequately clarify the process and criteria by which legitimacy determinations may

be made will create enormous disincentives to recovering energy value from materials which

otherwise would be landfilled.Boiler Emissions EnvAnalysis-092611-LMOP forWM.XLSX 9/26/11 Baseline Emissions = LFG fired in boilers

New Emissions Scenario = Natural gas fired in boilers, LFG flared

LFG Energy Boiler Projects LFG Energy Boiler-Steam Turbine Projects

Total Estimated MMBtu/hr of LFG Utilized = 1,896 Total Estimated MMBtu/hr of LFG Utilized = 2,499

Project Count = 60 Project Count = 17

Emissions

Source Pollutant Baseline New

Scenario Increase Emissions

Source Pollutant Baseline New

Scenario Increase

Fossil CO2 0 873,972 873,972 Fossil CO2 0 1,151,726 1,151,726

CO 0 CO 0

PM 0 PM 0

NOx 0 NOx 0

SO2 115 4.4 -111 SO2 152 5.8 -146

Hg 0 Hg 0

Fossil CO2

- 0 0 Fossil CO2

- 0 0

CO

- 5,540 5,540 CO

- 7,301 7,301

PM

- 126 126 PM

- 165 165

NOx

- 295 295 NOx

- 389 389

SO2

- 115 115 SO2

- 152 152

Hg

- 0.0022 0.0022 Hg

- 0.0030 0.0030

Fossil CO2 873,972 Fossil CO2 1,151,726

CO 5,540 CO 7,301

PM 126 PM 165

NOx 295 NOx 389

SO2 4.4 SO2 5.8

Hg 0.0022 Hg 0.0030



### Assumptions and Rationale:

References: same

same

same Boiler

Emissions (tpy) same

same

same

same 

## Boiler Emissions Analysis

Greenhouse Gas Reporting Program (GHGRP) - 40 CFR 98, Subpart C, Table C-1 (Default CO2 Emission Factors and High Heat Values for Various Types of Fuel),

Default natural gas (weighted U.S. average) CO2 emission factor.

http://ecfr.gpoaccess.gov/cgi/t/text/text-idx?c=ecfr&sid=4069608504fe50a3a5715cd4da0bae39&rgn=div6&view=text&node=40:21.0.1.1.3.3&idno=40 AP-42 (LFG) - Chapter 2 (Solid Waste Disposal), Section 2.4 (MSW Landfills), November 1998.

http://www.epa.gov/ttn/chief/ap42/ch02/final/c02s04.pdf

AP-42 (Natural gas) - Chapter 1 (External Combustion Sources), Section 1.4 (Natural Gas Combustion), July 1998.

http://www.epa.gov/ttn/chief/ap42/ch01/final/c01s04.pdf 6. A gross capacity factor of 90% was applied to all of the emission calculations to account for loss of energy production due to problems in the gas collection

system, problems with project equipment, weather related interruptions of the local utilities, and shutdowns at the energy consumer end of the system. Flare Emissions

(tpy)

Overall

Emissions

Increase (tpy) Flare Emissions

(tpy)

Overall

Emissions

Increase (tpy)

1. To estimate boiler and flare emissions, emission factors were applied to the total estimated amount of LFG utilized (MMBtu/hr) for boiler projects and boilersteam turbine projects from the LMOP database (as of Sept 20, 2011). Emissions for individual boilers and boiler projects were not analyzed.

2. CO2 - All CO2 generated from LFG (combustion of CH4 and generation of CO2 from decomposition of MSW) was considered biogenic and not included in the

calculations. CO2 generated from combustion of natural gas as a fossil fuel (non-biogenic) was included in the calculations using an emission factor of 53.02 kg

CO2/MMBtu (116.9 lb CO2/MMBtu) from Subpart C of the Greenhouse Gas Reporting Program (GHGRP).

3. CO, PM & NOx - For combustion by-products CO, PM & NOx, emission factors for LFG-fired boilers and natural gas-fired boilers were not found to be statistically

unique and, in addition, they vary by individual boiler instead of fuel type. Therefore, for this analysis, it was assumed that CO, PM & NOx emissions from boilers

would not change when the fuel is switched from LFG to natural gas. Emissions of CO, PM & NOx were estimated for LFG being flared using emission factors from

AP-42 (Table 2.4-5) of 750 lb CO/million dscf methane, 17 lb PM/million dscf methane, and 40 lb NOx/million dscf methane.

4. SO2 emissions were estimated for the baseline and new emissions scenario because the amount of SO2 emitted from combustion in a boiler or flare varies by

the fuel type. The decrease in SO2 boiler emissions is a result of LFG typically containing higher levels of sulfur than natural gas. SO2 emissions for LFG-fired boilers

and flares were estimated using a default sulfur content of 46.9 ppmv for raw LFG from AP-42 (pg 2.4-8) and assumes all sulfur compounds in LFG are converted to

SO2 during combustion. SO2 emissions from natural gas-fired boilers were estimated using an emission factor of 0.6 lb SO2/million scf from AP-42 (Table 1.4-2).

5. Mercury (Hg) - Emission factors for Hg for LFG-fired boilers and natural gas-fired boilers were not found to be statistically unique. The amount of Hg in LFG and

natural gas was found to be very similar since Hg passes through combustion devices and the amount emitted varies by the amount of Hg in the fuel itself.

Therefore, for this analysis, it was assumed that Hg emissions from boilers would not change when the fuel is switched from LFG to natural gas. Emissions of Hg

were estimated for LFG being flared using a default Hg concentraion of 2.92E-04 ppmv from AP-42 (Table 2.4-1). Boiler

Emissions (tpy) same

### Operational LFG Energy Boiler Projects in LMOP Database 9/20/11

This information is from the LMOP Landfill/Project database.

Information in the database is compiled from a variety of sources

by voluntary submittal, is updated periodically, and can change.

LMOP cannot guarantee the validity of the data. 1Landfill ID #

Landfill NameLandfill State

Landfill Owner OrganizationProject ID #Expansion ID #

Current

Project

Status Project Name Project Start

Date Project

Shutdown

Date LFGE Project

Type

36 Acme LF CA Acme Fill Corporation 91 0 Operational Project #1 1/1/1982 Boiler

122 Cold Canyon LF Solid Waste Disposal

Site CA Waste Connections, Inc. 178 0 Operational Project #1 1/1/1999 Boiler

264 Sacramento City LF CA City of Sacramento, CA 323 0 Operational Project #1 1/1/1990 Boiler

428 Saint Lucie County SLF Phase I FL St. Lucie County 493 0 Operational Project #1 8/22/2005 Boiler

0 Shutdown Project #1 6/15/2008 12/31/2008 Boiler

1 Operational Project #1, DeExpansion #1 1/1/2009 Boiler

0 Operational Project #1 2/23/2005 Boiler

1 Operational Project #1,

Expansion #1 1/1/2007 Boiler

542 Elkhart County - CR 7 LF IN Elkhart County, IN 609 0 Operational Project #1 6/1/2007 Boiler

1939 South Side Landfill IN Balkema 167015 0 Operational Project #2 11/1/1999 Boiler

1943 Laubscher Meadows LF IN Republic Services, Inc. 180863 0 Operational Project #2 5/29/2009

Boiler

1939 South Side Landfill IN Balkema 180981 0 Operational Project #6 6/30/2009 Boiler

636 Brooks LF KS City of Wichita, KS 706 0 Operational Project #1 9/1/1998

Boiler

660 Seward County Landfill KS Seward County, KS 730 0 Operational Project #1 6/1/2007

Boiler

681 Outer Loop RDF KY Waste Management, Inc. 751 0 Operational Project #1 5/1/1999 Boiler

715 East Baton Rouge Parish LF LA City of Baton Rouge/East Baton Rouge

Parish 785 0 Operational Project #1 12/28/2004 Boiler 462 Old Dixie Highway MSW Landfill GA Dalton-Whitfield Regional Solid Waste

Management Authority (DWRSWMA),

GA 527

2303 Pine Bluff Landfill GA Waste Management, Inc. 180396

### Operational LFG Energy Boiler Projects in LMOP Database 9/20/11

This information is from the LMOP Landfill/Project database.

Information in the database is compiled from a variety of sources

by voluntary submittal, is updated periodically, and can change.

LMOP cannot guarantee the validity of the data. 2Landfill ID #

Landfill Name

36 Acme LF

122 Cold Canyon LF Solid Waste Disposal

Site

264 Sacramento City LF

428 Saint Lucie County SLF Phase I

542 Elkhart County - CR 7 LF

1939 South Side Landfill

1943 Laubscher Meadows LF

1939 South Side Landfill

636 Brooks LF

660 Seward County Landfill

681 Outer Loop RDF

715 East Baton Rouge Parish LF 462 Old Dixie Highway MSW Landfill

2303 Pine Bluff Landfill LFG Use DetailsLFG Flow to Project(mmscfd) - IndividualLFG Flow to Project(mmscfd) - Total

End User OrganizationNo. of BoilersHeat Input (MMBtu/hr)Heat Input per Boiler(MMBtu/hr)

1.5 1.5 Central Contra Costa Sanitary

District 31.6

LFG piped 2 miles to oilfield to fuel steam generators, the steam is used to increase the productivity of the oil wells, LFG

providing 20% of fuel needs 1.008 1.008 Plains Exploration and

Production Company 21.3

fuel for almond grower's boilers 1.6 1.6 California Almond Growers

Exchange (CAGE) 33.7

retrofitted boiler for steam production in juice manufacturing plant 1.008 1.008 Tropicana 1 21.3 21.3

2-mile pipeline to one boiler, end user to consume 240 billion Btu/yr, facility manufactures latex for carpet backing

applications 1.296

2-mile pipeline to (1) boiler, average LFG use = 9,100 MMBtu/month, use fluctuates as fuel needs vary due to batch

processing at plant, facility manufactures latex for carpet backing applications 0.864

2.304

1.296

compressed LFG co-fired with NG in 2 boilers at county jail 1 mile away for heating and production of hot water for the

kitchen and laundry facilities 0.346 0.346 Elkhart County Correctional

Complex 2 7.3 3.6

three modified boilers (1 coal, 2 NG), each rated at 60,000 lb/hr (plant 8) 2.4 2.4 Rolls Royce 3 50.6 16.9

5-mile pipeline to 3 boilers at industrial facility for production of nutritional infant products, LFG will almost completely

replace facility's use of NG 2.16 2.16 Mead Johnson

Nutritionals/Bristol-Myers

Squibb 3 45.5 15.2

0.72 0.72 Vertellus 15.2

LFG transported via 11-mile pipeline to water tube CB DL-94 boiler with dual-gas burner requiring 100 MMBtu/hr heat

input to produce ~80K lb/hr in the production of 25 mil gal of ethanol per year, co-fire NG in winter only, LFG usage is

2:1 over NG 3.7 3.7 Abengoa Bioenergy Corporation 1 78.0 78.0

Two 25 hp blowers pull LFG from gas vents & leachate cleanouts, uncleaned LFG is piped 1,800 ft to nearest wastewater

treatment anaerobic lagoon and injected under floating cover to join lagoon's gas, used as boiler fuel 0.1 0.1 National Beef 2.1

LFG transported via ~5 mile pipeline 0.72 0.72 General Electric 15.2

steam boiler(s) 1.09 1.09 Deltech Corporation 23.0 Styron LLC 18.2

25.3 18.2

75.9 3.6 Pilgrim's Pride 3.5-mi pipeline to chicken processing cooperative for use in (3) 125 psig steam boilers, 90 MMBtu/hr capacity, LFG used

to heat equipment for processing chickens for pet food 0.864 1

3

### Operational LFG Energy Boiler Projects in LMOP Database 9/20/11

This information is from the LMOP Landfill/Project database.

Information in the database is compiled from a variety of sources

by voluntary submittal, is updated periodically, and can change.

LMOP cannot guarantee the validity of the data. 3Landfill ID #

Landfill NameLandfill State

Landfill Owner OrganizationProject ID #Expansion ID #

Current

Project

Status Project Name Project Start

Date Project

Shutdown

Date LFGE Project

Type

0 Operational Project #1 - End

User 1

1 Operational Project #1 - End

User 2

0 Operational Project #2 10/1/2003

1 Operational Project #2,

Expansion #1 1/1/2009

741 Brown Station Road Sanitary LF MD Prince George's County, MD 811 0 Operational Project #1 4/20/1987 Boiler

0 Shutdown Project #1 1/15/2003 12/31/2010

1 Operational Project #1, DeExpansion #1 1/1/2011

1897 Vienna Junction Industrial Park

Landfill MI Republic Services, Inc. 166947 0 Operational Project #1 1/1/1995 Boiler

1936 Eagle Valley Landfill MI Waste Management, Inc. 0 Operational Combination

Project 1/1/1998

1894 Oakland Heights Development MI Republic Services, Inc. 1 Operational Combination

Project 1/1/1998

2068 Autumn Hills Recycling & Disposal

Facility MI Waste Management, Inc. 180117 0 Operational Project #1 1/1/2005 Boiler

1990 Muskegon DPW Type II Landfill MI Muskegon County, MI 181030 0 Operational Project #2 12/31/2006 Boiler

814 Crow Wing County SLF (new) MN Crow Wing County, MN 884 0 Operational Project #1 10/1/2009 Boiler

832 IESI Landfill MO Progressive Waste Solutions Ltd. 902 0 Operational Project #3 1/1/1997 Boiler

1963 Pecan Grove Sanitary Landfill MS Waste Management, Inc. 167045 0 Operational Project #1 7/12/2005 Boiler

0 Shutdown Project #1 1/1/1997 12/31/2003

1 Operational Project #1, DeExpansion #1 1/1/2004

0 Operational Project #1 12/1/1989

1 Operational Project #1,

Expansion #1 10/1/1997

1075 Cumberland County LF NC Cumberland County, NC 1148 0 Operational Project #1 12/1/1997

Boiler

1093 Henderson County LF NC Henderson County, NC 1166 0 Operational Project #1 1/1/1997 Boiler Boiler

Boiler

Boiler Boiler Boiler 7/10/2010 Boiler

768 Sandy Hill SLF MD Prince George's County, MD 838 180199

1064 City of Greensboro LF NC City of Greensboro, NC 1137

1066 Wilder's Grove Landfill NC City of Raleigh Solid Waste Services

Dept. 1139 167010 730 North Baton Rouge Landfill LA City of Baton Rouge/East Baton Rouge

Parish 800

700 Woolworth Road Landfill LA City of Shreveport, LA

### Operational LFG Energy Boiler Projects in LMOP Database 9/20/11

This information is from the LMOP Landfill/Project database.

Information in the database is compiled from a variety of sources

by voluntary submittal, is updated periodically, and can change.

LMOP cannot guarantee the validity of the data. 4Landfill ID #

Landfill Name

741 Brown Station Road Sanitary LF

1897 Vienna Junction Industrial Park

Landfill

1936 Eagle Valley Landfill

1894 Oakland Heights Development

2068 Autumn Hills Recycling & Disposal

Facility

1990 Muskegon DPW Type II Landfill

814 Crow Wing County SLF (new)

832 IESI Landfill

1963 Pecan Grove Sanitary Landfill

1075 Cumberland County LF

1093 Henderson County LF

768 Sandy Hill SLF

1064 City of Greensboro LF

1066 Wilder's Grove Landfill

730 North Baton Rouge Landfill

700 Woolworth Road Landfill LFG Use DetailsLFG Flow to Project(mmscfd) - IndividualLFG Flow to Project(mmscfd) - Total

End User OrganizationNo. of BoilersHeat Input (MMBtu/hr)Heat Input per Boiler(MMBtu/hr)

ExxonMobil Baton Rouge

Polyolefins

Novolyte Technologies, Inc.

2.592

1.008

2.5 mile pipeline from landfill to 2 boilers at correctional facility 1.332 1.332 Prince George's Co. Correctional

Facility 2 28.1 14.0

2.13

1.55

2 million sq. ft. manufacturing plant produces 130,000-150,000 MMBtu/yr from 2 boilers using LFG 0.864 0.864 General Motors Company 2 18.2 9.1

1.08

1.08

6.5-mile pipeline to soybean plant, boilers will produce heat and steam used to process beans 1.65 1.65 Zeeland Farm Soya 34.8

local chemical pigment company uses LFG in its boiler 0.432 0.432 Sun Chemical Company 9.1

Raypak Raytherm H1125 boiler supplies heat to in-floor heating system in 11,000 sq ft maintenance building, replaced

heater orifices in boiler for lower Btu 0.043 0.043 Crow Wing County SLF (new) 1 0.9 0.9

0.7 mile pipeline 0.3 0.3 Pattonville High School 6.3

LFG is used in retrofitted boiler(s) 24/7, piped over 5 miles, system designed for 3,200 cfm 3.3 3.3 EI DuPont de Nemours &

Company 69.6

2.2

0.97

0.8

0.8

LFG is refrigerated, filtered through a 10 micron screen, and compressed before being piped 2 miles under a river to a

steam boiler and oil heater at soybean processing facility; 2nd boiler (53 MMBtu/hr on LFG) added in 2006 1 1 Cargill 2 21.1 10.5

LFG and NG co-fired in Cleaver-Brooks boiler, steam sold to juice plant 0.82 0.82 Clement-Pappas 1 17.3 17.3 20.5

16.9 38.0

10.9 75.9

45.5 3

1

2 75.9

32.7

20.5

33.7 3.6

3.6 LFG is processed (free liquid & solids removal via a suction scrubber), compressed, and dehydrated (via a refrigeration

system), then piped 7 miles to 2 steam boilers at GM for both heating & cooling purposes, offsetting NG use General Motors Company 3.75-mi pipeline to the south and 1.5-mi to the north supply 80-85 MMBtu/hr total to boilers

1927 Hiene field-erected brick set 70,000 lb/hr boiler retrofitted with 2 Coen burners to generate 30,000 lb/hr of 350

psig saturated steam (co-fired with NG or #6 fuel oil), LFG is monitored at each well for % CH4, CO2, & O, and vacuum Cone Mills

LFG transported via 1-mile pipeline to be co-fired with NG in two 800-hp Cleaver Brooks firetube boilers (eliminated use

of fuel oil); produces steam to heat facility and warm pharmaceutical cultures Ajinomoto USA, Inc. NASA Goddard Space Flight

Center

plant is located between the 2 LFs, LFG is used in boilers converted from coal-firing to generate steam and provide utility

service to the main assembly plant, some coal is still used in winter but boilers run only on LFG the rest of the year General Motors Company 1.55

2.16

0.97

1.6 LFG is piped 5.5 mi. to (3) 1995 40,000 lb/hr package boilers modified to burn LFG and use NG and fuel oil as backup;

steam from boilers is circulated to heat the Center's buildings 2

### Operational LFG Energy Boiler Projects in LMOP Database 9/20/11

This information is from the LMOP Landfill/Project database.

Information in the database is compiled from a variety of sources

by voluntary submittal, is updated periodically, and can change.

LMOP cannot guarantee the validity of the data. 5Landfill ID #

Landfill NameLandfill State

Landfill Owner OrganizationProject ID #Expansion ID #

Current

Project

Status Project Name Project Start

Date Project

Shutdown

Date LFGE Project

Type

1122 Pitt County LF NC Pitt County, NC 1196 0 Operational Project #1 1/1/1998 Boiler

0 Shutdown Project #1 11/1/1997 12/31/2005 Boiler

1 Operational Project #1,

Expansion #1 5/15/2006

Boiler

2 Operational Project #1,

Expansion #2 11/1/2009 Boiler

2153 City of Fargo Landfill ND City of Fargo, ND 180222 0 Operational Project #1 5/15/2002 Boiler

1839 Turnkey Recycling & Environmental

Enterprises NH Waste Management, Inc. 181082 0 Operational Project #1 1/1/1991 Boiler

940 Burlington County SLF NJ Burlington County Board of Chosen

Freeholders 180439 0 Operational Project #1 1/1/1996 Greenhouse

1006 Ontario County SLF NY Ontario County, NY 180964 0 Operational Project #2 3/1/2008 Boiler

1164 Tremont LF OH Danis 1238 0 Operational Project #1 9/4/2002

Boiler

1174 Bedford #1 and #2 LFs OH Bedford-Ecol, Inc. 1248 0 Operational Project #1 1/1/1986 Boiler

1202 Evergreen Recycling & Disposal LF OH Waste Management, Inc. 1276 0 Operational Project #1 1/1/1999 Boiler

0 Shutdown Project #1 10/1/1999 12/31/2007 Boiler

1 Operational Project #1, DeExpansion #1 1/1/2008 Boiler

1167 Cuyahoga Regional Sanitary LF OH Waste Management, Inc. 180129 0 Operational Project #2 1/1/2001 Boiler

1908 Lake County LF OH Lake County, OH 180968 0 Operational Project #2 1/1/2009 Boiler

1294 Commonwealth Environmental

Systems (CES) LF PA DeNaples Brothers 1369 0 Operational Project #1 6/20/2005

Boiler

1275 Lycoming County LF PA Lycoming County, PA 180916 0 Operational Project #2 1/1/2003 Boiler

1918 Wellford LF SC Spartanburg County Public Works

Department, SC 166973 0 Operational Project #2 6/22/2011 Boiler 1908 Lake County LF OH Lake County, OH 166959 1837 North Wake Solid Waste Landfill NC Wake County, NC 166410

### Operational LFG Energy Boiler Projects in LMOP Database 9/20/11

This information is from the LMOP Landfill/Project database.

Information in the database is compiled from a variety of sources

by voluntary submittal, is updated periodically, and can change.

LMOP cannot guarantee the validity of the data. 6Landfill ID #

Landfill Name

1122 Pitt County LF

2153 City of Fargo Landfill

1839 Turnkey Recycling & Environmental

Enterprises

940 Burlington County SLF

1006 Ontario County SLF

1164 Tremont LF

1174 Bedford #1 and #2 LFs

1202 Evergreen Recycling & Disposal LF

1167 Cuyahoga Regional Sanitary LF

1908 Lake County LF

1294 Commonwealth Environmental

Systems (CES) LF

1275 Lycoming County LF

1918 Wellford LF 1908 Lake County LF 1837 North Wake Solid Waste Landfill LFG Use DetailsLFG Flow to Project(mmscfd) - IndividualLFG Flow to Project(mmscfd) - Total

End User OrganizationNo. of BoilersHeat Input (MMBtu/hr)Heat Input per Boiler(MMBtu/hr)

1 boiler of 2 produces steam for hospital use 1 1 Pitt County Memorial Hospital 1 21.1 21.1

2-mile pipeline to Cleaver Brooks fire-tube steam boiler designed to burn LFG with NG as back-up, generating 23-25,000

lb steam/hr, 1/2 of plant's demand 1.296

Existing boiler with a maximum heat input of 96.2 mmBtu/hr was modified to add LFG as another fuel, running a

combination of LFG and NG to meet site's steam demands, No. 2 Fuel Oil is used as a back-up for NG during times of

curtailments, 2-mile pipeline 1.8

2-mile pipeline 1.224

1.5-mile pipeline to oilseed processing/crushing plant, LFG provides 1/3 of plant's thermal energy needs (1/3 from

sunflower hulls, 1/3 from NG) 1.152 1.152 Cargill 24.3

2.03 MMBtu/hr Envirex boiler (model 1506 RM) at leachate plant 0.09 0.09 Turnkey Recycling &

Environmental Enterprises 1 1.9 1.9

LFG (instead of propane) fuels boiler to heat 46,000 sq. ft. greenhouse, LFG heats greenhouse, office, and lab space as

well as aquaculture and agriculture systems 0.216 0.216 Rutgers EcoComplex 1 4.6 4.6

pipeline carries LFG to small package boiler that runs on NG or LFG, in 4000 ft2 administrative office adjacent to the

landfill 0.009 0.009 Ontario County, NY 1 0.2 0.2

LFG used directly for combustion units including: human comfort boiler, process ovens, process heaters, and air

pollution abatement unit 0.5082 0.5082 International Truck and Engine

Corporation - Springfield

Operations 1 10.7 10.7

LFG is piped ~3 mi. to fuel boilers that generate steam for space heating and hot water, backup system allows boilers to

supplement LFG w/ NG if necessary 2 2 Lucent Technologies 42.2

1.1 1.1 Walbridge Coatings 23.2

retrofitted boiler ~3 miles from landfill at fatty acid/glycerin plant 2.016 Twin Rivers Technologies

1.72 Hardy Industrial Technologies,

LLC

LFG fires boilers that generate steam for process use (to cook food) and comfort heat, provides 90 percent of the

processing and building heating needs; 2.5 mile pipeline 1.728 1.728 Stouffer's Foods 36.4

2 boilers 2.016 2.016 Nova Chemicals, Inc. 2 42.5 21.3

1/2-mi pipeline, 800 hp boiler (24,000 lb/hr) burns LFG for steam to convert raw potatoes into dehydrated flakes,

30,000 gal propane tank for back-up fuel or to co-fire if LFG heating value drops below a critical point, boiler load

managed by steam demand 0.24 0.24 Keystone Potato 1 5.1 5.1

heating 65,000 ft2 on-site Materials Recovery Facility with two 2.4 MMBtu/hr boilers (~150 cfm peak) 0.019 0.019 Lycoming County LF 2 0.4 0.2

6.1-mi pipeline to (1) Cleaver-Brooks 600 HP fire-tube boiler, (1) Cleaver-Brooks 250 HP fire-tube boiler, (1) Carotek 400

HP hot oil heater; offsetting NG use; provides 100% of facility's energy needs 0.72 0.72 Milliken & Company 2 15.2 7.6 36.3 63.8 Mallinckrodt Inc., a Covidien

company 1 63.8

1 36.3 1.72 3.024

### Operational LFG Energy Boiler Projects in LMOP Database 9/20/11

This information is from the LMOP Landfill/Project database.

Information in the database is compiled from a variety of sources

by voluntary submittal, is updated periodically, and can change.

LMOP cannot guarantee the validity of the data. 7Landfill ID #

Landfill NameLandfill State

Landfill Owner OrganizationProject ID #Expansion ID #

Current

Project

Status Project Name Project Start

Date Project

Shutdown

Date LFGE Project

Type

2105 Three Rivers Regional Subtitle D

MSWLF SC Three Rivers Solid Waste Authority, SC 180166 0 Operational Project #1 5/15/2008 Boiler

1913 Greenwood Landfill SC Greenwood County Public Works, SC 0 Operational Combination

Project 6/25/2009

2115 Greenwood County Subtitle D LF SC Greenwood County Public Works, SC 1 Operational Combination

Project 6/25/2009

2294 Sioux Falls Regional Sanitary Landfill SD City of Sioux Falls, SD 180387 0 Operational Project #1 2/28/2009 Boiler

0 Operational Project #1 8/1/2004

1 Operational Project #1,

Expansion #1 11/1/2005

1388 Iris Glen Landfill TN City of Johnson City, TN 1464 0 Operational Project #1 2/1/2007

Boiler

1812 Blue Ridge LF TX Republic Services, Inc. 101871 0 Operational Project #1 12/1/2009 Boiler

1948 Rosenberg Landfill TX Fort Bend County, TX 167030 0 Operational Project #1 1/1/2000 Boiler

1473 City of Waco LF TX City of Waco, TX 180913 0 Operational Project #2 4/24/2008 Boiler

1465 McCarty Road LF TX Republic Services, Inc. 180917 0 Operational Project #2 3/1/2009 Boiler Boiler Boiler 180176

1330 South Shelby Landfill TN Republic Services, Inc. 1406

### Operational LFG Energy Boiler Projects in LMOP Database 9/20/11

This information is from the LMOP Landfill/Project database.

Information in the database is compiled from a variety of sources

by voluntary submittal, is updated periodically, and can change.

LMOP cannot guarantee the validity of the data. 8Landfill ID #

Landfill Name

2105 Three Rivers Regional Subtitle D

MSWLF

1913 Greenwood Landfill

2115 Greenwood County Subtitle D LF

2294 Sioux Falls Regional Sanitary Landfill

1388 Iris Glen Landfill

1812 Blue Ridge LF

1948 Rosenberg Landfill

1473 City of Waco LF

1465 McCarty Road LF 1330 South Shelby Landfill LFG Use DetailsLFG Flow to Project(mmscfd) - IndividualLFG Flow to Project(mmscfd) - Total

End User OrganizationNo. of BoilersHeat Input (MMBtu/hr)Heat Input per Boiler(MMBtu/hr)

15.8-mile pipeline to retrofitted steam boiler at industrial site 1.656 1.656 Kimberly Clark Beech Island

Facility 1 34.9 34.9

0.46

0.116

11-mile pipeline to plant for use in boiler for producing portion of 105 million gallons of ethanol per year, offsets 10% of

NG needs 1.8 1.8 POET 1 38.0 38.0

6.048

1.152

PSA, carbon filter, & membrane filtration system, ~90% pipeline quality gas (~875 Btu/scf), ~4 mi pipeline, capacity of

100,000 lb/hr steam, 7.5 MW, & chilled water (offsets NG use in 4 industrial boilers or 3.5 MW engine/genset) 2.16 2.16 Veterans Affairs Medical Center,

Mountain Home 4 45.5 11.4

34-mile pipeline to (1) boiler 4.32 4.32 Ineos Olefins Corporation 1 91.1 91.1

5-mile pipeline supplies LFG to a boiler to generate steam for process use and comfort heat, LFG & NG mix 1 1 Frito-Lay Inc. 1 21.1 21.1

Filtered and dehydrated LFG is piped ~5 miles to replace 60% of plant's NG usage, co-fired (NG) boilers generate steam

for cooking, hot water, and humidity control 1.19 1.19 Mars North America 25.1

6-mile pipeline, LFG for primary fuel for 4 boilers, for heat and steam in the brewing process, will replace 55% of NG use 6.48 6.48 Anheuser-Busch Companies 4 136.6 34.2 50.6 6.1 12.1

151.8 2

3 0.576

7.2 LFG is piped 5 miles to 3 boilers for steam generation at the Solae facility, a soy based food ingredients plant The Solae Company 5.2 mi pipeline to 2 (full-time) converted NG boilers - 197,000 decatherms to start, to provide up to 60% of end user's

energy needs FujiFilm

### Operational LFG Energy Boiler Projects in LMOP Database 9/20/11

This information is from the LMOP Landfill/Project database.

Information in the database is compiled from a variety of sources

by voluntary submittal, is updated periodically, and can change.

LMOP cannot guarantee the validity of the data. 9Landfill ID #

Landfill NameLandfill State

Landfill Owner OrganizationProject ID #Expansion ID #

Current

Project

Status Project Name Project Start

Date Project

Shutdown

Date LFGE Project

Type

1586 Lynchburg City LF VA City of Lynchburg 0 Operational Combination

Project 1/1/2002

1587 Lynchburg City SLF VA City of Lynchburg 1 Operational Combination

Project 1/1/2002

1597 SPSA Regional LF VA Southeastern Public Service Authority,

VA 167139 0 Operational Project #3 8/1/2001 Boiler

2131 Rockingham County Landfill VA Rockingham County Department of

Public Works, VA 180195 0 Operational Project #1 6/1/2010

Boiler

1702 Veolia ES Cranberry Creek Landfill,

LLC WI Veolia ES Solid Waste, Inc. 1782 0 Operational Project #1 10/15/2005 Boiler

1705 Valley Trail Recycling & Disposal

Facility WI Waste Management, Inc. 1785 0 Operational Project #1 12/1/1998 Boiler

1707 Winnebago County LF-Sunnyview WI Winnebago County, WI 180929 0 Operational Project #3 1/1/2006 Boiler

2225 Wetzel County Landfill WV J.P. Mascaro & Sons 180309 0 Operational Project #1 1/1/2003 Boiler

Project Count 60 Boiler 1665

### Operational LFG Energy Boiler Projects in LMOP Database 9/20/11

This information is from the LMOP Landfill/Project database.

Information in the database is compiled from a variety of sources

by voluntary submittal, is updated periodically, and can change.

LMOP cannot guarantee the validity of the data. 10Landfill ID #

Landfill Name

1586 Lynchburg City LF

1587 Lynchburg City SLF

1597 SPSA Regional LF

2131 Rockingham County Landfill

1702 Veolia ES Cranberry Creek Landfill,

LLC

1705 Valley Trail Recycling & Disposal

Facility

1707 Winnebago County LF-Sunnyview

2225 Wetzel County Landfill LFG Use DetailsLFG Flow to Project(mmscfd) - IndividualLFG Flow to Project(mmscfd) - Total

End User OrganizationNo. of BoilersHeat Input (MMBtu/hr)Heat Input per Boiler(MMBtu/hr)

0.11

0.44

Transmission by 2.4-mile pipeline (14 in. HDPE pipe) to 2 retrofitted boilers producing 25,000 lbs steam 1 1 Ciba Specialty Chemicals 2 21.1 10.5

(1) 500-HP boiler initially at half-load, 15,000 lbs/hr low pressure steam to sterilize surgical equipment, cook food & heat

water, 2 boilers will operate at full-load during winter - LFG can meet 100% of peak heat demand, 3rd boiler will be backup unit 0.7488 0.7488 Rockingham Memorial Hospital 1 15.8 15.8

1.5-mile pipeline to steam boilers to energize a cranberry concentrator, dual-fuel boilers can burn LFG, NG, or

combination 0.84 0.84 Ocean Spray Cranberries, Inc. 17.7

boiler uses 400 cfm when operational 0.576 0.576 National By-Products, Inc. 1 12.1 12.1

0.1224 0.1224 Winnebago County Highway

Building 2.6

LFG fed to boiler to heat leachate for pre-treatment, heating allows less chemicals to be used to treat the leachate 0.15 0.15 1 3.2 3.2

Sum 67 1,896

Missing 20

Assume 1 Boiler for Missing 87 11.6 11.6 1 0.55 boiler is 64 feet from landfill Rock Tenn Paper

### Operational LFG Energy Boiler Projects in LMOP Database 9/20/11

This information is from the LMOP Landfill/Project database.

Information in the database is compiled from a variety of sources

by voluntary submittal, is updated periodically, and can change.

LMOP cannot guarantee the validity of the data. 11Landfill ID #

Landfill NameLandfill State

Landfill Owner OrganizationProject ID #Expansion ID #

Current

Project

Status Project Name Project Start

Date Project

Shutdown

Date LFGE Project

Type

Projects Utilizing LFG in Boiler(s) but also in other Equipment So Amount of LFG Utilized Just by Boiler(s) is Unknown

2288 City of LaGrange Landfill GA City of LaGrange, GA 180378 0 Operational Project #1 - End

User 1 10/3/2005 Direct Thermal

832 IESI Landfill MO Progressive Waste Solutions Ltd. 166964 0 Operational Project #1 1/1/1983 Direct Thermal

1154 Yancey/Mitchell County LF NC Yancey County 1228 0 Operational EnergyXchange 4/22/1999 Direct Thermal

1748 L.P. Gill LF NE L.P. Gill 6427 0 Operational Project #1 4/1/2008 Direct Thermal

0 Operational Project #1 12/15/2004

Direct Thermal

1 Operational Project #1,

Expansion #1 10/18/2005 Direct Thermal

2 Operational Project #1,

Expansion #2 2/1/2006 Direct Thermal

3 Operational Project #1 - End

User 4 12/10/2008 Boiler

4 Operational Project #1 - End

User 5 12/15/2008 Boiler

5 Operational Project #1 - End

User 6 12/17/2008 Direct Thermal

6 Operational Project #1 - End

User 7 12/20/2008 Direct Thermal

1257 Pine Grove LF PA Waste Management, Inc. 180903 0 Operational Project #2 3/1/2008 Direct Thermal

1928 Palmetto Landfill SC Waste Management, Inc. 180843 0 Operational Project #2 9/1/2006

Direct Thermal

Project Count 8

Total Project Count 68 1266 Lanchester LF PA Chester County Solid Waste Authority,

PA 1341

1269 Conestoga LF PA Republic Services, Inc. 180899

### Operational LFG Energy Boiler Projects in LMOP Database 9/20/11

This information is from the LMOP Landfill/Project database.

Information in the database is compiled from a variety of sources

by voluntary submittal, is updated periodically, and can change.

LMOP cannot guarantee the validity of the data. 12Landfill ID #

Landfill Name

Projects Utilizing LFG in Boiler(s) but also in

2288 City of LaGrange Landfill

832 IESI Landfill

1154 Yancey/Mitchell County LF

1748 L.P. Gill LF

1257 Pine Grove LF

1928 Palmetto Landfill 1266 Lanchester LF

1269 Conestoga LF LFG Use DetailsLFG Flow to Project(mmscfd) - IndividualLFG Flow to Project(mmscfd) - Total

End User OrganizationNo. of BoilersHeat Input (MMBtu/hr)Heat Input per Boiler(MMBtu/hr)

LFG burned directly in 3 Interface hot oil burners and a steam boiler (instead of NG) for process heat conditioning

equipment for 600 cfm and 8 miles of pipeline 0.0415 0.28 InterfaceFLOR 1

oil burner and rotary dryers at North Asphalt plant, boiler at concrete facility Breckenridge Ready-Mix 1

LFG fuels furnaces for glass blowers and metal workers and potters' kilns (Craft Studio) and boilers to heat greenhouses

via radiant floor heating (Project Branch Out) 0.054 0.054 EnergyXchange Renewable

Energy Center

LFG is compressed at the LF and piped 1.25 miles to the refinery to replace 1/3 of NG needs in thermal oxidizer/boiler,

refinery has 50 mil gal ethanol/yr production capacity 0.864 0.864 Siouxland Ethanol LLC 1

13-mile pipeline, Dart is furthest customer, LFG provides 100% of Dart's fuel needs - combusted in nine boilers, two

thermal oxidizers, two building heaters, and two ovens, LFG generates electricity to treat & transport LFG (self-reliant

project) 3.456 Dart Corporation 9

13-mile pipeline, combusted in three boilers at Advanced Food Products, usage is seasonal, LFG generates electricity to

treat & transport LFG (self-reliant project) 1.584 Advanced Food Products 3

13-mile pipeline, combusted in one boiler at L&S Sweeteners, LFG generates electricity to treat & transport LFG (selfreliant project) 0.432 L&S Sweeteners 1

LFG is dewatered, filtrated, and compressed, then piped 9 miles to connect to Lanchester LF project pipeline; 2 boilers H.R. Ewell 2

LFG is dewatered, filtrated, and compressed, then piped 9 miles to connect to Lanchester LF project pipeline; 1 boiler New Holland Concrete 1

LFG is dewatered, filtrated, and compressed, then piped 9 miles to connect to Lanchester LF project pipeline; 4 oil

heaters and 6 boilers Tyson Foods Incorporated 6

LFG is dewatered, filtrated, and compressed, then piped 9 miles to connect to Lanchester LF project pipeline; 1 boiler, 2

ovens, 2 rooftop building heaters Case New Holland 1

2-mile pipeline, burned in industrial heater and used to power steam boiler; displacing 300,000 gallons of fuel oil use per

year 0.44 0.44 Guilford Technical Textiles 1

LFG fuels 19 of 23 paint shop oven burners and indirect heating of area (displaces NG), processes using LFG are

regenerative thermal oxidizer & hot air supply units (heater boxes), also fueling burner for 1 of 3 boiler systems, total

use is 27 MMBtu/hr 1.152 1.152 BMW Manufacturing Co., LLC 1

Sum 28

Missing 1

Assume 1 Boiler for Missing 29

Total Known 95

Total with Assumption 116 3.6 5.472

### Operational LFG Energy Boiler/Steam Turbine Projects in LMOP Database 9/20/11

This information is from the LMOP Landfill/Project database.

Information in the database is compiled from a variety of sources

by voluntary submittal, is updated periodically, and can change.

LMOP cannot guarantee the validity of the data. 1Landfill ID #

Landfill NameLandfill State

Landfill Owner

OrganizationProject ID #Expansion ID #

Current

Project

Status Project Name Project Start

Date Project

Shutdown

Date LFGE Project

Type LFG Use Details

0 Shutdown Project #1 12/15/1999 12/31/2008

1 Operational Project #1, DeExpansion #1 1/1/2009

72 BKK Landfill-Phases I & II CA BKK Corporation 128 0 Operational Project #2 1/1/1992 Steam Turbine

128 Coyote Canyon SLF CA Irvine Company 184 0 Operational Project #1 1/1/1989 Steam Turbine Zurn boiler supplying a steam turbine driving a 27.5 MW generator

274 Scholl Canyon SLF CA Sanitation Districts of Los

Angeles County, CA, City of

Glendale, CA 333 0 Operational Project #1 7/1/1994 Steam Turbine 5-mile pipeline delivers LFG to be used in unit 3, 4, or 5 at Grayson Power

Plant, remaining capacity of units is fueled by NG

352 Puente Hills LF CA Sanitation Districts of Los

Angeles County, CA 414 0 Operational Project #3, Steam

Cycle Plant 8/8/1986 Steam Turbine 2 boilers to steam turbine

354 Spadra LF CA Sanitation Districts of Los

Angeles County, CA 418 0 Operational Project #1 2/21/1990 Steam Turbine steam boiler power plant

1780 Palos Verdes Landfill CA Sanitation Districts of Los

Angeles County, CA 101831 0 Operational Project #1 5/20/1988 Steam Turbine 1988 steam plant rated at 12 MWe

0 Operational Project #1 1/1/1995

1 Operational Project #1,

Expansion #1 1/1/2004

2 Operational Project #1,

Expansion #2 1/1/2010

420 Orange County SLF FL Orange County, FL 485 0 Operational Project #1 4/1/1998 Steam Turbine 1.6 mile pipeline to Stanton Energy Center, LFG co-fired with coal in 1 of 2

boilers retrofitted with an LFG port to produce steam and electricity

424 North Central Landfill FL Polk County Board of

County Commissioners, FL 489 0 Operational Project #1 1/1/1997 Steam Turbine supplements wood waste and waste tires fuel for steam driven electric

generators Steam Turbine 1-mile pipeline to co-fired boilers coal, oil, natural gas co-fired utility boiler

1829 Cherry Island Landfill DE Delaware Solid Waste

Authority 166401 Steam Turbine 1770 Los Reales Landfill AZ City of Tucson, AZ 101803

### Operational LFG Energy Boiler/Steam Turbine Projects in LMOP Database 9/20/11

This information is from the LMOP Landfill/Project database.

Information in the database is compiled from a variety of sources

by voluntary submittal, is updated periodically, and can change.

LMOP cannot guarantee the validity of the data. 2Landfill ID #

Landfill Name

72 BKK Landfill-Phases I & II

128 Coyote Canyon SLF

274 Scholl Canyon SLF

352 Puente Hills LF

354 Spadra LF

1780 Palos Verdes Landfill

420 Orange County SLF

424 North Central Landfill 1829 Cherry Island Landfill 1770 Los Reales LandfillMW Capacity -Individual MW

Capacity

Type Other MW Capacity

Type DescriptionMW Capacity - TotalLFG Flow to Project(mmscfd) - IndividualLFG Flow to Project(mmscfd) - Total

End User OrganizationNo. of BoilersHeat Input(MMBtu/hr)Heat Input per Boiler(MMBtu/hr)

6 Unknown

2.4 Unknown 1.5

6 Estimated rated capacity: 6.8 MW 6 Anaheim Public Utilities 70.2

21 Unknown 21 7 7 San Diego Gas & Electric Company 1 147.6 147.6

8 Unknown 8 9.29 9.29 City of Glendale, CA 1 195.9 195.9

50 Other contract capacity 50 33.1 33.1 Southern California Edison (SCE) Company 2 697.9 348.9

8.5 Other contract capacity 8.5 6 6 Southern California Edison (SCE) Company 126.5

6 Other operating capacity 6 8.52 8.52 Southern California Edison (SCE) Company 179.6

Unknown 2

Unknown 4.4

Unknown 0.8

12.4 Unknown 12.4 5.76 5.76 Orlando Utilities Commission (OUC) 1 121.4 121.4

5 Other 10% of 50 MW 5 2.83 2.83 Wheelabrator Ridge Energy (WRE) 59.7 31.6

151.8 7.2 Connectiv Power 2.4 1.5 Tucson Electric Power Company 1 31.6

### Operational LFG Energy Boiler/Steam Turbine Projects in LMOP Database 9/20/11

This information is from the LMOP Landfill/Project database.

Information in the database is compiled from a variety of sources

by voluntary submittal, is updated periodically, and can change.

LMOP cannot guarantee the validity of the data. 3Landfill ID #

Landfill NameLandfill State

Landfill Owner

OrganizationProject ID #Expansion ID #

Current

Project

Status Project Name Project Start

Date Project

Shutdown

Date LFGE Project

Type LFG Use Details

0 Shutdown Project #1 5/1/1999 12/31/1999

1 Shutdown Project #1, DeExpansion #1 1/1/2000 12/31/2000

2 Shutdown Project #1, DeExpansion #2 1/1/2001 12/31/2002

3 Shutdown Project #1, DeExpansion #3 1/1/2003 12/31/2003

4 Operational Project #1, DeExpansion #4 1/1/2004

554 MacBeth Road Landfill IN Republic Services, Inc. 180202 0 Operational Project #3 5/1/2002 Boiler LFG is piped 8 or 9 mi. for use in 1 of 3 powerhouse boilers that was

converted from using NG or fuel oil; boiler produces steam to heat

assembly plant and process equipment, and to drive turbines to produce

chilled water and to pump water

787 Fitchburg-Westminster LF MA Waste Management, Inc. 857 0 Operational Project #1 1/1/1997 Steam Turbine LFG is supplemental fuel to wood waste plant

945 Middlesex County LF NJ Middlesex County Utilities

Authority 180848 0 Operational Project #1 1/1/2000 Steam Turbine

1252 Tullytown LF PA Waste Management, Inc. 0 Operational Combination

Project 1/1/1997 boiler/steam turbine

1249 GROWS LF PA Waste Management, Inc. 1 Operational Combination

Project -

Expansion #1 1/1/1999 boiler to steam turbine; each of the 2 steam turbine-generator units at the

Fairless Hills power generation facility is 30 MW but only one is operating

1252 Tullytown LF PA Waste Management, Inc. 2 Operational Combination

Project -

Expansion #2 1/1/2007

1249 GROWS LF PA Waste Management, Inc. 3 Operational Combination

Project -

Expansion #3 1/1/2007 boiler to steam turbine; each of the 2 steam turbine-generator units at the

Fairless Hills power generation facility is 30 MW 1327 Steam Turbine Steam Turbine LFG injected into natural gas line feeding a utility steam boiler 436 North LF FL City of Jacksonville, FL 501

### Operational LFG Energy Boiler/Steam Turbine Projects in LMOP Database 9/20/11

This information is from the LMOP Landfill/Project database.

Information in the database is compiled from a variety of sources

by voluntary submittal, is updated periodically, and can change.

LMOP cannot guarantee the validity of the data. 4Landfill ID #

Landfill Name

554 MacBeth Road Landfill

787 Fitchburg-Westminster LF

945 Middlesex County LF

1252 Tullytown LF

1249 GROWS LF

1252 Tullytown LF

1249 GROWS LF

436 North LFMW Capacity -Individual MW

Capacity

Type Other MW Capacity

Type DescriptionMW Capacity - TotalLFG Flow to Project(mmscfd) - IndividualLFG Flow to Project(mmscfd) - Total

End User OrganizationNo. of BoilersHeat Input(MMBtu/hr)Heat Input per Boiler(MMBtu/hr)

2.55 Unknown 1.26

2.07 Unknown 1.03

0.96 Unknown 0.48

0.78 Unknown 0.42

0.54 Unknown 0.29

2.52 2.52 General Motors Company 1 53.1 53.1

2.09 Unknown 2.09 1.56 1.56 Pine Tree Biogas 32.9

9.9 Unknown 9.9 Public Service Electric & Gas Company

(PSE&G) 115.8

11 Unknown

14.3 Unknown

2.2 Unknown

2.5 Unknown 6.1

394.3 1 1

30 18.7 Exelon Power 0.54 0.29 JEA 6.1

394.3

### Operational LFG Energy Boiler/Steam Turbine Projects in LMOP Database 9/20/11

This information is from the LMOP Landfill/Project database.

Information in the database is compiled from a variety of sources

by voluntary submittal, is updated periodically, and can change.

LMOP cannot guarantee the validity of the data. 5Landfill ID #

Landfill NameLandfill State

Landfill Owner

OrganizationProject ID #Expansion ID #

Current

Project

Status Project Name Project Start

Date Project

Shutdown

Date LFGE Project

Type LFG Use Details

0 Operational Project #2 - End

User 1 7/28/1998

1 Operational Project #2 - End

User 2 7/28/1998

1473 City of Waco LF TX City of Waco, TX 1550 0 Operational Project #1 3/1/2004 Steam Turbine steam boiler from an old naval destroyer ship powers two 750 kW steam

turbine generators from an old missile carrier, enclosed loop system cools

& condenses steam

Project Count 17

Projects Utilizing LFG in Boiler(s) but also in other Equipment So Amount of LFG Utilized Just by Boiler(s) is Unknown

1903 Woodland Meadows LandfillNorth MI Waste Management, Inc. 0 Operational Combination

Project 1/1/1991

1911 Woodland Meadows LandfillSouth MI Waste Management, Inc. 1 Operational Combination

Project, Expansion

#1

1912 Woodland Meadows LandfillVan Buren MI Waste Management, Inc. 2 Operational Combination

Project, Expansion

#1

Project Count 1

Total Project Count 18 1256 Keystone Sanitary Landfill,

Inc. PA Keystone Sanitary Landfill,

Inc. 167018 Cogeneration 12-mile pipeline transports LFG to converted coal-fired boiler to generate

steam to supply steam turbine. Power is sold to the wholesale market.

Steam is also sold to a plastics manufacturer. Plant's full capacity is 21 MW

and burns NG as well as LFG.

166953 Reciprocating

Engine 1.3-mile pipeline to steam boilers and 2.4 MW cogeneration plant (3

engines) - equivalent MW total is 3.5 MW

### Operational LFG Energy Boiler/Steam Turbine Projects in LMOP Database 9/20/11

This information is from the LMOP Landfill/Project database.

Information in the database is compiled from a variety of sources

by voluntary submittal, is updated periodically, and can change.

LMOP cannot guarantee the validity of the data. 6Landfill ID #

Landfill Name

1473 City of Waco LF

Projects Utilizing LFG in Boiler(s) bu

1903 Woodland Meadows LandfillNorth

1911 Woodland Meadows LandfillSouth

1912 Woodland Meadows LandfillVan Buren 1256 Keystone Sanitary Landfill,

Inc.MW Capacity -Individual MW

Capacity

Type Other MW Capacity

Type DescriptionMW Capacity - TotalLFG Flow to Project(mmscfd) - IndividualLFG Flow to Project(mmscfd) - Total

End User OrganizationNo. of BoilersHeat Input(MMBtu/hr)Heat Input per Boiler(MMBtu/hr)

Unknown PPL Corporation

Unknown PEI Power

1.5 Other rated capacity 1.5 1 1 Tenaska 1 21.1 21.1

Sum 11 2,499

Missing 7

Assume 1 Boiler for Missing 18

0 Unknown 0

0 Unknown 0

3.5 Unknown 2.016

Sum 0

Missing 1

Assume 1 Boiler for Missing 1

Total Known 11

Total with Assumption 19 93.6 1

Ford Motor Company 8

3.5 2.016 93.6

### Wastewater Treatment Residuals (WWTR) at Forest Product Mills as Non-Waste Fuels

1. Generation and Management

In 2008, 23 percent of WWTR were used in boile rs as a critical source of energy for

mills. Use depends on fuel availability, cost of alternative fuels and the capacity of the

boiler to use alternative fuels. For example, if a mill has a surplus of hog fuel/bark, it will

not need the makeup energy from other onsite residuals such as WWTR.

Over 90 percent of WWTR ar e processed in some manner to ensure fuel product

specification needs are met. T he primary preparati on is dewatering with belt filter or

screw presses. This results in the delivery of a material to the boiler th at is ready to burn

according to the specifications of the m ill’s biomass boilers which are uniquely designed

to handle a wide range of fuel qua lities and moisture contents.

Two types of residuals are generated by mills . Primary residuals are generated on a

continuous basis. They are typically conveyed directly from the clarifiers to dewatering

equipment, dewatered, mixed with hog fuel (with bins and metered conveyors or in piles

with a front end loader) and conveyed to boiler in a continuous or semi-continuous

process.

Secondary WWTR are generat ed depending upon the type of secondary treatment in

use. In some instances, the residuals are generated continuously (such as for activated

sludge); in others (such as aerated stabiliz ation) residuals are generated far less

frequently. For activated sludge systems, like with primary residuals, wastewater is

decanted from the secondary clarifiers, and re siduals are removed from the bottom of

the clarifiers and sent di rectly to be dewatered.

When aerated stabilization residual s are burned, they are norma lly staged for a time to

allow free water to drain. This would o ccur on a concrete pad on another surface, in a

fabric tube or any other manner that allows free water to drain back to WWT system.

Additional dewatering is accomplished with scr ew presses, belt presses or other similar

devices.

When WWTR are not immediately used as fuels, they are stored in piles like other

biomass materials such as bark and hog fuel because they have similar Btu and content

properties. Because of their similar pr operties, WWTR are blended with other fuels to

obtain the optimum overall fuel properties and consistency prior to introduction into the

boiler to produce stable combustion condi tions. WWTR, with the other fuels, are

delivered to the boiler in the same manner as other biomass fuels pr imarily via conveyor

belt, but often using a front end loader. As mentioned, in most instances storage is

minimized and the fuel is prepared, conveyed, blended with other fuels and burned in a

continuous or semi-continuous process.

### A typical configuration for management of primary and secon dary residuals is shown on

the following diagram.

These facts demonstrate that WWTR destined fo r energy recovery in a mill boiler is not

a solid waste because it is not discarded and is managed to enhance its fuel qualities

and stored and burned like ot her biomass residuals.

2. Reliability in meeting steam de mands of the manufacturing process

Multi-fuel boilers at pulp and paper mills are designed to burn a wide variety of biomassbased materials with different fu el characteristics and moisture s. For example, typically,

hog fuel ranges from 35 – 60 percent moisture content. However, during certain times

of the year, very wet bark (which can be as high as 70 percent moisture content) is used Mill

Process Equalization

Basin Primary

Clarifiers

Process Wastewate r Secondary

Clarifiers Contact / Aeration

Basins WWTR

Dewatering Thickener

Waste Treatment

Residuals Primary Residuals

Secondary Residuals

### as a fuel. The moisture content of WWT R when burned is in the same range as

biomass hog fuel and similar in terms of biomass content and thus fuel value.

A typical mill with an activated sludge system may have combined primary and

secondary WWTR content as follows: Wa ter - ~60%; Wood fiber - 8-20%; other

Biomass - 12-16%; Paper fillers - 14-20%;

WWTR are produced at a steady and regular rate at pulp and paper mills as clarifier

solids streams and thus are a steady, reliable, and necessary part of the fuel stream.

Clarifiers exist for the purpose of removi ng the largely paper fi ber solids from the

wastewater as the first st ep in WWT. As noted ear lier, depending on the type of

wastewater treatment proce ss in place, some mills have both primary and secondary

clarifiers. Fiber also carries over to se condary treatment system s where it builds up

with time and is then removed and handled in a similar manner to clarifier solids.

Removal of WWTR from secondary treatment systems, polishing p onds and other areas

downstream of clarifiers is necessary to maintain treatment system performance and it

is scheduled appropriately to achieve this objective. Timing is unique to the system

configuration, pulp mill performance and other site specific factors.

Thus boiler operators at mills can plan for th at portion of the Btu needs that comes from

WWTR when determining the mix of fuels to us e at any given time (hog fuel, other

biomass residuals, or fossil fuels). Relati ve amounts of WWTR, hog fuel and other fuels

feeding a given boiler depend on the particular site equipment scenario of the mill:

dewatering equipment, WWTR properties, and boiler design.

For all the above reasons, WWTR is a reliable sour ce of fuel. In fact, WWTR is used as

the primary fuel (and in some cases as the on ly fuel) in fluidized Bed Combustors (FBC)

in the US. In fact, one of the best performi ng boilers used to set the MACT floor for

carbon monoxide from FBC burns only WWTRs.

3. Material Specifications

WWTR Btu/lb values range from 3,300 to 9, 500 (on a dry basis) depending on whether

it is derived from primary or secondary wastewater treatment, type of pulp and paper

mill and the quantity of clay or other inert ma terials present. As noted, dewatering of

WWTR is a regular practice to ready the ma terial for combustion. In the rare cases

when dewatering does not occur, the WWTR m eets the combustion specifications to

efficiently burn in the biomass boiler when mixed with other fuel s. Using additional

energy to dewater WWTR becomes counterproducti ve to the energy balance of the mill.

### 4. Off-site WWTR Management

According to AF&PA’s 2008 member surv ey, WWTR were managed in a number of

different ways: 23 percent were burned for energy, 16 percent for land application, and

13 percent for other beneficial uses (such as raw materials for other processes – roofing

felt, flower pots, potting soil, etc.). 1 

### Thus, more than half of WWTR are managed for

beneficial use. When burned for energy, WWTR are almost entirely managed on site.

However, when used for other purposes, WWTR ar e shipped off site usually in trucks.

As shown in the diagram above, WWTR ar e generally dewatered prior to management

– including when shipped off site to r educe transportation costs and ease the handling

of the material.

1 Of course, the NHSM Rule only addresses whethe r materials are wastes when combusted.

Management of WWTR for other purposes is not rele vant to a determination whether they are solid

wastes when they are managed as fuel to be burned for energy recovery5. Contaminant Levels in WWTRAs presented to OSW in June, the chart below shows that there is a range of values for select contaminants in WWTR butthe variability ranges from 2 to5 times between the mean and the 90thpercentile confidence interval across the samples(see mercury as example shaded in orange). This is no different than many other materials used as fuel such as coal thatare derived from natural materials which have inherent variability. The level of contaminants in no way affects theperformance characteristicsof WWTR as a fuel.Wastewater Treatment Residuals Select Constituent Variability for Available Test DataBTU(BTU/lb)Hg(mg/Kg)Cl-(mg/Kg)As(mg/Kg)Be (mg/Kg)Cd(mg/Kg)Cr(mg/Kg)Pb(mg/Kg)Mn(mg/Kg)Ni(mg/Kg)Se(mg/Kg)Number of Samples94 82 93 77 53 82 84 77 84 84 55Mean58000.040 361 1.15 0.206 0.376 11.35 4.94 381 23.08 0.177Std. Dev.1548 0.063 661 1.18 0.106 0.3666.96 2.55 291 33.17 0.168T-distribution factor1.296 1.296 1.296 1.296 1.299 1.2961.296 1.296 1.296 1.296 1.29990% ConfidenceInterval7,8070.123 1217 2.68 0.345 0.850 20.37 8.24 758 66.07 0.395